Business Plan for UJVNL - UJVN Limited Dehradun...
Business Plan for UJVNL - UJVN Limited Dehradun...
Business Plan for UJVNL - UJVN Limited Dehradun...
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
<strong>Business</strong> <strong>Plan</strong> <strong>for</strong> the Control Period<br />
(April 1, 2013 to March 31, 2016)<br />
BEFORE THE<br />
HON’BLE UTTARAKHAND ELECTRICITY REGULATORY COMMISSION<br />
DEHRADUN, UTTARAKHAND<br />
<strong>UJVN</strong> <strong>Limited</strong><br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
TABLE OF CONTENTS<br />
1 INTRODUCTION .................................................................................................................................... 16<br />
1.1 COMPANY OVERVIEW .................................................................................................................................. 17<br />
1.2 VISION AND MISSION ................................................................................................................................... 19<br />
1.3 EXISTING INSTALLED CAPACITY ....................................................................................................................... 20<br />
1.4 UPCOMING GENERATION CAPACITY: ............................................................................................................... 23<br />
2 CAPITAL EXPENDITURE PLAN – UPCOMING PROJECTS .......................................................................... 31<br />
2.1 VYASI HYDROELECTRIC PROJECT (120 MW) .................................................................................................... 32<br />
2.2 LAKHWAR MULTIPURPOSE PROJECT (300 MW) ............................................................................................... 38<br />
2.3 KISHAU MULTIPURPOSE PROJECT (660 MW) .................................................................................................. 44<br />
2.4 SIRKARI BHYOL RUPSIABAGAR HYDROELECTRIC PROJECT (210 MW) .................................................................... 49<br />
2.5 BOWALA NAND PRAYAG HYDROELECTRIC PROJECT (300 MW) ........................................................................... 53<br />
2.6 NAND PRAYAG LANGASU HYDROELECTRIC PROJECT (100 MW) .......................................................................... 58<br />
2.7 TAMAK LATA HYDROELECTRIC PROJECT (250 MW)........................................................................................... 63<br />
2.8 PALA MANERI HYDROELECTRIC PROJECT (480 MW) ......................................................................................... 67<br />
2.9 BHAIRONGHATI HYDROELECTRIC PROJECT (381 MW) ....................................................................................... 68<br />
3 CAPITAL EXPENDITURE PLAN – EXISTING PROJECTS ............................................................................. 69<br />
3.1 CHIBRO POWER STATION (240 MW) ............................................................................................................. 70<br />
3.2 KHODRI POWER STATION (120 MW) ............................................................................................................. 76<br />
3.3 DHAKRANI POWER STATION (33.75 MW) ...................................................................................................... 82<br />
3.4 DHALIPUR POWER STATION (51 MW) ............................................................................................................ 88<br />
3.5 KULHAL POWER STATION (30 MW) ............................................................................................................... 94<br />
3.6 TILOTH POWER STATION (90 MW) .............................................................................................................. 100<br />
3.7 CHILLA POWER STATION (144 MW) ............................................................................................................ 106<br />
3.8 KHATIMA POWER STATION (41.40 MW) ...................................................................................................... 112<br />
3.9 RAMGANGA POWER STATION (198 MW) ..................................................................................................... 118<br />
3.10 MANERI BHALI - II HYDROELECTRIC PROJECT (304 MW) ............................................................................ 124<br />
3.11 REFURBISHMENT OF ASAN BARRAGE, AT DHALIPUR (DEHRADUN).................................................................. 128<br />
3.12 REFURBISHING OF ICHARI DAM, AT ICHARI, KOTI (DEHRADUN)...................................................................... 130<br />
3.13 REHABILITATION WORK OF VIRBHADRA BARRAGE, PASHULOK, RISHIKESH ....................................................... 132<br />
3.14 REFURBISHMENT OF DAKPATHAR BARRAGE, AT DAKPATHAR (DEHRADUN) ...................................................... 134<br />
3.15 REFURBISHMENT OF MANERI DAM AT MANERI, UTTRAKASHI ....................................................................... 136<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.16 SPECIAL CLOSURE WORKS OF CIVIL & HYDRO MECHANICAL STRUCTURES FOR YAMUNA HYDEL SCHEME STAGE–I<br />
(PART-I&II) & STAGE-IV ..................................................................................................................................... 138<br />
3.17 CLOSURE OF CHILLA HEP FOR SPECIAL REPAIR OF POWER CHANNEL, SUBMERGED PARTS OF STRUCTURES & HYDRO-<br />
MECHANICAL COMPONENTS OF VIRBHADRA BARRAGE, PASHULOK, RISHIKESH ............................................................... 140<br />
4 MAJOR SHUTDOWN PLAN OF POWER STATIONS................................................................................ 143<br />
4.1 MAJOR SHUTDOWN PLAN OF POWER STATIONS ............................................................................................. 144<br />
5 SUMMARY .......................................................................................................................................... 146<br />
5.1 CAPITAL EXPENDITURE & CAPITALIZATION...................................................................................................... 147<br />
6 TECHNICAL REPORT OF EXISTING POWER STATIONS .......................................................................... 149<br />
6.1 OBJECTIVE OF THE TECHNICAL REPORT .......................................................................................................... 150<br />
6.2 TECHNICAL REPORT OF TILOTH POWER STATION ................................................................................. 151<br />
6.3 TECHNICAL REPORT OF CHIBRO POWER STATION ................................................................................ 166<br />
6.4 TECHNICAL REPORT OF DHAKRANI POWER STATION ........................................................................... 179<br />
6.5 TECHNICAL REPORT OF DHALIPUR POWER STATION ............................................................................ 192<br />
6.6 TECHNICAL REPORT OF KHODRI POWER STATION ............................................................................... 205<br />
6.7 TECHNICAL REPORT OF KULHAL POWER STATION ............................................................................... 218<br />
6.8 TECHNICAL REPORT OF CHILLA POWER STATION ................................................................................. 231<br />
6.9 TECHNICAL REPORT OF KHATIMA POWER STATION ............................................................................. 244<br />
6.10 TECHNICAL REPORT OF RAMGANGA POWER STATION ................................................................... 256<br />
6.11 TECHNICAL REPORT OF MANERI BHALI – II HYDROELECTRIC PROJECT ............................................ 271<br />
7 ANNEXURES ........................................................................................................................................ 278<br />
7.1 ANNEXURE 1: 10 DAILY DISCHARGE TILOTH POWER STATION............................................................................ 279<br />
7.2 ANNEXURE 2: 10 DAILY DISCHARGE CHIBRO POWER STATION ........................................................................... 280<br />
7.3 ANNEXURE 3: 10 DAILY DISCHARGE DHAKRANI POWER STATION ....................................................................... 281<br />
7.4 ANNEXURE 4: 10 DAILY DISCHARGE DHALIPUR POWER STATION ....................................................................... 282<br />
7.5 ANNEXURE 5: 10 DAILY DISCHARGE KHODRIPOWER STATION ........................................................................... 283<br />
7.6 ANNEXURE 6: 10 DAILY DISCHARGE KULHAL POWER STATION ........................................................................... 284<br />
7.7 ANNEXURE 7: 10 DAILY DISCHARGE CHILLA POWER STATION ............................................................................ 285<br />
7.8 ANNEXURE 8: 10 DAILY DISCHARGE KHATIMA POWER STATION ........................................................................ 286<br />
7.9 ANNEXURE 9: 10 DAILY DISCHARGE MANERI BHALI – II HYDROELECTRIC PROJECT ................................................ 287<br />
7.10 ANNEXURE 10: BREAKUP OF COST FOR BALANCE WORKS AS PER ORIGINAL DPR AS APPROVED BY CEA AND PROPOSED<br />
NEW WORKS FOR MANERI BHALI –II HEP................................................................................................................ 288<br />
7.11 ANNEXURE 11: NATURE OF ENVIRONMENTAL IMPACTS CAUSED BY RMU AND SUGGESTED MITIGATION MEASURES 302<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
7.12 ANNEXURE 12: FINANCING OF RMU OF SIX HYDRO ELECTRIC PROJECTS THROUGH KFW .................................. 307<br />
ANNEXURE 13: LETTER OF CEA FOR LAKHWAR POWER STATION ................................................................................. 314<br />
7.13 ANNEXURE 14: LOAN AGREEMENT OF PFC FOR RMU OF KHATIMA POWER STATION ....................................... 315<br />
7.14 Annexure 15: Note on Small Hydroelectric Projects........................................................... ............<br />
..3156<br />
7.15 Annexure 16 : Note on Manpower <strong>Plan</strong>ning of <strong>UJVN</strong> Ltd. during the Control Period......................317<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
List of Tables<br />
Table 1: Brief History of Formation of <strong>UJVN</strong> <strong>Limited</strong> ............................................................... 19<br />
Table 2: Salient Features of the Existing Power Stations ........................................................ 20<br />
Table 3: Generation of Hydro Projects in <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> last 5 years ................................. 22<br />
Table 4: <strong>Plan</strong>ned Capacity Addition by <strong>UJVN</strong> <strong>Limited</strong> .............................................................. 24<br />
Table 5: Capital Expenditure during Control Period – Vyasi Project ....................................... 33<br />
Table 6: Capital Cost – Vyasi Project ........................................................................................ 34<br />
Table 7: Funding Pattern during the Control Period – Vyasi Project ....................................... 36<br />
Table 8: Capex & Capitalization during the Control Period – Vyasi Project ............................ 37<br />
Table 9: Capital Expenditure during the Control Period – Lakhwar Project ............................ 39<br />
Table 10: Capital Cost – Lakhwar Project ................................................................................ 40<br />
Table 11: Funding Pattern during the Control Period – Lakhwar Project ............................... 43<br />
Table 12: Capex & Capitalization during the Control Period – Lakhwar Project ..................... 43<br />
Table 13: Capital Expenditure during the Control Period – Kishau Project ............................. 45<br />
Table 14: Capital Cost – Kishau Project ................................................................................... 46<br />
Table 15: Funding Pattern during the Control Period – Kishau Project .................................. 48<br />
Table 16: Capex & Capitalization during the Control Period – Kishau Project ........................ 48<br />
Table 17: Capital Expenditure during the Control Period – Sirkari Bhyol Rupsiabagar Project<br />
.................................................................................................................................................. 49<br />
Table 18: Capital Cost – Sirkari Bhyol Rupsiabagar Project ..................................................... 50<br />
Table 19: Funding Pattern during the Control Period – Sirkari Bhyol Rupsiabagar Project .... 52<br />
Table 20: Capex & Capitalization during the Control Period –Sirkari Bhyol Rupsiabagar<br />
Project ...................................................................................................................................... 52<br />
Table 21: Capital Expenditure during the Control Period – Bowala Nand Prayag Project ...... 53<br />
Table 22: Capital Cost – Bowala Nand Prayag Project ............................................................. 54<br />
Table 23: Funding Pattern during the Control Period – Bowla Nand Prayag Project .............. 57<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 24: Capex & Capitalization during the Control Period – Bowla Nand Prayag Project ... 57<br />
Table 25: Capital Expenditure during the Control Period – Nand Prayag Langasu Project ..... 58<br />
Table 26: Capital Cost – Nand Prayag Langasu Project ........................................................... 59<br />
Table 27: Funding Pattern during the Control Period – Nand Prayag Langasu Project .......... 61<br />
Table 28: Capex & Capitalization during the Control Period – Nand Prayag Langasu Project 62<br />
Table 29: Capital Expenditure during the Control Period – Tamak Lata Project ..................... 63<br />
Table 30: Capital Cost – Tamak Lata Project ............................................................................ 64<br />
Table 31: Funding Pattern during the Control Period – Tamak Lata Project ........................... 66<br />
Table 32: Capex & Capitalization during the Control Period – Tamak Lata Project ................ 66<br />
Table 33: Capital Expenditure during the Control Period – Chibro Project ............................. 70<br />
Table 34: Capital Cost – Chibro Project ................................................................................... 72<br />
Table 35: Funding Pattern during the Control Period – Chibro Project .................................. 75<br />
Table 36: Capex & Capitalization during the Control Period – Chibro Project ........................ 75<br />
Table 37: Capital Expenditure during Control Period – Khodri Project ................................... 76<br />
Table 38: Capital Cost – Khodri Project ................................................................................... 78<br />
Table 39: Funding Pattern during the Control Period – Khodri Project .................................. 81<br />
Table 40: Capex & Capitalization during the Control Period – Khodri Project ........................ 81<br />
Table 41: Capital Expenditure during the Control Period – Dhakrani Project ......................... 82<br />
Table 42: Capital Cost – Dhakrani Project................................................................................ 84<br />
Table 43: Funding Pattern during the Control Period – Dhakrani Project............................... 87<br />
Table 44: Capex & Capitalization during the Control Period – Dhakrani Project .................... 87<br />
Table 45: Capital Expenditure during the Control Period – Dhalipur Project ......................... 88<br />
Table 46: Capital Cost – Dhalipur Project ................................................................................ 90<br />
Table 47: Funding Pattern during Control Period – Dhalipur Project ...................................... 93<br />
Table 48: Capex & Capitalization during the Control Period – Dhalipur Project ..................... 93<br />
Table 49: Capital Expenditure during the Control Period – Kulhal Project ............................. 94<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 50: Capital Cost – Kulhal Project .................................................................................... 96<br />
Table 51: Funding Pattern during the Control Period – Kulhal Project ................................... 99<br />
Table 52: Capex & Capitalization during the Control Period – Kulhal Project ......................... 99<br />
Table 53: Capital Expenditure during the Control Period – Tiloth Project ............................ 101<br />
Table 54: Capital Cost – Tiloth Project ................................................................................... 102<br />
Table 55: Funding Pattern during the Control Period – Tiloth Project .................................. 105<br />
Table 56: Capex & Capitalization during the Control Period – Tiloth Project ....................... 105<br />
Table 57: Capital Expenditure during the Control Period – Chilla Project ............................ 106<br />
Table 58: Capital Cost – Chilla Project ................................................................................... 108<br />
Table 59: Funding Pattern during the Control Period – Chilla Project .................................. 111<br />
Table 60: Capex & Capitalization during the Control Period – Chilla Project ........................ 111<br />
Table 61: Capital Expenditure during the Control Period – Khatima Project ........................ 112<br />
Table 62: Capital Cost – Khatima Project ............................................................................... 114<br />
Table 63: Funding Pattern during the Control Period – Khatima Project .............................. 117<br />
Table 64: Capex & Capitalization during the Control Period – Khatima Project ................... 117<br />
Table 65: Capital Expenditure during the Control Period – Ramganga Project .................... 119<br />
Table 66: Capital Cost – Ramganga Project ........................................................................... 120<br />
Table 67: Funding Pattern during the Control Period – Ramganga Project .......................... 122<br />
Table 68: Capex & Capitalization during the Control Period – Ramganga Project ................ 123<br />
Table 69: Capital Expenditure during the Control Period – Maneri Bhali - II Project ............ 125<br />
Table 70: Capital Cost – Maneri Bhali - II Project .................................................................. 126<br />
Table 71: Funding Pattern during the Control Period – Maneri Bhali - II Project ................. 127<br />
Table 72: Capex & Capitalization during the Control Period – Maneri Bhali - II Project ....... 127<br />
Table 73 : Summary of expenses proposed under DRIP Scheme and Closure Works<br />
(in Rs. Lakh) ............................................................................................................................ 141<br />
Table 74 : Outage <strong>Plan</strong> during the Control Period <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong>..................................... 145<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 75: Capex & Capitalization during the control period - <strong>UJVN</strong> <strong>Limited</strong> ......................... 147<br />
Table 76: Debt & Equity <strong>for</strong> Capital Expenditure during the control period - <strong>UJVN</strong> <strong>Limited</strong> 148<br />
Table 77: 90% dependable year – Tiloth Power Station ........................................................ 152<br />
Table 78: Discharge & Generation Data – Tiloth Power Station ........................................... 154<br />
Table 79: Design Energy: Tiloth Power Station ...................................................................... 155<br />
Table 80: Uncontrollable Losses – Tiloth Power Station ....................................................... 155<br />
Table 81: Year wise Maximum Possible Generation (MU) – Tiloth Power Station ............... 157<br />
Table 82: Design Energy – Tiloth Power Station .................................................................... 157<br />
Table 83: <strong>Plan</strong>t Availability during FY 2000 - 12 – Tiloth Power Station................................ 158<br />
Table 84: % Generation Loss on account of various Factors – Tiloth Power Station ............ 160<br />
Table 85: Auxiliary and Trans<strong>for</strong>mation Losses – Tiloth Power Station ................................ 161<br />
Table 86: 90% Dependable year – Chibro Power Station ...................................................... 167<br />
Table 87: Discharge & Generation Data – Chibro Power Station .......................................... 169<br />
Table 88: Design Energy- Chibro Power Station .................................................................... 170<br />
Table 89: Uncontrollable Losses – Chibro Power Station ...................................................... 170<br />
Table 90: Year wise Maximum Possible Generation (MU) – Chibro Power Station .............. 171<br />
Table 91: Design Energy – Chibro Power Station .................................................................. 172<br />
Table 92: <strong>Plan</strong>t Availability during FY 2000 - 12 – Chibro Power Station .............................. 172<br />
Table 93: % Generation Loss on account of various Factors – Chibro Power Station ........... 174<br />
Table 94: Auxiliary and Trans<strong>for</strong>mation Losses – Chibro Power Station ............................... 174<br />
Table 95: 90% Dependable Year– Dhakrani Power Station ................................................... 180<br />
Table 96: Discharge & Generation Data – Dhakrani Power Station ...................................... 182<br />
Table 97- Design Energy: Dhakrani Power Station ................................................................ 183<br />
Table 98: Uncontrollable Losses – Dhakrani Power Station .................................................. 183<br />
Table 99: Year wise Maximum Possible Generation (MU) – Dhakrani Power Station .......... 184<br />
Table 100: Design Energy – Dhakrani Power Station ............................................................ 185<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 101: <strong>Plan</strong>t Availability during FY 2000 - 12 – Dhakrani Power Station ........................ 185<br />
Table 102: % Generation Loss on account of various Factors – Dhakrani Power Station ..... 187<br />
Table 103: Auxiliary and Trans<strong>for</strong>mation Losses – Dhakrani Power Station ......................... 188<br />
Table 104: 90% Dependable year – Dhalipur Power Station ................................................. 193<br />
Table 105: Discharge & Generation Data – Dhalipur Power Station ..................................... 195<br />
Table 106: Design Energy- Dhalipur Power Station ............................................................... 196<br />
Table 107: Uncontrollable Losses – Dhalipur Power Station ................................................. 196<br />
Table 108: Year wise Maximum Possible Generation (MU) – Dhalipur Power Station ......... 197<br />
Table 109: Design Energy – Dhalipur Power Station ............................................................. 198<br />
Table 110: <strong>Plan</strong>t Availability during FY 2001- 12 – Dhalipur Power Station .......................... 198<br />
Table 111: % Generation Loss on account of various Factors – Dhalipur Power Station ...... 200<br />
Table 112: Auxiliary and Trans<strong>for</strong>mation Losses – Dhalipur Power Station .......................... 201<br />
Table 113: 90% Dependable year – Khodri Power Station .................................................... 207<br />
Table 114: Discharge & Generation Data – Power Station .................................................... 208<br />
Table 115: Design Energy-Khodri Power Station ................................................................... 209<br />
Table 116: Uncontrollable Losses – Khodri Power Station .................................................... 209<br />
Table 117: Year wise Maximum Possible Generation (MU) – Khodri Power Station ............ 210<br />
Table 118: Design Energy – Khodri Power Station ................................................................ 211<br />
Table 119: <strong>Plan</strong>t Availability during FY 2000 - 12 – Khodri Power Station ............................ 211<br />
Table 120: % Generation Loss on account of various Factors – Khodri Power Station ......... 213<br />
Table 121: Auxiliary and Trans<strong>for</strong>mation Losses – Khodri Power Station ............................. 214<br />
Table 122: 90% dependable year – Kulhal Power Station ..................................................... 219<br />
Table 123: Discharge & Generation Data – Kulhal Power Station ......................................... 221<br />
Table 124: Design Energy-Kulhal Power Station .................................................................... 222<br />
Table 125: Uncontrollable Losses – Kulhal Power Station .................................................... 222<br />
Table 126: Year wise Maximum Possible Generation (MU) – Kulhal Power Station ............ 223<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 127: Design Energy – Kulhal Power Station ................................................................. 224<br />
Table 128: <strong>Plan</strong>t Availability during FY 2001- 12 – Kulhal Power Station .............................. 224<br />
Table 129: % Generation Loss on account of various Factors – Kulhal Power Station ......... 225<br />
Table 130: Auxiliary and Trans<strong>for</strong>mation Losses – Kulhal Power Station ............................. 226<br />
Table 131: 90% dependable year – Chilla Power Station ...................................................... 232<br />
Table 132: Discharge & Generation Data – Chilla Power Station .......................................... 234<br />
Table 133: Design Energy: Chilla Power Station .................................................................... 235<br />
Table 134: Uncontrollable Losses – Chilla Power Station ...................................................... 235<br />
Table 135: Year wise Maximum Possible Generation (MU) – Chilla Power Station .............. 236<br />
Table 136: Design Energy – Chilla Power Station .................................................................. 237<br />
Table 137: <strong>Plan</strong>t Availability during FY 2002- 12 – Chilla Power Station ............................... 237<br />
Table 138: % Generation Loss on account of various Factors – Chilla Power Station ........... 239<br />
Table 139: Auxiliary and Trans<strong>for</strong>mation Losses – Chilla Power Station ............................... 240<br />
Table 140: 90% dependable year – Khatima Power Station ................................................. 246<br />
Table 141: Discharge & Generation Data – Khatima Power Station ..................................... 247<br />
Table 142: Design Energy- Khatima Power Station ............................................................... 248<br />
Table 143: Uncontrollable Losses – Khatima Power Station ................................................. 248<br />
Table 144: Year wise Maximum Possible Generation (MU) – Khatima Power Station ......... 249<br />
Table 145: Design Energy – Khatima Power Station .............................................................. 250<br />
Table 146: <strong>Plan</strong>t Availability during FY 2000 - 12 – Khatima Power Station ......................... 250<br />
Table 147: % Generation Loss on account of various Factors – Khatima Power Station ...... 251<br />
Table 148: Auxiliary and Trans<strong>for</strong>mation Losses – Khatima Power Station .......................... 252<br />
Table 149: Annual Discharge ................................................................................................. 260<br />
Table 150: 90% Dependable year .......................................................................................... 261<br />
Table 151: Energy Generation potential <strong>for</strong> the dependable year on 10 daily discharge basis<br />
................................................................................................................................................ 262<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 152: <strong>Plan</strong>t availability based on Peaking Capability ..................................................... 265<br />
Table 153: <strong>Plan</strong>t Availability during 2007-12 ......................................................................... 266<br />
Table 154: Auxiliary and Trans<strong>for</strong>mation losses .................................................................... 267<br />
Table 155: <strong>Plan</strong>t Availability during FY 2008-12 – Maneri Bhali - II Hydroelectric Project.... 272<br />
Table 156: % Generation Loss on account of various Factors – Maneri Bhali - II Hydroelectric<br />
Project .................................................................................................................................... 274<br />
Table 157: Auxiliary and Trans<strong>for</strong>mation Losses – Maneri Bhali - II Hydroelectric Project .. 275<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
BEFORE THE HON’BLE UTTARAKHAND ELECTRICITY REGULATORY COMMISSION<br />
DEHRADUN, UTTARAKHAND<br />
IN THE MATTER OF:<br />
The <strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> FY 2013-14 to FY 2015-2016 under Section 62 and 86<br />
of the Electricity Act, 2003 read with the relevant regulations and guidelines of the Hon’ble<br />
Commission.<br />
And<br />
IN THE MATTER OF THE APPLICANT:<br />
<strong>UJVN</strong> <strong>Limited</strong>, a Company incorporated under the provisions of the Companies Act, 1956<br />
and having its registered office at UJJWAL, Maharani Bagh, GMS Road, <strong>Dehradun</strong> –<br />
Petitioner<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
A. Specific Legal Provisions under which the Petition is being filed<br />
The Hon’ble Commission has notified the Uttarakhand Electricity Regulatory<br />
Commission (Terms and Conditions <strong>for</strong> Determination of Tariff) Regulations, 2011,<br />
on 19 th December 2011. In accordance with Regulation 9 of these regulations states<br />
that Applicant is to submit a <strong>Business</strong> <strong>Plan</strong> <strong>for</strong> the entire control period. Regulation<br />
9(1) states:<br />
“An Applicant shall submit, under affidavit and as per the UERC (Conduct of <strong>Business</strong>)<br />
Regulations, 2004, a <strong>Business</strong> <strong>Plan</strong> by May 31, 2012, <strong>for</strong> the Control Period of three<br />
(3) financial years from April 1, 2013 to March 31, 2016,<br />
a) The <strong>Business</strong> <strong>Plan</strong> <strong>for</strong> the Generating Company shall be <strong>for</strong> the entire control<br />
period and shall, interalia, contain-<br />
(i) Capital investment plan, which shall include details of the<br />
investments planned by the Generating Company <strong>for</strong> existing<br />
stations, yearly phasing of capital expenditure along with the<br />
source of funding, financing plan and corresponding capitalisation<br />
schedule. This plan shall be commensurate with R&M schemes and<br />
proposed efficiency improvements <strong>for</strong> various plants of the<br />
company.<br />
(ii) The capital investment plan shall show separately, on-going<br />
projects that will spill over into the years under review, and new<br />
projects (along with justification) that will commence in the years<br />
under review but may be completed within or beyond the tariff<br />
period.<br />
(iii) The Generating Company shall submit plant-wise details of the<br />
capital structure and cost of financing (interest on debt and return<br />
on equity), after considering the existing market conditions, terms<br />
of the existing loan agreements, risks associated in generation<br />
business and creditworthiness;<br />
(iv) Details related to major shut down of machines, if any<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
(v) Trajectory of per<strong>for</strong>mance parameters”<br />
In compliance with this Regulation, the <strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> has been<br />
submitted through this petition.<br />
B. Facts of the Case<br />
1. The Petitioner, <strong>UJVN</strong> <strong>Limited</strong>, is a company incorporated under the provisions of the<br />
Companies Act, 1956, having its registered office at UJJWAL, Maharani Bagh, GMS<br />
Road, <strong>Dehradun</strong>.<br />
2. It is submitted that Government of India (GoI) vide order dated November 5, 2001<br />
transferred all hydropower assets of Uttar Pradesh Jal Vidyut Nigam <strong>Limited</strong><br />
(UPJVNL) located in the State of Uttarakhand to <strong>UJVN</strong> <strong>Limited</strong> with effect from<br />
November 09, 2001. In compliance to the said order, administrative and financial<br />
control of all hydro Power Stations of UPJVNL in operation or under construction in<br />
the State of Uttarakhand was taken over by <strong>UJVN</strong> <strong>Limited</strong> with effect from<br />
November 09, 2001. GOI order also defines the basis of division of assets and<br />
liabilities between UPJVNL and <strong>UJVN</strong> <strong>Limited</strong>.<br />
3. Though administrative and financial control was transferred to <strong>UJVN</strong> <strong>Limited</strong> on<br />
November 09, 2001, <strong>UJVN</strong> <strong>Limited</strong> initiated discussions with UPJVNL <strong>for</strong> <strong>for</strong>mulation<br />
of transfer scheme as per the said GOI order on mutually agreed terms.<br />
4. Government of Uttarakhand (GoU) has notified the provisional transfer scheme vide<br />
its notification no. 70/AS (E)/I/2008-04 (3)/22/08 dated 07/03/08.<br />
C. Prayer to Hon’ble Commission<br />
Further, <strong>UJVN</strong> <strong>Limited</strong> prays the following be<strong>for</strong>e the Hon’ble Commission:<br />
1) Approve the <strong>Business</strong> <strong>Plan</strong> <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> the Control Period (FY 2013-<br />
14 to FY 2015-16) in accordance with Regulation 9 of Uttarakhand Electricity<br />
14
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Regulatory Commission (Terms and Conditions <strong>for</strong> Determination of Tariff)<br />
Regulations, 2011.<br />
2) Approve planned outages of Power Stations and also grant permission <strong>for</strong><br />
change in the schedule.<br />
3) Approve Methodology adopted <strong>for</strong> calculation of NAPAF and other technical<br />
parameters.<br />
4) Condone any inadvertent omission/ errors/ shortcomings and permit <strong>UJVN</strong><br />
<strong>Limited</strong> to add/ change/ modify/ alter this filing and make further<br />
submissions as may be required at a future date.<br />
5) Any other relief that the Hon’ble Commission may deem fit.<br />
15
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
1 INTRODUCTION<br />
16
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
1.1 Company Overview<br />
1.1.1 <strong>UJVN</strong> <strong>Limited</strong> is a wholly owned Corporation of the Government of Uttarakhand. The<br />
main objects to be pursued by the company are as under:<br />
To establish takeover, operate and maintain power generating stations<br />
harnessing the conventional, non-conventional, nuclear and other sources of<br />
energy by what so ever name called that include sub-stations, transmission lines,<br />
other ancillaries and activities that are essential <strong>for</strong> generation, transmission,<br />
distribution and trading of power.<br />
To carry on its activities within the State of Uttarakhand or elsewhere as may be<br />
found feasible.<br />
To make arrangements with any Company, Authority, Government or other<br />
persons or institutions <strong>for</strong> the operation and maintenance of any generating<br />
station owned by it (including transmission lines and other works connected<br />
therewith) on such terms and conditions as may be agreed upon between it and<br />
the Company.<br />
To take such measures as in the opinion of the Company, are calculated to<br />
advance the development of water power in the State of Uttarakhand and may<br />
carry out power and Hydro –metric survey work and cause to be made such<br />
maps, plans, sections and estimate as are necessary <strong>for</strong> any of the said purpose.<br />
To carry out investigation and to prepare one or more schemes relating to the<br />
establishment or acquisition of generating stations, tie-lines, sub-stations and<br />
transmission lines <strong>for</strong> promoting the use of electricity within the State of<br />
Uttarakhand.<br />
To operate and maintain in the most efficient and economical manner the<br />
generating stations, tie-lines, sub-stations and main transmission lines, owned by<br />
the Company.<br />
To enter into agreement with any licensee licensed under the Indian Electricity<br />
Act, 1910 or any other Act, Law of Regulation in <strong>for</strong>ce <strong>for</strong> the time being, or as<br />
17
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
modified from time to time or with any person <strong>for</strong> use of any transmission line,<br />
distribution line or main transmission line of that licensee or person <strong>for</strong> such time<br />
and upon such terms as may be agreed.<br />
To enter into arrangement on such terms as may be agreed upon, <strong>for</strong> the sale of<br />
electricity generated by it to the State Electricity Company constituted <strong>for</strong><br />
Uttarakhand or <strong>for</strong> the sale of electricity generated by it to any other state, body,<br />
person by itself with the consent of such person or persons duly authorized or<br />
licensed under prevalent Laws and Regulations or on its own account.<br />
To avail such rights, exercise such powers and functions and to per<strong>for</strong>m such<br />
duties as are conferred upon or expected of the company under the provisions of<br />
such Laws, legislation and regulations as are in <strong>for</strong>ce from time to time.<br />
To do such other acts and things as are authorized to be done under the<br />
Electricity (Supply) Act, 1948, or any other Act, Laws or regulations in <strong>for</strong>ce or<br />
amended from time to time.<br />
To do such other acts and things as are authorized to be done under Indian<br />
Electricity Act, 1910, as amended from time to time.<br />
1.1.2 The erstwhile Uttar Pradesh State Electricity Board was trifurcated pursuant to<br />
enactment of U.P. Electricity Re<strong>for</strong>ms Act, 1999. U.P. State Electricity Re<strong>for</strong>ms<br />
Transfer Scheme, 2000 was promulgated <strong>for</strong> execution of the trifurcation of<br />
erstwhile UPSEB into U.P. Power Corporation Ltd. (In short UPPCL), U.P. Jal Vidyut<br />
Nigam Ltd. (In short UPJVNL) and U.P. Rajya Vidyut Utpadan Nigam <strong>Limited</strong><br />
(UPRVUNL). By operation of the a<strong>for</strong>esaid Scheme all the Hydro Electric Projects<br />
earlier owned and operated by UPSEB were transferred to UPJVNL (a Govt. Company<br />
existing prior to the said trifurcation) in addition to other projects owned and<br />
operated by the UPJVNL previously.<br />
1.1.3 Uttar Pradesh was bifurcated by en<strong>for</strong>cement of U.P. Reorganization Act, 2000 as a<br />
result thereof the State of Uttarakhand came into existence. The Government of<br />
18
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
India issued an order dated 05-11-01 u/s 63(4)(a) of the Reorganization Act whereby<br />
assets and liabilities between UPJVNL and <strong>UJVN</strong> <strong>Limited</strong> were divided. By operation<br />
of this order all the Hydro Power Assets of UPJVNL located in the State of<br />
Uttarakhand were transferred to <strong>UJVN</strong> <strong>Limited</strong>. In compliance to the said order,<br />
administrative and financial control of all hydro power plants of UPJVNL in operation<br />
or under construction was taken over by <strong>UJVN</strong> <strong>Limited</strong> with effect from November<br />
09, 2001.<br />
1.1.4 The brief history of <strong>for</strong>mation of <strong>UJVN</strong> <strong>Limited</strong> is presented in Table 1.<br />
Table 1: Brief History of Formation of <strong>UJVN</strong> <strong>Limited</strong><br />
Milestone<br />
Date<br />
UPSEB Unbundled under UPSEB Transfer Scheme 14-01-2000<br />
Uttarakhand State Created under UP Reorganisation Act 09-11-2000<br />
<strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong>med under Companies Act, 1956 12-02-2001<br />
<strong>UJVN</strong> <strong>Limited</strong> Commenced Operations 09-11-2001<br />
<strong>UJVN</strong> <strong>Limited</strong> Took Possession of Assets 09-11-2001<br />
1.1.5 Presently, <strong>UJVN</strong> <strong>Limited</strong> operates Hydro Power Stations ranging in capacity from 0.2<br />
MW to 304 MW, totaling around 1310.25 MW. Though the State was more or less<br />
sufficient in energy generation to meet its own requirements at the time of its<br />
<strong>for</strong>mation, it is falling short of power at present. As such efficient operation of<br />
exiting hydro power projects <strong>for</strong> economic well-being and growth of the State and its<br />
people has become relevant and essential.<br />
1.2 Vision and Mission<br />
1.2.1 The vision of <strong>UJVN</strong> <strong>Limited</strong> is to be a significant player in the National Power Sector<br />
and best corporate in Uttarakhand. It aims to be an excellent & efficient organization<br />
19
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
on the strength of its human resources and induce adjacent infrastructure business<br />
that provides opportunities <strong>for</strong> growth.<br />
1.2.2 The Mission of the Nigam is to contribute to improvement in the quality of life in<br />
Uttarakhand. To achieve this, <strong>UJVN</strong> <strong>Limited</strong> has adopted a value based approach and<br />
its values include:<br />
Creation of value <strong>for</strong> all stakeholder<br />
Result oriented with professional work culture<br />
Earn trust through fair business practices with all<br />
Growth balanced with environmental protection & enrichment<br />
Law abiding<br />
1.3 Existing Installed Capacity<br />
1.3.1 Currently, <strong>UJVN</strong> <strong>Limited</strong> has an installed capacity of 1310.25 MW with installed<br />
capacity of Power Stations ranging from 0.2 MW to 304 MW. The salient features of<br />
these existing Power Stations are summarized in Table 2.<br />
Table 2: Salient Features of the Existing Power Stations<br />
S.<br />
N<br />
Power<br />
Station<br />
Installed<br />
Capacity<br />
(MW)<br />
Year of<br />
Commiss<br />
ioning<br />
Type<br />
of<br />
Scheme<br />
River<br />
Design<br />
Head<br />
(m)<br />
Design<br />
Discharge<br />
(m3/s)<br />
1 MB-II 304.00 2008 ROR Bhagirathi 247.60 142.00<br />
2 Khodri 120.00 1984 ROR Tons 57.90 200.00<br />
3 Tiloth 90.00 1984 ROR Bhagirathi 147.50 71.40<br />
4 Chilla 144.00 1980 ROR Ganga 32.50 565.00<br />
5 Chibro 240.00 1975 ROR Tons 110 200.00<br />
6 Kulhal 30.00 1975 ROR Yamuna 18.00 198.00<br />
7 Ramganga 198.00 1975 Reservoir Ramganga 84.40 235.60<br />
20
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
S.<br />
N<br />
Power<br />
Station<br />
Installed<br />
Capacity<br />
(MW)<br />
Year of<br />
Commiss<br />
ioning<br />
Type<br />
of<br />
Scheme<br />
River<br />
Design<br />
Head<br />
(m)<br />
Design<br />
Discharge<br />
(m3/s)<br />
8 Dhakrani 33.75 1965 ROR Yamuna 19.80 199.20<br />
9 Dhalipur 51.00 1965 ROR Yamuna 30.48 199.20<br />
10 Khatima 41.40 1956 ROR Sharda 17.98 269.00<br />
11 Pathri 20.40 1955 ROR Ganga 9.75 253.00<br />
12 M. Pur 9.30 1952 ROR Ganga 5.70 255.00<br />
13 Galogi 3.00 1907 ROR Bhatta 285.00 1.36<br />
14 Urgam 3.00 1998 ROR Kalpganga 196.00 1.86<br />
15 Tharali 0.40 1989 ROR Pranmati 79.77 0.67<br />
16 Badrinath–II 1.25 2004 ROR Rishiganga 75.45 2.07<br />
17 Pandukesh<br />
war<br />
0.75 2004 ROR Laxman<br />
ganga<br />
113.00 0.94<br />
18 Jumma 1.20 2005 ROR Jumma<br />
gad<br />
19 Tapovan 0.80 2005 ROR Dak<br />
Gadera<br />
143.50 1.07<br />
274.00 0.41<br />
20 Sonprayag 0.50 2002 ROR Sone 46.70 1.36<br />
21 Sapteshwar 0.30 1994 ROR Koiralgad 82.30 0.48<br />
22 Kanchauti 2.00 1993 ROR Kanchauti<br />
gad<br />
400.00 0.62<br />
23 Chhirkila 1.50 1997 ROR Dukugad 275.00 0.68<br />
24 Relagad 3.00 2004 ROR Relagad 264.83 1.42<br />
25 Kulagad 1.20 1995 ROR Kulagad 200.00 0.79<br />
26 Pilangad 2.25 2004 ROR Pilangad 102.00 2.75<br />
27 Harsil 0.20 2000 ROR Bhagirathi 114.00 0.26<br />
28 Kaliganga 4.00 2012 ROR Kaliganga 166.00 3.00<br />
29 Suringad 0.80 1986 ROR Sureingad 151.00 0.76<br />
21
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
S.<br />
N<br />
Power<br />
Station<br />
Installed<br />
Capacity<br />
(MW)<br />
Year of<br />
Commiss<br />
ioning<br />
Type<br />
of<br />
Scheme<br />
River<br />
Design<br />
Head<br />
(m)<br />
Design<br />
Discharge<br />
(m3/s)<br />
30 Taleshwar 0.60 2000 ROR Kaliganga 189.00 0.59<br />
31 Barar 0.75 1997 ROR Ramganga 99.48 0.96<br />
32 Chharandeo 0.40 2000 ROR Kaliganga 229.74 0.19<br />
33 Garaon 0.30 2001 ROR Ramganga 119.50 0.24<br />
34 Kotabagh 0.20 1990 ROR Dabaka 29.33 0.94<br />
Total 1310.25<br />
1.3.2 Most of the Power Stations were commissioned by the early 1980’s and the oldest<br />
Galogi Power Station was commissioned way back in 1907. The latest hydro station<br />
to be commissioned is Kaliganga-I SHP with an installed capacity of 4 MW in the year<br />
2012. Thus, it can be said that about more than 3 quarters of the capacity has been<br />
in operation <strong>for</strong> nearly 30 to 60 years and is, almost at the end of the life.<br />
1.3.3 All the <strong>UJVN</strong> <strong>Limited</strong> Power Stations except Ramganga are run of the river stations<br />
and thus are highly dependent on water availability and monsoon <strong>for</strong> electricity<br />
generation. Table 3 summarizes generation of hydro projects in the last 5 years.<br />
Table 3: Generation of Hydro Projects in <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> last 5 years<br />
Year Unit 2007-08 2008-09 2009-10 2010-11 2011-12<br />
Chibro Gen. (MU) 755.08 837.68 587.89 795.69 848.97<br />
Khodri Gen. (MU) 354.66 379.98 275.89 361.77 382.87<br />
Dhakrani Gen. (MU) 148.93 146.53 105.09 143.02 152.76<br />
Dhalipur Gen. (MU) 210.70 224.44 160.15 210.84 229.58<br />
Kulhal Gen. (MU) 149.76 143.68 112.62 142.53 157.83<br />
22
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Year Unit 2007-08 2008-09 2009-10 2010-11 2011-12<br />
Tiloth Gen. (MU) 466.14 403.80 449.08 504.41 516.11<br />
MB-II Gen. (MU) 77.02 1044.95 1198.04 1335.96 1351.15<br />
Chilla Gen. (MU) 825.97 776.59 739.49 775.15 910.09<br />
Ramganga Gen. (MU) 279.06 325.48 174.29 325.62 416.42<br />
Khatima Gen. (MU) 155.43 140.65 151.01 155.94 164.00<br />
LHPs Gen. (MU) 3422.75 4423.78 3953.55 4750.93 5129.78<br />
SHPS Gen. (MU) 180.43 189.45 173.00 155.34 132.03<br />
Total Gen. (MU) 3603.18 4613.23 4126.54 4906.26 5261.82<br />
1.3.4 Three Power Stations, namely, MB-II, Chilla and Chibro account <strong>for</strong> nearly 60% of the<br />
generation but Chilla & Chibro are now more than 30 years old. The generation of<br />
<strong>UJVN</strong> <strong>Limited</strong> increased by 28% between FY 2007-08 and FY 2008-09 on account of<br />
commissioning of MB-II, in FY 2007-08. There was a dip in generation between FY<br />
2008-09 and FY 2009-10 due to low hydrology.<br />
1.4 Upcoming Generation Capacity:<br />
1.4.1 <strong>UJVN</strong> <strong>Limited</strong> plans to expand its current capacity base and has about 3276 MW of<br />
Generating <strong>Plan</strong>ts in different stages of planning and implementation. The details of<br />
the projects planned and currently being implemented by <strong>UJVN</strong> <strong>Limited</strong> in the<br />
coming years are presented in the Table 4 below.<br />
23
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 4: <strong>Plan</strong>ned Capacity Addition by <strong>UJVN</strong> <strong>Limited</strong><br />
S.No.<br />
Name of<br />
Estimated<br />
District<br />
River/<br />
Expected<br />
Project<br />
Potential<br />
Tributary<br />
Commissioning<br />
(MW)<br />
Year<br />
1 Vyasi 120 <strong>Dehradun</strong> Yamuna 2016<br />
2 Lakhwar 300 <strong>Dehradun</strong> Yamuna 2018<br />
3 Bowla<br />
Nandprayag<br />
300 Chamoli Alaknanda 2019<br />
4 Tamak lata 250 Chamoli Dhauliganga 2019<br />
5 Nand Pyayag<br />
Langasu<br />
6 Sirkari Bhyol<br />
Rupsiabagar<br />
100 Chamoli Alaknanda 2020<br />
210 Pithoragarh Goriganga 2021<br />
7 Sela Urthing 230 Pithoragarh Dhauliganga 2023<br />
8 Kishau 660 <strong>Dehradun</strong> Tons 2024<br />
9 Pala Maneri 480 Uttarkashi Bhagirathi On hold<br />
10 Bhairon Ghati 381 Uttarkashi Bhagirathi On hold<br />
11 Taluka Sankri 140 Uttarkashi Tons 2026*<br />
12 Rishiganga I 70 Chamoli Rishiganga 2026*<br />
13 Rishiganga – II 35 Chamoli Rishiganga 2026*<br />
Total 3276<br />
*Subject to clearance of Wildlife Board and MoEF.<br />
1.4.2 It will be important to consider some of these Projects in this business plan as some<br />
capital expenditure related to these projects shall also be done during the current<br />
24
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
control period. Two hydro projects namely Pala Maneri and Bhairon Ghati on the<br />
Bhagirathi River are currently on hold due to environmental issues. Taluka Sankri,<br />
Rishiganga – I , Rishigana – II and Sela Urthing are still under planning phase and<br />
hence no capital expenditure will be incurred during the control period. Sela Urthing<br />
is expected to be commissioned in 2023 and no capital expenditure is expected to be<br />
incurred during the control period.<br />
In addition to these Large Hydroelectric Projects, quite a number of Small<br />
Hydroelectric Projects are in operation as well as in various stages of implementation<br />
requiring substantial capital investments during the Control Period 2013-14 to<br />
2015-16. These have been appended as Annexure-15.<br />
Ef<strong>for</strong>t towards Diversification of Generation Base<br />
1.4.3 Electricity demand in the state has grown exponentially due to rapid industrialization<br />
as a result of industry friendly policies and special package granted to the State by<br />
the Union Government. The demand <strong>for</strong> electricity has been growing at the rate of<br />
about 14% per annum during the last 8 years and the demand-supply gap is<br />
increasing. At present power generation in the state is wholly dependent on<br />
Hydro projects and allocation of power from central pool is not sufficient to meet<br />
the requirement of the State. The power deficit becomes acute during winter season<br />
as freezing temperatures causes low river discharges leading to lower generation<br />
whereas demand goes up significantly.<br />
Bottlenecks in development of Hydro projects<br />
1.4.4 The state could not harness the full potential of Hydro power due to various reasons,<br />
notably among them are the inordinate delay in various clearances <strong>for</strong> the upcoming<br />
hydro projects, suspension / closure of 480 MW Pala Maneri & 381 MW<br />
Bhairoghati projects of State PSU (<strong>UJVN</strong> <strong>Limited</strong>), 600 MW Lohari Nag Pala project of<br />
25
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
NTPC Ltd. by Govt. of India and cancellation of already issued environment clearance<br />
to some Hydroelectric projects. Because of these factors the development of hydro<br />
power projects in the state is not taking place at desired pace. It is pertinent to<br />
mention that due to various environmental, social and religious issues, the<br />
development of hydro power in Uttarakhand state has been greatly hampered.<br />
Several religious agitations against developments of hydro power projects have<br />
resulted in the closure of three a<strong>for</strong>esaid hydro projects in the state and there is a<br />
strong demand <strong>for</strong> closure of other up-coming projects.<br />
Alternate Resources: Development of Gas based thermal power plant<br />
1.4.5 For the reasons listed in the previous section, the State Government is exploring<br />
alternatives to hydro power. In this regard Gas Based Power Projects have been<br />
initiated by the State Government (<strong>UJVN</strong> Ltd, A Govt. Uttarakhand Undertaking) in<br />
joint venture with GAIL (India) Ltd. at Haridwar & Kashipur in Uttarakhand, but<br />
Government of India has in<strong>for</strong>med that they do not have adequate Gas supply and<br />
have expressed its inability to allocate gas to the state <strong>for</strong> generation in near future.<br />
Development of Coal based Power <strong>Plan</strong>t and allocation of Coal Block<br />
1.4.6 Uttarakhand state does not have any coal reserve and no coal block has been<br />
allocated to the state since its <strong>for</strong>mation. Govt. of India has notified a new coal policy<br />
“The Auction by Competitive Bidding of Coal Mines Rules, 2012” on 02-02-2012. As<br />
per the in<strong>for</strong>mation available on different websites, 54 Coal Blocks with total<br />
geological reserves of about 18.22 Billion Tonnes have been identified <strong>for</strong> allocation.<br />
Out of which 16 Blocks with 7.27 BT have been reserved <strong>for</strong> Government owned<br />
companies, 16 Coal Blocks with 8.16 BT <strong>for</strong> power sector companies selected<br />
through tariff based bidding and 22 Blocks with 7.29 BT <strong>for</strong> companies selected<br />
through auction have been earmarked <strong>for</strong> allocation. Allocation of above coal blocks<br />
will start soon.<br />
26
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
1.4.7 In this reference a meeting was held on 11 th May 2012 under the Chairmanship of<br />
Secretary (Coal), GoI to finalize the terms and conditions <strong>for</strong> allocation of Coal Blocks<br />
to Government owned companies through auction by competitive bidding.<br />
Secretary (Coal), GoI has in<strong>for</strong>med that coal blocks <strong>for</strong> Power Sector will be allotted<br />
only through competitive bidding.<br />
Steps Taken For Allocation of Coal Block<br />
1.4.8 Growing demand – supply gap of power is of utmost concern <strong>for</strong> the Government of<br />
Uttarakhand. To bridge the gap, a 2000 MW Coal Based Power Project is required.<br />
1.4.9 In this context a request <strong>for</strong> allocation of coal block <strong>for</strong> 2000 MW Coal Based Power<br />
Project has been made by the Chief Minister of Uttarakhand vide his office letter No.<br />
763/I(2)/2010-05/33/2007, dated 21.04.2010 to the Government of India.<br />
1.4.10 In continuation to above Chief Secretary of Uttarakhand vide letter no.<br />
760/I2/09/2012 dated 10 th May, 2012 has further requested Secretary Coal, GoI <strong>for</strong><br />
allocation of Coal Block <strong>for</strong> setting-up a 2000 MW thermal power plant at pit head<br />
on priority basis.<br />
1.4.11 For development of Coal based Power <strong>Plan</strong>t with Uttar Pradesh (UPPCL), Managing<br />
Director, <strong>UJVN</strong> Ltd. requested vide letter no. 1728/<strong><strong>UJVN</strong>L</strong>/MD/Coal dated<br />
26.04.2012 Chairman and Managing director, UPPCL <strong>for</strong> development of Thermal<br />
Power <strong>Plan</strong>t under joint venture route. In this regard Nigam Official met and<br />
appraised the matter to CMD, UPPCL.. CMD, UPPCL has in<strong>for</strong>med that there is no<br />
coal block left <strong>for</strong> link/tie-up <strong>for</strong> development of Coal based Thermal power plant.<br />
1.4.12 In the Month of February 2012, Managing Director <strong>UJVN</strong> Ltd. discussed the power<br />
scenario of Uttarakhand with Chairman, Jharkhand Electricity Board (JSEB) and<br />
27
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
requested <strong>for</strong> development of a Coal based power plant at pit in Jharkhand.<br />
Chairman, JSEB vide letter no. 60/Ch. Dated 21-03-2012 invited <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong><br />
setting up a coal based thermal power plant in Jharkhand and hydro power project in<br />
the territory of Uttarakhand through joint venture route <strong>for</strong> the mutual benefit of<br />
both states.<br />
1.4.13 JSEB and <strong><strong>UJVN</strong>L</strong> have decided to <strong>for</strong>m a joint working group to go into details of the<br />
modality <strong>for</strong> <strong>for</strong>mation of SPV/ Joint Venture as well as to develop a concept report<br />
on the proposed thermal and hydro power plant. The report of the working group<br />
shall be reviewed by JSEB/<strong><strong>UJVN</strong>L</strong> and shall be put up to their respective Boards/<br />
Government of the states <strong>for</strong> their approval.<br />
1.4.14 <strong>UJVN</strong> Ltd. is also exploring other options <strong>for</strong> allocation of new Coal Blocks as per GoI<br />
Coal Block allotment policy. It is seeking consultancy services <strong>for</strong> “Identification,<br />
Application <strong>for</strong> Allocation and Bidding on behalf of <strong>UJVN</strong> Ltd. <strong>for</strong> coal block as per the<br />
final Terms & Conditions of the Ministry of Coal <strong>for</strong> allotment of Coal Blocks to Govt.<br />
Companies under Auction by Competitive Bidding of Coal Mines Rules 2012 <strong>for</strong> a<br />
2000 MW Pit head coal based power project”. Various options (including case 2 PPP<br />
option) to establish the thermal plant will be explored and evaluated by <strong>UJVN</strong><br />
<strong>Limited</strong> once the coal block is allocated to the state.<br />
Initiative <strong>for</strong> increasing the Power availability <strong>for</strong> state of Uttarakhand<br />
1.4.15 The Government of Uttaranchal has taken initiative to increase the base load power<br />
availability within the state. Consequent to persuasion by GoU the MoP, GoI has<br />
allocated a share of 200 MW in the Ultra Mega Power Project (UMPP) to be<br />
established in the state of Orissa. In this regard <strong><strong>UJVN</strong>L</strong> has paid Rs. 35. 93 Crores to<br />
PFC towards its share of cost of land to be procured <strong>for</strong> the thermal plant. Once the<br />
UMPPP is awarded to the successful bidder this cost will be reimbursed by the<br />
selected bidder.<br />
28
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Alternate Resources: Development of Solar Power <strong>Plan</strong>ts<br />
1.4.16 The Renewable purchase obligation (RPO <strong>for</strong> solar) <strong>for</strong> Uttarakhand as stated in<br />
Uttarakhand Electricity Regulatory Commission (Renewable Purchase Obligation, its<br />
compliance & implementation of REC framework), Regulations 2010 is 0.025% <strong>for</strong><br />
FY2010-11, FY2011-12 & FY2012-13 while <strong>for</strong> the control period i.e. FY2013-14,<br />
FY2014-15 & FY2015-16 the RPO would be 0.050%. For the compliance of this<br />
requirement <strong>UJVN</strong> limited has taken several initiatives.<br />
1.4.17 Order <strong>for</strong> installation of 100 kWp Solar Photo Voltaic (SPV) Power <strong>Plan</strong>t at Ujjwal,<br />
<strong>Dehradun</strong> has been placed with M/s Central Electronics <strong>Limited</strong>, a Public Sector<br />
Enterprise under DSIR of Ministry of Science & Technology, Government of India, on<br />
23.12.2011. Total cost of installation of 100 kWp Solar Photo Voltaic (SPV) Power<br />
<strong>Plan</strong>t at Ujjwal is Rs. 2.73 Crores. For project development Central Financial<br />
Assistance (CFA) of Rs. 2.43 Crores has been sanctioned by MNRE and Rs. 1.20 Crores<br />
has been released by MNRE directly to M/s Central Electronics <strong>Limited</strong> on<br />
02.02.2012. Remaining expenditure will be borne by <strong>UJVN</strong> <strong>Limited</strong>. Solar Photo<br />
Voltaic (SPV) of 100 kWp capacity Power <strong>Plan</strong>t at “ Ujjwal”, <strong>Dehradun</strong> has been<br />
commissioned in the month of December, 2012.<br />
1.4.18 DPRs <strong>for</strong> installation of 50 kWp and 80 kWp Solar Photo Voltaic (SPV) Power <strong>Plan</strong>ts at<br />
Ganga Bhawan and Yamuna Bhawan have been submitted to MNRE <strong>for</strong> Central<br />
Finance Assistance (CFA) <strong>for</strong> funding these projects.<br />
1.4.19 <strong>UJVN</strong> Ltd. also propose to install Solar Photo Voltaic (SPV) Power <strong>Plan</strong>ts in the long<br />
run at various Hydro Electric Projects and their Power Channels. Initial studies have<br />
been made by <strong>UJVN</strong> Ltd. about the possibilities of installation of 0.2 MWp to 5.26<br />
MWp Solar PV Power <strong>Plan</strong>ts at existing Power Stations and capacities ranging from<br />
29
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
1.07 MWp to much higher capacities over canal banks (subject to Forest &<br />
Environment and UPID clearances) have been studied. Installation of Power <strong>Plan</strong>ts<br />
at some of these locations are proposed to be firmed up after seeing the efficacy of<br />
100 kWp Solar Photo Voltaic (SPV) Power <strong>Plan</strong>t commissioned at “Ujjwal" which has<br />
already been taken up is established.<br />
1.4.20 <strong>UJVN</strong> Ltd. as indicated in the above sections is looking at various sources of<br />
generation to augment its existing generation. In the above sections the endeavor of<br />
<strong>UJVN</strong> Ltd. has been to apprise the Commission the status of its initiatives in this<br />
regard. <strong>UJVN</strong> Ltd. shall file be<strong>for</strong>e the Commission the initiatives planned by it as<br />
soon as they take some concrete shape. At that stage <strong><strong>UJVN</strong>L</strong> shall file be<strong>for</strong>e the<br />
Commission technical, financial and commercial details of the project <strong>for</strong> its<br />
approval.<br />
1.4.21 Note on Manpower <strong>Plan</strong>ning of <strong>UJVN</strong> Ltd. during the Control Period is enclosed as<br />
Annexure-16.<br />
30
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2 CAPITAL EXPENDITURE PLAN –<br />
UPCOMING PROJECTS<br />
31
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.1 Vyasi Hydroelectric Project (120 MW)<br />
2.1.1 Background:<br />
2.1.1.1 Vyasi HE Project of 120 MW is located downstream of Lakhwar dam scheme in the<br />
district of <strong>Dehradun</strong> in Uttarakhand. The project is planned to be constructed on<br />
the river Yamuna. The work site is connected with rest of the country through<br />
railways, airport at <strong>Dehradun</strong> and road network.<br />
2.1.1.2 Initially this project was started in 1979 by the State Govt. of Uttar Pradesh. Partial<br />
work on various components of the project such as abutment stripping of Vyasi<br />
dam, excavation of surface powerhouse at Hathiari, HRT and surge shaft had been<br />
carried out. The major civil works on this project was started in 1987 and which<br />
progressed till 1992 but thereafter, all works on this project have been stopped.<br />
2.1.1.3 Later on erstwhile UPSEB prepared a DPR revising the project cost at March 96<br />
price level and submitted to CWC/CEA <strong>for</strong> approval. MOU was signed between<br />
Uttarakhand Government authorities and NHPC on 1 st November 2003 <strong>for</strong><br />
execution of the remaining work. Later on GoU entrusted the implementation of<br />
Lakhwar & Vyasi HE project (420 MW) to <strong>UJVN</strong> <strong>Limited</strong> vide letter No. 1596/ l(2)/<br />
2008-04(8)/ 77/ 2003 dated 23.06.08. <strong>UJVN</strong> <strong>Limited</strong> initiated the process of taking<br />
over the project but NHPC requested GOI and GoU <strong>for</strong> reconsideration of the<br />
decision to take over the project . GoU again vide Letter No. 3326/ I(2)/ 2004-04(8)-<br />
17/ 2008 dated 30.12.08 in<strong>for</strong>med Secretary (Power), GoI of its decision that <strong>UJVN</strong><br />
<strong>Limited</strong> will complete the remaining work of the project and the request of NHPC<br />
<strong>for</strong> reconsideration of this decision may not be considered. The GoU decided to<br />
start construction work at the project immediately.<br />
2.1.2 Capital Expenditure:<br />
32
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.1.2.1 The estimated cost of the project at February 2010 price level is Rs. 936.23 Crores<br />
including IDC of 72.51 Crores and Rs. 6.55 Crores of Financing Charges. The project<br />
is estimated to get completed by December 2016. Capital expenditure of Rs. 500<br />
Crores is projected to be incurred during the control period. The year wise phasing<br />
of the capital expenditure during the control period is shown in the table below:<br />
Table 5: Capital Expenditure during Control Period – Vyasi Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure 104.00 100.00 200.00 200.00 332.23 936.23<br />
2.1.2.2 Details of the project cost are provided in the table on next page :<br />
33
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 6: Capital Cost – Vyasi Project<br />
VYASI H. E. PROJECT (120 MW), UTTARAKHAND<br />
ABSTRACT OF COST (February 2010)<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
A CIVIL WORKS<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 28.36<br />
B - Land 32.52<br />
C - Works 317.79<br />
J - Power <strong>Plan</strong>t Civil Works 172.57<br />
K - Buildings 19.66<br />
M - <strong>Plan</strong>tation 1.00<br />
O - Miscellaneous 16.61<br />
P - Maintenance During Construction 5.44<br />
Q - Special Tools and <strong>Plan</strong>ts 1.27<br />
R - Communication 34.06<br />
X - Environment and Ecology 23.34<br />
Y - Losses on Stock 1.36<br />
TOTAL OF I - WORKS 653.97<br />
II - Establishment 49.72<br />
III - Tools and <strong>Plan</strong>ts 1.00<br />
IV - Suspense -<br />
V- Receipt & Recoveries -0.94<br />
TOTAL DIRECT CHARGES 703.74<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue 0.36<br />
II - Audit & Accounts Charges 3.27<br />
TOTAL INDIRECT CHARGES 3.63<br />
TOTAL CIVIL WORKS 707.38<br />
B ELECTRICAL WORKS 149.79<br />
TOTAL COST (CIVIL + ELECTRICAL) 857.17<br />
INTEREST DURING CONSTRUCTION 72.51<br />
FINANCING CHARGES 6.55<br />
TOTAL COST INCLUDING IDC & FINANCING CHARGES 936.23<br />
Total 936.23<br />
34
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.1.2.3 Economic Analysis<br />
The energy generation from the project with an installed capacity of 120 MW in<br />
stand-alone operation mode is estimated at 375.24 MU in a 90% dependable year<br />
with 95% machine availability and considering aquatic release of 2 cumec<br />
continuously.<br />
Interest rate of 12%, financing charges of 1% of loan amount, RoE of 14%,<br />
depreciation is considered same as repayment schedule and O&M charges of<br />
1.5% of capital cost is assumed. Based on the above assumptions, Levellised tariff<br />
in this mode from the project works out as Rs. 4.19 per unit (with 10.74%<br />
discounting factor).<br />
The detailed working of the economic analysis is provided in Detailed Project<br />
Report.<br />
2.1.2.4 Status Update of Capital Expenditure:<br />
Environment clearance received <strong>for</strong> Vyasi Power Station has been transferred<br />
in favour of <strong>UJVN</strong> <strong>Limited</strong> by MOEF on 22.04.2010 after NHPC conveyed its<br />
NOC <strong>for</strong> the same.<br />
The case <strong>for</strong> transfer of Forest land in favour of <strong>UJVN</strong> <strong>Limited</strong> from Irrigation<br />
Department has since been processed and recommended at State level on<br />
05.06.2012 <strong>for</strong> sending the proposal to MoEF, GOI <strong>for</strong> according final<br />
approval. The case has been submitted in MoEF on 14.06.2012. The proposal<br />
was discussed in the meeting of Forest Advisory Committee held on<br />
17.08.2012. FAC has recommended the transfer of land in favour of <strong>UJVN</strong><br />
<strong>Limited</strong> from Irrigation Department with certain conditions.<br />
The case <strong>for</strong> preparing Forest Proposal <strong>for</strong> diversion of additional Forest land<br />
in River bed area and area above underground works has been started.<br />
35
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Earlier an R&R package was decided by GoU <strong>for</strong> Lakhwar Vyasi Project and<br />
provided to NHPC in August, 2004. Later in May, 2008 an R&R proposal <strong>for</strong><br />
projects of <strong>UJVN</strong> <strong>Limited</strong> was submitted to GoU <strong>for</strong> approval. Based on the<br />
above R&R package <strong>for</strong> Vyasi Project is to be finalised by the GoU.<br />
The supplementary agreement was <strong>for</strong>mally executed between UJVL <strong>Limited</strong><br />
and M/s NPCC <strong>Limited</strong> on 06.03.2012.<br />
The prequalification of contractors <strong>for</strong> Dam & associated structures has been<br />
done. Process of review/ vetting of tender document with the help of<br />
consultancy firm <strong>for</strong> execution of balance dam work, which was prepared in<br />
house has been undertaken.<br />
Work <strong>for</strong> Consultancy service <strong>for</strong> Design Engineering of Vyasi Project has been<br />
awarded.<br />
2.1.3 Financing of Capital Expenditure:<br />
2.1.3.1 The project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 500 Crores planned <strong>for</strong> the control period, debt component will be Rs. 350<br />
Crores and equity contribution will be Rs. 150 Crores. Equity will be provided by<br />
GoU from budgetary support envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt is yet to be<br />
tied-up with financial institutions through a tender has been floated <strong>for</strong> debt tie-up.<br />
Year-wise allocation of debt and equity <strong>for</strong> the control period is provided in the<br />
table below:<br />
Year<br />
Table 7: Funding Pattern during the Control Period – Vyasi Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Debt 72.80 70.00 140.00 140.00 232.56 655.36<br />
Equity 31.20 30.00 60.00 60.00 99.67 280.87<br />
Debt 70% 70% 70% 70% 70% 70%<br />
Equity 30% 30% 30% 30% 30% 30%<br />
36
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.1.4 Capitalization Schedule:<br />
2.1.4.1 As per the Commissioning schedule, Vyasi project will get commissioned in<br />
December, 2016. The entire capital expenditure of Rs. 936.23 Crores will get<br />
capitalized in FY 2016-17. Year-wise capitalization during the control period is<br />
provided in the table below:<br />
Table 8: Capex & Capitalization during the Control Period – Vyasi Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure 104.00 100.00 200.00 200.00 332.23 936.23<br />
Capitalization - - - - 936.23 936.23<br />
37
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.2 Lakhwar Multipurpose Project (300 MW)<br />
2.2.1 Background<br />
2.2.1.1 Lakhwar Project of 300 MW is located in the district of <strong>Dehradun</strong>. The project is<br />
planned to be constructed on the river Yamuna in Uttarakhand state. The work site<br />
is connected through railway and airport from <strong>Dehradun</strong>. Initially this project was<br />
started in 1979 by the State Govt. of Uttar Pradesh.<br />
2.2.1.2 The construction of main works of the project was started through three major<br />
contractors in July 1987. However the progress of construction of the project works<br />
suffered due to paucity of funds and by the end of 1992, the construction works<br />
were stopped. Be<strong>for</strong>e stoppage of the project works, part works on various<br />
components of the project such as abutment stripping of Lakhwar dam,<br />
construction of diversion tunnel, part construction of underground powerhouse<br />
had been carried out.<br />
2.2.1.3 After the project was handed over to GoU a revised DPR at March 96 price level<br />
was prepared and submitted to CWC / CEA <strong>for</strong> approval and the project was<br />
handed over to NHPC <strong>for</strong> early completion. However, due to acute shortage of<br />
power in Uttarakhand State, the State Govt. decided to get the project executed by<br />
<strong>UJVN</strong> <strong>Limited</strong> and the project was taken back from NHPC. The DPR has been again<br />
updated at Feb 2010 price level. CEA vide its letter dated 3 rd September 2012 has<br />
estimated IDC and FC <strong>for</strong> the revised cost of power component of the project.<br />
2.2.2 Capital Expenditure:<br />
2.2.2.1 The approved cost of the project at May 2012 price level is Rs. 3966.51 Crores<br />
without considering IDC & Financing Charges. The indicated cost includes Irrigation<br />
component of Rs. 2578.23 Crores and Power component of Rs. 1388.28 Crores.<br />
CEA vide its letter dated 3 rd September 2012 has communicated IDC of Rs. 190.82<br />
Crores and FC of Rs. 11.13 Crores <strong>for</strong> the hard cost of power component of the<br />
38
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
project. Since the project has been declared as National Project by GOI, 90% of the<br />
cost of Irrigation and Water component will be given as Grant Assistance by GOI<br />
and 10% by the beneficiary states. The project is estimated to get completed by<br />
December, 2018. Capital expenditure of Rs. 530 Crores is projected to be incurred<br />
during the control period <strong>for</strong> the Power Component and Rs 830 Crores <strong>for</strong> the<br />
Water/ Irrigation Component. The year wise phasing of the capital expenditure<br />
during the control period is shown in the table below:<br />
Table 9: Capital Expenditure during the Control Period – Lakhwar Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital Expenditure<br />
(Power Component) 242.00 80.00 200.00 250.00 818.23 1,590.23<br />
Capital Expenditure<br />
(Water/ Irrigation<br />
Component)* - 100.00 325.00 405.00 1,748.23 2,578.23*<br />
* 90% cost of Water/ Irrigation component will be provided as grant assistance by GoI and<br />
10% cost of Water/ Irrigation component shall be borne by beneficiary states.<br />
2.2.2.2 Details of the project cost are provided in the table on the next page :<br />
39
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 10: Capital Cost – Lakhwar Project<br />
Lakhwar H. E. PROJECT (300 MW), UTTARAKHAND<br />
ABSTRACT OF COST (February 2010)<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
A CIVIL WORKS<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 44.28<br />
B - Land 142.92<br />
C - Works 2,423.90<br />
J - Power <strong>Plan</strong>t Civil Works 263.04<br />
K - Buildings 62.52<br />
M - <strong>Plan</strong>tation -<br />
O - Miscellaneous 73.71<br />
P - Maintenance During Construction 32.86<br />
Q - Special Tools and <strong>Plan</strong>ts 2.79<br />
R - Communication 104.31<br />
X - Environment and Ecology 35.77<br />
Y - Losses on Stock 8.21<br />
TOTAL OF I - WORKS 3,194.31<br />
II - Establishment 309.81<br />
III - Tools and <strong>Plan</strong>ts 35.85<br />
IV - Suspense -<br />
V- Receipt & Recoveries -1.15<br />
TOTAL DIRECT CHARGES 3,538.83<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue 0.86<br />
II - Audit & Accounts Charges 35.85<br />
TOTAL INDIRECT CHARGES 36.72<br />
TOTAL CIVIL WORKS 3,575.54<br />
B ELECTRICAL WORKS 390.96<br />
TOTAL COST (CIVIL + ELECTRICAL) 3,966.51<br />
INTEREST DURING CONSTRUCTION<br />
FINANCING CHARGES<br />
TOTAL COST EXCLUDING IDC & FINANCING CHARGES 3,966.51<br />
Total 3,966.51<br />
40
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.2.2.3 Economic Analysis<br />
The energy generation from the project with an installed capacity of 300 MW in<br />
stand-alone mode operation has been estimated at 612.93 MU in a 90%<br />
dependable year with 95% machine availability.<br />
The unit cost of energy at saleable Design Energy at Bus Bar, considering return of<br />
14% on the Equity invested in Lakhwar Project at May 2012 Price Level with 35%<br />
of total Cost of the project apportioned towards power component works out as<br />
follows:<br />
Total cost of project without IDC = Rs. 3966.51 Crores<br />
Total cost <strong>for</strong> power (35% apportioned) = Rs 1388.28 Crores (without IDC)<br />
= Rs. 1590.23 Crores (including IDC of Rs. 190.82 Crores and Rs. 11.13 Crores of<br />
FC)<br />
Cost towards drinking water and Irrigation component = Rs. 2578.23 Crores<br />
Considering Interest rate of 10% <strong>for</strong> Capex, working capital interest rate of<br />
10.25%, RoE of 14%, depreciation is considered same as repayment schedule and<br />
O&M charges of 1.5% of capital cost with an escalation of 4%, Levellised tariff <strong>for</strong><br />
the project works out as Rs. 3.40 (without IDC and FC charges). However the rate<br />
has been revised to 4.34 per unit <strong>for</strong> revised project cost with IDC and FC charges.<br />
This rate has been communicated by CEA through its letter dated 3 rd September<br />
2012.The letter of CEA is annexed as annexure 13.<br />
The detailed working of the economic analysis is provided in the Detailed<br />
Project Report.<br />
2.2.2.4 Status Update of Capital Expenditure:<br />
Revised DPR with revised cost estimate based on price level of February, 2010<br />
was submitted to CWC on 16 th July, 2010.<br />
41
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
A copy of revised DPR has been sent to member States of Upper Yamuna River<br />
Board (UYRB) in 2010 and again in 2012 <strong>for</strong> their views/comments regarding<br />
sharing of benefits. Rajasthan & Delhi have submitted their acceptance<br />
regarding sharing the benefits as per the MoU of 1994. Chairman, <strong>UJVN</strong><br />
<strong>Limited</strong> has requested Principal Secretary, Irrigation Department, Haryana and<br />
Chief Secretary, U.P. <strong>for</strong> expediting their replies regarding sharing of benefits<br />
in continuation to earlier requests of <strong>UJVN</strong> <strong>Limited</strong>.<br />
Replies to the comments of all the Directorates of CWC were submitted and<br />
clearances have been received.<br />
The Project has been cleared by the Technical Advisory Committee of CWC in<br />
its meeting held on 14.12.2012.<br />
The <strong>for</strong>est and environmental clearance was granted by Department of<br />
Environment Forest and Wild Life, GoI in October, 1986 and February, 1987<br />
respectively.<br />
MOEF has conveyed continuation of earlier Environmental Clearance <strong>for</strong><br />
Lakhwar project with additional conditions as specified by the EAC of MoEF.<br />
On their observations replies shall be submitted by <strong>UJVN</strong> <strong>Limited</strong> by February<br />
2013.<br />
Case of transfer of <strong>for</strong>est land in favour of <strong>UJVN</strong> <strong>Limited</strong> from Irrigation<br />
Department, Uttarakhand shall be submitted by February 2013.<br />
2.2.3 Financing of Capital Expenditure:<br />
2.2.3.1 Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs.<br />
530 Crores planned during the control period, debt will be Rs. 371 Crores and<br />
equity contribution will be Rs. 159 Crores. Equity will be provided by GoU from<br />
budgetary support envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt is yet to be tied-up with<br />
financial institutions. Year-wise allocation of debt and equity <strong>for</strong> the control<br />
period is provided in the table below:<br />
42
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Year<br />
Table 11: Funding Pattern during the Control Period – Lakhwar Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Debt - 56.00 140.00 175.00 789.41 1,160.41<br />
Equity 242.00 24.00 60.00 75.00 28.82 429.82<br />
Debt 0% 70% 70% 70% 96% 73%<br />
Equity 100% 30% 30% 30% 4% 27%<br />
2.2.4 Capitalization Schedule:<br />
2.2.4.1 As per Commissioning schedule, Lakhwar project will get commissioned in<br />
December 2018. The entire capital expenditure of Rs. 1590.23 Crores will get<br />
capitalized in FY 2018-19. Year-wise capitalization during the control period is<br />
provided in the table below:<br />
Table 12: Capex & Capitalization during the Control Period – Lakhwar Project<br />
Rs.Crores<br />
Year<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure 242.00 80.00 200.00 250.00 818.23 1,590.23<br />
Capitalization - - - - 1,590.23 1,590.23<br />
43
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.3 Kishau Multipurpose Project (660 MW)<br />
2.3.1 Background<br />
2.3.1.1 Kishau Dam Project would utilize the water of river Tons which is a major tributary<br />
of river Yamuna and <strong>for</strong>ms boundary between Himachal Pradesh and Uttarakhand<br />
in most of its reaches in this region. The water stored in the Kishau reservoir shall<br />
be utilized <strong>for</strong> irrigation, power generation and to augment drinking water supply<br />
<strong>for</strong> National Capital Delhi.<br />
2.3.1.2 The project with a proposed installation of 660 MW (4 x 165 MW) is envisaged to<br />
generate an annual energy of 1379 MU in a 90% dependable year with 95% of<br />
Installed Capacity.<br />
2.3.2 Capital Expenditure:<br />
2.3.2.1 The estimated cost of the project at June 2010 price level is Rs. 7193 Crores<br />
excluding IDC and Financing Charges and it comprises of Rs. 4509 Crores of Power<br />
component and Rs. 2684 Crores of Irrigation & Water component as per <strong>for</strong>mula<br />
adopted by CWC committee constituted by MoWR in December 2002 . As the<br />
project has been declared as a National Project by GOI, 90% cost of Irrigation and<br />
Water component will be given as Grant Assistance by GOI and 10% by the<br />
beneficiary states. The project is estimated to get completed in a period of 109<br />
months. Capital expenditure of Rs. 110 Crores is projected to be incurred during<br />
the control period <strong>for</strong> the Power Component and Rs 60 Crores <strong>for</strong> the Water/<br />
Irrigation Component.. The year wise phasing of the capital expenditure during the<br />
control period is shown in the table on the next page :<br />
44
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 13: Capital Expenditure during the Control Period – Kishau Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital Expenditure<br />
(Power Component) - - 10.00 100.00 4,399.00 4,509.00<br />
Capital Expenditure<br />
(Water / Irrigation<br />
Component) - - - 60.00 2,624.00 2,684.00<br />
* 90% cost of Water/ Irrigation component will be provided as grant assistance by GoI and<br />
10% cost of Water/ Irrigation component shall be borne by beneficiary states.<br />
2.3.2.2 Details of the same are provided in the table on the next page :<br />
45
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 14: Capital Cost – Kishau Project<br />
KISHAU MULTIPURPOSE H. E. PROJECT (660 MW), UTTARAKHAND<br />
ABSTRACT OF COST (June 2010)<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
A CIVIL WORKS<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 164.51<br />
B - Land 800.40<br />
C - Works 4,184.60<br />
J - Power <strong>Plan</strong>t Civil Works 175.56<br />
K - Buildings 150.11<br />
M - <strong>Plan</strong>tation 3.90<br />
O - Miscellaneous 40.00<br />
P - Maintenance During Construction 45.10<br />
Q - Special Tools and <strong>Plan</strong>ts 22.01<br />
R - Communication 71.71<br />
X - Environment and Ecology 379.62<br />
Y - Losses on Stock 11.28<br />
TOTAL OF I - WORKS 6,048.80<br />
II - Establishment 100.00<br />
III - Tools and <strong>Plan</strong>ts 60.49<br />
IV - Suspense -<br />
V- Receipt & Recoveries -8.07<br />
TOTAL DIRECT CHARGES 6,201.22<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue 15.37<br />
II - Audit & Accounts Charges 15.12<br />
TOTAL INDIRECT CHARGES 30.49<br />
TOTAL CIVIL WORKS 6,231.72<br />
B ELECTRICAL WORKS 961.52<br />
TOTAL COST (CIVIL + ELECTRICAL) 7,193.24<br />
TOTAL COST EXCLUDING IDC & FINANCING CHARGES 7,193.24<br />
46
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.3.2.3 Economic Analysis<br />
Finalization of the project cost is under process and currently project cost<br />
excluding IDC & financing charges is available. After IDC & financial charges have<br />
been finalized, economic evaluation will be carried out <strong>for</strong> the project.<br />
2.3.2.4 Status Update of Capital Expenditure:<br />
Revised DPR with cost estimate based on price level of June, 2010 was<br />
submitted by <strong>UJVN</strong> <strong>Limited</strong> to CWC on 15 th October, 2010.<br />
A copy of revised DPR has been sent to member States of UYRB in 2010 and<br />
again in 2012 <strong>for</strong> their views/comments regarding sharing of benefits.<br />
Rajasthan & Delhi have submitted their acceptance regarding sharing of the<br />
benefits as per the MoU of 1994. Chairman, <strong>UJVN</strong> <strong>Limited</strong> has requested<br />
Principal Secretary, Irrigation Department, Haryana and Chief Secretary, U.P.<br />
<strong>for</strong> expediting their replies regarding sharing of benefits in continuation to<br />
earlier requests of <strong>UJVN</strong> <strong>Limited</strong>.<br />
Comments from various Directorates of CWC/CEA are being replied by <strong>UJVN</strong><br />
<strong>Limited</strong>. Further, persuasion/ discussion/ replies shall be expedited on<br />
nomination of JV partner by GoHP.<br />
Proposal <strong>for</strong> issue of TOR <strong>for</strong> EIA/EMP studies of the project was submitted to<br />
MoEF on 25th February, 2011.<br />
The agency <strong>for</strong> EIA/EMP studies shall be finalized after nomination of JV<br />
partner by GoHP <strong>for</strong> which correspondences/ Discussion/ meetings have been<br />
undertaken with Principal Secretary (Power), GoHP and others on various<br />
occasions.<br />
2.3.3 Financing of Capital Expenditure:<br />
2.3.3.1 The project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 110 Crores planned <strong>for</strong> the control period, debt will be Rs. 77 Crores and equity<br />
47
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
contribution will be Rs. 33 Crores Equity contribution will be 50% from <strong>UJVN</strong><br />
<strong>Limited</strong> and 50% by JV partner to be nominated by GoHP. The equity contribution<br />
by <strong>UJVN</strong> <strong>Limited</strong> will be considered as investment in its books of accounts. Equity<br />
will be provided from budgetary support of GoU while debt is yet to be tied-up<br />
with financial institutions. Year-wise allocation of debt and equity <strong>for</strong> the control<br />
period is provided in the table below:<br />
Table 15: Funding Pattern during the Control Period – Kishau Project<br />
Rs.Crores<br />
Year<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
after<br />
31.03.2016 Total<br />
Debt - JV - - 7.00 70.00 3,079.30 3,156.30<br />
Equity -<br />
<strong><strong>UJVN</strong>L</strong> - - 1.50 15.00 659.85 676.35<br />
Equity - JV<br />
Partner - - 1.50 15.00 659.85 676.35<br />
Debt - JV 0% 0% 70% 70% 70% 70%<br />
Equity -<br />
<strong><strong>UJVN</strong>L</strong> 15.00% 15.00% 15.00% 15.00% 15.00% 15.00%<br />
Equity - JV<br />
Partner 15.00% 15.00% 15.00% 15.00% 15.00% 15.00%<br />
2.3.4 Capitalization Schedule:<br />
2.3.4.1 As per Commissioning schedule, Kishau project will get commissioned in March<br />
2024. The entire capital expenditure of Rs. 4509 Crores (excluding IDC & Financing<br />
Charges) will get capitalized in FY 2023-24. Year-wise capitalization during the<br />
control period is provided in the table below:<br />
Table 16: Capex & Capitalization during the Control Period – Kishau Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure - - 10.00 100.00 4,399.00 4,509.00<br />
Capitalization - - - - 4,509.00 4,509.00<br />
48
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.4 Sirkari Bhyol Rupsiabagar Hydroelectric Project (210 MW)<br />
2.4.1 Background<br />
2.4.1.1 Sirkari Bhyol Rupsiabagar Hydroelectric Project is located in Pithoragarh district of<br />
Uttarakhand and it envisages utilization of the waters of the river Goriganga, a<br />
tributary of river Kali (Sarda) <strong>for</strong> power generation as a run of river scheme,<br />
harnessing a head of about 388.97 m.<br />
2.4.1.2 The project with a proposed installation of 210 MW (3 x 70 MW) is envisaged to<br />
generate an annual energy of 967.97 MU in a 90% dependable year with 95%<br />
Installed capacity.<br />
2.4.2 Capital Expenditure:<br />
2.4.2.1 The estimated cost of the project at June 2003 price level is Rs. 893.63 Crores<br />
including IDC & Financing Charges of Rs. 141.07 Crores. The project is estimated to<br />
get completed in a period of 66 months. Capital expenditure of Rs. 5 Crores is<br />
projected to be incurred during the control period. The year wise phasing of the<br />
capital expenditure during the control period is shown in the table below:<br />
Table 17: Capital Expenditure during the Control Period – Sirkari Bhyol Rupsiabagar<br />
Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - - - 5.00 888.63 893.63<br />
2.4.2.2 Details of the project cost are provided in the table on the next page :<br />
49
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 18: Capital Cost – Sirkari Bhyol Rupsiabagar Project<br />
SARKARI BHYOL RUPSIABAGAR H. E. PROJECT (210 MW), UTTARAKHAND<br />
ABSTRACT OF COST (June 2003)<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
A CIVIL WORKS<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 8.60<br />
B - Land 1.80<br />
C - Works 276.50<br />
J - Power <strong>Plan</strong>t Civil Works 151.20<br />
K - Buildings 17.20<br />
M - <strong>Plan</strong>tation 2.00<br />
O - Miscellaneous 17.20<br />
P - Maintenance During Construction 4.62<br />
Q - Special Tools and <strong>Plan</strong>ts 10.00<br />
R - Communication 17.20<br />
X - Environment and Ecology 8.60<br />
Y - Losses on Stock -1.16<br />
TOTAL OF I - WORKS 513.76<br />
II - Establishment 40.96<br />
III - Tools and <strong>Plan</strong>ts 5.14<br />
IV - Suspense 5.14<br />
V- Receipt & Recoveries -4.08<br />
TOTAL DIRECT CHARGES 555.78<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue 0.09<br />
II - Audit & Accounts Charges 5.14<br />
TOTAL INDIRECT CHARGES 5.23<br />
TOTAL CIVIL WORKS 561.01<br />
B ELECTRICAL WORKS 191.55<br />
TOTAL COST (CIVIL + ELECTRICAL) 752.56<br />
INTEREST DURING CONSTRUCTION 141.07<br />
FINANCING CHARGES -<br />
TOTAL COST INCLUDING IDC & FINANCING CHARGES 893.63<br />
Total 893.63<br />
50
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.4.2.3 Economic Analysis<br />
The energy generation from the project with an installed capacity of 210 MW in<br />
stand-alone operation mode is estimated at 967.97 MU in a 90% dependable year<br />
with 95% machine availability.<br />
Considering Interest rate of 10%, RoE of 14%, depreciation is considered same as<br />
repayment schedule and O&M charges of 1.5% of capital cost with escalation rate<br />
of 5% the, Levellised tariff of the project works out as Rs. 1.25 per unit (with<br />
12.00% discounting factor).<br />
The detailed working of the economic analysis is provided in the Detailed<br />
Project Report.<br />
2.4.2.4 Status Update of Capital Expenditure:<br />
Preparation of comprehensive and bankable DPR of Sirkari Bhyol Rupsiabagar<br />
Power Station is under progress. Work <strong>for</strong> conducting geological<br />
investigations has been awarded on 27.04.2012 and mobilisation of resources<br />
<strong>for</strong> the same at the project site is in progress. DPR consultant has been<br />
requested <strong>for</strong> finalisation of Layout of the Project.<br />
After finalisation of layout and salient features of various components of the<br />
Project, revised ToR <strong>for</strong> conducting EIA/EMP studies shall be sought from<br />
MoEF.<br />
2.4.3 Financing of Capital Expenditure:<br />
2.4.3.1 This Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 5 Crores planned <strong>for</strong> the control period, debt will be Rs. 3.5 Crores and equity<br />
contribution will be Rs. 1.5 Crores. Equity will be provided from budgetary support<br />
of GoU <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt is yet to be tied-up with financial institutions.<br />
51
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Year-wise allocation of debt and equity <strong>for</strong> the control period is provided in the<br />
table below:<br />
Table 19: Funding Pattern during the Control Period – Sirkari Bhyol Rupsiabagar Project<br />
Year<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Debt - - - 3.50 622.04 625.54<br />
Equity - - - 1.50 266.59 268.09<br />
Debt 0% 0% 0% 70% 70% 70%<br />
Equity 0% 0% 0% 30% 30% 30%<br />
2.4.4 Capitalization Schedule:<br />
2.4.4.1 As per Commissioning schedule, Sirkari Bhyol Rupsiabagar project will get<br />
commissioned in June, 2021. The entire capital expenditure of Rs. 893.63 Crores<br />
will get capitalized in FY 2020-21. Year-wise capitalization during the control period<br />
is provided in the table below:<br />
Table 20: Capex & Capitalization during the Control Period –Sirkari Bhyol Rupsiabagar<br />
Project<br />
Rs.Crores<br />
Year<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - - - 5.00 888.63 893.63<br />
Capitalization - - - - 893.63 893.63<br />
52
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.5 Bowala Nand Prayag Hydroelectric Project (300 MW)<br />
2.5.1 Background:<br />
2.5.1.1 The Bowala Nand Prayag Hydro Electric Power Project is located in Chamoli district<br />
of Uttarakhand State on the Alaknanda River, near to Chamoli and some 25 km<br />
downstream of Josimath. The Alaknanda River is one of the main tributaries of the<br />
Ganga. The Project can be approached via a 200 km long drive from Rishikesh on<br />
National Highway 58 which goes up to Badrinath, the road is metalled right up to<br />
the project site.<br />
2.5.1.2 The project with a proposed installation of 300 MW (4 x 75 MW) is envisaged to<br />
generate an annual energy of 1340 MU in a 90% dependable year with 95% of the<br />
Installed Capacity.<br />
2.5.2 Capital Expenditure:<br />
2.5.2.1 The estimated cost of the project at May 2012 price level is Rs. 3007.24 Crores<br />
including IDC of 612.39 Crores and Rs. 290.35 Crores <strong>for</strong> Financing Charges. The<br />
project is estimated to get completed in a period of 60 months. Capital expenditure<br />
of Rs. 305 Crores is projected to be incurred during the control period. The year<br />
wise phasing of the capital expenditure during the control period is shown in the<br />
table below:<br />
Table 21: Capital Expenditure during the Control Period – Bowala Nand Prayag Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - 5.00 100.00 200.00 2,702.24 3,007.24<br />
2.5.2.2 Details of the project cost are provided in the table on the next page :<br />
53
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 22: Capital Cost – Bowala Nand Prayag Project<br />
BOWALA NNANDPRAYAG H. E. PROJECT (300 MW), UTTARAKHAND<br />
ABSTRACT OF COST (May 2012)<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
A CIVIL WORKS<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 20.69<br />
B - Land 34.67<br />
C - Works 763.52<br />
J - Power <strong>Plan</strong>t Civil Works 573.81<br />
K - Buildings 38.66<br />
M - <strong>Plan</strong>tation 0.65<br />
O - Miscellaneous 34.23<br />
P - Maintenance During Construction 14.10<br />
Q - Special Tools and <strong>Plan</strong>ts 5.76<br />
R - Communication 33.62<br />
X - Environment and Ecology 48.56<br />
Y - Losses on Stock 3.52<br />
TOTAL OF I - WORKS 1,571.78<br />
II - Establishment 104.20<br />
III - Tools and <strong>Plan</strong>ts 15.72<br />
IV - Suspense -<br />
V- Receipt & Recoveries -3.33<br />
TOTAL DIRECT CHARGES 1,688.37<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue 0.20<br />
II - Audit & Accounts Charges 15.72<br />
TOTAL INDIRECT CHARGES 15.92<br />
TOTAL CIVIL WORKS 1,704.30<br />
B ELECTRICAL WORKS 400.20<br />
TOTAL COST (CIVIL + ELECTRICAL) 2,104.50<br />
INTEREST DURING CONSTRUCTION 612.39<br />
FINANCING CHARGES 290.35<br />
TOTAL COST INCLUDING IDC & FINANCING CHARGES 3,007.24<br />
Total 3,007.24<br />
54
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.5.2.3 Economic Analysis<br />
With the Design Energy of 1340 GWh, 0.2% as auxiliary consumption and 0.5% as<br />
trans<strong>for</strong>mation losses, saleable energy is 1330.62 GWh per annum.<br />
Levelised Tariff<br />
Considering interest rate of 10.25%, RoE of 14%, depreciation is considered same<br />
as loan repayment schedule and O&M charges of 1.5% of capital cost with<br />
escalation of 4% the levelised tariff calculated in accordance with the CERC<br />
guidelines is Rs 2.35/kWh and the tariff <strong>for</strong> the first year of operation is Rs<br />
3.24/kWh.<br />
Benefit: Cost Ratio<br />
The Net Present Values of costs and benefits based on the 90% dependable year’s<br />
energy and with a fixed tariff of Rs 2.50/kWh work out to be as follows (after tax):<br />
Rs. Lakhs<br />
NPV of Benefit (90% Year) 1,08,530<br />
NPV of Cost (90% Year) 1,04,026<br />
Benefit / Cost (90% Year) 1.04<br />
Net Benefit (90% Year) 4,504<br />
The detailed working of the economic analysis is provided in Detailed Project<br />
Report.<br />
2.5.2.4 Status Update of Capital Expenditure:<br />
The project DPR with enhanced capacity of 300 MW has been submitted to<br />
CEA <strong>for</strong> concurrence on 18 th July 2007. Most of the chapters of the DPR have<br />
been cleared by CEA/ CWC. Revised final DPR prepared in 6 volumes has been<br />
55
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
submitted to CEA in 22 sets <strong>for</strong> Techno Economic Concurrence on 18 th August,<br />
2012.<br />
Techno Economic Clearance (TEC) from CEA is expected by February, 2013.<br />
Report of EIA/EMP studies conducted by M/s Rites has been submitted by<br />
<strong>UJVN</strong> <strong>Limited</strong> to MoEF in April, 2011 <strong>for</strong> permission to conduct public hearing.<br />
Public hearing was conducted through State Pollution Control Board (SPCB) on<br />
23.08.12 and as decided another Public hearing shall be held in February,<br />
2013 <strong>for</strong> which requisite fee has been deposited with SPCB on 23.11.12.<br />
The approval of GoU to execute Bowla Nand Prayag & Nand Prayag Langasu<br />
Projects through Joint Venture through open bidding process has been<br />
received vide letter no. 2302/I(2)/2011-04/(3)/11/2006 dated 24.11.2011.<br />
RFQ cum RFP document, Joint Venture Agreement & Share Holding<br />
Agreement have been finalised and submitted to GoU <strong>for</strong> approval on<br />
18.01.2012.<br />
2.5.3 Financing of Capital Expenditure:<br />
2.5.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 305 Crores planned during the control period, debt will be Rs. 213.5 Crores<br />
and equity contribution will be Rs. 91.5 Crores. Equity will be provided from<br />
budgetary support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt is yet to be tiedup<br />
with financial institutions. Equity contribution will be 26% from <strong>UJVN</strong> <strong>Limited</strong><br />
and 74% by JV partner. Free equity offered by the probable JV partner over and<br />
above 10% threshold equity to <strong>UJVN</strong> <strong>Limited</strong> will be the basis of selecting the JV<br />
partner, thus <strong>UJVN</strong> <strong>Limited</strong> will be required to invest 16% or less of the equity<br />
component in the project. The equity contribution by <strong>UJVN</strong> <strong>Limited</strong> will be<br />
considered as investment in its books of accounts. Year-wise allocation of debt<br />
and equity <strong>for</strong> the control period is provided in the table below:<br />
56
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 23: Funding Pattern during the Control Period – Bowla Nand Prayag Project<br />
Rs.Crores<br />
Year<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
after<br />
31.03.2016 Total<br />
Debt - JV - 3.50 70.00 140.00 1,891.57 2,105.07<br />
Equity -<br />
<strong><strong>UJVN</strong>L</strong> - 0.39 7.80 15.60 210.77 234.56<br />
Equity - JV<br />
Partner - 1.11 22.20 44.40 599.90 667.61<br />
Debt - JV 0% 70% 70% 70% 70% 70%<br />
Equity -<br />
<strong><strong>UJVN</strong>L</strong> 0.00% 7.80% 7.80% 7.80% 7.80% 7.80%<br />
Equity - JV<br />
Partner 0.00% 22.20% 22.20% 22.20% 22.20% 22.20%<br />
2.5.4 Capitalization Schedule:<br />
2.5.4.1 As per the existing commissioning schedule, Bowla Nand Prayag Project will get<br />
commissioned in March, 2019. The entire capital expenditure of Rs. 3007.24 Crores<br />
will get capitalized in FY 2018-19. Year-wise capitalization during the control period<br />
is provided in the table below:<br />
Table 24: Capex & Capitalization during the Control Period – Bowla Nand Prayag Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure - 5.00 100.00 200.00 2,702.24 3,007.24<br />
Capitalization - - - - 3,007.24 3,007.24<br />
57
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.6 Nand Prayag Langasu Hydroelectric Project (100 MW)<br />
2.6.1 Background:<br />
2.6.1.1 Nand Prayag Langasu Hydroelectric project located on the New Delhi – Badarinath<br />
National Highway No. 58 almost midway between Karanprayag and Nandprayag in<br />
Chamoli district of Uttarakhand State. The project envisages utilization of the water<br />
of river Alaknanda <strong>for</strong> power generation on a run of the river scheme harnessing a<br />
gross head of about 80 m.<br />
2.6.1.2 The project with a proposed installation of 100 MW (4 x 25 MW) is envisaged to<br />
generate an annual energy of 490.45 MU in a 90% dependable year with 95% of the<br />
Installed Capacity.<br />
2.6.2 Capital Expenditure:<br />
2.6.2.1 The estimated cost of the project at August 2010 price level is Rs. 1401.19 Crores<br />
including IDC & Financing Charges of 261.00 Crores. The project is estimated to get<br />
completed in a period of 66 months. Capital expenditure of Rs. 105 Crores is<br />
projected to be incurred during the control period. The year wise phasing of the<br />
capital expenditure during the control period is shown in the table below:<br />
Table 25: Capital Expenditure during the Control Period – Nand Prayag Langasu Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - - 5.00 100.00 1,296.19 1,401.19<br />
2.6.2.2 Details of the project cost are provided in the table on the next page :<br />
58
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 26: Capital Cost – Nand Prayag Langasu Project<br />
NANDPRAYAG LANGASU H. E. PROJECT (100 MW), UTTARAKHAND<br />
ABSTRACT OF COST August 2010)<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
A CIVIL WORKS<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 11.92<br />
B - Land 3.45<br />
C - Works 228.28<br />
J - Power <strong>Plan</strong>t Civil Works 598.99<br />
K - Buildings 2.07<br />
M - <strong>Plan</strong>tation 0.18<br />
O - Miscellaneous 7.08<br />
P - Maintenance During Construction 8.29<br />
Q - Special Tools and <strong>Plan</strong>ts 3.85<br />
R - Communication 2.97<br />
X - Environment and Ecology 22.46<br />
Y - Losses on Stock 2.07<br />
TOTAL OF I - WORKS 891.61<br />
II - Establishment 69.26<br />
III - Tools and <strong>Plan</strong>ts 2.50<br />
IV - Suspense -<br />
V- Receipt & Recoveries -1.57<br />
TOTAL DIRECT CHARGES 961.80<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue 0.09<br />
II - Audit & Accounts Charges 4.46<br />
TOTAL INDIRECT CHARGES 4.55<br />
TOTAL CIVIL WORKS 966.34<br />
B ELECTRICAL WORKS 173.85<br />
TOTAL COST (CIVIL + ELECTRICAL) 1,140.19<br />
INTEREST DURING CONSTRUCTION 261.00<br />
FINANCING CHARGES -<br />
TOTAL COST INCLUDING IDC & FINANCING CHARGES 1,401.19<br />
Total 1,401.19<br />
59
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.6.2.3 Economic Analysis<br />
The energy generation from the project with an installed capacity of 100 MW in<br />
stand-alone operation mode is estimated at 490.45 MU in a 90% dependable year<br />
with 95% machine availability.<br />
Considering Interest rate of 8.50% <strong>for</strong> capital, interest rate of 12.00% <strong>for</strong> working<br />
capital, RoE of 14%, depreciation is considered same as repayment schedule and<br />
O&M charges of 2.00% of capital cost with escalation of 5.72% the Levellised tariff<br />
from the project works out as Rs. 4.19 per unit (with 12.00% discounting factor).<br />
The detailed working of the economic analysis is provided in Detailed Project<br />
Report.<br />
2.6.2.4 Status Update of Capital Expenditure:<br />
Updated DPR with approved hydrology was submitted to CEA on 5 th March,<br />
2011. A presentation in CEA along with the consultant M/s Tractebal<br />
Engineers <strong>Limited</strong> was given on 04.04.2011 in the presence of various<br />
Directors of CEA/CWC on Nand Prayag Langasu project. The<br />
observations/comments of various directorates of CEA/CWC have been<br />
received and will be replied in due course.<br />
With regard to comments of GSI, a joint site visit of Geologists of <strong>UJVN</strong><br />
<strong>Limited</strong> & the consultant was conducted in January, 2012 & replies have been<br />
submitted on 25.04.2012.<br />
Revised ToR has been issued by MOEF. As per revised ToR, EIA/EMP studies<br />
are to be conducted by accredited institutions registered with Quality Council<br />
of India/ NABET. Work <strong>for</strong> EIA/ EMP studies based upon revised TOR conveyed<br />
by MoEF was awarded on 26.6.12 and the same is to be completed by<br />
December 2013.<br />
60
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
The approval of GoU has been received vide letter no. 2302/I(2)/2011-<br />
04/(3)/11/2006 dated 24.11.2011 to execute Bowla Nand Prayag & Nand<br />
Prayag Langasu Projects through Joint Venture through open bidding process.<br />
RFQ cum RFP document, Joint Venture Agreement & Share Holding<br />
Agreement have been finalised and submitted on 18.01.2012 to GoU <strong>for</strong><br />
approval.<br />
2.6.3 Financing of Capital Expenditure:<br />
2.6.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 105 Crores planned during the control period, debt will be Rs. 73.5 Crores and<br />
equity contribution will be Rs. 31.5 Crores. Equity will be provided from budgetary<br />
support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt is yet to be tied-up with<br />
financial institutions. Equity contribution will be 26% from <strong>UJVN</strong> <strong>Limited</strong> and 74%<br />
by JV partner. Free equity offered by the probable JV partner over and above 10%<br />
threshold equity to <strong>UJVN</strong> <strong>Limited</strong> will be the basis of selecting the JV partner, thus<br />
<strong>UJVN</strong> <strong>Limited</strong> will be required to invest 16% or less of the equity component in the<br />
project. The equity contribution by <strong>UJVN</strong> <strong>Limited</strong> will be considered as investment<br />
in its books of accounts. Year-wise allocation of debt and equity <strong>for</strong> the control<br />
period is provided in the table below:<br />
Table 27: Funding Pattern during the Control Period – Nand Prayag Langasu Project<br />
Rs.Crores<br />
Year<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
after<br />
31.03.2016 Total<br />
Debt - JV - - 3.50 70.00 907.33 980.83<br />
Equity -<br />
<strong><strong>UJVN</strong>L</strong> - - 0.39 7.80 101.10 109.29<br />
Equity - JV<br />
Partner - - 1.11 22.20 287.75 311.06<br />
Debt - JV 0% 0% 70% 70% 70% 70%<br />
Equity -<br />
<strong><strong>UJVN</strong>L</strong> 0.00% 0.00% 7.80% 7.80% 7.80% 7.80%<br />
Equity - JV<br />
Partner 0.00% 0.00% 22.20% 22.20% 22.20% 22.20%<br />
61
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.6.4 Capitalization Schedule:<br />
2.6.4.1 As per the present commissioning schedule, Nand Prayag Langasu project will get<br />
commissioned in March 2020. The entire capital expenditure of Rs. 1401.19 Crores<br />
will get capitalized in FY 2019-20. Year-wise capitalization during the control period<br />
is provided in the table below:<br />
Table 28: Capex & Capitalization during the Control Period – Nand Prayag Langasu Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure - - 5.00 100.00 1,296.19 1,401.19<br />
Capitalization - - - - 1,401.19 1,401.19<br />
62
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.7 Tamak Lata Hydroelectric Project (250 MW)<br />
2.7.1 Background:<br />
2.7.1.1 Tamak-Lata Hydroelectric Project is planned as a Run–of–River Project on river<br />
Dhauliganga to develop a rated head of about 291.4 m between barrage site at<br />
Tamak village and Powerhouse site at village Lata in Joshimath Tehsil of Chamoli<br />
District of Uttarakhand. The barrage site will be located immediately downstream<br />
of Tailrace out fall from Powerhouse of Jhelam-Tamak H.E. Project. The<br />
underground Power house complex is proposed to be located near village Lata<br />
upstream barrage site of Lata Tapovan project.<br />
2.7.1.2 The project with a proposed installation of 250 MW (4 x 62.5 MW) is envisaged to<br />
generate an annual energy of 1041.43 MU in a 90% dependable year with 95%<br />
Installed Capacity.<br />
2.7.2 Capital Expenditure:<br />
2.7.2.1 The estimated cost of the project at November 2007 price level is Rs. 1053.45<br />
Crores excluding IDC & Financing Charges. The project is estimated to get<br />
completed in a period of 42 months.<br />
Capital expenditure of Rs. 52 Crores is<br />
projected to be incurred during the control period. The year wise phasing of the<br />
capital expenditure during the control period is shown in the table below:<br />
Table 29: Capital Expenditure during the Control Period – Tamak Lata Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - - 2.00 50.00 1,001.45 1,053.45<br />
2.7.2.2 Details of the project cost are provided in the table on the next page :<br />
63
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 30: Capital Cost – Tamak Lata Project<br />
TAMAKLATA H. E. PROJECT (250 MW), UTTARAKHAND<br />
ABSTRACT OF COST (November 2007)<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
A CIVIL WORKS<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 24.25<br />
B - Land 19.83<br />
C - Works 198.85<br />
J - Power <strong>Plan</strong>t Civil Works 373.65<br />
K - Buildings 8.59<br />
M - <strong>Plan</strong>tation 0.95<br />
O - Miscellaneous 11.78<br />
P - Maintenance During Construction 6.38<br />
Q - Special Tools and <strong>Plan</strong>ts 7.04<br />
R - Communication 25.70<br />
X - Environment and Ecology 14.20<br />
Y - Losses on Stock -<br />
TOTAL OF I - WORKS 691.22<br />
II - Establishment 33.35<br />
III - Tools and <strong>Plan</strong>ts 6.91<br />
IV - Suspense -<br />
V- Receipt & Recoveries -<br />
TOTAL DIRECT CHARGES 731.48<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue -<br />
II - Audit & Accounts Charges 6.91<br />
TOTAL INDIRECT CHARGES 6.91<br />
TOTAL CIVIL WORKS 738.39<br />
B ELECTRICAL WORKS 315.05<br />
TOTAL COST (CIVIL + ELECTRICAL) 1,053.45<br />
TOTAL COST EXCLUDING IDC & FINANCING CHARGES 1,053.45<br />
64
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.7.2.3 Economic Evaluation<br />
Finalization of the project cost is under process and currently project cost<br />
excluding IDC & financing charges is available. After IDC & financial charges have<br />
been calculated, economic evaluation will be carried out <strong>for</strong> the project.<br />
2.7.2.4 Status Update of Capital Expenditure:<br />
Draft DPR of the project has been submitted by the consultant. Hydrology has<br />
been cleared by CWC in September, 2011. During presentation be<strong>for</strong>e MoEF,<br />
EAC advised <strong>for</strong> reduction of Length of HRT <strong>for</strong> free stretch of flow of river <strong>for</strong><br />
at least 1-2 Km. in this regard consultations with THDC officials were<br />
undertaken. Additional study <strong>for</strong> alternative site <strong>for</strong> location of powerhouse<br />
has been conducted & after finalization of free riverine stretch by MoEF,<br />
revision of DPR shall be undertaken.<br />
As desired by MoEF revised power potential studies of Malari Jhelum, Jhelum<br />
Tamak (both under development by THDC) and Tamak Lata were submitted<br />
by THDC to MoEF on 18.04.2012. Further, replies to the observations of<br />
Expert Appraisal Committee (EAC) <strong>for</strong> providing ToR <strong>for</strong> conducting EIA/EMP<br />
studies have been framed and same will be submitted to MoEF in due course.<br />
The approval of GoU to execute Tamak Lata Project through Joint Venture<br />
through open bidding process has been received vide letter no.<br />
2302/I(2)/2011-04/(3)/11/2006 dated 24.11.2011. RFQ cum RFP document,<br />
Joint Venture Agreement & Share Holding Agreement have been finalised and<br />
submitted to GoU <strong>for</strong> approval on 15.02.2012.<br />
2.7.3 Financing of Capital Expenditure:<br />
2.7.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 52 Crores planned during the control period, debt will be Rs. 36.4 Crores and<br />
equity contribution will be Rs. 15.6 Crores. Equity will be provided from the<br />
65
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
budgetary support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt is yet to be tiedup<br />
with financial institutions. Equity contribution will be 26% from <strong>UJVN</strong> <strong>Limited</strong><br />
and 74% by JV partner. Free equity offered by the probable JV partner over and<br />
above 10% threshold equity to <strong>UJVN</strong> <strong>Limited</strong> will be the basis of selecting the JV<br />
partner, thus <strong>UJVN</strong> <strong>Limited</strong> will be required to invest 16% or less of the equity<br />
component in the project. The equity contribution by <strong>UJVN</strong> <strong>Limited</strong> will be<br />
considered as investment in its books of accounts. Year-wise allocation of debt and<br />
equity <strong>for</strong> the control period is provided in the table below:<br />
Table 31: Funding Pattern during the Control Period – Tamak Lata Project<br />
Rs.Crores<br />
Year<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
after<br />
31.03.2016 Total<br />
Debt - JV - - 1.40 35.00 701.02 737.42<br />
Equity -<br />
<strong><strong>UJVN</strong>L</strong> - - 0.16 3.90 78.11 82.17<br />
Equity - JV<br />
Partner - - 0.44 11.10 222.32 233.87<br />
Debt - JV 0% 0% 70% 70% 70% 70%<br />
Equity -<br />
<strong><strong>UJVN</strong>L</strong> 0.00% 0.00% 7.80% 7.80% 7.80% 7.80%<br />
Equity - JV<br />
Partner 0.00% 0.00% 22.20% 22.20% 22.20% 22.20%<br />
2.7.4 Capitalization Schedule:<br />
2.7.4.1 As per present Commissioning schedule, Tamak Lata project will get commissioned<br />
in March 2019. The entire capital expenditure of Rs. 1053.45 Crores excluding IDC<br />
& Financing charges will get capitalized in FY 2018-19. Year-wise capitalization<br />
during the control period is provided in the table below:<br />
Table 32: Capex & Capitalization during the Control Period – Tamak Lata Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure - - 2.00 50.00 1,001.45 1,053.45<br />
Capitalization - - - - 1,053.45 1,053.45<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.8 Pala Maneri Hydroelectric Project (480 MW)<br />
1 Proposed Capacity (MW) 480(4x120)<br />
2 River/District Bhagirathi/Uttarkashi<br />
3 Date of allocation to <strong><strong>UJVN</strong>L</strong> 21.04.2003<br />
4 Annu. Energy Generation( MU) 1993<br />
5 Project Cost (in Rs Crore) 1922.8 (PL- Feb,2007)<br />
6 Tariff (Rs per unit) 1.71<br />
7 MOEF-Ist stage clearance 07.12.2005<br />
8 Detailed Project Report<br />
submission and clearance<br />
DPR was submitted to CEA/CWC on 04.07.2005, which<br />
was Updated and revised as per requirement of CWC<br />
and further submitted on November, 2006. Technoeconomic<br />
concurrence (TEC) by CEA was accorded on<br />
23.02.2007.<br />
9 Present status of work Pre-construction works related to the project i.e.<br />
construction power, construction of road, detailed<br />
Investigation, detailed design engineering & colony<br />
maintenance were started <strong>for</strong> early implementation of<br />
the Project. Works related to acquisition of private<br />
land, govt. land and diversion of <strong>for</strong>est land etc. were<br />
also taken up. The contracts <strong>for</strong> major works of the<br />
project were also prepared.<br />
The project is discontinued by Government of India on<br />
the basis of meeting of National Ganga River Basin<br />
Authority (NGRBA) held on dated 01.11.2010 as<br />
communicated by GoU vide letter no. 03/I(2)/2010-<br />
04(8)/52/2008 dated 03.01.2011. Proposal <strong>for</strong><br />
approval of <strong>for</strong>eclosure of existing contracts in a safe<br />
and logical manner with a minimum expenditure of Rs.<br />
15.67 crores was presented in the 60th Board meeting<br />
held on 07.09.2011 <strong>for</strong> recommendation / approval.<br />
Board approved the same and further advised to<br />
<strong>for</strong>ward it to Government <strong>for</strong> their final<br />
approval/consent and fund allocation. Accordingly, a<br />
proposal was <strong>for</strong>warded to GoU <strong>for</strong> final approval and<br />
fund allocation on 01.10.2011. Total expenditure<br />
incurred on the project till date is Rs. 111.89 Crores.<br />
67
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
2.9 Bhaironghati Hydroelectric Project (381 MW)<br />
1 Proposed Capacity (MW) 381 (3x127)<br />
2 River/District Bhagirathi/Uttarkashi<br />
3 Date of allocation to <strong><strong>UJVN</strong>L</strong> 06.10.2005<br />
4<br />
Annual Energy Generation(<br />
MU)<br />
1406.20<br />
5 Project Cost (in Rs Crore) 2033.37 (PL-June,2007)<br />
6 Tariff (Rs per unit) 2.00<br />
7 MOEF-1st stage clearance 13.09.2005<br />
8 DPR work & its submission<br />
9 Present status of work<br />
Work of DPR and EIA/EMP studies was assigned by<br />
GoU to M/s Canadian Commercial Corporation in<br />
Feb 2004 with SNC Lavalin as their Executing<br />
agency.<br />
DPR was submitted to CEA /CWC <strong>for</strong> concurrence in<br />
Jan’2008. Hydrology, Electromechanical, Hydromechanical<br />
equipment design chapters etc. have<br />
been cleared. For concurrence on Geology, civil<br />
design and foundation engineering additional Geotechnical<br />
investigation are required.<br />
The project is discontinued by Government of India<br />
on the basis of meeting of National Ganga River<br />
Basin Authority (NGRBA) held on dated 01.11.2010<br />
as communicated by GoU vide letter no.<br />
03/I(2)/2010-04(8)/52/2008 dated 03.01.2011. Total<br />
expenditure incurred till date on the project is Rs.<br />
20.92 Crores. Committed liabilities on the Project<br />
amounts to Rs. 3.8 Crores.<br />
68
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3 CAPITAL EXPENDITURE PLAN –<br />
EXISTING PROJECTS<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.1 Chibro Power Station (240 MW)<br />
3.1.1 Background:<br />
3.1.1.1 Chibro Power Station is a Run-of-River scheme with an underground Power Station.<br />
It was the first underground Power Station in the North India and was<br />
commissioned in the year 1975. The Power Station draws water from Ichari dam<br />
located on the river Tons, one of the major tributary of river Yamuna.<br />
3.1.1.2 Chibro Power Station is a unique engineering marvel in the country and was the<br />
first experience in carrying out tunnelling in the Himalayan Thrust Zones, which was<br />
a challenge due to varied rock structure and strength. There were unexpected<br />
challenges in the tunnelling ef<strong>for</strong>t. The water from Ichari Dam is fed into the Power<br />
Station through a 6.2 km long Head Race Tunnel (HRT). The Power Station<br />
comprising of 4 units of 60 MW each with Francis turbines of 62.66 MW output, is<br />
housed in a rock cavern with the major challenge of maintaining fresh air and<br />
safety measures due to constraint of space. Design head of the project is 110m.<br />
3.1.1.3 On 5 th of March 2008, <strong>UJVN</strong> <strong>Limited</strong> entrusted the Consultant, Lahmeyer<br />
International GmbH., with a comprehensive study <strong>for</strong> the modernisation and<br />
upgradation of the station. The study is financed by the Kreditanstalt fur<br />
Wiederaufbau (KfW), Germany.<br />
3.1.2 Capital Expenditure:<br />
3.1.2.1 Capital Expenditure <strong>for</strong> RMU works is estimated at Rs. 184.88 Crores. Capital<br />
expenditure of Rs. 27.73 Crores is projected to be incurred during the control<br />
period. The year wise phasing of the capital expenditure during the control period<br />
is shown in the table below:<br />
Table 33: Capital Expenditure during the Control Period – Chibro Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - - - 27.73 157.15 184.88<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.1.2.2 RMU Project<br />
Primary purpose of RMU is life extension of the project apart from increase in<br />
generation. After RMU, generation will increase from 865 MU to 942 MU (as per<br />
DPR) subject to same water discharge. Details of the total cost are provided in the<br />
table on the next page :<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 34: Capital Cost – Chibro Project<br />
CHIBRO H. E. PROJECT (240 MW), UTTARAKHAND<br />
ABSTRACT OF COST<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 1.43<br />
B - Land -<br />
C - Works<br />
C1 - Civil Works 3.06<br />
C2 - Hydrulic Steel Structures 6.67<br />
J - Power <strong>Plan</strong>t Civil Works<br />
J1 - Civil Works 2.27<br />
J2 - Hydrulic Steel Structures 2.85<br />
K - Buildings -<br />
M - <strong>Plan</strong>tation -<br />
O - Miscellaneous 4.28<br />
P - Maintenance During Construction 0.15<br />
Q - Special Tools and <strong>Plan</strong>ts 0.10<br />
R - Communication -<br />
S - Power <strong>Plan</strong>t<br />
S1 - Mechanical Equipment 49.63<br />
S2 - Electrical Equipment 77.79<br />
X - Environment and Ecology 0.13<br />
Y - Losses on Stock 0.04<br />
TOTAL OF I - WORKS 148.39<br />
II - Establishment 11.87<br />
III - Tools and <strong>Plan</strong>ts 1.48<br />
IV - Suspense -<br />
V- Receipt & Recoveries -0.02<br />
TOTAL DIRECT CHARGES 161.73<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue -<br />
II - Audit & Accounts Charges 0.37<br />
TOTAL INDIRECT CHARGES 0.37<br />
TOTAL COST (Direct & Indirect Cost) 162.10<br />
Escalation till start of M&U Measure 18.92<br />
IDC 2.91<br />
Commitment Fees 0.72<br />
Up-front Fees -<br />
Guarantee Fees 0.22<br />
Total 184.88<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.1.2.3 Economic and Environmental Impact Evaluation<br />
The economic feasibility of the RM&U project <strong>for</strong> Chibro Power Station was<br />
appraised based on the following economic indicators:<br />
The Economical Internal Rate of Return (EIRR) which represents the rate of<br />
return that equates the present value of costs with the present value of<br />
benefits;<br />
The Economic Net Present Value (ENPV) which derived by discounting the net<br />
benefits;<br />
The benefit-cost-ratio which represents the ratio between the present value<br />
of benefits and the present value of costs.<br />
An economic discount rate of ten percent (10%) was used in the appraisal of<br />
the economic feasibility. Results are summarised below:<br />
RESULTS<br />
Site Chibro Power<br />
Station<br />
Economic Discount Rate 10.00%<br />
EIRR (%) 30.08%<br />
ENPV (Rs. Crores) 406.14<br />
B/C Ratio 2.92<br />
These results lead to the conclusion that the modernization and upgradation of<br />
the Chibro Power Station is an economically feasible project. The conclusion is<br />
drawn due to the following observations:<br />
The EIRR is greater than the assumed economic discount rate of 10%<br />
The ENPV is greater than zero.<br />
The benefit-cost ratio is greater than one.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
The detailed working of the economic analysis is provided in the Detailed<br />
Project Report.<br />
As considerable time has elapsed since the approval of DPRs on 15.9.2010, the<br />
implementation schedule has now been revised and has been made realistic<br />
considering ongoing RMU of other projects of <strong>UJVN</strong> Ltd. The Financial Analysis<br />
provided herein is as per approved DPR prepared <strong>for</strong> RMU of the Project. It is<br />
considered that the Financial Analysis data given herein above shall hold good<br />
<strong>for</strong> the revised execution schedule and the project shall be viable.<br />
The likely impact of the project on the environment has been carried and has<br />
been provided in the Detailed Project Report. Further a summary of the<br />
Environment Impact Analysis has been provided in annexure 11.<br />
3.1.2.4 Status Update of Capital Expenditure:<br />
DPR <strong>for</strong> RMU works has been prepared by M/s Lahmeyer International.<br />
The DPR has been approved by Board in its 56 th BoD meeting held on 15-09-<br />
2010.<br />
Qualification Criterion <strong>for</strong> Contractors <strong>for</strong> RMU of Chibro Power Station has<br />
been submitted to KfW and PFC <strong>for</strong> their NOC.<br />
Preparation of tender documents <strong>for</strong> RMU works is in progress and shall be<br />
submitted to PFC <strong>for</strong> their NOC.<br />
3.1.3 Financing of Capital Expenditure:<br />
3.1.3.1 The Project will be financed through a Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 27.73 Crores planned during the control period, debt will be Rs. 19.41 Crores<br />
and equity contribution will be Rs. 8.32 Crores. Equity will be provided from<br />
budgetary support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt will be provided<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Year<br />
by financial institutions like PFC, REC, NABARD, IREDA etc. Year-wise allocation of<br />
debt and equity <strong>for</strong> the control period is provided in the table below:<br />
Table 35: Funding Pattern during the Control Period – Chibro Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Debt - - - 19.41 110.00 129.42<br />
Equity - - - 8.32 47.14 55.46<br />
Debt 0% 0% 0% 70% 70% 70%<br />
Equity 0% 0% 0% 30% 30% 30%<br />
3.1.4 Capitalization Schedule:<br />
3.1.4.1 The completion schedule <strong>for</strong> RMU works of various units of Chibro project is as<br />
under:<br />
Unit No Start Date Completion Date<br />
Unit I 1 st November 2015 31 st March 2017<br />
Unit II 1 st June 2017 31 st March 2018<br />
Unit III 1 st June 2018 31 st March 2019<br />
Unit IV 1 st June 2019 31 st March 2020<br />
3.1.4.2 Total capital expenditure of Rs. 184.88 Crores will get capitalized after the control<br />
period. Year-wise capitalization during the control period is provided in the table<br />
below:<br />
Table 36: Capex & Capitalization during the Control Period – Chibro Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure - - - 27.73 157.15 184.88<br />
Capitalization - - - - 184.88 184.88<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.2 Khodri Power Station (120 MW)<br />
3.2.1 Background:<br />
3.2.1.1 The Power Station is located downstream of the Chibro Power Station and was<br />
commissioned in the year 1984. The Power Station draws water through a tunnel<br />
5.6 km long and 7.5 m in diameter, directly from the collection gallery of the Chibro<br />
Power Station. The surface Power Station comprising 4 units of 30 MW each with<br />
Francis Turbines of 43,600 HP output is located on the banks of Yamuna. The outlet<br />
of the water from the Power Station is in river Yamuna, upstream of the Dakpathar<br />
Barrage. Design head of the Power Station is 57.9 m.<br />
3.2.1.2 The operation of Chibro Power Station and the Khodri Power Station is another<br />
engineering marvel. The tandem control scheme between Chibro and Khodri Power<br />
Stations is in operation since January, 1984 and is the first of its kind in the country<br />
which optimizes the utilization of water <strong>for</strong> generation besides maintaining the<br />
safety of both the stations in case of outages.<br />
3.2.1.3 On 5 th of March 2008, <strong>UJVN</strong> <strong>Limited</strong> entrusted the Consultant, Lahmeyer<br />
International GmbH., with a comprehensive study <strong>for</strong> the modernisation and<br />
upgradation of the station. The study is financed by the Kreditanstalt fur<br />
Wiederaufbau (KfW), Germany.<br />
3.2.2 Capital Expenditure:<br />
3.2.2.1 Capital Expenditure <strong>for</strong> RMU works is estimated at Rs. 169.63 Crores. Capital<br />
expenditure of Rs. 25.44 Crores is projected to be incurred during the control<br />
period. The year wise phasing of the capital expenditure during the control period<br />
is shown in the table below:<br />
Table 37: Capital Expenditure during Control Period – Khodri Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - - - 25.44 144.19 169.63<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.2.2.2 RMU Project<br />
Primary purpose of RMU is life extension of the project apart from increase in<br />
generation. After RMU, generation will increase from 406 MU to 444 MU (as per<br />
DPR) subject to same water discharge. Details of the total project cost are<br />
provided in the table on the next page :<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 38: Capital Cost – Khodri Project<br />
KHODRI H. E. PROJECT (120 MW), UTTARAKHAND<br />
ABSTRACT OF COST<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 1.31<br />
B - Land -<br />
C - Works -<br />
C1 - Civil Works -<br />
C2 - Hydrulic Steel Structures -<br />
J - Power <strong>Plan</strong>t Civil Works<br />
J1 - Civil Works 1.95<br />
J2 - Hydrulic Steel Structures 2.09<br />
K - Buildings -<br />
M - <strong>Plan</strong>tation -<br />
O - Miscellaneous 3.93<br />
P - Maintenance During Construction 0.04<br />
Q - Special Tools and <strong>Plan</strong>ts 0.10<br />
R - Communication -<br />
S - Power <strong>Plan</strong>t<br />
S1 - Mechanical Equipment 36.79<br />
S2 - Electrical Equipment 89.97<br />
X - Environment and Ecology 0.09<br />
Y - Losses on Stock 0.01<br />
TOTAL OF I - WORKS 136.27<br />
II - Establishment 10.90<br />
III - Tools and <strong>Plan</strong>ts 1.36<br />
IV - Suspense -<br />
V- Receipt & Recoveries -0.02<br />
TOTAL DIRECT CHARGES 148.51<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue -<br />
II - Audit & Accounts Charges 0.34<br />
TOTAL INDIRECT CHARGES 0.34<br />
TOTAL COST (Direct & Indirect Cost) 148.85<br />
Escalation till start of M&U Measure 17.37<br />
IDC 2.51<br />
Commitment Fees 0.70<br />
Up-front Fees -<br />
Guarantee Fees 0.19<br />
Total 169.63<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.2.2.3 Economic and Environment Impact Evaluation<br />
The economic feasibility of the RM&U project <strong>for</strong> the Khodri Power Station was<br />
appraised using the following economic indicators:<br />
The Economical Internal Rate of Return (EIRR) which represents the rate of<br />
return that equates the present value of costs with the present value of<br />
benefits;<br />
The Economic Net Present Value (ENPV) which is derived by discounting the<br />
net benefits;<br />
The benefit-cost-ratio which represents the ratio between the present value<br />
of benefits and the present value of costs.<br />
An economic discount rate of ten percent (10%) was used in the appraisal of the<br />
economic feasibility. Results are summarised below:<br />
RESULTS<br />
Site Khodri Power<br />
Station<br />
Economic Discount Rate 10.00%<br />
EIRR (%) 23.29%<br />
ENPV (Rs. Crores) 227.88<br />
B/C Ratio 2.23<br />
These results lead to the conclusion that the modernization and upgradation of<br />
the Khodri Power Station is an economically feasible project. This conclusion is<br />
drawn due to the following observations:<br />
The EIRR is greater than the assumed economic discount rate of 10%<br />
The ENPV is greater than zero.<br />
The benefit-cost ratio is greater than one.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
The detailed working of the economic analysis is provided in the Detailed<br />
Project Report.<br />
As considerable time has elapsed since the approval of DPRs on 15.9.2010, the<br />
implementation schedule has now been revised and has been made realistic<br />
considering ongoing RMU of other projects of <strong>UJVN</strong> Ltd. The Financial Analysis<br />
provided herein is as per approved DPR prepared <strong>for</strong> RMU of the Project. It is<br />
considered that the Financial Analysis data given herein above shall hold good <strong>for</strong><br />
the revised execution schedule and the project shall be viable.<br />
The likely impact of the project on the environment has been carried and has<br />
been provided in the Detailed Project Report. Further a summary of the<br />
Environment Impact Analysis has been provided in annexure 11.<br />
3.2.2.4 Status Update of Capital Expenditure:<br />
DPR <strong>for</strong> RMU works has been prepared by M/s Lahmeyer International.<br />
The DPR has been approved by Board of <strong>UJVN</strong> Ltd. in its 56th BoD meeting<br />
held on 15-09-2010.<br />
Qualification Criterion <strong>for</strong> RMU of Khodri Power Station has been submitted<br />
to KfW and PFC <strong>for</strong> their NOC.<br />
Preparation of tender documents <strong>for</strong> RMU works is under progress and shall<br />
be submitted to PFC <strong>for</strong> their NOC.<br />
3.2.3 Financing of Capital Expenditure:<br />
3.2.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 25.44 Crores planned during the control period, Rs. 17.81 Crores will be<br />
funded through debt and Rs. 7.63 Crores through equity. Equity will be provided<br />
by GoU through budgetary support envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt will be<br />
80
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Year<br />
provided financial institutions like PFC, REC, NABARD and IREDA etc. Year wise<br />
phasing of debt and equity <strong>for</strong> the control period is provided in the table below:<br />
Table 39: Funding Pattern during the Control Period – Khodri Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Debt - - - 17.81 100.93 118.74<br />
Equity - - - 7.63 43.26 50.89<br />
Debt 0% 0% 0% 70% 70% 70%<br />
Equity 0% 0% 0% 30% 30% 30%<br />
3.2.4 Capitalization Schedule:<br />
3.2.4.1 The completion schedule <strong>for</strong> RMU works of various units of Khodri project is as<br />
under:<br />
Unit No Start Date Completion Date<br />
Unit I 1 st November 2015 31 st March 2017<br />
Unit II 1 st June 2017 31 st March 2018<br />
Unit III 1 st June 2018 31 st March 2019<br />
Unit IV 1 st June 2019 31 st March 2020<br />
3.2.4.2 Total capital expenditure of Rs. 169.63 Crores will get capitalized after the control<br />
period. Year-wise capitalization during the control period is provided in the table<br />
below:<br />
Table 40: Capex & Capitalization during the Control Period – Khodri Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure - - - 25.44 144.19 169.63<br />
Capitalization - - - - 169.63 169.63<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.3 Dhakrani Power Station (33.75 MW)<br />
3.3.1 Background:<br />
3.3.1.1 The Power Station is located on the downstream of the Dakpathar Barrage at a<br />
distance of 8 km on the Power Channel which takes off from the Barrage. The<br />
Power Station was commissioned in the year 1965.<br />
3.3.1.2 The surface Power Station comprises of 3 units of 11.25 MW each with Kaplan<br />
Turbines of 14300 HP output. Water from Dhakrani Power Station feeds Dhalipur<br />
Power Station on its downstream side through the same Power Channel. Design<br />
head of the Power Station is 19.8 m.<br />
3.3.1.3 On 5 th of March 2008, <strong>UJVN</strong> <strong>Limited</strong> entrusted the Consultant, Lahmeyer<br />
International GmbH., with a comprehensive study <strong>for</strong> the modernisation and<br />
upgradation of the station. The study is financed by the Kreditanstalt fur<br />
Wiederaufbau (KfW), Germany.<br />
3.3.2 Capital Expenditure:<br />
3.3.2.1 Capital Expenditure <strong>for</strong> RMU works is estimated at Rs. 116.41 Crores.Capital<br />
expenditure of Rs. 40.74 Crores is projected to be incurred during the control<br />
period. The year wise phasing of the capital expenditure during the control period<br />
is shown in the table below:<br />
Table 41: Capital Expenditure during the Control Period – Dhakrani Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - - 17.46 23.28 75.67 116.41<br />
3.3.2.2 RMU Project<br />
Financial tie-up <strong>for</strong> RM&U works of this power station has been done with KfW,<br />
Germany. General terms and conditions of funding from KfW are given in<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Annexure-12. <strong><strong>UJVN</strong>L</strong> <strong>Limited</strong> had carried out a study through Uttarakhand<br />
Infrastructure Development Company <strong>for</strong> assessment of the viability of the<br />
funding from KfW as compared to funding from Indian Financial Institutions. UIDC<br />
had concluded that the funding from KfW would be cheaper than funding from<br />
Indian Financial Institution. Primary purpose of RMU is life extension of the<br />
project apart from increase in generation. After RMU, generation will increase<br />
from 161 MU to 184 MU (as per DPR) subject to same water discharge. Details of<br />
the total project cost are provided in the table on the next page :<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 42: Capital Cost – Dhakrani Project<br />
DHAKRANI H. E. PROJECT (33.75 MW), UTTARAKHAND<br />
ABSTRACT OF COST<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 0.89<br />
B - Land -<br />
C - Works<br />
C1 - Civil Works 0.22<br />
C2 - Hydrulic Steel Structures 6.01<br />
J - Power <strong>Plan</strong>t Civil Works<br />
J1 - Civil Works 1.74<br />
J2 - Hydrulic Steel Structures 4.86<br />
K - Buildings -<br />
M - <strong>Plan</strong>tation -<br />
O - Miscellaneous 2.68<br />
P - Maintenance During Construction 0.13<br />
Q - Special Tools and <strong>Plan</strong>ts 0.10<br />
R - Communication -<br />
S - Power <strong>Plan</strong>t<br />
S1 - Mechanical Equipment 21.50<br />
S2 - Electrical Equipment 54.75<br />
X - Environment and Ecology 0.08<br />
Y - Losses on Stock 0.03<br />
TOTAL OF I - WORKS 93.00<br />
II - Establishment 7.44<br />
III - Tools and <strong>Plan</strong>ts 0.93<br />
IV - Suspense -<br />
V- Receipt & Recoveries -0.02<br />
TOTAL DIRECT CHARGES 101.35<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue -<br />
II - Audit & Accounts Charges 0.23<br />
TOTAL INDIRECT CHARGES 0.23<br />
TOTAL COST (Direct & Indirect Cost) 101.58<br />
Escalation till start of M&U Measure 11.86<br />
IDC 2.34<br />
Commitment Fees 0.45<br />
Up-front Fees -<br />
Guarantee Fees 0.18<br />
Total 116.41<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.3.2.3 Economic and Environment Evaluation<br />
The economic feasibility of the RM&U project <strong>for</strong> the Dhakrani Power Station was<br />
appraised based on the following economic indicators:<br />
The Economical Internal Rate of Return (EIRR) which represents the rate of<br />
return that equates the present value of costs with the present value of<br />
benefits;<br />
The Economic Net Present Value (ENPV) which derived by discounting the net<br />
benefits;<br />
The benefit-cost-ratio which represents the ratio between the present value<br />
of benefits and the present value of costs.<br />
An economic discount rate of ten percent (10%) was used in the appraisal of the<br />
economic feasibility. Results are summarised below:<br />
RESULTS<br />
Site Dhakrani Power<br />
Station<br />
Economic Discount Rate 10.00%<br />
EIRR (%) 25.67%<br />
ENPV (Rs. Crores) 235.74<br />
B/C Ratio 2.88<br />
These results lead to the conclusion that the modernization and upgradation of<br />
the Dhakrani Power Station is an economically feasible project. The conclusion is<br />
drawn due to the following observations:<br />
The EIRR is greater than the assumed economic discount rate of 10%<br />
The ENPV is greater than zero.<br />
The benefit-cost ratio is greater than one.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
The detailed working of the economic analysis is provided in Detailed Project<br />
Report.<br />
As considerable time has elapsed since the approval of DPRs on 15.9.2010, the<br />
implementation schedule has now been revised and has been made realistic<br />
considering ongoing RMU of other projects of <strong>UJVN</strong> Ltd. The Financial Analysis<br />
provided herein is as per approved DPR prepared <strong>for</strong> RMU of the Project. It is<br />
considered that the Financial Analysis data given herein above shall hold good <strong>for</strong><br />
the revised execution schedule and the project shall be viable.<br />
The likely impact of the project on the environment has been carried and has<br />
been provided in the Detailed Project Report. Further a summary of the<br />
Environment Impact Analysis has been provided in annexure 11.<br />
3.3.2.4 Status Update of Capital Expenditure:<br />
DPR <strong>for</strong> RMU works has been prepared by M/s Lahmeyer International.<br />
The DPR has been approved by Board of <strong>UJVN</strong> <strong>Limited</strong> in its 56 th BoD meeting<br />
held on 15-09-2010.<br />
On the basis of NOC from KfW on the Qualification Criterion <strong>for</strong> 3X11.25 MW<br />
Dhakrani Power Station, Qualification Criteria <strong>for</strong> the project has been<br />
approved by the Chairman, <strong>UJVN</strong> <strong>Limited</strong>.<br />
Tender <strong>for</strong> the project has been published upon receipt of NoC on Short<br />
Notice inviting bids and tender documents (International Competitive Bidding)<br />
from KfW and PFC.<br />
Contract <strong>for</strong> RMU of Dhakrani Power Station is likely to be awarded by 31-06-<br />
2013.<br />
3.3.3 Financing of Capital Expenditure:<br />
3.3.3.1 The Project will be financed with the Debt: Equity ratio of 80:20. Out of Capex of<br />
Rs. 40.74 Crores planned during the control period, debt will be Rs. 32.59 Crores<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
and equity contribution will be Rs. 8.15 Crores. Equity will be provided from<br />
budgetary support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt will be provided<br />
by KfW & PFC. Year-wise allocation of debt and equity <strong>for</strong> the control period is<br />
provided in the table below:<br />
Table 43: Funding Pattern during the Control Period – Dhakrani Project<br />
Year<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Debt - - 13.97 18.63 60.53 93.13<br />
Equity - - 3.49 4.66 15.13 23.28<br />
Debt 0% 0% 80% 80% 80% 80%<br />
Equity 0% 0% 20% 20% 20% 20%<br />
3.3.4 Capitalization Schedule:<br />
3.3.4.1 The completion schedule <strong>for</strong> RMU works of various units of Dhakrani project is as<br />
under:<br />
Unit No Start Date Completion Date<br />
Unit I 1 st October 2014 30 th June 2015<br />
Unit II 1 st October 2015 30 th June 2016<br />
Unit III 1 st October 2016 30 th June 2017<br />
3.3.4.2 Out of total capital expenditure of Rs. 40.74 Crores, Rs 38.80 Crores will get<br />
capitalized during the control period. Year-wise capitalization during the control<br />
period is provided in the table below:<br />
Table 44: Capex & Capitalization during the Control Period – Dhakrani Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure - - 17.46 23.28 75.67 116.41<br />
Capitalization - - - 38.80 77.61 116.41<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.4 Dhalipur Power Station (51 MW)<br />
3.4.1 Background:<br />
3.4.1.1 The Power Station is located on the downstream of the Dhakrani Power Station at a<br />
distance of 4 km on the Power Channel which takes off from the Dakpathar<br />
Barrage. The Power Station was commissioned in the year 1965.<br />
3.4.1.2 The surface Power Station comprises 3 units of 17 MW each with Francis Turbine of<br />
24,000 HP output. The water from the Tail Race of the Power Station joins Asan<br />
River at Asan Barrage. Design head of the Power Station is 30.48 m.<br />
3.4.1.3 On 5 th of March 2008, <strong>UJVN</strong> <strong>Limited</strong> entrusted the Consultant, Lahmeyer<br />
International GmbH., with a comprehensive study <strong>for</strong> the modernisation and<br />
upgradation of the station. The study is financed by the Kreditanstalt fur<br />
Wiederaufbau (KfW), Germany.<br />
3.4.2 Capital Expenditure:<br />
3.4.2.1 Capital Expenditure <strong>for</strong> RMU works is estimated at Rs. 116.81 Crores. Capital<br />
expenditure of Rs. 40.88 Crores is projected to be incurred during the control<br />
period. The year wise phasing of the capital expenditure during the control period<br />
is shown in the table below:<br />
Table 45: Capital Expenditure during the Control Period – Dhalipur Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - - 17.52 23.36 75.93 116.81<br />
3.4.2.2 RMU Project<br />
Financial tie-up <strong>for</strong> RM&U works of this power station has been done with KfW,<br />
Germany. General terms and conditions of funding from KfW are given in<br />
Annexure-12. <strong><strong>UJVN</strong>L</strong> <strong>Limited</strong> had carried out a study through Uttarakhand<br />
88
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Infrastructure Development Company <strong>for</strong> assessment of the viability of the<br />
funding from KfW as compared to funding from Indian Financial Institutions. UIDC<br />
had concluded that the funding from KfW would be cheaper than funding from<br />
Indian Financial Institution. Primary purpose of RMU is life extension of the<br />
project apart from increase in generation. After RMU, generation will increase<br />
from 240 MU to 276 MU (as per DPR) subject to same water discharge. Details of<br />
the total project cost are provided in the table on the next page :<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 46: Capital Cost – Dhalipur Project<br />
DHALIPUR H. E. PROJECT (51 MW), UTTARAKHAND<br />
ABSTRACT OF COST<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 0.90<br />
B - Land -<br />
C - Works -<br />
C1 - Civil Works -<br />
C2 - Hydrulic Steel Structures -<br />
J - Power <strong>Plan</strong>t Civil Works<br />
J1 - Civil Works 1.23<br />
J2 - Hydrulic Steel Structures 4.76<br />
K - Buildings -<br />
M - <strong>Plan</strong>tation -<br />
O - Miscellaneous 2.69<br />
P - Maintenance During Construction 0.06<br />
Q - Special Tools and <strong>Plan</strong>ts 0.10<br />
R - Communication -<br />
S - Power <strong>Plan</strong>t<br />
S1 - Mechanical Equipment 30.12<br />
S2 - Electrical Equipment 53.47<br />
X - Environment and Ecology 0.08<br />
Y - Losses on Stock 0.01<br />
TOTAL OF I - WORKS 93.43<br />
II - Establishment 7.47<br />
III - Tools and <strong>Plan</strong>ts 0.93<br />
IV - Suspense -<br />
V- Receipt & Recoveries -0.02<br />
TOTAL DIRECT CHARGES 101.82<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue -<br />
II - Audit & Accounts Charges 0.23<br />
TOTAL INDIRECT CHARGES 0.23<br />
TOTAL COST (Direct & Indirect Cost) 102.05<br />
Escalation till start of M&U Measure 11.91<br />
IDC 2.20<br />
Commitment Fees 0.48<br />
Up-front Fees -<br />
Guarantee Fees 0.16<br />
Total 116.81<br />
90
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.4.2.3 Economic and Environment Impact Evaluation<br />
The economic feasibility of the M&U project <strong>for</strong> the Dhalipur Power Station was<br />
appraised based on the following economic indicators:<br />
The Economical Internal Rate of Return (EIRR) which represents the rate of<br />
return that equates the present value of costs with the present value of<br />
benefits;<br />
The Economic Net Present Value (ENPV) which derived by discounting the net<br />
benefits;<br />
The benefit-cost-ratio which represents the ratio between the present value<br />
of benefits and the present value of costs.<br />
An economic discount rate of ten percent (10%) was used in the appraisal of the<br />
economic feasibility. Results are summarised below:<br />
RESULTS<br />
Site Dhalipur Power<br />
Station<br />
Economic Discount Rate 10.00%<br />
EIRR (%) 24.96%<br />
ENPV (Rs. Crores) 252.05<br />
B/C Ratio 2.97<br />
These results lead to the conclusion that the modernization and upgradation of<br />
the Dhalipur Power Station is an economically feasible project. The conclusion is<br />
drawn due to the following observations:<br />
The EIRR is greater than the assumed economic discount rate of 10%<br />
The ENPV is greater than zero.<br />
The benefit-cost ratio is greater than one.<br />
91
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
The detailed working of the economic analysis is provided in<br />
Project Report.<br />
the Detailed<br />
As considerable time has elapsed since the approval of DPRs on 15.9.2010, the<br />
implementation schedule has now been revised and has been made realistic<br />
considering ongoing RMU of other projects of <strong>UJVN</strong> Ltd. The Financial Analysis<br />
provided herein is as per approved DPR prepared <strong>for</strong> RMU of the Project. It is<br />
considered that the Financial Analysis data given herein above shall hold good <strong>for</strong><br />
the revised execution schedule and the project shall be viable.<br />
The likely impact of the project on the environment has been carried and has<br />
been provided in the Detailed Project Report. Further a summary of the<br />
Environment Impact Analysis has been provided in annexure 11.<br />
3.4.2.4 Status Update of Capital Expenditure:<br />
DPR <strong>for</strong> RMU works has been prepared by M/s Lahmeyer International.<br />
The DPR has been approved by Board of <strong>UJVN</strong> <strong>Limited</strong> in its 56 th BoD meeting<br />
held on 15-09-2010.<br />
On the basis of NOC from KfW on the Qualification Criterion <strong>for</strong> 3X17 MW,<br />
Dhalipur Power Station, Qualification Criteria <strong>for</strong> the project has been<br />
approved by the Chairman, <strong>UJVN</strong> <strong>Limited</strong>.<br />
Tender <strong>for</strong> the project has been published upon receipt on NoC on Short<br />
Notice inviting bids and tender documents (International Competitive Bidding)<br />
from KfW and PFC.<br />
Contract <strong>for</strong> RMU of Dhalipur Power Station is likely to be awarded by 31-06-<br />
2013.<br />
3.4.3 Financing of Capital Expenditure:<br />
3.4.3.1 The Project will be financed with the Debt: Equity ratio of 80:20. Out of Capex of<br />
Rs. 40.88 Crores planned during the control period, debt will be Rs. 32.71 Crores<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
and equity contribution will be Rs. 8.17 Crores. Equity will be provided from<br />
budgetary support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt will be provided<br />
by KfW & PFC. Year-wise allocation of debt and equity <strong>for</strong> the control period is<br />
provided in the table below:<br />
Table 47: Funding Pattern during Control Period – Dhalipur Project<br />
Year<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Debt - - 14.02 18.69 60.74 93.45<br />
Equity - - 3.50 4.67 15.19 23.36<br />
Debt 0% 0% 80% 80% 80% 80%<br />
Equity 0% 0% 20% 20% 20% 20%<br />
3.4.4 Capitalization Schedule:<br />
3.4.4.1 The completion schedule <strong>for</strong> RMU works of various units of Dhalipur project is as<br />
under:<br />
Unit No Start Date Completion Date<br />
Unit I 1 st October 2014 30 th June2015<br />
Unit II 1 st October 2015 30 th June 2016<br />
Unit III 1 st October 2016 30 th June 2017<br />
3.4.4.2 Out of total capital expenditure of Rs. 40.88 Crores during the control period, Rs.<br />
38.94 Crores will get capitalized during the control period. Year-wise capitalization<br />
during the control period is provided in the table below:<br />
Table 48: Capex & Capitalization during the Control Period – Dhalipur Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure - - 17.52 23.36 75.93 116.81<br />
Capitalization - - - 38.94 77.87 116.81<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.5 Kulhal Power Station (30 MW)<br />
3.5.1 Background:<br />
3.5.1.1 The Power Station is located on the downstream of the Asan Barrage at a distance<br />
of 4.5 km on the Power Channel which takes off from the Asan Barrage. The Power<br />
Station was commissioned in the year 1975.<br />
3.5.1.2 The surface Power Station comprising three units of 10 MW each with Kaplan<br />
turbine is located on the Power Channel. The water from the tail race flows<br />
towards Khara Power Station in UP. Design Head of the Power Station is 18 m.<br />
3.5.1.3 On 5 th of March 2008, <strong>UJVN</strong> <strong>Limited</strong> entrusted the Consultant, Lahmeyer<br />
International GmbH., with a comprehensive study <strong>for</strong> the modernisation and<br />
upgradation of the station. The study is financed by the Kreditanstalt fur<br />
Wiederaufbau (KfW), Germany.<br />
3.5.2 Capital Expenditure:<br />
3.5.2.1 Capital Expenditure <strong>for</strong> RMU works is estimated at Rs. 118.72 Crores. Capital<br />
expenditure of Rs. 41.55 Crores is projected to be incurred during the control<br />
period. The year wise phasing of the capital expenditure during the control period<br />
is shown in the table below:<br />
Table 49: Capital Expenditure during the Control Period – Kulhal Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - - 17.81 23.74 77.17 118.72<br />
3.5.2.2 RMU Project<br />
Financial tie-up <strong>for</strong> RM&U works of six stations has been done with KfW,<br />
Germany. General terms and conditions of funding from KfW are given in<br />
Annexure-12. <strong><strong>UJVN</strong>L</strong> <strong>Limited</strong> had carried out a study through<br />
Uttarakhand<br />
94
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Infrastructure Development Company <strong>for</strong> assessment of the viability of the<br />
funding from KfW as compared to funding from Indian Financial Institutions. UIDC<br />
had concluded that the funding from KfW would be cheaper than funding from<br />
Indian Financial Institution. Primary purpose of RMU is life extension of the<br />
project apart from increase in generation. After RMU, generation will increase<br />
from 145 MU to 183 MU (as per DPR) subject to same water discharge. Detail of<br />
the total cost is provided in the table on the next page :<br />
95
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 50: Capital Cost – Kulhal Project<br />
KULHAL H. E. PROJECT (30 MW), UTTARAKHAND<br />
ABSTRACT OF COST<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 0.91<br />
B - Land -<br />
C - Works -<br />
C1 - Civil Works 0.22<br />
C2 - Hydrulic Steel Structures 4.97<br />
J - Power <strong>Plan</strong>t Civil Works<br />
J1 - Civil Works 1.41<br />
J2 - Hydrulic Steel Structures 4.66<br />
K - Buildings -<br />
M - <strong>Plan</strong>tation -<br />
O - Miscellaneous 2.73<br />
P - Maintenance During Construction 0.11<br />
Q - Special Tools and <strong>Plan</strong>ts 0.10<br />
R - Communication -<br />
S - Power <strong>Plan</strong>t<br />
S1 - Mechanical Equipment 19.19<br />
S2 - Electrical Equipment 60.43<br />
X - Environment and Ecology 0.08<br />
Y - Losses on Stock 0.03<br />
TOTAL OF I - WORKS 94.85<br />
II - Establishment 7.59<br />
III - Tools and <strong>Plan</strong>ts 0.95<br />
IV - Suspense -<br />
V- Receipt & Recoveries -0.02<br />
TOTAL DIRECT CHARGES 103.37<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue -<br />
II - Audit & Accounts Charges 0.24<br />
TOTAL INDIRECT CHARGES 0.24<br />
TOTAL COST (Direct & Indirect Cost) 103.61<br />
Escalation till start of M&U Measure 12.10<br />
IDC 2.38<br />
Commitment Fees 0.46<br />
Up-front Fees -<br />
Guarantee Fees 0.18<br />
Total 118.72<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.5.2.3 Economic and Environment Impact Evaluation<br />
The economic feasibility of the M&U project <strong>for</strong> the Kulhal Power Station was<br />
appraised based on the following economic indicators:<br />
The Economical Internal Rate of Return (EIRR) which represents the rate of<br />
return that equates the present value of costs with the present value of<br />
benefits;<br />
The Economic Net Present Value (ENPV) which derived by discounting the net<br />
benefits;<br />
The benefit-cost-ratio which represents the ratio between the present value<br />
of benefits and the present value of costs.<br />
An economic discount rate of ten percent (10%) was used in the appraisal of the<br />
economic feasibility. Results are summarised below:<br />
RESULTS<br />
Site Kulhal Power<br />
Station<br />
Economic Discount Rate 10.00%<br />
EIRR (%) 20.57%<br />
ENPV (Rs. Crores) 143.86<br />
B/C Ratio 2.12<br />
These results lead to the conclusion that the modernization and upgradation of<br />
the Kulhal Power Station is an economically feasible project. The conclusion is<br />
drawn due to the following observations:<br />
The EIRR is greater than the assumed economic discount rate of 10%<br />
The ENPV is greater than zero.<br />
The benefit-cost ratio is greater than one.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
The detailed working of the economic analysis is provided in the Detailed<br />
Project Report.<br />
As considerable time has elapsed since the approval of DPRs on 15.9.2010, the<br />
implementation schedule has now been revised and has been made realistic<br />
considering ongoing RMU of other projects of <strong>UJVN</strong> Ltd. The Financial Analysis<br />
provided herein is as per approved DPR prepared <strong>for</strong> RMU of the Project. It is<br />
considered that the Financial Analysis data given herein above shall hold good <strong>for</strong><br />
the revised execution schedule and the project shall be viable.<br />
The likely impact of the project on the environment has been carried and has<br />
been provided in the Detailed Project Report. Further a summary of the<br />
Environment Impact Analysis has been provided in annexure 11.<br />
3.5.2.4 Status Update of Capital Expenditure:<br />
DPR <strong>for</strong> RMU works has been prepared by M/s Lahmeyer International.<br />
The DPR has been approved by Board of <strong>UJVN</strong> <strong>Limited</strong> in its 56 th BoD meeting<br />
held on 15-09-2010.<br />
Short Notice inviting bids (International Competitive Bidding) and tender<br />
documents <strong>for</strong> the project has been published in newspapers on 25.03.2011.<br />
The tender is under evaluation.<br />
Contract <strong>for</strong> RMU of Kulhal Power Station is likely to be awarded by 30 th June<br />
2013..<br />
3.5.3 Financing of Capital Expenditure:<br />
3.5.3.1 The Project will be financed with the Debt: Equity ratio of 80:20. Out of Capex of<br />
Rs. 41.55 Crores planned during the control period, debt will be Rs. 33.24 Crores<br />
and equity contribution will be Rs. 8.31 Crores. Equity will be provided from<br />
budgetary support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt will be provided<br />
98
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
by KfW & PFC. Year-wise allocation of debt and equity <strong>for</strong> the control period is<br />
provided in the table below:<br />
Table 51: Funding Pattern during the Control Period – Kulhal Project<br />
Year<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Debt - - 14.25 19.00 61.73 94.98<br />
Equity - - 3.56 4.75 15.43 23.74<br />
Debt 0% 0% 80% 80% 80% 80%<br />
Equity 0% 0% 20% 20% 20% 20%<br />
3.5.4 Capitalization Schedule:<br />
3.5.4.1 The completion schedule <strong>for</strong> RMU works of various units of Kulhal project is as<br />
under:<br />
Unit No Start Date Completion Date<br />
Unit I 1 st October 2014 30 th June 2015<br />
Unit II 1 st October 2015 30 th June 2016<br />
Unit III 1 st October 2016 30 th June 2017<br />
3.5.4.2 Out of total capital expenditure of Rs. 41.55 Crores, Rs 39.57 Crores will get<br />
capitalized during the control period. Year-wise capitalization during the control<br />
period is provided in the table below:<br />
Table 52: Capex & Capitalization during the Control Period – Kulhal Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure - - 17.81 23.74 77.17 118.72<br />
Capitalization - - - 39.57 79.15 118.72<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.6 Tiloth Power Station (90 MW)<br />
3.6.1 Background:<br />
3.6.1.1 Maneri Bhali Stage-I Project harnesses power potential of river ‘Bhagirathi’<br />
between Maneri and Tiloth in district Uttarkashi <strong>for</strong> generation of electrical power.<br />
The Power Station was commissioned in the year 1984.<br />
3.6.1.2 The Power Station consists of three generating units of 30 MW. Each Unit has<br />
vertical shaft, suspension type Hydro-Generator coupled to Francis type hydro<br />
turbines supplied by M/s. BHEL. The Hydraulic system of the Power Station consists<br />
of a diversion dam at Maneri and about 6.5 Km long, 6 m dia pressure tunnel, surge<br />
tank at the end of tunnel and a single penstock controlled by a gate at surge tank,<br />
trifurcating into three units penstock near the upstream of Power Station building,<br />
each controlled by a spherical valve of 1.8 m dia operating under a head of about<br />
180 m. Each unit is connected to the tail race channel through the draft tube<br />
controlled by a draft tube gate. The tail race is a short open channel connecting to<br />
river Bhagirathi.<br />
3.6.1.3 On 5 th of March 2008, <strong>UJVN</strong> <strong>Limited</strong> entrusted the Consultant, Lahmeyer<br />
International GmbH., with a comprehensive study <strong>for</strong> the modernisation and<br />
upgradation of the station. The study is financed by the Kreditanstalt fur<br />
Wiederaufbau (KfW), Germany.<br />
3.6.2 Capital Expenditure:<br />
3.6.2.1 Capital Expenditure <strong>for</strong> RMU works is estimated at Rs. 126.23 Crores. Capital<br />
expenditure of Rs. 88.36 Crores is projected to be incurred during the control<br />
period. The year wise phasing of the capital expenditure during the control period<br />
is shown in the table on the next page :<br />
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Table 53: Capital Expenditure during the Control Period – Tiloth Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Capital<br />
Expenditure - 18.93 25.25 44.18 37.87 126.23<br />
3.6.2.2 RMU Project<br />
Primary purpose of RMU is life extension of the project apart from increase in<br />
generation. After RMU, generation will increase from 446 MU to 484 MU (as per<br />
DPR) subject to same water discharge.<br />
provided in the table on the next page :<br />
Details of the total project cost are<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Table 54: Capital Cost – Tiloth Project<br />
TILOTH H. E. PROJECT (90 MW), UTTARAKHAND<br />
ABSTRACT OF COST<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 0.97<br />
B - Land -<br />
C - Works<br />
C1 - Civil Works 3.04<br />
C2 - Hydrulic Steel Structures 2.19<br />
J - Power <strong>Plan</strong>t Civil Works<br />
J1 - Civil Works 2.42<br />
J2 - Hydrulic Steel Structures 5.08<br />
K - Buildings -<br />
M - <strong>Plan</strong>tation -<br />
O - Miscellaneous 2.90<br />
P - Maintenance During Construction 0.13<br />
Q - Special Tools and <strong>Plan</strong>ts 0.10<br />
R - Communication -<br />
S - Power <strong>Plan</strong>t<br />
S1 - Mechanical Equipment 17.96<br />
S2 - Electrical Equipment 65.86<br />
X - Environment and Ecology 0.18<br />
Y - Losses on Stock 0.03<br />
TOTAL OF I - WORKS 100.85<br />
II - Establishment 8.07<br />
III - Tools and <strong>Plan</strong>ts 1.01<br />
IV - Suspense -<br />
V- Receipt & Recoveries -<br />
TOTAL DIRECT CHARGES 109.92<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue -<br />
II - Audit & Accounts Charges 0.25<br />
TOTAL INDIRECT CHARGES 0.25<br />
TOTAL COST (Direct & Indirect Cost) 110.18<br />
Escalation till start of M&U Measure 12.84<br />
IDC 2.53<br />
Commitment Fees 0.49<br />
Up-front Fees -<br />
Guarantee Fees 0.19<br />
Total 126.23<br />
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3.6.2.3 Economic and Environment Impact Evaluation:<br />
The economic feasibility of the RM&U project <strong>for</strong> the Tiloth Power Station was<br />
appraised based on the following economic indicators:<br />
The Economical Internal Rate of Return (EIRR) which represents the rate of<br />
return that equates the present value of costs with the present value of<br />
benefits;<br />
The Economic Net Present Value (ENPV) which derived by discounting the net<br />
benefits;<br />
The benefit-cost-ratio which represents the ratio between the present value<br />
of benefits and the present value of costs.<br />
An economic discount rate of ten percent (10%) was used in the appraisal of the<br />
economic feasibility. Results are summarised below:<br />
RESULTS<br />
Site Tiloth Power<br />
Station<br />
Economic Discount Rate 10.00%<br />
EIRR (%) 29.28%<br />
ENPV (Rs. Crores) 262.06<br />
B/C Ratio 2.87<br />
These results lead to the conclusion that the modernization and upgradation of<br />
the Tiloth Power Station represents an economically feasible project. The<br />
conclusion is drawn due to the following observations:<br />
The EIRR is greater than the assumed economic discount rate of 10%<br />
The ENPV is greater than zero.<br />
The benefit-cost ratio is greater than one.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
The detailed working of the economic analysis is provided in the Detailed<br />
Project Report.<br />
As considerable time has elapsed since the approval of DPRs on 15.9.2010, the<br />
implementation schedule has now been revised and has been made realistic<br />
considering ongoing RMU of other projects of <strong>UJVN</strong> Ltd. The Financial Analysis<br />
provided herein is as per approved DPR prepared <strong>for</strong> RMU of the Project. It is<br />
considered that the Financial Analysis data given herein above shall hold good <strong>for</strong><br />
the revised execution schedule and the project shall be viable.<br />
The likely impact of the project on the environment has been carried and has<br />
been provided in the Detailed Project Report. Further a summary of the<br />
Environment Impact Analysis has been provided in annexure 11.<br />
3.6.2.4 Status Update of Capital Expenditure:<br />
DPR <strong>for</strong> RMU works has been prepared by M/s Lahmeyer International.<br />
The DPR has been approved by Board of <strong>UJVN</strong> <strong>Limited</strong> in its 56 th BoD meeting<br />
held on 15-09-2010.<br />
Qualification Criterion and tender documents <strong>for</strong> RM&U of 3X30 MW Tiloth<br />
Power Station are under preparation and shall be submitted PFC <strong>for</strong> their<br />
NOC.<br />
3.6.3 Financing of Capital Expenditure:<br />
3.6.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 88.36 Crores planned during the control period, debt will be Rs. 61.85 Crores<br />
and equity contribution will be Rs. 26.51 Crores. Equity will be provided from<br />
budgetary support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt will be provided<br />
104
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Year<br />
by financial institution like PFC, REC, NABARD and IREDA etc. Year-wise allocation<br />
of debt and equity <strong>for</strong> the control period is provided in the table below:<br />
Table 55: Funding Pattern during the Control Period – Tiloth Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Debt - 13.25 17.67 30.93 26.51 88.36<br />
Equity - 5.68 7.57 13.25 11.36 37.87<br />
Debt 0% 70% 70% 70% 70% 70%<br />
Equity 0% 30% 30% 30% 30% 30%<br />
3.6.4 Capitalization Schedule:<br />
3.6.4.1 The completion schedule <strong>for</strong> RMU works of various units of Tiloth project is as<br />
under:<br />
Unit No Start Date Completion Date<br />
Unit I 1 st November 2013 31 st March 2015<br />
Unit II 1 st June 2015 31 st March 2016<br />
Unit III 1 st June 2016 31 st March 2017<br />
3.6.4.2 Out of total capital expenditure of Rs. 88.36 Crores, Rs. 84.15 Crores will get<br />
capitalized during the control period. Year-wise capitalization during the control<br />
period is provided in the table below:<br />
Table 56: Capex & Capitalization during the Control Period – Tiloth Project<br />
upto<br />
31.03.2013<br />
FY 2013-<br />
14<br />
FY 2014-<br />
15<br />
FY 2015-<br />
16<br />
Rs.Crores<br />
after<br />
31.03.2016 Total<br />
Year<br />
Capital<br />
Expenditure - 18.93 25.25 44.18 37.87 126.23<br />
Capitalization - - 42.08 42.08 42.08 126.23<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.7 Chilla Power Station (144 MW)<br />
3.7.1 Background:<br />
3.7.1.1 The Power Station is a Run-of-River scheme on river Ganga located upstream of the<br />
holy city Hardwar and was commissioned in the year 1980.<br />
3.7.1.2 The Power Station has four units of 36 MW each. The four Kaplan Vertical Shaft<br />
Turbines operate at a head of 32.5 m. Water of River Ganga from Pashulok Barrage<br />
is diverted through a Power Channel to feed the turbines of Chilla Power Station.<br />
3.7.1.3 Government of Uttarakhand (GoU) entered into an agreement with CCC, Canada<br />
<strong>for</strong> Chilla Hydroelectric Project Up-gradation Program.<br />
3.7.2 Capital Expenditure:<br />
3.7.2.1 Capital Expenditure <strong>for</strong> RMU works is Rs. 337.00 Crores. Initially funding was to be<br />
provided by EDC line of credit but an agreement could not be reached between<br />
borrower and GoU, now funding is likely to be tied up with Financial Institution like<br />
PFC, REC, IREDA, NABARD etc. Capital expenditure of Rs. 161.76 Crores is projected<br />
to be incurred during the control period. The year wise phasing of the capital<br />
expenditure during the control period is shown in the table below:<br />
Table 57: Capital Expenditure during the Control Period – Chilla Project<br />
Rs. Crores<br />
upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Capital Expenditure - - 33.70 128.06 175.24 337.00<br />
3.7.2.2 RMU Project<br />
Primary purpose of RMU is life extension of the project apart from increase in<br />
generation. After RMU, generation will increase from 684 MU (Pre-Tehri scenario)<br />
to 1074 MU (after commissioning of Tehri Hydroelectric Project).. Capacity of<br />
machine will enhance from present 36 MW to 43.2 MW and install capacity of<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
plant will increase from 144 MW to 172.8 MW on account of RMU. Detail of the<br />
total cost is provided in the table on the next page :<br />
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Table 58: Capital Cost – Chilla Project<br />
CHILLA H. E. PROJECT (144 MW), UTTARAKHAND<br />
ABSTRACT OF COST<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary -<br />
B - Land -<br />
C - Works<br />
C1 - Civil Works -<br />
C2 - Hydrulic Steel Structures -<br />
J - Power <strong>Plan</strong>t Civil Works<br />
J1 - Civil Works 23.96<br />
J2 - Hydrulic Steel Structures 6.37<br />
K - Buildings -<br />
M - <strong>Plan</strong>tation -<br />
O - Miscellaneous -<br />
P - Maintenance During Construction -<br />
Q - Special Tools and <strong>Plan</strong>ts 4.92<br />
R - Communication -<br />
S - Power <strong>Plan</strong>t<br />
S1 - Mechanical Equipment 134.83<br />
S2 - Electrical Equipment 129.92<br />
X - Environment and Ecology -<br />
Y - Losses on Stock -<br />
TOTAL OF I - WORKS 300.00<br />
II - Establishment<br />
III - Tools and <strong>Plan</strong>ts<br />
IV - Suspense -<br />
V- Receipt & Recoveries -<br />
TOTAL DIRECT CHARGES 300.00<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue -<br />
II - Audit & Accounts Charges -<br />
TOTAL INDIRECT CHARGES -<br />
TOTAL COST (Direct & Indirect Cost) 300.00<br />
Escalation till start of M&U Measure<br />
IDC 37.00<br />
Commitment Fees -<br />
Up-front Fees -<br />
Guarantee Fees -<br />
Total 337.00<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.7.2.3 Economic and Environment Impact Evaluation:<br />
The economic feasibility of the RM&U project <strong>for</strong> the Chilla Power Station was<br />
appraised based on the following economic indicators:<br />
The Economical Internal Rate of Return (EIRR) which represents the rate of<br />
return that equates the present value of costs with the present value of<br />
benefits;<br />
The Economic Net Present Value (ENPV) which derived by discounting the net<br />
benefits;<br />
The benefit-cost-ratio which represents the ratio between the present value<br />
of benefits and the present value of costs.<br />
An economic discount rate of ten percent (10%) was used in the appraisal of the<br />
economic feasibility. Results are summarised below:<br />
RESULTS<br />
Site Chilla Power<br />
Station<br />
Economic Discount Rate 10.00%<br />
EIRR (%) 24.74%<br />
ENPV (Rs. Crores) 528.37<br />
B/C Ratio 2.86<br />
These results lead to the conclusion that the modernization and upgrading of the<br />
Chilla Power Station represents an economically feasible project. The conclusion<br />
is drawn due to the following observations:<br />
The EIRR is greater than the assumed economic discount rate of 10%<br />
The ENPV is greater than zero.<br />
The benefit-cost ratio is greater than one.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
The detailed working of the economic analysis is provided in the Detailed<br />
Project Report.<br />
The likely impact of the project on the environment has been carried and has<br />
been provided in the Detailed Project Report.<br />
3.7.2.4 Status Update of Capital Expenditure:<br />
DPR <strong>for</strong> RMU works has been prepared by M/s CCC, Canada/ SNC Lavalin Inc.<br />
Amendment to Agreement No. 2 <strong>for</strong> revised scope and Supplementary<br />
Agreement <strong>for</strong> Phase 2 has been examined and a letter has been sent to GoU<br />
<strong>for</strong> entering into agreement <strong>for</strong> Phase-2 (Execution Phase). Comprehensive<br />
note regarding Phase-2 agreement was sent to GoU in October 2010 <strong>for</strong><br />
approval. Some queries were received from GoU regarding Phase-2<br />
Agreement. Replies have been submitted to GoU in March 2011 and decision<br />
from GoU is awaited.<br />
Due to delay in execution of the project, letter recommending the termination<br />
of contract with CCC has been sent to GOU in December 2012.<br />
3.7.3 Financing of Capital Expenditure:<br />
3.7.3.1 The project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 161.76 Crores planned during the control period, debt will be Rs. 113.23<br />
Crores and equity contribution will be Rs. 48.53 Crores. Equity will be provided<br />
from budgetary support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt is required<br />
to be arranged from financial institutions like PFC, REC, NABARD and IREDA etc.<br />
Year-wise allocation of debt and equity <strong>for</strong> the control period is provided in the<br />
table below:<br />
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Table 59: Funding Pattern during the Control Period – Chilla Project<br />
Rs. Crores<br />
Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Debt - - 23.59 89.64 122.67 235.90<br />
Equity - - 10.11 38.42 52.57 101.10<br />
Debt 0% 0% 70% 70% 70% 70%<br />
Equity 0% 0% 30% 30% 30% 30%<br />
3.7.4 Capitalization Schedule:<br />
3.7.4.1 The completion schedule <strong>for</strong> RMU works of various units of Chilla project is as<br />
under:<br />
Unit No Start Date Completion Date<br />
Unit I 1 st November 2014 31 st March 2016<br />
Unit II 1 st June 2016 31 st March 2017<br />
Unit III 1 st June 2017 31 st March 2018<br />
Unit IV 1 st June 2018 31 st March 2019<br />
3.7.4.2 Total Capex will get capitalized after the control period. Year-wise capitalization<br />
during the control period is provided in the table below:<br />
Table 60: Capex & Capitalization during the Control Period – Chilla Project<br />
Rs. Crores<br />
Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Capital Expenditure - - 33.70 128.06 175.24 337.00<br />
Capitalization - - - - 337.00 337.00<br />
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3.8 Khatima Power Station (41.40 MW)<br />
3.8.1 Background:<br />
3.8.1.1 The Power Station is located on the downstream of the Banbasa Barrage over River<br />
Sharda at a distance of 16 km on the irrigation canal which takes off from the<br />
Barrage. The Power Station was commissioned in the year 1955 & 1956. The<br />
surface Power Station comprising 3 units of 13.8 MW each with Kaplan turbines of<br />
19200 HP output is located on the unlined irrigation canal. The water is utilized <strong>for</strong><br />
the irrigation purpose in the command area of the canal. Design Head of the Power<br />
Station is 17.98 m.<br />
3.8.1.2 The Khatima Power Station is a low head station with a design discharge of 269<br />
cum. The discharge in the canal is regulated by Irrigation Department of Uttar<br />
Pradesh depending upon the irrigation requirement in the command area of the<br />
Irrigation canal and is also limited to the capacity of the escape channel<br />
downstream of the Power Station in case there is no demand.<br />
3.8.2 Capital Expenditure:<br />
3.8.2.1 Capital Expenditure <strong>for</strong> RMU works is estimated at Rs. 220.44 Crores. Capital<br />
expenditure of Rs. 171.04 Crores is projected to be incurred during the control<br />
period. The year wise phasing of the capital expenditure during the control period<br />
is shown in the table below:<br />
Table 61: Capital Expenditure during the Control Period – Khatima Project<br />
Rs. Crores<br />
upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Capital Expenditure 49.40 84.28 60.82 25.94 - 220.44<br />
3.8.2.2 RMU Project<br />
Primary purpose of RMU is life extension of the project apart from increase in<br />
generation. After RMU, generation will increase from 149.03 MU to 235 MU (as<br />
112
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
per DPR) subject to same water discharge. Details of the total project cost are<br />
provided in the table on the next page :<br />
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Table 62: Capital Cost – Khatima Project<br />
KHATIMA H. E. PROJECT (41.40 MW), UTTARAKHAND<br />
ABSTRACT OF COST<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 0.95<br />
B - Land -<br />
C - Works<br />
C1 - Civil Works -<br />
C2 - Hydrulic Steel Structures -<br />
J - Power <strong>Plan</strong>t Civil Works<br />
J1 - Civil Works 30.22<br />
J2 - Hydrulic Steel Structures 14.39<br />
K - Buildings -<br />
M - <strong>Plan</strong>tation -<br />
O - Miscellaneous -<br />
P - Maintenance During Construction 0.43<br />
Q - Special Tools and <strong>Plan</strong>ts -<br />
R - Communication -<br />
S - Power <strong>Plan</strong>t<br />
S1 - Mechanical Equipment<br />
S2 - Electrical Equipment<br />
X - Environment and Ecology<br />
129.50<br />
-<br />
Y - Losses on Stock 0.07<br />
TOTAL OF I - WORKS 175.56<br />
II - Establishment 7.02<br />
III - Tools and <strong>Plan</strong>ts 1.75<br />
IV - Suspense -<br />
V- Receipt & Recoveries -0.79<br />
TOTAL DIRECT CHARGES 183.54<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue -<br />
II - Audit & Accounts Charges 1.75<br />
TOTAL INDIRECT CHARGES 1.75<br />
TOTAL COST (Direct & Indirect Cost) 185.30<br />
Escalation till start of M&U Measure -<br />
IDC 35.14<br />
Commitment Fees -<br />
Up-front Fees -<br />
Guarantee Fees -<br />
Total 220.44<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
3.8.2.3 Economic and Environmental Impact Evaluation:<br />
The economic feasibility of the RM&U project <strong>for</strong> the Khatima Power Station was<br />
appraised in the Detailed Project Report prepared in-house which has projected<br />
cost of Rs. 256 Crores. Based on the tender invited by <strong>UJVN</strong> <strong>Limited</strong>, the revised<br />
cost is coming out to Rs. 220.44 Crores. Economic evaluation based on the DPR<br />
cost is shown below <strong>for</strong> reference. Economic evaluation is done based on the<br />
following economic indicators:<br />
The Economical Internal Rate of Return (EIRR) which represents the rate of<br />
return that equates the present value of costs with the present value of<br />
benefits;<br />
The Economic Net Present Value (ENPV) which derived by discounting the net<br />
benefits;<br />
The benefit-cost-ratio which represents the ratio between the present value<br />
of benefits and the present value of costs.<br />
An economic discount rate of ten percent (10%) was used in the appraisal of the<br />
economic feasibility. Results are summarised below:<br />
RESULTS<br />
Site Khatima Power<br />
Station<br />
Economic Discount Rate 10.00%<br />
EIRR (%) 11.32%<br />
ENPV (Rs. Crores) 34.22<br />
B/C Ratio 1.18<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
These results lead to the conclusion that the modernization and upgrading of the<br />
Khatima Power Station is an economically feasible project. The conclusion is<br />
drawn due to the following observations:<br />
The EIRR is greater than the assumed economic discount rate of 10%<br />
The ENPV is greater than zero.<br />
The benefit-cost ratio is greater than one.<br />
The detailed working of the economic analysis is provided in<br />
Project Report.<br />
the Detailed<br />
The likely impact of the project on the environment has been carried and has<br />
been provided in the Detailed Project Report.<br />
3.8.2.4 Status Update of Capital Expenditure:<br />
DPR <strong>for</strong> RM&U of Khatima Power Station has been approved by the BoD of<br />
<strong>UJVN</strong> <strong>Limited</strong> in its 56 th Board meeting held on 15.09.2010.<br />
NIT <strong>for</strong> E&M and Hydro mechanical works has been published in newspapers<br />
on 25.02.2011.<br />
Part-I was opened on 21.07.2011 and Price bid (part-II) has been opened on<br />
21.10.2011.<br />
Letter of award has been issued on 12.12.2011 to JV of M/s Alstom (India)<br />
Pvt., Vadodara and M/s PES Engineers Pvt. <strong>Limited</strong>, Hyderabad and contract<br />
has been signed on 03.01.2012.<br />
RMU of Unit-1 started on 1 st October 2012<br />
3.8.3 Financing of Capital Expenditure:<br />
3.8.3.1 The Project is being financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 171.04 Crores planned during the control period, debt will be Rs. 119.73 Crores<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
and equity contribution will be Rs. 51.31 Crores. Equity will be provided from<br />
budgetary support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while loan has been tied up<br />
with Power Finance Corporation. Copy of loan agreement is provided in Annexure<br />
14. Year-wise allocation of debt and equity <strong>for</strong> the control period is provided in the<br />
table below:<br />
Table 63: Funding Pattern during the Control Period – Khatima Project<br />
Rs. Crores<br />
Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Debt 34.58 58.99 42.57 18.16 - 154.31<br />
Equity 14.82 25.28 18.24 7.78 - 66.13<br />
Debt 70% 70% 70% 70% 0% 70%<br />
Equity 30% 30% 30% 30% 0% 30%<br />
3.8.4 Capitalization Schedule:<br />
3.8.4.1 The completion schedule <strong>for</strong> RMU works of various units of Khatima project is as<br />
under:<br />
Unit No Start Date Completion Date<br />
Unit I 1 st October 2012 31 st March 2014<br />
Unit II 1 st April 2014 31 st January 2015<br />
Unit III 1 st January 2015 31 st October 2015<br />
3.8.4.2 Total capital expenditure of Rs. 220.44 Crores will get capitalized during the control<br />
period. Year-wise capitalization during the control period is provided in the table<br />
below:<br />
Table 64: Capex & Capitalization during the Control Period – Khatima Project<br />
Rs. Crores<br />
Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Capital Expenditure 49.40 84.28 60.82 25.94 - 220.44<br />
Capitalization - - 146.96 73.48 - 220.44<br />
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3.9 Ramganga Power Station (198 MW)<br />
3.9.1 Background:<br />
3.9.1.1 The Power Station is a Reservoir based scheme on river Ramganga located near the<br />
famous Jim Corbett Park in district Pauri Garwhal and utilizes the water dammed<br />
up <strong>for</strong> irrigation purpose. The Project was commissioned in the year 1975. The<br />
water in the irrigation channel is regulated by Irrigation Department of Uttar<br />
Pradesh. The generation from Power Station is dependent on the rains in the<br />
catchment area and also on the drawl of water <strong>for</strong> irrigation purpose in the<br />
command area of the canal. The surface Power Station is located at the toe of the<br />
dam and houses 3 units of 66 MW each with Francis turbines of 92400 HP. Design<br />
Head of the Power Station is 84.4 m.<br />
3.9.1.2 The Ramganga Power Station is a medium head scheme with a design discharge of<br />
285 cum. The Project has unique challenges in operation due to restriction imposed<br />
on the release of water in the water conductor system by Irrigation Department of<br />
Uttar Pradesh which is dependent on the demand of water in the command area of<br />
the canal based on the irrigation requirement. The generation in the station takes<br />
place after the monsoon season when the demand <strong>for</strong> irrigation picks up.<br />
3.9.1.3 <strong>UJVN</strong> <strong>Limited</strong> has done comprehensive study in-house <strong>for</strong> the modernisation and<br />
upgradation of the station.<br />
3.9.2 Capital Expenditure:<br />
3.9.2.1 Capital Expenditure <strong>for</strong> RMU works is estimated at Rs. 455.22 Crores. Capital<br />
expenditure of Rs. 240.25 Crores is projected to be incurred during the control<br />
period. The year wise phasing of the capital expenditure during the control period<br />
is shown in the table on the next page :<br />
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Table 65: Capital Expenditure during the Control Period – Ramganga Project<br />
Rs. Crores<br />
upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Capital Expenditure - 39.01 81.44 119.80 214.97 455.22<br />
3.9.2.2 RMU Project<br />
Primary purpose of RMU is life extension of the project apart from increase in<br />
generation. After RMU, generation will increase from 283 MU to 450 MU (as per<br />
DPR) corresponding to 363/364m dam level at the end of filling period subject to<br />
releases by UP irrigation department. Detail of the total cost is provided in the<br />
table on the next page :<br />
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Table 66: Capital Cost – Ramganga Project<br />
RAMGANGA H. E. PROJECT (198 MW), UTTARAKHAND<br />
ABSTRACT OF COST<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
1 DIRECT CHARGES<br />
I - Works<br />
A - Preliminary 0.77<br />
B - Land -<br />
C - Works<br />
C1 - Civil Works 1.70<br />
C2 - Hydrulic Steel Structures -<br />
J - Power <strong>Plan</strong>t Civil Works<br />
J1 - Civil Works 3.61<br />
J2 - Hydrulic Steel Structures 2.33<br />
K - Buildings -<br />
M - <strong>Plan</strong>tation -<br />
O - Miscellaneous -<br />
P - Maintenance During Construction -<br />
Q - Special Tools and <strong>Plan</strong>ts -<br />
R - Communication -<br />
S - Power <strong>Plan</strong>t<br />
S1 - Mechanical Equipment 150.78<br />
S2 - Electrical Equipment 181.27<br />
X - Environment and Ecology -<br />
Y - Losses on Stock 0.01<br />
TOTAL OF I - WORKS 340.47<br />
II - Establishment 13.59<br />
III - Tools and <strong>Plan</strong>ts 3.40<br />
IV - Suspense -<br />
V- Receipt & Recoveries -0.03<br />
TOTAL DIRECT CHARGES 357.43<br />
2 INDIRECT CHARGES<br />
I - Capitalised Value of Abatement of Land Revenue -<br />
II - Audit & Accounts Charges 3.40<br />
TOTAL INDIRECT CHARGES 3.40<br />
TOTAL COST (Direct & Indirect Cost) 360.83<br />
Escalation till start of M&U Measure -<br />
IDC 94.38<br />
Commitment Fees -<br />
Up-front Fees -<br />
Guarantee Fees -<br />
Total 455.22<br />
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3.9.2.3 Economic and Environmental Impact Evaluation:<br />
The economic feasibility of the RM&U project <strong>for</strong> the Ramganga Power Station<br />
was appraised based on the following economic indicators:<br />
The Economical Internal Rate of Return (EIRR) which represents the rate of<br />
return that equates the present value of costs with the present value of<br />
benefits;<br />
The Economic Net Present Value (ENPV) which derived by discounting the net<br />
benefits;<br />
The benefit-cost-ratio which represents the ratio between the present value<br />
of benefits and the present value of costs.<br />
An economic discount rate of ten percent (10%) was used in the appraisal of the<br />
economic feasibility. Results are summarised below:<br />
RESULTS<br />
Site<br />
Ramganga Power<br />
Station<br />
Economic Discount Rate 10.00%<br />
EIRR (%) 12.97%<br />
ENPV (Rs. Crores) 82.92<br />
B/C Ratio 1.41<br />
These results lead to the conclusion that the modernization and upgradation of<br />
the Ramganga Power Station represents an economically feasible project. The<br />
conclusion is drawn due to the following observations:<br />
The EIRR is greater than the assumed economic discount rate of 10%<br />
The ENPV is greater than zero.<br />
The benefit-cost ratio is greater than one.<br />
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The detailed working of the economic analysis is provided in the Detailed<br />
Project Report.<br />
The likely impact of the project on the environment has been carried and has<br />
been provided in the Detailed Project Report.<br />
3.9.2.4 Status Update of Capital Expenditure:<br />
Revised DPR <strong>for</strong> RMU works was prepared in-house based on in<strong>for</strong>mation<br />
received from the site.<br />
Order <strong>for</strong> review of DPR by AHEC IIT, Roorkee has been placed. Review of DPR<br />
is under progress.<br />
DPR has been approved by <strong>UJVN</strong> <strong>Limited</strong> Board on 13 th September 2012.<br />
AHEC, IIT Roorkee is being engaged <strong>for</strong> review, checking and vetting of the<br />
technical specification prepared in house by <strong>UJVN</strong> <strong>Limited</strong>.<br />
3.9.3 Financing of Capital Expenditure:<br />
3.9.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 240.25 Crores planned during the control period, debt will be Rs. 168.18 Crores<br />
and equity contribution will be Rs. 72.08 Crores. Equity will be provided from<br />
budgetary support of GoU envisaged <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong> while debt is yet to be<br />
arranged. Year-wise allocation of debt and equity <strong>for</strong> the control period is provided<br />
in the table below:<br />
Table 67: Funding Pattern during the Control Period – Ramganga Project<br />
Rs. Crores<br />
Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Debt - 27.31 57.01 83.86 150.48 318.65<br />
Equity - 11.70 24.43 35.94 64.49 136.57<br />
Debt 0% 70% 70% 70% 70% 70%<br />
Equity 0% 30% 30% 30% 30% 30%<br />
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3.9.4 Capitalization Schedule:<br />
3.9.4.1 The completion schedule <strong>for</strong> RMU works of various units of Ramganga project is as<br />
under:<br />
Unit No Start Date Completion Date<br />
Unit I 15 th June 2014 28 th February 2015<br />
Unit II 15 th June 2015 28 th February 2016<br />
Unit III 15 th June 2016 28 th February 2017<br />
3.9.4.2 Out of capital expenditure of Rs. 455.22 Crores, Rs. 303.48 Crores will get<br />
capitalized during the control period. Year-wise capitalization during the control<br />
period is provided in the table below:<br />
Table 68: Capex & Capitalization during the Control Period – Ramganga Project<br />
Rs. Crores<br />
Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Capital Expenditure - 39.01 81.44 119.80 214.97 455.22<br />
Capitalization - - 151.74 151.74 151.74 455.22<br />
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3.10 Maneri Bhali - II Hydroelectric Project (304 MW)<br />
3.10.1 Background:<br />
3.10.1.1 Maneri Bhali Stage-II Hydroelectric Project utilizes a 285 m drop available in river<br />
Bhagirathi between the tail waters of Tiloth Power Station (Maneri Bhali Stage-I<br />
Project) and the head waters of Tehri Dam. The diversion structure is a baraage<br />
situated at Joshiyara, Uttarkashi which is about 152 km from Rishikesh, the nearest<br />
railhead. Joshiyara Barrage is designed to divert 142 cumecs of water through a 6 m<br />
dia. and 16 km long Head Race Tunnel to feed four Francis Turbines of the Power<br />
Station at MB-II.<br />
3.10.1.2 This project has been commissioned in 2008 and is the second Power Project of<br />
<strong>UJVN</strong> <strong>Limited</strong> on river Bhagirathi.<br />
3.10.1.3 Since its commissioning in the year 2008, Maneri Bhali Stage-II HEP has not been<br />
able to operate at its full capacity because of following reasons :<br />
Restriction of reservoir level at 1104 m at Joshiyara Barrage instead of<br />
designed maximum level of 1108 m.<br />
Heavy vibrations in the machines due to improper water evacuation through<br />
TRC, when load is increased beyond 275-280 MW.<br />
For analyzing the issue of excessive vibrations, <strong>UJVN</strong> Ltd. approached various<br />
agencies and department to carry out the studies regarding TRC and finally<br />
the work of carrying out the CFD analysis of TRC was awarded to SVNIT, Surat.<br />
The SVNIT faculty members along with Dr. Shrikant Bhave (retired expert of<br />
BHEL) visited the site and analyzed the problem. The remedy <strong>for</strong> the problem<br />
of excessive vibrations has been suggested by modifying the geometry of TRC.<br />
3.10.1.4 <strong>UJVN</strong> <strong>Limited</strong> has prepared a report on balance capital works to be done in<br />
Maneri Bhali – II. The Breakup of Cost <strong>for</strong> Balance works as per Original DPR as<br />
approved by CEA and proposed new works that are to be taken up <strong>for</strong> operating<br />
the Power Station at its full capacity are given in Annexure 10.<br />
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3.10.2 Capital Expenditure:<br />
3.10.2.1 Capital Expenditure <strong>for</strong> balance works is estimated at Rs. 216.23 Crores <strong>for</strong> FY<br />
2012-13, FY 2013-14 and FY 2014-15 .Capital expenditure of Rs. 191.23 Crores is<br />
projected to be incurred during the control period. The year wise phasing of the<br />
capital expenditure during the control period is shown in the table below:<br />
Table 69: Capital Expenditure during the Control Period – Maneri Bhali - II Project<br />
Rs. Crores<br />
upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Capital Expenditure 25.00 100.00 91.23 - - 216.23<br />
3.10.2.2 Details of the total cost of balance works is provided in the table on the next<br />
page:<br />
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Table 70: Capital Cost – Maneri Bhali - II Project<br />
MANERI BHALI - II H. E. PROJECT (304 MW), UTTARAKHAND<br />
ABSTRACT OF COST<br />
S. No Description Amount (Rs. in<br />
Crores)<br />
1 Rehabilitation 15.56<br />
2 Compensation <strong>for</strong> the affected people 1.14<br />
3 Construction of Protection wall 32.32<br />
4 Modification of tail race channel 24.15<br />
5 Construction of Office Building at Joshiyara 1.03<br />
6 Construciton of Joshiyara colony 1.10<br />
7 Construciton of Road from Joshiyara Bridge to Flushing<br />
2.22<br />
conduit on left Bank (1.2 km) and from Barrage to NH-108 on<br />
Right Bank (0.4 km)<br />
8 Balance infrastructure works <strong>for</strong> affected villages of<br />
9.50<br />
Joshiyara, Gyanshu & Kansain as per their demands<br />
9 Construction of boundary wall, sectrity fencing and gate <strong>for</strong><br />
1.21<br />
Shaktipuram colony and Shifting of existing boundary wall<br />
of Shaktipuram colony and provide the separate way <strong>for</strong><br />
villagers behind Shaktipuram colony<br />
10 Construction of 04 Nos Type-IV Residences and 01 Nos Type-<br />
1.10<br />
V Residence in Shaktipuram colony, Chinyalisaur<br />
11 Construction of school building <strong>for</strong> Saraswati Shishu Mandir<br />
2.00<br />
School in Shaktipuram Colony Chinyalisaur<br />
12 Strengthening of water distribution system of Shaktipuram<br />
0.89<br />
colony, Chinyalisaur<br />
13 Construction of workshop building at Dharasu power house<br />
1.69<br />
of MB-II project<br />
14 Protection work on hill slope behind power house 2.57<br />
15 Testing of surge shaft gate 5.00<br />
16 Centage Charges 60.84<br />
17 Payment to M/sNPCC against claim of Principal Agreement<br />
12.68<br />
in accordance to the decision of High Power Committee<br />
18 Liabilities against major civil contract of MB-II Project<br />
a. Reimbursement of Sales Tax 8.15<br />
b. Reimbursement of royalty 0.45<br />
c. Award given by the arbitrator in favour of M/s Hydel<br />
30.73<br />
Construction (P) Ltd against dispute related to swellex rock<br />
bolt, Steel fivre as extra items and loss due to flood along<br />
with the interest of Rs. 95424/- per day<br />
d. Payment against misc. works 0.26<br />
e. Security 0.35<br />
f. Pending Liability of GSI 0.95<br />
g. Expenditure incurred <strong>for</strong> arbitration 0.35<br />
Total 216.23<br />
3.10.3 Financing of Capital Expenditure:<br />
3.10.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of<br />
Rs. 191.23 Crores planned during the control period, debt will be Rs. 133.86<br />
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Crores and equity contribution will be Rs. 57.37 Crores. Year-wise allocation of<br />
debt and equity <strong>for</strong> the control period is provided in the table below:<br />
Table 71: Funding Pattern during the Control Period – Maneri Bhali - II Project<br />
Rs. Crores<br />
Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Debt 17.50 70.00 63.86 - - 151.36<br />
Equity 7.50 30.00 27.37 - - 64.87<br />
Debt 70% 70% 70% 0% 0% 70%<br />
Equity 30% 30% 30% 0% 0% 30%<br />
3.10.4 Capitalization Schedule:<br />
3.10.4.1 Total capital expenditure of Rs. 191.23 Crores will get capitalized during the control<br />
period. Year-wise capitalization during the control period is provided in the table<br />
below:<br />
Table 72: Capex & Capitalization during the Control Period – Maneri Bhali - II Project<br />
Rs. Crores<br />
Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total<br />
Capital Expenditure 25.00 100.00 91.23 - 216.23<br />
Capitalization 25.00 100.00 91.23 - - 216.23<br />
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3.11 Refurbishment of Asan Barrage, at Dhalipur (<strong>Dehradun</strong>)<br />
3.11.1 Yamuna Hydel Scheme Stage-IV envisages power generation by utilizing the tail race<br />
water of the Yamuna Hydel Scheme Stage-I along with flow of Asan River. To use<br />
water from river Asan, Asan Barrage is constructed at Dhalipur in District <strong>Dehradun</strong><br />
along with a power channel to carry water to Kulhal power house of 30 MW installed<br />
capacity which has been constructed at the end of the power channel near village<br />
Kulhal. The construction of this project was completed in 1975.<br />
3.11.2 Asan Barrage had been operated & maintained by Irrigation Department-<br />
Uttarakhand till 30 th April, 2010 and since then it is being run and maintained by<br />
<strong>UJVN</strong> <strong>Limited</strong>.<br />
3.11.3 In the last 35 years, no major repair of the Asan barrage and its associated structure<br />
has been done. Even it faced many floods. Due to record rainfall in August and<br />
September 2010, heavy floods have damaged treatment works in upstream as well<br />
as in downstream of the barrage.<br />
3.11.4 The Asan Barrage, proposed <strong>for</strong> refurbishment has spent life of more than 36 years.<br />
Since commissioning of the project, it has been continuously under operation <strong>for</strong><br />
diverting water to generating plants. It underwent heavy floods during monsoon<br />
period, every year carrying heavy logs and boulders with it. With the passage of<br />
time and continuous operation, a lot of defects in the infrastructure have developed.<br />
The sills and other components of Asan Barrage have gone weary. After creation of<br />
Uttarakhand state, the government has given a major thrust on the development of<br />
Hydo electric projects. A lot of work is being done by Uttarakhand Government<br />
towards making Uttarakhand an “Energy state”. Under present scenario, apart from<br />
implementation of new projects it has become essential that maximum energy be<br />
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harnessed from existing projects also. To ensure its reliable operation refurbishment<br />
of Asan Barrage is essentially required.<br />
3.11.5 The refurbishment shall prevent the leakage of water from Asan Barrage, during lean<br />
season, which shall be utilized <strong>for</strong> generating more electricity. Further, its<br />
refurbishment is essential <strong>for</strong> its life extension and hassle free operation. Repair of<br />
damaged structures/components of Asan Barrage will certainly prevent further<br />
deterioration of structures/components so that threat to these structures and any<br />
loss of power generation may be averted in future.<br />
3.11.6 The cost of Refurbishment of Asan Barrage is Rs 535.32 lacs. The work is to be<br />
carried out under World Bank funded DRIP (Dam Rehabilitation and Improvement<br />
Project) Scheme. The expenditure shall be done in the year 2013-14 and 2014-15 in<br />
the ratio of 40:60, subject to approval by the DRIP Authorities. This fund will be<br />
provided as a grant <strong>for</strong> this project.<br />
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3.12 Refurbishing of Ichari Dam, at Ichari, Koti (<strong>Dehradun</strong>)<br />
3.12.1 Ichari Dam was built under Yamuna Hydro Electric Scheme Stage-II and it has been in<br />
operation since 1975. It is a straight Gravity Dam of 59.25 meter height from deepest<br />
foundation level with a live storage capacity of 5.11 million cum <strong>for</strong> diurnal variation.<br />
The total length of the dam at top is about 155 m with seven spilling bays each of<br />
9.50 m clear opening. Spillways are provided with 16.50 m high and 9.5 m wide<br />
radial gates. The energy dissipation arrangement consists of slotted roller bucket in<br />
all spillway bays. Due to poor site conditions, special treatment on left bank of dam<br />
in D/S as well as in upstream has been made.<br />
3.12.2 Ichari Dam was being operated and maintained by Irrigation Department up to<br />
30/4/2010. Since the midnight of 30/4/2010, the dam is being operated and<br />
maintained by <strong>UJVN</strong> <strong>Limited</strong>.<br />
3.12.3 For the last 35 years the dam has encountered many floods and no major<br />
refurbishment of dam and its associated structures/equipment has been carried out.<br />
Heavy floods due to record rainfall in August and September 2010 have further<br />
damaged the treatment provided in upstream as well as downstream of the dam.<br />
3.12.4 The Ichari dam proposed <strong>for</strong> refurbishing has spent life of more than 35 years. Since<br />
commissioning, the dam is continuously under operation <strong>for</strong> diverting water to<br />
generating plants. Every year it encounters heavy floods during monsoon period,<br />
carrying heavy logs and boulders with it. With the passage of time and continuous<br />
operation a lot of defects in the Hydro-mechanical equipment have developed along<br />
with wear & tear. The sills and other components of Ichari Dam have gone weary.<br />
After creation of Uttarakhand state, the government has provided a major thrust on<br />
the development of Hydo electric projects. A lot of work is being done by<br />
Uttarakhand Government towards making Uttarakhand an “Energy state”. Under<br />
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present scenario, apart from implementation of new projects it has become<br />
essential that maximum energy be harnessed from existing projects also.<br />
3.12.5 Since no major repair works have been carried out on Ichari Dam so far, its<br />
refurbishment is essentially required. The refurbishing shall prevent the leakage of<br />
water from Ichari Dam during lean season which would be utilized <strong>for</strong> generating<br />
more electricity. Further, its refurbishment is essential in view of its life extension<br />
and hassle free operation. Repair of damaged structures/components of Ichari Dam<br />
will certainly prevent further deterioration of structures/components so that threat<br />
to these structures and any loss of power generation may be averted in future.<br />
3.12.6 The cost of Refurbishment of Ichari Dam is Rs 2237.57 lacs. The work is to be carried<br />
out under World Bank funded DRIP (Dam Rehabilitation and Improvement Project)<br />
Scheme. The expenditure shall be done in the year 2013-14 and 2014-15 in the ratio<br />
of 40:60, subject to approval by the DRIP Authorities. This fund will be provided as<br />
grant <strong>for</strong> this project.<br />
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3.13 Rehabilitation Work of Virbhadra Barrage, Pashulok, Rishikesh<br />
3.13.1 Virbhadra barrage was constructed and commissioned in the year 1980 and during<br />
its Thirty years of operation, various components of barrage have gone under heavy<br />
wear and tear and are posing troubles during operational activity <strong>for</strong> passing the<br />
flood safely into downstream. After construction of Tehri and Koteshwar Dam,<br />
Virbhadra Barrage, Pashulok is playing its important role round the year <strong>for</strong><br />
consistent power generation. In view of its importance and to ensure reliable<br />
operation Virbhadra barrage needs to be rehabilitated. Following are the main<br />
components where rehabilitation is required:<br />
All gates of barrage, head regulator and silt ejector.<br />
Piers and apron of barrage<br />
Afflux bund seepage drain of pond.<br />
Service road of afflux bund.<br />
Painting on steel structures of barrage.<br />
Painting on civil structures of barrage.<br />
Electro- mechanical components such as motors and brake shoes.<br />
Luminaries of barrage.<br />
Renovation of Barrage Control Room including improvement of sanitation<br />
facility<br />
Installation of Trash Rack Cleaning Machine<br />
Automation of Barrage<br />
3.13.2 Closure <strong>for</strong> special repair of submerged parts of Power channel and hydro<br />
mechanical components is necessary as the above said project runs throughout the<br />
year without any interruption except in high flood condition. A lot of wear & tear of<br />
very serious nature in civil structures as well as hydro-mechanical equipment takes<br />
place every year and there<strong>for</strong>e routine maintenance of submerged parts of<br />
structures is not possible. Since the commissioning of this project no regular closure<br />
have been taken <strong>for</strong> inspection and repair works of power channel and hydromechanical<br />
equipments. Lining and bed of power channel is severely damaged and is<br />
required to be repaired. In view of expected extensive damage to the components<br />
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leading to loss of generation from projects any delay in the repair of power channel<br />
is undesirable.<br />
3.13.3 The cost of Rehabilitation work of Virbhadra Barrage is Rs 625.81 lacs. The work is to<br />
be carried out under World Bank funded DRIP (Dam Rehabilitation and Improvement<br />
Project) Scheme. The expenditure shall be done in the year 2013-14 and 2014-15 in<br />
the ratio of 40:60, subject to approval by the DRIP Authorities. This fund will be<br />
provided as grant <strong>for</strong> this project.<br />
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3.14 Refurbishment of Dakpathar Barrage, at Dakpathar (<strong>Dehradun</strong>)<br />
3.14.1 A Barrage of 543.3m length with head regulator was commissioned in 1965 as a runof-river<br />
scheme across river Yamuna at Dakpathar in <strong>Dehradun</strong>. From the barrage a<br />
flow of 198 cum/sec is diverted and conveyed through a power channel to Dhakrani<br />
(33.75MW) Powerhouse and Dhalipur (51 MW) Powerhouse where heads of 19.80 m<br />
and 30.50 m respectively are utilized <strong>for</strong> power generation. After generating power<br />
at Dhalipur power house, the diverted water from Dakpathar Barrage meets Asan<br />
river/pond behind Asan Barrage.<br />
3.14.2 Dakpathar Barrage is provided with 6 nos. under sluices and 19 nos. spillway bays to<br />
discharge floods of River Yamuna. The head regulator takes off at an angle of 110°<br />
towards left bank of barrage. The provision of stop log gates is not available at the<br />
barrage. There<strong>for</strong>e, a closure of powerhouse is required to carry out the repair work<br />
of gates and other submerged components of barrage. No repair work of submerged<br />
part has been carried out since 2005. During last seven years several floods have<br />
passed through the barrage and especially due to record floods in August and<br />
September 2010, the sill beams of gates and other associated structures have got<br />
severely damaged. As such restoration works are required to be taken up.<br />
3.14.3 The Dakpathar Barrage proposed <strong>for</strong> refurbishing has spent life of more than 46<br />
years. Since the commissioning of the project, it is continuously under operation <strong>for</strong><br />
diverting water to generating plants. Every year it has encountered heavy floods<br />
during monsoon period carrying heavy logs and boulders with it. With the passage of<br />
time and continuous operation a lot of defects in the installed system have<br />
developed. The sills and other components of Dakpathar Barrage have gone weary.<br />
After creation of Uttarakhand state, the government has provided a major thrust on<br />
the development of Hydroelectric projects. A lot of work is being done by<br />
Uttarakhand Government towards making Uttarakhand an “Energy state”. Under<br />
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present scenario, apart from implementation of new projects it has become<br />
essential that maximum energy be harnessed from existing projects also.<br />
3.14.4 Since no major repair works have been carried out on Dakpathar Barrage so far, its<br />
refurbishment is essentially required. The refurbishing shall prevent the leakage of<br />
water from Dakpathar Barrage during lean season which would be utilized <strong>for</strong><br />
generating more electricity. Further, its refurbishment is essential in view of its life<br />
extension and hassle free operation. Repair of damaged structures/components of<br />
Dakpathar Barrage will certainly prevent further deterioration of<br />
structures/components so that threat to these structures and any loss of power<br />
generation may be averted in future.<br />
3.14.5 The cost of Refurbishment of Dakpathar Barrage is Rs 672.21 lacs. The work is to be<br />
carried out under World Bank funded DRIP (Dam Rehabilitation and Improvement<br />
Project) Scheme. The expenditure shall be done in the year 2013-14 and 2014-15 in<br />
the ratio of 40:60, subject to approval by the DRIP Authorities. This fund will be<br />
provided as grant to the project.<br />
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3.15 Refurbishment of Maneri Dam at Maneri, Uttrakashi<br />
3.15.1 Maneri Dam is situated across river Bhagirathi at Maneri, 15 Km towards Gangotri<br />
from district Uttarkashi. It is a 39 m high concrete gravity dam with 4 nos. ogee<br />
spillways having crest elevation at 1280.5 m, each 13 m wide, separated by 4 m wide<br />
piers and followed by a roller bucket at an elevation of 1261 m.<br />
3.15.2 The power intake consists of 4 bays with sill beam level at the elevation of 1283.25<br />
m and is located on left bank of river and designed <strong>for</strong> a maximum discharge of 99<br />
cumecs. Out of this discharge 70 cumec is carried out through 8.86 Km long head<br />
race tunnel <strong>for</strong> power generation at Tiloth Power House (90 MW) & rest is<br />
discharged through flushing tunnel. The capacity of the dam reservoir is 0.6 million<br />
cubic meters.<br />
3.15.3 Maneri Bhali Stage-I (3 x 30 MW) was commissioned in the year 1984 and it was<br />
constructed by UP Irrigation Department and financed by UPSEB. Since then<br />
Operation & Maintenance was carried out by Irrigation Department but since<br />
19.10.08, the Operation & Maintenance of Maneri Dam has been taken over from<br />
Irrigation department by <strong>UJVN</strong> Ltd.<br />
3.15.4 During its life, the Maneri Dam has faced several floods including the disastrous<br />
flood in August 1978 and due to this flood the reservoir got silted fully up to crest<br />
and since then, the total sediment load carried by the river has been passing through<br />
the spillway. Further, due to heavy floods in August and September, 2010, the sill<br />
beam of gates and other associated structures have got damaged severely.<br />
3.15.5 There is an acute bend just upstream of dam spillway structure with a reverse acute<br />
bend about 50 m downstream of spillway structure. In addition to this a protruding<br />
rock cliff exists on the left bank downstream of spillway/dam axis. The above<br />
topographical features combined with floods induce the asymmetrical flow of water<br />
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in the dam structure in the Upstream as well as Downstream sides. Moreover, the<br />
rolling down boulders along with heavy sediment load pass through the spillway,<br />
which often damages the surface of spillway and roller bracket.<br />
3.15.6 The refurbishment shall prevent the leakage of water from Maneri Dam, during lean<br />
season, which shall be utilized <strong>for</strong> generating more electricity. Further, its<br />
refurbishment is essential in view of its life extension and hassle free operation.<br />
Repair of damaged structures/components of Maneri Dam will certainly prevent<br />
further deterioration of structures/components so that threat to these structures<br />
and any loss of power generation may be averted in future.<br />
3.15.7 The cost <strong>for</strong> Refurbishment of Maneri Dam is Rs 453.24 lacs. The work is to be<br />
carried out under World Bank funded DRIP (Dam Rehabilitation and Improvement<br />
Project) Scheme. The expenditure shall be done in the year 2013-14 and 2014-15 in<br />
the ratio of 40:60, subject to approval by the DRIP Authorities. This fund will be<br />
provided as grant to the project.<br />
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3.16 Special Closure Works of Civil & Hydro Mechanical Structures <strong>for</strong><br />
Yamuna Hydel Scheme Stage–I (Part-I&II) & Stage-IV<br />
3.16.1 Yamuna Hydroelectric Scheme Stage-I at Dakpathar,46 Kms from <strong>Dehradun</strong> was<br />
launched in 1960 and completed in 1965. Under this scheme the barrage has been<br />
constructed across the river Yamuna at Dakpathar <strong>for</strong> diverting the discharge of<br />
Yamuna River through a Power Channel of 198 cumes capacity <strong>for</strong> power generation<br />
through two nos. Power Houses of 33.75 MW and 51 MW capacities located at<br />
Dhakrani and Dhalipur respectively.<br />
3.16.2 Under Yamuna Hydel Scheme Stage-IV, Kulhal Power Station constructed during the<br />
period 1970-75, the tail race discharge of Dhalipur Power House along with<br />
discharge of Asan River was picked up by another barrage constructed across river<br />
Asan just downstream of Dhalipur Power House and further the water was carried<br />
through a 4 Km long power channel to utilize it <strong>for</strong> power generation at Kulhal Power<br />
House with installed capacity of 30 MW. Since commissioning of the project the<br />
channel was operated and maintained by Irrigation Department. From the midnight<br />
of 30/4/2010 it has been taken over by <strong>UJVN</strong> <strong>Limited</strong> and since then it is being<br />
operated and maintained by <strong>UJVN</strong> Ltd.<br />
3.16.3 Closure <strong>for</strong> special repair of submerged parts of Dakpathar and Asan Barrages,<br />
Power channel and hydro mechanical components is necessary as the above said<br />
projects run throughout the year without any interruption except in high flood<br />
condition. As such, the routine maintenance of submerged parts of structures cannot<br />
be carried out and a lot of wear & tear of very serious nature in civil structures as<br />
well as hydro-mechanical equipment takes place every year. To inspect & maintain<br />
such parts, regular closures have not been taken since the commissioning of this<br />
project. Last closure was allowed <strong>for</strong> Dakpathar Barrage & Asan Barrage in Jan, 2005<br />
and Feb, 2005. Since then submerged structure/ parts could not be repaired. Lining<br />
of power channel is severely damaged and bed of the channel needs to be repaired.<br />
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Any delay in the repair of power channel is not af<strong>for</strong>dable in view of expected<br />
extensive damage to the components leading to loss of generation from projects.<br />
3.16.4 The cost of repair work is as under:<br />
Lot-1 (Dakpathar Barrage & Power channel upto silt ejector & escape channel, Rs<br />
410.327 lacs.<br />
Lot-2 Power channel from silt ejector Dakpathar to Skew Bridge Dhalipur<br />
including Dhakrani Power House, Rs 633.066 Lacs.<br />
Lot-3 Power channel from Skew bridge Dhalipur to intake of Dhalipur Power<br />
House including Dhalipur PH complex, Rs 203.297 lacs.<br />
Lot-4 Closure works of Yamuna Hydel Scheme stage IV (From Asan Barrage to<br />
Kulhal Power House, Rs 426.467 Lacs.<br />
3.16.5 As such, the total cost <strong>for</strong> Special Closure Works of Civil & Hydro Mechanical<br />
Structures <strong>for</strong> Yamuna Hydel Scheme Stage–I (Part-I&II) & Stage-IV is Rs 1673.15 lacs<br />
(approx.). Closure works shall be carried out after obtaining approval from Govt. of<br />
Uttarakhand.<br />
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3.17 Closure of Chilla HEP <strong>for</strong> Special Repair of Power Channel, Submerged<br />
Parts of Structures & Hydro-Mechanical Components of Virbhadra<br />
Barrage, Pashulok, Rishikesh<br />
3.17.1 Chilla HEP is one of the major HEP of <strong>UJVN</strong> Ltd. with an Installed capacity of 144 MW.<br />
The project is RoR scheme on river Ganga. After commissioning of Tehri and<br />
Koteshwar Dam, the project utilizes the water released from these upstream<br />
projects continuously. Chilla HEP runs throughout the year without any interruption,<br />
except in high flood condition <strong>for</strong> shorter duration. Hence the routine maintenance<br />
of submerged parts of structures is not possible. To inspect & maintain such parts,<br />
periodic closures have been taken since commissioning of the project. However<br />
since the year 2003, no closure has been allowed due to increasing gap between<br />
demand & supply of power in the State and hence the submerged parts of structures<br />
have undergone intensive damage, especially lining of power channel, right afflux<br />
bund, trash rack, piers & floor of barrage, silt excluder tunnels and Under Sluice<br />
Gates specially Gate #1. As such it has become imperative to repair the said<br />
structures/equipment.<br />
3.17.2 Pashulok barrage proposed <strong>for</strong> refurbishment have spent a life of approx. 30 years.<br />
Since the commissioning of the project, it is continuously under operation <strong>for</strong><br />
diverting water to generating plants. Every year it has encountered heavy floods<br />
during monsoon period which carries heavy logs and rolling boulders. With the<br />
passage of time and continuous operation a lot of defects in the installed system<br />
have developed. The sills and other components of Pashulok Barrage have gone<br />
weary.<br />
3.17.3 Since no major repair works have been carried out on this barrage so far, it is<br />
essentially required to carry out the said repair <strong>for</strong> hassle free operation. The repair<br />
shall prevent the leakage of water from the barrage during lean season which would<br />
be utilized <strong>for</strong> generating more electricity. Repair of damaged structure/component<br />
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of the Barrage will certainly prevent further deterioration of structure/component so<br />
that threat to these structures and any loss of power generation may be averted in<br />
future.<br />
3.17.4 The cost <strong>for</strong> Special Repair of Power Channel, Submerged Parts of Structures &<br />
Sr.<br />
No.<br />
Hydro-Mechanical equipment of Virbhadra Barrage is Rs 645 lacs. Closure works<br />
shall be carried out after obtaining approval from Govt. of Uttarakhand.<br />
Table 73 : Summary of expenses proposed under DRIP Scheme and Closure Works<br />
(in Rs. Lakh)<br />
Name of Work Amount FY14 FY15 Sources<br />
1 Refurbishment of Asan Barrage, at<br />
Dhalipur (<strong>Dehradun</strong>)<br />
2 Refurbishing of Ichari Dam, at Ichari, Koti<br />
(<strong>Dehradun</strong>)<br />
3 Rehabilitation Work of Virbhadra<br />
Barrage, Pashulok, Rishikesh.<br />
4 Refurbishment of Dakpathar Barrage, at<br />
Dakpathar (<strong>Dehradun</strong>)<br />
5 Refurbishment of Maneri Dam at Maneri,<br />
Uttrakashi<br />
6 Special Closure Works of Civil & Hydro<br />
Mechanical Structures <strong>for</strong> Yamuna Hydel<br />
Scheme Stage–I (Part-I&II) & Stage-IV.<br />
7 Closure of Chilla HEP <strong>for</strong> Special Repair of<br />
Power Channel, Submerged Parts Of<br />
Structures & Hydro-Mechanical<br />
Components of Virbhadra Barrage,<br />
Pashulok, Rishikesh.<br />
535.32 214.13 321.19 Grant<br />
under<br />
2237.57 895.03 1342.54 DRIP<br />
Scheme<br />
625.81 250.32 375.49<br />
672.21 268.88 403.33<br />
453.24 181.30 271.94<br />
1673.15<br />
645.00<br />
1673.15<br />
645.00<br />
Debt<br />
Equity<br />
ratio of<br />
70:30<br />
Total 6842.30 4127.81 2714.49<br />
Note: The works proposed to be funded under DRIP (Dam Rehabilitation and Improvement<br />
Project) Scheme will be carried out only if approved by DRIP authorities. Similarly the Closure<br />
works will be carried out after obtaining approval from Govt. of Uttarakhand. The fund to be<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
provided under DRIP will be in the <strong>for</strong>m of grant to <strong><strong>UJVN</strong>L</strong> and so the capital cost of such<br />
projects has also not been included in the capital expenditure plan proposed in this <strong>Business</strong><br />
<strong>Plan</strong>.<br />
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4 MAJOR SHUTDOWN PLAN OF POWER<br />
STATIONS<br />
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4.1 Major Shutdown <strong>Plan</strong> of Power Stations<br />
4.1.1 Availability of a generating unit is dependent on the outages taken <strong>for</strong> the unit, both<br />
<strong>for</strong>ced and planned. While the <strong>for</strong>ced outages are minimized by having a robust<br />
maintenance plan, the planned outages are necessary <strong>for</strong> the smooth functioning of<br />
the unit. Either or all the following is included in an outage:<br />
Schedule Preventive Measures<br />
Audit History based Maintenance<br />
Overall Operational Constraints<br />
Technological Upgradation<br />
Per<strong>for</strong>mance Improvement Measures<br />
Statutory Compliances<br />
Life Sustenance, Extension, Enhancement Actions<br />
4.1.2 For enhancing the life of the plant and to get generation on sustained basis from the<br />
power station, timely maintenance of the power station and replacement of old<br />
equipment is essential. Most of the Power Stations of <strong>UJVN</strong> <strong>Limited</strong> are quite old and<br />
their units, auxiliaries and associated systems need major repair/renovation,<br />
modernization and uprating <strong>for</strong> enhancing the Generation output, <strong>Plan</strong>t Availability<br />
and to cope-up with the technological changes taking place from time to time.<br />
Identifying the need and importance of RMU of Old Power Stations, <strong>UJVN</strong> <strong>Limited</strong> is<br />
proactively taking up RMU of its different Power Stations.<br />
4.1.3 Considering the present power requirement of Uttarakhand state, <strong>UJVN</strong> Ltd. has<br />
staggered the RMU of its Power Stations and the RMU is being done in phases. The<br />
outages of various units during routine annual maintenance are staggered and<br />
planned based on expected generation from various units and criticality of the<br />
outage requirement. The outage plan may change based on the exigencies of the<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
business. The proposed outage plan <strong>for</strong> the various generating units of <strong>UJVN</strong> <strong>Limited</strong><br />
during the control period is shown in the table below:<br />
Table 74 : Outage <strong>Plan</strong> during the Control Period <strong>for</strong> <strong>UJVN</strong> <strong>Limited</strong><br />
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5 SUMMARY<br />
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5.1 Capital Expenditure & Capitalization<br />
5.1.1 <strong>Plan</strong>t-wise and year-wise capital expenditure of <strong>UJVN</strong> <strong>Limited</strong> and its capitalization<br />
during the control period is summarised in the table below:<br />
Table 75: Capex & Capitalization during the control period - <strong>UJVN</strong> <strong>Limited</strong><br />
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5.1.2 <strong>Plan</strong>t-wise and year-wise Debt and Equity contribution <strong>for</strong> capital expenditure of<br />
<strong>UJVN</strong> <strong>Limited</strong> is summarised below:<br />
Table 76: Debt & Equity <strong>for</strong> Capital Expenditure during the control period - <strong>UJVN</strong> <strong>Limited</strong><br />
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6 TECHNICAL REPORT OF EXISTING<br />
POWER STATIONS<br />
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6.1 Objective of the Technical Report<br />
6.1.1 The objective of this study is to:-<br />
i. Determine Design Energy<br />
ii. Determine NAPAF (Normative Annual <strong>Plan</strong>t Availability Factor)<br />
iii. To explain special circumstances and abnormal operating conditions which<br />
affect plant availability<br />
iv. To establish that auxiliary consumption and trans<strong>for</strong>mation losses are within<br />
limits set by the Commission<br />
v. To <strong>for</strong>ecast operating parameters such as <strong>Plan</strong>t Availability, Auxiliary and<br />
Trans<strong>for</strong>mation losses <strong>for</strong> the control period<br />
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6.2 TECHNICAL REPORT OF TILOTH POWER STATION<br />
6.2.1 Introduction<br />
6.2.1.1 Tiloth Hydro Power Station with an installed capacity of 90 MW (3x30 MW) is a run<br />
of river scheme constructed on river Bhagirathi, a major tributary of river Ganga<br />
and situated in District Uttarkashi of Uttarakhand state. The scheme consists of a<br />
39 m high concrete diversion dam. The river inflows are diverted through intake<br />
structure with sedimentation basin into a concrete lined head race tunnel of 6.5 km<br />
long and 6 m dia. The head race tunnel ends at the 69 m high and 11m dia. surge<br />
shaft, where the water is fed through 415 m long 3.8/2.5 m dia. underground<br />
penstocks which was trifurcated to feed all the three machines installed in the<br />
Power Station.<br />
6.2.1.2 There are three generating units having vertical Francis turbine directly coupled<br />
with synchronous generator. The turbine output is 31.6 MW <strong>for</strong> a rated net head of<br />
145 m. The generators are designed <strong>for</strong> a nominal output of 34 MVA with lagging<br />
power factor of 0.9 and class “B” insulation<br />
6.2.1.3 This Power Station was commissioned in the year 1984. Due to continuous<br />
operation of machines <strong>for</strong> the past 28 years in silt laden water, efficiency of<br />
machines has substantially decreased and availability of machines has been<br />
adversely affected even in spite of best and timely maintenance and adoption of<br />
effective operational strategy.<br />
6.2.2 Determination of Design Energy<br />
6.2.2.1 Tiloth Hydro Power Station is a run-of-river type plant. For computing the Design<br />
Energy two methodologies have been considered i.e. (i) on the basis of average of<br />
10 daily discharges as per provision <strong>for</strong> calculation of NAPAF <strong>for</strong> Run-of-river type<br />
plants as prescribed in UERC MYT 2011 Regulations “To be determined plant-wise,<br />
based on 10-day Design Energy data, moderated by past experience where<br />
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available / relevant ”and (ii) the maximum generation possible from the Tiloth<br />
Power Station considering that there were no machine and other outages. Due to<br />
non-availability of 90% dependable 10 daily inflows pattern as approved in the DPR<br />
of the project, Design Energy and NAPAF have been calculated on the basis of<br />
available past reliable 10 daily discharge data.<br />
(i) On the basis of Average of 10 daily discharges<br />
Reliable 10 daily (average) discharge data <strong>for</strong> Tiloth Power Station is available<br />
<strong>for</strong> the period April 2000 to March 2012 and the same has been considered<br />
<strong>for</strong> determination of 90% dependable year and Design Energy (Data is<br />
provided in the Annexure 1). Reliable data <strong>for</strong> periods prior to April 2000 is<br />
not available with <strong>UJVN</strong> <strong>Limited</strong>. On considering the average daily discharge<br />
of the year <strong>for</strong> the same period, the 90% dependable year is found to be<br />
2008-09, as given in the table below:<br />
Table 77: 90% dependable year – Tiloth Power Station<br />
Sl. No.<br />
10 Daily<br />
Discharge<br />
Average<br />
Year %<br />
Dependability<br />
1 44.58 2011-12 8.3%<br />
2 43.76 2010-11 16.7%<br />
3 42.67 2007-08 25.0%<br />
4 42.39 2003-04 33.3%<br />
5 42.10 2006-07 41.7%<br />
6 39.69 2004-05 50.0%<br />
7 39.60 2005-06 58.3%<br />
8 39.54 2002-03 66.7%<br />
9 38.97 2009-10 75.0%<br />
10 35.37 2000-01 83.3%<br />
11 35.05 2008-09 91.7%<br />
12 32.62 2001-02 100.0%<br />
For calculation of power following <strong>for</strong>mula has been used:<br />
Power = Head x Flow x Gravity x Turbine Efficiency x Generator Efficiency<br />
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Where power is measured in Watts, head in metres, flow in litres per second,<br />
and acceleration due to gravity in metres per second per second. The<br />
acceleration due to gravity is approximately 9.81 metres per second per<br />
second.<br />
For computation of possible energy generation corresponding to the<br />
discharge considered, generator and turbine efficiencies have been<br />
considered as 0.97 and 0.92 as per the past design records available with<br />
<strong>UJVN</strong> <strong>Limited</strong> Design Energy estimation is sensitive to these assumptions. The<br />
plant has been in operation <strong>for</strong> past 28 years and it is quite possible that<br />
these parameters may have deteriorated from their designed values. In the<br />
absence of detailed technical study on the present efficiency levels of<br />
generator and turbine of Tiloth Power Station, <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> the present<br />
exercise is constrained to use these efficiency levels <strong>for</strong> computational<br />
purpose, though the actual efficiency levels are expected to be much lower<br />
than the designed values.<br />
The energy generation corresponding to the 10 (ten) daily discharge <strong>for</strong><br />
2008-09 with 95% of the Installed capacity is given in the table below:<br />
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Table 78: Discharge & Generation Data – Tiloth Power Station<br />
Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh)<br />
(cumecs) (meter) (kW)<br />
1 April-I 27.7 147.5 35,803.3 85,92,800.2<br />
2 April-II 39.1 147.5 50,427.1 1,21,02,500.6<br />
3 April-III 53.0 147.5 68,384.9 1,64,12,381.6<br />
4 May-I 49.9 147.5 64,406.5 1,54,57,557.2<br />
5 May-II 63.9 147.5 82,534.8 1,98,08,346.0<br />
6 May-III 68.6 147.5 88,634.7 2,25,72,000.0<br />
7 June-I 62.2 147.5 80,375.8 1,92,90,181.0<br />
8 June-II 37.5 147.5 48,479.8 1,16,35,160.3<br />
9 June-III 33.2 147.5 42,848.6 1,02,83,654.5<br />
10 July-I 38.5 147.5 49,706.6 1,19,29,572.3<br />
11 July-II 15.2 147.5 19,641.7 47,14,000.2<br />
12 July-III 5.4 147.5 6,929.5 18,29,382.9<br />
13 Aug-I - 147.5 - -<br />
14 Aug-II - 147.5 - -<br />
15 Aug-III - 147.5 - -<br />
16 Sept-I 6.2 147.5 7,996.9 19,19,256.0<br />
17 Sept-III 41.9 147.5 54,062.0 1,29,74,889.7<br />
18 Sept-III 61.4 147.5 79,329.8 1,90,39,156.1<br />
19 Oct-I 69.0 147.5 89,073.8 2,05,20,000.0<br />
20 Oct-II 64.1 147.5 82,793.0 1,98,70,327.5<br />
21 Oct-III 54.5 147.5 70,338.4 1,85,69,336.6<br />
22 Nov-I 48.1 147.5 62,168.7 1,49,20,487.8<br />
23 Nov-II 44.0 147.5 56,821.5 1,36,37,161.6<br />
24 Nov-III 41.0 147.5 52,911.5 1,26,98,762.2<br />
25 Dec-I 37.4 147.5 48,283.6 1,15,88,054.4<br />
26 Dec-II 34.7 147.5 44,829.4 1,07,59,052.3<br />
27 Dec-III 31.9 147.5 41,156.6 1,08,65,350.6<br />
28 Jan-I 29.5 147.5 38,095.4 91,42,885.7<br />
29 Jan-II 27.8 147.5 35,835.6 86,00,547.9<br />
30 Jan-III 26.8 147.5 34,541.8 91,19,022.8<br />
31 Feb-I 26.1 147.5 33,710.2 80,90,440.4<br />
32 Feb-II 24.7 147.5 31,928.2 76,62,768.3<br />
33 Feb-III 24.5 147.5 31,607.3 60,68,605.1<br />
34 March-I 24.8 147.5 32,075.4 76,98,097.8<br />
35 March-II 25.0 147.5 32,236.8 77,36,836.2<br />
36 March-III 25.4 147.5 32,800.9 86,59,430.3<br />
Annual Energy Generation<br />
39,47,68,006.1<br />
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Table 79: Design Energy: Tiloth Power Station<br />
Sr. No Particulars Unit Value<br />
1 Generation Lost due to uncontrollable situation % 6.1%<br />
2 Generation loss due to uncontrollable situation kWh 24156595.35<br />
3 Design Energy kWh 370611410.70<br />
4 Design Energy MUs 370.61<br />
5 Availability of FY 08-09 % 72%<br />
While determining Design Energy, a 6.1% (based on losses experienced<br />
during the period <strong>for</strong> which the data is available) reduction in the energy<br />
generation has been considered. This reduction has been considered to take<br />
into account generation loss experienced due to uncontrollable factors such<br />
as <strong>for</strong>ced stoppages of machines and outages to prevent damage to the<br />
machines due to heavy silting during flash floods, flood passing and grid<br />
failure etc. These losses represent Hydrological risk and other uncontrollable<br />
risks which <strong>UJVN</strong> <strong>Limited</strong> cannot control in spite of its robust operating<br />
procedures. This figure of 6.1% has been determined considering generation<br />
loss on account of uncontrollable factors as a percentage of maximum<br />
possible generation without any unit and other outages <strong>for</strong> the period 2000-<br />
12 <strong>for</strong> which data is available with <strong>UJVN</strong> <strong>Limited</strong>. The details of these losses<br />
are provided in the table below.<br />
Table 80: Uncontrollable Losses – Tiloth Power Station<br />
Sr. No % losses B/D of<br />
Equipment<br />
(1)<br />
1<br />
2<br />
Flushing &<br />
Choking<br />
(2)<br />
System<br />
Condition<br />
(3)<br />
Flood<br />
Passing &<br />
Any Other<br />
Reason (4)<br />
Total (5)<br />
Gross losses as % of Max.<br />
Grosss Generation 2.1% 5.5% 0.3% 0.3% 8.2%<br />
Losses due to uncontrollable<br />
factors (5)-(1) 6.1%<br />
(ii) On the basis of Maximum possible plant generation<br />
In view of the limited data size, <strong>UJVN</strong> <strong>Limited</strong> has also considered an alternate<br />
approach of computing Design Energy on the basis of actual gross generation<br />
and generation lost on account of various operational & hydrological reasons<br />
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since 2000-01, <strong>for</strong> which the data is available. The loss of generation (possible<br />
additional generation lost by <strong>UJVN</strong> <strong>Limited</strong>) is on account of (i) Equipment<br />
break down (ii) Flushing and Choking (iii) System Conditions (iv) Flood passing<br />
and other reasons. <strong>UJVN</strong> <strong>Limited</strong> computes on a daily basis, the generation<br />
opportunity missed by it on account of these reasons. Thus, the maximum<br />
energy that Tiloth Power Station possibly could have generated (with 100%<br />
Unit availability and with no generation loss on account of any reason) is the<br />
gross generation by its Units and the generation loss suffered by it. This is an<br />
equally good approach <strong>for</strong> an existing plant <strong>for</strong> computing Design Energy<br />
when compared with the method of computing Design Energy on the basis of<br />
river discharge data as it is based on existing unit efficiencies instead of their<br />
design values, considers the impact of other project design related issues and<br />
also operational restrictions imposed on the plant. For example it was not<br />
anticipated that there shall be huge quantum of generation loss from Tiloth<br />
Power Station on account of erosion of underwater parts of turbines during<br />
the monsoon period, as a result of which the plant will have to remain under<br />
shutdown during heavy monsoon period. However, the Power Station is run<br />
on partial load during monsoon period as per the power requirements of the<br />
state, provided the silt content is within permissible limit.<br />
The maximum possible year wise generation has been computed in the table<br />
below:<br />
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Table 81: Year wise Maximum Possible Generation (MU) – Tiloth Power Station<br />
Sr. no.<br />
Actual Gross<br />
Generation<br />
(MU)<br />
Generation<br />
Loss (MU)<br />
Maximum<br />
Possible<br />
Generation<br />
(MU)<br />
Year %<br />
Dependabi<br />
lity<br />
1 457.46 153.05 610.51 2002-03 8.33<br />
2 372.64 196.54 569.18 2001-02 16.67<br />
3 516.11 28.58 544.69 2011-12 25.00<br />
4 488.52 52.19 540.71 2003-04 33.33<br />
5 504.41 5.60 510.00 2010-11 41.67<br />
6 466.14 6.83 472.97 2007-08 50.00<br />
7 467.49 3.32 470.82 2006-07 58.33<br />
8 456.54 13.47 470.02 2004-05 66.67<br />
9 456.30 3.54 459.84 2005-06 75.00<br />
10 449.08 2.95 452.03 2009-10 83.33<br />
11 403.80 15.93 419.74 2008-09 91.67<br />
12 408.52 3.66 412.18 2000-01 100.00<br />
On re-arranging the data in the descending order and considering the 90%<br />
dependable year, the Design Energy <strong>for</strong> the Tiloth Power Station is computed<br />
to be 394.05 MUs as given in the table below:<br />
Table 82: Design Energy – Tiloth Power Station<br />
Sr. No. Particular Unit Value<br />
1 Dependable Year FY 2008-09<br />
2 Maximum Possible Generation MUs 419.74<br />
3 <strong>Plan</strong>t Availability <strong>for</strong> FY 2008-09 % 72%<br />
4 Energy losses due to uncontrollable factors % 6.1%<br />
5 Energy losses due to uncontrollable factors MUs 25.68<br />
6 Design Energy (2)-(5) MUs 394.05<br />
6.2.3 Determination of NAPAF<br />
6.2.3.1 The Actual average plant availability during the last 12 years is given in the table<br />
below:<br />
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Sr. No (1)<br />
Table 83: <strong>Plan</strong>t Availability during FY 2000 - 12 – Tiloth Power Station<br />
Month (2)<br />
Total<br />
Running<br />
Hrs. of all<br />
the units<br />
(Hrs.) (3)<br />
Reserve<br />
Outage<br />
(Hrs.) (4)<br />
Forced<br />
Outage<br />
(Hrs.) (5)<br />
<strong>Plan</strong>ned Maintenance<br />
Annual<br />
Mainten<br />
ance<br />
(Hrs.) (6)<br />
Capital<br />
Major<br />
repairs (Hrs.)<br />
(7)<br />
Total<br />
hours(max)<br />
(Hrs.) (8)<br />
<strong>Plan</strong>t<br />
Availability<br />
% (9)<br />
(Col. 3+Col.<br />
4)/Col.8<br />
1 April 16795 5775 967 2376 7 25920 87%<br />
2 May 25084 983 705 12 0 26784 97%<br />
3 June 23757 1013 962 134 54 25920 96%<br />
4 July 10435 5421 1589 9339 0 26784 59%<br />
5 August 1728 828 221 24007 0 26784 10%<br />
6 Sept 18697 663 291 6268 0 25919 75%<br />
7 Oct 24506 1864 152 262 0 26784 98%<br />
8 Nov 16877 6231 44 2768 0 25920 89%<br />
9 Dec 13096 5496 690 7502 0 26784 69%<br />
10 Jan 10887 7892 789 6471 744 26783 70%<br />
11 Feb 9536 6442 5 8425 0 24408 65%<br />
12 March 11876 5591 22 9295 0 26784 65%<br />
Total 183274 48199 6437 76859 805 315574 73%<br />
6.2.3.2 The Tiloth Power Station experiences excessive <strong>for</strong>ced shut downs during the<br />
monsoon period. The reasons <strong>for</strong> these <strong>for</strong>ced shut downs have been provided in<br />
the section below. The average plant availability during the last 12 years is around<br />
73%. The plant availability is showing sign of improvement and during the last five<br />
years it has improved over the last 12 years’ average.<br />
6.2.4 Special Circumstances and Abnormal Operating Conditions<br />
6.2.4.1 Since its commissioning, Tiloth Power Station operates on base load during<br />
monsoon period and as a peaking station during non-monsoon period when<br />
discharge in the river reduces and Power Station has to be run on partial load. But<br />
due to silting of Maneri Dam, the peaking capacity has also reduced and the Power<br />
Station meets evening and morning peaks at partial load during the lean discharge<br />
period.<br />
6.2.4.2 Study of the available inflow data revealed that the maximum capacity can be<br />
generated between May to September (excluding the heavy monsoon period<br />
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during which machines had to be closed due to high ppm <strong>for</strong> about 45 days). The<br />
Power Station is run on partial capacity between October to April. Lean discharge<br />
period is again utilised <strong>for</strong> planned annual or capital maintenance.<br />
6.2.4.3 The silt which passes through the turbines is highly abrasive and contains<br />
substantial amount of quartzite angular particles which in turn causes severe<br />
damages to the underwater parts of the units, as a result of this machines are<br />
losing efficiency at a rapid pace. Though ef<strong>for</strong>ts are on to combat this problem<br />
since it was detected after few months of operation of Power Station, but no viable<br />
solution could be found except hard coating of underwater parts, changing<br />
material <strong>for</strong> runner manufacturing and also changing design of runner which<br />
slightly improved availability of machines<br />
6.2.4.4 To avoid extensive damage to the underwater parts, every year the underwater<br />
parts of machines are taken out when silt ppm goes beyond 2000 at Maneri Dam<br />
which corresponds to 1200 ppm at bell mouth of penstocks during last week of July<br />
to first week of September. This period is utilised in carrying out necessary<br />
maintenance of the machines. However, the Power Station is sometimes run on<br />
partial load during the monsoon period provided that the silt ppm level is within<br />
the permissible limits. Sometimes machines have to be stopped to allow passing of<br />
excessive discharge of water and trash during flood.<br />
6.2.4.5 Thus it can be concluded that quite a good amount of energy is lost during<br />
monsoon season which is beyond the control of <strong>UJVN</strong> <strong>Limited</strong>. Annual loss of<br />
energy during Monsoon due to flushing and choking over the period 2000-12 has<br />
been calculated in Table 80 & 84, which is around 5.5% of the gross generation and<br />
67% of the total generation loss. Such annual loss should there<strong>for</strong>e be<br />
appropriately accounted <strong>for</strong> while computing Design Energy and <strong>Plan</strong>t Availability.<br />
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6.2.5 <strong>Plan</strong>t Outages and Breakdowns<br />
6.2.5.1 Apart from above facts, when flood recedes lot of silt having substantial quartzite<br />
particles are lodged in cavities and caves on both banks of river which gets<br />
dislodged when level of river starts rising as a result of snow melting during<br />
summer season and is carried to the machines through water conductor system<br />
causing severe damage to under water parts and frequent plant outages which is<br />
beyond the control of <strong>UJVN</strong> <strong>Limited</strong><br />
6.2.5.2 The <strong>for</strong>ced outage data <strong>for</strong> the period 2000-12 has revealed that 25% of the total<br />
energy loss is on this account. The table below provides the details.<br />
Table 84: % Generation Loss on account of various Factors – Tiloth Power Station<br />
Sr. No. Month↓ B/D of<br />
Equipment<br />
(in MU)<br />
Flushing &<br />
Choking<br />
(in MU)<br />
System<br />
Condition<br />
& Grid fail<br />
(in MU)<br />
Flood<br />
passing &<br />
Any Other<br />
Reasons<br />
(in MU)<br />
Total<br />
(in MU)<br />
1 April 20.58 0.00 0.55 0.18 21.31<br />
2 May 10.26 4.26 6.43 0.02 20.96<br />
3 June 9.83 10.36 8.99 0.14 29.31<br />
4 July 33.11 155.83 0.68 2.16 191.78<br />
5 August 1.29 134.63 0.00 5.17 141.09<br />
6 September 40.83 15.86 0.96 0.23 57.88<br />
7 October 4.70 1.70 0.65 0.79 7.84<br />
8 November 0.00 2.53 0.00 0.00 2.53<br />
9 December 1.90 0.00 0.13 0.00 2.04<br />
10 January 0.00 0.22 0.05 0.00 0.28<br />
11 Feburary 0.00 0.00 0.04 0.00 0.04<br />
12 March 0.12 0.00 0.04 10.45 10.62<br />
Total 122.62 325.38 18.51 19.15 485.65<br />
% Generation loss 25% 67% 4% 4% 100%<br />
6.2.6 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
6.2.6.1 The analysis of auxiliary consumption data of past 12 years reveals that the<br />
auxiliary consumption of Tiloth Power Station is around 0.30% of the Gross<br />
Generation. Similarly the trans<strong>for</strong>mation losses of past 9 years <strong>for</strong> which the data is<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
available reveals that these losses are 0.7% of the gross generation. Both auxiliary<br />
consumption and trans<strong>for</strong>mation losses together constitute around 1% of the Gross<br />
Generation.<br />
Table 85: Auxiliary and Trans<strong>for</strong>mation Losses – Tiloth Power Station<br />
6.2.6.2 <strong>UJVN</strong> Ltd. has taken steps to reduce the auxiliary consumption and trans<strong>for</strong>mation<br />
losses. Data of previous 4 years as shown in the table below and which has already<br />
been submitted to Hon’ble UERC, shows improvement in auxiliary and<br />
trans<strong>for</strong>mation losses.<br />
6.2.7 Inferences<br />
6.2.7.1 Design Energy<br />
Sr. No. Particulars Unit Value<br />
1 Total Gross Generation (2000-12) MUs 5447.0<br />
2 Total Aux. consumption (2000-12) MUs 16.5<br />
3 Aux. consumption as a % of Gross Generation % 0.3%<br />
4 Total Gross Generation (2003-12) MUs 4208.4<br />
5 Total Trans<strong>for</strong>mation loss (2003-12) MUs 29.1<br />
6 Trans<strong>for</strong>mation loss as a % of Gross Generation % 0.7%<br />
7 Total Aux. and Trans<strong>for</strong>mation losses (2003-12) MUs 42.3<br />
8<br />
Total Aux. and Trans<strong>for</strong>mation losses as a % of<br />
Gross Generation<br />
% 1.0%<br />
Sr. No Year Trans<strong>for</strong>mation<br />
& line losses<br />
Auxiliary<br />
Consumption<br />
1 FY 2010-11 0.3% 0.2%<br />
2 FY 2009-10 0.3% 0.2%<br />
3 FY 2008-09 0.7% 0.3%<br />
4 FY 2007-08 0.2% 0.3%<br />
5 Average 0.4% 0.3%<br />
Discharge data on 10 daily (average) basis <strong>for</strong> Tiloth Power Station is available <strong>for</strong><br />
the period April 2000 to March 2012. The data <strong>for</strong> each 10 daily discharge of the<br />
year is selected on the basis of 90% dependability. Correspondingly the Design<br />
Energy is calculated (refer the earlier Table 79) to be 370.61 MU after accounting<br />
<strong>for</strong> uncontrollable energy loss of 6.1%. Design Energy was also calculated based<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
on maximum possible generation (refer Table-82) basis which comes to 394.05<br />
MU.<br />
Tiloth Power Station is quite old Power Station and has been under operation in<br />
heavy silt laden water since its commissioning in the year 1984. This long<br />
operation period has resulted into excessive wear and tear of the hydromechanical<br />
and electro-mechanical equipment, thereby causing breakdown of<br />
machines. The condition of these equipment is deteriorating with passage of<br />
time. <strong>UJVN</strong> Ltd. is taking proactive action by taking up comprehensive RMU of<br />
the Project <strong>for</strong> revival and life extension of the project.<br />
Keeping in view the long operational life of the project, it is proposed that<br />
Design Energy <strong>for</strong> Tiloth Power Station may be considered as 394.05 MU which<br />
is the Design Energy computed using the second approach mentioned earlier.<br />
However, after completion of the proposed RMU works of the Project, <strong>UJVN</strong> Ltd.<br />
shall approach the Commission to revise the Design Energy of the Project.<br />
6.2.7.2 NAPAF<br />
UERC has prescribed principle <strong>for</strong> determination of Normative <strong>Plan</strong>t Availability<br />
<strong>for</strong> run of the river plants. Based on the principle given by UERC the annual plant<br />
availability has been calculated in the above table 79, which comes to 72%<br />
Based on actual running hours, reserve hours, <strong>for</strong>ced outage hours and plant<br />
outage hours <strong>for</strong> last 12 years, average annual plant availability has been<br />
calculated to be 73% and this may be taken as NAPAF <strong>for</strong> Tiloth Power Station <strong>for</strong><br />
the base year of the control period.<br />
6.2.7.3 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
As explained in the earlier section these losses are within the limit of 1%<br />
prescribed by the UERC in its regulations <strong>for</strong> Surface hydroelectric power<br />
generating stations with static excitation system.<br />
6.2.8 Projections <strong>for</strong> the control period<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
6.2.8.1 RMU works are proposed <strong>for</strong> the Tiloth Power Station. The proposed RMU works<br />
are likely to result in (i) Extension of the <strong>Plan</strong>t life by around 25 years (ii) Higher<br />
<strong>Plan</strong>t Availability (iii) Increased operating efficiencies of plant. The RMU works <strong>for</strong><br />
the plant is likely to be completed during the control period. The unit wise schedule<br />
<strong>for</strong> implementing RMU is as given below:<br />
Name of<br />
Unit<br />
Date of Start Date of<br />
Commissioning<br />
Unit-1 01.11.13 31.03.15<br />
Unit-2 01.06.15 31.03.16<br />
Unit-3 01.06.16 31.03.17<br />
6.2.9 Impact of RMU works on Energy Generation<br />
6.2.9.1 The proposed RMU of Tiloth Power Station is likely to result in refurbishment of<br />
turbines and generators leading to increased efficiencies.<br />
6.2.9.2 Improvement in sedimentation handling, hard coating of underwater parts of<br />
turbines, reduction in closure period to around 30 days in August could yield<br />
energy gains of the order of 8.5% if the same level of water discharge is considered<br />
pre and post RMU. Primary purpose of RMU is life extension of the project apart<br />
from increase in generation. After RMU, generation will increase from 446 MU to<br />
484 MU (as per DPR) subject to same water discharge.<br />
6.2.10 Availability<br />
6.2.10.1 The annual maintenance schedule and the RMU schedule proposed <strong>for</strong> Tiloth<br />
Power Station under RMU works <strong>for</strong> the Control period is as given below:<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
FY2013-14<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2013 31-03-2015 516 RMU<br />
Interim repair of spherical<br />
15-07-2013 31-07-2013 17<br />
2<br />
valve of Unit 2<br />
15-01-2014 31-01-2014 17 Interim repair of Unit-2<br />
01-02-2014 15-02-2014 15 Interim repair of of Unit 3<br />
3<br />
FY2014-15<br />
15-07-2013 30-08-2013 47<br />
Major repair of Unit-3<br />
(15/7/13 to 30/8/14), Major<br />
repair of Spherical Valve of<br />
Unit-3 (15/7/13 to 15/8/13)<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2013 31-03-2015 516 RMU<br />
Major repair of Unit 2<br />
15-07-2014 30-08-2014 47<br />
2<br />
(15/7/14 to 30/8/14)<br />
15-01-2015 31-01-2015 17 Interim repair of Unit-2<br />
Interim repair of Unit 3,<br />
3<br />
15-07-2014 31-07-2014 17 Interim repair of<br />
spherical valve of Unit 3<br />
15-11-2014 14-12-2014 30 Repair of Unit-3<br />
FY2015-16<br />
Unit No. Start Date End date Days Reasons<br />
1 01-12-2015 30-12-2015 30<br />
Interim repair of of Unit<br />
1, Interim repair of<br />
spherical valve of Unit 1<br />
2 01-06-2015 31-03-2016 305 RMU<br />
01-01-2016 30-01-2016 30 Interim repair of Unit 3<br />
3<br />
Interim repair of Unit 3,<br />
15-07-2015 31-07-2015 17 Interim repair of<br />
spherical valve of Unit 3<br />
6.2.10.2 After implementation of RMU works full capacity of the plant is likely to be<br />
available <strong>for</strong> the entire year except <strong>for</strong> the closure during monsoon period and<br />
annual maintenance period. The plant availability during the control year<br />
considering maintenance schedule given above and <strong>for</strong>ced outages expected<br />
(based on past data) during monsoon months is expected to be as given below:<br />
Particulars Base Year 2013-14 2014-15 2015-16<br />
<strong>Plan</strong>t Availability (%) 73% 76% 54% 64%<br />
The plant availability expected post RMU is likely to be around 80 %.<br />
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6.2.11 Auxiliary Consumption and Trans<strong>for</strong>mation losses<br />
6.2.11.1 As stated above the auxiliary and trans<strong>for</strong>mation losses are within the limits<br />
prescribed by the Commission. During the control period these are expected to be<br />
within the limits prescribed by the Commission.<br />
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6.3 TECHNICAL REPORT OF CHIBRO POWER STATION<br />
6.3.1 Introduction<br />
6.3.1.1 Chibro Hydro Power Station with an installed capacity of 240 MW (4x60 MW) is a<br />
run of river scheme constructed on river Tons, a major tributary of river Yamuna<br />
and is situated in District <strong>Dehradun</strong> of Uttarakhand state. The scheme consists of a<br />
39 m high concrete diversion dam at Ichari. The river inflows are diverted through<br />
intake structure with sedimentation basin into a concrete lined head race tunnel of<br />
6.22 km long and 7 m dia. The head race tunnel ends at the 92 m high and 20m dia.<br />
surge shaft, where the water is fed through 123 m long 3.8 m dia. 4 nos.<br />
underground steel lined penstocks to feed all the four machines installed in Chibro<br />
underground Power Station.<br />
6.3.1.2 There are four generating units having vertical Francis turbine directly coupled with<br />
synchronous generator. The turbine output is 63 MW <strong>for</strong> a rated net head of 110<br />
m. The generators are designed <strong>for</strong> a nominal output of 63 MVA with lagging<br />
power factor of 0.9 and class “B” insulation<br />
6.3.1.3 This Power Station was commissioned in the year 1975. Due to operations of<br />
machines <strong>for</strong> past 36 years in silt laden water, efficiency of machines has<br />
substantially decreased and availability of machines has been adversely affected<br />
even in spite of best and timely maintenance.<br />
6.3.1.4 Though this Power Station has an installed capacity of 4x60 MW but due to<br />
discharge limitations in HRT maximum generating capacity is restricted to around<br />
185 MW. As such while analyzing data <strong>for</strong> calculating Design Energy, installed<br />
capacity of the Power Station has been considered as 185 MW.<br />
6.3.2 Determination of Design Energy<br />
6.3.2.1 Chibro Power Station is a run-of-river type plant. For computing the Design Energy<br />
two methodologies have been considered i.e. (i) on the basis of average of 10 daily<br />
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discharges as per provision <strong>for</strong> calculation of NAPAF <strong>for</strong> Run-of-river type plant<br />
prescribed in UERC MYT 2011 Regulations “To be determined plant-wise, based on<br />
10-day Design Energy data, moderated by past experience where available<br />
/relevant “and (ii) the maximum generation possible from the Chibro Power Station<br />
considering that there were no machine and other outages. Due to non-availability<br />
of 90% dependable 10 daily inflows pattern as approved in the DPR of the project,<br />
Design Energy and NAPAF have been calculated on the basis of available past years<br />
reliable 10 daily discharge data.<br />
(i) On the basis of Average of 10 daily discharges<br />
Reliable 10 daily (average) discharge data <strong>for</strong> Chibro Power Station is<br />
available <strong>for</strong> the period April 1993 to March 2012 and the same has been<br />
considered <strong>for</strong> determination of 90% dependable year and corresponding<br />
Design Energy (Data is provided in the annexure 2). Considering the average<br />
daily discharge data of the years <strong>for</strong> which data was available, the 90%<br />
dependable year is found to be 2004-05, as given in the table below:<br />
Table 86: 90% Dependable year – Chibro Power Station<br />
Sr. No.<br />
10 Daily<br />
Average<br />
Discharge<br />
Year %<br />
Dependability<br />
1 129.08 98-99 5.26<br />
2 112.19 95-96 10.53<br />
3 107.07 97-98 15.79<br />
4 106.70 96-97 21.05<br />
5 103.75 94-95 26.32<br />
6 102.52 02-03 31.58<br />
7 100.13 93-94 36.84<br />
8 97.22 03-04 42.11<br />
9 97.05 11-12 47.37<br />
10 96.95 08-09 52.63<br />
11 92.38 99-00 57.89<br />
12 92.27 05-06 63.16<br />
13 90.88 10-11 68.42<br />
14 88.26 00-01 73.68<br />
15 87.34 01-02 78.95<br />
16 86.76 06-07 84.21<br />
17 85.16 07-08 89.47<br />
18 72.25 04-05 94.74<br />
19 66.10 09-10 100.00<br />
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For computation of possible energy generation corresponding to the<br />
discharge considered, generator and turbine efficiencies have been<br />
considered as 0.973 and 0.92 as per the past design records available with<br />
<strong>UJVN</strong> <strong>Limited</strong>. Design Energy estimation is sensitive to these assumptions.<br />
The plant has been in operation <strong>for</strong> 36 years and it is quite possible that<br />
these parameters may have deteriorated from their design values. In the<br />
absence of detailed technical study on the present efficiency levels of<br />
generator and turbine of Chibro, <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> the present is constrained<br />
to use these efficiency levels <strong>for</strong> computational purpose though the actual<br />
efficiency levels are expected to be lower.<br />
The energy generation corresponding to the 10 (ten) daily discharge <strong>for</strong><br />
2004-05 with 95% of the Installed capacity is given in the table below:<br />
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Table 87: Discharge & Generation Data – Chibro Power Station<br />
Sl.no. Month Net Discharge Net Head Power Potential Energy (kWh)<br />
(cumecs) (meter) (kW)<br />
1 April-I 45.1 110.0 43565.1 10455628.5<br />
2 April-II 48.9 110.0 47235.8 11336590.5<br />
3 April-III 53.0 110.0 51196.3 12287102.2<br />
4 May-I 60.0 110.0 57958.0 13909927.0<br />
5 May-II 77.1 110.0 74476.1 17874256.3<br />
6 May-III 74.4 110.0 71832.8 18963867.2<br />
7 June-I 58.0 110.0 56026.1 13446262.8<br />
8 June-II 84.2 110.0 81334.4 19520264.3<br />
9 June-III 67.0 110.0 64719.8 15532751.9<br />
10 July-I 90.8 110.0 87709.8 21050356.3<br />
11 July-II 78.0 110.0 75345.4 18082905.2<br />
12 July-III 94.3 110.0 91064.4 24040990.6<br />
13 Aug-I 148.6 110.0 143542.7 34450252.7<br />
14 Aug-II 167.1 110.0 161413.1 38739146.8<br />
15 Aug-III 155.5 110.0 150164.0 39643292.1<br />
16 Sept-I 125.7 110.0 121422.1 29141297.2<br />
17 Sept-III 103.7 110.0 100170.8 24040990.6<br />
18 Sept-III 76.7 110.0 74089.7 17781523.4<br />
19 Oct-I 63.3 110.0 61145.7 14674973.0<br />
20 Oct-II 83.3 110.0 80465.1 19311615.4<br />
21 Oct-III 54.1 110.0 52250.0 13794011.0<br />
22 Nov-I 43.1 110.0 41633.2 9991964.3<br />
23 Nov-II 36.5 110.0 35257.8 8461872.3<br />
24 Nov-III 35.6 110.0 34388.4 8253223.4<br />
25 Dec-I 39.0 110.0 37672.7 9041452.6<br />
26 Dec-II 36.4 110.0 35161.2 8438689.1<br />
27 Dec-III 34.7 110.0 33545.4 8855986.9<br />
28 Jan-I 35.7 110.0 34485.0 8276406.6<br />
29 Jan-II 33.7 110.0 32553.1 7812742.4<br />
30 Jan-III 37.1 110.0 35828.6 9458750.4<br />
31 Feb-I 45.9 110.0 44337.9 10641094.2<br />
32 Feb-II 66.7 110.0 64430.0 15463202.2<br />
33 Feb-III 60.9 110.0 58803.3 11290224.1<br />
34 March-I 77.9 110.0 75248.8 18059721.9<br />
35 March-II 102.5 110.0 99011.6 23762792.0<br />
36 March-III 99.9 110.0 96508.9 25478349.7<br />
Annual Energy Generation<br />
611364477<br />
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Table 88: Design Energy- Chibro Power Station<br />
Sr. no Particulars Units Value<br />
1 Generation Loss due to uncontrollable situation % 4.15%<br />
2 Energy loss during monsoon and <strong>for</strong>ced outages kWh 2,53,67,508.8<br />
3 Design Energy kWh 58,59,96,968.1<br />
4 Design Energy (MU) MU 586.0<br />
5 <strong>Plan</strong>t Availability of FY 04-05 % 77.9<br />
While determining Design Energy, a 4.15% (based on losses experienced<br />
during the period <strong>for</strong> which data is available) reduction in the energy<br />
generation has been considered. This reduction has been considered to take<br />
into account generation loss experienced due to uncontrollable factors such<br />
as <strong>for</strong>ced stoppages of machines and outages to prevent damage to the<br />
machines due to heavy silting during flash floods, flood passing and grid<br />
failure etc. These losses represent Hydrological risk and other uncontrollable<br />
risks which <strong>UJVN</strong> <strong>Limited</strong> cannot control in spite of its robust operating<br />
procedures. The figure of 4.15% has been determined considering generation<br />
loss on account of uncontrollable factors as a percentage of maximum<br />
possible generation without any unit and other outages on the basis of past<br />
data of the period 1998-99 to 2011-12. The details of these losses are<br />
provided in the table below.<br />
Table 89: Uncontrollable Losses – Chibro Power Station<br />
Sr. No % losses B/D of<br />
Equipment<br />
(1)<br />
1<br />
2<br />
Flushing &<br />
Choking<br />
(2)<br />
System<br />
Condition<br />
(3)<br />
Flood<br />
Passing &<br />
Any Other<br />
Reason (4)<br />
Total (5)<br />
Gross lossesas a % of Max<br />
Gross Generation 1.54% 2.44% 0.30% 1.41% 5.69%<br />
Losses due to Uncontrollable<br />
factor (5)-(1) 4.15%<br />
(ii) On the basis of Maximum possible plant generation<br />
In view of the limited data size, <strong>UJVN</strong> <strong>Limited</strong> has also considered an alternate<br />
approach of computing Design Energy on the basis of actual gross generation<br />
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and generation lost on account of various operational & hydrological reasons<br />
since 1998-99, <strong>for</strong> which the data is available. The loss of generation (possible<br />
additional generation lost by <strong>UJVN</strong> <strong>Limited</strong>) is on account of (i) Equipment<br />
break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing<br />
and other reasons. <strong>UJVN</strong> <strong>Limited</strong> computes on a daily basis, the generation<br />
opportunity missed by it on account of these reasons. Thus the maximum<br />
that Chibro Power Station possibly could have generated (with 100% Unit<br />
availability and with no generation loss on account of any reason) is the gross<br />
generation by its Units and the generation loss suffered by it. This is an<br />
equally good approach <strong>for</strong> an existing plant <strong>for</strong> computing Design Energy<br />
when compared with the method of computing Design Energy on the basis of<br />
river discharge data as it is based on existing unit efficiencies instead of their<br />
design values, considers the impact of other project design related issues and<br />
also operational restrictions imposed on the plant. The maximum possible<br />
year wise generation has been computed in the table below:<br />
Table 90: Year wise Maximum Possible Generation (MU) – Chibro Power Station<br />
Sr. no.<br />
Actual Gross<br />
Generation<br />
(MU)<br />
Generation<br />
Loss (MU)<br />
Maximum<br />
Power<br />
Generation<br />
(MU)<br />
Year %<br />
Dependabi<br />
lity<br />
1 1,063.50 95.24 1,158.74 1998-99 7.14<br />
2 870.54 33.70 904.24 2002-03 14.29<br />
3 848.96 54.38 903.34 2011-12 21.43<br />
4 837.69 47.57 885.26 2008-09 28.57<br />
5 795.65 83.69 879.35 2010-11 35.71<br />
6 804.96 64.24 869.20 2005-06 42.86<br />
7 824.23 37.18 861.41 2003-04 50.00<br />
8 766.46 88.18 854.64 2000-01 57.14<br />
9 803.08 11.96 815.04 1999-00 64.29<br />
10 743.39 54.36 797.75 2001-02 71.43<br />
11 755.69 27.92 783.61 2007-08 78.57<br />
12 756.05 24.23 780.27 2006-07 85.71<br />
13 636.41 18.97 655.38 2004-05 92.86<br />
14 587.97 27.42 615.39 2009-10 100.00<br />
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On re-arranging the data in the descending order and considering the 90%<br />
dependable year, the Design Energy <strong>for</strong> the Chibro Power Station is<br />
computed to be 628.18 MUs.<br />
Table 91: Design Energy – Chibro Power Station<br />
Sr. No. Particular Unit Value<br />
1 Dependable Year FY 2004-05<br />
2 Maximum Possible Generation MUs 655.38<br />
3 <strong>Plan</strong>t Availability <strong>for</strong> FY 04-05 % 77.92<br />
4 Energy losses due to uncontrollable factors % 4.15%<br />
5 Energy losses due to uncontrollable factors MUs 27.19<br />
6 Design Energy (2)-(5) MUs 628.18<br />
6.3.3 Determination of NAPAF<br />
6.3.3.1 Actual plant availability during the last 12 years is given in table 91 below:<br />
Table 92: <strong>Plan</strong>t Availability during FY 2000 - 12 – Chibro Power Station<br />
Sr. No (1) Month (2)<br />
Total<br />
Running<br />
Hrs. of all<br />
the units<br />
(Hrs.) (3)<br />
Reserve<br />
Outage<br />
(Hrs.) (4)<br />
Forced<br />
Outage<br />
(Hrs.) (5)<br />
<strong>Plan</strong>ned Maintenance<br />
Annual<br />
Mainten<br />
ance<br />
(Hrs.) (6)<br />
Capital<br />
Major<br />
repairs (Hrs.)<br />
(7)<br />
Total hours<br />
(max)<br />
(Hrs.) (8)<br />
<strong>Plan</strong>t<br />
Availability<br />
% (9)<br />
(Col. 3+Col.<br />
4)/Col.8<br />
1 April 13569 9460 475 10336 720 34560 67%<br />
2 May 18596 9259 237 7353 267 35712 78%<br />
3 June 20203 8808 1081 4312 156 34560 84%<br />
4 July 25925 6513 1266 1957 51 35712 91%<br />
5 August 27615 4465 1537 2086 9 35712 90%<br />
6 Sept 25706 7509 199 1146 0 34560 96%<br />
7 Oct 17182 13396 580 4158 396 35712 86%<br />
8 Nov 10594 13597 703 8956 710 34560 70%<br />
9 Dec 8558 13465 779 12166 744 35712 62%<br />
10 Jan 7897 12872 1401 13127 415 35712 58%<br />
11 Feb 7777 11105 75 12891 696 32544 58%<br />
12 March 11739 11605 65 11681 622 35712 65%<br />
Total 195361 122054 8398 90169 4786 420768 75%<br />
6.3.3.2 The Chibro plant experiences excessive <strong>for</strong>ced shut downs during the monsoon<br />
seasons. The reasons <strong>for</strong> these <strong>for</strong>ced shut downs have been provided in the<br />
section below. The average plant availability during the last 12 years is around<br />
75%.<br />
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6.3.4 Special Circumstances and Abnormal Operating Conditions<br />
6.3.4.1 Since its commissioning, this Power Station operates on base load during monsoon<br />
and as a peaking station during non-monsoon period when discharge in the river<br />
reduces and Power Station has to be run on part load. This Power Station meets<br />
evening and morning peaks during lean discharge period as per instructions by<br />
SLDC. But due to silting of Ichari Dam the peaking capacity has also reduced. Lean<br />
discharge period is again utilised <strong>for</strong> planned annual or capital maintenance.<br />
6.3.4.2 Annual loss of energy during Monsoon due to flushing and choking over the period<br />
1998-12 has been calculated in Table no. 89 & 93, which is around 2.4% of the<br />
gross generation and 43% of the total generation loss. Such annual loss should<br />
there<strong>for</strong>e be appropriately accounted <strong>for</strong> while computing Design Energy and plant<br />
availability.<br />
6.3.5 <strong>Plan</strong>t Outages and Breakdowns<br />
6.3.6 Apart from above facts, when flood recedes lot of silt having substantial silt particles<br />
are lodged in cavities and caves on both banks of river which gets dislodged when<br />
level of river starts rising as a result of snow melting during summer season and is<br />
carried to the machines through water conductor system causing severe damage to<br />
under water parts and frequent plant outages which becomes beyond control of<br />
<strong>UJVN</strong> <strong>Limited</strong>.<br />
6.3.6.1 The <strong>for</strong>ced outage data <strong>for</strong> the period 1998-2012 has revealed that 27% of the total<br />
energy loss is on this account. The table below provides the details.<br />
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Table 93: % Generation Loss on account of various Factors – Chibro Power Station<br />
Sr. No. Month↓ B/D of<br />
Equipment<br />
Flushing &<br />
Choking<br />
System<br />
Condition<br />
& Grid fail<br />
Flood<br />
passing &<br />
Any Other<br />
Reasons<br />
Total<br />
1 April 0.75 4.32 0.65 0.27 5.99<br />
2 May 4.03 3.96 2.59 0.00 10.57<br />
3 June 16.01 33.71 5.33 6.93 61.98<br />
4 July 67.24 106.19 12.32 30.07 215.82<br />
5 August 85.99 77.16 11.80 64.57 239.52<br />
6 September 6.55 46.95 1.46 53.06 108.01<br />
7 October 0.35 11.44 1.18 8.49 21.47<br />
8 November 0.00 1.08 0.00 0.98 2.06<br />
9 December 0.00 0.00 0.00 0.00 0.00<br />
10 January 0.00 0.00 0.03 0.58 0.61<br />
11 Feburary 0.00 0.97 0.37 0.00 1.34<br />
12 March 0.00 1.27 0.00 0.39 1.66<br />
Total 180.92 287.04 35.72 165.34 669.03<br />
Generation Lost 27% 43% 5% 25% 100%<br />
6.3.7 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
6.3.7.1 The analysis of auxiliary consumption data of past 14 years (1998–12) reveals that<br />
the auxiliary consumption of Chibro Power Station is around 0.2% of the Gross<br />
Generation. Similarly the trans<strong>for</strong>mation losses of past 9 years (2003-12) <strong>for</strong> which<br />
the data is available has been analysed. The trans<strong>for</strong>mation losses are 1.4% of the<br />
gross generation. Both auxiliary and trans<strong>for</strong>mation losses together constitute<br />
around 1.6 % of the Gross Generation.<br />
Table 94: Auxiliary and Trans<strong>for</strong>mation Losses – Chibro Power Station<br />
Sr. No. Particulars Unit Value<br />
1 Total Gross Generation (1998-12) MUs 11094.58<br />
2 Total Aux. consumption (1998-12) MUs 25.39<br />
3 Aux. consumption as a % of Gross Generation % 0.23%<br />
4 Total Gross Generation (2003-12) MUs 6847.60<br />
5 Total Trans<strong>for</strong>mation loss (2003-12) MUs 92.95<br />
6 Trans<strong>for</strong>mation loss as a % of Gross Generation % 1.36%<br />
7 Total Aux. and Trans<strong>for</strong>mation losses (2003-12) MUs 104.68<br />
8<br />
Total Aux. and Trans<strong>for</strong>mation losses as % of<br />
Gross Generation<br />
% 1.53%<br />
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6.3.7.2 <strong>UJVN</strong> Ltd. has taken steps to reduce the auxiliary consumption and trans<strong>for</strong>mation<br />
losses. Data of previous 4 years, which has already been submitted to Hon’ble<br />
UERC, as shown below, shows improvement in auxiliary and trans<strong>for</strong>mation losses.<br />
Hence the same may be considered <strong>for</strong> the control period.<br />
Sr. No Year Trans<strong>for</strong>mation<br />
& line losses<br />
Auxiliary<br />
Consumption<br />
1 FY 2010-11 1.3% 0.1%<br />
2 FY 2009-10 1.2% 0.1%<br />
3 FY 2008-09 1.4% 0.2%<br />
4 FY 2007-08 1.6% 0.2%<br />
5 Average 1.4% 0.2%<br />
6.3.8 Inferences<br />
6.3.8.1 Design Energy<br />
The discharge data <strong>for</strong> Chibro Power Station is available on 10 daily (average)<br />
basis <strong>for</strong> the period April 1993 to March 2012. The discharge data <strong>for</strong> each 10<br />
daily of the year is selected <strong>for</strong> the 90% dependable year. Correspondingly the<br />
Design Energy is calculated (refer earlier table no.88) to be 586 MU after<br />
accounting <strong>for</strong> uncontrollable energy loss of 4.15%.<br />
Design Energy was also calculated on the basis of maximum possible generation<br />
(refer earlier Table no. 91) which comes to 628.18 MU.<br />
Chibro Power Station is quite old Power Station and has been under operation<br />
since its commissioning in the year 1975. This long operation period has resulted<br />
into excessive wear and tear of the hydro mechanical and electro mechanical<br />
equipment, thereby causing breakdown of machines. The condition of these<br />
equipment is deteriorating with passage of time. <strong>UJVN</strong> Ltd. is taking proactive<br />
action by taking up comprehensive RMU of the Project <strong>for</strong> revival and life<br />
extension of the project.<br />
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Keeping in view the long operational life of the project, it is proposed that Design<br />
Energy <strong>for</strong> Chibro Power Station may be considered as 628.18 MU which is the<br />
Design Energy computed using the second approach mentioned earlier. However,<br />
after completion of the proposed RMU works of the Project, <strong>UJVN</strong> Ltd. shall<br />
approach the Commission to revise the Design Energy of the Project.<br />
6.3.8.2 NAPAF<br />
UERC has prescribed principle <strong>for</strong> determination of Normative <strong>Plan</strong>t Availability<br />
<strong>for</strong> run of the river plant. Based on the principle given by UERC the annual plant<br />
availability has been calculated in the table no.91 which comes to 77.92%.<br />
Based on actual running hours, reserve hours, <strong>for</strong>ced outage hours and plant<br />
outage hours <strong>for</strong> last 10 years, average annual plant availability has been<br />
calculated, which comes to 75% and this may be taken as NAPAF <strong>for</strong> Chibro<br />
Power Station <strong>for</strong> the base year of the control period.<br />
6.3.8.3 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
The auxiliary and trans<strong>for</strong>mation losses exceed the norms set by UERC <strong>for</strong><br />
underground hydroelectric power generating stations with static excitation<br />
system by 0.3%. As indicated earlier these losses are showing sign of reduction.<br />
<strong>UJVN</strong> <strong>Limited</strong> proposes to take remedial measures during the proposed RMU to<br />
reduce these losses within the prescribed limits prescribed by the Commission.<br />
6.3.9 Projections <strong>for</strong> the control period<br />
6.3.9.1 RMU works are proposed <strong>for</strong> the Chibro Power Station. The proposed RMU works<br />
are likely to result in (i) Extension of the <strong>Plan</strong>t life by around 25 years (ii) Higher<br />
<strong>Plan</strong>t Availability (iii) Increased operating efficiencies of plant. The RMU works <strong>for</strong><br />
the plant is likely to be completed during the control period. The unit wise schedule<br />
<strong>for</strong> implementing RMU is as given below:<br />
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Name of<br />
Unit<br />
Date of Start Date of<br />
Commissioning<br />
Unit-1 01.11.15 31.03.17<br />
Unit-2 01.06.17 31.03.18<br />
Unit-3 01.06.18 31.03.19<br />
Unit 4 01.06.19 31.03.20<br />
6.3.10 Impact of RMU works on Energy Generation<br />
6.3.10.1 Primary purpose of RMU is life extension of the project apart from increase in<br />
generation. After RMU, generation will increase from 865 MU to 942 MU (as per<br />
DPR) subject to same water discharge.<br />
6.3.11 Availability<br />
6.3.11.1 The annual maintenance schedule and the RMU schedule proposed <strong>for</strong> Chibro<br />
Power Station under RMU works <strong>for</strong> the Control period is as given below:<br />
FY 2013-14<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2013 10-12-2013 40 Annual Maintenance<br />
2 14-12-2013 22-01-2014 40 Annual Maintenance<br />
3 27-01-2014 07-03-2014 40 Annual Maintenance<br />
4 13-01-2014 21-02-2014 40 Annual Maintenance<br />
FY 2014-15<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2014 10-12-2014 40 Annual Maintenance<br />
2 14-12-2014 22-01-2015 40 Annual Maintenance<br />
3 27-01-2015 07-03-2015 40 Annual Maintenance<br />
4 13-01-2015 21-02-2015 40 Annual Maintenance<br />
FY 2015-16<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2015 31-03-2017 517 RMU<br />
2 14-12-2015 22-01-2016 40 Annual Maintenance<br />
3 27-01-2016 06-03-2016 40 Annual Maintenance<br />
4 13-01-2016 21-02-2016 40 Annual Maintenance<br />
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6.3.11.2 After implementation of RMU works full capacity of the plant is likely to be<br />
available <strong>for</strong> the year except during monsoon period and annual maintenance<br />
period. The plant availability during the control year considering maintenance<br />
schedule given above and <strong>for</strong>ced outages expected (based on past data) during<br />
monsoon months is expected to be as given below:<br />
Particulars Base Year 2013-14 2014-15 2015-16<br />
<strong>Plan</strong>t Availability (%) 75% 85% 87.5% 79.9%<br />
6.3.11.3 The plant availability expected post RMU is likely to be around 85%.<br />
6.3.12 Auxiliary Consumption and Trans<strong>for</strong>mation losses<br />
6.3.12.1 The normative auxiliary and trans<strong>for</strong>mation losses can be achieved after<br />
implementation of RMU works wherein energy efficient motors, starters, heating,<br />
air conditioning, illumination, power trans<strong>for</strong>mation and switching system would<br />
be adopted. The Chibro Power Station is expected to achieve normative loss level<br />
in the year after the control period. During the control period losses are likely<br />
remain at the existing levels.<br />
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6.4 TECHNICAL REPORT OF DHAKRANI POWER STATION<br />
6.4.1 Introduction<br />
6.4.1.1 The Dhakrani (3X11.25 MW) Power Station is located on the downstream of the<br />
Dakpathar Barrage at a distance of 8 km on the power channel which takes off from<br />
the Barrage constructed on river Yamuna. River Tons is a major tributary of Yamuna<br />
and meets just be<strong>for</strong>e the location of Barrage. Tail water of Khodri Power Station<br />
also falls in Yamuna just upstream of Barrage. The Tail water of this Power Station<br />
feeds the Dhalipur Power Station on the downstream on the same power channel.<br />
6.4.1.2 There are three generating units having vertical Kaplan turbine directly coupled<br />
with synchronous generator. The turbine output is 14300 HP <strong>for</strong> a rated net head<br />
of 19.8 m. The generators are designed <strong>for</strong> a nominal output of 11.25 MW with<br />
lagging power factor of 0.9 and class “B” insulation.<br />
6.4.1.3 This Power Station was commissioned in the year 1965. Due to continuous<br />
operations of machines <strong>for</strong> the past 46 years, efficiency of machines has<br />
substantially decreased and availability of machines has been adversely affected<br />
even in spite of best and timely maintenance and adoption of effective operational<br />
strategy.<br />
6.4.2 Determination of Design Energy<br />
6.4.2.1 Dhakrani is a Run of the river Power Station. For computing the Design Energy two<br />
methodologies have been considered i.e. (i) on the basis of average of 10 daily<br />
discharges as per provision <strong>for</strong> calculation of NAPAF <strong>for</strong> Run-of-river type plant as<br />
prescribed in UERC MYT 2011 Regulations “To be determined plant-wise, based on<br />
10-day Design Energy data, moderated by past experience where available<br />
/relevant” and (ii) the maximum generation possible from the Dhakrani Power<br />
Station considering that there were no machine and other outages. Due to nonavailability<br />
of 90% dependable 10 daily inflows pattern as approved in the DPR of<br />
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the project, Design Energy and NAPAF have been calculated on the basis of<br />
available past reliable 10 daily discharge data.<br />
(i) On the basis of Average of 10 daily discharges<br />
Reliable 10 daily (average) discharge data <strong>for</strong> Dhakrani Power Station is<br />
available <strong>for</strong> the period April 1994 to March 2012 and the same has been<br />
considered <strong>for</strong> determination of 90% dependable year and Design Energy<br />
(This data has been provided in the annexure 3). Reliable data <strong>for</strong> periods<br />
prior to April 1994 is not available with <strong>UJVN</strong> <strong>Limited</strong>. The year wise average<br />
daily discharge data was considered <strong>for</strong> the same period and the 90%<br />
dependable year is found to be 2004-05 as given in table 94 below:<br />
Table 95: 90% Dependable Year– Dhakrani Power Station<br />
Sr. No.<br />
10 Daily<br />
Average<br />
Discharge<br />
Year %<br />
Dependability<br />
1 141.40 98-99 5.56<br />
2 124.86 97-98 11.11<br />
3 122.09 02-03 16.67<br />
4 118.77 96-97 22.22<br />
5 114.33 95-96 27.78<br />
6 111.72 03-04 33.33<br />
7 111.25 05-06 38.89<br />
8 111.03 11-12 44.44<br />
9 108.92 94-95 50.00<br />
10 106.59 08-09 55.56<br />
11 104.96 00-01 61.11<br />
12 104.66 10-11 66.67<br />
13 102.08 99-00 72.22<br />
14 101.51 06-07 77.78<br />
15 100.70 07-08 83.33<br />
16 96.15 01-02 88.89<br />
17 87.39 04-05 94.44<br />
18 75.28 09-10 100.00<br />
For computation of possible energy generation corresponding to the<br />
discharge considered, generator and turbine efficiencies have been<br />
considered as 0.97 and 0.9114 as per the past design records available with<br />
<strong>UJVN</strong> <strong>Limited</strong>. Design energy estimation is sensitive to these assumptions.<br />
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The plant has been in operation <strong>for</strong> past 46 years and it is quite possible that<br />
these parameters may have deteriorated from their designed values. In the<br />
absence of detailed technical study on the present efficiency levels of<br />
generator and turbine of Dhakrani Power Station, <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> the<br />
present exercise is constrained to use these efficiency levels <strong>for</strong><br />
computational purpose though the actual efficiency levels are expected to be<br />
much lower than the designed values.<br />
The energy generation corresponding to the 10 (ten) daily discharge <strong>for</strong><br />
2004-05 with 95% of the Installed capacity is given in the table below:<br />
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Table 96: Discharge & Generation Data – Dhakrani Power Station<br />
Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh)<br />
(cumecs) (meter) (kW)<br />
1 April-I 56.8 19.8 9,754.2 23,41,020.0<br />
2 April-II 59.0 19.8 10,124.1 24,29,791.1<br />
3 April-III 63.9 19.8 10,971.0 26,33,049.9<br />
4 May-I 71.4 19.8 12,266.5 29,43,955.0<br />
5 May-II 84.4 19.8 14,498.0 34,79,508.0<br />
6 May-III 82.8 19.8 14,217.9 37,53,528.2<br />
7 June-I 69.3 19.8 11,906.6 28,57,574.1<br />
8 June-II 103.4 19.8 17,762.0 42,62,870.2<br />
9 June-III 82.5 19.8 14,173.2 34,01,575.7<br />
10 July-I 130.8 19.8 22,462.0 53,90,890.4<br />
11 July-II 119.2 19.8 20,466.9 49,12,045.4<br />
12 July-III 117.6 19.8 20,195.2 53,31,544.8<br />
13 Aug-I 182.9 19.8 31,412.1 75,38,913.5<br />
14 Aug-II 188.0 19.8 32,282.6 76,95,000.0<br />
15 Aug-III 190.9 19.8 32,782.9 84,64,500.0<br />
16 Sept-I 177.6 19.8 30,500.7 73,20,158.9<br />
17 Sept-III 175.4 19.8 30,112.6 72,27,019.2<br />
18 Sept-III 133.7 19.8 22,958.5 55,10,035.0<br />
19 Oct-I 113.6 19.8 19,511.2 46,82,699.3<br />
20 Oct-II 136.4 19.8 23,426.6 56,22,379.6<br />
21 Oct-III 98.4 19.8 16,901.1 44,61,884.1<br />
22 Nov-I 77.2 19.8 13,260.9 31,82,615.1<br />
23 Nov-II 65.3 19.8 11,215.1 26,91,612.5<br />
24 Nov-III 58.2 19.8 9,987.6 23,97,027.4<br />
25 Dec-I 57.0 19.8 9,788.2 23,49,180.0<br />
26 Dec-II 52.6 19.8 9,028.7 21,66,898.3<br />
27 Dec-III 48.1 19.8 8,262.9 21,81,405.0<br />
28 Jan-I 48.8 19.8 8,375.4 20,10,104.0<br />
29 Jan-II 14.2 19.8 2,435.6 5,84,554.4<br />
30 Jan-III - 19.8 - -<br />
31 Feb-I - 19.8 - -<br />
32 Feb-II - 19.8 - -<br />
33 Feb-III - 19.8 - -<br />
34 March-I 36.3 19.8 6,237.0 14,96,869.7<br />
35 March-II 128.3 19.8 22,029.8 52,87,159.2<br />
36 March-III 122.0 19.8 20,945.2 55,29,528.4<br />
Annual Energy Generation<br />
13,21,36,896.3<br />
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Table 97- Design Energy: Dhakrani Power Station<br />
Sr. No Particulars Unit Value<br />
1 Generation Loss due to uncontrollable situation % 7.3%<br />
2 Energy loss during monsoon and <strong>for</strong>ced outages kWh 9633453.9<br />
3 Design Energy kWh 122503442.4<br />
4 Design Energy (MU) MUs 122.5<br />
5 <strong>Plan</strong>t Availability of FY 04-05 % 83.5<br />
While determining Design Energy, a 7.3% (based on losses experienced<br />
during the period <strong>for</strong> which data is available) reduction in the energy<br />
generation has been considered. This reduction has been considered to take<br />
into account generation loss experienced due to uncontrollable factors such<br />
as <strong>for</strong>ced stoppages of machines and outages to prevent damage to the<br />
machines due to heavy silting (and accumulation of trash) during flash floods,<br />
flood passing and grid failure etc. These losses represent hydrological risk and<br />
other uncontrollable risks which <strong>UJVN</strong> <strong>Limited</strong> cannot control in spite of its<br />
robust operating procedures. The figure of 7.3% has been determined<br />
considering generation loss on account of uncontrollable factors as a<br />
percentage of maximum possible generation without any unit and other<br />
outages on the basis of past data of the period 1997-98 to 2011-12. The<br />
details of these losses are provided in the table below:<br />
Table 98: Uncontrollable Losses – Dhakrani Power Station<br />
Sr. No % losses B/D of<br />
Equipment<br />
(1)<br />
1<br />
2<br />
Flushing<br />
&<br />
Choking<br />
(2)<br />
System<br />
Condition<br />
(3)<br />
Flood<br />
Passing &<br />
Any Other<br />
Reason (4)<br />
Total (5)<br />
Gross losses as % of Max<br />
Gross Generation 2.6% 3.6% 0.2% 3.5% 9.9%<br />
Losses due to uncontrollable<br />
factors (5)-(1) 7.3%<br />
(ii) On the basis of Maximum Possible <strong>Plan</strong>t generation<br />
In view of the limited data size, <strong>UJVN</strong> <strong>Limited</strong> has also considered an alternate<br />
approach of computing Design Energy on the basis of actual gross generation<br />
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and generation lost on account of various operational & hydrological reasons<br />
since 1997-98, <strong>for</strong> which the data is available. The loss of generation (possible<br />
additional generation loss to <strong>UJVN</strong> <strong>Limited</strong>) is on account of (i) Equipment<br />
break down (ii) Flushing and choking (iii) System Conditions (iv) Flood passing<br />
and other reasons. <strong>UJVN</strong> <strong>Limited</strong> computes on a daily basis, the generation<br />
opportunity missed by it on account of these reasons. Thus the maximum<br />
energy that Dhakrani Power Station possibly could have generated (with<br />
100% Unit availability and with no generation loss on account of any reason)<br />
is the gross generation by its Units and the generation loss suffered by it. This<br />
is an equally good approach <strong>for</strong> an existing plant <strong>for</strong> computing Design Energy<br />
when compared with the method of computing Design Energy on the basis of<br />
river discharge data as it is based on existing unit efficiencies instead of their<br />
design values, considers the impact of other project design related issues and<br />
also the operational restrictions imposed on the plant. The maximum possible<br />
year wise generation has been computed in table 99 below:<br />
Table 99: Year wise Maximum Possible Generation (MU) – Dhakrani Power Station<br />
Sr. no.<br />
Actual Gross<br />
Generation<br />
(MU)<br />
Generation<br />
Loss (MU)<br />
Maximum<br />
Possible<br />
Generation<br />
(MU)<br />
Year %<br />
Dependabi<br />
lity<br />
1 159.39 55.15 214.54 1998-99 6.67<br />
2 163.83 22.73 186.56 1997-98 13.33<br />
3 173.78 4.79 178.57 2002-03 20.00<br />
4 164.63 10.89 175.52 2005-06 26.67<br />
5 160.31 11.64 171.95 2003-04 33.33<br />
6 152.75 9.76 162.50 2011-12 40.00<br />
7 143.02 18.52 161.53 2010-11 46.67<br />
8 146.52 10.26 156.78 2008-09 53.33<br />
9 143.19 12.92 156.11 2000-01 60.00<br />
10 148.92 4.95 153.87 2007-08 66.67<br />
11 147.35 4.88 152.22 2006-07 73.33<br />
12 107.77 41.48 149.24 1999-00 80.00<br />
13 115.38 22.54 137.92 2001-02 86.67<br />
14 125.90 2.87 128.77 2004-05 93.33<br />
15 105.08 4.72 109.80 2009-10 100.00<br />
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On re-arranging the above data in the descending order and considering the<br />
90% dependability, the Design Energy <strong>for</strong> the Dhakrani Power Station is<br />
computed to be 119.38 MUs as given in table below;<br />
Table 100: Design Energy – Dhakrani Power Station<br />
Sr. No. Particular Unit Value<br />
1 Dependable Year FY 2004-05<br />
2 Maximum Possible Generation MUs 128.77<br />
3 <strong>Plan</strong>t Availability <strong>for</strong> FY 2004-05 % 83.55<br />
4 Energy losses due to uncontrollable factors % 7.3%<br />
5 Energy losses due to uncontrollable factors MUs 9.39<br />
6 Design Energy (2)-(5) MUs 119.38<br />
6.4.3 Determination of NAPAF<br />
6.4.3.1 Actual average plant availability during the last 12 years is given in table below:<br />
Table 101: <strong>Plan</strong>t Availability during FY 2000 - 12 – Dhakrani Power Station<br />
Sr. No (1) Month (2)<br />
Total<br />
Running<br />
Hrs. of all<br />
the units<br />
(Hrs.) (3)<br />
Reserve<br />
Outage<br />
(Hrs.) (4)<br />
Forced<br />
Outage<br />
(Hrs.) (5)<br />
<strong>Plan</strong>ned Maintenance<br />
Annual<br />
Mainten<br />
ance<br />
(Hrs.) (6)<br />
Capital<br />
Major<br />
repairs (Hrs.)<br />
(7)<br />
Total hours<br />
(max)<br />
(Hrs.) (8)<br />
<strong>Plan</strong>t<br />
Availability<br />
% (9)<br />
(Col. 3+Col.<br />
4)/Col.8<br />
1 April 13168 7727 64 4961 0 25920 81%<br />
2 May 16875 7223 194 2492 0 26784 90%<br />
3 June 18275 6630 55 960 0 25920 96%<br />
4 July 22734 3230 76 744 0 26784 97%<br />
5 August 23481 2489 64 750 0 26784 97%<br />
6 Sept 22895 2788 237 0 0 25920 99%<br />
7 Oct 18275 8375 134 0 0 26784 99%<br />
8 Nov 11308 8703 253 5656 0 25920 77%<br />
9 Dec 9564 8704 21 8495 0 26784 68%<br />
10 Jan 8997 9049 626 8112 0 26784 67%<br />
11 Feb 7561 8197 17 8633 0 24408 65%<br />
12 March 10520 6512 167 9585 0 26784 64%<br />
Total 183653 79627 1908 50388 0 315576 83%<br />
6.4.3.2 The plant availability <strong>for</strong> this period is around 83%. The Dhakrani Power Station<br />
experiences excessive <strong>for</strong>ced shut downs during the monsoon period. The reasons<br />
<strong>for</strong> these <strong>for</strong>ced shut downs have been provided in the section below.<br />
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6.4.4 Special Circumstances and Abnormal Operating Conditions<br />
6.4.4.1 Since its commissioning, Dhakrani Power Station operates on base load during<br />
monsoon period and as a peaking station during non-monsoon period when<br />
discharge in the river reduces and Power Station has to be run on partial load. But<br />
due to silting of reservoir of Dakpathar Barrage the peaking capacity has also<br />
reduced and the Power Station meets evening and morning peaks during lean<br />
discharge period as per requirement of SLDC.<br />
6.4.4.2 Study of the available inflow data revealed that the maximum capacity that can be<br />
generated in between May to September and partially between October to April.<br />
Lean discharge period is again utilised <strong>for</strong> planned annual or capital maintenance.<br />
6.4.4.3 Average annual loss of energy during Monsoon due to flushing and choking over<br />
the period 1997-12 has been calculated in Table 98 & 102, which is around 3.6% of<br />
the gross generation and 36% of the total generation loss. Such annual loss should<br />
there<strong>for</strong>e be appropriately accounted <strong>for</strong> while computing Design Energy and plant<br />
availability.<br />
6.4.5 <strong>Plan</strong>t Outages and Breakdowns<br />
6.4.5.1 The <strong>for</strong>ced outage data <strong>for</strong> the period 1997-2012 has revealed that 27% of the<br />
total energy loss is on this account. The table below provides the details.<br />
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Table 102: % Generation Loss on account of various Factors – Dhakrani Power Station<br />
Sr. No. Month↓ B/D of<br />
Equipment<br />
(in MU)<br />
Flushing &<br />
Choking<br />
(in MU)<br />
System<br />
Condition<br />
& Grid fail<br />
(in MU)<br />
Flood<br />
passing &<br />
Any Other<br />
Reasons<br />
(in MU)<br />
Total<br />
(in MU)<br />
1 April 0.74 0.00 0.20 4.13 5.07<br />
2 May 1.98 0.27 0.39 2.77 5.41<br />
3 June 5.14 5.01 0.50 0.67 11.31<br />
4 July 5.45 31.25 1.21 5.67 43.58<br />
5 August 15.82 35.39 0.78 20.57 72.56<br />
6 September 16.01 8.53 0.34 29.69 54.56<br />
7 October 10.47 2.81 0.35 3.08 16.71<br />
8 November 4.54 0.02 0.11 0.12 4.79<br />
9 December 1.91 0.00 0.06 0.67 2.64<br />
10 January 0.20 0.07 0.12 0.10 0.48<br />
11 Feburary 0.56 1.86 0.12 2.85 5.39<br />
12 March 0.59 0.26 0.19 14.56 15.60<br />
Total 63.42 85.45 4.36 84.86 238.09<br />
% Generation Loss 27% 36% 2% 36% 100%<br />
6.4.6 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
6.4.6.1 The analysis of auxiliary consumption data of past 15 years reveals that the<br />
auxiliary consumption of Dhakrani Power Station is around 1.19% of the Gross<br />
Generation. Dhakrani Power Station acts as source of electrical energy <strong>for</strong><br />
providing the auxiliary supply to Chibro, Khodri, Kulhal, Dhalipur Power Stations,<br />
Ichari Dam, Asan Barrage, Dakpathar Barrage and to residential colonies of<br />
Dakpathar, Koti, Dhalipur and Kulhal.<br />
6.4.6.2 For providing these power supplies, various 33 kV lines emanates from Dhakrani<br />
Power Station. This 33 kV network is large and diversified. There are many 33/11<br />
kV and 11kV/0.415 kV trans<strong>for</strong>mers along with 11 kV and LT lines. Consequently<br />
there are trans<strong>for</strong>mation and distribution losses. These losses are getting<br />
accounted as Auxiliary and Trans<strong>for</strong>mation losses. However the analysis of data<br />
post 2008 reveals that these losses have come down and are likely to reduce<br />
further.<br />
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Table 103: Auxiliary and Trans<strong>for</strong>mation Losses – Dhakrani Power Station<br />
Sr. No Particulars Unit Value<br />
1 Total Gross Generation 1997-12) MUs 2157.79<br />
2 Total Aux. consumption (1997-12) MUs 25.71<br />
3 Aux. consumption as a % of Gross Generation % 1.19%<br />
6.4.6.3 <strong>UJVN</strong> Ltd. has taken steps to reduce the auxiliary consumption and trans<strong>for</strong>mation<br />
losses. Data of previous 4 years, which has already been submitted to Hon’ble<br />
UERC, as shown below, shows improvement in auxiliary and trans<strong>for</strong>mation losses.<br />
Sr. No Year Trans<strong>for</strong>mation<br />
& line losses<br />
Auxiliary<br />
Consumption<br />
1 FY 2010-11 2.4% 1.1%<br />
2 FY 2009-10 4.6% 1.5%<br />
3 FY 2008-09 0.3% 1.2%<br />
4 FY 2007-08 1.9% 1.4%<br />
5 Average 2.3% 1.3%<br />
6.4.7 Inferences<br />
6.4.7.1 Design Energy<br />
The discharge data <strong>for</strong> Dhakrani Power Station is available on 10 daily (average)<br />
basis <strong>for</strong> the period April 1994 to March 2012. The data <strong>for</strong> each 10 daily<br />
discharge of the year is selected on the basis of 90% dependability.<br />
Correspondingly the Design Energy is calculated (refer the earlier table 97) to be<br />
122.5 MU after accounting <strong>for</strong> uncontrollable energy loss of 7.3%.<br />
Design Energy was also calculated based on maximum possible generation (refer<br />
Table-100) which comes to 119.38 MU after considering uncontrollable loss of<br />
7.3%.<br />
Dhakrani Power Station is quite old Power Station and has been under operation<br />
since its commissioning in the year 1965. This long operation period has resulted<br />
into excessive wear and tear of the hydro mechanical and electro mechanical<br />
equipment, thereby causing breakdown of machines. The condition of these<br />
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equipments is deteriorating with passage of time. <strong>UJVN</strong> Ltd. is taking proactive<br />
action by taking up comprehensive RMU of the Project <strong>for</strong> revival and life<br />
extension of the project.<br />
Keeping in view the long operational life of the project, it is proposed that Design<br />
Energy <strong>for</strong> Dhakrani Power Station may be considered as 119.38 MU which is the<br />
Design Energy computed using the second approach mentioned earlier. However,<br />
after completion of the proposed RMU works of the Project, <strong>UJVN</strong> Ltd. shall<br />
approach the Commission to revise the Design Energy of the Project.<br />
6.4.7.2 NAPAF<br />
UERC has prescribed principle <strong>for</strong> determination of Normative <strong>Plan</strong>t Availability<br />
<strong>for</strong> run of the river plant. Based on the principle given by UERC the annual plant<br />
availability has been calculated in earlier table 97 which comes to 83.5%.<br />
Based on actual running hours, reserve hours, <strong>for</strong>ced outage hours and plant<br />
outage hours <strong>for</strong> last 12 years plant average annual plant availability has been<br />
calculated in earlier table no. 101 which comes to 83% which may be taken as<br />
NAPAF <strong>for</strong> Dhakrani Power Station <strong>for</strong> base year of the control period.<br />
6.4.7.3 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
The auxiliary and trans<strong>for</strong>mation losses exceed the norms set by UERC <strong>for</strong> surface<br />
hydroelectric power generating stations with rotary excitation system by 7.7%.<br />
The steps are being taken to control losses and improve the loss accounting<br />
procedure. <strong>UJVN</strong> <strong>Limited</strong> proposes to take remedial measures during the<br />
proposed RMU to reduce these losses within the prescribed limits prescribed by<br />
the Commission.<br />
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6.4.8 Projections <strong>for</strong> the control period<br />
6.4.8.1 RMU works are proposed <strong>for</strong> the Dhakrani Power Station. The proposed RMU<br />
works are likely to result in (i) Extension of the <strong>Plan</strong>t life by around 25 years (ii)<br />
Higher <strong>Plan</strong>t Availability (iii) Increased operating efficiencies of plant.<br />
6.4.8.2 The RMU works <strong>for</strong> the plant is likely to be completed during the control period.<br />
The unit wise schedule <strong>for</strong> implementing RMU is as given below:<br />
Name of<br />
Unit<br />
Date of Start Date of<br />
Commissioning<br />
Unit-1 01.10.14 30.06.15<br />
Unit-2 01.10.15 30.06.16<br />
Unit-3 01.10.16 30.06.17<br />
6.4.9 Impact of RMU works on Energy Generation<br />
6.4.9.1 The proposed RMU of Dhakrani Power Station is likely to result in refurbishment of<br />
turbines and generators leading to increased efficiencies. This could yield energy<br />
generation gains of the order of 14 % if the same level of water discharge is<br />
considered pre and post RMU. Primary purpose of RMU is life extension of the<br />
project apart from increase in generation. After RMU, generation will increase from<br />
161 MU to 184 MU (as per DPR) subject to same water discharge.<br />
6.4.10 Availability<br />
6.4.10.1 The annual maintenance schedule and the RMU schedule proposed <strong>for</strong> Dhakrani<br />
Power Station under RMU works <strong>for</strong> the Control period is as given below:<br />
FY2013-14<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2013 15-12-2013 45 Annual Maintenance<br />
2 16-12-2013 29-01-2014 45 Annual Maintenance<br />
3 30-01-2014 15-03-2014 45 Annual Maintenance<br />
FY2014-15<br />
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Unit No. Start Date End date Days Reasons<br />
1 01-10-2014 30-06-2015 273 RMU<br />
2 01-11-2014 15-12-2014 45 Annual Maintenance<br />
3 16-12-2014 29-01-2015 45 Annual Maintenance<br />
FY2015-16<br />
Unit No. Start Date End date Days Reasons<br />
1 16-12-2015 14-01-2016 30 Annual Maintenance<br />
2 01-10-2015 30-06-2016 274 RMU<br />
3 01-11-2015 15-12-2015 45 Annual Maintenance<br />
6.4.10.2 After implementation of RMU works, full capacity of the plant is likely to be<br />
available <strong>for</strong> the entire year except during monsoon period and annual<br />
maintenance period. The plant availability during the control year considering<br />
maintenance schedule given above and <strong>for</strong>ced outages expected (based on past<br />
data) during monsoon months is expected to be as given below:<br />
Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16<br />
<strong>Plan</strong>t Availability (%) 83% 87% 74.67% 67.76%<br />
6.4.10.3 The plant availability expected post RMU is likely to be around 88%.<br />
6.4.11 Auxiliary Consumption and Trans<strong>for</strong>mation losses<br />
6.4.11.1 The normative auxiliary and trans<strong>for</strong>mation losses can be achieved after<br />
implementation of RMU works wherein energy efficient motors, starters, heating,<br />
air conditioning, illumination, power trans<strong>for</strong>mation and switching system would<br />
be adopted. The Dhakrani Power Station is expected to achieve normative auxiliary<br />
consumption and trans<strong>for</strong>mation loss level after completion of RMU works.<br />
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6.5 TECHNICAL REPORT OF DHALIPUR POWER STATION<br />
6.5.1 Introduction<br />
6.5.1.1 The Dhalipur Power Station of 51 MW (3X17 MW) is located on the downstream of<br />
the Dhakrani Power Station at a distance of 5km on the power channel which takes<br />
off from the Dakpathar Barrage. The Power Station was commissioned during<br />
December 1965 to March, 1970. The 5 Km long power channel ends at 42.5 m wide<br />
and 8.8 m deep Fore bay. From <strong>for</strong>e bay three steel lined 53 m long and 5 m dia.<br />
penstocks are laid to feed water to each of the 3 units installed in the Power<br />
Station. The surface Power Station comprising 3 units of 17 MW each is located on<br />
the power channel and the water from the tail race flows into Asan River. The<br />
Power Station's design head is 30.48 m. The Dhalipur Power Station is a low head<br />
scheme located on power channel with a design discharge of 199.2 cum.<br />
There are three generating units having vertical Francis turbine directly coupled<br />
with synchronous generator. The turbine output is 24,000 HP <strong>for</strong> a rated net head<br />
of 30.48 m. The generators are designed <strong>for</strong> a nominal output of 19 MVA with<br />
lagging power factor of 0.9 and class “B” insulation<br />
6.5.1.2 This Power Station was commissioned in the year Dec 1965 to March 1970. Due to<br />
continuous operations of machines <strong>for</strong> past 46 years, efficiency of machines has<br />
substantially decreased and availability of machines has been adversely affected<br />
even in spite of best and timely maintenance and adoption of effective operational<br />
strategy.<br />
6.5.2 Determination of Design Energy<br />
6.5.2.1 Dhalipur Power Station is a run of the river Power Station. For computing the<br />
Design Energy two methodologies have been considered i.e. (i) on the basis of<br />
average of 10 daily discharges <strong>for</strong> calculation of NAPAF <strong>for</strong> Run-of-river type plant<br />
as per provision of UERC MYT 2011 Regulations “To be determined plant-wise,<br />
based on 10-day Design Energy data, moderated by past experience where<br />
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available /relevant” and (ii) the maximum generation possible from the Dhalipur<br />
Power Station considering that there were no machine and other outages. Due to<br />
non-availability of 90% dependable 10 daily inflows pattern as approved in the DPR<br />
of the project, Design Energy and NAPAF have been calculated on the basis of<br />
available past reliable 10 daily discharge data.<br />
(i) On the basis of Average of 10 daily discharges<br />
Reliable 10 daily (average) discharge data <strong>for</strong> Dhalipur Power Station is<br />
available <strong>for</strong> the period April 1994 to March 2012 and the same has been<br />
considered <strong>for</strong> determination of 90% dependable year and Design Energy<br />
(this data is provided in the annexure 4). Reliable data <strong>for</strong> periods prior to<br />
April 1994 is not available with <strong>UJVN</strong> <strong>Limited</strong>. The yearly average daily<br />
discharge data was considered <strong>for</strong> the same period and the 90% dependable<br />
year is found to be 2004-05, as given in the table below:<br />
Table 104: 90% Dependable year – Dhalipur Power Station<br />
Sr. No.<br />
10 Daily<br />
Average<br />
Discharge<br />
Year %<br />
Dependability<br />
1 141.40 98-99 5.56<br />
2 124.86 97-98 11.11<br />
3 122.09 02-03 16.67<br />
4 118.77 96-97 22.22<br />
5 114.33 95-96 27.78<br />
6 111.72 03-04 33.33<br />
7 111.25 05-06 38.89<br />
8 111.03 11-12 44.44<br />
9 108.92 94-95 50.00<br />
10 106.59 08-09 55.56<br />
11 104.96 00-01 61.11<br />
12 104.66 10-11 66.67<br />
13 102.08 99-00 72.22<br />
14 101.51 06-07 77.78<br />
15 100.70 07-08 83.33<br />
16 96.15 01-02 88.89<br />
17 87.39 04-05 94.44<br />
18 75.28 09-10 100.00<br />
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For computation of possible energy generation corresponding to the<br />
discharge considered, generator and turbine efficiencies have been<br />
considered as 0.97 and 0.90 as per the past design records available with<br />
<strong>UJVN</strong> <strong>Limited</strong>. Design Energy estimation is sensitive to these assumptions.<br />
The plant has been in operation <strong>for</strong> past 46 years and it is quite possible that<br />
these parameters may have deteriorated from their designed values. In the<br />
absence of detailed technical study on the present efficiency levels of<br />
generator and turbine of Dhalipur Power Station <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> the<br />
present exercise is constrained to use these efficiency levels <strong>for</strong><br />
computational purpose though the actual efficiency levels are expected to be<br />
much lower than the designed values.<br />
The energy generation corresponding to the 10 (ten) daily discharge <strong>for</strong><br />
2004-05 with 95% of the Installed capacity is given in the table below:<br />
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Table 105: Discharge & Generation Data – Dhalipur Power Station<br />
Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh)<br />
(cumecs) (meter) (kW)<br />
1 April-I 56.8 30.5 14,827.8 35,58,675.4<br />
2 April-II 59.0 30.5 15,390.1 36,93,619.9<br />
3 April-III 63.9 30.5 16,677.5 40,02,601.4<br />
4 May-I 71.4 30.5 18,646.8 44,75,220.4<br />
5 May-II 84.4 30.5 22,038.9 52,89,335.3<br />
6 May-III 82.8 30.5 21,613.2 57,05,884.0<br />
7 June-I 69.3 30.5 18,099.6 43,43,909.5<br />
8 June-II 103.4 30.5 27,000.6 64,80,154.7<br />
9 June-III 82.5 30.5 21,545.3 51,70,867.3<br />
10 July-I 130.8 30.5 34,145.4 81,94,901.9<br />
11 July-II 119.2 30.5 31,112.5 74,66,991.1<br />
12 July-III 117.6 30.5 30,699.6 81,04,688.4<br />
13 Aug-I 182.9 30.5 47,750.8 1,14,60,195.2<br />
14 Aug-II 188.0 30.5 49,074.0 1,16,28,000.0<br />
15 Aug-III 190.9 30.5 49,834.6 1,27,90,800.0<br />
16 Sept-I 177.6 30.5 46,365.2 1,11,27,657.9<br />
17 Sept-III 175.4 30.5 45,775.3 1,09,86,072.7<br />
18 Sept-III 133.7 30.5 34,900.1 83,76,018.2<br />
19 Oct-I 113.6 30.5 29,659.8 71,18,353.1<br />
20 Oct-II 136.4 30.5 35,611.7 85,46,797.6<br />
21 Oct-III 98.4 30.5 25,692.0 67,82,683.4<br />
22 Nov-I 77.2 30.5 20,158.4 48,38,016.8<br />
23 Nov-II 65.3 30.5 17,048.4 40,91,624.7<br />
24 Nov-III 58.2 30.5 15,182.6 36,43,814.5<br />
25 Dec-I 57.0 30.5 14,879.5 35,71,079.8<br />
26 Dec-II 52.6 30.5 13,724.9 32,93,986.2<br />
27 Dec-III 48.1 30.5 12,560.8 33,16,038.4<br />
28 Jan-I 48.8 30.5 12,731.8 30,55,637.2<br />
29 Jan-II 14.2 30.5 3,702.5 8,88,603.8<br />
30 Jan-III - 30.5 - -<br />
31 Feb-I - 30.5 - -<br />
32 Feb-II - 30.5 - -<br />
33 Feb-III - 30.5 - -<br />
34 March-I 36.3 30.5 9,481.0 22,75,449.8<br />
35 March-II 128.3 30.5 33,488.4 80,37,216.1<br />
36 March-III 122.0 30.5 31,839.6 84,05,650.9<br />
Annual Energy Generation<br />
20,07,20,545.5<br />
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Table 106: Design Energy- Dhalipur Power Station<br />
Sr. No Parameter Unit Value<br />
1 Generation Loss due to uncontrollable situation % 5.01%<br />
2 Energy loss during monsoon and <strong>for</strong>ced outages kWh 10064099.5<br />
3 Design Energy kWh 190656446.1<br />
4 Design Energy (MU) MUs 190.7<br />
5 <strong>Plan</strong>t Availability of FY 04-05 % 76.5<br />
While determining Design Energy, a 5.01% (based on losses experienced<br />
during the operation of the plant) reduction in the energy generation has<br />
been considered. This reduction has been considered to take into account<br />
generation loss due to uncontrollable factors such as <strong>for</strong>ced stoppages of<br />
machines and outages to prevent damage to the machines due to heavy<br />
silting during flash floods, flood passing and grid failure etc. These losses<br />
represent Hydrological risk and other uncontrollable risks which <strong>UJVN</strong><br />
<strong>Limited</strong> cannot control in spite of its robust operating procedures. The figure<br />
of 5.01% has been determined considering generation loss on account of<br />
uncontrollable factors as a percentage of maximum possible generation<br />
without any unit and other outages on the basis of past data of the period<br />
1998-99 to 2011-12. The details of these losses are provided in the table<br />
below:<br />
Table 107: Uncontrollable Losses – Dhalipur Power Station<br />
Sr. No % losses B/D of<br />
Equipment<br />
(1)<br />
1<br />
2<br />
Flushing &<br />
Choking<br />
(2)<br />
System<br />
Condition<br />
(3)<br />
Flood<br />
Passing &<br />
Any Other<br />
Reason (4)<br />
Total (5)<br />
Gross losses as % of Max<br />
Gross Generation 1.44% 4.13% 0.13% 0.76% 6.46%<br />
Losses due to uncontrollable<br />
factors (5)-(1) 5.01%<br />
(ii) On the basis of Maximum possible plant generation<br />
In view of the limited data size, <strong>UJVN</strong> <strong>Limited</strong> has also considered an alternate<br />
approach of computing Design Energy on the basis of actual gross generation<br />
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and generation lost on account of various operational & hydrological reasons<br />
considering data available since 1998-99. The loss of generation (possible<br />
additional generation loss to <strong>UJVN</strong> <strong>Limited</strong>) is on account of (i) Equipment<br />
break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing<br />
and other reasons. <strong>UJVN</strong> <strong>Limited</strong> computes on a daily basis, the generation<br />
opportunity missed by it on account of these reasons. Thus the maximum<br />
energy that Dhalipur Power Station possibly could have generated (with 100%<br />
Unit availability and with no generation loss on account of any reason) is the<br />
gross generation by its Units and the generation loss suffered by it. This is an<br />
equally good approach <strong>for</strong> an existing plant <strong>for</strong> computing Design Energy<br />
when compared with the method of computing Design Energy on the basis of<br />
river discharge data as it is based on existing unit efficiencies instead of their<br />
design values, considers the impact of other project design related issues and<br />
also operational restrictions imposed on the plant. The maximum possible<br />
year wise generation has been computed in the table below:<br />
Table 108: Year wise Maximum Possible Generation (MU) – Dhalipur Power Station<br />
Sr. no.<br />
Actual Gross<br />
Generation<br />
(MU)<br />
Generation<br />
Loss (MU)<br />
Maximum<br />
Possible<br />
Generation<br />
(MU)<br />
Year %<br />
Dependabi<br />
lity<br />
1 305.03 16.84 321.87 1998-99 7.14<br />
2 259.01 6.28 265.30 2002-03 14.29<br />
3 236.14 24.35 260.48 2005-06 21.43<br />
4 230.22 24.96 255.18 2003-04 28.57<br />
5 229.58 15.96 245.54 2011-12 35.71<br />
6 224.44 14.25 238.69 2008-09 42.86<br />
7 210.82 25.38 236.20 2010-11 50.00<br />
8 218.21 14.27 232.48 2000-01 57.14<br />
9 210.70 21.22 231.92 2007-08 64.29<br />
10 212.04 16.70 228.74 1999-00 71.43<br />
11 214.41 8.92 223.33 2006-07 78.57<br />
12 193.45 11.71 205.16 2001-02 85.71<br />
13 185.35 6.50 191.85 2004-05 92.86<br />
14 160.15 5.99 166.14 2009-10 100.00<br />
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On re-arranging the data in the descending order and considering the 90%<br />
dependable year, the Design Energy <strong>for</strong> the Dhalipur Power Station is<br />
computed to be 182.23 MUs as given in the table below:<br />
Table 109: Design Energy – Dhalipur Power Station<br />
Sr. No. Particular Unit Value<br />
1 Dependable Year FY 2004-05<br />
2 Maximum Possible Generation MUs 191.85<br />
3 <strong>Plan</strong>t Availability <strong>for</strong> FY 2004-05 % 76.51<br />
4 Energy losses due to uncontrollable factors % 5.01%<br />
5 Energy losses due to uncontrollable factors MUs 9.62<br />
6 Design Energy (2)-(5) MUs 182.23<br />
6.5.3 Determination of NAPAF<br />
6.5.3.1 Actual average plant availability during the last 11 years is given in table below:<br />
Table 110: <strong>Plan</strong>t Availability during FY 2001- 12 – Dhalipur Power Station<br />
Sr. No (1) Month (2)<br />
Total<br />
Running<br />
Hrs. of all<br />
the units<br />
(Hrs.) (3)<br />
Reserve<br />
Outage<br />
(Hrs.) (4)<br />
Forced<br />
Outage<br />
(Hrs.) (5)<br />
<strong>Plan</strong>ned Maintenance<br />
Annual<br />
Mainten<br />
ance<br />
(Hrs.) (6)<br />
Capital<br />
Major<br />
repairs (Hrs.)<br />
(7)<br />
Total hours<br />
(max)<br />
(Hrs.) (8)<br />
<strong>Plan</strong>t<br />
Availability<br />
% (9)<br />
(Col. 3+Col.<br />
4)/Col.8<br />
1 April 11732 5848 974 3766 1440 23760 74%<br />
2 May 15652 6258 475 1662 505 24552 89%<br />
3 June 16997 6050 457 256 0 23760 97%<br />
4 July 21716 2779 57 0 0 24552 100%<br />
5 August 20935 2111 1499 7 0 24552 94%<br />
6 Sept 20561 2342 857 0 0 23760 96%<br />
7 Oct 16888 7346 318 0 0 24552 99%<br />
8 Nov 10383 8372 0 5005 0 23760 79%<br />
9 Dec 8758 6758 222 8814 0 24552 63%<br />
10 Jan 8389 8552 13 6854 744 24552 69%<br />
11 Feb 6994 6472 139 8115 672 22392 60%<br />
12 March 9490 5957 615 7746 744 24552 63%<br />
Total 168495 68845 5626 42225 4105 289296 82%<br />
6.5.3.2 The Dhalipur Power Station experiences <strong>for</strong>ced shut downs during the monsoon<br />
period. The reasons <strong>for</strong> these <strong>for</strong>ced shut downs have been provided in the<br />
section below. The average plant availability during the last 11 year is around<br />
82%.<br />
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6.5.4 Special Circumstances and Abnormal Operating Conditions<br />
6.5.4.1 Since its commissioning, Dhalipur Power Station operates on base load during<br />
monsoon period and as a peaking station during non-monsoon period when<br />
discharge in the river reduces and Power Station has to be run on partial load. But<br />
due to silting of Dakpathar Barrage the peaking capacity has also reduced and<br />
Power Station meets evening and morning peaks during lean discharge period as<br />
per requirement of SLDC.<br />
6.5.4.2 Study of the available inflow data revealed that the maximum capacity can be<br />
generated between May to September and partially between October to April.<br />
Lean discharge period is again utilised <strong>for</strong> planned annual or capital maintenance.<br />
6.5.4.3 Annual loss of energy during Monsoon due to flushing and choking over the period<br />
1998-12 has been calculated in table 107 & 111, which is around 64% of the total<br />
generation loss. Such annual loss should there<strong>for</strong>e be appropriately accounted <strong>for</strong><br />
while computing Design Energy and plant availability.<br />
6.5.5 <strong>Plan</strong>t Outages and Breakdowns<br />
6.5.5.1 The <strong>for</strong>ced outage data <strong>for</strong> the period 1998-2012 has revealed that 22% of the<br />
total energy loss is on this account. The table below provides the details.<br />
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Table 111: % Generation Loss on account of various Factors – Dhalipur Power Station<br />
Sr. No. Month↓ B/D of<br />
Equipment<br />
(in MU)<br />
Flushing &<br />
Choking<br />
(in MU)<br />
System<br />
Condition<br />
& Grid fail<br />
(in MU)<br />
Flood<br />
passing &<br />
Any Other<br />
Reasons<br />
(in MU)<br />
Total<br />
(in MU)<br />
1 April 0.62 0.00 0.24 4.38 5.23<br />
2 May 0.79 0.38 0.72 0.13 2.02<br />
3 June 1.08 7.59 0.53 0.07 9.28<br />
4 July 4.58 45.61 0.79 0.37 51.34<br />
5 August 23.58 48.87 0.53 3.89 76.87<br />
6 September 7.74 29.33 0.44 4.31 41.83<br />
7 October 2.46 4.08 0.37 0.83 7.74<br />
8 November 0.02 0.30 0.13 0.01 0.46<br />
9 December 0.02 0.00 0.07 0.23 0.31<br />
10 January 0.00 0.03 0.12 5.09 5.24<br />
11 Feburary 0.57 0.00 0.15 4.16 4.87<br />
12 March 6.26 0.10 0.08 1.68 8.12<br />
Total 47.71 136.30 4.17 25.14 213.31<br />
% Generation Lost 22% 64% 2% 12% 100%<br />
6.5.6 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
6.5.6.1 The analysis of auxiliary consumption data of past 14 years reveals that the<br />
auxiliary consumption of Dhalipur Power Station is around 0.27% of the Gross<br />
Generation. Similarly the trans<strong>for</strong>mation losses of past 14 years <strong>for</strong> which the<br />
data is available has been analysed are 1.66% of the gross generation. Both<br />
auxiliary and trans<strong>for</strong>mation losses together constitute around 1.94 % of the<br />
Gross Generation<br />
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Table 112: Auxiliary and Trans<strong>for</strong>mation Losses – Dhalipur Power Station<br />
6.5.6.2 <strong>UJVN</strong> Ltd. has taken steps to reduce the auxiliary consumption and trans<strong>for</strong>mation<br />
losses. Data of previous 4 years, which has already been submitted to Hon’ble<br />
UERC, as shown below, shows improvement in auxiliary and trans<strong>for</strong>mation losses.<br />
6.5.7 Inferences<br />
6.5.7.1 Design Energy<br />
Sr. No Particulars Unit Value<br />
1 Total Gross Generation 1998-12) MUs 3089.55<br />
2 Total Aux. consumption (1998-12) MUs 8.49<br />
3 Aux. consumption as a % of Gross Generation % 0.27%<br />
4 Total Gross Generation (1998-12) MUs 3089.55<br />
5 Total Trans<strong>for</strong>mation loss (1998-12) MUs 51.30<br />
6 Trans<strong>for</strong>mation loss as a % of Gross Generation % 1.66%<br />
7 Total Aux. and Trans<strong>for</strong>mation losses (1998-12) MUs 59.79<br />
8<br />
Total Aux. and Trans<strong>for</strong>mation losses as a % of<br />
Gross Generation<br />
% 1.94%<br />
Sr. No Year Trans<strong>for</strong>mation<br />
& line losses<br />
Auxiliary<br />
Consumption<br />
1 FY 2010-11 0.7% 0.2%<br />
2 FY 2009-10 1.2% 0.2%<br />
3 FY 2008-09 1.5% 0.2%<br />
4 FY 2007-08 1.3% 0.2%<br />
5 Average 1.2% 0.2%<br />
The discharge data <strong>for</strong> Dhalipur Power station is available on 10 daily (average)<br />
basis <strong>for</strong> the period April 1994 to March 2012. The Design Energy is computed on<br />
the basis of the data <strong>for</strong> each 10 daily average discharge of the 90% dependable<br />
year. Correspondingly the Design Energy is calculated (refer to the earlier Table<br />
106) to be 190.7 MU after accounting <strong>for</strong> uncontrollable energy loss of 5.01%.<br />
Design Energy was also calculated on the basis of maximum possible generation<br />
(refer earlier table 109) which comes to 182.23 MU.<br />
Dhalipur Power Station is quite old Power Station and has been under operation<br />
since its commissioning in the year 1965. This long operation period has resulted<br />
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into excessive wear and tear of the hydro mechanical and electro mechanical<br />
equipment, thereby causing breakdown of machines. The condition of these<br />
equipment is deteriorating with passage of time. <strong>UJVN</strong> Ltd. is taking proactive<br />
action by taking up comprehensive RMU of the Project <strong>for</strong> revival and life<br />
extension of the project.<br />
Keeping in view the long operational life of the project, it is proposed that Design<br />
Energy <strong>for</strong> Dhalipur Power Station may be considered as 182.23 MU which is the<br />
Design Energy computed using the second approach mentioned earlier. However,<br />
after completion of the proposed RMU works of the Project, <strong>UJVN</strong> Ltd. shall<br />
approach the Commission to revise the Design Energy of the Project.<br />
6.5.7.2 NAPAF<br />
UERC has prescribed principle <strong>for</strong> Normal <strong>Plan</strong>t Availability determination. Based<br />
on the principle given by UERC the annual plant availability has been calculated in<br />
the earlier table 106 which comes to 76.5%.<br />
Based on actual running hours, reserve hours, <strong>for</strong>ced outage hours and plant<br />
outage hours <strong>for</strong> last 11 years, plant average annual plant availability has been<br />
calculated in table no. 110 which comes to 82% and this may be taken as NAPAF<br />
<strong>for</strong> Dhalipur Power Station <strong>for</strong> base year of the control period.<br />
6.5.7.3 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
The auxiliary and trans<strong>for</strong>mation losses exceed the norms set by UERC <strong>for</strong> surface<br />
hydroelectric power generating stations with rotary excitation system by 1.24%.<br />
<strong>UJVN</strong> <strong>Limited</strong> proposes to take remedial measures during the proposed RMU to<br />
reduce these losses within the prescribed limits prescribed by the Commission.<br />
6.5.8 Projections <strong>for</strong> the Control Period<br />
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6.5.8.1 RMU works are proposed <strong>for</strong> the Dhalipur Power Station. The proposed RMU works<br />
are likely to result in (i) Extension of the <strong>Plan</strong>t life by around 25 years (ii) Higher<br />
<strong>Plan</strong>t Availability (iii) Increased operating efficiencies of plant. The RMU works <strong>for</strong><br />
the plant is likely to be completed during the control period. The unit wise schedule<br />
<strong>for</strong> implementing RMU is as given below:<br />
Name of<br />
Unit<br />
Date of Start Date of<br />
Commissioning<br />
Unit-1 01.10.14 30.06.15<br />
Unit-2 01.10.15 30.06.16<br />
Unit-3 01.10.16 30.06.17<br />
6.5.9 Impact of RMU works on Energy Generation<br />
6.5.9.1 The proposed RMU of Dhalipur Power Station is likely to result in increased<br />
availability of plant and refurbishment of turbines and generators leading to<br />
increased efficiencies. This could yield energy generation gains of the order of 15 %<br />
if the same level of water discharge is considered pre and post RMU. Primary<br />
purpose of RMU is life extension of the project apart from increase in generation.<br />
After RMU, generation will increase from 240 MU to 276 MU (as per DPR) subject<br />
to same water discharge.<br />
6.5.10 Availability<br />
6.5.10.1 The annual maintenance schedule and the RMU schedule proposed <strong>for</strong> Dhalipur<br />
Power Station under RMU works <strong>for</strong> the Control period is as given below:<br />
FY2013-14<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2013 15-12-2013 45 Annual Maintenance<br />
2 16-12-2013 29-01-2014 45 Annual Maintenance<br />
3 30-01-2014 15-03-2014 45 Annual Maintenance<br />
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FY2014-15<br />
Unit No. Start Date End date Days Reasons<br />
1 01-10-2014 30-06-2015 273 RMU<br />
2 01-11-2014 15-12-2014 45 Annual Maintenance<br />
3 16-12-2014 29-01-2015 45 Annual Maintenance<br />
FY2015-16<br />
Unit No. Start Date End date Days Reasons<br />
1 16-12-2015 14-01-2016 30 Annual Maintenance<br />
2 01-10-2015 30-06-2016 274 RMU<br />
3 01-11-2015 15-12-2015 45 Annual Maintenance<br />
6.5.10.2 After implementation of RMU works, full capacity of the plant is likely to be<br />
available <strong>for</strong> the entire year except during monsoon period and annual<br />
maintenance period. The plant availability during the control year considering<br />
maintenance schedule given above and <strong>for</strong>ced outages expected (based on past<br />
data) during monsoon months is expected to be as given below:<br />
Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16<br />
<strong>Plan</strong>t Availability (%) 82% 86.7% 73.9% 66.4%<br />
6.5.10.3 The plant availability expected post RMU is likely to be around 87 %.<br />
6.5.11 Auxiliary Consumption and Trans<strong>for</strong>mation losses<br />
6.5.11.1 The normative auxiliary and trans<strong>for</strong>mation losses can be achieved after<br />
implementation of RMU works wherein energy efficient motors, starters, heating,<br />
air conditioning, illumination, power trans<strong>for</strong>mation and switching system would<br />
be adopted. The Dhalipur Power Station is expected to achieve normative loss level<br />
after completion of the RMU works.<br />
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6.6 TECHNICAL REPORT OF KHODRI POWER STATION<br />
6.6.1 Introduction<br />
6.6.1.1 The Khodri Power Station with installed capacity of 120 MW (4X30 MW) is located<br />
on the downstream of the Chibro Power Station and was commissioned in the year<br />
1984.The Power Station draws water through a 6 km long and 7.5 m diameter head<br />
race tunnel directly from the collection gallery of the Chibro Power Station through<br />
a siphon tunnel under river Tons. HRT ends at 21 m dia. and 46 m high surge tank<br />
where the water is conveyed and distributed to two no.5.5 m dia. and 85 m<br />
pressure shaft and subsequently by four 4.1 m dia. and 24 m long penstocks to the<br />
generating units.<br />
6.6.1.2 Khodri Power Station operates in tandem mode with Chibro Power Station, which<br />
means both Power Stations are laid out <strong>for</strong> same design flow and no intermediate<br />
water storage.<br />
6.6.1.3 The surface Power Station comprising 4 units of 30 MW each with Francis turbines<br />
of 43,600 HP output is located on the banks of river Yamuna in Distt. Sirmaur of<br />
H.P. State and the tail water flows in river Yamuna, upstream of the Dakpathar<br />
Barrage. The Power Station's design head is of 57.9 m.<br />
6.6.1.4 The operation of Chibro and Khodri Power Stations is another engineering marvel.<br />
The tandem control scheme between Chibro and Khodri Power Stations is in<br />
operation since January, 1984 and is the first of its kind in the country which<br />
optimizes the utilization of water <strong>for</strong> generation besides maintaining the safety of<br />
both the plants in case of outages.<br />
6.6.1.5 There are four generating units having vertical Francis turbine directly coupled with<br />
synchronous generator. The turbine output is 32.1 MW <strong>for</strong> a rated net head of 57.9<br />
m. The generators are designed <strong>for</strong> a nominal output of 34 MVA with lagging<br />
power factor of 0.9 and class “B” insulation<br />
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6.6.1.6 This Power Station was commissioned in the year 1984. Due to operations of<br />
machines <strong>for</strong> past 27 years in silt laden water, efficiency of machines has<br />
substantially decreased and availability of machines has been adversely affected, in<br />
spite of best and timely maintenance.<br />
6.6.1.7 Though this Power Station has an installed capacity of 4x30 MW but due to<br />
constraints of water discharge limitations in HRT from collection gallery of Chibro<br />
maximum generating capacity is only 83 MW. As such while analyzing data <strong>for</strong><br />
calculating Design Energy installed capacity of 83MW has been considered.<br />
6.6.2 Determination of Design Energy<br />
6.6.2.1 Khodri power Station is a run of the river Power Station. For computing the Design<br />
Energy two methodologies have been considered i.e. (i) on the basis of average of<br />
10 daily discharges <strong>for</strong> calculation of NAPAF <strong>for</strong> Run-of-river type plant as per<br />
provision of UERC MYT 2011 Regulations “To be determined plant-wise, based on<br />
10-day Design Energy data, moderated by past experience where available<br />
/relevant” and (ii) the maximum generation possible from the Khodri Power Station<br />
considering that there were no machine and other outages. Due to non-availability<br />
of 90% dependable 10 daily inflows pattern as approved in the DPR of the project,<br />
Design Energy and NAPAF have been calculated on the basis of available past<br />
reliable 10 daily discharge data.<br />
(i) On the basis of Average of 10 daily discharges<br />
Reliable 10 daily (average) discharge data <strong>for</strong> Khodri Power Station is<br />
available <strong>for</strong> the period April 1993 to March 2012 and the same has been<br />
considered <strong>for</strong> determination of 90% dependable year and Design Energy<br />
(this data is provided in the annexure 5). Reliable data <strong>for</strong> periods prior to<br />
April 1993 is not available with <strong>UJVN</strong> <strong>Limited</strong>. On considering average daily<br />
discharge data of the years <strong>for</strong> the same period, the 90% dependable year is<br />
found to be 2004-05, as given in table 113 below:<br />
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Table 113: 90% Dependable year – Khodri Power Station<br />
Sl. No.<br />
For computation of possible energy generation corresponding to the<br />
discharge considered, generator and turbine efficiencies have been<br />
considered as 0.969and 0.925 as per the past design records available with<br />
<strong>UJVN</strong> <strong>Limited</strong>. Design Energy estimation is sensitive to these assumptions.<br />
The plant has been in operation <strong>for</strong> past 28 years and it is quite possible that<br />
these parameters may have deteriorated from their designed values. In the<br />
absence of detailed technical study on the present efficiency levels of<br />
generator and turbine of Khodri Power Station, <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> the present<br />
exercise is constrained to use these efficiency levels <strong>for</strong> computational<br />
purpose though the actual efficiency levels are expected to be much lower<br />
than the designed values. The energy generation corresponding to the 10<br />
(ten) daily discharge <strong>for</strong> 2004-05 with 95% of the Installed capacity is given in<br />
the table below:<br />
10 Daily<br />
Discharge<br />
Average<br />
Year %<br />
Dependability<br />
1 129.06 1998-99 5.26<br />
2 112.19 1995-96 10.53<br />
3 107.07 1997-98 15.79<br />
4 106.30 1996-97 21.05<br />
5 103.75 1994-95 26.32<br />
6 102.66 2002-03 31.58<br />
7 100.01 1993-94 36.84<br />
8 97.22 2003-04 42.11<br />
9 97.05 2011-12 47.37<br />
10 92.42 2005-06 52.63<br />
11 92.28 1999-00 57.89<br />
12 90.97 2010-11 63.16<br />
13 88.05 2000-01 68.42<br />
14 87.89 2008-09 73.68<br />
15 87.34 2001-02 78.95<br />
16 86.83 2006-07 84.21<br />
17 84.62 2007-08 89.47<br />
18 72.25 2004-05 94.74<br />
19 66.25 2009-10 100.00<br />
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Table 114: Discharge & Generation Data – Power Station<br />
Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh)<br />
(cumecs) (meter) (kW)<br />
1 April-I 45.1 57.9 22,960.9 55,10,625.1<br />
2 April-II 48.9 57.9 24,895.6 59,74,935.0<br />
3 April-III 53.0 57.9 26,982.9 64,75,900.9<br />
4 May-I 60.0 57.9 30,546.7 73,31,208.5<br />
5 May-II 77.1 57.9 39,252.5 94,20,603.0<br />
6 May-III 74.4 57.9 37,859.4 99,94,881.0<br />
7 June-I 58.0 57.9 29,528.5 70,86,834.9<br />
8 June-II 84.2 57.9 42,867.2 1,02,88,129.3<br />
9 June-III 67.0 57.9 34,110.5 81,86,516.2<br />
10 July-I 90.8 57.9 46,227.3 1,10,94,562.2<br />
11 July-II 78.0 57.9 39,710.7 95,30,571.1<br />
12 July-III 94.3 57.9 47,995.3 1,26,70,772.1<br />
13 Aug-I 148.6 57.9 75,654.0 1,81,56,959.8<br />
14 Aug-II 167.1 57.9 85,072.6 2,04,17,415.8<br />
15 Aug-III 155.5 57.9 79,143.7 2,08,93,944.3<br />
16 Sept-I 125.7 57.9 63,995.3 1,53,58,881.9<br />
17 Sept-III 103.7 57.9 52,794.9 1,26,70,772.1<br />
18 Sept-III 76.7 57.9 39,048.9 93,71,728.2<br />
19 Oct-I 63.3 57.9 32,226.8 77,34,425.0<br />
20 Oct-II 83.3 57.9 42,409.0 1,01,78,161.2<br />
21 Oct-III 54.1 57.9 27,538.3 72,70,115.1<br />
22 Nov-I 43.1 57.9 21,942.7 52,66,251.5<br />
23 Nov-II 36.5 57.9 18,582.6 44,59,818.5<br />
24 Nov-III 35.6 57.9 18,124.4 43,49,850.4<br />
25 Dec-I 39.0 57.9 19,855.4 47,65,285.5<br />
26 Dec-II 36.4 57.9 18,531.7 44,47,599.8<br />
27 Dec-III 34.7 57.9 17,680.1 46,67,536.1<br />
28 Jan-I 35.7 57.9 18,175.3 43,62,069.1<br />
29 Jan-II 33.7 57.9 17,157.1 41,17,695.5<br />
30 Jan-III 37.1 57.9 18,883.4 49,85,221.8<br />
31 Feb-I 45.9 57.9 23,368.2 56,08,374.5<br />
32 Feb-II 66.7 57.9 33,957.8 81,49,860.2<br />
33 Feb-III 60.9 57.9 30,992.2 59,50,497.6<br />
34 March-I 77.9 57.9 39,659.8 95,18,352.4<br />
35 March-II 102.5 57.9 52,183.9 1,25,24,147.9<br />
36 March-III 99.9 57.9 50,864.9 1,34,28,330.3<br />
Annual Energy Generation<br />
32,22,18,833.7<br />
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Table 115: Design Energy-Khodri Power Station<br />
Sr. No Particulars Unit Value<br />
1 Generation Loss due to uncontrollable situation % 3.42%<br />
2 Energy loss during monsoon and <strong>for</strong>ced outages kWh 11029620.0<br />
3 Design Energy kWh 311189213.7<br />
4 Design Energy (MU) MUs 311.2<br />
5 <strong>Plan</strong>t Availability of FY 04-05 % 83.4<br />
While determining Design Energy, a 3.42% (based on losses experienced<br />
during the operation of the plant) reduction in the energy generation has<br />
been considered. This reduction has been considered to take into account<br />
generation loss due to uncontrollable factors such as <strong>for</strong>ced stoppages of<br />
machines and outages to prevent damage to the machines due to heavy<br />
silting during flash floods, flood passing and grid failure. These losses<br />
represent Hydrological risk and other uncontrollable risks which <strong>UJVN</strong><br />
<strong>Limited</strong> cannot control in spite of its robust operating procedures. The figure<br />
of 3.42% has been determined considering generation loss on account of<br />
uncontrollable factors as a percentage of maximum possible generation<br />
without any unit and other outages on the basis of past data of the period<br />
1999-00 to 2011-12. The details of these losses are provided in the table<br />
below:<br />
Table 116: Uncontrollable Losses – Khodri Power Station<br />
Sr. No % losses B/D of<br />
Equipment<br />
(1)<br />
1<br />
2<br />
Flushing &<br />
Choking<br />
(2)<br />
System<br />
Condition<br />
(3)<br />
Flood<br />
Passing &<br />
Any Other<br />
Reason (4)<br />
Total (5)<br />
Gross losses as % of Max.<br />
Gross Generation 1.74% 2.47% 0.36% 0.59% 5.16%<br />
Losses due to uncontrollable<br />
factors (5)-(1) 3.42%<br />
(ii) On the basis of Maximum possible plant generation<br />
In view of the limited data size, <strong>UJVN</strong> <strong>Limited</strong> has also considered an alternate<br />
approach of computing Design Energy on the basis of actual gross generation<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
and generation lost on account of various operational & Hydrological reasons<br />
<strong>for</strong> which the data is available since 1999-2012. The loss of generation<br />
(possible additional generation loss to <strong>UJVN</strong> <strong>Limited</strong>) is on account of (i)<br />
Equipment break down (ii) Flushing and Choking (iii) System Condition (iv)<br />
Flood passing and other reasons. <strong>UJVN</strong> <strong>Limited</strong> computes on a daily basis, the<br />
generation opportunity missed by it on account of these reasons. Thus the<br />
maximum energy that Khodri Power Station possibly could have generated<br />
(with 100% Unit availability and with no generation loss on account of any<br />
reason) is the gross generation by its Units and the generation loss suffered<br />
by it. This is an equally good approach <strong>for</strong> an existing plant <strong>for</strong> computing<br />
Design Energy when compared with the method of computing Design Energy<br />
on the basis of river discharge data as it is based on existing unit efficiencies<br />
instead of their design values, considers the impact of other project design<br />
related issues and also operational restrictions imposed on the plant. The<br />
maximum possible year wise generation has been computed in the table<br />
below:<br />
Table 117: Year wise Maximum Possible Generation (MU) – Khodri Power Station<br />
Sr. no.<br />
Actual Gross<br />
Generation<br />
(MU)<br />
Generation<br />
Loss (MU)<br />
Maximum<br />
Possible<br />
Generation<br />
(MU)<br />
Year %<br />
Dependabi<br />
lity<br />
1 408.57 10.81 419.38 2002-03 7.69<br />
2 388.79 28.09 416.88 2003-04 15.38<br />
3 367.41 40.49 407.90 2000-01 23.08<br />
4 382.83 22.34 405.17 2011-12 30.77<br />
5 378.94 25.83 404.76 2005-06 38.46<br />
6 379.90 19.60 399.50 2008-09 46.15<br />
7 361.78 37.14 398.92 2010-11 53.85<br />
8 358.67 21.14 379.81 2001-02 61.54<br />
9 365.35 9.30 374.65 1999-00 69.23<br />
10 356.18 10.92 367.10 2006-07 76.92<br />
11 354.72 10.38 365.10 2007-08 84.62<br />
12 304.55 7.27 311.82 2004-05 92.31<br />
13 275.87 11.53 287.41 2009-10 100.00<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
On re-arranging the above data in the descending order and considering the<br />
90% dependable year, the Design Energy <strong>for</strong> the Khodri Power Station is<br />
computed to be 301.15 MUs as given in the table below:<br />
Table 118: Design Energy – Khodri Power Station<br />
Sr. No. Particular Unit Value<br />
1 Dependable Year FY 2004-05<br />
2 Maximum Possible Generation MUs 311.82<br />
3 <strong>Plan</strong>t Availability <strong>for</strong> FY 2004-05 % 83.44<br />
4 Energy losses due to uncontrollable factors % 3.42%<br />
5 Energy losses due to uncontrollable factors MUs 10.67<br />
6 Design Energy (2)-(5) MUs 301.15<br />
6.6.3 Determination of NAPAF<br />
6.6.3.1 Actual average plant availability during the last 12 years is given in table below:<br />
Table 119: <strong>Plan</strong>t Availability during FY 2000 - 12 – Khodri Power Station<br />
Sr. No (1) Month (2)<br />
Total<br />
Running<br />
Hrs. of all<br />
the units<br />
(Hrs.) (3)<br />
Reserve<br />
Outage<br />
(Hrs.) (4)<br />
Forced<br />
Outage<br />
(Hrs.) (5)<br />
<strong>Plan</strong>ned Maintenance<br />
Annual<br />
Mainten<br />
ance<br />
(Hrs.) (6)<br />
Capital<br />
Major<br />
repairs (Hrs.)<br />
(7)<br />
Total hours<br />
(max)<br />
(Hrs.) (8)<br />
<strong>Plan</strong>t<br />
Availability<br />
% (9)<br />
(Col. 3+Col.<br />
4)/Col.8<br />
1 April 13552 14275 207 3004 3522 34560 81%<br />
2 May 18647 14024 135 1399 1507 35712 91%<br />
3 June 20183 13381 137 859 0 34560 97%<br />
4 July 25795 9312 395 210 0 35712 98%<br />
5 August 27675 7794 106 137 0 35712 99%<br />
6 Sept 25619 8814 90 37 0 34560 100%<br />
7 Oct 17247 14647 355 993 2470 35712 89%<br />
8 Nov 10591 15404 70 2889 5606 34560 75%<br />
9 Dec 8569 15635 71 3841 7596 35712 68%<br />
10 Jan 8057 16406 906 3290 7053 35712 69%<br />
11 Feb 7603 14498 427 4059 5957 32544 68%<br />
12 March 11640 14782 59 3025 6206 35712 74%<br />
Total 195178 158972 2958 23743 39917 420768 84%<br />
6.6.3.2 The Khodri Power Station experiences <strong>for</strong>ced shut downs during the monsoon<br />
period. The reasons <strong>for</strong> these <strong>for</strong>ced shut downs have been provided in the section<br />
below. The average plant availability during last 12 years is around 84%.<br />
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6.6.4 Special Circumstances and Abnormal Operating Conditions<br />
6.6.4.1 Since, its commissioning Khodri Power Station operates on base load during<br />
Monsoon period and as a peaking station during non-monsoon period when<br />
discharge in the river reduces and Power Station has to be run on partial Capacity.<br />
But due to silting of Ichari Dam the peaking capacity has also reduced and Power<br />
Station meets evening and morning peaks during lean discharge period as per the<br />
requirement of SLDC.<br />
6.6.4.2 Study of the available inflow data revealed that the maximum capacity can be<br />
generated between May to September and partially between October to April.<br />
Lean discharge period is again utilised <strong>for</strong> planned annual or capital maintenance.<br />
6.6.4.3 Annual loss of energy during Monsoon due to flushing and choking, over the period<br />
1999-12 has been calculated in the table 116 & 120 below, which is around 2.5% of<br />
the gross generation and 48% of the total generation loss. Such annual loss should<br />
there<strong>for</strong>e be appropriately accounted <strong>for</strong> while computing Design Energy and plant<br />
availability.<br />
6.6.5 <strong>Plan</strong>t Outages and Breakdowns<br />
6.6.5.1 Apart from above facts, when flood recedes lot of silt having substantial quartzite<br />
particles are lodged in cavities and caves on both banks of river which gets<br />
dislodged when level of river starts rising as a result of snow melting during<br />
summer season and is carried to the machines through water conductor system<br />
causing severe damage to under water parts and frequent plant outages which<br />
becomes beyond control of <strong>UJVN</strong> <strong>Limited</strong><br />
6.6.5.2 The <strong>for</strong>ced outage data <strong>for</strong> the period 1999-2012 has revealed that 34% of the total<br />
energy loss is on this account. The table below provides the details.<br />
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Table 120: % Generation Loss on account of various Factors – Khodri Power Station<br />
Sr. No. Month↓ B/D of<br />
Equipment<br />
(in MU)<br />
Flushing &<br />
Choking<br />
(in MU)<br />
System<br />
Condition<br />
& Grid fail<br />
(in MU)<br />
Flood<br />
passing &<br />
Any Other<br />
Reasons<br />
(in MU)<br />
Total<br />
(in MU)<br />
1 April 0.00 0.74 0.30 0.11 1.14<br />
2 May 8.00 1.19 9.05 0.00 18.24<br />
3 June 3.76 11.62 0.19 1.23 16.79<br />
4 July 19.88 43.01 2.60 1.59 67.08<br />
5 August 31.09 45.98 5.43 16.90 99.40<br />
6 September 18.51 17.83 0.08 6.43 42.85<br />
7 October 0.91 0.50 0.06 2.23 3.70<br />
8 November 0.00 0.42 0.00 0.41 0.83<br />
9 December 0.00 0.00 0.00 0.00 0.00<br />
10 January 3.64 0.00 0.02 0.26 3.91<br />
11 Feburary 0.00 0.00 0.16 0.00 0.17<br />
12 March 0.00 0.73 0.00 0.00 0.73<br />
Total 85.80 122.01 17.89 29.14 254.85<br />
Generation Lost 34% 48% 7% 11% 100%<br />
6.6.6 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
6.6.6.1 The analysis of auxiliary consumption of past 13 years reveals that the auxiliary<br />
consumption of Khodri Power Station is around 0.2% of the Gross Generation.<br />
Similarly the trans<strong>for</strong>mation losses of past 13 years <strong>for</strong> which the data is available<br />
has been analysed. The trans<strong>for</strong>mation losses are 0.5% of the gross generation.<br />
Both auxiliary and trans<strong>for</strong>mation losses together constitute around 0.7% of the<br />
Gross Generation.<br />
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Table 121: Auxiliary and Trans<strong>for</strong>mation Losses – Khodri Power Station<br />
6.6.6.2 <strong>UJVN</strong> Ltd. has taken steps to reduce the auxiliary consumption and trans<strong>for</strong>mation<br />
losses. Data of previous 4 years, which has already been submitted to Hon’ble<br />
UERC, as shown below, shows improvement in auxiliary and trans<strong>for</strong>mation losses.<br />
6.6.7 Inferences<br />
Sr. No Particulars Unit Value<br />
1 Total Gross Generation (1999-12) MUs 4683.56<br />
2 Total Aux. consumption (1999-12) MUs 10.96<br />
3 Aux. consumption as a % of Gross Generation % 0.2%<br />
4 Total Gross Generation (1999-12) MUs 4683.56<br />
5 Total Trans<strong>for</strong>mation loss (1999-12) MUs 23.36<br />
6 Trans<strong>for</strong>mation loss as a % of Gross Generation % 0.5%<br />
7 Total Aux. and Trans<strong>for</strong>mation losses (1999-12) MUs 34.32<br />
8<br />
Total Aux. and Trans<strong>for</strong>mation losses as a % of<br />
Gross Generation<br />
% 0.7%<br />
6.6.7.1 Design Energy<br />
Sr. No Year Trans<strong>for</strong>mation<br />
& line losses<br />
Auxiliary<br />
Consumption<br />
1 FY 2010-11 0.03% 0.22%<br />
2 FY 2009-10 0.16% 0.29%<br />
3 FY 2008-09 0.37% 0.23%<br />
4 FY 2007-08 0.34% 0.26%<br />
5 Average 0.23% 0.25%<br />
The discharge data <strong>for</strong> Khodri Power Station is available on 10 daily (average)<br />
basis <strong>for</strong> the period April 1993 to March 2012. The Design Energy computed on<br />
the basis of data <strong>for</strong> each 10 daily average discharge of 90% dependable year.<br />
Correspondingly the Design Energy is calculated (refer to the earlier table 115) to<br />
be 311.19 MU after accounting <strong>for</strong> uncontrollable energy loss of 3.42%.<br />
Design Energy was also calculated based on maximum possible generation (refer<br />
to the earlier table 118) which comes to 301.15 MU.<br />
Khodri Power Station is quite old Power Station and has been under operation<br />
since its commissioning in the year 1984. This long operation period has resulted<br />
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into excessive wear and tear of the hydro mechanical and electro mechanical<br />
equipment, thereby causing breakdown of machines. The condition of these<br />
equipment is deteriorating with passage of time. <strong>UJVN</strong> Ltd. is taking proactive<br />
action by taking up comprehensive RMU of the Project <strong>for</strong> revival and life<br />
extension of the project.<br />
Keeping in view the long operational life of the project, it is proposed that Design<br />
Energy <strong>for</strong> Khodri Power Station may be considered as 301.15 MU which is the<br />
Design Energy computed using the second approach mentioned earlier. However,<br />
after completion of the proposed RMU works of the Project, <strong>UJVN</strong> Ltd. shall<br />
approach the Commission to revise the Design Energy of the Project.<br />
6.6.7.2 NAPAF<br />
UERC has prescribed principle <strong>for</strong> determination of NAPAF. Based on the principle<br />
given by UERC the annual plant availability has been calculated in the table no<br />
115 which comes to 83.4%.<br />
Based on actual running hours, reserve hours, <strong>for</strong>ced outage hours and plant<br />
outage hours <strong>for</strong> last 12 years average annual plant availability has been<br />
calculated in table no. 119 which comes to 84% and this may be considered as<br />
NAPAF <strong>for</strong> Khodri Power Station <strong>for</strong> control period.<br />
6.6.7.3 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
As explained in the earlier section, these losses are within the limit of 1%<br />
prescribed by UERC <strong>for</strong> Surface hydroelectric power generating stations with<br />
static excitation system.<br />
6.6.8 Projections <strong>for</strong> the control period<br />
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6.6.8.1 RMU works are proposed <strong>for</strong> the Khodri Power Station. The proposed RMU works<br />
are likely to result in (i) Extension of the <strong>Plan</strong>t life by around 25 years (ii) Higher<br />
<strong>Plan</strong>t Availability (iii) Increased operating efficiencies of plant. The RMU works <strong>for</strong><br />
the plant is likely to be completed during the control period. The unit wise schedule<br />
<strong>for</strong> implementing RMU is as given below:<br />
Name of<br />
Unit<br />
Date of Start Date of<br />
Commissioning<br />
Unit-1 01.11.15 31.03.17<br />
Unit-2 01.06.17 31.03.18<br />
Unit-3 01.06.18 31.03.19<br />
Unit-4 01.06.19 31.03.20<br />
6.6.9 Impact of RMU works on Energy Generation<br />
6.6.9.1 The proposed RMU of Khodri Power Station is likely to result in increased plant<br />
availability and refurbishment of turbines and generators is likely to lead to<br />
increased efficiencies. These measures could yield energy gains of the order of 9.4<br />
% if the same level of power discharge is considered pre and post RMU. Primary<br />
purpose of RMU is life extension of the project apart from increase in generation.<br />
After RMU, generation will increase from 406 MU to 444 MU (as per DPR) subject<br />
to same water discharge.<br />
6.6.10 Availability<br />
6.6.10.1 The annual maintenance schedule and the RMU schedule proposed <strong>for</strong> Khodri<br />
Power Station under RMU works <strong>for</strong> the Control period is as given below:<br />
2013-14<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2013 10-12-2013 40 Annual Maintenance<br />
2 14-12-2013 22-01-2014 40 Annual Maintenance<br />
3 27-01-2014 07-03-2014 40 Annual Maintenance<br />
4 13-01-2014 21-02-2014 40 Annual Maintenance<br />
2014-15<br />
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Unit No. Start Date End date Days Reasons<br />
1 01-11-2014 10-12-2014 40 Annual Maintenance<br />
2 14-12-2014 22-01-2015 40 Annual Maintenance<br />
3 27-01-2015 07-03-2015 40 Annual Maintenance<br />
4 13-01-2015 21-02-2015 40 Annual Maintenance<br />
2015-16<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2015 31-03-2017 517 RMU<br />
2 14-12-2015 22-01-2016 40 Annual Maintenance<br />
3 27-01-2016 06-03-2016 40 Annual Maintenance<br />
4 13-01-2016 21-02-2016 40 Annual Maintenance<br />
6.6.10.2 After implementation of RMU works full capacity of the plant is likely to be<br />
available <strong>for</strong> the entire year except <strong>for</strong> monsoon and annual maintenance. The<br />
plant availability during the control year considering maintenance schedule given<br />
above and <strong>for</strong>ced outages expected (based on past data) during monsoon months<br />
is expected to be as given below:<br />
Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16<br />
<strong>Plan</strong>t Availability (%) 84% 88.5% 88.5% 80.9%<br />
6.6.10.3 The plant availability expected post RMU is likely to be around 88 %.<br />
6.6.11 Auxiliary Consumption and Trans<strong>for</strong>mation losses<br />
6.6.11.1 As stated above the auxiliary and trans<strong>for</strong>mation losses are within the limits<br />
prescribed by the Commission. During the control period these are expected to be<br />
within the limits prescribed by the Commission.<br />
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6.7 TECHNICAL REPORT OF KULHAL POWER STATION<br />
6.7.1 Introduction<br />
6.7.1.1 The Kulhal Power Station with an installed capacity of 30 MW (3X10 MW) is located<br />
on the downstream of the Asan Barrage at a distance of 4.0 km on the power<br />
channel which takes off from the Asan Barrage. The Power Station was<br />
commissioned in the year 1975. The surface Power Station comprising 3 units of 10<br />
MW each with Kaplan turbines is located on the power channel which terminates<br />
in 39.2 m wide and 6.9 m deep <strong>for</strong>e bay. There are three 30 m long and 4.5 m dia.<br />
steel lined penstocks, one <strong>for</strong> each unit. In case of tripping of machines full<br />
discharge gets bye-passed through a 21m wide gated bye pass channel. The water<br />
from the tail race flows towards Khara Power Station in UP. The Kulhal Power<br />
Station is a low head scheme located on power channel with a design head of 18 m<br />
and design discharge of 198 cum.<br />
6.7.1.2 There are three generating units having vertical Kaplan turbine directly coupled<br />
with synchronous generator. The turbine output is 10.4 MW <strong>for</strong> a rated net head of<br />
18 m. The generators are designed <strong>for</strong> a nominal output of 11.1 MVA with lagging<br />
power factor of 0.9 and class “B” insulation.<br />
6.7.1.3 This Power Station was commissioned in the year 1975. Due to continuous<br />
operations of machines <strong>for</strong> past 36 years, efficiency of machines has substantially<br />
decreased and availability of machines has been adversely affected even in spite of<br />
best and timely maintenance and adoption of effective operational strategy.<br />
6.7.2 Determination of Design Energy<br />
6.7.2.1 Kulhal Power Station is a run of the river plant. For computing the Design Energy<br />
two methodologies have been considered i.e. (i) on the basis of average of 10 daily<br />
discharges <strong>for</strong> calculation of NAPAF <strong>for</strong> Run-of-river type plant as per provision of<br />
UERC MYT 2011 Regulations “To be determined plant-wise, based on 10-day Design<br />
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Energy data, moderated by past experience where available /relevant” and (ii) the<br />
maximum generation possible from the Kulhal Power Station considering that there<br />
were no machine and other outages. Due to non-availability of 90% dependable 10<br />
daily inflows pattern as approved in the DPR of the project, Design Energy and<br />
NAPAF have been calculated on the basis of available past reliable 10 daily<br />
discharge data.<br />
(i)<br />
On the basis of Average of 10 daily discharges<br />
Reliable 10 daily (average) discharge data <strong>for</strong> Kulhal Power Station is available<br />
<strong>for</strong> the period April 2001 to March 2012 and the same has been considered<br />
<strong>for</strong> determination of 90% dependable year and Design Energy (this data is<br />
provided in the annexure 6). Reliable data <strong>for</strong> periods prior to April 2001 is<br />
not available with <strong>UJVN</strong> <strong>Limited</strong>. On considering the average daily discharge<br />
data of the years <strong>for</strong> the same period, the 90% dependable year is found to<br />
be 2001-02, as given in the table below:<br />
Table 122: 90% dependable year – Kulhal Power Station<br />
Sl. No.<br />
10 Daily<br />
Discharge<br />
Average<br />
Year %<br />
Dependability<br />
1 124.04 02-03 9.09<br />
2 121.52 05-06 18.18<br />
3 118.63 11-12 27.27<br />
4 117.07 03-04 36.36<br />
5 115.02 08-09 45.45<br />
6 113.81 06-07 54.55<br />
7 113.49 07-08 63.64<br />
8 109.10 10-11 72.73<br />
9 101.01 04-05 81.82<br />
10 98.97 01-02 90.91<br />
11 86.17 09-10 100.00<br />
For computation of possible energy generation corresponding to the<br />
discharge considered, generator and turbine efficiencies have been<br />
considered as 0.968 (at 100% load) and 0.91 as per the past design records<br />
available with <strong>UJVN</strong> <strong>Limited</strong>. Design Energy estimation is sensitive to these<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
assumptions. The plant has been in operation <strong>for</strong> 36 years and it is quite<br />
possible that these parameters may have deteriorated from their designed<br />
values. In the absence of detailed technical study on the present efficiency<br />
levels of generator and turbine of Kulhal Power Station, <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> the<br />
present exercise is constrained to use these efficiency levels <strong>for</strong><br />
computational purpose though the actual efficiency levels are expected to be<br />
much lower than designed values.<br />
The energy generation corresponding to the 10 (ten) daily discharge <strong>for</strong><br />
2001-02 with 95% of the Installed capacity is given in the table below:<br />
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Table 123: Discharge & Generation Data – Kulhal Power Station<br />
Sr.no. Month Net Discharge<br />
(cumecs)<br />
Net Head<br />
(meter)<br />
Power Potential<br />
(kW)<br />
Energy (kWh)<br />
1 April-I 60.6 18.0 9,507.4 22,81,784.2<br />
2 April-II 73.1 18.0 11,474.9 27,53,965.9<br />
3 April-III 84.1 18.0 13,206.8 31,69,630.4<br />
4 May-I 95.1 18.0 14,924.3 35,81,828.6<br />
5 May-II 113.2 18.0 17,539.6 42,09,509.9<br />
6 May-III 102.4 18.0 15,863.1 41,87,861.8<br />
7 June-I 109.7 18.0 16,994.7 40,78,728.7<br />
8 June-II 140.3 18.0 21,749.0 52,19,753.6<br />
9 June-III 151.3 18.0 23,538.4 56,49,224.0<br />
10 July-I 173.2 18.0 26,944.4 64,66,660.7<br />
11 July-II 158.2 18.0 24,603.0 59,04,717.3<br />
12 July-III 152.7 18.0 23,755.1 62,71,345.0<br />
13 Aug-I 158.3 18.0 24,621.0 59,09,047.7<br />
14 Aug-II 149.8 18.0 23,303.6 55,92,854.2<br />
15 Aug-III 169.8 18.0 26,419.3 69,74,698.1<br />
16 Sept-I 178.4 18.0 27,750.9 66,60,221.9<br />
17 Sept-III 159.5 18.0 24,816.6 59,55,972.8<br />
18 Sept-III 129.3 18.0 20,045.4 48,10,895.0<br />
19 Oct-I 109.7 18.0 17,007.9 40,81,890.4<br />
20 Oct-II 91.3 18.0 14,340.9 34,41,816.8<br />
21 Oct-III 83.6 18.0 13,121.5 34,64,084.6<br />
22 Nov-I 81.3 18.0 12,756.5 30,61,569.7<br />
23 Nov-II 66.7 18.0 10,464.9 25,11,582.8<br />
24 Nov-III 63.5 18.0 9,962.6 23,91,013.0<br />
25 Dec-I 59.0 18.0 9,256.6 22,21,574.7<br />
26 Dec-II 59.6 18.0 9,351.7 22,44,407.6<br />
27 Dec-III 56.0 18.0 8,793.8 23,21,572.3<br />
28 Jan-I 50.3 18.0 7,904.2 18,97,015.7<br />
29 Jan-II 50.9 18.0 7,995.3 19,18,869.0<br />
30 Jan-III 50.8 18.0 7,978.9 21,06,430.5<br />
31 Feb-I 58.4 18.0 9,162.4 21,98,967.8<br />
32 Feb-II 81.0 18.0 12,716.4 30,51,924.1<br />
33 Feb-III 1.9 18.0 295.3 56,705.5<br />
34 March-I - 18.0 - -<br />
35 March-II - 18.0 - -<br />
36 March-III 105.2 18.0 16,309.6 43,05,736.0<br />
Annual Energy Generation<br />
13,09,53,860.0<br />
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Table 124: Design Energy-Kulhal Power Station<br />
Sr. No Particulars Unit Value<br />
1 Generation Loss due to uncontrollable situation % 5.35%<br />
2 Energy loss during monsoon and <strong>for</strong>ced outages kWh 70,09,640.9<br />
3 Design Energy kWh 12,39,44,219.1<br />
4 Design Energy (MU) MUs 123.94<br />
5 <strong>Plan</strong>t Availability of FY 01-02 % 86.1<br />
While determining Design Energy, a 5.35% (based on losses experienced<br />
during the operation of the plant) reduction in the energy generation has<br />
been considered. This reduction has been considered to take into account<br />
generation loss due to uncontrollable factors such as <strong>for</strong>ced stoppages of<br />
machines and outages to prevent damage to the machines due to heavy<br />
silting during flash floods, flood passing and grid failure etc. These losses<br />
represent Hydrological risk and other uncontrollable risks which <strong>UJVN</strong><br />
<strong>Limited</strong> cannot control in spite of its robust operating procedures. The figure<br />
of 5.35% has been determined considering generation loss on account of<br />
uncontrollable factors as a percentage of maximum possible generation<br />
without any unit and other outages on the basis of past data of the period<br />
2001-12. The details of these losses are provided in the table below:<br />
Table 125: Uncontrollable Losses – Kulhal Power Station<br />
Sr. No % losses B/D of<br />
Equipment<br />
(1)<br />
1<br />
2<br />
Flushing &<br />
Choking<br />
(2)<br />
System<br />
Condition<br />
(3)<br />
Flood<br />
Passing &<br />
Any Other<br />
Reason (4)<br />
Total (5)<br />
Gross losses as % of Max.<br />
Gross Generation 0.49% 3.01% 0.18% 2.20% 5.84%<br />
Losses due to uncontrollable<br />
factors (5)-(1) 5.35%<br />
(ii) On the basis of Maximum possible plant generation<br />
In view of the limited data size, <strong>UJVN</strong> <strong>Limited</strong> has also considered an alternate<br />
option of computing Design Energy on the basis of actual gross generation<br />
and generation lost on account of various operational & Hydrological reasons<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
<strong>for</strong> which the data is available since 2001-02. The loss of generation (possible<br />
additional generation loss to <strong>UJVN</strong> <strong>Limited</strong>) is on account of (i) Equipment<br />
break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing<br />
and other reasons. <strong>UJVN</strong> <strong>Limited</strong> computes on a daily basis, the generation<br />
opportunity missed by it on account of these reasons. Thus the maximum<br />
energy that Kulhal Power Station possibly could have generated (with 100%<br />
Unit availability and with no generation loss on account of any reason) is the<br />
gross generation by its Units and the generation loss suffered by it. This is an<br />
equally good option <strong>for</strong> an existing plant <strong>for</strong> computing Design Energy when<br />
compared with the method of computing Design Energy on the basis of river<br />
discharge data as it is based on existing unit efficiencies instead of their<br />
design values, considers the impact of other project design related issues and<br />
also operational restrictions imposed on the plant. The maximum possible<br />
year wise generation has been computed in the table below:<br />
Table 126: Year wise Maximum Possible Generation (MU) – Kulhal Power Station<br />
Sr. no.<br />
Actual Gross<br />
Generation<br />
(MU)<br />
Generation<br />
Loss (MU)<br />
Maximum<br />
Possible<br />
Generation<br />
(MU)<br />
On re-arranging the above data in the descending order and considering the<br />
90% dependable year, the Design Energy <strong>for</strong> the Kulhal Power Station is<br />
computed to be 127.55 MUs as given in the table below:<br />
Year %<br />
Dependabi<br />
lity<br />
1 160.94 10.04 170.98 2005-06 9.09<br />
2 157.83 10.60 168.43 2011-12 18.18<br />
3 163.70 3.83 167.53 2002-03 27.27<br />
4 155.33 10.04 165.37 2003-04 36.36<br />
5 142.53 19.00 161.53 2010-11 45.45<br />
6 143.69 15.77 159.46 2008-09 54.55<br />
7 149.76 5.09 154.85 2007-08 63.64<br />
8 148.67 3.62 152.29 2006-07 72.73<br />
9 124.89 10.49 135.38 2001-02 81.82<br />
10 128.82 5.95 134.77 2004-05 90.91<br />
11 112.61 4.10 116.71 2009-10 100.00<br />
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Table 127: Design Energy – Kulhal Power Station<br />
Sr. No. Particular Unit Value<br />
1 Dependable Year FY 2004-05<br />
2 Maximum Possible Generation MUs 134.77<br />
3 <strong>Plan</strong>t Availability <strong>for</strong> FY 2004-05 % 91.00<br />
4 Energy losses due to uncontrollable factors % 5.35%<br />
5 Energy losses due to uncontrollable factors MUs 7.21<br />
6 Design Energy (2)-(5) MUs 127.55<br />
6.7.3 Determination of NAPAF<br />
6.7.3.1 Actual average plant availability during the last 11 years is given in the table below:<br />
Sr. No (1)<br />
Table 128: <strong>Plan</strong>t Availability during FY 2001- 12 – Kulhal Power Station<br />
Month (2)<br />
Total<br />
Running<br />
Hrs. of all<br />
the units<br />
(Hrs.) (3)<br />
Reserve<br />
Outage<br />
(Hrs.) (4)<br />
Forced<br />
Outage<br />
(Hrs.) (5)<br />
<strong>Plan</strong>ned Maintenance<br />
Annual<br />
Mainten<br />
ance<br />
(Hrs.) (6)<br />
Capital<br />
Major<br />
repairs (Hrs.)<br />
(7)<br />
Total hours<br />
(max)<br />
(Hrs.) (8)<br />
<strong>Plan</strong>t<br />
Availability<br />
% (9)<br />
(Col. 3+Col.<br />
4)/Col.8<br />
1 April 13604 8524 615 1017 0 23760 93%<br />
2 May 16689 7773 90 0 0 24552 100%<br />
3 June 17445 5993 322 0 0 23760 99%<br />
4 July 21867 2149 536 0 0 24552 98%<br />
5 August 22400 2068 84 0 0 24552 100%<br />
6 Sept 21734 2012 9 5 0 23760 100%<br />
7 Oct 18780 5513 130 129 0 24552 99%<br />
8 Nov 13044 6013 0 4703 0 23760 80%<br />
9 Dec 10360 7023 605 6564 0 24552 71%<br />
10 Jan 9616 7831 518 6587 0 24552 71%<br />
11 Feb 7872 8291 626 5603 0 22392 72%<br />
12 March 11734 5401 763 6654 0 24552 70%<br />
Total 185145 68591 4298 31262 0 289296 88%<br />
6.7.3.2 The availability plant availability during this period is around 88%.<br />
6.7.4 Special Circumstances and Abnormal Operating Conditions<br />
6.7.4.1 Since its commissioning this Power Station operates on base load during monsoon<br />
period and as a peaking station during non- monsoon period when discharge in the<br />
river reduces and Power Station has to be run on partial load. But due to silting of<br />
reservoir of Asan Barrage, the peaking capacity has also reduced and Power Station<br />
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meets evening and morning peaks during lean discharge period as per the<br />
requirement of SLDC.<br />
6.7.4.2 Study of the available inflow data revealed that the maximum capacity that can be<br />
generated between May to September and partially between October to April.<br />
Lean discharge period is again utilised <strong>for</strong> planned annual or capital maintenance.<br />
Annual loss of energy during Monsoon due to flushing and choking over the period<br />
2001-12 has been calculated in the table 125 and 129, which is around 3% of the<br />
gross generation and 52% of the total generation loss. Such annual loss should<br />
there<strong>for</strong>e be appropriately accounted <strong>for</strong> while computing Design Energy and plant<br />
availability.<br />
6.7.5 <strong>Plan</strong>t Outages and Breakdowns<br />
6.7.5.1 The <strong>for</strong>ced outage data <strong>for</strong> the period 2001-2012 has revealed that 8% of the<br />
total energy loss is on this account. The table below provides the details.<br />
Table 129: % Generation Loss on account of various Factors – Kulhal Power Station<br />
Sr. No. Month↓ B/D of<br />
Equipment<br />
(in MU)<br />
Flushing &<br />
Choking<br />
(in MU)<br />
6.7.6 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
System<br />
Condition<br />
& Grid fail<br />
(in MU)<br />
Flood<br />
passing &<br />
Any Other<br />
Reasons<br />
(in MU)<br />
Total<br />
(in MU)<br />
1 April 0.00 0.00 0.81 0.20 1.01<br />
2 May 0.15 0.09 0.39 0.00 0.63<br />
3 June 3.07 2.28 0.30 0.00 5.89<br />
4 July 4.25 17.87 0.46 2.99 28.38<br />
5 August 0.34 15.53 0.34 9.08 30.32<br />
6 September 0.09 12.00 0.40 15.75 26.09<br />
7 October 0.00 2.42 0.05 4.24 1.31<br />
8 November 0.00 0.56 0.03 0.64 0.12<br />
9 December 0.00 0.08 0.07 0.00 0.07<br />
10 January 0.00 0.00 0.04 0.01 0.07<br />
11 Feburary 0.00 0.00 0.09 2.72 2.81<br />
12 March 0.32 0.03 0.05 1.47 1.85<br />
Total 8.22 50.85 3.04 37.08 98.54<br />
% Generation Lost 8% 52% 3% 38% 100%<br />
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6.7.6.1 The analysis of auxiliary consumption data of past 12 years reveals that the<br />
auxiliary consumption of Kulhal Power Station is around 0.3% of the Gross<br />
Generation. Similarly the trans<strong>for</strong>mation losses of past 12 years <strong>for</strong> which the<br />
data is available has been analysed. The trans<strong>for</strong>mation losses are 2.8% of the<br />
gross generation. Both auxiliary consumption and trans<strong>for</strong>mation losses together<br />
constitute around 3.1 % of the Gross Generation.<br />
Table 130: Auxiliary and Trans<strong>for</strong>mation Losses – Kulhal Power Station<br />
6.7.6.2 <strong>UJVN</strong> Ltd. has taken steps to reduce the auxiliary consumption and trans<strong>for</strong>mation<br />
losses. Data of previous 4 years, which has already been submitted to Hon’ble<br />
UERC, as shown below, shows improvement in auxiliary consumption and<br />
trans<strong>for</strong>mation losses.<br />
6.7.7 Inferences<br />
6.7.7.1 Design Energy<br />
Sr. No. Particulars Unit Value<br />
1 Total Gross Generation (2000-12) MUs 1733.89<br />
2 Total Aux. consumption (2000-12) MUs 5.09<br />
3 Aux. consumption as a % of Gross Generation % 0.3%<br />
4 Total Gross Generation (2000-12) MUs 1733.89<br />
5 Total Trans<strong>for</strong>mation loss (2000-12) MUs 48.14<br />
6 Trans<strong>for</strong>mation loss as a % of Gross Generation % 2.8%<br />
7 Total Aux. and Trans<strong>for</strong>mation losses (2000-12) MUs 53.23<br />
8<br />
Total Aux. and Trans<strong>for</strong>mation losses as a % of<br />
Gross Generation<br />
% 3.1%<br />
Sr. No Year Trans<strong>for</strong>mation<br />
& line losses<br />
Auxiliary<br />
Consumption<br />
1 FY 2010-11 4.3% 0.3%<br />
2 FY 2009-10 1.5% 0.4%<br />
3 FY 2008-09 2.5% 0.3%<br />
4 FY 2007-08 1.3% 0.3%<br />
5 Average 2.4% 0.3%<br />
The discharge data <strong>for</strong> Kulhal Power Station is available on 10 daily (average) basis<br />
<strong>for</strong> the period April 2001 to March 2012. The data <strong>for</strong> each 10 daily average<br />
discharge of the year is selected on the basis of 90% dependable year.<br />
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Correspondingly the Design Energy is calculated (refer the earlier Table 124) to be<br />
123.9 MU after accounting <strong>for</strong> uncontrollable energy loss of 5.4%.<br />
Design Energy was also calculated based on maximum possible generation (refer<br />
the earlier table 127) which comes to 127.55 MU.<br />
Kulhal Power Station is quite old Power Station and has been under operation<br />
since its commissioning in the year 1975. This long operation period has resulted<br />
into excessive wear and tear of the hydro mechanical and electro mechanical<br />
equipment, thereby causing breakdown of machines. The condition of these<br />
equipment is deteriorating with passage of time. <strong>UJVN</strong> Ltd. is taking proactive<br />
action by taking up comprehensive RMU of the Project <strong>for</strong> revival and life<br />
extension of the project.<br />
Keeping in view the long operational life of the project, it is proposed that Design<br />
Energy <strong>for</strong> Kulhal Power Station may be considered as 127.55 MU which is the<br />
Design Energy computed using the second approach mentioned earlier. However,<br />
after completion of the proposed RMU works of the Project, <strong>UJVN</strong> Ltd. shall<br />
approach the Commission to revise the Design Energy of the Project.<br />
6.7.7.2 NAPAF<br />
UERC has prescribed principle <strong>for</strong> its determination of Normative <strong>Plan</strong>t Availability<br />
<strong>for</strong> run of the river plant. Based on the principle prescribed by UERC, the annual<br />
plant availability has been calculated in the earlier tables 124 & 127 which comes<br />
to 86.1% (FY01-02) and 91 %( 2004-05) respectively.<br />
Based on actual running hours, reserve hours, <strong>for</strong>ced outage hours and plant<br />
outage hours <strong>for</strong> last 12 years average annual <strong>Plan</strong>t Availability has been<br />
calculated in the table 127 which comes to 88% and this may be taken as NAPAF<br />
<strong>for</strong> Kulhal Power Station <strong>for</strong> base year of the control period.<br />
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6.7.7.3 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
The auxiliary and trans<strong>for</strong>mation losses exceed the norms set by UERC <strong>for</strong> surface<br />
hydroelectric power generating stations with rotating excitation system by 2.4%.<br />
<strong>UJVN</strong> <strong>Limited</strong> proposes to take remedial measures during the proposed RMU to<br />
reduce these losses within the prescribed limits prescribed by the Commission.<br />
6.7.8 Projections <strong>for</strong> the Control Period<br />
6.7.8.1 RMU works are proposed <strong>for</strong> the Kulhal Power Station. The proposed RMU works<br />
are likely to result in (i) Extension of the <strong>Plan</strong>t life by around 25 years (ii) Higher<br />
<strong>Plan</strong>t Availability (iii) Increased operating efficiencies of plant. The RMU works <strong>for</strong><br />
the plant is likely to be completed during the control period. The unit wise schedule<br />
<strong>for</strong> implementing RMU is as given below:<br />
Name of<br />
Unit<br />
Date of Start Date of<br />
Commissioning<br />
Unit-1 01.10.14 30.06.15<br />
Unit-2 01.10.15 30.06.16<br />
Unit-3 01.10.16 30.06.17<br />
6.7.9 Impact of RMU works on Energy Generation<br />
6.7.9.1 The proposed RMU of Kulhal Power Station is likely to result in increased plant<br />
availability and refurbishment of turbines and generators is likely to result in<br />
increased efficiencies. These measures could yield energy gains of the order of 26<br />
% if the same level of waterdischarge is considered pre and post RMU. Primary<br />
purpose of RMU is life extension of the project apart from increase in generation.<br />
After RMU, generation will increase from 145 MU to 183 MU (as per DPR) subject<br />
to same water discharge<br />
6.7.10 Availability<br />
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6.7.10.1 The annual maintenance schedule and the RMU schedule proposed <strong>for</strong> Kulhal<br />
Power Station under RMU works <strong>for</strong> the Control period is as given below:<br />
FY2013-14<br />
\<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2013 15-12-2013 45 Annual Maintenance<br />
2 16-12-2013 29-01-2014 45 Annual Maintenance<br />
3 30-01-2014 15-03-2014 45 Annual Maintenance<br />
FY2014-15<br />
Unit No. Start Date End date Days Reasons<br />
1 01-10-2014 30-06-2015 273 RMU<br />
2 01-11-2014 15-12-2014 45 Annual Maintenance<br />
3 16-12-2014 29-01-2015 45 Annual Maintenance<br />
FY2015-16<br />
Unit No. Start Date End date Days Reasons<br />
1 16-12-2015 14-01-2016 30 Annual Maintenance<br />
2 01-10-2015 30-06-2016 274 RMU<br />
3 01-11-2015 15-12-2015 45 Annual Maintenance<br />
6.7.10.2 After implementation of RMU works full capacity of the plant is likely to be<br />
available <strong>for</strong> the entire period except monsoon period and annual maintenance<br />
period. The plant availability during the control year considering maintenance<br />
schedule given above and <strong>for</strong>ced outages expected (based on past data) during<br />
monsoon months is expected to be as given below:<br />
Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16<br />
<strong>Plan</strong>t Availability (%) 88% 86.7% 73.6% 66.8%<br />
6.7.10.3 The plant availability expected post RMU is likely to be around 90 %.<br />
6.7.11 Auxiliary Consumption and Trans<strong>for</strong>mation losses<br />
6.7.11.1 The normative auxiliary and trans<strong>for</strong>mation losses can be achieved after<br />
implementation of RMU works wherein energy efficient motors, starters, heating,<br />
air conditioning, illumination, power trans<strong>for</strong>mation and switching system would<br />
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be adopted. The Kulhal Power Station is expected to achieve normative auxiliary<br />
consumption and trans<strong>for</strong>mation loss level after completion of the RMU works.<br />
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6.8 TECHNICAL REPORT OF CHILLA POWER STATION<br />
6.8.1 Introduction<br />
6.8.1.1 Chilla Hydro Power Station with an installed capacity of 144 MW (4x36 MW) is a<br />
run of river scheme constructed on river Ganga 5 Km upstream of holy town<br />
Hardwar and situated in District Pauri Garhwal of Uttarakhand state. The scheme<br />
consists of a 312 m long, 11.5 m high gated diversion barrage at Pashulok, about 4<br />
Km downstream of holy town Rishikesh. The river inflows are diverted via head<br />
regulator with silt ejector constructed 500 m downstream in the bed of lined power<br />
channel and 14.3 km long and 565 cumecs capacity power channel, which ends at<br />
<strong>for</strong>e bay of Chilla Power Station where the water is fed to the generating units<br />
through 4 nos. 4.6 m dia. and 55 m long steel lined penstocks.<br />
6.8.1.2 There are four generating units having vertical Kaplan turbines directly coupled<br />
with synchronous generator. The turbine output is 36 MW <strong>for</strong> a rated net head of<br />
32.5 m. The generators are designed <strong>for</strong> a nominal output of 36 MW with lagging<br />
power factor of 0.9 and class “B” insulation.<br />
6.8.1.3 This Power Station was commissioned in the year 1980-81. Due to operations of<br />
machines <strong>for</strong> past 32 years in highly abrasive silt laden water, efficiency of<br />
machines has substantially decreased and availability of machines has been<br />
adversely affected even in spite of best and timely maintenance.<br />
6.8.2 Determination of Design Energy<br />
6.8.2.1 Chilla Power Station is a run of the river plant. For computing the Design Energy,<br />
two methodologies have been considered i.e. (i) on the basis of average of 10 daily<br />
discharges <strong>for</strong> calculation of NAPAF <strong>for</strong> Run-of-river type plant as per provision of<br />
UERC MYT 2011 Regulations “To be determined plant-wise, based on 10-day Design<br />
Energy data, moderated by past experience where available /relevant” and (ii) the<br />
maximum generation possible from the Chilla Power Station considering that there<br />
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were no machine and other outages. Due to non-availability of 90% dependable 10<br />
daily inflows pattern as approved in the DPR of the project, Design energy and<br />
NAPAF have been calculated on the basis of available past reliable 10 daily<br />
discharge data.<br />
(i) On the basis of average of 10 daily discharges<br />
Reliable 10 daily (average) discharge data <strong>for</strong> Chilla Power Station is available<br />
only <strong>for</strong> the period April 2002 to March 2012 and the same has been<br />
considered <strong>for</strong> determination of Design Energy (this data is provided in the<br />
annexure 7). Reliable data <strong>for</strong> periods prior to April 2002 is not available with<br />
<strong>UJVN</strong> limited. On considering the yearly average daily discharge of the same<br />
period, the 90% dependable year is found to be 2005-06, as given in the table<br />
below:<br />
Table 131: 90% dependable year – Chilla Power Station<br />
Sr. No.<br />
10 Daily<br />
Average<br />
Discharge<br />
Year %<br />
Dependability<br />
1 500.61 11-12 10.00<br />
2 432.68 07-08 20.00<br />
3 425.38 08-09 30.00<br />
4 424.59 10-11 40.00<br />
5 399.43 09-10 50.00<br />
6 393.49 06-07 60.00<br />
7 374.05 04-05 70.00<br />
8 373.43 03-04 80.00<br />
9 346.28 05-06 90.00<br />
10 338.89 02-03 100.00<br />
For computation of possible energy generation corresponding to the<br />
discharge considered, generator and turbine efficiencies have been<br />
considered as 0.97 and 0.92 as per the past design records available with<br />
<strong>UJVN</strong> <strong>Limited</strong>. Design Energy estimation is sensitive to these assumptions.<br />
The plant has been in operation <strong>for</strong> 32 years and it is quite possible that<br />
these parameters may have deteriorated from their design values. In the<br />
absence of detailed technical study on the present efficiency levels of<br />
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generator and turbine of Chilla Power Station, <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> the present<br />
exercise is constrained to use these efficiency levels <strong>for</strong> computational<br />
purpose though the actual efficiency levels are expected to be lower.<br />
The energy generation corresponding to the 10 (ten) daily discharge <strong>for</strong><br />
2005-06 with 95% of the Installed capacity is given in the table below:<br />
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Table 132: Discharge & Generation Data – Chilla Power Station<br />
Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh)<br />
(cumecs) (meter) (kW)<br />
1 April-I 253.4 32.5 72,409.4 1,73,78,255.3<br />
2 April-II 273.0 32.5 78,010.1 1,89,82,463.5<br />
3 April-III 350.6 32.5 1,00,175.3 2,43,75,999.0<br />
4 May-I 408.5 32.5 1,16,729.4 2,84,04,162.4<br />
5 May-II 429.5 32.5 1,22,730.2 2,98,64,351.9<br />
6 May-III 376.0 32.5 1,07,442.5 2,61,44,345.3<br />
7 June-I 417.2 32.5 1,19,215.5 2,90,09,098.1<br />
8 June-II 477.0 32.5 1,36,303.4 3,31,67,161.5<br />
9 June-III 414.6 32.5 1,18,472.5 2,88,28,312.7<br />
10 July-I 426.7 32.5 1,21,930.1 2,96,69,660.0<br />
11 July-II 471.2 32.5 1,34,646.0 3,27,63,871.1<br />
12 July-III 517.6 32.5 1,47,915.3 3,32,88,000.0<br />
13 Aug-I 537.5 32.5 1,53,591.4 3,32,88,000.0<br />
14 Aug-II 534.4 32.5 1,52,705.5 3,32,88,000.0<br />
15 Aug-III 549.1 32.5 1,56,903.5 3,32,88,000.0<br />
16 Sept-I 558.9 32.5 1,59,706.4 3,32,88,000.0<br />
17 Sept-III 520.3 32.5 1,48,676.4 3,32,88,000.0<br />
18 Sept-III 539.7 32.5 1,54,220.0 3,32,88,000.0<br />
19 Oct-I 556.9 32.5 1,59,134.9 3,32,88,000.0<br />
20 Oct-II 547.4 32.5 1,56,420.3 3,32,88,000.0<br />
21 Oct-III 476.1 32.5 1,36,043.6 3,31,03,949.8<br />
22 Nov-I 295.7 32.5 84,496.7 2,05,60,858.8<br />
23 Nov-II 244.4 32.5 69,837.6 1,69,93,824.5<br />
24 Nov-III 208.6 32.5 59,607.7 1,45,04,549.0<br />
25 Dec-I 188.0 32.5 53,721.3 1,30,72,172.7<br />
26 Dec-II 180.5 32.5 51,578.1 1,25,50,676.4<br />
27 Dec-III 183.4 32.5 52,396.4 1,27,49,793.2<br />
28 Jan-I 179.7 32.5 51,349.5 1,24,95,050.1<br />
29 Jan-II 181.4 32.5 51,835.3 1,26,13,256.0<br />
30 Jan-III 173.4 32.5 49,538.9 1,20,54,464.8<br />
31 Feb-I 170.0 32.5 48,577.7 1,18,20,581.7<br />
32 Feb-II 165.7 32.5 47,349.0 1,15,21,590.5<br />
33 Feb-III 164.8 32.5 47,077.5 1,14,55,534.3<br />
34 March-I 160.6 32.5 45,891.7 1,11,66,973.0<br />
35 March-II 164.1 32.5 46,891.8 1,14,10,337.9<br />
36 March-III 124.5 32.5 35,589.0 86,59,998.3<br />
Annual Energy Generation<br />
82,49,13,291.7<br />
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Table 133: Design Energy: Chilla Power Station<br />
Sr. No Particulars Unit Value<br />
1 Generation Loss due to uncontrollable situation % 5.6%<br />
2 Energy loss during monsoon and <strong>for</strong>ced outages kWh 45964112.2<br />
3 Design Energy kWh 778949179.6<br />
4 Design Energy (MU) MUs 778.9<br />
5 <strong>Plan</strong>t Availability of 05-06 % 76.4<br />
While determining Design Energy, a 5.6% (based on losses experienced<br />
during the operation of the plant) reduction in the energy generation has<br />
been considered. This reduction has been considered to take into account<br />
generation loss due to uncontrollable factors such as <strong>for</strong>ced stoppages of<br />
machines and outages to prevent damage to the machines due to heavy<br />
silting during flash floods, flood passing and grid failure. These losses<br />
represent hydrological risk and other uncontrollable risks which <strong>UJVN</strong> <strong>Limited</strong><br />
cannot control in spite of robust operating procedures. The figure of 5.6% has<br />
been determined considering generation loss on account of uncontrollable<br />
factors as a percentage of maximum possible generation without any unit<br />
and other outages on the basis of past data of the period 2002-03 to 2011-<br />
12. The details of the losses are provided in the table below:<br />
Table 134: Uncontrollable Losses – Chilla Power Station<br />
Sr. No % losses B/D of<br />
Equipment<br />
(1)<br />
1<br />
2<br />
Flushing &<br />
Choking<br />
(2)<br />
(ii) On the basis of Maximum possible plant generation<br />
System<br />
Condition<br />
(3)<br />
Flood<br />
Passing &<br />
Any Other<br />
Reason (4)<br />
Total (5)<br />
Gross losses as % of Max<br />
Gross Generation 2.3% 2.0% 0.2% 3.4% 7.9%<br />
Losses due to uncontrollable<br />
factors (5)-(1) 5.6%<br />
In view of the limited data size, <strong>UJVN</strong> <strong>Limited</strong> has also considered an alternate<br />
approach of computing Design Energy on the basis of actual gross generation<br />
and generation lost on account of various operational & hydrological reasons<br />
<strong>for</strong> which the data is available since 2002-03. The loss of generation (possible<br />
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additional generation loss to <strong>UJVN</strong> <strong>Limited</strong>) is on account of (i) Equipment<br />
break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing<br />
and other reasons. <strong>UJVN</strong> <strong>Limited</strong> computes on a daily basis, the generation<br />
opportunity missed by it on account of these reasons. Thus the maximum<br />
that Chilla Power Station possibly could have generated (with 100% Unit<br />
availability and with no generation loss on account of any reason) is the gross<br />
generation by its Units and the generation loss suffered by it. This is an<br />
equally good approach <strong>for</strong> an existing plant <strong>for</strong> computing Design Energy<br />
when compared with the method of computing Design Energy on the basis of<br />
river discharge data as it is based on existing unit efficiencies instead of their<br />
design values, considers the impact of other project design related issues and<br />
also operational restrictions imposed on the plant. The maximum possible<br />
year wise generation has been computed in table below:<br />
Table 135: Year wise Maximum Possible Generation (MU) – Chilla Power Station<br />
Sr. no.<br />
Actual Gross<br />
Generation<br />
(MU)<br />
Generation<br />
Loss (MU)<br />
Maximum<br />
Possible<br />
Generation<br />
(MU)<br />
On re-arranging the above data in the descending order and considering the<br />
90% dependable year, the Design Energy <strong>for</strong> the Chilla Power Station is<br />
computed to be 718.98 MUs as given in table 136 below.<br />
Year %<br />
Dependabi<br />
lity<br />
1 910.02 35.20 945.22 2011-12 10.00<br />
2 826.02 34.44 860.45 2007-08 20.00<br />
3 775.16 66.20 841.35 2010-11 30.00<br />
4 776.58 43.66 820.24 2008-09 40.00<br />
5 688.90 123.11 812.01 2003-04 50.00<br />
6 739.48 57.39 796.87 2009-10 60.00<br />
7 746.07 34.91 780.98 2004-05 70.00<br />
8 740.46 25.17 765.64 2006-07 80.00<br />
9 607.40 154.01 761.41 2002-03 90.00<br />
10 659.18 64.76 723.94 2005-06 100.00<br />
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Table 136: Design Energy – Chilla Power Station<br />
Sr. No. Particular Unit Value<br />
1 Dependable Year FY 2002-03<br />
2 Maximum Possible Generation MUs 761.41<br />
3 <strong>Plan</strong>t Availability <strong>for</strong> FY 2002-03 % 56.71<br />
4 Energy losses due to uncontrollable factors % 5.6%<br />
5 Energy losses due to uncontrollable factors MUs 42.43<br />
6 Design Energy (2)-(5) MUs 718.98<br />
6.8.3 Determination of NAPAF<br />
6.8.3.1 The actual average plant availability during the last 10 years is given in the table<br />
Sr. No (1)<br />
137 below:<br />
Table 137: <strong>Plan</strong>t Availability during FY 2002- 12 – Chilla Power Station<br />
Month (2)<br />
Total<br />
Running<br />
Hrs. of all<br />
the units<br />
(Hrs.) (3)<br />
Reserve<br />
Outage<br />
(Hrs.) (4)<br />
Forced<br />
Outage<br />
(Hrs.) (5)<br />
<strong>Plan</strong>ned Maintenance<br />
Annual<br />
Mainten<br />
ance<br />
(Hrs.) (6)<br />
Capital<br />
Major<br />
repairs (Hrs.)<br />
(7)<br />
Total hours<br />
(max)<br />
(Hrs.) (8)<br />
<strong>Plan</strong>t<br />
Availability<br />
% (9)<br />
(Col. 3+Col.<br />
4)/Col.8<br />
1 April 16904 2223 1210 8463 0 28800 66%<br />
2 May 21091 1605 1205 5859 0 29760 76%<br />
3 June 23244 1476 1029 3051 0 28800 86%<br />
4 July 25973 1195 1725 867 0 29760 91%<br />
5 August 26135 1622 1205 798 0 29760 93%<br />
6 Sept 24879 1294 1288 1339 0 28800 91%<br />
7 Oct 25670 1428 133 2433 0 29760 91%<br />
8 Nov 19489 2325 1547 5535 0 28800 76%<br />
9 Dec 17261 3817 287 8395 0 29760 71%<br />
10 Jan 15731 4018 46 9965 0 29760 66%<br />
11 Feb 14502 3523 397 8746 0 27168 66%<br />
12 March 16476 2766 402 10116 0 29760 65%<br />
Total 247355 27292 10474 65567 0 350688 78%<br />
6.8.3.2 The average plant availability during the last 10 years is around 78%. The Chilla<br />
Power Station experiences <strong>for</strong>ced shut downs during the monsoon seasons. The<br />
reasons <strong>for</strong> these <strong>for</strong>ced shut downs have been provided in the section below.<br />
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6.8.4 Special Circumstances and Abnormal Operating Conditions<br />
6.8.4.1 Since its commissioning, Chilla Power Station operates on base load during<br />
Monsoon but meets evening and morning peaks during lean discharge period as<br />
per the instructions of SLDC. But due to silting of reservoir upstream of Pashulok<br />
(Rishikesh) Barrage the peaking capacity has also reduced.<br />
6.8.4.2 Study of the available inflow data revealed that the maximum capacity can be<br />
generated between May to September and partial between October to April. Lean<br />
discharge period is again utilised <strong>for</strong> planned annual or capital maintenance.<br />
6.8.4.3 The silt which passes through the turbines is highly abrasive and contains<br />
substantial amount of quartzite angular particles which in turn causes severe<br />
damages to the underwater parts of the units, as a result of this the machines are<br />
losing efficiency at a rapid pace. Though ef<strong>for</strong>ts are on to combat this problem<br />
when first unit was opened <strong>for</strong> annual maintenance but no viable solution could be<br />
found. The problem of silt erosion is of such magnitude that <strong>for</strong> the first time in<br />
country runner chambers had to be replaced and special grouting of the same had<br />
to done.<br />
6.8.4.4 Thus, it can be concluded that quite a good amount of energy is lost during<br />
monsoon season which is beyond the control of <strong>UJVN</strong> <strong>Limited</strong>. Annual loss of<br />
energy during monsoon due to flushing and choking over the period 2002-12 has<br />
been calculated in the table 134 and 138, which is around 2% of the gross<br />
generation and 25% of the total generation loss. Such annual loss should there<strong>for</strong>e<br />
be appropriately accounted <strong>for</strong> while computing Design Energy and plant<br />
availability.<br />
6.8.5 <strong>Plan</strong>t Outages and Breakdowns<br />
6.8.5.1 Apart from above facts, when flood recedes lot of silt having substantial quartzite<br />
particles are lodged in cavities and caves on both banks of river which gets<br />
dislodged when level of river starts rising as a result of snow melting during<br />
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summer season and is carried to the machines through water conductor system<br />
causing severe damage to under water parts and frequent plant outages which<br />
becomes beyond the control of <strong>UJVN</strong> <strong>Limited</strong><br />
6.8.5.2 The <strong>for</strong>ced outage data <strong>for</strong> the period 2002-2012 has revealed that 29% of the total<br />
energy loss is on this account. The table below provides the details.<br />
Table 138: % Generation Loss on account of various Factors – Chilla Power Station<br />
Sr. No. Month↓ B/D of<br />
Equipment<br />
(in MU)<br />
Flushing &<br />
Choking<br />
(in MU)<br />
System<br />
Condition<br />
& Grid fail<br />
(in MU)<br />
Flood<br />
passing &<br />
Any Other<br />
Reasons<br />
(in MU)<br />
Total<br />
(in MU)<br />
1 April 5.54 1.06 0.54 4.50 11.63<br />
2 May 13.49 5.24 1.73 20.60 41.06<br />
3 June 7.79 5.55 0.90 97.33 111.57<br />
4 July 44.66 53.26 2.02 34.35 134.30<br />
5 August 45.31 60.42 3.79 37.68 147.19<br />
6 September 56.65 26.59 2.69 51.40 137.32<br />
7 October 4.52 8.05 0.82 17.64 31.03<br />
8 November 1.64 0.00 0.58 1.36 3.58<br />
9 December 2.79 0.00 0.34 1.38 4.51<br />
10 January 0.80 0.00 0.80 0.00 1.60<br />
11 Feburary 1.81 0.29 0.23 1.36 3.70<br />
12 March 2.08 0.00 0.29 9.00 11.36<br />
Total 187.06 160.46 14.73 276.59 638.84<br />
% Generation Lost 29% 25% 2% 43% 100%<br />
6.8.6 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
6.8.6.1 The analysis of auxiliary consumption data of past 10 years reveals that the<br />
auxiliary consumption of Chilla Power Station is around 0.1% of the Gross<br />
Generation. Similarly the trans<strong>for</strong>mation losses of past 10 years <strong>for</strong> which the<br />
data is available has been analysed. These losses are 0.9% of the gross generation.<br />
Both auxiliary and trans<strong>for</strong>mation losses together constitute around 1.0 % of the<br />
Gross Generation.<br />
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Table 139: Auxiliary and Trans<strong>for</strong>mation Losses – Chilla Power Station<br />
Sr. No Particulars Unit Value<br />
1 Total Gross Generation (2002-12) MUs 7469.26<br />
2 Total Aux. consumption (2002-12) MUs 9.05<br />
3 Aux. consumption as a % of Gross Generation % 0.1%<br />
4 Total Gross Generation (2002-12) MUs 7469.26<br />
5 Total Trans<strong>for</strong>mation loss (2002-12) MUs 68.63<br />
6 Trans<strong>for</strong>mation loss as a % of Gross Generation % 0.9%<br />
7 Total Aux. and Trans<strong>for</strong>mation losses (2002-12) MUs 77.68<br />
8<br />
Total Aux. and Trans<strong>for</strong>mation losses as a % of<br />
Gross Generation<br />
% 1.0%<br />
6.8.6.2 <strong>UJVN</strong> <strong>Limited</strong> has taken steps to reduce the auxiliary consumption and<br />
trans<strong>for</strong>mation losses. Data of previous 4 years, which has already been submitted<br />
to Hon’ble UERC, as shown below, shows improvement in auxiliary and<br />
trans<strong>for</strong>mation losses.<br />
Sr. No Year Trans<strong>for</strong>mation<br />
& line losses<br />
Auxiliary<br />
Consumption<br />
1 FY 2010-11 0.19% 0.15%<br />
2 FY 2009-10 0.02% 0.18%<br />
3 FY 2008-09 0.41% 0.17%<br />
4 FY 2007-08 0.16% 0.16%<br />
5 Average 0.19% 0.17%<br />
6.8.7 Inferences<br />
6.8.7.1 Design Energy<br />
The discharge data <strong>for</strong> Chilla Power Station is available on 10 daily (average) basis<br />
<strong>for</strong> the period April 2002 to March 2012. The Design Energy has been computed<br />
on the basis of data <strong>for</strong> each 10 daily average discharge of the 90% dependable<br />
year. Correspondingly the Design Energy is calculated (refer to the earlier Table<br />
133) to be 778.95 MU after accounting <strong>for</strong> uncontrollable energy loss of 5.6%.<br />
Design Energy was also calculated based on maximum possible generation (refer<br />
Table- 136) which comes to 718.98 MU.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Chilla Power Station is quite old Power Station and has been under operation in<br />
silt laden water since its commissioning in the year 1980. This long operation<br />
period has resulted into excessive wear and tear of the hydro mechanical and<br />
electro mechanical equipment, thereby causing breakdown of machines. The<br />
condition of these equipment is deteriorating with passage of time. <strong>UJVN</strong> Ltd. is<br />
taking proactive action by taking up comprehensive RMU of the Project <strong>for</strong> revival<br />
and life extension of the project.<br />
Keeping in view the long operational life of the project, it is proposed that Design<br />
Energy <strong>for</strong> Chilla Power Station may be considered as 718.98 MU which is the<br />
Design Energy computed using the second approach mentioned earlier. However,<br />
after completion of the proposed RMU works of the Project, <strong>UJVN</strong> Ltd. shall<br />
approach the Commission to revise the Design Energy of the Project.<br />
6.8.7.2 NAPAF<br />
UERC has prescribed principle <strong>for</strong> determination of Normative <strong>Plan</strong>t Availability.<br />
Based on the principle given by UERC the annual plant availability has been<br />
calculated in the table 133 which comes to 76.37%.<br />
Based on actual running hours, reserve hours, <strong>for</strong>ced outage hours and plant<br />
outage hours <strong>for</strong> last 10 years plant average annual plant availability has been<br />
calculated to be 78% (refer table no 137) and this may be taken as NAPAF <strong>for</strong><br />
Chilla Power Station <strong>for</strong> the control period.<br />
6.8.7.3 Auxiliary Consumption and Trans<strong>for</strong>mation Loss<br />
As explained in the earlier section, these losses are within the limit of 1%<br />
prescribed by UERC <strong>for</strong> Surface hydroelectric power generating stations with<br />
static excitation system.<br />
6.8.8 Projections <strong>for</strong> the control period<br />
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6.8.8.1 RMU works are proposed <strong>for</strong> the Chilla Power Station. The proposed RMU works<br />
are likely to result in (i) Extension of the <strong>Plan</strong>t life by around 25 years (ii) Higher<br />
<strong>Plan</strong>t Availability (iii) Increased operating efficiencies of plant. The RMU works <strong>for</strong><br />
the entire plant is not likely to be completed during the control period. The unit<br />
wise schedule <strong>for</strong> implementing RMU is as given below:<br />
Name of<br />
Unit<br />
Date of Start Date of<br />
Commissioning<br />
Unit-1 01.11.14 31.03.16<br />
Unit-2 01.06.16 31.03.17<br />
Unit-3 01.06.17 31.03.18<br />
Unit-4 01.06.18 31.03.19<br />
6.8.9 Impact of RMU works on Energy Generation<br />
6.8.9.1 The proposed RMU of Chilla Power Station is likely to result in increased availability<br />
of plants and refurbishment of turbines and generators is likely to lead to increased<br />
efficiencies. On account of these measures the annual generation is likely to<br />
increase. Primary purpose of RMU is life extension of the project apart from<br />
increase in generation. After RMU, generation will increase from 684 MU (Pre-Tehri<br />
scenario) to 1074 MU (after commissioning of Tehri Hydroelectric Project). Capacity<br />
of machine will enhance from present 36 MW to 43.2 MW and install capacity of<br />
plant will increase from 144 MW to 172.8 MW on account of RMU.<br />
6.8.10 Availability<br />
6.8.10.1 The annual maintenance schedule and the RMU schedule proposed <strong>for</strong> Chilla<br />
Power Station under RMU works <strong>for</strong> the Control period is as given below:<br />
2013-14<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2013 15-12-2013 45 Annual Maintenance<br />
2 11-12-2013 24-01-2014 45 Annual Maintenance<br />
3 25-01-2014 10-03-2014 45 Annual Maintenance<br />
4 06-03-2014 19-04-2014 45 Annual Maintenance<br />
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2014-15<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2014 31-03-2016 517 RMU<br />
2 11-12-2014 24-01-2015 45 Annual Maintenance<br />
3 25-01-2015 10-03-2015 45 Annual Maintenance<br />
4 06-03-2015 19-04-2015 45 Annual Maintenance<br />
2015-16<br />
Unit No. Start Date End date Days Reasons<br />
1 01-11-2014 31-03-2016 517 RMU<br />
2 11-12-2015 24-01-2016 45 Annual Maintenance<br />
3 25-01-2016 09-03-2016 45 Annual Maintenance<br />
4 06-03-2016 19-04-2016 45 Annual Maintenance<br />
6.8.10.2 After implementation of RMU works, full capacity of the plant is likely to be<br />
available <strong>for</strong> the entire year except during monsoon period and annual<br />
maintenance period. The plant availability during the control year considering<br />
maintenance schedule given above and <strong>for</strong>ced outages expected (based on past<br />
data) during monsoon months is expected to be as given below:<br />
Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16<br />
<strong>Plan</strong>t Availability (%) 78% 86.0% 77.4% 63.6%<br />
6.8.10.3 The plant availability expected post RMU is likely to be around 88 %.<br />
6.8.11 Auxiliary Consumption and Trans<strong>for</strong>mation losses<br />
6.8.11.1 As stated above the auxiliary and trans<strong>for</strong>mation losses are within the limits<br />
prescribed by the Commission. During the control period these are expected to be<br />
within the limits prescribed by the Commission.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
6.9 TECHNICAL REPORT OF KHATIMA POWER STATION<br />
6.9.1 Introduction<br />
6.9.1.1 Khatima Power Station, with an Installed Capacity of 41.4 MW (3X13.8 MW) is<br />
situated at Lohiahead (Khatima), District Udham Singh Nagar of Uttarakhand.<br />
Khatima hydro power Station is an irrigation canal based project. The project is<br />
located at a distance of about 6 km from Khatima town and connected by road.<br />
Meter Gauge rail connection is also available up to Khatima town.<br />
6.9.1.2 The Sharda Canal / Power Channel draws water from river Sharda through<br />
Banbasa Barrage located at a distance of about 16 km upstream of the Power<br />
Station at Banbasa near Tanakpur. The Power Station units were commissioned in<br />
1955 & 1956. Three English Electric make generating units of 13.8 MW capacity<br />
each have been installed, totalling to aggregate capacity of 41.4 MW. The Power<br />
Station has been operating since more than 55 years & maximum capacity of 41.4<br />
MW has been achieved in the past.<br />
6.9.1.3 Power generated from Kaplan turbines at 11 kV is stepped up to 132 kV via three<br />
phase 17.5 MVA trans<strong>for</strong>mers. The generated power is evacuated through 2 nos.<br />
132 kV feeders to 132 kV Dohna substation (Bareilly) and 3 nos. 33 kV feeders (one<br />
through 40 MVA, 132/33 kV trans<strong>for</strong>mer and other 2 nos. feeders through 20 MVA,<br />
132 / 33 kV trans<strong>for</strong>mer) to Diesel PH, industrial supply and Tanakpur Project of<br />
NHPC respectively.<br />
6.9.1.4 Due to long operation of about 55 years, the operating efficiency of the machines<br />
has gone down considerably. Generating units have derated and the condition of<br />
their auxiliaries, instruments, protective relays & control equipment have<br />
deteriorated to such an extent that the combined output of the Power Station is<br />
restricted to about 25-28 MW against the rated capacity of 41.4 MW.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
6.9.1.5 The Power Station is located on the downstream of the Banbasa Barrage over river<br />
Sharda at a distance of 1.6 km on the irrigation canal which takes off from the<br />
Barrage. The Power Station was commissioned in the year 1956.<br />
6.9.1.6 The surface Power Station comprising 3 units of 13.8 MW each with vertical Kaplan<br />
turbines of 19200 BHP output coupled with synchronous generator of 17.25 MW<br />
rated output, 0.8 lagging power factor is located on the unlined irrigation canal.<br />
The water of canal is utilized <strong>for</strong> the irrigation purpose in the command area of the<br />
canal.<br />
6.9.1.7 The Power Station has a design head of 17.98 m. The Khatima Power Station is a<br />
low head plant with a design discharge of 269 cum.<br />
6.9.1.8 The discharge in the canal is regulated by UP Irrigation Department depending<br />
upon the irrigation requirement in the command area of the Irrigation canal and is<br />
also limited to the capacity of the escape channel downstream of the Power Station<br />
in case there is no demand.<br />
6.9.1.9 Due to operations of machines <strong>for</strong> past so many years, efficiency of machines has<br />
substantially decreased and availability of machines has been adversely affected, in<br />
spite of best and timely maintenance.<br />
6.9.2 Determination of Design Energy<br />
6.9.2.1 Khatima Power Station is a run of the river type plant. For computing the Design<br />
Energy two methodologies have been considered i.e. (i) on the basis of average of<br />
10 daily discharges <strong>for</strong> calculation of NAPAF <strong>for</strong> Run-of-river type plant as per<br />
provision of UERC MYT 2011 Regulations “To be determined plant-wise, based on<br />
10-day Design Energy data, moderated by past experience where available<br />
/relevant ”and (ii) the maximum generation possible from the Khatima Power<br />
Station considering that there were no machine and other outages. Due to nonavailability<br />
of 90% dependable 10 daily inflows pattern as approved in the DPR of<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
the project, Design Energy and NAPAF have been calculated on the basis of<br />
available past reliable 10 daily discharge data.<br />
(i) On the basis of Average of 10 daily discharges<br />
Reliable 10 daily (average) discharge data <strong>for</strong> Khatima Power Station is<br />
available <strong>for</strong> the period April 2001 to March 2012 and the same has been<br />
considered <strong>for</strong> determination of 90% dependable year and Design Energy This<br />
data is provided in the annexure no. 8. On considering the yearly average<br />
daily discharge data <strong>for</strong> the same period, the 90% dependable year is found<br />
to be 2009-10, as given in table below:<br />
Table 140: 90% dependable year – Khatima Power Station<br />
Sr. No.<br />
10 Daily<br />
Average<br />
Discharge<br />
Year %<br />
Dependability<br />
1 219.30 04-05 9.09<br />
2 215.31 02-03 18.18<br />
3 211.66 05-06 27.27<br />
4 209.89 07-08 36.36<br />
5 208.17 01-02 45.45<br />
6 206.70 06-07 54.55<br />
7 202.94 10-11 63.64<br />
8 199.35 03-04 72.73<br />
9 194.12 08-09 81.82<br />
10 193.98 09-10 90.91<br />
11 153.61 11-12 100.00<br />
For computation of possible energy generation corresponding to the<br />
discharge considered, generator and turbine efficiencies have been<br />
considered as 0.96 and 0.90 as per the past design records available with<br />
<strong>UJVN</strong> <strong>Limited</strong>. Design Energy estimation is sensitive to these assumptions.<br />
The plant has been in operation <strong>for</strong> last 55 years and it is quite possible that<br />
these parameters may have deteriorated from their design values. In the<br />
absence of detailed technical study on the present efficiency levels of<br />
generator and turbine of Khatima Power Station, <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> the<br />
present exercise is constrained to use these efficiency levels <strong>for</strong><br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
computational purpose though the actual efficiency levels are expected to be<br />
lower.<br />
The energy generation corresponding to the 10 daily discharges <strong>for</strong> 2009-10<br />
with 95% of the Installed capacity is given in the table below:<br />
Table 141: Discharge & Generation Data – Khatima Power Station<br />
Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh)<br />
(cumecs) (meter) (kW)<br />
1 April-I 103.3 18.0 15,739.0 37,77,357.6<br />
2 April-II 116.9 18.0 17,817.3 42,76,144.5<br />
3 April-III 126.8 18.0 19,330.7 46,39,359.9<br />
4 May-I 166.7 18.0 25,397.6 60,95,432.3<br />
5 May-II 144.2 18.0 21,976.4 52,74,339.6<br />
6 May-III 220.7 18.0 33,635.1 88,79,669.7<br />
7 June-I 235.2 18.0 35,845.1 86,02,830.5<br />
8 June-II 168.2 18.0 25,628.9 61,50,945.1<br />
9 June-III 269.6 18.0 41,086.1 94,39,200.0<br />
10 July-I 276.8 18.0 42,183.5 94,39,200.0<br />
11 July-II 318.5 18.0 48,542.2 94,39,200.0<br />
12 July-III 318.6 18.0 48,555.3 1,03,83,120.0<br />
13 Aug-I 291.5 18.0 44,423.6 94,39,200.0<br />
14 Aug-II 282.6 18.0 43,068.2 94,39,200.0<br />
15 Aug-III 301.7 18.0 45,974.7 1,03,83,120.0<br />
16 Sept-I 304.6 18.0 46,426.8 94,39,200.0<br />
17 Sept-III 302.0 18.0 46,021.6 94,39,200.0<br />
18 Sept-III 298.0 18.0 45,410.6 94,39,200.0<br />
19 Oct-I 210.4 18.0 32,061.4 76,94,740.2<br />
20 Oct-II 115.1 18.0 17,542.4 42,10,171.2<br />
21 Oct-III 117.3 18.0 17,875.4 47,19,107.8<br />
22 Nov-I 132.5 18.0 20,198.9 48,47,740.2<br />
23 Nov-II 129.4 18.0 19,718.6 47,32,468.2<br />
24 Nov-III 152.8 18.0 23,290.0 55,89,602.8<br />
25 Dec-I 181.6 18.0 27,670.5 66,40,928.6<br />
26 Dec-II 197.8 18.0 30,144.5 72,34,688.0<br />
27 Dec-III 177.6 18.0 27,065.2 71,45,204.6<br />
28 Jan-I 172.1 18.0 26,221.9 62,93,248.5<br />
29 Jan-II 158.4 18.0 24,136.3 57,92,701.0<br />
30 Jan-III 137.3 18.0 20,919.3 55,22,697.4<br />
31 Feb-I 135.7 18.0 20,674.0 49,61,769.3<br />
32 Feb-II 158.4 18.0 24,136.7 57,92,804.6<br />
33 Feb-III 141.5 18.0 21,558.5 41,39,226.7<br />
34 March-I 148.4 18.0 22,619.4 54,28,657.0<br />
35 March-II 131.3 18.0 20,003.0 48,00,720.0<br />
36 March-III 140.0 18.0 21,332.8 56,31,858.8<br />
Annual Energy Generation<br />
24,51,54,254.1<br />
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Table 142: Design Energy- Khatima Power Station<br />
Sr. No Particulars Unit Value<br />
1 Generation Loss due to uncontrollable situation % 4.7%<br />
2 Energy loss during monsoon and <strong>for</strong>ced outages kWh 11464688.3<br />
3 Design Energy kWh 233689565.8<br />
4 Design Energy (MU) MUs 233.7<br />
5 <strong>Plan</strong>t Availability of FY 09-10 % 84.8<br />
While determining Design Energy, a 4.7% (based on losses experienced<br />
during the operation of the plant) reduction in the energy generation has<br />
been considered. This reduction has been considered to take into account<br />
generation loss due to uncontrollable factors such as <strong>for</strong>ced stoppages of<br />
machines and outages to prevent damage to the machines due to heavy<br />
silting during flash floods, flood passing and grid failure etc. These losses<br />
represent hydrological risk and other controllable risks which <strong>UJVN</strong> <strong>Limited</strong><br />
cannot control in spite of its robust operating procedures. The figure of 4.7 %<br />
has been determined considering generation loss on account of<br />
uncontrollable factors as a percentage of maximum possible generation<br />
without any unit and other outages on the basis of past data of the period<br />
2000-12. The details of these losses are provided in the table below:<br />
Table 143: Uncontrollable Losses – Khatima Power Station<br />
Sr. No % losses B/D of<br />
Equipment<br />
(1)<br />
1<br />
2<br />
Flushing &<br />
Choking<br />
(2)<br />
(ii) On the basis of Maximum possible plant generation<br />
System<br />
Condition<br />
(3)<br />
Flood<br />
Passing &<br />
Any Other<br />
Reason (4)<br />
Total (5)<br />
Gross losses as % of Max.<br />
Gross Generation 2.4% 3.5% 1.2% 0.0% 7.1%<br />
Losses due to uncontrollable<br />
factors (5)-(1) 4.7%<br />
In view of the limited data size, <strong>UJVN</strong> <strong>Limited</strong> has also considered an alternate<br />
option of computing Design Energy on the basis of actual gross generation<br />
and generation lost on account of various operational & hydrological reasons<br />
<strong>for</strong> which the data is available since 2000-01. The loss of generation (possible<br />
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additional generation loss to <strong>UJVN</strong> <strong>Limited</strong>) is on account of (i) Equipment<br />
break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing<br />
and other reasons. <strong><strong>UJVN</strong>L</strong> computes on a daily basis, the generation<br />
opportunity missed by it on account of these reasons. Thus the maximum<br />
that Khatima Power Station possibly could have generated (with 100% Unit<br />
availability and with no generation loss on account of any reason) is the gross<br />
generation by its Units and the generation loss suffered by it. This is an<br />
equally good approach <strong>for</strong> an existing plant <strong>for</strong> computing Design Energy<br />
when compared with the method of computing Design Energy on the basis of<br />
river discharge data as it is based on existing unit efficiencies instead of their<br />
design values, considers the impact of other project design related issues and<br />
also operational restrictions imposed on the plant. The maximum possible<br />
year wise generation has been computed in table below:<br />
Table 144: Year wise Maximum Possible Generation (MU) – Khatima Power Station<br />
Sr. no.<br />
Actual Gross<br />
Generation<br />
(MU)<br />
Generation<br />
Loss (MU)<br />
On re-arranging the above data in the descending order and considering the<br />
90% dependable year, the Design Energy <strong>for</strong> the Khatima Power Station after<br />
accounting <strong>for</strong> losses on account of uncontrollable factors is computed to be<br />
152.57 MUs as given in table below;<br />
Maximum<br />
Possible<br />
Generation<br />
(MU)<br />
Year %<br />
Dependabi<br />
lity<br />
1 165.01 26.17 191.18 2005-06 8.33<br />
2 183.42 7.74 191.16 2004-05 16.67<br />
3 163.07 20.87 183.94 2002-03 25.00<br />
4 171.53 9.94 181.48 2001-02 33.33<br />
5 165.49 12.99 178.48 2000-01 41.67<br />
6 154.04 18.75 172.79 2006-07 50.00<br />
7 157.24 14.48 171.72 2003-04 58.33<br />
8 164.00 3.68 167.68 2011-12 66.67<br />
9 155.43 10.18 165.60 2007-08 75.00<br />
10 155.94 6.16 162.10 2010-11 83.33<br />
11 151.01 9.05 160.06 2009-10 91.67<br />
12 140.88 6.64 147.52 2008-09 100.00<br />
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6.9.3 Determination of NAPAF<br />
Table 145: Design Energy – Khatima Power Station<br />
Sr. No. Particular Unit Value<br />
1 Dependable Year FY 2009-10<br />
2 Maximum Possible Generation MUs 160.06<br />
3 <strong>Plan</strong>t Availability <strong>for</strong> FY 2009-10 % 84.82<br />
4 Energy losses due to uncontrollable factors % 4.7%<br />
5 Energy losses due to uncontrollable factors MUs 7.49<br />
6 Design Energy (2)-(5) MUs 152.57<br />
6.9.3.1 Actual average plant availability during the last 12 years is given in the table below:<br />
Table 146: <strong>Plan</strong>t Availability during FY 2000 - 12 – Khatima Power Station<br />
Sr. No (1)<br />
Month (2)<br />
Total<br />
Running<br />
Hrs. of all<br />
the units<br />
(Hrs.) (3)<br />
Reserve<br />
Outage<br />
(Hrs.) (4)<br />
Forced<br />
Outage<br />
(Hrs.) (5)<br />
<strong>Plan</strong>ned Maintenance<br />
Annual<br />
Mainten<br />
ance<br />
(Hrs.) (6)<br />
Capital<br />
Major<br />
repairs (Hrs.)<br />
(7)<br />
Total hours<br />
(max)<br />
(Hrs.) (8)<br />
<strong>Plan</strong>t<br />
Availability<br />
% (9)<br />
(Col. 3+Col.<br />
4)/Col.8<br />
1 April 14810 2777 1431 6902 0 25920 68%<br />
2 May 17705 2634 3247 3198 0 26784 76%<br />
3 June 19192 1706 3132 1890 0 25920 81%<br />
4 July 22471 1248 2564 501 0 26784 89%<br />
5 August 23437 1274 1766 307 0 26784 92%<br />
6 Sept 22841 1470 1341 268 0 25920 94%<br />
7 Oct 21129 4465 829 361 0 26784 96%<br />
8 Nov 15813 4109 1090 4908 0 25920 77%<br />
9 Dec 16216 2789 111 7668 0 26784 71%<br />
10 Jan 14568 3419 526 8271 0 26784 67%<br />
11 Feb 11975 3579 1102 7752 0 24408 64%<br />
12 March 13327 4695 1222 7540 0 26784 67%<br />
Total 213484 34165 18361 49566 0 315576 78%<br />
6.9.3.2 The average plant availability <strong>for</strong> the period 2000-12 is around 78%.The Khatima<br />
plant experiences <strong>for</strong>ced shut downs during the monsoon seasons. The reasons <strong>for</strong><br />
these <strong>for</strong>ced shut downs have been provided in the section below.<br />
6.9.4<br />
6.9.5 Special Circumstances and Abnormal Operating Conditions<br />
6.9.5.1 Since its commissioning, Khatima Power Station operates on base load during<br />
monsoon and non-monsoon periods. Study of the available inflow data revealed<br />
that the maximum capacity can be generated between May to September and<br />
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partially between October to April. Lean discharge period is again utilised <strong>for</strong><br />
planned annual or capital maintenance.<br />
6.9.5.2 Annual loss of energy during Monsoon due to flushing and choking over the period<br />
2000-12 has been calculated in the tables 143 and 147, which is around 3.5% of the<br />
gross generation and 49% of the total generation loss. Such annual loss should<br />
there<strong>for</strong>e be appropriately accounted <strong>for</strong> while computing Design Energy and plant<br />
availability.<br />
6.9.6 <strong>Plan</strong>t Outages and Breakdowns<br />
6.9.6.1 The <strong>for</strong>ced outage data <strong>for</strong> the period 2000-2012 has revealed that 34% of the<br />
total energy loss is on this account. The table below provides the details.<br />
Table 147: % Generation Loss on account of various Factors – Khatima Power Station<br />
Sr. No. Month↓ B/D of<br />
Equipment<br />
(in MU)<br />
Flushing &<br />
Choking<br />
(in MU)<br />
System<br />
Condition<br />
& Grid fail<br />
(in MU)<br />
Flood<br />
passing &<br />
Any Other<br />
Reasons<br />
(in MU)<br />
Total<br />
(in MU)<br />
1 April 4.03 2.30 1.27 0.00 7.59<br />
2 May 6.07 3.01 3.89 0.00 12.97<br />
3 June 8.29 6.61 7.14 0.00 22.04<br />
4 July 14.78 13.63 3.33 0.00 31.73<br />
5 August 6.88 14.91 3.12 0.00 24.92<br />
6 September 4.53 16.47 1.36 0.00 22.36<br />
7 October 1.54 8.19 0.90 0.00 10.64<br />
8 November 1.45 2.75 0.69 0.00 4.89<br />
9 December 0.23 1.09 0.68 0.00 2.00<br />
10 January 0.01 1.02 1.26 0.00 2.29<br />
11 Feburary 0.01 0.84 1.19 0.00 2.04<br />
12 March 1.85 0.76 0.58 0.00 3.19<br />
Total 49.67 71.57 25.41 0.00 146.64<br />
Generation Lost 34% 49% 17% 0% 100%<br />
6.9.7<br />
6.9.8 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
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6.9.8.1 The analysis of auxiliary consumption data of past 12 years reveals that the<br />
auxiliary consumption of Khatima Power Station is around 0.3% of the Gross<br />
Generation. Similarly the trans<strong>for</strong>mation losses of past 12 years <strong>for</strong> which the<br />
data is available has been analysed. The trans<strong>for</strong>mation losses are 0.5% of the<br />
gross generation. Both auxiliary and trans<strong>for</strong>mation losses together constitute<br />
around 0.8 % of the Gross Generation.<br />
Table 148: Auxiliary and Trans<strong>for</strong>mation Losses – Khatima Power Station<br />
Sr. No. Particulars Unit Value<br />
1 Total Gross Generation (2000-12) MUs 1927.06<br />
2 Total Aux. consumption (2000-12) MUs 5.71<br />
3 Aux. consumption as a % of Gross Generation % 0.3%<br />
4 Total Gross Generation (2000-12) MUs 1927.06<br />
5 Total Trans<strong>for</strong>mation loss (2000-12) MUs 9.64<br />
6 Trans<strong>for</strong>mation loss as a % of Gross Generation % 0.5%<br />
7 Total Aux. and Trans<strong>for</strong>mation losses (2000-12) MUs 15.34<br />
8<br />
Total Aux. and Trans<strong>for</strong>mation losses as a % of<br />
Gross Generation<br />
% 0.8%<br />
6.9.9 Inferences<br />
6.9.9.1 Design Energy<br />
The discharge data <strong>for</strong> Khatima Power Station is available on 10 daily (average)<br />
basis <strong>for</strong> the period April 2001 to March 2012. The data <strong>for</strong> each 10 daily average<br />
discharge of the year is selected <strong>for</strong> 90% dependable year. Correspondingly the<br />
Design Energy is calculated (refer the earlier table 142) to be 233.7 MU after<br />
accounting <strong>for</strong> uncontrollable energy loss of 4.7%.<br />
Design Energy has also been calculated based on maximum possible generation<br />
(refer to the earlier Table 145) which comes to 152.57 MU.<br />
Khatima Power Station is quite old Power Station and has been under operation<br />
since its commissioning in the year 1955. This long operation period has resulted<br />
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into excessive wear and tear of the hydro mechanical and electro mechanical<br />
equipment, thereby causing breakdown of machines. The condition of these<br />
equipment is deteriorating with passage of time. <strong>UJVN</strong> Ltd. is taking proactive<br />
action by taking up comprehensive RMU of the Project <strong>for</strong> revival and life<br />
extension of the project.<br />
Keeping in view the long operational life of the project, it is proposed that Design<br />
Energy <strong>for</strong> Khatima Power Station may be considered as 152.57 MU which is the<br />
Design Energy computed using the second approach mentioned earlier. However,<br />
after completion of the proposed RMU works of the Project, <strong>UJVN</strong> Ltd. shall<br />
approach the Commission to revise the Design Energy of the Project.<br />
6.9.9.2 NAPAF<br />
UERC has prescribed principle <strong>for</strong> its determination of NAPAF. Based on the<br />
principle given by UERC, the annual plant availability has been calculated in the<br />
earlier table 142, which comes to 84.82%.<br />
Based on actual running hours, reserve hours, <strong>for</strong>ced outage hours and plant<br />
outage hours <strong>for</strong> last 12 years average annual plant availability has been<br />
calculated in the earlier table 146 which comes to only 78% and this may be taken<br />
as NAPAF <strong>for</strong> Khatima Power Station <strong>for</strong> control period.<br />
6.9.9.3 Auxiliary Consumption and Trans<strong>for</strong>mation Loss<br />
As explained in the earlier section these losses exceed the limit of 0.7% by 0.1%<br />
prescribed by UERC <strong>for</strong> Surface hydroelectric power generating stations with<br />
rotary excitation system. <strong>UJVN</strong> <strong>Limited</strong> proposes to take remedial measures<br />
during the proposed RMU to reduce these losses within the prescribed limits<br />
prescribed by the Commission.<br />
6.9.10 Projection <strong>for</strong> the control period<br />
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6.9.10.1 RMU works are proposed <strong>for</strong> the Khatima Power Station. The proposed RMU<br />
works are likely to result in (i) Extension of the <strong>Plan</strong>t life by around 25 years (ii)<br />
Higher <strong>Plan</strong>t Availability (iii) Increased operating efficiencies of plant. The RMU<br />
works <strong>for</strong> the plant is likely to be completed during the control period. The unit<br />
wise schedule <strong>for</strong> implementing RMU is as given below:<br />
Name of<br />
Unit<br />
Date of Start Date of<br />
Commissioning<br />
Unit-1 01.10.12 31.03.14<br />
Unit-2 01.04.14 31.01.15<br />
Unit-3 01.01.15 31.10.15<br />
6.9.11 Impact of RMU works on Energy generation<br />
6.9.11.1 The proposed RMU of Khatima Power Station is likely to result in increased plant<br />
availability and refurbishment of turbines and generators is likely to result in<br />
increased efficiencies. These measures could yield energy gains of the order of<br />
57.7% if the same level of water discharge is considered pre and post RMU. Primary<br />
purpose of RMU is life extension of the project apart from increase in generation.<br />
After RMU, generation will increase from 149.03 MU to 235 MU (as per DPR)<br />
subject to same water discharge.<br />
6.9.12 Availability<br />
6.9.12.1 The annual maintenance schedule and the maintenance schedule proposed <strong>for</strong><br />
Khatima Power Station under RMU works <strong>for</strong> the Control period is as given below:<br />
FY2013-14<br />
Unit No. Start Date End date Days Reasons<br />
1 01-10-2012 31-03-2014 547 RMU<br />
2 15-12-2013 31-12-2013 17<br />
Interim Maintenance, as<br />
Unit is to be taken under<br />
RMU soon<br />
3 10-01-2014 23-02-2014 45 Annual Maintenance<br />
FY2014-15<br />
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Unit No. Start Date End date Days Reasons<br />
1 15-11-2014 29-12-2014 45 Annual Maintenance<br />
2 01-04-2014 31-01-2015 306 RMU<br />
3 01-01-2015 31-10-2015 304 RMU<br />
FY2015-16<br />
Unit No. Start Date End date Days Reasons<br />
1 12-11-2015 26-12-2015 45 Annual Maintenance<br />
2 01-01-2016 14-02-2016 45 Annual Maintenance<br />
3 15-02-2016 05-03-2016 20<br />
General inspection,<br />
interim repairs may be<br />
carried out as the RMU<br />
work of the unit has just<br />
completed<br />
6.9.12.2 The plant availability during the control year considering maintenance schedule<br />
given above and <strong>for</strong>ced outages expected (based on past data) during monsoon<br />
months is expected to be as given below:<br />
Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16<br />
<strong>Plan</strong>t Availability (%) 72% 58.0% 56.4% 65.5%<br />
6.9.12.3 The plant availability expected post RMU is likely to be around 80 %.<br />
6.9.13 Auxiliary Consumption and Trans<strong>for</strong>mation losses<br />
6.9.13.1 As explained in the earlier section these losses exceed the limit of 0.7% by 0.1%<br />
prescribed by UERC <strong>for</strong> Surface hydroelectric power generating stations with rotary<br />
excitation system. Khatima Power Station is expected to achieve normative<br />
auxiliary consumption and trans<strong>for</strong>mation loss level after completion of the RMU<br />
works.<br />
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6.10 TECHNICAL REPORT OF RAMGANGA POWER STATION<br />
6.10.1 Introduction:<br />
6.10.1.1 Ramganga Power Station has an Installed capacity of 198 MW (3X66 MW).<br />
Ramganga Power Station is a Reservoir based scheme on river Ramganga located<br />
near the famous Jim Corbett Park in district Pauri Garwhal. It utilizes water stored<br />
<strong>for</strong> irrigation purpose. The water release from Ramganga Dam is regulated by the<br />
UP Irrigation Department. The generation is dependent on the rain in the<br />
catchment area and on the drawl of water <strong>for</strong> irrigation purpose in the command<br />
area of the canal in the state of Uttar Pradesh.<br />
6.10.1.2 The surface Power Station is located at the toe of the dam and houses 3 units of 66<br />
MW each with vertical Francis turbines of 92400 HP. The Ramganga Power Station<br />
is a medium head scheme with a design head of 84.4 m and a design discharge of<br />
285 cum.<br />
6.10.1.3 The project has unique challenges in operation due to restriction imposed on the<br />
release of water in the water conductor system by the UP irrigation Department<br />
which is dependent on the demand of water in the command area of the canal in<br />
Uttar Pradesh based on the irrigation requirement.<br />
6.10.2 Water Availability<br />
6.10.2.1 Ramganga Power Station utilizes discharge from Ramganga reservoir <strong>for</strong> power<br />
generation. Since this is an irrigation based Power Station, the water released from<br />
the reservoir is as per irrigation requirement in the downstream areas of Uttar<br />
Pradesh. Water discharge utilized <strong>for</strong> power generation is measured by irrigation<br />
authorities.<br />
6.10.2.2 The water availability from the reservoir <strong>for</strong> generation during different periods of<br />
the year is as follows:-<br />
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6.10.2.3 Summer<br />
During summer water discharge from the reservoir can cater to two units<br />
operating at full capacity or three units operating at part capacity.<br />
6.10.2.4 Winter<br />
During winter, due to greater demand of water <strong>for</strong> irrigation purposes in western<br />
part of U.P, the water discharge from the reservoir is highest and generally all the<br />
three units operate at about 85-90% of full capacity.<br />
6.10.2.5 Rainy Season<br />
During rainy season water is stored in the dam. Generally, this period falls<br />
between 16th June to 15th October of each year and to utilize this period<br />
effectively annual maintenance of Ramganga Power Station is planned. However,<br />
if during this period the reservoir level reaches 365.3 m, the maintenance of the<br />
machines are deferred and the machines are kept in ready condition to avoid any<br />
wastage of water.<br />
6.10.2.6 The maximum average discharge recorded in the reservoir is 42049 cusecs in ten<br />
days block from 21-31 December and minimum average discharge of 102 cusecs in<br />
ten days block from 1-10 September.<br />
6.10.3 Head Availability<br />
6.10.3.1 Head Race Level<br />
At the upstream of Power Station there is a spillway (on the right bank) <strong>for</strong> bypassing<br />
the surplus water to tail race. Water is released to the spillway from<br />
headrace through a radial gate system, but this system is rarely used <strong>for</strong> spilling of<br />
water as generally all the water is discharged through the machines. Normally,<br />
the head race level varies from maximum to minimum during October to June. It<br />
is highest in October and lowest in June.<br />
6.10.3.2 Tail Race Level<br />
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6.10.3.3 Tail race level varies according to the generation from the Project. It is minimum<br />
in the month of October and maximum in the month of June.<br />
The theoretical (as per original DPR prepared during construction) normal,<br />
maximum and minimum tail race levels are as follows:-<br />
• Normal Tail water level : 258.700 m<br />
• Maximum Tail water level : 278.000 m<br />
• Minimum Tail water level : 256.100 m<br />
6.10.4 Effect of discharge through spill way by-pass / irrigation tunnel T-2 on tail race level<br />
6.10.4.1 The spill way by-pass / irrigation tunnel T-2 joins tail race approximately 70 m<br />
parallel to the Power Station. The effect of backwater on tail race level has been<br />
negligible on variation of head unless heavy flood occurs and irrigation department<br />
is compelled to open the spill way radial gates. The discharge through tunnel T-2 is<br />
in the range of 150-200 cusec day during lean season. It is not possible to run the<br />
machines on such low discharge as turbines cannot be run below 60-70 % of rated<br />
load otherwise there will be enormous hunting and under water parts will get<br />
severely damaged.<br />
6.10.5 Operating Head Range and Design Head<br />
6.10.5.1 Maximum and Minimum head of Ramganga Power Station is as follows:-<br />
a. Operating Head Range<br />
Maximum Head<br />
Maximum Head Water Level<br />
Minimum Tail Water Level<br />
Maximum Head (Theoretical)<br />
366.200 m<br />
256.100 m<br />
110.100 m<br />
Minimum Net Head<br />
Minimum Head Water Level<br />
332.900 m<br />
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Maximum Tail Water Level<br />
Minimum Head (Theoretical)<br />
278.000 m<br />
54.900 m<br />
b. Design Net Head<br />
Ramganga Power Station being a reservoir scheme, the head (water level) is<br />
not constant but varies from maximum to minimum from 16th October to<br />
15th June (generating season) and from 16th June to 15th October (water<br />
storage period). The tailrace water level increases with increase in generating<br />
factor and at maximum discharge, the available head is minimum. The design<br />
net head of Ramganga Power Station is 84.4 m. The maximum to minimum<br />
net head of the Power Station varies from 108.85 m to 54.9 m.<br />
This Power Station was commissioned in the year 1975. Due to operations of<br />
machines <strong>for</strong> past 37 years, efficiency of machines has substantially<br />
decreased and availability of machines has been adversely affected in spite of<br />
robust operational and maintenance schedule.<br />
6.10.6 Determination of Design Energy<br />
6.10.6.1 The Design Energy is proposed to be computed on the basis of average of 10 daily<br />
discharges as prescribed by UERC in its regulations.<br />
6.10.6.2 Average of 10 daily discharges<br />
The discharge data <strong>for</strong> Ramganga River is available on yearly (average) basis <strong>for</strong><br />
the period 1992-93 to 2011-12 as given in the table 149 below. This discharge<br />
data has been considered <strong>for</strong> determining 90% dependable year.<br />
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Sr. No Year Full<br />
Reservoir<br />
Level(FRL)<br />
Table 149: Annual Discharge<br />
Minimum<br />
Draw Down<br />
Level<br />
(MDDL)<br />
Discharge available<br />
<strong>for</strong> Generation in M.<br />
Cum<br />
1 1992-93 353.27 329.09 1,315.08<br />
2 1993-94 362.30 329.00 2,017.33<br />
3 1994-95 356.07 324.87 1,806.49<br />
4 1995-96 358.58 317.16 1,677.65<br />
5 1996-97 351.60 328.21 1,628.57<br />
6 1997-98 341.51 304.55 647.51<br />
7 1998-99 365.30 325.11 2,128.71<br />
8 1999-00 356.00 331.94 1,526.27<br />
9 2000-01 365.40 332.51 2,202.81<br />
10 2001-02 351.48 334.92 1,316.85<br />
11 2002-03 341.20 325.73 927.14<br />
12 2003-04 351.51 323.04 1,397.43<br />
13 2004-05 349.82 312.06 1,370.29<br />
14 2005-06 357.51 317.17 1,650.87<br />
15 2006-07 342.85 322.25 897.87<br />
16 2007-08 359.73 327.01 1,334.03<br />
17 2008-09 356.41 328.44 1,335.96<br />
18 2009-10 338.47 320.26 1,061.23<br />
19 2010-11 365.40 319.20 1,102.31<br />
20 2011-12 362.55 340.00 1,883.23<br />
6.10.6.3 On stacking the discharge data in the descending order, the dependable year is<br />
determined to be 2002-03 as given in the table 150 below.<br />
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Sr. No.<br />
Table 150: 90% Dependable year<br />
6.10.6.4 From the above table the 90 % dependable year is determined to be FY 2002-03.<br />
For computation of Design Energy corresponding to the discharge considered,<br />
generator and turbine efficiencies have been considered as 0.97 and 0.92 as per<br />
the design records available with <strong>UJVN</strong> <strong>Limited</strong>.<br />
Design Energy estimation is<br />
sensitive to these assumptions and in the absence of detailed technical study on<br />
the present efficiency levels of generator and turbine of Ramganga Power Station,<br />
<strong>UJVN</strong> <strong>Limited</strong> is constrained to use these efficiency levels though actual levels are<br />
expected to be lower.<br />
10 Daily<br />
Average<br />
Discharge<br />
Year %<br />
Dependability<br />
1 2,202.81 2000-01 5<br />
2 2,128.71 1998-99 10<br />
3 2,017.33 1993-94 15<br />
4 1,883.23 2011-12 20<br />
5 1,806.49 1994-95 25<br />
6 1,677.65 1995-96 30<br />
7 1,650.87 2005-06 35<br />
8 1,628.57 1996-97 40<br />
9 1,526.27 1999-00 45<br />
10 1,397.43 2003-04 50<br />
11 1,370.29 2004-05 55<br />
12 1,335.96 2008-09 60<br />
13 1,334.03 2007-08 65<br />
14 1,316.85 2001-02 70<br />
15 1,315.08 1992-93 75<br />
16 1,102.31 2010-11 80<br />
17 1,061.23 2009-10 85<br />
18 927.14 2002-03 90<br />
19 897.87 2006-07 95<br />
20 647.51 1997-98 100<br />
6.10.6.5 The 10 daily discharge data of dependable year 2002-03 was then utilized to<br />
calculate corresponding energy generation which is given in the table 151 below:<br />
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Table 151: Energy Generation potential <strong>for</strong> the dependable year on 10 daily discharge<br />
basis<br />
Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh)<br />
(cumecs) (meter) (kW)<br />
1 April-I 69.00 84.40 54.27 13.03<br />
2 April-II 61.00 84.40 47.98 11.52<br />
3 April-III 102.00 84.40 80.23 19.26<br />
4 May-I 112.00 84.40 88.10 21.14<br />
5 May-II 46.00 84.40 36.18 8.68<br />
6 May-III 27.00 84.40 21.24 5.10<br />
7 June-I 32.00 84.40 25.17 6.04<br />
8 June-II 70.00 84.40 55.06 13.21<br />
9 June-III 92.00 84.40 72.36 17.37<br />
10 July-I - 84.40 - -<br />
11 July-II - 84.40 - -<br />
12 July-III - 84.40 - -<br />
13 Aug-I - 84.40 - -<br />
14 Aug-II - 84.40 - -<br />
15 Aug-III - 84.40 - -<br />
16 Sept-I - 84.40 - -<br />
17 Sept-III - 84.40 - -<br />
18 Sept-III - 84.40 - -<br />
19 Oct-I - 84.40 - -<br />
20 Oct-II - 84.40 - -<br />
21 Oct-III - 84.40 - -<br />
22 Nov-I 3.00 84.40 2.36 0.57<br />
23 Nov-II - 84.40 - -<br />
24 Nov-III 10.00 84.40 7.87 1.89<br />
25 Dec-I 18.00 84.40 14.16 3.40<br />
26 Dec-II 49.00 84.40 38.54 9.25<br />
27 Dec-III 55.00 84.40 43.26 10.38<br />
28 Jan-I 21.00 84.40 16.52 3.96<br />
29 Jan-II 73.00 84.40 57.42 13.78<br />
30 Jan-III 108.00 84.40 84.95 20.39<br />
31 Feb-I 46.00 84.40 36.18 8.68<br />
32 Feb-II 55.00 84.40 43.26 10.38<br />
33 Feb-III 80.00 84.40 62.93 15.10<br />
34 March-I 65.00 84.40 51.13 12.27<br />
35 March-II 94.00 84.40 73.94 17.74<br />
36 March-III 72.00 84.40 56.63 13.59<br />
Annual Energy Generation<br />
256.7<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
6.10.6.6 On the basis of 10 daily discharge data of 90 % dependable year, the Design Energy<br />
is computed to be 256.7 MU. No generation loss has been considered as there is no<br />
spilling of water.<br />
6.10.6.7 For run off the river plants an alternate approach of computing Design Energy on<br />
the basis of maximum possible generation was also considered. This approach is<br />
not being considered <strong>for</strong> the Ramganga Power Station as generation from the plant<br />
is regulated on the basis of the irrigation requirements and is not entirely governed<br />
by the plant availability. Thus this method could lead to erroneous conclusions.<br />
6.10.7 Determination of NAPAF<br />
6.10.7.1 Ramganga Power Station can be classified as Storage and Pondage type Power<br />
Station. However this Power Station is run strictly in accordance with the<br />
requirement of UP Irrigation Department as mentioned earlier. UERC has not<br />
prescribed principles <strong>for</strong> irrigation need based Power Station though it has<br />
prescribed principles <strong>for</strong> Storage and Pondage type power station. The Commission<br />
is requested to prescribe principles <strong>for</strong> determination of NAPAF <strong>for</strong> such Power<br />
Stations. Though, as discussed the principles prescribed by UERC <strong>for</strong> determination<br />
of NAPAF <strong>for</strong> storage and pondage type of Power Stations are not applicable to<br />
Ramganga Power Station per se but <strong>UJVN</strong> Ltd. has used these principles (in the<br />
absence of the principle <strong>for</strong> such plants) to determine NAPAF <strong>for</strong> the Power Station<br />
and to show the impact of control of UP Irrigation department on plant operations.<br />
6.10.7.2 UERC in its Regulations UERC (Terms and conditions <strong>for</strong> determination of tariff)<br />
Regulations 2011 has prescribed either NAPAF or the principle <strong>for</strong> determination<br />
<strong>for</strong> NAPAF <strong>for</strong> Storage and Pondage type plants depending upon difference<br />
between Full Reservoir Level (FRL) and Minimum Draw Down Level (MDDL).<br />
According to these regulations <strong>for</strong> Storage and Pondage type plants with head<br />
variation between Full Reservoir Level (FRL) and Minimum Draw Down Level<br />
(MDDL) of:<br />
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up to 8% and where plant availability is not affected by silt: NAPAF is 90%, but<br />
if the plant is significantly affected by the slit a margin of 5% is provided. The<br />
NAPAF <strong>for</strong> such plants if 85%.<br />
more than 8% and where plant availability is not affected by silt, the month<br />
wise peaking capability as provided by the project authorities in the DPR<br />
(approved by CEA or the State Govt.), shall <strong>for</strong>m basis of fixation of NAPAF.<br />
6.10.7.3 Ramganga Power Station belongs to the latter category of Power Stations as<br />
variation between net head recordings in October and June 16th is more than 8%.<br />
However the principle prescribed by UERC <strong>for</strong> such Power Stations cannot be<br />
applied as such to (leaving aside the limitations expressed earlier). Ramganga<br />
Power Station is 37 years old and the original DPR of the Power Station is not<br />
available with <strong>UJVN</strong> Ltd. In the absence of the DPR it is proposed to compute<br />
month wise peaking capability on the basis of actual running data available with<br />
<strong>UJVN</strong> Ltd. and determine NAPAF accordingly.<br />
6.10.8 Peaking Capability<br />
6.10.8.1 Daily peaking data <strong>for</strong> the period April 2002 to March 2012 which is available with<br />
<strong>UJVN</strong> <strong>Limited</strong> was analysed as per the principles prescribed and illustration<br />
provided in the Regulations by UERC. The analysis reveals that NAPAF on yearly<br />
basis is only 19% and 38% <strong>for</strong> the period 1st December to 31st March when plant is<br />
operational to meet irrigation requirements. In the latter method of calculation of<br />
NAPAF, the fact that operations of the plant are governed by irrigation<br />
requirements and plant is not in operation <strong>for</strong> around 8 months has been<br />
considered. Even during the period December to March when the plant is in<br />
operation most of the time permissible water discharge is not sufficient to run the<br />
plant at (or near) its rated capacity. The analysis is provided in the table-152 below:<br />
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Table 152: <strong>Plan</strong>t availability based on Peaking Capability<br />
Sr. no. Month Average three<br />
hour Peaking<br />
Capacity<br />
6.10.8.2 <strong>Plan</strong>t availability as calculated in any way is not a reflection of the operational<br />
efficiencies of the plant because the prescribed methodology does not capture the<br />
scenario when plant is available <strong>for</strong> generation but cannot be scheduled because<br />
water discharges are not within the control of <strong>UJVN</strong> <strong>Limited</strong>. The actual average<br />
plant availability computed on the basis of availability of units <strong>for</strong> generation<br />
(though not scheduled) during last five years (2007-12) has been 84.65% as given in<br />
the table-153 below. There has been no generation loss on account of nonavailability<br />
of units as regular and other maintenance requirements are scheduled<br />
during season (monsoon) when plant is not in operation.<br />
Considering<br />
months of Dec, Jan<br />
, Feb & March only<br />
1 April 49 -<br />
2 May 45 -<br />
3 June 29 -<br />
4 July 1 -<br />
5 August 5 -<br />
6 September 4 -<br />
7 October 5 -<br />
8 November 21 -<br />
9 December 60 60<br />
10 January 85 85<br />
11 February 85 85<br />
12 March 80 80<br />
Weighted average of<br />
13 peaking capability<br />
39 77<br />
14 Forced Outage 2% 1.5%<br />
Expected Average<br />
15 peaking Capability<br />
38 76<br />
16 Installed Capacity 198<br />
17 NAPAF 19% 38%<br />
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Table 153: <strong>Plan</strong>t Availability during 2007-12<br />
6.10.8.3 Ramganga Power Station is neither a run of the river nor a storage Power Station<br />
solely dedicated <strong>for</strong> electricity generation. Hon’ble UERC is requested to make<br />
appropriate amendments in its existing tariff regulations to accommodate<br />
Ramganga Power Station.<br />
Sr. no. Year Availability (%)<br />
1 2007-08 75.66<br />
2 2008-09 80.24<br />
3 2009-10 85.12<br />
4 2010-11 92.98<br />
5 2011-12 89.26<br />
6 Average 84.65<br />
6.10.9 <strong>Plan</strong>t Outages and Break Downs<br />
6.10.9.1 Annual/ capital maintenance of the plant is scheduled during the period 16th June<br />
to 15th October. During this period, water is stored in the dam and is released later<br />
as per the irrigation requirement. Unplanned outages even if they occur when<br />
Power Station is generating (December- March) generally do not result in<br />
generation loss as there is no spillage of water and the water is retained in the<br />
reservoir <strong>for</strong> future generation. The exception to this could be if the reservoir<br />
reaches the level of 365.300 m be<strong>for</strong>e 15th of October and machines are still under<br />
maintenance. However such situations are rare.<br />
6.10.10 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
6.10.10.1 The analysis of auxiliary consumption data <strong>for</strong> the period 2002-12 reveals that the<br />
auxiliary consumption of Ramganga Power Station is around 0.47% of the Gross<br />
Generation.<br />
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Table 154: Auxiliary and Trans<strong>for</strong>mation losses<br />
Sr. no. Year Gross<br />
Generation<br />
(MU)<br />
6.10.10.2 Auxiliary consumption as percentage of gross generation <strong>for</strong> past 10 years is<br />
0.46%. The trans<strong>for</strong>mation loss <strong>for</strong> the period 2007-11 <strong>for</strong> which data is available (it<br />
has been shared with the Commission) have been analysed and has been found to<br />
be 1.16% of the gross generation <strong>for</strong> the period.<br />
Auxiliary<br />
Consumption<br />
(MU)<br />
1 2002-03 183.71 0.76<br />
2 2003-04 209.16 0.94<br />
3 2004-05 211.88 2.36<br />
4 2005-06 333.29 1.27<br />
5 2006-07 154.17 1.10<br />
6 2007-08 279.06 1.17<br />
7 2008-09 325.48 1.34<br />
8 2009-10 174.29 1.20<br />
9 2010-11 325.62 1.07<br />
10 2011-12 416.42 1.07<br />
11 Total 2,613.07 12.28<br />
Thus both auxiliary and<br />
trans<strong>for</strong>mation losses together constitute around 1.6% of the Gross Generation.<br />
6.10.11 Inferences:<br />
6.10.11.1 Design Energy<br />
Ramganga Power Station is quite old Power Station and has been under operation<br />
since its commissioning in the year 1975. This long operation period has resulted<br />
into excessive wear and tear of the hydro mechanical and electro mechanical<br />
equipments, thereby causing breakdown of machines. The condition of these<br />
equipments are deteriorating with passage of time. <strong>UJVN</strong> Ltd. is taking proactive<br />
action by taking up comprehensive RMU of the Project <strong>for</strong> revival and life<br />
extension of the project.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
The 90% dependable year was computed on the basis of yearly (average)<br />
discharge data <strong>for</strong> the period April 1993 to March 2012 and then the Design<br />
Energy was computed on the basis of 10 daily discharge data of the dependable<br />
year. The Design Energy computed on this basis is 256.7 MU. Keeping in view the<br />
long operational life of the project, it is proposed that Design Energy <strong>for</strong><br />
Ramganga Power Station may be considered as 256.7 MU. However, after<br />
completion of the proposed RMU works of the Project, <strong>UJVN</strong> Ltd. shall approach<br />
the Commission to revise the Design Energy of the Project.<br />
6.10.11.2 NAPAF<br />
NAPAF <strong>for</strong> Ramganga Power Station computed on the basis of the principle<br />
prescribed by UERC has been found to be 19%. For reasons stated above the<br />
prescribed principles are not applicable to this Power Station and there<strong>for</strong>e this<br />
figure does not represent the operational efficiency of the plant. <strong>Plan</strong>t Availability<br />
computed on the basis of availability of units <strong>for</strong> generation (irrespective of<br />
scheduling of water release) during last five years is around 85%. In this context<br />
UERC is requested to prescribe principles <strong>for</strong> determination of NAPAF <strong>for</strong><br />
Ramganga Power Station. Till the time such principles are notified NAPAF <strong>for</strong><br />
Ramganga may be taken as 85%.<br />
6.10.11.3 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
These auxiliary consumption and trans<strong>for</strong>mation losses together are around 1.6%<br />
and more than the limit of 0.7% prescribed by UERC <strong>for</strong> Surface hydroelectric<br />
power generating stations with rotary excitation system. However these losses<br />
are expected to be within the limit prescribed by UERC after RMU works.<br />
6.10.12 Impact of Proposed RMU during control period<br />
6.10.12.1 The proposed RMU works are likely to result in (i) Extension of the <strong>Plan</strong>t life by<br />
around 25 years (ii) Higher <strong>Plan</strong>t Availability (iii) Increased operating efficiencies of<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
plant. The RMU works <strong>for</strong> the plant is likely to be completed during the control<br />
period. The unit wise schedule <strong>for</strong> implementing RMU is as given in table below:<br />
Name of<br />
Unit<br />
Date of Start Date of<br />
Commissioning<br />
Unit-1 15-06-2014 28-02-2015<br />
Unit-2 15-06-2015 28-02-2016<br />
Unit-3 15-06-2016 28-02-2017<br />
6.10.13 Impact of RMU works on Energy generation<br />
6.10.13.1 The proposed RMU of Ramganga Power Station is likely to result in increased<br />
plant availability, increased plant capacity and refurbishment of turbines and<br />
generators is likely to result in increased efficiencies. Primary purpose of RMU is life<br />
extension of the project apart from increase in generation. After RMU, generation<br />
will increase from 283 MU to 450 MU (as per DPR) corresponding to 363/364m<br />
dam level at the end of filling period subject to releases by UP irrigation<br />
department.<br />
6.10.14 Availability<br />
6.10.14.1 The annual maintenance schedule and the RMU schedule proposed <strong>for</strong> Ramganga<br />
Power Station under RMU works <strong>for</strong> the Control period is as given in the table<br />
below:<br />
FY2013-14<br />
Unit No. Start Date End date Days Reasons<br />
1 21-07-2013 08-09-2013 50 Annual Maintenance<br />
2 21-08-2013 09-10-2013 50 Annual Maintenance<br />
3 21-06-2013 09-08-2013 50 Annual Maintenance<br />
FY2014-15<br />
Unit No. Start Date End date Days Reasons<br />
1 15-06-2014 28-02-2015 259 RMU<br />
2 21-08-2014 09-10-2014 50 Annual Maintenance<br />
3 21-06-2014 09-08-2014 50 Annual Maintenance<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
FY2015-16<br />
Unit No. Start Date End date Days Reasons<br />
1 15-7-2015 28-8-2015 45 Annual Maintenance<br />
2 15-06-2015 28-02-2016 259 RMU<br />
3 21-06-2015 09-08-2015 50 Annual Maintenance<br />
6.10.14.2 The plant availability during the control year considering maintenance schedule<br />
given above and <strong>for</strong>ced outages expected (based on past data) during monsoon<br />
months is expected to be as given in the table below:<br />
Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16<br />
<strong>Plan</strong>t Availability (%) 85% 86.3% 67.2% 67.8%<br />
The plant availability expected post RMU is likely to be around 87 %.<br />
6.10.15 Auxiliary Consumption and Trans<strong>for</strong>mation losses<br />
6.10.15.1 The auxiliary consumption and trans<strong>for</strong>mation losses which are currently higher<br />
than the limit prescribed by UERC are likely to achieve the prescribed norms after<br />
the completion of RMU works.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
6.11 TECHNICAL REPORT OF MANERI BHALI – II HYDROELECTRIC PROJECT<br />
6.11.1 Introduction<br />
6.11.1.1 Maneri Bhali Hydroelectric Project II with an installed capacity of 304 MW (4X76<br />
MW) envisages the utilization of head available in the river Bhagirathi between the<br />
tail waters of Maneri Bhali Stage I and Stage II Projects. In Maneri Bhali Stage II<br />
Project, water is diverted through a barrage at Joshiyara situated near the township<br />
of Uttarkashi at about 152 Km from Rishikesh, the nearest railhead. The barrage is<br />
designed to divert 142 cumecs of water into a head race tunnel of diameter 6.0 m<br />
and length 16 km to generate electricity through a Power Station of 4X76 MW<br />
constructed at Dharasu village.<br />
6.11.1.2 The Power Station comprises of four hydro power generating units of 76 MW each.<br />
The generator is powered by Francis turbines of 78 MW rated capacity. The rated<br />
flow through each turbine is 35.5 cumecs and is discharged to a common tail race<br />
channel.<br />
6.11.2 Determination of Design Energy<br />
6.11.2.1 The Design Energy <strong>for</strong> all other Power Stations (except <strong>for</strong> Ramganga Power<br />
Station) has been computed considering two approaches. (i) On the basis of<br />
average of 10 daily discharges and (ii) the maximum generation possible from the<br />
Power Station considering that there were no machine and other outages. The<br />
Design Energy <strong>for</strong> Ramganga has been computed using the first approach only.<br />
These approaches considered are probabilistic approaches and <strong>for</strong> acceptable<br />
outcome these requires data of reasonable sample size. This condition is not met in<br />
the case of Maneri Bhali-II which has been commissioned in March 2008 only. The<br />
Design Energy <strong>for</strong> Maneri Bhali Stage-II is 1566 MUs, but this DE was calculated<br />
considering total installed capacity of Power Station and attainment of full barrage<br />
level of 1108 m. Presently, due to restriction of reservoir level of 1104 m at<br />
Joshiyara Barrage instead of designed maximum level of 1108 m, the peaking<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
capacity has reduced. However after completion of required essential civil works at<br />
barrage and modification of Tail Race Channel, it is expected that Power Station will<br />
be able to attain its Design Energy.<br />
6.11.2.2 Due to restriction of barrage level and improper evacuation of water through TRC,<br />
presently the capacity of the plant has been restricted to 280 MW. As such, it is<br />
recommended that till the proposed civil works are completed, Design Energy of<br />
Maneri Bhali Stage II HEP <strong>for</strong> the Control Period be considered as average of annual<br />
generation of past four years. After, completion of Civil works at barrage and<br />
modification of TRC of Power Station, <strong>UJVN</strong> Ltd. shall approach the Hon’ble<br />
Commission <strong>for</strong> revision in Design Energy of Maneri Bhali Stage II HEP.<br />
6.11.3 Determination of NAPAF<br />
6.11.3.1 The actual average plant availability during the last four years is given in the table<br />
below:<br />
Table 155: <strong>Plan</strong>t Availability during FY 2008-12 – Maneri Bhali - II Hydroelectric Project<br />
Sr. No (1)<br />
Month (2)<br />
Total<br />
Running<br />
Hrs. of all<br />
the units<br />
(Hrs.) (3)<br />
Reserve<br />
Outage<br />
(Hrs.) (4)<br />
Forced<br />
Outage<br />
(Hrs.) (5)<br />
<strong>Plan</strong>ned Maintenance<br />
Annual<br />
Mainten<br />
ance<br />
(Hrs.) (6)<br />
Capital<br />
Major<br />
repairs (Hrs.)<br />
(7)<br />
Total hours<br />
(max)<br />
(Hrs.) (8)<br />
<strong>Plan</strong>t<br />
Availability<br />
% (9)<br />
(Col. 3+Col.<br />
4)/Col.8<br />
1 April 4998 2291 925 3306 0 11520 63%<br />
2 May 9031 1673 122 754 326 11904 90%<br />
3 June 10084 838 598 0 0 11520 95%<br />
4 July 9611 1148 1086 60 0 11904 90%<br />
5 August 6650 3452 942 860 0 11904 85%<br />
6 Sept 9106 1352 346 716 0 11520 91%<br />
7 Oct 8459 2470 323 653 0 11904 92%<br />
8 Nov 5431 3482 122 2486 0 11520 77%<br />
9 Dec 4188 2572 300 4845 0 11904 57%<br />
10 Jan 3385 2991 0 5529 0 11904 54%<br />
11 Feb 2836 2882 74 5057 0 10848 53%<br />
12 March 3684 2690 1664 3866 0 11904 54%<br />
Total 77460 27838 6501 28131 326 140256 75%<br />
6.11.3.2 The average plant availability of Maneri Bhali Stage-II HEP during last four years is<br />
around 75%.The Maneri Bhali Stage II Hydro Electric Project experiences <strong>for</strong>ced<br />
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shut downs during the monsoon seasons. The reasons <strong>for</strong> these <strong>for</strong>ced shut downs<br />
have been provided in the section below.<br />
6.11.4 Special Circumstances and Abnormal Operating Conditions<br />
6.11.4.1 Since its commissioning, the Power Station operates on base load during monsoon<br />
and as a peaking station as per the instructions of SLDC during non-monsoon<br />
period when discharge in the river reduces and Power Station has to be run on part<br />
capacity. This Power Station meets evening and morning peaks during lean<br />
discharge period. But due to restriction of reservoir level to be kept 1104 m at<br />
Joshiyara Barrage instead of designed maximum level of 1108 m, the peaking<br />
capacity has reduced. However, after completion of required essential civil works<br />
at barrage and modification of Tail Race Channel by 2014-2015, peaking capacity<br />
will improve and four hours each of evening and morning peaks will be possible.<br />
6.11.4.2 Due to restriction of barrage level and improper evacuation of water through TRC,<br />
the capacity of the plant has been restricted to 280 MW. Study of the available<br />
inflow data revealed that the maximum capacity can be generated between May to<br />
September and partially between October to April. Lean discharge period is utilised<br />
<strong>for</strong> planned annual or capital maintenance.<br />
6.11.5 <strong>Plan</strong>t Outages and Breakdowns<br />
6.11.5.1 Apart from above facts, when flood recedes lot of silt having substantial quartzite<br />
particles are lodged in cavities and caves on both banks of river which gets<br />
dislodged when level of river starts rising as a result of snow melting during<br />
summer season and is carried to the machines through water conductor system<br />
causing severe damage to under water parts and frequent plant outages which<br />
becomes beyond control of <strong>UJVN</strong> <strong>Limited</strong>.<br />
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6.11.5.2 The <strong>for</strong>ced outage data <strong>for</strong> the period 2008-2012 has revealed that 58% of the<br />
total energy loss is on this account. The table below provides the details.<br />
Table 156: % Generation Loss on account of various Factors – Maneri Bhali - II<br />
Hydroelectric Project<br />
Sr. No. Month↓ B/D of<br />
Equipment<br />
(in MU)<br />
Flushing &<br />
Choking<br />
(in MU)<br />
System<br />
Condition<br />
& Grid fail<br />
(in MU)<br />
Flood<br />
passing &<br />
Any Other<br />
Reasons<br />
(in MU)<br />
Total<br />
(in MU)<br />
1 April 0.00 0.71 0.26 2.72 3.69<br />
2 May 10.16 4.99 3.32 2.50 20.97<br />
3 June 32.82 8.33 15.06 7.01 63.20<br />
4 July 71.15 20.46 3.81 5.25 100.67<br />
5 August 50.18 8.84 0.07 11.29 70.37<br />
6 September 20.41 6.21 1.24 31.04 58.90<br />
7 October 2.73 0.61 1.36 2.78 7.48<br />
8 November 0.00 0.00 0.00 0.00 0.00<br />
9 December 0.02 0.00 0.00 0.66 0.69<br />
10 January 0.00 0.00 0.00 0.00 0.00<br />
11 Feburary 0.00 0.00 0.00 0.00 0.00<br />
12 March 0.00 0.00 0.00 0.00 0.00<br />
Total 187.46 50.16 25.11 63.25 325.98<br />
Energy Lost 58% 15% 8% 19% 100%<br />
6.11.6 Auxiliary Consumption and Trans<strong>for</strong>mation Losses<br />
6.11.6.1 The analysis of auxiliary consumption data of past 4 years reveals that the<br />
auxiliary consumption of Maneri Bhali Stage II HEP is around 0.35% of the Gross<br />
Generation. Similarly the trans<strong>for</strong>mation losses of past 4 years <strong>for</strong> which the data<br />
is available has been analysed. The trans<strong>for</strong>mation losses are 0.31% of the gross<br />
generation. Both auxiliary and trans<strong>for</strong>mation losses together constitute around<br />
0.66 % of the Gross Generation.<br />
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Table 157: Auxiliary and Trans<strong>for</strong>mation Losses – Maneri Bhali - II Hydroelectric Project<br />
Sr. No Particulars Unit Value<br />
1 Total Gross Generation (2008-12) MUs 4930.10<br />
2 Total Aux. consumption (2008-12) MUs 17.08<br />
3 Aux. consumption as a % of Gross Generation % 0.35%<br />
4 Total Gross Generation (2008-12) MUs 4930.10<br />
5 Total Trans<strong>for</strong>mation loss (2008-12) MUs 15.45<br />
6 Trans<strong>for</strong>mation loss as a % of Gross Generation % 0.31%<br />
7 Total Aux. and Trans<strong>for</strong>mation losses (2008-12) MUs 32.53<br />
8<br />
Total Aux. and Trans<strong>for</strong>mation losses as a % of<br />
Gross Generation<br />
% 0.66%<br />
6.11.7 Inferences<br />
6.11.7.1 Design Energy<br />
Due to Barrage level restriction and improper evacuation of water through Tail<br />
Race Channel of Power Station, Maneri Bhali Stage II HEP is not able to attain its<br />
Design Energy. Actions are being taken in this regard by <strong>UJVN</strong> Ltd. <strong>for</strong> attainment<br />
of Design Energy as stated in the Capex <strong>Plan</strong> earlier. Maneri Bhali Stage II HEP has<br />
been under operation since last four years. There<strong>for</strong>e, it is proposed that until the<br />
necessary civil works are completed in order to attain Design Energy of the<br />
Project, the Primary Energy of Maneri Bhali Stage II HEP be considered as average<br />
of last four years generation i.e, 1232.52 MUs.<br />
After completion of the proposed civil works <strong>for</strong> attainment of Design Energy, the<br />
Primary Energy <strong>for</strong> the Project can be considered w.r.t. original Design Energy of<br />
the Project.<br />
6.11.7.2 NAPAF<br />
Based on actual running hours, reserve hours, <strong>for</strong>ced outage hours and plant<br />
outage hours <strong>for</strong> last 4 years average plant availability as calculated in the table<br />
155 is around 75% and this may be taken as NAPAF <strong>for</strong> Maneri Bhali Stage II HEP<br />
<strong>for</strong> the control period.<br />
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6.11.7.3 Auxiliary Consumption and Trans<strong>for</strong>mation Loss<br />
As explained in the earlier section auxiliary consumption is within the limits set<br />
by UERC <strong>for</strong> underground hydroelectric power generating stations with static<br />
excitation system. The same may be considered <strong>for</strong> the control period.<br />
6.11.8 Projection <strong>for</strong> the control period<br />
6.11.8.1 As Power Station is recently commissioned, no RMU is planned <strong>for</strong> Maneri Bhali - II<br />
Project. The per<strong>for</strong>mance parameters <strong>for</strong> the control period will be same as<br />
<strong>for</strong>ecast provided in the petition.<br />
6.11.9 Availability<br />
6.11.9.1 The annual maintenance schedule proposed <strong>for</strong> Maneri Bhali-II Power Station<br />
during the Control period is as given in the table below:<br />
FY2013-14<br />
Unit No. Start Date End date Days Reasons<br />
1 03-11-2013 01-01-2014 60 Annual Maintenance<br />
2 25-11-2013 23-01-2014 60 Annual Maintenance<br />
3 06-01-2014 06-03-2014 60 Annual Maintenance<br />
4 27-01-2014 27-03-2014 60 Annual Maintenance<br />
FY2014-15<br />
Unit No. Start Date End date Days Reasons<br />
1 03-11-2014 01-01-2015 60 Annual Maintenance<br />
2 25-11-2014 23-01-2015 60 Annual Maintenance<br />
3 06-01-2015 06-03-2015 60 Annual Maintenance<br />
4 27-01-2015 27-03-2015 60 Annual Maintenance<br />
FY2015-16<br />
Unit No. Start Date End date Days Reasons<br />
1 03-11-2015 01-01-2016 60 Annual Maintenance<br />
2 25-11-2015 23-01-2016 60 Annual Maintenance<br />
3 06-01-2016 05-03-2016 60 Annual Maintenance<br />
4 27-01-2016 26-03-2016 60 Annual Maintenance<br />
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6.11.9.2 The plant availability during the control year considering maintenance schedule<br />
given above and <strong>for</strong>ced outages expected (based on past data) during monsoon<br />
months is expected to be as given in the table below:<br />
Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16<br />
<strong>Plan</strong>t Availability (%) 75% 80% 80% 80%<br />
6.11.10 Auxiliary Consumption and Trans<strong>for</strong>mation losses<br />
6.11.10.1 As explained in the earlier section auxiliary consumption is within the limits set by<br />
UERC <strong>for</strong> underground hydroelectric power generating stations with static<br />
excitation system. The same may be considered <strong>for</strong> the control period.<br />
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7 ANNEXURES<br />
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7.1 Annexure 1: 10 Daily Discharge Tiloth Power Station<br />
Sr. No Month<br />
10 Daily<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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7.2 Annexure 2: 10 Daily Discharge Chibro Power Station<br />
Sl.no. Month<br />
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<br />
Average<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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7.3 Annexure 3: 10 Daily Discharge Dhakrani Power Station<br />
Sl.no.<br />
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<br />
Month average<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
281
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
7.4 Annexure 4: 10 Daily Discharge Dhalipur Power Station<br />
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<br />
average<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
282
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
7.5 Annexure 5: 10 Daily Discharge KhodriPower Station<br />
Sl.no.<br />
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<br />
Month Discharge<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
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<br />
283
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
7.6 Annexure 6: 10 Daily Discharge Kulhal Power Station<br />
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<br />
Discharge<br />
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<br />
2 ii 73.09 137.50 113.06 96.39 118.04 88.13 140.22 88.57 57.74 67.96 92.50<br />
3 iii 84.12 153.34 123.54 100.02 133.97 94.86 117.35 102.60 63.53 61.94 106.82<br />
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<br />
5 ii 113.17 178.77 122.67 96.39 102.73 148.17 122.99 106.87 79.73 64.88 132.23<br />
6 iii 102.35 149.89 124.30 99.12 113.96 145.57 102.44 128.24 84.65 88.89 138.31<br />
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<br />
8 ii 140.33 141.42 142.06 116.91 136.10 93.13 145.73 167.16 61.48 84.63 152.84<br />
9 iii 151.33 155.54 151.77 102.67 183.21 118.05 145.48 174.64 97.12 115.74 171.75<br />
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<br />
11 ii 158.17 161.30 174.32 132.54 149.24 174.84 184.08 156.75 148.43 166.73 167.42<br />
12 iii 152.72 159.97 161.75 134.42 169.16 168.84 168.15 178.09 154.31 166.75 159.08<br />
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<br />
14 ii 149.82 166.23 177.38 188.49 185.48 190.94 183.27 127.52 169.81 166.09 135.16<br />
15 iii 169.85 189.01 186.35 191.50 185.50 192.63 183.26 187.34 130.74 40.68 134.56<br />
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<br />
17 ii 159.55 176.39 188.45 182.84 155.99 179.31 185.53 156.21 153.87 130.50 178.81<br />
18 iii 241.84 189.02 180.63 149.01 185.74 145.83 157.67 177.36 163.05 133.62 190.29<br />
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<br />
20 ii 91.35 143.11 153.49 149.54 168.40 102.95 102.46 153.08 87.95 189.70 164.42<br />
21 iii 83.58 108.48 122.87 114.72 138.49 94.90 101.18 133.30 66.87 182.54 131.86<br />
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<br />
23 ii 66.66 86.35 98.33 77.76 97.42 72.45 77.68 99.83 80.00 132.98 102.64<br />
24 iii 63.46 84.48 88.33 74.86 92.54 70.06 68.84 94.20 67.98 119.06 92.14<br />
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<br />
26 ii 59.57 70.46 81.77 66.31 77.14 64.25 71.95 79.91 55.51 96.08 78.26<br />
27 iii 56.01 62.28 70.11 61.13 70.15 58.06 60.55 71.69 51.19 89.07 69.77<br />
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<br />
29 ii 50.93 54.65 61.72 27.45 79.16 51.48 71.95 60.38 47.91 86.33 77.63<br />
30 iii 50.82 56.00 86.43 7.21 70.33 46.68 62.93 60.35 46.77 75.92 70.79<br />
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<br />
32 ii 81.00 71.13 73.44 0.00 64.90 73.36 63.84 61.11 52.28 81.79 66.87<br />
33 iii 1.88 89.28 0.00 0.00 63.37 61.43 65.03 50.43 50.50 79.00 68.24<br />
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<br />
35 ii 0.00 85.27 63.62 145.84 81.03 148.27 79.24 45.90 48.37 76.41 73.98<br />
36 iii 105.23 98.54 61.94 137.85 74.45 147.73 64.46 52.08 61.90 84.90 88.10<br />
Month Average 98.97 124.04 117.07 101.01 121.52 113.81 113.49 115.02 86.17 109.10 118.63<br />
284
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
7.7 Annexure 7: 10 Daily Discharge Chilla Power Station<br />
Sl.no. Month 02-03 03-04 04-05 05-06 06-07 07-08 08-09 09-10 10-11 11-12<br />
1 April i 310.10 269.80 175.10 253.40 156.60 308.20 315.00 328.90 335.90 469.70<br />
2 ii 363.70 356.60 187.10 273.00 169.60 330.20 336.40 355.50 409.80 508.30<br />
3 iii 426.80 320.10 227.20 362.40 196.60 334.30 375.70 384.30 386.50 589.70<br />
4 May i 409.70 339.10 229.00 408.50 296.00 413.80 402.40 417.40 378.00 623.30<br />
5 ii 406.60 418.00 349.00 429.50 453.00 474.30 428.10 409.30 352.00 631.30<br />
6 iii 375.18 507.36 429.18 376.00 526.55 367.00 493.45 465.09 423.55 608.82<br />
7 June i 369.80 525.90 439.40 417.20 551.70 453.40 533.00 492.40 486.70 615.50<br />
8 ii 207.70 492.00 462.40 477.00 541.30 560.60 455.40 378.40 436.80 621.90<br />
9 iii 295.00 496.30 526.20 414.60 467.60 567.00 461.90 395.50 557.40 603.40<br />
10 July i 454.90 502.30 500.50 426.70 578.80 526.30 466.00 542.30 558.10 608.30<br />
11 ii 532.40 541.30 567.20 471.20 554.80 552.20 474.00 555.10 556.10 602.10<br />
12 iii 524.64 565.64 502.45 517.64 556.36 524.27 530.45 510.55 559.55 566.73<br />
13 Aug i 524.90 544.20 518.10 537.50 581.30 494.90 556.70 540.70 566.30 569.20<br />
14 ii 453.20 560.10 547.20 534.40 599.20 460.00 545.70 533.00 543.00 399.90<br />
15 iii 532.82 539.45 567.18 549.09 600.00 482.27 554.91 487.55 526.73 568.18<br />
16 Sept i 510.60 510.90 582.20 558.90 560.00 567.00 545.80 460.40 392.10 582.50<br />
17 ii 496.60 519.00 593.60 520.30 600.00 567.00 555.30 464.40 391.60 593.60<br />
18 iii 543.20 567.00 571.00 539.70 592.90 544.70 539.80 430.30 461.70 631.50<br />
19 Oct i 550.90 563.30 571.00 556.90 498.90 560.30 551.70 378.30 584.80 586.70<br />
20 ii 504.00 514.80 573.20 547.40 383.40 484.80 473.20 314.60 576.10 597.40<br />
21 iii 419.27 429.36 493.45 476.09 366.18 453.09 388.45 349.55 547.36 542.64<br />
22 Nov i 314.30 373.90 387.20 295.70 356.60 426.40 368.00 306.50 467.90 463.70<br />
23 ii 258.20 318.40 329.90 244.40 281.40 402.10 349.30 343.20 400.70 370.80<br />
24 iii 276.40 266.50 288.40 208.60 290.10 364.10 343.00 291.40 381.20 367.50<br />
25 Dec i 258.00 245.00 258.60 188.00 291.00 368.50 355.00 298.30 370.70 392.10<br />
26 ii 224.50 240.30 232.50 180.50 287.00 354.50 333.40 300.90 309.60 368.60<br />
27 iii 215.09 217.64 216.91 183.36 282.91 357.00 354.45 315.18 195.36 359.00<br />
28 Jan i 209.60 203.30 205.60 179.70 268.40 376.50 403.20 357.10 191.90 389.10<br />
29 ii 198.00 194.30 196.70 181.40 249.70 384.50 383.30 377.30 175.00 426.00<br />
30 iii 193.36 203.00 204.45 173.36 242.18 380.91 386.27 338.00 216.27 378.73<br />
31 Feb i 204.50 192.50 228.80 170.00 257.10 384.40 341.20 349.60 371.90 407.70<br />
32 ii 15.60 183.30 261.20 165.70 270.50 378.50 354.50 376.50 426.10 410.70<br />
33 iii 0.00 183.00 243.00 164.75 242.38 354.67 362.75 360.75 408.38 383.22<br />
34 March i 46.90 154.10 250.90 160.60 275.60 344.60 335.40 355.90 428.30 394.10<br />
35 ii 228.00 183.20 243.90 164.10 341.20 350.20 323.70 406.10 457.30 375.60<br />
36 iii 262.82 181.18 273.09 124.55 351.36 329.55 319.36 394.91 456.00 409.73<br />
Average 338.89 373.43 374.05 346.28 393.49 432.68 425.38 399.43 424.59 500.61<br />
285
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
7.8 Annexure 8: 10 Daily Discharge Khatima Power Station<br />
Sl.no. 01-02 02-03 03-04 04-05 05-06 06-07 07-08 08-09 09-10 10-11 11-12<br />
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<br />
2 ii 136.57 162.89 207.58 105.83 160.59 131.49 197.18 134.45 116.91 167.77 110.76<br />
3 iii 163.22 209.78 224.04 154.32 199.48 138.07 196.84 160.02 126.85 177.28 126.11<br />
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<br />
5 ii 244.95 294.34 236.88 189.73 215.32 242.39 228.26 188.53 144.21 170.86 180.41<br />
6 iii 222.62 300.79 256.68 220.17 237.70 251.69 217.42 218.97 220.71 193.64 208.07<br />
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<br />
8 ii 227.74 246.02 236.88 230.16 284.95 235.07 305.83 287.44 168.17 218.25 234.47<br />
9 iii 269.82 250.37 256.68 267.21 297.47 229.00 273.74 308.43 269.60 267.91 241.17<br />
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<br />
11 ii 308.96 243.54 296.19 324.88 291.74 313.13 313.13 294.87 318.53 303.14 207.99<br />
12 iii 310.28 239.25 262.05 326.18 317.88 311.70 292.55 287.05 318.61 271.57 221.53<br />
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<br />
14 ii 317.83 305.56 290.22 326.18 322.53 313.13 284.70 270.34 282.61 190.34<br />
15 iii 308.38 285.85 288.88 326.18 318.83 313.13 305.07 168.03 301.68<br />
16 Sept i 322.00 294.84 299.48 326.18 323.58 313.13 293.82 193.93 304.65<br />
17 ii 307.39 281.74 220.31 326.18 316.79 313.13 319.40 300.58 301.99<br />
18 iii 317.30 289.96 178.31 301.92 233.28 323.58 256.25 178.20 297.98<br />
19 Oct i 315.74 299.99 178.40 326.18 310.52 323.58 317.31 238.98 210.38<br />
20 ii 244.77 294.80 271.56 315.74 313.13 305.30 266.43 297.69 115.11<br />
21 iii 169.94 243.24 253.31 228.67 195.02 207.71 159.31 217.45 117.30<br />
22 Nov i 159.74 198.33 176.27 204.86 175.25 180.75 159.31 144.47 132.54<br />
23 ii 196.13 205.98 176.84 195.03 188.44 167.39 171.13 163.82 129.39<br />
24 iii 185.14 191.73 158.57 192.83 175.25 135.08 164.45 174.70 152.83<br />
25 Dec i 160.96 184.59 151.92 149.53 167.23 123.79 163.74 199.84 181.57<br />
26 ii 147.94 158.39 149.51 138.05 151.95 142.75 169.67 191.38 197.80<br />
27 iii 129.67 131.89 134.06 146.61 148.35 129.64 160.36 173.87 177.60<br />
28 Jan i 118.77 140.85 132.99 137.06 144.48 121.98 144.48 146.27 172.06<br />
29 ii 132.17 115.97 124.45 137.28 135.58 112.05 141.02 132.12 158.38<br />
30 iii 116.54 117.07 129.49 164.56 126.91 101.26 133.01 130.65 137.27<br />
31 Feb i 113.91 142.50 120.93 162.69 117.66 90.51 134.09 130.63 135.66<br />
32 ii 134.10 130.24 117.94 179.65 111.60 134.22 132.37 129.39 158.38<br />
33 iii 122.85 140.52 119.25 171.82 107.86 103.65 123.04 108.63 141.46<br />
34 March i 149.59 176.24 104.82 149.92 93.40 144.65 119.96 107.44 148.43<br />
35 ii 138.30 162.83 118.93 178.46 109.71 161.96 123.22 111.43 131.26<br />
36 iii 144.30 172.35 116.83 177.50 106.39 180.74 123.13 107.51 139.98 116.05 103.26<br />
Month Average 208.17 215.31 199.35 219.30 211.66 206.70 209.89 194.12 193.98 213.90 183.66<br />
286
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
7.9 Annexure 9: 10 Daily Discharge Maneri Bhali – II Hydroelectric Project<br />
Sr. No Month<br />
10 Daily<br />
Average 2008-09 2009-10 2010-11 2011-12<br />
1 April 1 29.03 30.05 37.81<br />
2 2 34.97 57.13 48.93<br />
3 3 44.32 56.06 65.36<br />
4 May 1 53.56 79.95 88.61<br />
5 2 70.01 69.12 112.29<br />
6 3 116.15 100.87 109.16<br />
7 June 1 122.54 113.46 102.99<br />
8 2 105.85 97.66 126.91<br />
9 3 115.09 131.13 98.85<br />
10 July 1 129.14 113.25 117.17<br />
11 2 103.42 112.46 124.69<br />
12 3 91.13 121.96 120.37<br />
13 Aug 1 58.17 108.99 101.36<br />
14 2 77.03 78.19 90.93<br />
15 3 118.62 107.57 104.24<br />
16 Sept 1 97.90 111.44 110.37<br />
17 2 115.04 103.40 111.22<br />
18 3 100.32 88.39 122.59<br />
19 Oct 1 97.78 99.53 121.23 112.00<br />
20 2 76.26 65.53 104.47 79.89<br />
21 3 63.37 53.93 84.62 62.03<br />
22 Nov 1 55.98 44.81 65.44 53.62<br />
23 2 50.30 39.55 57.11 47.42<br />
24 3 45.86 36.64 49.23 41.58<br />
25 Dec 1 39.71 32.26 42.59 38.74<br />
26 2 38.01 30.34 38.85 34.07<br />
27 3 35.24 26.21 35.64 29.54<br />
28 Jan 1 33.36 27.69 33.87 30.20<br />
29 2 31.00 27.20 31.21 33.08<br />
30 3 29.71 26.93 29.73 30.72<br />
31 Feb 1 28.21 26.27 28.06 30.34<br />
32 2 25.43 27.18 31.54 29.22<br />
33 3 25.49 29.74 29.03 28.54<br />
34 March 1 26.63 28.64 28.70 32.14<br />
35 2 26.69 33.85 34.32 33.03<br />
36 3 27.82 45.23 39.01 41.96<br />
Average 42.05 63.44 71.27 71.72<br />
287
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
7.10 Annexure 10: Breakup of Cost <strong>for</strong> Balance works as per Original DPR as approved by CEA and proposed new works<br />
<strong>for</strong> Maneri Bhali –II HEP<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
1 Rehabilitation 1555.94 During commissioning of the project, habitants of Joshiyara,<br />
Gyansu and Malin Basti demanded to consider the submerge<br />
area upto El 1110 m instead of El 1108 as mentioned in DPR.<br />
Earlier, it was proposed to construct the protection wall upto<br />
El 1108 m on the periphery of Joshiyara Reservoir on the<br />
required locations. But habitants of Joshiyara, Gyansu and<br />
Malin Basti also demanded to construct the protection wall<br />
upto El 1110 m. At last, this project was commissioned on<br />
16 th Feb, 2008 at barrage level of El 1104 m, instead of<br />
Maximum Pond level El 1108 m as given in DPR. There<strong>for</strong>e,<br />
288
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
this cost involved in rehabilitation was not included in the<br />
earlier approved proposal accorded by CEA.<br />
2 Compensation <strong>for</strong> the<br />
affected people<br />
113.55 Due to Joshiyara Reservoir, 0.532 Ha land of Gyansu &<br />
Joshiyara villagers have been submerged without acquiring<br />
their land. At present, Maneri Bhali Stage-II Project is<br />
completely and all properties of project are in the possession<br />
of <strong>UJVN</strong> Ltd. There<strong>for</strong>e, their compensation will also be paid<br />
by the Nigam. There are 9 affected people/family of Gyansu<br />
village & Joshiyara Village, who had not got the land<br />
compensation and one owner, who had not got the<br />
compensation against his building.<br />
In addition to the above compensation, it was decided in the<br />
289
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
meeting of Chief Secretary, GoU with the Affected People<br />
held on 04.03.2008 that an amount equal to one year rent<br />
should be paid to affected owner of the building due to<br />
Joshiyara Reservoir, so that they can live during construction<br />
their house.<br />
The cost of the above compensation was not included in the<br />
earlier approved proposal accorded by CEA.<br />
3 Construction of Protection<br />
wall<br />
850 3231.54 The reasons <strong>for</strong> increase in the construction cost are as under:<br />
Earlier, It was proposed upto El 1108 m only but as pet the<br />
demand of the affected people, it is proposed upto El 1110 m.<br />
It was proposed in the required location only. Now, it is<br />
290
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
proposed almost all around the Joshiyara reservoir.<br />
Earlier estimate was based on 2007 schedule of rate. Now it is<br />
based on the current schedule.<br />
4 Modification of tail race<br />
channel<br />
2415.00 On 16th Feb, 2008, Maneri Bhali Stage-II project was<br />
commissioned and handed over in the service of nation.<br />
After the availability of water to run all the four machines<br />
at full load in July-2008, excessive vibrations on the<br />
machines were observed by <strong><strong>UJVN</strong>L</strong> and BHEL Engineers<br />
because The existing tailrace configuration is not suitable<br />
<strong>for</strong> proper evacuation of the flow from all the turbine units<br />
running at full load.<br />
This work was not included in the earlier approved<br />
291
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
proposal accorded by CEA.<br />
5 Construction of Office<br />
Building at Joshiyara<br />
6 Construction of Joshiyara<br />
colony<br />
5.00 102.74 Initially, it was decided that the all works shall be looked after<br />
from the main office of MB-II, Chinyalisaur. But during<br />
operation of Joshiyara Barrage, it has been experienced that<br />
the Executive Engineer (Civil) may look after the works of<br />
barrage operation efficiently from Joshiyara. There<strong>for</strong>e, a<br />
permanent office <strong>for</strong> Executive Engineer (Civil) is also<br />
proposed in Joshiyara, which was not included in the earlier<br />
approved proposal accorded by CEA.<br />
109.77 Affected People demanded to rehabilitate in the Project land<br />
and the District Administration also requested to shift them in<br />
the area where temporary residences exist. There<strong>for</strong>e, these<br />
292
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
residences have been demolished.<br />
Hence, some residences are required to accommodate the<br />
officers/staff posted at Joshiyara Barrage.<br />
7 Construction of Road from<br />
Joshiyara Bridge to<br />
Flushing conduit on left<br />
Bank (1.2 km) and from<br />
Barrage to NH-108 on Right<br />
Bank (0.4 Km)<br />
8 Construction of<br />
Infrastructure works <strong>for</strong><br />
15.9 222.18 Police line and Gyansu village are situated on the right bank of<br />
the Joshiyara reservoir. There is no direct road from police<br />
line to Uttarkashi city. There<strong>for</strong>e, residents of the police line<br />
and gyansu villagers are using our barrage road. So, there is<br />
an urgent requirement of road from Barrage to NH-108 <strong>for</strong><br />
safety point of view, which was not included in the earlier<br />
approved proposal accorded by CEA.<br />
950.00 The works proposed to fullfill the demands of the affected<br />
People of Joshiyara Village, Gyansu and Malin Basti come to<br />
293
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
affected villagers from<br />
the notice after submission of the proposal to CEA. There<strong>for</strong>e,<br />
Joshiyara, Gyansu and<br />
the cost against these works was not included in the earlier<br />
Kansain village as per their<br />
approved proposal accorded by CEA.<br />
demands<br />
9 Construction of boundary<br />
14.90<br />
It is proposed after submission of the proposal to CEA <strong>for</strong> the<br />
wall, security fencing and<br />
safety of the residential colony at Chinyalisaur because due to<br />
gate <strong>for</strong> Shaktipuram<br />
120.59<br />
the non existence of the security fencing/boundary wall, the<br />
colony and Shifting of<br />
entry of the unwanted peoples in the colony is very easy<br />
existing boundary wall of<br />
resulting in thefts and the feeling of insecurity to the residents<br />
Shaktipuram colony and<br />
of the colony. There<strong>for</strong>e, the cost against these works was not<br />
provide the separate way<br />
included in the earlier approved proposal accorded by CEA.<br />
<strong>for</strong> villagers behind<br />
Shaktipuram colony<br />
294
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
10 Construction of 04 Nos<br />
Type-IV Residences and 01<br />
Nos Type-V Residence in<br />
Shaktipuram Colony,<br />
Chinyalisaur<br />
11 Construction of school<br />
building <strong>for</strong> Saraswati<br />
Shishu Mandir School in<br />
Shaktipuram Colony<br />
Chinyalisaur<br />
12 Strengthening of water<br />
distribution system of<br />
15.00 109.77 As per the new structure of the staff at MB-II Power House<br />
and demolition of old & temporary quarters, new quarters are<br />
required to accommodate all officers/staffs, which cost was<br />
not included in the earlier approved proposal accorded by<br />
CEA.<br />
199.79 Saraswati Shishu Mandir School in Shaktipuram Colony,<br />
Chinyalisaur is established <strong>for</strong> more than 30 years ago in<br />
temporary type quarters. In the later stage, it is decided to<br />
construct the new school building, which cost was not<br />
included in the earlier approved proposal accorded by CEA.<br />
66.87 88.57 Enhance the cost of these work is due to escalation only.<br />
295
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
Shaktipuram<br />
Chinyalisaur<br />
colony,<br />
13 Construction of workshop<br />
building at Dharasu power<br />
house of MB-II project<br />
14 Protection work on hill<br />
slope behind power house<br />
150 168.78 Enhance the cost of these work is due to escalation only.<br />
257.00 Initially, some protection works of Dharasu Power House had<br />
been done by Irrigation Department. But just be<strong>for</strong>e the<br />
commissioning of the Project, the protection works failed at<br />
some point. There<strong>for</strong>e, it is decided to re-protect these works<br />
against the capital expenditure. It is also to in<strong>for</strong>m that the<br />
cost against this work was not included in the earlier<br />
approved proposal accorded by CEA.<br />
296
<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
15 Testing of surge shaft gate 500.00 The surge tank gate has been installed during running<br />
condition of Power House, so that testing of this gate has not<br />
been done till to-date. At present, the testing of gate shall be<br />
made possible with the help of Mixed Gas Diving or Saturation<br />
diving <strong>for</strong> deeper zone upto 103 m deep water as per the<br />
requirement of site <strong>for</strong> complete sealing of Gates.<br />
It is also to in<strong>for</strong>m that the cost of this work was not included<br />
in the earlier approved proposal accorded by CEA.<br />
16 Centage Charges<br />
6084.00<br />
GoU directed to release the payment to Irrigation Department<br />
against centage charges in the later stage. There<strong>for</strong>e, the cost<br />
involved in this was not included in the earlier approved<br />
proposal accorded by CEA.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
17 Payments to M/s NPCC<br />
against claims of Principal<br />
Agreement in accordance<br />
to the decision of High<br />
Power Committee<br />
5000.00 1268<br />
18 Liabilities against major<br />
civil contract of MB-II<br />
Project<br />
(a)<br />
Reimbursement of Sales<br />
Tax<br />
815.32 Initially the project authority didnot release the payment<br />
against reimbursement of the Sales Tax. But it is being<br />
reviewed that this payment is payable or not as per the terms<br />
of condition of the contract. There<strong>for</strong>e, the cost involved in<br />
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Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
this was not included in the earlier approved proposal<br />
accorded by CEA.<br />
(b) Reimbursement of royalty 45.13 Initially the project authority didnot release the payment<br />
against reimbursement of the Royalty. But it is being reviewed<br />
that this payment is payable or not as per the terms of<br />
condition of the contract. There<strong>for</strong>e, the cost involved in this<br />
was not included in the earlier approved proposal accorded<br />
by CEA.<br />
(c) Award given by the<br />
arbitrator in favour of M/s<br />
Hydel Construction (P) Ltd<br />
against dispute related to<br />
6000.00 3073.00<br />
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Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
swellex Rock Bolt, Steel<br />
Fibre as Extra Item and loss<br />
due to flood alongwith<br />
interest of Rs 95424/- per<br />
month<br />
(d) Payment against misc.<br />
Works<br />
26.03<br />
(e) Security 35.00<br />
(g) Pending payment of GSI 95.32 GSI raised their bills after commissioning of the project.<br />
There<strong>for</strong>e, the cost involved in this was not included in the<br />
earlier approved proposal accorded by CEA.<br />
(g) Expenditure incurred <strong>for</strong> 3.00 35.00 Due to increase the number of arbitration cases.<br />
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Estimated cost of<br />
balance works, which<br />
Estimated<br />
S.No.<br />
Particulars of works<br />
were included in the<br />
Amount<br />
Remarks<br />
approval accorded by<br />
(in Lakhs)<br />
CEA<br />
arbitration<br />
Total 12120.00 21623.00<br />
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7.11 Annexure 11: Nature of Environmental Impacts caused by RMU and suggested mitigation measures<br />
Impact Area Impacts on Environmental Impact Mitigation Measures<br />
Soil and land<br />
Land take <strong>for</strong> reservoir<br />
Dumping of dredged silt in identified areas followed by<br />
(DAM & Head<br />
sediment disposal (muck),<br />
proper reclamation of the dumping sites. Alternatively,<br />
race tunnel)<br />
sediment flushing in smaller portions during monsoon<br />
period into river may be preferred. Special sediment<br />
Dam<br />
including<br />
flushing procedure to be developed.<br />
colony, desilting<br />
chamber,<br />
Head Race<br />
Tunnel &<br />
Barrage<br />
Geology<br />
(Head race<br />
tunnel)<br />
Soil and land<br />
(BARRAGE)<br />
Excavation of rock <strong>for</strong><br />
additional underground tunnel<br />
Permanent land take <strong>for</strong><br />
dumping of reservoir<br />
sediments:<br />
To be taken up only after detailed geological<br />
investigation keeping in view the fragile geology<br />
encountered at the time of initial construction of the<br />
project.<br />
Adequate engineering measures such as terraces and<br />
retaining walls should be implemented while dumping<br />
the dredged silt in identified areas, with proper<br />
reclamation and landscaping of dumping sites.<br />
Soil and land Soil pollution from handling of For dismantling and handling of oil containing equipment<br />
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Impact Area Impacts on Environmental Impact Mitigation Measures<br />
(DAM<br />
&<br />
oil (fuel, equipment)<br />
construction solutions should be developed.<br />
BARRAGE)<br />
Local<br />
climate<br />
Threats on air caused by<br />
Sprinkling of water at the construction site and on the<br />
and air<br />
dismantling: Dust from cement,<br />
transportation route; proper maintenance of project<br />
sand, excavation, induced by<br />
vehicles.<br />
heavy machines and vehicles<br />
etc.<br />
Water quality<br />
Noise<br />
environment<br />
Pollution of water quality due<br />
to the chemicals and fluids<br />
from vehicles, equipment to be<br />
dismantled<br />
Noise due to construction<br />
activities including increased<br />
vehicular movement<br />
For dismantling and handling of oil containing equipment<br />
special construction solutions have to be developed. This<br />
would include proper storage and disposal of all waste<br />
generated during the project work in compliance with<br />
the existing rules and regulations.<br />
Restriction of noise generating activities at night, use of<br />
noise barriers, and proper maintenance of vehicles and<br />
machineries.<br />
Fish stocks Degradation of natural fish Mandatory provision of minimum downstream discharge<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Impact Area Impacts on Environmental Impact Mitigation Measures<br />
stocks by dismantling and<br />
<strong>for</strong> ecological and social reasons<br />
construction works<br />
Health<br />
and<br />
Injury and sickness of project<br />
Preparation and implementation of health and safety<br />
safety<br />
personnel and local residents<br />
plan. Use of personal protective gears, availability of first<br />
due to accidents/fires and<br />
aid kits at site and arrangements with local<br />
natural hazards<br />
hospitals/dispensaries <strong>for</strong> emergency care.<br />
Powerhouse<br />
including units,<br />
trans<strong>for</strong>mers<br />
and switchyard<br />
Soil and land Permanent land take <strong>for</strong><br />
dumping of tunnel muck :<br />
Approximately 600,000 m³<br />
(incl. muck of Khodri HRT)<br />
Soil pollution from handling of<br />
oil (fuel, equipment)<br />
Local climate Threats on air caused by<br />
and air<br />
dismantling: Dust from cement,<br />
sand, excavation, induced by<br />
heavy machines and vehicles<br />
Dumping of excavated muck in identified areas only<br />
followed by proper reclamation of the dumping sites<br />
For dismantling and handling of oil containing equipment<br />
construction solutions should be developed.<br />
Sprinkling of water at the construction site and on the<br />
transportation route; proper maintenance of project<br />
vehicles.<br />
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Impact Area Impacts on Environmental Impact Mitigation Measures<br />
etc.<br />
Water quality<br />
Noise<br />
environment<br />
Change of water quality due to<br />
the chemicals and fluids from<br />
trans<strong>for</strong>mers, vehicles, heavy<br />
machines etc.<br />
Noise due to construction<br />
activities including increased<br />
vehicular movement<br />
For dismantling and handling of oil containing equipment<br />
construction solutions should be developed. This would<br />
include proper storage and disposal of all waste<br />
generated during the project work in compliance with<br />
the existing rules and regulations.<br />
Restriction of noise generating activities at night, use of<br />
noise barriers, and proper maintenance of vehicles and<br />
machineries.<br />
Fish stocks Degradation of natural fish<br />
stocks in Tons River by<br />
dismantling and construction<br />
works<br />
Mandatory provision of minimum downstream discharge<br />
<strong>for</strong> ecological and social reasons.<br />
Health<br />
and<br />
Injury and sickness of project<br />
Preparation and implementation of health and safety<br />
safety<br />
personnel and local residents<br />
plan. Use of personal protective gears, availability of first<br />
due to accidents/fires and<br />
aid kits at site and arrangements with local<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Impact Area Impacts on Environmental Impact Mitigation Measures<br />
natural hazards<br />
Geology Excavation of rock <strong>for</strong><br />
additional underground tunnel<br />
hospitals/dispensaries <strong>for</strong> emergency care.<br />
To be taken up only after detailed geological<br />
investigation keeping in view the fragile geology<br />
encountered at the time of initial construction of the<br />
project.<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
7.12 Annexure 12: Financing of RMU of Six Hydro Electric Projects Through KfW<br />
INTRODUCTION<br />
<strong>UJVN</strong> Ltd. has submitted the project cost <strong>for</strong> Modernization and Upgradation of six HEPs in the State of Uttarakhand which have been<br />
identified <strong>for</strong> funding under Loan from KfW available through Loan and Financing Agreement signed between kfW and PFC, on the basis<br />
of Bilateral Agreements executed between the Governments of India and Germany.<br />
1. Bilateral Agreement<br />
The Development Policy of the Federal Republic of Germany aims at improving economic and social living conditions in the developing<br />
countries. This goal is pursued chiefly by bilateral, government-to-government cooperation. The Bilateral Agreements on Financial Cooperation<br />
between the Govt. of Federal Republic of Germany and the Govt. of India were signed on 28.07.1994, 05.06.1997,<br />
04.10.2002 and 09.12.2005. The Financial Cooperation is carried out by KfW (Kreditanstalt für Wiederaufbau), on behalf of the German<br />
Federal Government.<br />
2. Loan and Financing Agreements<br />
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<br />
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-<br />
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<br />
<strong>for</strong> the purpose of partial funding of the investment costs of the rehabilitation and modernization of the electro-mechanical part<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
of older Hydro-Electric <strong>Plan</strong>ts (HEPs) in re<strong>for</strong>m-oriented States of India as identified by PFC and services of the pertaining<br />
implementation consultant.<br />
The project activities eligible <strong>for</strong> financing from the loan shall be:<br />
• Rehabilitation, modernization and up-gradation of electro-mechanical equipment and civil works of hydro power stations<br />
• Consulting services of the Implementation Consultant<br />
Financial Contribution shall be used exclusively <strong>for</strong> expert and seminar services. The project activities eligible <strong>for</strong> financing from the<br />
Financial Contribution shall comprise:<br />
• Consulting Services <strong>for</strong> preparation of Feasibility Studies (EUR 1,800,000)<br />
• Expert Services (EUR 1,033,875.64)<br />
o Panel of Experts (EUR 333,875.64)<br />
o Long-Term Experts (EUR 700,000)<br />
• Seminars (EUR 500,000)<br />
Interest Rate, Repayment Period and Commitment Charges<br />
The interest rate, repayment period and commitment charge, as applicable on soft loan (Portion I) and commercial loan (Portion II), as<br />
per financial terms of lending the proceeds from the KfW Line of Credit to PFC are as follows:<br />
Commercial Loan (Portion II) Soft Loan (Portion I)<br />
Amount (in EUR Million) 65.00 35.564<br />
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Commercial Loan (Portion II) Soft Loan (Portion I)<br />
KfW Interest Rate EURIBOR + 1.3% 0.75% (Fixed)<br />
Repayment period (as per original<br />
agreement)<br />
7 years 28 years (Starting after repayment of commercial<br />
loan)<br />
Repayment period (as per original<br />
agreement)<br />
30 th June 2011 – 30 th Dec<br />
2017<br />
30 th June 2018 – 30 th Dec 2045<br />
Repayment period (Revised) 30 th June 2014 – 30 th Dec<br />
30 th June 2018 – 30 th Dec 2045<br />
Commitment Charges<br />
2020<br />
0.25% p.a. on undisbursed<br />
loan amounts of each sub<br />
loan of portion II. It shall be<br />
computed <strong>for</strong> a period<br />
beginning three months from<br />
the date KfW approves in<br />
writing the re-financing of an<br />
individual sub-project from<br />
portion II and ending at the<br />
date at which disbursements<br />
are debited.<br />
0.25% p.a. on undisbursed amounts of portion I. It<br />
shall be computed <strong>for</strong> a period beginning three<br />
months after signing of the loan and financing<br />
agreement and ending at the date at which<br />
disbursements are debited.<br />
The salient features of Loan and Financing Agreement between KfW and PFC are as follows:<br />
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• 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<br />
is now December 30, 2015.<br />
• Taxes and other public charges to be borne by the Sub-borrowers and import duties would not be financed from the sub-loans.<br />
• As per clause 3.5, PFC shall pay the commitment charge, interest and any other charges on arrears semi-annually on June 30 and<br />
on December 30 of each year <strong>for</strong> the half year then ending. The commitment charge shall become due <strong>for</strong> the first time together<br />
with the first interest payment.<br />
• As per Article 6, to furnish security <strong>for</strong> the loan, the Republic of India (Guarantor) shall enter into separate Guarantee Agreement<br />
with KfW.<br />
Further, following major amendments are proposed to be made in the Loan and Financing Agreement between KfW and PFC:<br />
1. Extension of last disbursement date from 30.12.2010 to 30.12.2015.<br />
2. Extension of repayment commencement date of Portion-II of the loan from 30.06.2011 to 30.06.2014.<br />
These amendments have been approved by Ministry of Power, GoI and <strong>for</strong>warded to Dept. of Economic Affairs, Ministry of Finance,<br />
GoI <strong>for</strong> their approval. Sanction of loan is proposed to be subject to signing of amendments (as cited above) to Loan and Financing<br />
Agreement between PFC and KfW.<br />
3. Counter Guarantee cum Guarantee Fee Agreement<br />
In accordance with the provisions of the Loan and Financing Agreement between PFC and KfW, a Guarantee Agreement was signed<br />
between KfW and the Govt. of India (GoI) on 17.05.2006 whereby GoI has guaranteed the due and punctual repayment of principal,<br />
interest and other charges, including premium in case of pre-payment, to KfW. Accordingly, a Counter Guarantee cum Guarantee Fee<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
Agreement was signed between the Government of India (Ministry of Power, GoI) and PFC on 22.02.2008. The salient features of this<br />
Agreement are as follows:<br />
• The borrower (PFC) undertakes to pay the guarantor (GoI), in advance, a guarantee fee of zero point two percent (0.2%) p.a. on<br />
the sums guaranteed.<br />
• The payment of guarantee fee shall become due on the principal amount of loan withdrawn and outstanding including<br />
accumulated interest thereon and commence from the date of signing of the Guarantee agreement with KfW (i.e. 17.05.2006).<br />
• Thereafter <strong>for</strong> any subsequent financial year, the payment of guarantee fee would be made at the applicable rate on the principal<br />
amount of loan withdrawn and outstanding including accumulated interest thereon, on 1 st day of April next financial year.<br />
• 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<br />
year <strong>for</strong> which the guarantee fee is payable.<br />
4. Memorandum of Agreement between PFC and <strong><strong>UJVN</strong>L</strong><br />
Due to strong interest shown by <strong><strong>UJVN</strong>L</strong> in modernization and upgradation of its obsolete HEPs and fulfilment of eligibility criteria set by<br />
KfW and PFC <strong>for</strong> funding of projects, it was decided to concentrate the funds on <strong><strong>UJVN</strong>L</strong>. Subsequently, a Memorandum of Agreement<br />
(MoA) was signed between PFC and <strong><strong>UJVN</strong>L</strong> on 17.12.2005 <strong>for</strong> utilizing the above mentioned KfW Loan and Financial Contribution <strong>for</strong><br />
Modernization and Upgradation of older HEPs. Certain amendments to MoA are proposed to be signed between PFC and <strong><strong>UJVN</strong>L</strong> after<br />
taking note of changes in Loan and Financing Agreement. <strong><strong>UJVN</strong>L</strong> vide letter dated 04.05.2012 have agreed to sign such amendments.<br />
The financial terms of on-lending the proceeds from the line of credit from KfW are as follows:<br />
Commercial Loan<br />
KfW Interest Rate EURIBOR + 1.3% 0.75% (Fixed)<br />
Soft Loan<br />
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<strong>Business</strong> <strong>Plan</strong> of <strong>UJVN</strong> <strong>Limited</strong> <strong>for</strong> Control Period<br />
PFC Margin 1.00% 1.00%<br />
Total Interest Rate (Payable Semi-Annually) EURIBOR + 2.3% 1.75%<br />
Repayment period offered by PFC to <strong><strong>UJVN</strong>L</strong> (as per 7 years 5 years (Starting after repayment of<br />
original agreement)<br />
commercial loan)<br />
Repayment period (as per original agreement) 30 th June 2011 – 30 th Dec<br />
2017<br />
30 th June 2018- 30 th December 2022.<br />
Repayment period offered by PFC to <strong><strong>UJVN</strong>L</strong> (as per<br />
proposed amendments to MoA)<br />
7 years 11 years<br />
Repayment period (as per proposed amendments to<br />
MoA)<br />
30 th June 2014 – 30 th Dec<br />
2020<br />
30 th June 2018- 30 th December 2028.<br />
Commitment charges<br />
Taxes<br />
Govt. of India Guarantee fee<br />
(Reduced from 1.20% p.a. to 0.2% p.a., the benefit of<br />
reduction of guarantee fee is passed on to <strong><strong>UJVN</strong>L</strong>)<br />
On actuals (the entire commitment charges payable by PFC to KfW as per the<br />
LFA shall be reimbursable by <strong><strong>UJVN</strong>L</strong> to PFC)<br />
Additional charges, taxes and duties including withholding tax applicable if<br />
any, on borrowed funds under LoC are payable at actual by <strong><strong>UJVN</strong>L</strong><br />
0.20% p.a. on the principal amount of loan withdrawn and outstanding<br />
including accumulated interest thereon by <strong><strong>UJVN</strong>L</strong> which will be paid by <strong><strong>UJVN</strong>L</strong><br />
at the beginning of financial year till the end of repayment period of 35 years.<br />
The R&M Projects in Uttarakhand identified <strong>for</strong> utilization of KfW loan are as follows:<br />
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Chibro Khodri Tiloth Dhakrani Dhalipur Kulhal<br />
Capacity (MW) 4X60 4X30 3X30 3X11.25 3X17 3X10<br />
Project Cost (EUR Mn) 27.59 25.30 18.74 17.47 17.38 17.75<br />
Project Cost* (Rs Cr) 184.88 169.63 126.23 116.41 116.81 118.72<br />
Cost/MW (RsCr) 0.77 1.41 1.40 3.47 2.29 3.97<br />
*1 Euro= Rs67.07<br />
Note: As per decision taken by Department of External Affairs (DEA), Govt. of India, in the meeting held in New<br />
Delhi on dated 10/10/2012, three tunnel based HEP’s i.e. Chibro, Khodri and Tiloth HEPs may not be funded by<br />
KfW <strong>for</strong> RMU works. However communication from KfW in this respect has not yet been received. Accordingly,<br />
RMU of these projects may be undertaken under National Competitive Bidding with Domestic financing after<br />
consent of Government of Uttrakhand is conveyed to DEA and subsequently their <strong>for</strong>mal approval is received by<br />
<strong><strong>UJVN</strong>L</strong>.<br />
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Annexure 13: Letter of CEA <strong>for</strong> Lakhwar Power Station<br />
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7.13 Annexure 14: Loan Agreement of PFC <strong>for</strong> RMU of Khatima Power Station<br />
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7.14 Annexure 15: Note on Small Hydroelectric Projects<br />
316
SMALL HYDRO PROJECTS (SHP)<br />
There are 10 SHPs under construction having installed capacity of 58.00 MW in district<br />
Rudraprayag, Pauri, Uttarkashi and Pithoragarh. These projects are funded by ADB and<br />
NABARD. The list alongwith proposed fund requirement of these SHPs are enclosed as<br />
Annexure-A.<br />
There are 12 SHPs under investigation and planning (I&P) stage having installed<br />
capacity of 122.6 MW. DPR of Suringad-II and Bhilangna-IIA have been prepared and<br />
tenders have been invited which may be awarded during 2012-13 and 2013-14. The<br />
DPR of rest of the 10 SHPs are expected to be completed by June 2013. The list<br />
alongwith proposed fund requirement of SHPs are enclosed as Annexure-B.<br />
Apart from the above there are 32 SHPs, constructed in the time of erstwhile UPJVNL<br />
and handed over to Nigam Annexure-C. 22 no. of these SHPs are running and 10<br />
under closed conditions. The total installed capacity of these SHPs is 24.55 MW. In<br />
compliance to orders of Uttarakhand Government vide letter no. 80@fu-l-@Á-l&eq e-<br />
@2012 fnukad 12.12.2012 (Annexure), the SHPs below 3 MW capacity are to be<br />
handed over to UREDA. The process of handing over of SHPs below 3 MW capacity<br />
has been initiated. The list of plant, machinery, residential and non-residential building,<br />
furniture, land etc. is under preparation.
KALIGANGA-I SMALL HYDROELECTRIC PROJECT (4 MW)<br />
Kaliganga-I Small Hydro Electric Project is having an installed capacity of 4000 KW<br />
with two (02) units of 2000 KW each. The project is being financed by ADB. The<br />
contract was awarded on 07.11.2007 and completion as per Contract was 6th Feb.<br />
2010. This project has been commissioned on 18/19 July 2012 and now in<br />
operation. The reasons <strong>for</strong> delayed commissioning of the project were due to (i)<br />
Dispute in demarcation of Forest land, (ii) Design changes in the project took<br />
considerable time,(iii) Road Blockage due to cloud burst in rainy season affected<br />
progress of work at the project,(iv) Heavy monsoon and cloud bursting and<br />
washing away of T &P of contractor,(v)Difficulty being faced by the contractors in<br />
transporting material, machines and equipment to site due to damaged approach<br />
road near Kalimath Temple,(vi) Hindrance created by local villagers regarding their<br />
demands varying from time to time,(vii) Land issues with local natives <strong>for</strong><br />
transmission towers in Rudraprayag District.<br />
KALIGANGA-II SMALL HYDROELECTRIC PROJECT (6 MW)<br />
Kaliganga-II Small Hydro Electric Project is having an installed capacity of 6000<br />
KW with two (02) units of 3000 KW each. The project is being financed by ADB.<br />
For the project two contracts were awarded i) Civil & ii) E &M. Civil Contract was<br />
signed on 04.04.2008. The effective date of start was 2 nd May 08. The duration of<br />
contract was kept <strong>for</strong> two years with the due date of completion as 1 st May 2010. E<br />
&M Contract was signed on 16.06.2008 <strong>for</strong> Design, Supply, Installation,<br />
Commissioning and Testing of Electromechanical work of Kaliganga-II SHP. The<br />
effective date of start was 5 th July 08. The duration of contract was kept <strong>for</strong> two<br />
years with the due date of completion as 04 th July 10. The project could not be<br />
completed in time due to various reasons as mentioned below and now the<br />
commissioning of project is expected by Dec. 2013. The reasons <strong>for</strong> delay are<br />
mainly due to (i)Design was changed due to changes in gross head which took<br />
considerable time in finalization of the layout,(ii) The PWD Road to this project site<br />
was damaged due to frequent landslides. Due to this, difficulty was faced in<br />
supplying the material to site.(iii) <strong>Limited</strong> use of explosive due to tunnel location in<br />
the near vicinity of village.(iv) Increase in scope of work, change proposal.(v)Heavy<br />
monsoon and cloud bursting and washing away of T &P of contractor.(vi) Difficulty<br />
being faced by the contractors in transporting material, machines and equipment to<br />
site due to damaged approach road. (vii) Hindrance created by local villagers<br />
regarding their demands varying from time to time.<br />
MADHYAMAHESHWAR SMALL HYDROELECTRIC PROJECT (15 MW)<br />
Madhyamaheshwar Small Hydro Electric Project is having an installed capacity of<br />
15 MW with three units of 5MW each. Previously the capacity was 10MW which<br />
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<br />
start was 7 th Feb. 2008. The duration of contract was kept as two years with the<br />
due date of completion as 6 th Feb. 2010 <strong>for</strong> 10MW SHP. The capacity of the<br />
project was further enhanced to 15.00 MW and the modified contract agreement<br />
<strong>for</strong> 15 MW was signed on 11.03.2010 with modified completion period as<br />
10.08.2011. Works on the project slowed down due to various reasons, some of<br />
these are (i) Hindrance created by local villagers regarding their demands varying<br />
from time to time, (ii) PWD Road to this project site was damaged due to frequent<br />
landslides. Due to this difficulty was faced in supplying the material to site.(iii)<br />
Design changes in the project took considerable time.(iv)Considerable increase in<br />
scope of work (from 10 MW to 15 MW).(v) Unusual heavy rains in 2010 & 2011<br />
and cloud burst in Ukhimath in 2012.<br />
All out ef<strong>for</strong>ts are being made to commission the project in 2014-15 as per revised<br />
schedule, if there is no hindrance from any corner and uncertain geological<br />
condition in the tunnel or natural flood condition.<br />
KALDIGAD SMALL HYDROELECTRIC PROJECT (9 MW)<br />
Kaldigad Small Hydro Electric Project is having an installed capacity of 9 MW with<br />
two (02) units of 4.5 MW each. The project is being financed by ADB.<br />
For the project two contracts were awarded (i) Civil & ii) E &M. Civil Contract was<br />
signed on 24.12.2008 and the E&M contract was signed on 16.10.2008. The total<br />
duration of the contract was kept <strong>for</strong> two years as such the date of completion was<br />
2.12.2010, but civil contract has been cancelled due to poor per<strong>for</strong>mance of the<br />
contractor and new tenders shall have to be invited. This project has damaged due<br />
to devastating flood caused by cloudburst in District Uttarkashi on 03.08.2012, now<br />
action on the project is being taken as per recommendations of the Technical<br />
Expert Committee constituted <strong>for</strong> suggesting remedial measures. Some additional<br />
land may also be required. The commissioning of project is expected by Aug.<br />
2015, if there is no hindrance from any corner and uncertain geological condition in<br />
the tunnel and additional land is transferred at an early date.<br />
SOBLA-I SMALL HYDROELECTRIC PROJECT (8 MW)<br />
Sobla-I Small Hydro Electric Project is having an installed capacity of 8 MW with two<br />
(02) units of 4.0 MW. The Civil works are being funded by NABARD and E &M<br />
works are being funded by ADB. All out ef<strong>for</strong>ts are being made to commission the<br />
project upto June 2013 if there is no hindrance from any corner.
ASIGANGA-I SMALL HYDROELECTRIC PROJECT (4.5 MW)<br />
Asiganga-I Small Hydro Electric Project is having an installed capacity of 4500 kW<br />
with two (02) units of 2250 kW. The project is being financed from NABARD,<br />
MNRE & GoU Equity.<br />
Tenders in different packages were invited <strong>for</strong> the SHP and the original date of<br />
completion was 2005-06, the project could not be completed upto the expected<br />
date of completion due to some change in civil structures. The revised date of<br />
commissioning was Nov. 2012, but there were heavy damages in civil structures<br />
due to devastating flood caused by cloudburst on 03.08.2012. A Technical Expert<br />
Committee was <strong>for</strong>med by MD <strong><strong>UJVN</strong>L</strong> <strong>for</strong> study and suggesting remedial<br />
measures <strong>for</strong> small hydro power projects damaged due to flood caused by<br />
cloudburst in District Uttarkashi on 03.8.2012. Works on the project slowed down<br />
due to various reasons. Some of these are: (i) Allotment of land <strong>for</strong> compensatory<br />
af<strong>for</strong>estation in District Uttarkashi (ii) Due to introduction of tunnel in place of open<br />
power channel, previous tenders were cancelled and fresh tenders were invited, (iii) Land<br />
slide in Power Channel alignment.(iv) Need <strong>for</strong> construction of Tunnel in place of<br />
Power channel.(v) The agreements of some of the contractor were cancelled due<br />
to their non responsive nature, hence construction activity took considerable<br />
time.(vi) Public agitations resulted in disruption of work.(vii) Design changes in the<br />
project took considerable time. (viii) Local problems <strong>for</strong> their demand varying time<br />
to time mainly <strong>for</strong> permanent employment in <strong><strong>UJVN</strong>L</strong> and also development work in<br />
project affected villages.(ix) Three accidents during channel excavation.<br />
All out ef<strong>for</strong>ts are being made to commission the project upto October 2014, if<br />
there is no hindrance from any corner<br />
ASIGANGA-II SMALL HYDROELECTRIC PROJECT (4.5 MW)<br />
Asiganga-II Small Hydro Electric Project is having an installed capacity of 4500 kW<br />
with two (02) units of 2250 kW each. The project is being financed from NABARD,<br />
MNRE & GoU Equity.<br />
Tenders in different packages were invited <strong>for</strong> this SHP and the original date of<br />
completion was 2005-06 which was extended upto Oct. 2011 as per revised<br />
capacity. Works on the project slowed down due to various reasons. Some of<br />
these are: (i) Delay in allotment of land <strong>for</strong> compensatory af<strong>for</strong>estation in District<br />
Uttarkashi (ii) Due to introduction of tunnel in place of open power channel, the<br />
previous tenders were cancelled and fresh tenders were invited, (iii) The<br />
agreements of some of the contractor were cancelled due to their non responsive<br />
nature , hence construction activity took considerable time to start the works,(iv)<br />
The capacity of the project was enhanced from 3.0 MW to 4.5 MW , hence design<br />
parameters were changed, (v)Public agitations resulted in disruption of work, (vi)<br />
Design changes in the project took considerable time,(vii) Local problems <strong>for</strong> their<br />
demands varying time to time mainly <strong>for</strong> permanent employment in <strong><strong>UJVN</strong>L</strong> and<br />
also development work in project affected villages caused delay,(viii) In view of
accidents at adjacent project Asiganga-I , the construction activities were stopped<br />
during rains<br />
The project has damaged due to devastating flood caused by cloudburst in District<br />
Uttarkashi on 03.08.2012, now action on the project is being taken as per<br />
recommendations of the Technical Expert Committee constituted <strong>for</strong> suggesting<br />
remedial course of action <strong>for</strong> small hydro power projects damaged due to<br />
cloudburst in District Uttarkashi on 03.8.2012<br />
All out ef<strong>for</strong>ts are being made to commission the project upto October 2014, if<br />
there is no hindrance from any corner<br />
DUNAO SMALL HYDROELECTRIC PROJECT (1.5 MW)<br />
Dunao Small Hydro Electric Project is having an installed capacity of 1.5 MW with<br />
two (02) units of 750 kW project. The project is being financed from NABARD,<br />
MNRE & GoU Equity<br />
Tenders in different packages were invited <strong>for</strong> this SHP and the original date of<br />
completion was 2007-08, the project could not be completed upto the expected<br />
date of completion due to various reasons. Some of these are: (i) Necessity of retendering<br />
due to higher rates in original tenders. (ii) Due to remote site condition,<br />
the response of the bidder was poor, so tendering process took long time.(iii)<br />
Project was stopped as per directions of BOD from 11.02.2010 to 15.09.2010 due<br />
to shortage of funds.(iv) Slow progress of Civil works due to non-availability of site<br />
access.(v) Adverse working conditions & site remoteness even labourers are not<br />
staying at Project site.(vi) Considerable time taken in making approach to project<br />
site.(vii) Due to non-per<strong>for</strong>mance of Civil Contractor <strong>for</strong> P.H. Building, the contract<br />
has been cancelled.(viii) Technical problem <strong>for</strong> using old machines from another<br />
SHP <strong>for</strong> Dunao and necessity of procurement of new machine.<br />
All out ef<strong>for</strong>ts are being made to commission the project upto December 2013, if<br />
there is no hindrance from any corner<br />
SUWARIGAD SMALL HYDROELECTRIC PROJECT (2.0 MW)<br />
Suwarigad Small Hydro Electric Project is having an installed capacity of 2 MW<br />
with two (02) units of 1 MW each. The project is being financed from NABARD,<br />
MNRE & GoU Equity. The contract agreement <strong>for</strong> construction of the project was<br />
signed on 29.09.2011. The completion period was expected by Mar. 2013, but in<br />
the project there is problem of land. The land of the SHP was included in land case<br />
of Pala Maneri. With closure of Pala Maneri, the <strong>for</strong>est department has not allowed<br />
to work on Suwarigad SHP, now land case is being presented to competent<br />
authority <strong>for</strong> approval.
All out ef<strong>for</strong>ts are being made to commission the project upto December 2013, if<br />
there is no hindrance from any corner and the land case is approved at the<br />
earliest.<br />
LIMCHAGAD SMALL HYDROELECTRIC PROJECT (3.5 MW)<br />
Limchagad Small Hydro Electric Project is having an installed capacity of 3500 kW<br />
with two (02) units of 1750 kW each. The project is being financed by NABARD,<br />
MNRE & GoU Equity. The contract agreement <strong>for</strong> construction of the project was<br />
signed on 29.09.2011 and the commissioning is expected by March 2014, but in<br />
the project there is requirement of extra land <strong>for</strong> which approval is being taken from<br />
competent authority.<br />
All out ef<strong>for</strong>ts are being made to commission the project upto March 2014, if there<br />
is no hindrance from any corner
Annexure-A<br />
<strong>Business</strong> <strong>Plan</strong> <strong>for</strong> Small Hydro Projects Under Construction<br />
S.No.<br />
Name of Project<br />
Capacity<br />
(MW)<br />
Expected<br />
Commissioning<br />
of Project<br />
Project Cost Proposed Fund Requirement (Rs in Crores)<br />
(as per DPR)<br />
(Rs in upto 2012-<br />
Crores) 13<br />
2013-14 2014-15 2015-16 2016-17<br />
1 Kaliganga-I 4.00 Commissioned 32.22 29.25 2.97<br />
2 Sobla-I 8.00 Jun. 2013 36.26 19.00 11.00<br />
3 Kaliganga-II 6.00 Dec. 2013 68.93 33.53 10.00 6.89<br />
4 Dunao 1.50 Dec. 2013 31.20 7.85 10.00 3.12<br />
5 Madhyamaheshwar 15.00 2014-15 120.21 31.06 16.50 25.50 3.01<br />
6 Suwarigad 2.00 Mar. 2014 16.06 1.75 5.00 2.41 0.80<br />
7 Limchagad 3.50 Mar. 2014 26.59 2.68 5.00 3.99 1.33<br />
8 Asiganga-I 4.50 Oct. 2014 40.40 26.26 3.50 6.06 2.02<br />
9 Asiganga-II 4.50 Oct. 2014 36.97 17.85 10.00 5.55 1.85<br />
10 Kaldigad 9.00 Aug. 2015 76.19 32.29 5.00 11.46 11.43 3.81<br />
Total 58.00 485.03 201.52 78.97 64.98 20.44 3.81<br />
Note:- We are trying hard to complete these projects in time ,but the schedule may change due to uncertainty involved in geological conditions, change<br />
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-<br />
II ,Suwarigad and Limchagad SHP.
Annexure-B<br />
<strong>Business</strong> <strong>Plan</strong> <strong>for</strong> Small Hydro Projects Currently Under Investigation and <strong>Plan</strong>ning<br />
S.No.<br />
Name of Project<br />
Capacity<br />
(MW)<br />
Expected<br />
Award of<br />
Contract<br />
Expected<br />
Commissionin<br />
g of Project<br />
Project<br />
Cost<br />
(Rs in<br />
Crores)<br />
Proposed Fund Requirement (Rs in Crores)<br />
2013-14 2014-15 2015-16 2016-17 2017-18 2018-19 2019-20<br />
1 Suringad-II 5.00 Mar-13 Sep-16 49.60 4.96 9.92 14.88 14.88 4.96<br />
2 Urgam-II 5.00 Sep-13 Sep-16 47.00 4.70 9.40 14.10 14.10 4.70<br />
3 Guptkashi 1.30 Mar-14 Sep-16 8.00 0.80 3.20 3.20 0.80<br />
4 Chamoli 0.80 Jun-14 Jun-17 3.20 0.32 0.64 0.96 0.96 0.32<br />
5 Sonegad 7.50 Jun-14 Jun-17 65.00 6.50 13.00 19.50 19.50 6.50<br />
6 Tankul 12.00 Sep-14 Sep-17 96.00 9.60 19.20 28.80 28.80 9.60<br />
7 Bhilangna-II A 24.00 Sep-13 Sep-17 233.81 11.69 23.38 58.45 58.45 58.45 23.38<br />
8 Painagad 9.00 Mar-14 Sep-17 77.57 3.88 19.39 23.27 23.27 7.76<br />
9 Asiganga-III 9.00 Sep-13 Sep-17 93.34 4.67 23.34 28.00 28.00 9.33<br />
10 Pilangad-II 4.00 Dec-14 Dec-17 24.00 1.20 3.60 8.40 8.40 2.40<br />
11 Bhilangna-II B 24.00 Jun-14 Mar-18 227.93 11.40 34.19 45.59 56.98 56.98<br />
12 Bhilangna-II C 21.00 Sep-14 Jun-18 199.50 9.98 29.93 39.90 49.88 49.88 19.95<br />
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)<br />
Background:<br />
The power station is located on the Upper Ganga Irrigation canal that takes off<br />
from the Bhim goda Barrage near Haridwar at a distance of 13 km downstream<br />
of Haridwar. The power plant was commissioned in the year 1955. The surface<br />
Power House comprising 3 units of 6.8 MW each with Kaplan turbines of 8400<br />
HP output is located on the unlined irrigation canal and the water is utilized <strong>for</strong><br />
the irrigation purpose in the command area of the canal.<br />
Project Cost without IDC :<br />
INR 92.86 Crore<br />
Project Cost with IDC : INR 105.63 Crore<br />
Cost Breakup:<br />
E&M Works : INR 80.96 Crore<br />
HM Works : INR 4.92 Crore<br />
Civil Works : INR 2.41 Crore<br />
Establishment : INR 3.05 Crore<br />
Ordinary T&P : INR 0.77 Crore<br />
Loss on stock : INR 0.0055 Crore<br />
Receipt & recovery : INR -0.03 Crore<br />
Audit & Account : INR 0.77 Crore<br />
Average Generation as Per RMU DPR (Post Tehri) :<br />
90 MU<br />
Generation after RMU : 155.6 MU
Status of RMU Works:<br />
‣ Contract Signed on 9th March 2010<br />
‣ Machine # 3 given <strong>for</strong> reverse engineering on 11th May 2010 and<br />
after taking the measurements the machine was put on the bars on<br />
2nd July 2010.<br />
‣ After engineering & change request acceptance Machine # 3 was<br />
given <strong>for</strong> extensive RMU on 6th Oct 2011<br />
Commissioning Schedule:<br />
Machine # 3 : From 6th Oct 2011 to 30th April 2013<br />
Machine # 1 : From 1st March 2013 to 29th Nov 2013<br />
Machine # 2 : From 1st April 2013 to 30th Nov 2013<br />
Financing of Capital Expenditure:<br />
The Project is being financed with the Debt: Equity ratio of 70:30. The funding<br />
is being done through PNB.<br />
MNRE Grant : INR 12.50 Crore<br />
Phasing of Capital Expenditure :<br />
Year 2010-11 2011-12 2012-13 2013-14<br />
Capital<br />
Expenditure<br />
(Rs Cr)<br />
11.14 5.85 23.22 52.65
2. Mohd. Pur Hydroelectric Project (9.3 MW)<br />
Background:<br />
Mohammadpur Power House has been constructed on upper Ganga Canal at<br />
49.5 km downstream of Mayapur Head Works, Hardwar. The power house,<br />
which has 3 units of 3.1 MW each, was commissioned in the year 1952. All the<br />
mechanical equipments were supplied by M/s Boving and Co., England and<br />
electrical equipments by M/s British Thomson Houston, (BTH) England.<br />
Project Cost without IDC : INR 67.39 Crore<br />
Project Cost with IDC : INR 76.55 Crore<br />
Cost Breakup:<br />
E&M Works : INR 60.48 Crore<br />
HM Works : INR 1.2 Crore<br />
Civil Works : INR 1.9 Crore<br />
Establishment : INR 2.54 Crore<br />
Ordinary T&P : INR 0.64 Crore<br />
Loss on stock : INR 0.0.0077 Crore<br />
Receipt & recovery : INR -0.013 Crore<br />
Audit & Account : INR 0.64 Crore<br />
Average Generation as Per RMU DPR (Post Tehri) : 40.44 MU<br />
Generation after RMU : 64.92 MU<br />
Status of RMU Works:<br />
‣ Contract Signed on 6 th April 2010<br />
‣ Machine # 2 given <strong>for</strong> given <strong>for</strong> extensive RMU on 6 th June 2010<br />
‣ All works related to switchyard, control room & switchgear<br />
completed in Nov 2011.
‣ Machine # 2 was commissioned and connected to Grid on 30 th April<br />
2012<br />
‣ Machine # 1 was given <strong>for</strong> extensive RMU on 1 st May 2012<br />
‣ Machine # 3 was given <strong>for</strong> extensive RMU on 15 th Oct 2012<br />
Commissioning Schedule:<br />
Machine # 2 : From 6 th June to 30 th April 2012<br />
Machine # 1 : From 1 st May 2012 to 30 th April 2013<br />
Machine # 3 : From 15 th Oct 2012 to 5 th June 2013<br />
Financing of Capital Expenditure:<br />
The Project is being financed with the Debt: Equity ratio of 95:5. The funding is<br />
being done through NABARD.<br />
MNRE Grant<br />
: INR 6.65 Crore<br />
Phasing of Capital Expenditure :<br />
Year 2010-11 2011-12 2012-13 2013-14<br />
Capital<br />
Expenditure<br />
(Rs Cr)<br />
10.78 17.94 21.40 17.27
3. Galogi Hydroelectric Project (3 MW)<br />
Background:<br />
One of the oldest running power house (commissioned in 1907) in the country and<br />
there<strong>for</strong>e a part of Indian National Heritage, Galogi Hydropower Station is located<br />
on river Kyarkuli near Mussoorie – about 22 km from <strong>Dehradun</strong>. It has 2 machines<br />
of 500 kW each and 2 machines of 1000 kW each. However, the historical<br />
capacity of this scheme is 2381 kW based on available discharge to the<br />
machines. 2 units of 500 kW were installed in Phase-I in the year 1907 and 2 units<br />
of 1000 kW in 1933 in Phase-II. Mussoorie was India’s second and Northern<br />
India’s first region to generate electricity.<br />
Project Cost without IDC : INR 20.14 Crore<br />
Project Cost with IDC : INR 21.46 Crore<br />
Cost Breakup:<br />
E&M Works : INR 9.83 Crore<br />
HM Works : INR 6.8 Crore<br />
Civil Works : INR 2.7 Crore<br />
Establishment : INR 0.77 Crore<br />
Ordinary T&P : INR 0 Crore<br />
Loss on stock : INR 0.0.02 Crore<br />
Receipt & recovery : INR 0 Crore<br />
Audit & Account : INR 0.02 Crore<br />
Average Generation as Per DPR : 3.07 MU<br />
Generation after RMU : 8.28 MU<br />
Status of RMU Works:<br />
‣ Contract <strong>for</strong> penstock works signed in Jan 2009<br />
‣ Contract <strong>for</strong> E&M works signed in July 2009
‣ Penstock work completed on 30 th April 2012<br />
‣ Machine # 1 connected to grid on 18 th Feb 2012<br />
‣ Machine # 4 connected to grid on 7 th Aug 2012<br />
‣ Due to damage of 6.6 / 33 kV trans<strong>for</strong>mer at Anarwala S/S of UPCL<br />
the machines are being operated presently in standalone mode<br />
with a maximum demand of 200 kW at Barloganj.<br />
‣ Machine # 2 shall be taken under RMU after commissioning of DG<br />
set.<br />
Commissioning Schedule:<br />
Machine # 1 : From 7 th Aug 2009 to 18 th Feb 2012<br />
Machine # 2 :<br />
From 30 th Jan 2013 to 30 th April 2013 (subject to<br />
Installation of DG set)<br />
Machine # 4 : From 7 th Aug 2009 to 7 th Aug 2012<br />
Financing of Capital Expenditure:<br />
The Project is being financed with the Debt: Equity ratio of 70:30. The funding<br />
is being done through PNB.<br />
MNRE Grant : INR 3.5 Crore<br />
Phasing of Capital Expenditure :<br />
Year 2007-<br />
08<br />
2008-<br />
09<br />
2009-10 2010-<br />
11<br />
2011-12 2012-13 2013-<br />
14<br />
Capital<br />
Expenditure<br />
(Rs Cr)<br />
0.168 0.336 1.846 2.685 5.035 5.035 5.035
CAPITAL EXPENDITURE FOR RMU OF PATHRI, MOHD. PUR & GALOGI SHPs<br />
Rs. Crores<br />
PROJECT NAME<br />
Capital Expenditure<br />
FY 2007-08 FY 2008-09 FY 2009-10 FY 2010-11 FY 2011-12 FY 2012-13 FY 2013-14<br />
RMU OF SHPs<br />
GALOGI 0.17 0.34 1.85 2.69 5.04 5.04 5.04<br />
PATHRI 11.14 5.85 23.22 52.65<br />
MOHD.PUR 10.78 17.94 21.40 17.27<br />
TOTAL OF RMU OF SHPs 0.17 0.34 1.85 24.61 28.83 49.66 74.96
<strong>UJVN</strong> Ltd.<br />
Manpower <strong>Plan</strong>ning <strong>for</strong> the control Period<br />
1. Permanent Strength – Sanctioned and Actual at present – Annexure 1<br />
2. New Projects including Green Site Projects – as sanctioned by GoU – 213 Numbers –<br />
Annexure 2<br />
3. Vyasi Project - as sanctioned by GoU – 199 numbers – Annexure 3<br />
4. R.M.U. structure created to meet Renovation, Modernization and Up-gradation of existing<br />
Power Houses – Annexure 4<br />
5. S.H.P. (Small Hydro Projects) – Structure created – Annexure 5<br />
6. In order to cope up with the manpower requirement of New Projects and replacement of<br />
retired employees, the following steps have been taken during the year 2012-13<br />
6.1 Employees joined during 2012-13 :-<br />
Sl.No. Name of the post at Induction Level Number of persons<br />
recruited / joined<br />
1 Junior Engineer (Trainee) - Civil 68<br />
2 Asstt. Engineer (Trainee) - Civil 13<br />
3 Junior Engineer (Trainee) – E&M 28<br />
4 Accounts Officer 09<br />
5 Manager (Environment) 01<br />
Total 119<br />
6.2 Appointment Offers issued and number of employees expected to join :-<br />
Sl.No. Name of the post at Induction Number of persons Remarks<br />
Level<br />
recruited / joined<br />
1 Junior Engineer (Trainee) - Civil 19 To join on 28/01/13<br />
2 Asstt. Engineer (Trainee) – E&M 23 To join on 29/01/13<br />
3 Asstt. Engineer (Trainee) – Civil 04 To join by 01/03/13<br />
4 Junior Engineer (Trainee) –<br />
E&M<br />
30 Appointment Offers to be<br />
issued after verification of<br />
documents to join by<br />
31/03/13<br />
5 Asstt. Engineer (Trainee) – Civil 03 Appointment Offers to be<br />
issued to join by 31/03/13<br />
Total 79<br />
6.3 Recruitment planned <strong>for</strong> ministerial cadre during 2013 -14<br />
Written test organized by Uttarakhand Board of Technical Education on 04/11/2012<br />
<strong>for</strong> recruitment <strong>for</strong> following posts – expected to join during the year 2013-14<br />
‣ Stenos<br />
– 85 numbers<br />
‣ Office Asstt. Grade III (Clerical Cadre) – 68 numbers<br />
‣ Asstt. Store Keepers<br />
– 21 numbers<br />
‣ Asstt. Accountant<br />
–06 numbers<br />
Total<br />
- 180 numbers
6.4 Recruitment planned <strong>for</strong> Technical / Operating / Officer cadre during 2013-14<br />
Name of the post Number of posts Remarks<br />
T.G. II (Elect. & Mech) 123 Advertisement being released by<br />
Draughtsman 50 Uttarakhand Board of technical<br />
Education<br />
Personnel Officer 03 Advertisement being released by<br />
Geologist 02 <strong>UJVN</strong> Ltd.<br />
Asstt. Company Secretary 01<br />
Sr. Geologist 01 In process on Deputation basis<br />
Total 180<br />
6.5 Additional manpower of AEs (T) and JEs (T) will also be met – during the year 2013-14<br />
after sanction from GoU is received <strong>for</strong> additional posts to be appointed after 28.02.13<br />
(Annexure 2) as the recruitment process has already been finalized <strong>for</strong> one year.<br />
7. For optimum utilization of manpower and succession planning, the following steps to be<br />
taken –<br />
7.1 Defining of Job responsibilities, role/profile succession planning keeping in view<br />
structure of New Projects, SHPs/ O&M Projects/ RMU Projects, in consultation with<br />
concerned Director / E.D.<br />
7.2 Training of newly recruited Engineers at SJVNL/BBMB/NHPC/THDC/IITs<br />
7.3 In-house and on the job training of newly recruited engineers / staff in a systematic<br />
manner.<br />
7.4 Posting of Engineers in new projects to be done in a phased manner.<br />
7.5 As per Government instructions, Class IV posts are to be managed by way of<br />
outsourcing.