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BHARMOUR HYDRO PROJECTS PVT. LTD.

BHARMOUR-I HYDRO ELECTRIC PROJECT

(3 x 8 MW)

DISTRICT CHAMBA, HIMACHAL PRADESH

DETAILED PROJECT REPORT(VOLUME - I & II)

September 2014

Indo Canadian Consultancy Services Limited

Bhilwara Towers, A-12, Sector-1, Noida – 201301

Website : www.iccspower.com

Consultant :

gopikrushna.n

Typewritten Text

Annexure-VI

BHARMOUR HYDRO PROJECTS PVT. LTD.

BHARMOUR-I HYDRO ELECTRIC PROJECT

(3 x 8 MW)(3 x 8 MW)

DISTRICT CHAMBA, HIMACHAL PRADESH

DETAILED PROJECT REPORTDETAILED PROJECT REPORT

(VOLUME - I)

September 2014

Indo Canadian Consultancy Services Limited

Bhilwara Towers, A-12, Sector-1, Noida – 201301

Website : www.iccspower.com

Consultant :

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) Table of Contents

Indo Canadian Consultancy Services Ltd. 1 P-1335

Table of Contents LIST OF ANNEXURES .......................................................................................................................... 10

LIST OF TABLES .................................................................................................................................. 11

LIST OF FIGURES ................................................................................................................................ 13

LIST OF PHOTOS ................................................................................................................................. 14

BIBLIOGRAPHY OF ABBREVIATIONS .............................................................................................. 15

CHECK LIST ......................................................................................................................................... 19

1. INTRODUCTION ........................................................................................................................ 26

1.1 The Project .......................................................................................................................... 26

1.2 Location and Access to Project Site ................................................................................... 26

1.3 General Climatic Conditions, Topography and Geology of the Region .............................. 27

1.4 Need for the Project ............................................................................................................ 27

1.5 Natural Resources of the State ........................................................................................... 28

1.6 Land Requirement .............................................................................................................. 28

1.7 Population Affected by the Project ...................................................................................... 28

1.8 Scope of the Present Study ................................................................................................ 29

1.9 Preparation of DPR ............................................................................................................. 29

1.10 Project Benefits ................................................................................................................... 29

1.11 Project Cost ........................................................................................................................ 29

1.11.1 Inclusive of Transmission Line Works ..................................................................... 29

1.11.2 Exclusive of Transmission Line Works .................................................................... 30

1.12 Financial and Economic Aspects ........................................................................................ 30

1.13 Construction Programme .................................................................................................... 30 2. JUSTIFICATION OF THE PROJECT FROM POWER SUPPLY ANGLE .................................. 31

2.1 General ............................................................................................................................... 31

2.2 Energy Consumption in India .............................................................................................. 31

2.3 The Power Scenario of India .............................................................................................. 32

2.4 Resources of Power development in Himachal Pradesh ................................................... 33

2.5 Available Generation capacity in the state.......................................................................... 36

2.6 Development of Hydro Power Potential .............................................................................. 36

2.7 Bharmour Stage-I HEP ....................................................................................................... 39

2.8 Necessity and Justification for Implementing the Project ................................................... 40 3. ECONOMIC SCENE OF HIMACHAL PRADESH ...................................................................... 41

3.1 General ............................................................................................................................... 41

3.2 Geography .......................................................................................................................... 41

3.2.1 Physiography ........................................................................................................... 41

3.2.2 Rivers....................................................................................................................... 41

3.2.3 Climate .................................................................................................................... 42

3.2.4 Forest & Wildlife ...................................................................................................... 42

3.2.5 Population ................................................................................................................ 42

3.3 Sociology ............................................................................................................................ 43



3.3.1 Education ................................................................................................................. 43

3.3.2 Health and Family Welfare ...................................................................................... 43

3.4 Economy ............................................................................................................................. 43

3.4.1 Transportation ......................................................................................................... 43

3.4.2 Industrial Development ............................................................................................ 44

3.4.3 Agriculture ............................................................................................................... 45

3.4.4 Horticulture .............................................................................................................. 45

3.4.5 Irrigation ................................................................................................................... 45

3.4.6 Fisheries & Animal Husbandry ................................................................................ 45

3.4.7 Tourism .................................................................................................................... 46

3.5 Energy ................................................................................................................................. 46

3.5.1 Energy Potential ...................................................................................................... 46

3.5.2 Energy Demand ....................................................................................................... 47

3.5.3 Hydro Power Development ..................................................................................... 47

3.5.4 Transmission and Distribution System .................................................................... 48 4. PROJECT SUMMARY ............................................................................................................... 49

4.1 General ............................................................................................................................... 49

4.2 Salient Features .................................................................................................................. 49 5. SURVEY & INVESTIGATION .................................................................................................... 57

5.1 General ............................................................................................................................... 57

5.2 Topographical Investigations .............................................................................................. 57

5.3 Geotechnical Investigation .................................................................................................. 58

5.3.1 Field Investigations .................................................................................................. 58

5.3.2 Sub-surface Exploration .......................................................................................... 58

5.3.3 Construction Materials ............................................................................................. 59

5.4 Hydrological Investigations ................................................................................................. 60

5.5 Property Survey .................................................................................................................. 60

5.6 Communication Survey ....................................................................................................... 60 6. HYDROLOGY ............................................................................................................................. 61

6.1 Introduction ......................................................................................................................... 61

6.2 Basin Charectaristics .......................................................................................................... 61

6.3 Budhil Nallah and its Catchment ......................................................................................... 61

6.4 Design Requirement ........................................................................................................... 63

6.5 Water Available Studies ...................................................................................................... 63

6.5.1 Data Availability ....................................................................................................... 63

6.5.2 Climate .................................................................................................................... 64

6.5.3 Precipitation ............................................................................................................. 65

6.5.4 Discharge Data of Budhil River ............................................................................... 66

6.5.5 Statistical Charectaristics of Two Sets of Discharge Data at Budhil Nallah ............ 67

6.5.6 Development of Water Availability Series (Yield Series) ......................................... 67

6.5.7 Dependable Flows ................................................................................................... 68

6.5.8 Flow Duration Curve ................................................................................................ 71

6.6 Design Flood ....................................................................................................................... 72

6.6.1 Empirical Method ..................................................................................................... 72

6.6.2 Flood Frequency Analysis ....................................................................................... 73



6.6.3 Hydro Meteorological Approach .............................................................................. 75

6.6.4 Recommendations ................................................................................................... 79

6.7 Sediment Load .................................................................................................................... 80

6.8 Conclusion and Recommendations .................................................................................... 80 7. GEOLOGY .................................................................................................................................. 91

7.1 Introduction ......................................................................................................................... 91

7.2 Regional Geology ............................................................................................................... 91

7.3 Tectonics ............................................................................................................................. 92

7.4 Seismo-Tectonics and Seismicity ....................................................................................... 92

7.5 Discontinuity ........................................................................................................................ 93

7.6 Geology of Project Area ...................................................................................................... 94

7.6.1 Barrage Site ............................................................................................................. 95

7.6.2 Intake & Desilting Chamber ..................................................................................... 98

7.6.3 Water Conductor System ........................................................................................ 98

7.6.4 Power House ........................................................................................................... 98

7.7 Sub-Surface Exploration ................................................................................................... 100

7.7.1 Drilling .................................................................................................................... 100

7.7.2 Exploratory Pits ..................................................................................................... 101

7.8 Field and Laboratory Tests ............................................................................................... 101

7.8.1 Field Tests ............................................................................................................. 101

7.8.2 Laboratory Tests .................................................................................................... 101

7.9 Geotechnical Assessment ................................................................................................ 101

7.9.1 Head Works ........................................................................................................... 101

7.9.2 Head Race Tunnel ................................................................................................. 102

7.9.3 Surge Shaft ............................................................................................................ 103

7.9.4 Presure Shaft ......................................................................................................... 103

7.9.5 Power House ......................................................................................................... 103

7.10 Construction Material ........................................................................................................ 103 8. POWER POTENTIAL STUDIES .............................................................................................. 111

8.1 General ............................................................................................................................. 111

8.2 Methodology ..................................................................................................................... 111

8.3 Water Availability .............................................................................................................. 112

8.4 Head Available for Power Generation .............................................................................. 114

8.5 Computation of Unrestricted Energy ................................................................................. 114

8.6 Optimisation of Installed Capacity .................................................................................... 116

8.7 Design Energy of the Project ............................................................................................ 120

8.8 Number of Units to be installed ......................................................................................... 120

8.9 Conclusions ...................................................................................................................... 121 9. DESIGN OF CIVIL STRUCTURES .......................................................................................... 133

9.1 General ............................................................................................................................. 133

9.2 Head Works ...................................................................................................................... 133

9.2.1 Barrage .................................................................................................................. 134 9.2.1.1 Intake Structure ..................................................................................................... 135 9.2.1.2 Feeder Channel .................................................................................................... 135 9.2.1.3 Desilting Basin and Collection Pool ...................................................................... 136

9.3 Water Conductor System .................................................................................................. 136



9.3.1 Inlet Portal ............................................................................................................. 136

9.3.2 Adits ....................................................................................................................... 137

9.3.3 Head Race Tunnel (HRT) ...................................................................................... 137

9.3.4 Surge Shaft ............................................................................................................ 138 9.3.4.1 General .................................................................................................................. 138 9.3.4.2 Hydraulic Design of Surge Shaft ........................................................................... 138

9.3.5 Surge Shaft Gate ................................................................................................... 140

9.3.6 Pressure Shaft ....................................................................................................... 140 9.3.6.1 General .................................................................................................................. 140 9.3.6.2 Economical Diameter ............................................................................................ 141 9.3.6.3 Pressure Shaft Liner .............................................................................................. 141

9.4 Power House Complex ..................................................................................................... 141

9.4.1 General .................................................................................................................. 141

9.4.2 Power House ......................................................................................................... 142

9.4.3 Service bay ............................................................................................................ 142

9.4.4 Machine bay .......................................................................................................... 142

9.4.5 Draft Tube .............................................................................................................. 142

9.5 Tail Race Channel ............................................................................................................ 142

9.6 Intake Pool for Bharmour-II HEP ...................................................................................... 143 10. POWER PLANT - ELECTRICAL & MECHANICAL WORKS ................................................... 157

10.1 Introduction ....................................................................................................................... 157

10.2 Mechanical Equipment ...................................................................................................... 158

10.2.1 Introduction ............................................................................................................ 158

10.2.2 Power Station Characteristics ............................................................................... 158 10.2.2.1 Water Levels ........................................................................................................ 158 10.2.2.2 Gross Heads ........................................................................................................ 158 10.2.2.3 Head Losses ........................................................................................................ 159 10.2.2.4 Net Heads ............................................................................................................. 159 10.2.2.5 Turbine Layout and Design .................................................................................. 159

10.2.3 Turbine Governors ................................................................................................. 162 10.2.3.1 General ................................................................................................................. 162 10.2.3.2 Performance Data ................................................................................................ 163 10.2.3.3 Standards and Regulations .................................................................................. 163 10.2.3.4 Design Conditions ................................................................................................ 164

10.2.4 Butterfly Valves ...................................................................................................... 164

10.2.5 Draft Tube Gates ................................................................................................... 165

10.2.6 Cooling Water System ........................................................................................... 165

10.2.7 Station Drainage & Dewatering System ................................................................ 165 10.2.7.1 Station Drainage System ...................................................................................... 165 10.2.7.2 Unit Dewatering System ....................................................................................... 166

10.2.8 Main Lifting Equipment .......................................................................................... 166

10.2.9 Powerhouse Heating Ventilation & Air Conditioning Systems .............................. 167

10.2.10 Fire Fighting System .............................................................................................. 167

10.2.11 Oil Purification Systems......................................................................................... 167 10.2.11.1 General ............................................................................................................... 167 10.2.11.2 Lubricating Oil purifying system ......................................................................... 168 10.2.11.3 Insulating Oil Purifiers ........................................................................................ 168

10.2.12 Workshop Equipments .......................................................................................... 169

10.3 Electrical Equipment ......................................................................................................... 169



10.3.1 Main Single Line Diagram ..................................................................................... 169

10.3.2 Generator .............................................................................................................. 170

10.3.3 Excitation Transformer .......................................................................................... 172

10.3.4 The excitation cubicle ............................................................................................ 172

10.3.5 11 KV Main Switchgear ......................................................................................... 172 10.3.5.1 11 kV (UE) XLPE Aluminium Cable ..................................................................... 173 10.3.5.2 11 kV XLPE Cable & LAVT Panel ........................................................................ 173

10.3.6 Step-up Transformer ............................................................................................. 173

10.3.7 Grounding System ................................................................................................. 175

10.3.8 Control, SCADA, Instrumentation & Monitoring .................................................... 175 10.3.8.1 Unit Control Board (UCB) ..................................................................................... 176 10.3.8.2 Temperature & Gauge Panel ............................................................................... 176 10.3.8.3 SCADA ................................................................................................................. 176 10.3.8.4 Philosophy of Tandom Operation of Hydro Power Plants .................................... 176

10.3.9 Electrical Protection ............................................................................................... 177

10.3.10 Relaying and Metering ........................................................................................... 178

10.3.11 Auxiliary Electrical Services .................................................................................. 179

10.3.12 415 V Station Service Boards ............................................................................... 180

10.3.13 Power Supply during Construction ........................................................................ 180

10.3.14 Telephone System ................................................................................................. 180

10.3.15 Lighting .................................................................................................................. 180

10.3.16 Cables and Raceway System ............................................................................... 181 10.3.16.1 Basic Requirements for Cables .......................................................................... 181 10.3.16.2 Low Voltage Power Cables, Control Cables & Instrumentation Cables ............ 181 10.3.16.3 Cable Trays ........................................................................................................ 181

10.3.17 DC and UPS Systems ........................................................................................... 181 10.3.17.1 Field Flashing, Communication, System Design Criteria ................................... 182 10.3.17.2 220 V DC Battery Bank ...................................................................................... 182 10.3.17.3 Battery Chargers ................................................................................................ 182 10.3.17.4 220 V DC Switching and Metering Panel (SMP) & DCDB ................................. 183 10.3.17.5 Uninterruptible AC System (UPS) ...................................................................... 183

10.3.18 132 kV Switchyard Equipment .............................................................................. 183 10.3.18.1 132kV SF6 Circuit Breaker: ................................................................................ 184 10.3.18.2 132 kV Disconnector Switch With /Without Earth Switch ................................... 184

10.3.19 132 kV Current Transformers ................................................................................ 185

10.3.20 132 kV Potential Transformer (PT) ........................................................................ 185

10.3.21 120 KV Lightning Arrester: .................................................................................... 186

10.3.22 Electrical Workshop Equipment ............................................................................ 186

10.3.23 Layout Drawings .................................................................................................... 187

10.3.24 Establishment ........................................................................................................ 187 11. POWER EVACUATION ............................................................................................................ 188

11.1 Introduction ....................................................................................................................... 188

11.2 Load Demand ................................................................................................................... 188

11.3 Existing & Proposed Transmission System in Project Vicinity ......................................... 188

11.4 Identification of Transmission System .............................................................................. 189

11.5 Power Evacuation from Bharmour-I HEP ......................................................................... 190

11.6 Status of Open Access/connectivity ................................................................................. 190 12. CONSTRUCTION METHODOLOGY AND SCHEDULE .......................................................... 196

12.1 Basic Assessment Of Construction Methodology ............................................................. 197



12.2 Pre Construction Activities ................................................................................................ 197

12.3 Approach Roads ............................................................................................................... 197

12.4 Basic Considerations ........................................................................................................ 197

12.5 Detailed Design And Construction Drawings .................................................................... 198

12.6 Basic Assumptions for Equipment Planning ..................................................................... 198

12.6.1 Working hours of equipment ................................................................................. 198

12.6.2 Densities of Materials ............................................................................................ 198

12.6.3 Earth Volume conversion factor ............................................................................ 198

12.6.4 Operating Efficiency .............................................................................................. 199

12.6.5 Muck Dumping Lead .............................................................................................. 199

12.7 Construction Power ........................................................................................................... 199

12.8 Methodology Of Construction For Various civil work Activities ......................................... 199

12.8.1 River diversion during construction ....................................................................... 199

12.8.2 Cofferdam works ................................................................................................... 200

12.8.3 Phase-I - Headworks ............................................................................................. 200

12.8.4 Phase-II - Headworks ............................................................................................ 200

12.8.5 Feeder Channel, Desilting Basin and Collection Pool ........................................... 201

12.8.6 Headrace tunnel .................................................................................................... 201

12.8.7 Surge shaft ............................................................................................................ 204

12.8.8 Pressure Shaft ....................................................................................................... 205 12.8.8.1 Vertical Pressure Shaft ......................................................................................... 206

12.8.9 Powerhouse ........................................................................................................... 206

12.8.10 Tailrace .................................................................................................................. 207

12.8.11 Switchyard ............................................................................................................. 207

12.8.12 Hydro Mechanical Equipment ............................................................................... 207

12.9 Construction Schedule ...................................................................................................... 208

12.9.1 General .................................................................................................................. 208

12.9.2 Construction Adits ................................................................................................. 208

12.9.3 River Diversion during Construction ...................................................................... 209

12.9.4 Phase-I - Headworks ............................................................................................. 209

12.9.5 Phase-II - Headworks ............................................................................................ 209

12.9.6 Feeder Channel, Desilting Basin and Collection Pool ........................................... 210

12.9.7 Headrace Tunnel ................................................................................................... 210

12.9.8 Surge Shaft ............................................................................................................ 210

12.9.9 Presure Shaft ......................................................................................................... 210

12.9.10 Powerhouse complex and Tail Race Channel ...................................................... 211

12.9.11 Hydro Mechanical Works....................................................................................... 211 12.9.11.1 Gates for various components ........................................................................... 211

12.9.12 E&M Works ............................................................................................................ 211 13. PROJECT ORGANIZATION .................................................................................................... 223

13.1 General ............................................................................................................................. 223

13.2 Project Organisation ......................................................................................................... 223

13.2.1 Organization for Creation of Infrastructure Facilities ............................................. 224

13.2.2 Organization for Peak Construction Period ........................................................... 224

13.3 Functions And Responsibilities Of Project Team Members ............................................. 225



13.3.1 Senior Manager (Civil) ........................................................................................... 225

13.3.2 Senior Manager (Quality control) .......................................................................... 226

13.3.3 Senior Manager (Electrical and Mechanical Works) ............................................. 226

13.4 Need Based Units ............................................................................................................. 227

13.5 Project Planning And Monitoring ...................................................................................... 227

13.6 Finance & Accounts .......................................................................................................... 227

13.7 Project Administration ....................................................................................................... 227

13.8 Technical Advisory Committee ......................................................................................... 228

13.9 Consultants ....................................................................................................................... 228

13.10 Reporting / Reviews .......................................................................................................... 228 14. INFRASTRUCTURAL FACILITIES .......................................................................................... 230

14.1 General ............................................................................................................................. 230

14.2 Access Roads ................................................................................................................... 230

14.3 Project Roads ................................................................................................................... 230


14.4.1 Construction Power Requirement ......................................................................... 231

14.4.2 Power Supply Facilities ......................................................................................... 231

14.5 Telecommunication Facilities ............................................................................................ 231

14.6 Project Colonies/Buildings ................................................................................................ 231 15. ENVIRONMENT & ECOLOGICAL ASPECTS ......................................................................... 233

15.1 Environmental Base Line Data ......................................................................................... 233

15.1.1 General .................................................................................................................. 233

15.1.2 Physiography ......................................................................................................... 233

15.1.3 Geology ................................................................................................................. 233

15.1.4 Soil ......................................................................................................................... 234

15.1.5 Climate .................................................................................................................. 234

15.1.6 Water Resources and Water Quality ..................................................................... 234

15.1.7 Hydrometeorology of the Catchment ..................................................................... 235

15.1.8 Vegetation ............................................................................................................. 235

15.1.9 Fauna .................................................................................................................... 237

15.1.10 Human Population ................................................................................................. 238

15.1.11 Public Health ......................................................................................................... 238

15.1.12 Seismicity .............................................................................................................. 238

15.1.13 Land Use ............................................................................................................... 239

15.2 Infrastructure Facilities ...................................................................................................... 240

15.2.1 Roads .................................................................................................................... 240

15.2.2 Residential Facilities .............................................................................................. 240

15.2.3 Telecommunication ............................................................................................... 240

15.2.4 Power Source & Transmission .............................................................................. 241

15.3 Quality of Life Style ........................................................................................................... 241

15.3.1 Socio-Economic Values......................................................................................... 241

15.3.2 Development of Tourism and Agriculture .............................................................. 241

15.4 Assessment of Negative Impacts ..................................................................................... 242

15.4.1 Impacts Due to Project Location ........................................................................... 242 15.4.1.1 Rehabilitation and Resettlement .......................................................................... 242 15.4.1.2 Loss of Land ......................................................................................................... 242



15.4.1.3 Forest Land and Loss of Forest Produce ............................................................. 242 15.4.1.4 Encroachment into Nature Reserves and Wildlife ............................................... 242 15.4.1.5 Loss of Historical and Cultural Monuments .......................................................... 243 15.4.1.6 Risks Due to Earthquakes .................................................................................... 243

15.4.2 Impacts Due to Project Design .............................................................................. 243 15.4.2.1 Impacts Due to Project Location .......................................................................... 243 15.4.2.2 Impacts Due to Construction Works ..................................................................... 243 15.4.2.3 Cultural Hazards ................................................................................................... 244 15.4.2.4 Impacts Due to Project Operation ........................................................................ 244 15.4.2.5 Erosion and Sandation Risks ............................................................................... 244 15.4.2.6 Change in Water Quality and Risk of Eutrophication ........................................... 245 15.4.2.7 Increase Incidence of Water Related Deceases .................................................. 245 15.4.2.8 Impact on Fish ...................................................................................................... 245 15.4.2.9 Public Health Facilities ......................................................................................... 245

15.5 Assessment of Positive Impacts ....................................................................................... 246

15.5.1 Higher Power Generation ...................................................................................... 246

15.5.2 Employment opportunities ..................................................................................... 246

15.5.3 Recreation and tourism potential ........................................................................... 247

15.5.4 Less fuel consumption ........................................................................................... 247

15.5.5 Less Air Pollution ................................................................................................... 247

15.5.6 Benefits to Economy .............................................................................................. 247

15.6 Checklist of Impacts .......................................................................................................... 248

15.7 Environment Management Plan ....................................................................................... 249

15.7.1 Mitigation Measures .............................................................................................. 250

15.7.2 Disaster Management ........................................................................................... 256

15.7.3 Emergency Measures ............................................................................................ 258

15.7.4 Soil Erosion Control ............................................................................................... 259

15.7.5 Cost For Implementing Environmental Management Plan .................................... 259

15.8 Environmental Monitoring Plan ......................................................................................... 260

15.8.1 Water & Waste Water Quality ............................................................................... 260

15.8.2 Air Quality ............................................................................................................. 261

15.8.3 Noise...................................................................................................................... 262

15.8.4 Minimum Environmental Flow ............................................................................... 262

15.9 Conclusion ........................................................................................................................ 263 16. RATE ANALYSIS ..................................................................................................................... 271

16.1 General ............................................................................................................................. 271

16.2 Methodology ..................................................................................................................... 271 17. COST ESTIMATES .................................................................................................................. 344

17.1 General ............................................................................................................................. 344

17.2 Basis Of The Cost Estimate .............................................................................................. 344

17.3 Description of Item ............................................................................................................ 345

17.3.1 Civil works ............................................................................................................. 345 18. FINANCIAL & ECONOMIC EVALUATION ............................................................................... 430

18.1 General ............................................................................................................................. 430

18.2 Assumptions ..................................................................................................................... 430

18.2.1 Combined Project Cost.......................................................................................... 431

18.2.2 Capital Structure (Rs. in Crores) ........................................................................... 431

18.2.3 Debt Financing Terms ........................................................................................... 431



18.2.4 Plant Details .......................................................................................................... 431

18.2.5 Saleable Energy Details for Both Projects ............................................................ 431

18.2.6 Return of Equity ..................................................................................................... 432

18.2.7 O & M..................................................................................................................... 432

18.2.8 Taxes ..................................................................................................................... 432

18.2.9 Working Capital ..................................................................................................... 432

18.2.10 Depreciation .......................................................................................................... 432

18.2.11 DSCR Summary .................................................................................................... 432

18.2.12 Tariff (Calculated as per CERC Norms) ................................................................ 432

18.3 Conclusion ........................................................................................................................ 432 19. RECOMMENDATIONS ............................................................................................................ 453

19.1 General ............................................................................................................................. 453

19.2 Preliminary And Pre-Construction Works ......................................................................... 453

19.3 Civil And Hydro Mechanical Works ................................................................................... 453

19.4 Electro-Mechanical Works ................................................................................................ 454


19.6 Benefits ............................................................................................................................. 454

19.7 Project Cost ...................................................................................................................... 454

19.8 Recommendation .............................................................................................................. 454

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) List of Annexures


LIST OF ANNEXURES Annexure-6.1: Observed 10-Daily Average discharges of Budhil Nallah near Thalla G&D site (1972-73 to

2001-02 & 2007-08 to 2010-11)

Annexure-6.2: 10-daily observed discharge data of Ravi River at Bajoli Holi HEP

Annexure-6.3: Annual Rainfall Recorded at Twelve Raingauge Stations in Chamba District

Annexure-6.4: Observed 10-Daily Average Runoff Data of Budhil Nallah near Thalla G&D site (1972-73 to 2001-02 & 2007-08 to 2010-11)

Annexure-6.5: Observed & Correlated 10-Daily Average Discharge Data of Budhil Nala near Thalla G&D Site

Annexure-6.6: Observed & Correlated 10-Daily Average Discharge Data at Bharmour Stage-I HEP Diversion Site

Annexure-7.1: Geotechnical Log of Drill Hole

Annexure-8.1: 10-Daily flow series at Proposed Diversion Site (from 1972-73 to 2010-11)

Annexure-8.2: 10-daily flow series available at BHEP-I Intake for the Power Generation after Environmental release

Annexure-8.3: Head Loss Summary for Different Discharges

Annexure-8.4: Head Loss Calculation of the Project

Annexure-8.5: Comparison of Energy Generation

Annexure-8.6: Energy Generation for the 50% Dependable Year 1983 – 84

Annexure-8.7: Energy Generation for the 75% Dependable Year 2006 - 07

Annexure-8.8: Energy Generation for the 90% Dependable Year 1994 – 95

Annexure-8.9: Computation of Annual Energy for Different Installed Capacities (75% Dependable Year – 2006 - 07)

Annexure-9.1: Discharging capacity of Barrage

Annexure-9.2: Hydraulic Calculations of Trash Rack at Intake

Annexure-9.3: Hydraulic design of Desilting Basin

Annexure-9.4: Hydraulic Calculations of Collection Pool after Desilting Basin

Annexure-9.5: Hydraulic Design Calculation of Surge Tank

Annexure-9.6: Stability Analysis of Barrage

Annexure-11.1: Annual Report (2012-13) – Northen Regional Load Dispatch Center, Delhi

Annexure-11.2: Power Supply Position in Northen Region

Annexure-11.3: Master Plan of Evacuation System for Projects in Ravi Basin

Annexure-11.4: Ring Main Scheme for Power Evacuation from Harsar to Bharmour Projects

Annexure-16.1: Rate Analysis

Annexure-17.1: Cost Estimate

Annexure-18.1: Financial Statement for Combined Projects (BHEP-I & BHEP-II)

Annexure-18.2: Assumptions for Tariff Calculations

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) List of Tables


LIST OF TABLES

Table-1.1: Projects on the Budhil River

Table-1.2: 10-daily observed discharge data of Ravi River at Bajoli Holi HEP

Table-2.1: Power Supply Scenario in Himachal Pradesh

Table-2.2: List of Projects for Which MOUs Have Been Signed With Private Entrepreneurs

Table-2.3: List of Projects for Which MOUs Have Been Signed with Private Entrepreneurs – ICB route

Table- 6.1: Discharge data availability

Table- 6.2: Mean Daily Maximum/minimum Temperature at Chamba

Table- 6.3: Statistical Characteristics of Budhil nallah Discharge Data

Table- 6.4: Comparative Study of Statistical Characteristics ofTwo sets of Discharge Data

Table- 6.5: Calculation of Annual Dependability (1972-73 to 2010-11)

Table-6.6: 50%, 75% and 90% Dependable flow series at diversion site

Table-6.7: Diversion Flood for Different Return Periods

Table-6.8: Parameters of Synthetic Unit Hydrograph

Table-6.9: Ordinates of Synthetic Unit Hydrograph

Table-6.10: 4-hrs Temporal Distribution of Storm

Table-6.11: Rainfall Excess Block

Table-6.12: Estimation of Flood Peak

Table-6.13: Standard Project Flood at Bharmour Stage-I HEP Diversion Site

Table-7.1: Stratigraphic Succession in the Project Area

Table-7.2: Discontinuity Sets and their Engineering Properties at Barrage site and WCS area

Table.7.3: Discontinuity Sets and their Engineering Properties in Powerhouse area

Table-7.4 Summary of Drill Holes

Table-7.5 Design Support System for Head Race Tunnel and Adit

Table-7.6: Physical Tests Proposed to be carried out for Coarse and Fine Aggregates and the Relevant BIS Codes

Table-8.1: 50%, 75% and 90% Dependable flow series at diversion site of BHEP-I

Table-8.2: Project features considered for Net Head Calculation

Table-8.3: Project features considered for Power Potential Studies

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) List of Tables


Table-8.4: Un-restricted Energy Corresponding to Hydrological Years

Table-8.5: Summary of Power potential studies for 75% dependable year flow series

Table-8.6: Summary of Saleable Energies in 75% Dependable Year for

Various Installed Capacities

Table-9.1: Rock Support Requirements along HRT

Table 9.2: Adopted hydraulic conditions and resulting surge levels

Table-10.1: Step-up Transformer Main Electrical Characteristics

Table-10.2: Location Illumination Level

Table-10.3: Electrical characteristics





Table-15.1: Species Found in the District

Table-15.2: Common Terrestrial Fauna of the Area

Table-15.3: Birds of the Area

Table-15.4: Land Use Pattern of Himachal Pradesh State

Table-15.5: Land Use/Land Cover in the Catchment

Table-15.6: Muck Production by Excavation

Table-15.7: Checklist for Impacts Due To the Proposed Project

Table–15.8: Short Term and Long Term Impacts

Table–15.9: Recommended Tree Species for Reafforestation

Table-15.10: Capacity of Septic Tank for Individual Dwellings

Table–15.11: Illumination at Different Locations

Table–15.12: Cost of Implementing Environmental Management Plan

Table–15.13: Cost Estimates for Environmental Monitoring Programme

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) List of Figures


LIST OF FIGURES

Figure-2.1: Map of Himachal Pradesh and its Rivers

Figure-2.2: Map of River Systems

Figure- 6.1: Location Map of the Project

Figure- 6.2: Catchment Area Plan of Budhil Nallah

Figure-6.3: 10-Daily mean discharges pattern of Budhil River (1972-2002) and (2007-2011)

Figure- 6.4: Correlation between Budhil & Ravi River

Figure-6.5: Flow Duration Curve for Proposed Diversion Site

Figure-6.6: Synthetic Unit Hydrograph

Figure-6.7: 50- Year Return Period Flood

Figure-7.1: Stereoplot of Major Joint Sets in the Project Area

Figure-7.2: Stereoplot of Major Joint Sets at the Barrage Site

Figure-7.3: Stereoplot of Major Joint Sets at the Powerhouse Site

Figure-8.1: Variation of Incremental Annual Energy with Installed Capacity

Figure-8.2: Variation of Incremental Annual Saleable Energy with Installed Capacity

Figure-8.3: Variation of Annual Energy with the Number of Units

Figure 9.1: Mass Oscillation due to Full Load Rejection, with the Full Supply Level at 1835.0 m

Figure 9.2: Mass Oscillation due to Full Load Acceptance, MDDL at 1830.20 m

Figure-12.1: Excavation Faces of Head Race Tunnel

Figure-13.1: Project Organisation

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) List of Photos


LIST OF PHOTOS

Photo-7.1: Isoclinal Fold Seen in Road cut on Left Bank of Budhil River

Photo-7.2: Barrage Site Downstream View

Photo-7.3: Low Rocky Ridge on Right Bank of River Budhil around Which it takes a Sharp Turn

Photo-7.4: Sub-rounded Boulders in River Borne Material

Photo-7.5: Minor Gully on Left Bank of Budhil View from Confluenceof Chobia Nallah

Photo-7.6: General view of powerhouse site from road on right bank of Budhil

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) Bibliography of Abbreviations


BIBLIOGRAPHY OF ABBREVIATIONS

AC - Alternate Current

ACF - Altitude Correction Factor

Amp - Ampere

BHEP-I - Bharmour Hydro Electric Project Stage-I

BHEP-II - Bharmour Hydro Electric Project Stage-II

B/C Ratio - Benefit to Cost Ratio

BFV - Butterfly Valve

BH - Bore Hole

BIS - Bureau of Indian Standards

BHPPL - Bharmour Hydro Projects Pvt. Ltd

BOOT - Build-Own-Operate-Transfer

CA - Catchment Area

CAT - Catchment Area Treatment

CDM - Clean Development Mechanism

CEA - Central Electricity Authority

CERC - Central Electricity Regulatory Commission

C/L - Centre line

Cumecs - Cubic metre per second

m3 - Cubic metre

Cusecs - Cubic Feet Per Second

CTU - Central Transmission Utility

CWC - Central Water Commission

S/C - Single Circuit

d/s - Downstream

DCS - Distributed Control System

DG - Diesel Generator

Dia - Diameter

DOE - Directorate of Energy

DPR - Detailed Project Report

EIA - Environment Impact Assessment

El. - Elevation



E&M - Electro Mechanical

EOT - Electric Overhead Travelling

ERT - Electrical Resistivity Tomography

F&A - Finance and Accounts

FDC - Flow Duration Curve

FRL - Full Reservoir Level

FSL - Full Supply Level

ft - Feet

G&D - Gauge & Discharge

GHG - Green-house Gas

GIS - Geographical Information System

GIS - Gas-Insulated Switchgear

GIB - Gas-Insulated Bus

GoHP - Government of Himachal Pradesh

GoI - Government of India

GPS - Global Positioning System

GSI - Geological Survey of India

GTS - Great Trigonometrical Survey

GWh - Giga Watt Hours

Ha-m - Hectare metre

HEP - Hydro Electric Project

H&M - Hydro-Mechanical

HFL - Highest Flood Level

HPPCL - Himachal Pradesh Power Corporation Ltd.

HPPTCL - Himachal Pradesh Power Transmission Corporation Ltd.

HPSEB - Himachal Pradesh State Electricity Board

HP - Horse power

HT - High Tension

Hz - Hertz

ICB - International Competitive Bidding

ICCS - Indo Canadian Consultancy Services limited

ID - Internal Diameter

IDC - Interest During Construction

IMD - Indian Meteorological Department



IS - Indian Standard

km - Kilometre

kWh - Kilowatt hour

kV - kilo volt

LAVT - Lightning Arrestor and Voltage Transformers

LT - Low Tension

m - Metre

MCM - Million Cubic Meter

MIV - Main Inlet Valve

kW - Kilowatt

MoEF - Ministry of Environment & Forest

MoU - Memorandum of Understanding

MoWR - Ministry of Water Resource

MU - Million units

MW - Mega Watt

MWL - Maximum Water Level

NH - National Highway

NSL - Natural Surface Level

O&M - Operation & Maintenance

PCC - Plain Cement Concrete

PFR - Pre-Feasibility Report

PGCIL - Power Grid Corporation of India Ltd.

PIA - Pre Implementation Agreement

PLF - Plant Load Factor

PLCC - Power Line Carrier Communication

PPM - Parts Per Million

RBL - River Bed level

RCC - Reinforced Cement concrete

RD - Reduced Distance

RF - Runoff Factor

RL - Reduced Level

RMT - Rock Mass Type

RPM - Revolutions per Minute

RPS - Revolutions per Second



RQD - Rock Quality Designation

R & R - Rehabilitation & Resettlement

SCADA - Supervisory Control and Data Acquisition

SEISAT - Seismo-tectonic Atlas of India & Its Environs

SERC - State Electricity Regulatory Commission

km2 - Square Kilometer

m2 - Square metre

STU - State Transmission Utility

MT - Metric Tons

T - Temperature

TAC - Tariff Advisory Committee

TBM - Temporary Bench Mark

TG - Turbine Generator

T&P - Tools & Plant

TRCM - Trash Rack Cleaning Machine

TRT - Tail Race Tunnel

TWL - Tail Water Level

u/s - Upstream

UAT - Unit Auxillary Transformer

UCB - Unit Control Board

UPS - Uninterrupted Power Supply

V - Volts

VHF - Very High Frequency

WCS - Water Conductor system

WLL - Wireless in Local Loop

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) Check List


CHECK LIST

1 NAME OF THE PROJECT: Bharmour-I HEP (24 MW)

2 LOCATION:

a) State (s) Himachal Pradesh

b) District (s) Chamba

3 CATEGORY OF THE PROJECT

a) Irrigation or Multipurpose Hydro Electric Project

b) Storage or Diversion Diversion

4 PLANNING

a) Has the Master Plan for overall development of the river basin been prepared & stages of basin development discussed briefly?

Yes

b) Have the alternative proposals been studied and their merits and demerits discussed?

Yes

c) Does the scheme fit in the overall development of the river basin and its priority in the overall development of the basin discussed?

Yes

d) Are there any features which are not likely to fit in the overall development of the basin?

No

Have the other departments concerned with the development been informed?

Yes

e) Is the present scheme proposed to be executed in stages? If so, are its various stages of execution and development discussed in the report?

No

f) Are the effects of the scheme on the riparian rights existing upstream and downstream project etc., discussed?

No, no habitation on the river bank between the diversion and the power house tail race. This proposal will not affect any of the existing water supply and irrigation facilities falling in the project area.

5 Are there International/Interstate issue involved? If so, have these issues been identified and present status of agreement indicated specially in respect of;

No

a) Sharing of Water Not applicable

b) Sharing of Cost Not applicable

c) Sharing of Benefits Not applicable



d) Acceptance of the sub-mergence by the up stream stage (s)

Not applicable

e) Compensation of land under submergence Not applicable

f) Settlement of oustees Not applicable

g) Any Other Not applicable

Note If there is no agreement, state the present position against each item above

6 SURVEYS

Have the detailed topographical surveys been carried out for the following items and maps prepared as per prescribed scales?

a) River surveys Yes

b) Reservoir surveys Not Applicable

c) Head-work surveys (dams, dykes, barrages, weirs etc.) and auxiliary components.

Yes

d) Plant site and colonies Yes

e) Water conductor system Yes

f) Major hydraulic structures Yes

g) Power house, switchyard, surge tank, tail race. Yes

h) Penstocks etc. Yes

7 GEOLOGY

i) Have the geological surveys for the following items been carried out and report on geology appended?

Yes

a) Regional geology Yes

b) Head works Yes

c) Power House and appurtenances Yes

d) Intake and regulators Yes

e) Penstock Yes

f) Communication routes Yes

ii)

a)

Has the seismicity of the region been studied and co-efficient of vertical/horizontal acceleration for the various structures discussed?

Yes

b) Has the approval of the standing committee for recommending design of seismic co-efficient for River valley project been obtained?

Not applicable



8 FOUNDATION INVESTIGATION

Have the detailed foundation investigations (including insitu tests and laboratory tests) for the following structures been carried out and detailed report(s) appended?

a) Earth and rockfill dam/barrage/weir etc. Yes

b) Masonry/Concrete dam/Weir etc. Not Applicable

c) Power House, water conductor system etc. Yes

9 MATERIAL SURVEYS

i) Have the surveys and laboratory tests for the following construction materials been carried out and report(s) appended?

a) Sand Under progress

b) Rock and aggregate Under progress

c) Cement Will de done during construction stage

d) Steel Will de done during construction stage

ii) Have the sources for each of the above materials been identified and need indicated?

Yes in respect of a) & b)

iii) Have the proposals for procurement of scarce materials been indicated?

Not Applicable

10 HYDROLOGICAL AND METEOROLOGICAL INVESTIGATIONS

Have the hydrological and Meteorological investigations been carried out and status of data discussed in report?

Yes

11 HYDROLOGY

i) a) Is the Hydrology dealt with in detail in this report? Yes

b) Is an index map and bar chart showing locations of various & hydrometric, climatic & rainfall stations and the data availability at those stations been attached?

Yes

c) Are brief notes about quality, consistency, processing and gap filling of the data included?

Yes

ii) Have hydrological studies been carried out for the following?

a) To establish the availability of water for the benefits envisaged?

Yes

b) To determine design flood for the various structures (spillway, weir, barrage etc.)

Yes



iii) Have the analysis for the water flows/sediment flows & rainfall been discussed?

Yes

iv) Is the criterion adopted for selection of the construction diversion flood discussed?

Yes

12 LAND ACQUISITION AND RESETTLEMENT OF OUSTEES

i)

Have the type & quantum of land proposed to be acquired in the project area, area coming under water conductor system and other works, area required for rehabilitation of the oustees been detailed?

No

ii) Is the basis of provision for land acquisition indicated? Yes

iii) Have the rehabilitation measures, amenities and facilities to be provided to the oustees been discussed specially for the oustees from the upstream state(s)?

Not applicable

13 DESIGN

i) Has the final location of the head works and appurtenances, in preference to the other sites investigated been discussed?

Yes

ii) Has the layout of the project area viz, location of head works, workshop(s), sheds offices, colonies etc. been finalized and discussed?

Yes

iii) Has the layout of the various major components of the head works been discussed in the light of site features, geology and foundation characteristics etc?

Yes

iv) Have the designs been prepared for the following components and appended:

a) Barrage, Weir, Spillway etc. and appurtenances. Yes

b) Energy dissipation arrangements, training walls etc. Yes

c) Opening(s) through Intake, penstocks, other outlets, sluices etc.

Yes

d) Regulators Yes

e) Water Conductor System Yes

f) Power House, Surge Tank, Penstock, Tailrace. Yes

v) Have the assumption made in the design of above components of the project been indicated and basis of assumptions discussed?

Yes

vi)

Have any model studies been carried out for location of barrage/weir, spillway and other appurtenances, checking the design profile of the spillway, energy dissipation arrangements, location of outlets/regulators etc.

No, No model studies considered necessary in the present case.

vii) Has the final alignment of water conductor system been discussed in the light of various alignments

Yes



studied?

viii) Is the water conductor system being discussed in the light of various alignments studied?

Yes

ix) Is the location of the water conductor system fixed after detailed surveys of the final alignments?

Yes

x) Are the regulation arrangements of the off taking channel both near and away from the cross regulators discussed?

Not applicable

xi) Are sufficient escapes including terminal escapes provided on the water conductor system?

Not applicable

xii) Have the basis for adopting water-way for the cross drainage works been discussed?

Not Applicable

xiii) Have any model studies for major hydraulic structures been carried out and if so, are the results discussed and incorporated in the design?

No, No model studies are considered necessary.

14 POWER

Have the following points been discussed?

a) Availability of the power generating capacity in the region from different sources

Yes

b) Total energy available and peaking capacity of the system.

Yes

c) Integrated operation of the system and present status of utilization.

Yes

d) Surpluses and shortfalls in the system. Yes

e) Future plans of power development from different sources in the state/region.

Yes

f) Fitment of the scheme in planning of power development of the state/region.

Yes

g) Energy generated from the project, firm power, seasonal power and total power.

Yes

h) Proposal for transmission connecting to the existing system/grid.

Yes

i)

Cost of generation per kW installed and per kwhr generation as compared to the different hydro-electric projects and different sources in the state/region to justify the power component of the project.

Power component of the project has been justified based on techno-economic grounds considering the cost of generation and the expected rate of sale.

15 CONSTRUCTION PROGRAMME AND PLANT AND MANPOWER PLANNING

i) Are the major components of the project proposed to be done departmentally or through contractor?

Through Contractor

ii) Have the various alternatives for construction programme been studied and proper justification

Yes



furnished for the final programme adopted?

iii) Has the proposed construction programme been prepared and synchronized for timely completion of each of the major components of work?

Yes

16 FOREIGN EXCHANGE

i) Have the details of the plant & machinery, spares, instruments, scarce materials to be imported item wise?

Will be dealt with during Tender Design and Detailed Engineering

ii) Has the phasing of imports and source(s) of imports been discussed item wise?

-Do-

iii) Are the imports to be effected under foreign grants/credits or internal resources of the country?

-Do-

17 FINANCIAL RESOURCES

i) a) Has the concurrence of the finance Department been obtained?

Not Applicable

b) Whether the scheme has already been started? If not, what is the present position regarding its inclusion in the plan?

No

ii) Is the scheme included in the plan? If not, what is the present position regarding its inclusion in the plan?

Yes

iii) Have the year wise requirement of funds been indicated?

Yes

iv) Is the scheme covered under state sector or Central sector?

Private Sector

v) Is the scheme covered under any foreign assistance/aid agreement?

Not Applicable

18 ESTIMATE

i) Is the separate volume of estimate attached as appendix?

No, the cost and rate analysis are included in the Main Volume itself.

ii) Is the year to which the rates adopted in the estimate indicated?

Yes, rates refer to August, 14 level

iii) Have the analysis of rates for various major components of the project been furnished with basis for analysis?

Yes

19 ECOLOGICAL ASPECTS

a)

Is the area likely to have any of the following environmental and ecological problems due to the altered surface water pattern and preventive measures discussed?

i) Excessive sedimentation of the reservoir N.A.



ii) Water logging N.A.

iii) Increase in salinity of the ground water N.A.

iv) Ground water recharge N.A.

v) Health hazard water borne diseases, industrial pollution etc. N.A.

vi) Submergence of important minerals. N.A.

vii) Submergence of monuments N.A.

viii) Fish culture & aquatic life Least affected

ix) Plant life-forests - Do-

x) Life of migratory birds Not Applicable

xi) National parks & sanctuaries Nil

xii) Seismicity due to filling of reservoir Not Applicable

b) Has the concurrence of the environmental appraisal committee been obtained?

Not Applicable

20 COLONIES & BUILDINGS

i) Has the planning of the colony/buildings been done keeping in view the ultimate use for optimum utilization of the investment?

Yes

ii) Are the permanent buildings being constructed required for maintenance of the project only?

Yes

iii)

Can the buildings other than required for maintenance of the project being constructed be put to some other use after the completion of the project by the Department or any other agencies?

Will be considered on the completion of the project.

iv) Have the interested agencies been consulted in planning of the buildings to suit their requirements later on?

Not applicable

v) Have the proposals for disposal of temporary buildings been discussed?

Yes

21 SOIL CONSERVATION

Is the need for soil conservation measures in the catchment of the project discussed?

Yes

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 1-Introduction


1. INTRODUCTION

1.1 THE PROJECT

The Directorate of Energy of Government of Himachal Pradesh (DOE) has allocated the

Bharmour HEP (45 MW) on Built-Own-Operate-Transfer (BOOT) basis. Under the private

participation, Bharmour Stage-I HEP has been allocated by Govt of Himachal Pradesh to M/S

Soffimat SA, France. The Implementation Agreement (IA) was signed between M/S Soffimat SA

and the Govt. of Himachal Pradesh on 23.04.2011 followed by signing of a Tripartite Agreement

on 04.09.2012, wherein the liability and responsibility were transferred to an SPV floated by M/s

Soffimat SA, France namely M/s Bharmour Hydro Projects Pvt. Ltd. (M/s BHPPL) for further

investigation and construction.

M/s BHPPL has submitted a proposal for fragmentation of 45 MW Bharmour Hydro Electric

Project. In this regard, Government of Himachal Pradesh has decided to accord in-principle

approval to implement Bharmour (45 MW) HEP in two stages comprising Bharmour Hydro

Electric Project Stage-I (22.5 MW) & Bharmour Hydro Electric Project Stage-II (22.5 MW) HEPs.

The BHEP-I & BHEP-II are proposed and operated in tandem between El. 1835.50 m and El.

1648.00 m. After completion of the upstream project (i.e. BHEP-I), the discharge from tail pool of

BHEP-I would be conveyed to intake pool of BHEP-II for power generation through head race

tunnel.

Bharmour Stage-I hydro electric project (BHEP-I) has been conceived as run-of-river

development for generation of hydropower on Budhil Nallah a tributary of Ravi River. The project

consists of construction of a barrage across Budhil Nallah near village Bharmour. The water so

diverted shall pass through a Intake with two numbers of trash racks – each 6.0m (wide) x 5.0 m

(high), 2 nos. Dufour type desilting basins having dimensions of 10.0 m (wide) x 11.5 m

(effective depth) x 80 m (long), collection pool, headrace tunnel of size 3.6 m (wide) x 3.6 m

(high), 2485.0 m long, D-Shaped terminating in a 10 m diameter surge shaft from which

emerges a 2.8 m diameter steel pressure shaft having a horizontal length of 8.5 m 90.00 m long

vertical shaft and 24.50 m horizontal length upto the manifold. Three (3) branches would take-off

from the main penstock to feed three (3) nos. horizontal axis Francis machines kept in the

surface powerhouse, of 8.0 MW capacity each to generate 24.0 MW of power. Net head of

93.00 m is utilised to generate 24 MW (3 X 8.0 MW) of power. All the three machines are

arranged in a surface power house located on the right bank of Budhil Nallah. After power

generation, the water from the BHEP-I power house will be discharged into intake pool of for

Bharmour Stage-II HEP located at D/S of BHEP-I tail race channel exit.

1.2 LOCATION AND ACCESS TO PROJECT SITE

BHEP-I is located on Budhil Nallah near Bharmour town. The diversion structure is proposed at

El. 1827 m for an installed capacity of 24 MW. The project components sizing is carried out

corresponding to optimised project capacity of 24 MW. The surface power house is proposed



near village Nangli. Bharmour village is situated at an approximate distance of 95 km northeast

from the district headquarters at Chamba town in Himachal Pradesh. Chamba is well connected

by an all weather road from nearest railhead and airport at Pathankot. The diversion site is

approachable by 95 km long state highway from Chamba to Bharmour and subsequently

through a 2 km long foot track from Sandi village. The trekking route comprises a fairly wide and

steeply rising mule track. The track is aligned on the left bank of the Budhil Nallah.

The surface power house site is proposed near village nangli, District Chamba at Elevation

±1735 m. The Power house is proposed on the right bank of Budhil Nallah.

The project area falls between latitude 32°28'42" N & 32º28'36" N and longitude 76°32'07"N

and 76º35'44" E , in Survey of India’s toposheet no.52 - D/11.

1.3 GENERAL CLIMATIC CONDITIONS, TOPOGRAPHY AND GEOLOGY OF THE REGION

The state (Himachal Pradesh) took its name Himachal from Himalayas. Himachal Pradesh is a

hilly and mountainous state situated between 30°22' and 33°12' north latitude and 75°7' and

79°4' east longitude. Its neighbouring states are Jammu and Kashmir in the north, Punjab in the

west and south west, Haryana and Uttarakhand in the south and Tibet in the east. The territory

of state is mountainous except for a few pockets bordering Punjab and Haryana, which have a

sub mountainous topography. Altitude in different areas ranges from 350 m to 7000 m above

mean sea level. Wide difference in geophysical features accounts for considerable variation in

the climate and rainfall of different sub-regions of the state. Physiographically the state is part of

the Himalayan system.

From south to north it can be topographically divided in to three zones.

The Shivaliks or outer Himalayas.

Inner Himalayas or mid mountains. Alpine zones or the greater Himalayas

1.4 NEED FOR THE PROJECT

India’s installed capacity in the hydropower sector as on 31.03.2013 is about 39491 MW out of

total installed capacity of 223344 MW. Only about 20% of the economically feasible hydropower

potential has been exploited. The economic development in the country in this decade has

resulted in widening of the gap between the demand and the supply of power. The development

of hydropower potential can significantly help to bridge the gap between power demand and

supply. The central and state governments have taken significant initiatives for the development

of power projects in both public as well as private sectors. Special emphasis is being made for

development of hydropower potential of the country to keep a balanced mix of thermal and

hydro power generation.



The Government of India and State of Himachal Pradesh have identified the river Ravi and its

major tributary Budhil as one of the main promising future sources of hydroelectric power.

Government has now initiated development of about 200 MW hydroelectric projects along the

reach of river Budhil. The Bharmour Stage-I Hydroelectric Project (BHEP-I) is envisaged as a

run-of-the-river development on the Budhil Nallah, a tributary of Ravi river at Kharamukh, in

Chamba district of Himachal Pradesh.

There are five major river systems in the State, namely the Satluj, the Beas, the Ravi, the

Chenab and the Yamuna. Apart from the major rivers, the State has many small rivulets which

are perennial in nature and provide ideal condition for developing Hydro electric projects.

1.5 NATURAL RESOURCES OF THE STATE

Himachal Pradesh has a huge potential to generate hydroelectric power. The state has number

of large, medium, mini and micro hydel projects. The Government of Himachal Pradesh began

planned development of the hydropower potential of the state and invited private developers to

invest in the hydropower sector for the economic growth of the state and to decrease the energy

deficit in the country. The details of Hydroelectric Projects, which are proposed on the Budhil

river of Ravi basin are mentioned in the following Table-1.1.

Table-1.1 Projects on the Budhil River

Sr. No. Name of Scheme Installed Capacity

(in MW) 1 Budhil HEP 70

2 Harsar HEP 70

3 Bharmour HEP 45

4 Dhancho HEP 18 TOTAL

203

Say around 200 MW

With a view to harness the available potential of the Budhil River, this project was

conceptualised and allotted for development to BHPPL.

No topographical survey, flow gauging or other investigation studies were available in this

stream prior to the granting of license to BHPPL. The site investigations including collection of

topographical, geotechnical and discharge data of the river were carried out.

1.6 LAND REQUIREMENT

The total land required for the project implementation is about 12.65 hect. It includes 7.85

hectare of forest land and 4.80 hectare of private land.

1.7 POPULATION AFFECTED BY THE PROJECT

The project does not envisage any rehabilitation during implementation of the project.



1.8 SCOPE OF THE PRESENT STUDY

The scope of the present study is to:

Review site conditions and to undertake field investigations including hydrological data collection, topographical survey, geological and geotechnical investigations for site assessment

Selection of suitable site for diversion weir and power house

Hydrological studies

Power potential and power evacuation studies.

Hydraulic and structural design for surface and underground project components

Electro-mechanical works- planning and basic design.

Hydro-mechanical works-planning and basic design.

Construction schedule and Construction Methodology.

Estimation of bill of Quantity, item rate and project cost.

Financial analysis.

1.9 PREPARATION OF DPR

The work for the preparation of Detailed Project Report was done by Indo Canadian

Consultancy Services, India. While carrying out this work, BHPPL provided valuable information

and data related to the project collected from various departments of Government of Himachal

Pradesh. Site surveys and field investigations relating to hydrology, meteorology, topography,

geology, construction materials and environmental base line data were provided for DPR

preparation.

The Detailed Project Report has been prepared based on the guidelines of Government of

Himachal Pradesh and Central Electricity Authority.

The DPR is prepared in Two volumes. Volume I of the report comprises of nineteen Chapters.

Volume II of the report comprises of 34 drawings including details of Civil, Hydro mechanical,

Electro Mechanical and geological aspects.

1.10 PROJECT BENEFITS

The annual design energy from the project has been assessed as 115.36 Gwh in 75%

dependable year at 95% plant capacity availability.

1.11 PROJECT COST

1.11.1 Inclusive of Transmission Line Works

The cost estimate has been prepared at August 2014 price level to arrive at the capital cost of

the civil works including infrastructure facilities, electrical/ mechanical works and hydro-

mechanical works required for BHEP-I. The estimated project cost of generating works (Pre-



Operative Works, Civil, Electro Mechanical & Transmission Line) works out to Rs. 208.75 Crores

(exclusive of fund management expenses, IDC, Escalation, CAT & LADA).

1.11.2 Exclusive of Transmission Line Works


the civil works including infrastructure facilities, Electro Mechanical works and Hydro Mechanical

works required for BHEP-I. The estimated project cost of generating works (pre-operative works,

Civil & Electro Mechanical Works) works out to Rs. 196.00 Crores (exclusive of fund

management expenses, IDC, Escalation, CAT & LADA)

In view of the BHEP-I & BHEP-II shall operate in tandem, therefore, the total project cost for both

the projects including Transmission line and excluding Transmission line have been worked out

as Rs. 421.80 and Rs. 393.64 Crores respectively and the details are given in the beow table:

Description Project Cost WithTransmission

Line (Rs. in Crores)

Project Cost Without Transmission

Line (Rs. In Crores)

Civil Works 208.05 208.05

Electro-Mechanical works 87.53 87.53

Transmission line 23.90 -------

Pre-operative works 27.54 27.54

IDC, Financial Charges & Escalation

58.32 55.16

LADA & CAT 16.46 15.36

Total completion cost of Combined Projects

421.80 393.64

1.12 FINANCIAL AND ECONOMIC ASPECTS

Financial studies are carried out as per CERC guidelines considering interest rate on loan as

12.5%, Return on Equity as 15.5%, Discount Rate as 13.5% p.a. Salvage value at the end of

normal life of the plant has been assumed as 10% and average life of the project has been

taken as 40 years. The combined levelised and first year tariff inclusive of Transmission line cost

works out to Rs. 4.68 per kwh & Rs. 5.13 per kwh respectively. Similarly, the combined levelised

and first year tariff exclusive of Transmission line cost works out to Rs. 4.36 per kwh & Rs. 4.79

per kwh respectively.

The project being run of the river scheme shall be eligible for registration with UNFCCC under

CDM for Carbon Emission Reduction (CERs) benefits. The project envisages selling energy in

Northern Grid of India. Availing of CDM benefits will make this project economically more viable.

1.13 CONSTRUCTION PROGRAMME

The project shall be commissioned in 3 years time excluding 6 months of pre-implementation

stage.

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 2- Justification of the Project


2. JUSTIFICATION OF THE PROJECT FROM POWER SUPPLY ANGLE

2.1 GENERAL

Bharmour Hydroelectric project Stage-I (BHEP-I) is a run-of-the-river development harnessing

waters of Budhil Nallah, one of the tributary of Ravi River in Chamba district of Himachal

Pradesh. The project will feed power in the Northern region which comprises the states of

Uttaranchal, Uttar Pradesh, Rajasthan, Haryana, Punjab, Jammu & Kashmir, Himachal Pradesh,

Delhi and Union Territory of Chandigarh.

The power system in this region is operated in an inter-connected and coordinated manner.

Even after the coordinated operation of existing hydro, nuclear and thermal power stations the

Northern region has been experiencing an acute power shortage during the last few years. It is

obviously not possible to meet the rapidly growing power demands of industrial and agricultural

sector from the existing power stations. Viewed in this context, an early exploitation of the vast

hydro power potential of Himalayas assumes a great significance.

2.2 ENERGY CONSUMPTION IN INDIA

India is one of the countries where the present level of energy consumption, by world standards,

is very low. The estimate of annual energy consumption in India is about 330 Million Tones Oil

Equivalent (MTOE) for the year 2004. Accordingly, the per capita consumption of energy is

about 305 Kilogram Oil Equivalent (KGOE). As compared to this, the energy consumption in

some of the other countries is of the order of over 4050 for Japan, over 4275 for South Korea,

about 1200 for China, about 7850 for USA, about 4670 for OECD countries and the world

average is about 1690.

In so far as electricity consumption is concerned, India has reached a level of about 600-kilowatt

hour (kWh) per head per year. The comparable figures for Japan are about 7,800, for South

Korea about 7,000, for China about 1380, for USA about 13,000, for OECD countries about

8050 and world average are about 2430. Thus, both in terms of per capita energy consumption

and in terms of per capita electricity consumption, India is far behind many countries, and as a

matter of fact, behind even the world average. Therefore, to improve the standards of living of

Indian people and to let them enjoy the benefit of economic development, it is imperative that

both energy consumption and electricity consumption level is enhanced. India is targeting a

growth rate of 9 – 10%, having already reached a level of almost 8%. To sustain the double-

digit growth rate for next 10-15 years, it would be essential that the level of energy availability

and consumption, and electricity consumption in particular, is enhanced substantially.

In the profile of energy sources in India, coal has dominant position. Coal constitutes about 51%

of India’s primary energy resources followed by Oil (36%), Natural Gas (9%), Nuclear (2%) and

Hydro (2%). To address the issue concerning energy consumption, and more particularly, the

need for enhancing the energy supply, India has accorded appropriate priority to both - supply

side management and demand side management. On the supply side management, while it is



essential for India to radically expand the capacities on all the fronts and all the segments of

energy, equally important is the need for efficient consumption of energy for which a number of

initiatives have been put in place.

On the supply side, the mis-match between demand and supply is so large that India can ill-

afford to choose one option in preference to the other. For several years, in fact August be for

next few decades, India would need to exploit all possible options to create reasonably large

capacity base on the energy side. It needs to expand manifold the coal production, extract

through all possible means, the oil and gas reserves, wherever possible, resort to import of coal,

acquire coal and gas reserves abroad, will need to continue substantial dependence on import

of oil, and exploit fully the large hydro electric potential which is of the order of over 1,50,000

MW. Only about 39,500 MW i.e. about 23% of the hydroelectric potential has been exploited so

far. Increase in the capacity base of power generation through dependence on the coal

reserves of the country, which are of the order of 200 billion tones is inevitable. Nuclear

programme has proved to be effective and successful. After initial teething problems in mid

eighties, from early nineties, the nuclear power plants have demonstrated to be utilized at

substantially high level of availability and efficiency and this is one of the important options that

India is pursuing. Gratifyingly, a number of companies in India have discovered huge gas

reserves, both on the Western, and more particularly, toward the Eastern coast. Besides, a

number of LNG terminals have also been developed and are being developed so that the use of

gas could be supplemented through import of Liquefied Natural Gas. India is one of the very

few countries which has been successful in employing wind turbine technology and today of the

total capacity of 2,235,344 MW in the country about 12% is constituted by the various non-

conventional sources of generation, wind being the largest contributor.

2.3 THE POWER SCENARIO OF INDIA

The All India aggregate installed capacity of electric power generating stations under various

utilities as on 31.03.2013 was 223344 MW comprising 39491 MW of hydro, 151530 MW of

thermal, 4780 MW of nuclear and 27542 MW Renewable Energy Sources (RES). The

percentage share of hydro, thermal, nuclear and RES stood at 18 %, 68 %, 2% and 12%.

Non Conventional Energy Sources

Indian Government has accorded very high priority to develop and expand installed capacity

base through non-conventional sources of electricity generation. There is a separate Ministry in

the Government of India to exclusively focus on this important area of power generation.

National Electricity Policy notified in 2005 in pursuance of the Electricity Act, 2003, prescribes

that State Electricity Regulatory Commissions should prescribe a proportion of power which

should be produced and supplied to the grid through the non-conventional sources. Some of the

Regulatory Commissions have come out with specific policy guidelines with a different approach

on tariff for these plants in order to encourage these technologies and plants. National

Electricity Tariff Policy mandates that State Commissions should fix such minimum percentage

latest by April, 2006. India has very high potential for these capacities:



It August be seen from the above that India has achieved substantial success on wind turbine

based power generation. Ministry of Non-conventional Energy Sources (MNES) has set a target

of achieving at least 10,000 MW capacity through various non-conventional sources, by the year

2012.

2.4 RESOURCES OF POWER DEVELOPMENT IN HIMACHAL PRADESH

Electric energy has a vital and significant role to play in the economy of any state. Availability of

Power has been recognized as the surest index of a country’s overall economic growth as it is

one of the basic inputs for industrial as well as agricultural development. The coal is not

available in the state of Himachal Pradesh. Due to logistic problems and high cost for

transportation of coal, the development of coal based plant in the region is techno economically

not viable. However, the state has large potential for small as well as big hydropower schemes.

There are five major river systems in the State, namely the Satluj, the Beas, the Ravi, the

Chenab and the Yamuna. Apart from the major rivers, the State has many small rivulets which

are perennial in nature and provide ideal condition for developing Hydro electric projects.

Satluj River: Satluj rises from beyond Indian borders in the Southern slopes of the Kailash

Mountain near Mansarover Lake from Rakas lake, as Longcchen Khabab river (in Tibet). It has

total length of 1448 Km and is the largest among the five rivers of Himachal Pradesh. It enters

Himachal at Shipki (altitude = 6,608 metres) and flows in the South-Westerly direction through

Kinnaur, Shimla, Kullu, Solan, Mandi and Bilaspur districts. Its course in Himachal Pradesh is

320 Km. from Shipki, with famous tributaries viz. the Spiti, the Ropa, the Taiti, the Kashang, the

Mulgaon, the Yula, the Wanger, the Sorang and the Rupi as right bank tributaries, whereas the

Tidong, the Gayathing, the Baspa, the Duling and the Soldang are left bank tributaries. It leaves

Himachal Pradesh to enter the plains of Punjab at Bhakhra, where the world's highest gravity

dam has been constructed on this river. Its total catchment area in Himachal Pradesh is 20,000

km2. Its vedic name is Satudri and Sanskrit name Shatadru. The Satluj finally drains into the

Indus in Pakistan. The catchment area of about 50,140 km2 is located above the permanent

snow-line at an altitude of 4,500 metres. The upper tracts of the Satluj valley are under a

permanent snow cover. The prominent human settlements that have come on the banks of the

Satluj river are Namgia, Kalpa, Rampur, Tattapani, Suni and Bilaspur.

Potential (MW) Existing capacity (MW)

Wind 45,000 4,400

Small Hydro (upto 25 MW) 15,000 1,700

Solar (PV) 20 MW/Km2 Very little

Biogas plants 12 million 3.8 million

Urban/Industrial waste based plant 2,700 Very little



Figure-2.1: Map of Himachal Pradesh and its Rivers

Beas River: The River emerges from a cavern at the Rohtang pass and assume different

identities as the seasons go by. From a clear blue easy flowing mountain river to an awesome

torrent during the monsoon. On the right of Rohtang pass lies the source of the river Beas also

known as Beas Rishi. To the South of this source lies another source known as Beas Kund.

Both these mountain streams meet at Palachan village, 10 km. North of Manali to form the river

Beas. From Manali, this holy river after passing through dense evergreen forests reaches the

town of Kullu. After covering hundreds of Kilometres through the hills, the river embraces the

river Satluj at Hari Ka Patan in Ferozpore district of Punjab before flowing into Pakistan. Its main

tributaries are Parbati, Sainj in the East; and the Solang, the Manalsu, the Fozal and the Sarvari

Streams in the West. In Kangra, it is joined by Binwa, Neugal, Banganga, Gaj, Dehr and Chakki

from North, and Kunah, Maseh, Khairan and Man from the South. The Beas enters district

Kangra at Sandhol and leaves it near Mirthal. At Bajaura, it enters Mandi district situated on its

left bank. In Mandi district, its own Northern feeders are Hansa, Tirthan, Bakhli, Jiuni, Suketi,

Panddi, Son and Bather. The northern and Eastern tributaries of the Beas are perennial and

snow fed, while Southern are seasonal. Its flow is maximum during monsoon months. At

Pandoh, in Mandi district, the waters of the Beas have been diverted through a tunnel to join the

Satluj. It flows for 256 km. in Himachal Pradesh.

The Malana Khad originates from Dudhon glacier in Himachal Pradesh. The elevation in glacier

zone ranges from 4280 m to 6221 m with at least 17 peaks of elevation higher than 5000. Below

the glacier zone, the river traverses in westerly direction to an elevation of about 4000 m up to

the village Wachin. Thereafter, it travels in southwest direction till it joins with the river Parbati, a



major tributary of the river Beas. The elevation of the Malana Khad at its confluence with Parbati

River is about El 1360.

Ravi River: Ravi river rises from the Bara Banghal (a branch of Dhauladhar) as a joint stream

formed by the glacier-fed Badal and Tant Gari. The right bank tributaries of the Ravi are the

Budhil, Tundah Beljedi, Saho and Siul; and its left bank tributary worth mentioning is Chirchind

Nala. Town Chamba is situated on the right bank of the river Ravi. The Ravi river flows by the

foot of Dalhousie hill, through the famous Chamba valley. The river with its length of about 158

km. in Himachal has a catchment area of about 5,451 km2.

Chenab River: Two streams namely Chandra and Bhaga rise on the opposite sides of the

Baralacha pass at an elevation of 4,891 metres and meet at Tandi at an elevation of 2,286

metres to form the river Chenab. The Chandra rises from the South-East and Bhaga from the

North-West of the Baralacha pass. It enters Pangi valley of Chamba district near Bhujind and

leaves the district at Sansari Nala to enter Podar valley of Kashmir. It flows in Himachal for 122

km. With its total length of 1,200 km, it has a catchment area of 61,000 km2 out of which 7,500

km2 lie in Himachal Pradesh. It is the largest river of Himachal Pradesh in terms of volume of

waters. The Chenab valley is a structural trough formed by the great Himalayan and Pir Panjal

ranges.

Yamuna River: It enters Himachal Pradesh at Khadar Majri in Sirmaur district. Yamuna river is

the largest tributary of the Ganga. Its famous tributaries are Tons, Pabbar and Giri or Giri

Ganga. Its total catchment area in Himachal Pradesh is 2,320 km. It leaves the state near

Tajewala and enters into the Haryana state.

Figure-2.2: Map of River Systems



2.5 AVAILABLE GENERATION CAPACITY IN THE STATE

As per hydro-electric potential re-assessment studies carried out by HPSEB, it has been

estimated that about 20787.07 MW of hydel power potential can be exploited in the state by

constructing various major, medium & small hydel projects on the five river basins. Out of the

above estimated potential, about 7950 MW has already been developed and another 4062 MW

is presently under different stages of development.

The power supply position in the state during the last few years is given in the following table:

Table 2.1: Power Supply Scenario in Himachal Pradesh

Energy Surplus (+)/Deficit(-)% Peak Surplus (+)/Deficit(-)%

2001-2002

(End of 9th

Plan)

2006-2007

(End of 10th Plan)

2011-12 2001-2002

(End of 9th

Plan)

2006-2007

(End of 10th

Plan)

2011-12

-2.6 -2.7 -2.5 -0.0 -0.0 -7.1

The energy requirement of the state increased from 3293 GWh in 2001-2002 to 8161 GWh in

2011-12. The corresponding requirement of energy in the Northern Region is 276121 GWh.

Himachal Pradesh faces energy deficit as well as shortfall in availability of peak power

2.6 DEVELOPMENT OF HYDRO POWER POTENTIAL

The economy of the Himachal Pradesh is predominantly dependent on agricultural and allied

sectors which contribute nearly 40% to the state domestic product and provide direct

employment to about 69% of the population. The state government has provided numerous

incentives, which have given impetus to the industrial growth in the state. The electric power,

being a vital and essential infrastructure has a significant role to play in economic development

and upliftment of the state. Realising the importance of power in the overall development of the

state and taking advantage of the Central Govt’s decision to allow participation of private sector

for execution of power projects, the State Govt. has invited entrepreneurs and has signed MOUs

with them for development/exploitation of hydel potential in the state.

Realizing the importance of availability of power in the overall development of the state, hydel

power development has been accorded top priority by the govt. from the sixth plan onwards. The

installed generating capacity of hydro plants in the state sector has risen from about 112 MW in

1980-81 to about 7950 MW in December, 2012.

In the field of rural electrification, the state has attained remarkable achievements. Despite being

a late entrant in the field of rural electrification and located in difficult terrain, the state has been

able to electrify all of its 16,807 inhabitated villages.



Due to limited resources available with the Central and State Government, the Govt. of India has

approved the participation of the private sector in the generation, supply and distribution of

electricity in the country in order to overcome the anticipated power shortage. As a result, the

Himachal Pradesh has Govt. decided to allow private sector participation in respect of hydro-

electric projects. Highlights of new Hydro Policy on Privatization are as follows:

Selection of Developer on MOU Route allowed for projects up to 100 MW

Selection of Developer on ICB route for Projects above 100 MW.

No Clearances necessary from CEA for projects selected on competitive bidding route for

projects costing upto Rs. 2500 crores.

Secondary energy rate to be at par with primary energy. Premium on peak power

proposed.

Process of Transferring clearances to IPP’s simplified.

100% Foreign Equity permitted on the automatic approval route provided it does exceed

Rs. 1500 Crores.

Limit of 40% financing from Indian Financial Institutions waived off.

Tariff determination by SERC/CERC.

Projects upto 25 MW to be transferred to MNRE.

HPSEB to purchase power @ Rs. 2.95/kWh from projects upto 5 MW capacity

Banking & Wheeling Facilities permitted @ 2% including transmission losses.

Incentives for small HEP as per GOI Guidelines.

Moratorium of 5 years for payment of Electricity duty by companies which consume

electricity produced by them.

The Govt. of Himachal Pradesh has allotted hydropower projects to state and central sector and

also to independent power producers initially on MOU route and subsequently through

International competitive bidding route.The list of projects allotted through MOU route are

indicated in Table-2.2 and projects allotted through ICB are indicated in

Table-2.3.

Table 2.2: List of Projects for Which MOUs Have Been Signed With Private Entrepreneurs

Sl.No. Name of the Scheme Installed Capacity

(in MW)

1. Baspa-II 300

2. Dhamwari Sunda 70

3. Karcham Wangtoo 1000

4. Allain Dhungan 192



Sl.No. Name of the Scheme Installed Capacity

(in MW)

5. Malana 86

6. Harsar 60

7. Bharmour 45

8. Sainj 100

9. Sorang HEP 60

10. Kugti 45

11. Neogal 15

12. Budhil 70

13. Fozal 6

14. Patikari 16

15. Malana-II 100

16. Baragran 10.5

17. Paudital Lassa 36

18. Sai Kothi 17

19. Lambadag 15

20. Tangnu Romani 44

21. Dhaulasidh 80

22. Tidong-1 100

Table 2.3: List of Projects for Which MOUs Have Been Signed With

Private Entrepreneurs – ICB route

Sl.No. Name of the Scheme

Installed Capacity

(in MW)

1 Chanju-I 25.00

2 Chanju-II 17.00

3 Bara Banghal 200.00

4 Bajoli-Holi 180.00

5 Kuther 260.00

6 Suil 13.00

7 Sal-I 6.50

8 Bardang 126.00

9 Chattru 108.00

10 Miyar 90.00

11 Tinget 81.00



Sl.No. Name of the Scheme

Installed Capacity

(in MW)

12 Teling 69.00

13 Tandi 104.00

14 Rashil 102.00

15 Gondhala 144.00

16 Khoksar 90.00

17 Ropa 60.00

18 Mane Nadang 70.00

19 Lara 60.00

20 Bahairari 5.50

21 Chango Yangthang 140.00

22 Yangthang Khab 261.00

23 Sumta Kathang 130.00

24 Kut 24.00

25 Tidong-II 60.00

26 Jangi thopan 480.00

27 Thopan Porari 480.00

28 Kilhi-Balh 7.50

29 Dhaula-Sidh 40.00

30 Shalvi 7.00

31 Rupin 39.00

32 Malana III 30.00

33 Dhancho 18.00

Total Capacity 3527.50

2.7 BHARMOUR STAGE-I HEP

Under the private participation, Bharmour Stage-I HEP has been allocated by Govt of Himachal

Pradesh to M/S Soffimat SA, France. The Implementation Agreement (IA) was signed between

M/S Soffimat SA and the Govt. of Himachal Pradesh on 23.04.2011 followed by signing of a

Tripartite Agreement on 04.09.2012, wherein the liability and responsibility were transferred to

an SPV floated by M/s Soffimat SA, France namely M/s Bharmour Hydro Projects Pvt. Ltd. (M/s

BHPPL) for further investigation and construction.

M/s BHPPL has submitted a proposal for fragmentation of 45 MW Bharmour Hydro Electric

Project. In this regard, Government of Himachal Pradesh has decided to accord in-principle



approval to implement Bharmour (45 MW) HEP in two stages comprising Bharmour Hydro

Electric Project Stage-I (22.5 MW) & Bharmour Hydro Electric Project Stage-II (22.5 MW) HEPs.

BHEP-I Hydroelectric Project located in Chamba district of Himachal Pradesh, proposes to

utilize water from Budhil Nallah for generation of 24 MW of power. The Budhil Nallah is a

tributary of Ravi River and it’s catchment adjoins catchment of Ravi River. The gross head of

99.50 m and a design discharge of 29.50 m3/s is proposed to be utilized to generate 115.36 MU

of annual average energy with 95% plant availability.

2.8 NECESSITY AND JUSTIFICATION FOR IMPLEMENTING THE PROJECT

Comparing the projected growth of peak demand and anticipated increase in the generating

capacity on the basis of new projects proposed and/or under construction/consideration, it is

evident that there is a dire need to provide additional power to the Northern Grid to meet the

increasing demand of power. New schemes have to be taken up immediately and implemented

to derive timely benefits. The most important source of power development in the Northern

region is hydroelectric power located in Himachal Pradesh, Uttarakhand and Jammu & Kashmir.

There is an urgent need to develop huge untapped hydro power potential in an early and

efficient manner, manage efficiently the hydro generation capacity of existing power station and

to develop and promote new hydro projects with the purpose of harnessing hydro power

resources in the state for economic well being and growth of the people in the whole region.

Thus, implementing Bharmour Hydro Electric Project Stage-I Project is clearly justified. Power

from the Project is expected to be fully absorbed in the power starved Northern Grid.

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 3-Economic Scene of Himachal Pradesh


3. ECONOMIC SCENE OF HIMACHAL PRADESH

3.1 GENERAL

Himachal Pradesh, spread over an area of 55,673 sq. km, is located in the Northern part of the

country. It is situated south of Jammu & Kashmir and North-east of Punjab state. For

administrative purposes, the state has been divided into 12 districts. The population of the state

as per the 2011 population census is 68.56 lakhs. The per capita income of Himachal Pradesh

in 2010-11 was Rs 58,493/- as compared to Rs 54,835/- at the National level.

3.2 GEOGRAPHY

3.2.1 Physiography

The state is located at altitudes ranging from 450 m to 6500 m above mean sea level. There is

general increase in elevation from west to east and from south to north. It is veiled from the

plains by the Shivalik range of mountains. From south to north, the state August be divided into

the following three major physiographic divisions:

A. Outer Himalayas or the Shivaliks

B. Lesser Himalayas or the Central core

C. Great Himalayas and Zanskar or the Northern core

3.2.2 Rivers

Himachal Pradesh has the unique distinction of providing water both to the Indus and the

Ganges basins. The major river systems of the region are Chandrabhaga or the Chenab, the

Ravi, the Beas, the Sutlej and the Yamuna. These perennial rivers are both snow & rain fed and

are protected by fairly extensive cover of natural vegetation. The river Chandrabhaga (Chenab),

formed by the confluence of the rivers Chandra and the Bhaga at Tindi in Lahaul, is the largest

river of the state in terms of volume of water. The Ravi originates from Bara Banghal in Kangra

as a joint stream formed by the glacier fed Bhadal and Tantgari. The river with a catchment

area of 5,451 sq. km traverses 158 km in Himachal Pradesh. The Beas river originates in the

Pir Panjal range near Rohtang Pass and is joined by a number of tributories like Parbati, Hurla,

Uhl & Banganga etc. The river Sutlej finds its origin in Tibet with the association of its tributaries

like Tiang, Hogis, Gyamthing, Tidong, Baspa, Duling, Romni & Ponwi along its left bank and

Spiti river, Ropa, Kirang, Kashang, Pangi, Choling and Bhaba khad along right bank and after

running parallel to the Indus, it cuts through the great Himalayan and the Zanskar ranges and

emerges at Bhakra.



3.2.3 Climate

The seasonal system of the weather and vertical zoning of the climate are two important

characteristics of the climate of Himachal Pradesh. There is great diversification in climatic

conditions of the state mainly due to large variation in altitude (450 m-6500 m) and presence of

imposing main Himalayan mountain wall. It varies from hot and sub-humid tropical in southern

low tracts to temperate, cold alpine and glacial in northern and eastern high mountain ranges.

The climate of Lahaul-Spiti and Kinnaur is semiarid highland type, whereas Kangra, Una,

Hamirpur and part of Solan disctricts are less cold and have a severe hot weather. The tracts

lying close to the plains of Punjab and Haryana are the hottest where mercury soars to about

40ºC. On the other hand Lahaul Spiti is the coldest where temperature falls 30ºC below the

freezing point during winters. The rainfall in the state varies from a minimum of 50 mm (in Spiti)

to a maximum of 3400 mm in Dharamshala.

3.2.4 Forest & Wildlife

Forest in Himachal Pradesh cover an area of 44,939 sq. km. and form about two third of the total

geographical area of the state. They are, however, not uniformly distributed and are mostly

confined to higher hills and interior valleys. Due to wide range of altitudes and climatic

conditions, several varieties of vegetation from Himalayan meadows to tropical shrubs and

bamboo forests on low foothills are found in the state.

Until few years ago, the forests were considered as main source of income and their inundation

went on unabated. However, the concept has since undergone total change. The focus has

now shifted to the conservation and the forests have now been nationalised. Government is

now planning to provide green cover to 50 percent of the total area. A World Bank sponsored

Social Forestry Project has been launched to raise fuel, fodder and small timber species to meet

basic necessities of the people. Forests are now being protected from biotic interference and a

centrally-sponsored scheme has been launched to detect illicit felling and smuggling of timber.

From the tropical and sub-tropical forests of Una and Nurpur in the west to dry alpine vegetation

of the Pin valley National Park in the north-east, Himachal Pradesh is the home of a wide variety

of mammals, birds, reptiles and avifauna. These include snow leopard, ghoral, musk deer (the

state animal) and monal (the state bird). Elephants and tigers, which were found to exist in large

numbers in the past are now almost extinct. With a view to intensify wildlife preservation and

management, the state Govt. has banned ‘hunting’ and has established a number of “National

Parks” and “Sanctuaries” which cover nearly eight percent of its geographical area. Some of the

famous National Parks Sanctuaries in the state are Great Himalayan National Park, Pin valley

National Park, Renuka Sanctuary, Simbalwara Sanctuary etc.

3.2.5 Population

Based on the 2011 census, the population of the state is 68.56 lakhs registering a growth of

about 12.81% over that of 2001 population. The density of the population for the state is 123

persons per sq. km as compared to 382 persons per sq. km. for whole of India. As per the 2011



census, the number of females per thousand males have gone up to 974 against the

corresponding all India figure of 940. The urban population in the state constitutes about 10.04

% of the total population

3.3 SOCIOLOGY

3.3.1 Education

Literacy rate in Himachal Pradesh according to 2011 census was 83.78% Male/female

differential in literacy were wide in the state. As against 90.53% literacy rate for males, it was

only 76.48% for females. The govt. has provided free hostel accommodation in remote &

backward areas to help spreading of education.

At present 77 degree colleges 7 Universities, 5 polytechnics, 2 Engineering colleges and 20

Industrial Training Institutes are functioning in the state for imparting technical education. A

National Institute of Technology at Hamirpur is also functioning in the state since 1986-87.

The State Government has also taken a major step to make girl education free for all levels of

education including technical and professional courses within the state. Himachal Pradesh has

11500 educational institutions at present as compared to only 500 at the time of independence.

3.3.2 Health and Family Welfare

Health & family welfare department in Himachal Pradesh is providing service such as public

health, health education, family welfare, and maternal and child healthcare through a network of

72 civil hospitals, 291 primary health centres, 181 allopathic dispensaries and 657 ayurvedic

dispensaries. As a result of various public health measures, the death rate, over the years, has

come down from 10.3 per thousand in 1983 to 8.6 per thousand in 1994 and diseases like

malaria and small pox have been completely eradicated.

3.4 ECONOMY

3.4.1 Transportation

The hill state of Himachal Pradesh lacks developed means of transport. Rugged terrain, hard

climatic conditions and its remote location have kept this area practically isolated since long.

Roads are the lifeline for the people of the state, as there are practically no other means of

transport. A very high priority, therefore, continues to be accorded to the programmes of road

construction. There existed 4586 kms of roads connecting various towns and villages.

As on date, the total length of railway routes in the state was 225 kms. There are two narrow

gauge railway lines connecting Shimla with Kalka (96 km) and Joginder Nagar with Pathankot

(113 km) and one 16 km broad guage railway line from Nangaldam to Una. The air services in

the state are also limited and seasonal.Airports namely S, Bhunter in Kullu, Jubbar Hati at

Shimla and Gaggal at Kangra were operational with a view to boost tourism in the state.



3.4.2 Industrial Development

The state accounts for only 0.2 percent of the mining output of the country. Industries which are

mainly based on locally available raw materials like forests, horticulture produce and limestone

or those which require dust free environment like electronics & precision goods etc. can be

established. Inspite of availability of cheap electricity the state has remained backward in the

development of industries. The contribution of large scale and small scale industries to the State

Domestic Product is about 7% only. The main hurdles in the way of industrial growth of the

state have been shortage of capital and lack of transportation facilities etc.

In order to give impetus to the growth of industrial sector, a new industrial policy was adopted in

the seventies which provided incentives like cheap power, 25% subsidy and easier credit

facilities etc. for setting up of new industries. Allotment of land on 99 years lease at low rent,

exempting raw materials & finished goods from sales/purchase tax & Octroi for five years and

concession on freight charges for transport of raw materials are other distinguishing features of

the new industrial policy which has greatly helped in attracting entrepreneurs for establishing

industries in the state. Important industrial areas have been developed in Parwanoo,

Barotiwala, Baddi, Paonta Sahib, Nagrota & Bilaspur etc. The state presently has many large &

medium sized industries which are manufacturing items like tractors, granulated fertilizers, resin

and turpentine, vegetable ghee etc. Availability of electricity has also encouraged establishment

of cement & mini steel plants. A dozen medium size paper manufacturing units have also been

established. Tea, grown in Kangra and Mandi districts at an altitude of about 1000 to 1500 m

above sea level is providing employment to farmers. There are 1660 tea planters involved in

cultivating an area of 2000 hectares in the state. During 1994-95, about 800 tonnes of tea was

produced.

While the economic growth rate has risen sharply to 5% during 1994-95 from a low of 0.08% in

1992-93, investments continue to flow in and several new industrial projects both in the medium

and large scale sector have gone on stream. Moreover, many existing units located specially in

the industrial belt of Baddi, Barotiwala on the Shivalik Foothills and at Parwanoo are undergoing

their expansion cum modernisation programmes.

As many as 18 industrial projects in medium and large scale sector with investment of nearly Rs

1000 crores have begun production. Likewise, 1578 small scale units with an investment of Rs

110 crores have also gone on stream in the last two years. Another 109 projects in the medium

and large scale sector with an investment of Rs 5000 crores are under various stages of

implementation. Although the main sectors of investment are in the Pharmaceuticals, textiles

and knitwears, electronics and agro based industries, the state has also initialed MOUs with

private parties for setting up of 3 cement plants in the state involving an investment of nearly Rs

5000 crores.

At present, 22000 Small Scale industrial units having a total investment of Rs 280 crores, are

registered with the Industries department. These units provide employment opportunities to

about 80,000 persons. In addition, 140 large and medium scale projects are also functioning in



the state with an investment of Rs 530 crores. About 17000 persons have been provided

employment by these units.

3.4.3 Agriculture

The economy of the state is mainly based on agriculture. It provides direct employment to about

69 percent of the total work force. 8.44 lakh farmers operate 10.15 lakh hectares for agriculture

out of the total geographical area of 55.67 lakh hectares, as per the 2010-11 provisional

agricultural census. The agro-climatic conditions in the state are congenial for the production of

cash crops like potato, ginger and off-season vegetables. Potato is one of the most important

cash crops in the state on which the economy of the farmers is dependent, especially in Shimla

and Lahaul Spiti districts.

3.4.4 Horticulture

The varied agro-climatic conditions in the state are suitable for growing a wide range of fruit

crops. Due to higher productivity and income per unit area from fruit crops, horticulture is

playing a vital role in improving the socio-economic conditions of the rural population. To bring

about diversification in the horticulture industry, special efforts are being made to promote other

horticultural crops like olives, figs, hops, kiwifruit, strawberry etc. Efforts are also being made to

promote ancillary horticulture activities like mushroom production, bee keeping & flower

production etc. The important citrus fruits grown in the state are Kinnoo, Malta, Orange and

Galgal. The state won over 80 percent of prizes and Challenge shields awarded during the All

India 1993 Apple show, organised by the Ministry of Agriculture, Govt. of India at Madras on

28th and 29th Sept. 1993. Efforts have been made to introduce modern technology in orchard

management like drip irrgation system for economic utilization of available water in the orchards

and green house technology for increased and improved quality production of fruits, vegetables

and flower plants under protected cultivation system.

3.4.5 Irrigation

The state has irrigation potential of approximately 3.35 lakh hectares, out of which 50,000

hectares can be brought under irrigation through major and medium irrigation projects and the

balance can be provided irrigation through minor irrigation schemes.

3.4.6 Fisheries & Animal Husbandry

Himachal Pradesh is blessed with vast fishery resources in the network of rivers & sprawling

reservoirs, which harbor a wide array of temperate, sub-temperate and tropical fish species.

The state offers considerable potential for the development of fisheries.

The development programme of Animal Husbandry in the state includes :

Animal health and disease control

Cattle development



Sheep breeding and development of wool.

Poultry development

Feed and Fodder development

Veterinary Education.

At present 230 veterinary hospitals, 514 dispensaries and 89 outlying dispensaries are

functioning in the state to provide veterinary aid and prophylactic vaccination against various

contagious diseases.

3.4.7 Tourism

Himachal Pradesh has always had a mystical fascination for the Indian mind. It is visited by

over two lakh tourists every year. Its eternal snow, black woods, rippling springs, rhythmic

streams, roaring rivers, picturesque lakes, lush green valleys and meadows are irresistable

attractions. Besides the usual peace and relaxation of hill resorts, Himachal Pradesh provides

scope for adventure to the skiers, winter sportsmen, hikers & mountaineers. In addition,

thousands of devotees with religious fervour, visit various temples located in difficult terrains of

the state. Shimla, the capital city of the state and a hill station at an altitude of 7000 feet above

sea level, has remained the greatest attraction among the tourists. Himachal Pradesh boasts of

having a number of hill stations in the state including Shimla, Kufri, Chail, Kullu, Manali,

Dharamshala, Sundernagar etc.

Tourism industry has emerged as a major sector in the development of the State’s economy.

While the Private Sector has been roped in for development of infrastructure, pilgrims and

heritage tourism is being given priority. Adventure tourism is being developed by encouraging

mountaineering, skiing and heli skiing, trekking and water and winter sports.

Ten helipads have been constructed in far flung areas of the state and air strips at Banikhet in

Chamba district and Rangrik in Spiti districts are also being constructed. The airport at Bhunter

in Kullu is also being strengthened.

Tourism has the potential to be a major industry in Himachal Pradesh where there is

considerable scope for cashing in on the boundless natural attractions. Realising this, the state

govt. has declared tourism as an industry. This has also helped in the development of local

cottage industry and tiny industrial sector famous for shawls, caps, jewellery, wood craft and

hosts of other handicrafts. Further as a result of generous subsidies and loans, the hotel

industry has made considerable progress at important tourist resorts.

3.5 ENERGY

3.5.1 Energy Potential

Electric energy has a vital and significant role to play in the economy of any state. In fact

requirement of power and its availability have been recognised as the surest index of a country’s



overall economic growth as it is one of the basic inputs for industrial as well as agricultural

development. Himachal Pradesh has a vast hydro potential. As per hydro-electric potential re-

assessment studies carried out by HPSEB, it has been estimated that about 20787 MW of hydel

power potential can be exploited in the state by constructing various major, medium & small

hydel projects on the five river basins. Out of the above estimated potential, about 7950 MW has

already been developed and another 4062 MW is presently under different stages of

development.

3.5.2 Energy Demand

The power supply position in the state during the last few years is given in the table below:

Energy Surplus (+)/Deficit(-)% Peak Surplus (+)/Deficit(-)%

2001-2002

(End of 9th

Plan)

2006-2007

(End of 10th

Plan)

2011-12 2001-2002

(End of 9th

Plan)

2006-2007

(End of

10th Plan)

2011-12

-2.6 -2.7 -2.5 -0.0 -0.0 -7.1

The energy requirement of the state increased from 795.2 Gwh in 1988-89 to 8161Mkwh in

2011. The corresponding requirement of energy in the Northern Region is 276121 Mkwh.

3.5.3 Hydro Power Development

Realising the importance of development of the huge hydel potential in the overall development

of the state, hydel power development has been accorded top priority by the govt. from the sixth

plan onwards. The installed generating capacity of hydro plants in the state sector has risen

from about 112 MW in 1980-81 to about 1397 MW in March, 2012.

In the field of rural electrification, the state has attained remarkable achievements. Despite

being a late entrant in the field of rural electrification and located in difficult terrain, the state has

been able to electrify all of its 16,807 inhabitated villages.

The economy of the Himachal Pradesh is, predominantly dependent on agricultural and allied

sectors which contribute nearly 40% to the state domestic product and provide direct

employment to about 69% of the population. The state government has provided numerous

incentives, which have given impetus to the industrial growth in the state. The electric power,

being a vital and essential infrastructure has a significant role to play in economic development

and upliftment of the state. Realising the importance of power in the overall development of the

state, and taking advantage of the Central Govt’s decision to allow participation of private sector

for execution of power projects, the State Govt. has invited entrepreneurs and has signed MOUs

with them for development/exploitation of hydel potential in the state.



BHEP-I is another such project, proposed to be executed by Bharmour Hydro Projects Pvt ltd

(BHPPL). This project would afford power benefits of 24 MW and annual energy benefits to the

extent of 115.36 Gwh. The project would, therefore, meet the growing requirement of Himachal

Pradesh and surplus energy will be fed to the Northern grid.

3.5.4 Transmission and Distribution System

The need for strengthening the transmission and distribution system in the state is being felt by

the government for the last few years in order to ensure uninterrupted power supply at proper

voltage to the consumers and also for transmission of power from new projects. However,

because of inadequate funds the ongoing transmission and distribution schemes could not be

completed and work on new schemes could not be started. Of late, construction of a number of

132 KV transmission Line/substations have been undertaken with the assistance of World Bank,

which approved a loan amounting to 43 million dollars for the purpose.

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 4-Project Summary


4. PROJECT SUMMARY

4.1 GENERAL

Bharmour Hydroelectric Project Stage-I (BHEP-I) located in Chamba district of Himachal

Pradesh, is a run-of-river type development proposed to harness the Hydel potential of Budhil

Nallah.

The project envisages construction of an diversion structure comprises barrage with four

numbers of spill way bays and one number of undersluice bay of each size 5.5 m (W) X 8.5 m

(H) on the Budhil nallah near Bharmour town for diversion of a design discharge of 29.50 m3/s,

through an intake and two surface desanding arrangement into a 2.63 km long water conductor

system. The water conductor system comprises of headrace tunnel (HRT) (2485.00 m) having

D-shape of finished size 3.6 m (W) X 3.6 m (H) and an open to sky surge shaft. The initial

stretch of about 8.5 m of main pressure shaft from the exit of surge shaft is horizontal with centre

line at El.1806.00 m. After the horizontal portion 90o bend is provided to make it vertical

underground pressure shaft of length 90.0 m upto the lower vertical bend. The underground

pressure shaft continues horizontally upto the proposed location of trifurcation point for a length

of about 24.50 m. The pressure shaft is trifurcated into three branches of each 1.65 m dia & 21.0

m long feed water to each Horizontal Francis Turbine of 8.00 MW housed into surface power

house. Rated Net head of 93.0 m is utilised to generate 24 MW (3 X 8.0 MW) of power.

Harsar I (32 MW), Harsar II (20 MW), Harsar III (Chobia) (18 MW), Bharmour I (24 MW) &

Bharmour II (21 MW) HEP’s are located downstream of Kugti and upstream of Budhil HEP.

These five projects are being developed as run of the river projects on fast track. Accordingly,

composite power evacuation scheme on 132 & 220 kV for these HEP’s is proposed considering

15% overload and simultaneous operation of all Projects. As per suggestion of CEA, double

circuit line is recommended for medium and large projects. Considering small capacities of

Harsar & Bharmour HEPs and to optimise the project costs, 132 kV Double Circuit Ring Main

Scheme & 220 kV Single Circuit Transmission Line System has been proposed.

4.2 SALIENT FEATURES

The salient features of the Project are indicated below:



SALIENT FEATURES

1. PLANT

Type : Run-of-River

Capacity : 24.0 MW

Gross Head : 99.50 m

Design Discharge : 29.50 m3/s

Discharge at 15% Over Load on Rated Capacity

: 34.74 m3/s

2. LOCATION

Longitude : 76o 32' 07" to 76o 35' 44"

Latitude : 32o 28' 42" to 32o 28' 36"

State : Himachal Pradesh

District : Chamba

Stream : Budhil, a tributary of Ravi river

Vicinity : Near Bharmour Town

3. HYDROLOGY

Catchment area at diversion : 471 km2

50 year Return Period Flood : 2100 m3/s

100 year Return Period Flood : 2315 m3/s

10-Dily Average Discharge with 90%

Dependability : 7.02 m3/s

10-Daily Average Discharge with 75%


10-Daily Average Discharge with 50%


Discharge for Ecological & Environmental

Release : 0.64 m3/s

4. HEAD WORKS

a. DIVERSION STRUCTURE

Type : Barrage

Maximum Flood Level : El. 1843.50 m

Average River Bed Level at Barrage Axis : El. 1827.00 m



FRL : El. 1835.50 m

Crest Level of Spillway Bays & Under-sluice

bay : El. 1827.00 m

No. of spill way bays : 4

No. of undersluice bays : 1

Size of Spill Way Bays each : 5.5 m (W) x 8.5 m (H)

Size of undersluice Bay : 5.5 m (W) x 8.5 m (H)

Thickness of Pier & Divide Wall : 2.0 m

Total Length of Barrage between Abutments : 37.5 m

Type of gates : Radial Gates

Energy Dissipation System : Stilling Basin

b. INTAKE STRUCTURE

Trash Rack : 2 No. Vertical, 6.0 m (W) x 5.0 m (H)

Type : Rectangular, Bell mouth entrance type

Intake Gate : 2 No. vertical lift gate, 3.0 m (W) x 4.0 m (H)

Design Discharge :35.40 cumec (29.50 + 20% Silt Flushing

Discharge)

c. DESILTING ARRANGEMENT

Type : Surface Desilting Chambers

No. & Size of each Desilting Chamber :2 Nos., each 80.0 m (L) x 10.0 m (W) x 11.5

m (effective depth, H)

Particle size to be Excluded : 0.20 mm and above

Design Discharge :35.40 m3/s (including 20% Flushing

discharge)

Flow Through Velocity : 0.18 m/s

Settling Velocity : 0.024 m/sec

Valve for Flushing Conduit : 1200 mm

Silt Flushing Pipe : 1200 mm Ø Circular & 30 m length



d. COLLECTION POOL AFTER DESILTING BASIN

Invert Level : El. 1823.00

Size of Collection Pool : 21.0 m (L) x 12.0 m (W) x 13.2 m (H)

MDDL : El. 1830.20 m

FSL : El. 1835.00 m

5. HEAD RACE TUNNEL

Type and Size :Concrete Lined, D – Shaped, 3.6 m Dia

Finished.

Velocity : 2.52 m/s

Length : 2485 m

Design discharge : 29.50 cumec.

Average Slope of Tunnel : 1 in 132

6. ADITS

Adit-I (for HRT Construction) : D-Shaped, 4.0 m dia Finished & 60 m long

Adit-II (for HRT Construction) : D-Shaped, 4.0 m dia Finished & 115 m long

Adit-III (To Bottom of Surge Shaft) : D-Shaped, 4.0 m dia Finished & 85 m long

Adit-IV (To Penstock Trifurcation) : D-Shaped, 4.0 m dia Finished & 64 m long

7. SURGE SHAFT

Type : Restricted Orifice

Size of Surge Tank : 10.0 m Ø Circular & 59.80 m Height

Size of Orifice : 1.8 m Ø Circular Orifice at Bottom

Invert Level of Surge Tank : El. 1809.30 m

Top Level of Surge Tank : El. 1864.00 m

Max. Upsurge Level : El. 1856.15 m

Min. Down Surge Level : El. 1816.88 m

8. PRESSURE SHAFT

Type : Underground

Size Main :1 No. 2.8 m dia, 33.0 m long Horizontal &

90.0 m long vertical pressure shaft

Branches 3 nos., 1.65 m dia, 21 m each (average

length)



Velocity in Main : 4.79 m/s

Velocity in Branch 4.60 m/s

Type & thickness of steel liner : SAILMA 350, 12 mm to 24 mm thk.

9. POWER HOUSE

Type : Surface

Installed Capacity : 24.0 MW (3 x 8.0 MW)

Size of Power House including Service Bay : 56.0 m (L) x 15.0 m (W) x 22.0 m (H)

Size of Control Room : 56.0 m (L) x 6.00 m (W) x 4.50 m (H)

Service bay Level : El. 1737.00 m

Gross Head 99.50 m (1835.50-1736.00)

Total Head loss (on rated discharge = 29.5

m3/s) : 6.50 m

Rated Net Head : 93.0 m (99.50-6.50)

Maximum Net Head : 100.57 m (1835.5-1734.15-0.78)

Minimum Net Head : 90.74 m (1835.50-1736.30-8.46)

C/L of Turbine : 1733.40 m

Crane beam level : 1745.00 m

Normal TWL : 1736.00 m

Draft Tube Gates : 3 No. vertical lift gate 2.4 m x 2.1 m

9. TAIL RACE CHANNEL

Tail Pool :3 nos, 2.4 m wide draft tubes merges into

one common tail pool of Size 4.0 m Wide

10. INTAKE POOL FOR BHARMOUR STAGE-II HEP

Size of Intake Pool :24.05 (L) x 15.0 (W) x Depth Varies from

2.15 m to 11.50 m

FSL : El. 1735.50 m

MDDL : El. 1733.80 m

11. TURBINES

No. & Type : 3 Nos., Horizontal Francis

Rated Power : 8.0 MW of Each Unit



Overload capacity : 15 %

Rated Net Head : 93.00 m

Design Discharge : 9.83 cumec. Of Each Unit

Speed : 428.6 RPM

12. MAIN INLET VALVE

Type : Butterfly Valve

Diameter : 1500mm

Design Head : 132 m

Location : Power House Cavern

13. GENERATOR

Type :Horizontal Shaft, Salient pole synchronous

generator

Number : 3

Rated Capacity : 3 X 8.0 MW

Overload Capacity : 15 % COL

Synchronize Speed : 428.6 rpm

14. SWITCH YARD

Type : Surface Switch Yard

Area : 75.0 m X 35 .0 m

15. TRANSMISSION LINE

132 kV D/C Harsar I - Bharmour Pooling

Station Transmission Line (Ring Main

Scheme)

: 10.80 km

220 kV S/C from Bharmour Pooling

substation near Budhil dam (on left bank D/s

of Budhil dam) to interconnecting point with

existing 220 kV line near Budhil PH

: 8.00 km

220 kV S/C Stringing on Connecting Point-

Chamera III Transmission Line : 20 km

16. ANNUAL ENERGY CORRESPONDING TO 100% PLANT AVAILABILITY

50% Dependable Year : 119.93 Million kWh





39 Years – Average Energy : 122.77 Million kWh

17. COST ESTIMATE

Bharmour Stage-I HEP (BHEP-I)

Civil Works : Rs.134.11 Crores

Electro-Mechanical (E&M Works) : Rs. 44.47 Crores

Transmission and Distribution (T&D) Works : Rs-12.75 Crores

Pre Operative Works : Rs. 17.42 Crores

Total Cost of Project (Excluding

Transmission Line, IDC, FC etc.) : Rs.196.00 Crores

Total Cost of Project including Transmission

Line (Excluding IDC, FC etc.) : Rs.208.75 Crores

Bharmour Stage-II HEP (BHEP-II)



Transmission and Distribution (T&D) Works : Rs.11.15 Crores


Total Cost of Project (Excluding

Transmission Line, IDC, FC etc.) : Rs.127.13 Crores

Total Cost of Project including Transmission

Line (Excluding IDC, FC etc.) : Rs.138.28 Crores

Combined Cost of BHEP-I & BHEP-II (Excluding Transmission Line)




Interest During Construction (IDC) : Rs. 35.91 Crores

Escalation : Rs. 16.49 Crores

Fund management Expenses : Rs. 2.76 Crores

CAT : Rs. 9.46 Crores

LADA : Rs. 5.90 Crores

Total Combined Cost : Rs. 393.64 Crores



Combined Cost of BHEP-I & BHEP-II (Including Transmission Line)




Transmission and Distribution (T&D) Works : Rs. 23.90 Crores

Interest During Construction (IDC) : Rs. 38.12 Crores

Escalation : Rs. 17.24 Crores

Fund management Expenses : Rs2.95 Crores

CAT : Rs. 10.13 Crores

LADA : Rs. 6.33 Crores

Total Combined Cost : Rs. 421.80 Crores

18. TARIFF DETAILS (Excluding Transmission Line)

1st Year Tariff : Rs. 4.79

Levelised Tariff per KWh : Rs. 4.36

19. TARIFF DETAILS (Including Transmission Line)

1st Year Tariff per KWh : Rs. 5.13

Levelised Tariff per KWh : Rs. 4.68

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 5-Survey & Investigation


5. SURVEY & INVESTIGATION

5.1 GENERAL

The proposed Bharmour-I Hydro Electric Project is located on Budhil Nallah near Bharmour

town situated at an approximate distance of 95 km North-east from the district headquarters at

Chamba town in Himachal Pradesh. The project area is covered in Survey of India Toposheet

No: 52 D/11. The details of field activities related to Topographical survey, hydrological

measurements and Geotechnical Investigation at the project area is presented in this chapter

5.2 TOPOGRAPHICAL INVESTIGATIONS

The topographical survey for the entire project area covering the diversion site, water conductor

system, and power house area was carried out during the period October 2013 – December

2013.

The scope of the survey included:

Topographic survey & mapping of Diversion works

Topographic survey & mapping of water conductor system

Topographic survey and mapping of Surge Shaft area.

Topographic survey and mapping of the Powerhouse& Switchyard

Bathymetric sections of Budhil Nallah at Barrage site and Powerhouse site

Close circuit traversing of all control points

Establishment of a suitable contour grid for the entire project survey work

Plotting the maps as per the established coordinate system and grid size

Preparation of all maps in AUTOCAD format

As a prelude to the surveys, vertical control was established starting from listed Survey of India

control point and carrying the control to power house, penstock, head race tunnel and diversion

site areas. The traverse was run using Total Station Machine. The control traverse was closed

on the starting control point and the observed error was insignificant thereby, confirming the high

quality of the control work.

The total area surveyed at the Bharmour Stage-I diversion site measured 0.23 Sq. Km. Direct

contouring containing method by plane table and level was adopted for the survey. The survey

area covered distances of 500 meters both upstream and downstream of the diversion area.

The project components covered in the area are BHEP-I, intake, desilting basin. Contour plans

were drawn to a scale of 1:500 with contour interval of 2 meters.



The survey along the BHEP-I head race tunnel covered a strip of 150 meters (75 m on either

side of the proposed alignment) for the 3000 metres long tunnel. The survey plan has been

drawn to a scale of 1:500 with contour interval of 2 meters.

Topographic survey along the proposed underground pressure shaft alignment covered a strip

of 150 meters (75 meters on either side of the alignment). The survey plan covering an area of

0.1 square kms. has been drawn to a scale of 1:500 with contour interval of 2 meters. The total

area surveyed at surge shaft site is 0.05 sq kms. Contour plans were drawn to a scale of 1:500

with contour interval of 2 meters.

Topographic survey at the power house area spread over 0.05 sq. kms. covered the power

house, switchyard, plant area, dumping area, workshop, stores, offices and the residential

complex. The area plan has been drawn to a scale of 1:500 with a contour interval of 2 meters.

Survey movements comprising 10 nos. ‘B’ Type bench marks and 20 Nos. reference pillars were

established at intake location at the two diversion barrage/weir sites, along the head race tunnel

and pressure shaft alignment, surge shaft, power house complex and tail race channel. These

movements have been shown on the respective survey sheets.

The various survey drawings mentioned above have been used for geomapping of the project

components.The drawings also formed the basis for planning the layout of structures and design

optimization studies.

5.3 GEOTECHNICAL INVESTIGATION

The geotechnical investigations for the project have been taken up and detailed geological

mapping for the project area has been carried out for the project on 1:5000 scale and is

presented in Chapter.7 - Geology.

5.3.1 Field Investigations

Detailed Field and laboratory investigations shall be carried out during construction stage for

confirming findings of detailed geological mapping and for providing inputs for civil design and

project costing.

5.3.2 Sub-surface Exploration

Subsurface exploration is carried out through exploratory pits. The locations of the pits have

been marked on the investigation plan indicated in Chapter.7 - Geology.

The geo-technical investigation and exploration to be carried out by Bharmour Hydro Projects

Pvt. Ltd. covered the following:

i) Drilling, testing and geological logging at the following sites:

Desilting Basin site -1 Bore holes -20 meters deep



Head Race Tunnel - 4 Bore holes -20 meters deep each

Power house site -1 Bore hole -200 meter deep

ii) Geological mapping & photo interpretation at the following sites:

BHEP-I Diversion site

BHEP-I Tunnel intake & outlet

Head Race Tunnel

Surge Shaft

Pressure shaft

Power house area

Tail race channel

iii) Geophysical investigations at:

Diversion site

Head race tunnel

Surge shaft

Pressure shaft

Powerhouse

Tail race channel

5.3.3 Construction Materials

Two sets of samples each from the identified quarry sites should be tested for suitability of the

rock for its use as coarse aggregate. The same is proposed to be crushed and used as fine

aggregate. The laboratory tests to be carried out on aggregate are listed below.

Specific Gravity

Flakiness/ Elongation Index

Soundness

Aggregate Impact Value

Aggregate Crushing Value

Aggregate Abrasion Value (Los Angeles)

Alkali-Aggregate Reactivity (Chemical Method)

Alkali-Aggregate Reactivity (Mortar Bar Method) at one temperature regime

Alkali-Aggregate Reactivity (Mortar Bar) by ASTM method 1260 C for both

Petrography (including modal analysis for strained quartz)



The report and results of field investigations are indicated in Chapter 7 of Geology.

5.4 HYDROLOGICAL INVESTIGATIONS

The catchment of Budhil Nallah is very rugged, hilly and lies between elevation range of 4600 m

to 1387 m. Catchment area at the proposed BHEP-I diversion site is 471 sq. km. The catchment

receives heavy rainfall during monsoon months i.e. from June to September. Whereas, rainfall is

very small during winter months. Heavy to moderate snowfall occurs in the entire Bharmour

valley, during winter months. There are twelve raingauge station in the catchment area of Ravi

river. The normal annual rainfall in millimeters at all these stations for the period of 1960-1994

has been collected from Director of Land Records, Simla (HP).

The Runoff data of Budhil Nallah is available for sufficient period near Budhil HEP at Thalla

(1.6.1972 to 31.5.2011) The discharge data of this site has been used to develop co-relation and

transfer the same to diversion site of Bharmour Hydro-electric project Stage-I for carrying out

hydrological studies.

5.5 PROPERTY SURVEY

Virtually, population requiring rehabilitation and resettlement measures is negligible. The above

aspects have been covered in detail in chapter.15 - Environmental Aspects.

5.6 COMMUNICATION SURVEY

The proposed surface power house site is located on the right bank of Budhil nallah near village

Nangli. A road leading to the surge shaft area, head race tunnel, adits & power house has been

proposed bifurcating at different suitable locations from existing HPPWD road.

Approach roads to all the proposed quarry & muck dumping sites would be extended from the

existing Bharmour-Harsar road, at different suitable locations. The diversion barrage and

desilting tank area would be approached by proposing a bifurcation from existing Bharmour-

Harsar HPPWD Road.

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 6-Hydrology


6. HYDROLOGY

6.1 INTRODUCTION

The hydrology study for river basin involves the estimation of water flow, its time distribution i.e.

time of occurrence and frequency of occurrence and quantity of water in the river. This study is

an integral part of initial planning for a Hydro-Electric Project. Availability of reliable discharge

data for a period of 10 years or more is desirable for hydrological study for small hydro power

projects. Estimation of discharge availability and flood discharges in any catchment is essential

input for project planning and for design of structures such as weir, dam, barrage, desanding,

spillway, tunnel, surge shaft, penstock etc.

The hydrological study for planning and design of Hydroelectric Project consists of three main

components:-

Water Availability Studies

Design Flood Studies

Sedimentation studies

This chapter describes the hydrological study undertaken at intake location for Bharmour stage-I

HEP located on Budhil nallah.

6.2 BASIN CHARECTARISTICS

Ravi is major river of the Indus Basin. It originates from Bara Bangahal branch of the Dhaula-

Dhar range in the Himalayas at elevation of 4229 m. It consists of snow-covered mountains

ranging from 3050 m to 5800 m elevation above mean sea level. The main tributaries are

Kalihan, Budhil, Tundah, Suil & Sewa and these contributes to most of its discharge. The total

length of the River Ravi in India is about 720 kms. The river flows in a Northwesterly direction

for most of its course, rises in Baira-Banso and continues through Trehla and Chanota to Ulans,

where it is joined by two of its major tributaries in the head reaches viz. the Budhil and Tundah. It

finally leaves the territory of Himachal Pradesh near Mihl.

6.3 BUDHIL NALLAH AND ITS CATCHMENT

The Bharmour-I Hydro-Electric project (BHEP-I), is a run-of-the river scheme, proposed on

Budhil Nallah in Chamba District of Himachal Pradesh, which is a tributary of Ravi river. It

originates from the slopes of the mid Himalayas near Kugti pass at an elevation of 5300 m and

joins the Ravi river at an elevation of 1377 m near village Kharamukh in Chamba district. The

total length of Nallah is about 33 Km from its origin to the weir site of BHEP-I. It is joined by

several nallahs on its course; main nallahs that contributes to its runoff are Chalatu, Bhujal,

Thansari and Chobia nallahs. The elevation in the snow zone ranges from 6000 m to 4000 m.

The Nallah flows in northwest direction till its confluence with Ravi River.



The project envisages construction of a gated barrage with one no. of under-sluice bays on

Budhil Nallah and diverted water shall be carried through an underground water conductor

system followed by underground penstock to surface power house located on right bank of

Budhil nallah.

The head works of the project components are located near longitude 76 32' 7" to 76 35' 44"

and latitude 32 28' 42" to 32 28' 36". The location of the project is shown in Fig.6.1. The total

catchment area at proposed diversion structure near village Sandi is 471 km2 out of which 261

km2 is covered under permanent snow above El. 4000 m. The entire catchment comprises of

mountainous terrain with steep hill slopes and is very thinly populated. The total fall in Nallah

from its origin to diversion site is about 3480 m with very steep gradient in upper reaches. Its

average slope from its origin to proposed diversion site is about 1 in 9.5.

Figure-6.1: Location Map of Project

Figure-6.1 Location of the Project



6.4 DESIGN REQUIREMENT

BHEP-I is categorised as a small hydro electric scheme as the project capacity is under 25 MW.

The project is proposed as a pure Run of the river scheme without any storage for peaking

power generation. The dependable flows available to the project can be calculated using direct

or indirect methods. The direct method involves the measurement of discharges at Intake over a

period of time whereas the indirect method involves calculation of discharges at the proposed

Intake location by transforming the measured discharges in the same catchment or nearby

catchment using mathematical techniques.These technique involves use of catchment area,

rainfall data, etc.

The discharge measurement of Budhil nallah at BHEP-I intake site is not available and hence

the various types of data available for assessing the discharge pattern have been collected in

the same basin and are summarized below:

6.5 WATER AVAILABLE STUDIES

6.5.1 Data Availability

Stream flow record for about 34 years is available at diversion site for Budhil HEP (Catchment

area 524 km2) located on Budhil river near Thalla about 7 km downstream of proposed diversion

structure of BHEP-I at Sandi Village. The catchment area upto the diversion site of BHEP-I is

about 471 km2. Discharge data for about 14 years is available at diversion site for proposed

Bajoli Holi HEP located on Ravi River (Catchment Area = 902 km2 , Snow fed Area = 372 km2).

Budhil River joins Ravi River from right bank about 25 km downstream of diversion site of Bajoli

Holi HEP. Location of proposed BHEP-I diversion site on Budhil nallah and gauge and discharge

site on Budhil River is shown in Fig. 6.2. Table-6.1 shows the Discharge data availability which

has been utilized to determine the flow series at proposed diversion site of project.

Table- 6.1: Discharge data availability

Name of Gauge and Discharge

observation site

River Distance from Diversion Site

of BHEP-I

Catchment Area

Period of availability

Name of Discharge observing agency

Thalla Budhil 7 km D/S 524 km2 June, 1972 to August, 1996

Flow Series as Cleared by CWC

Thalla Budhil 7 km D/S 524 km2

June, 1996 to August, 2002 & June, 2007 to August, 2011

HPSEB and Budhil HEP Project

Authority

Bajoli Holi HEP Diversion site

Ravi - 902 km2 June, 1997 to August, 2010

HPSEB and Bajoli Holi HEP Project

Authority

The 10-daily average discharge data at Thalla & Bajoli Holi HEP Diversion site is presented in

Annexure-6.1 and Annexure-6.2 respectively.



Figure- 6.2: Catchment Area Plan of Budhil Nallah

6.5.2 Climate

There is no temperature recording station inside the catchment, while some record is available

at Chamba, situated about 76 kms downstream from the proposed diversion site. The mean

daily maximum/minimum temperature in degrees centigrade at Chamba is given in Table 6.2.

The relative humidity in the area is generally high in monsoon season, being over 80%. In the

post monsoon and winter seasons, the humidity is less. The winter months are from December

to February. The lowest temperature in the region is recorded in the months of January. The

highest temperature is recorded in the month of June and July.



Table- 6.2: Mean Daily Maximum/minimum Temperature at Chamba

Month Mean Daily Max. Temperature in ºC

Mean Daily Min. Temperature in ºC

January 15.20 5.20

February 16.10 5.90

March 22.30 10.60

April 28.30 14.60

August 32.51 17.80

June 30.40 22.00

July 30.40 22.00

August 28.80 21.20

September 29.10 18.10

October 27.10 12.60

November 22.50 8.50

December 28.30 5.90 * Source: HPSEB DRR – Budhil HE Project, 2003

6.5.3 Precipitation

The seasonal system of the weather and vertical zoning are the two important characteristics of

Himachal Pradesh. There is great diversification in climate condition of state mainly due to large

variation in altitude (450 m to 6500 m) and presence of imposing main Himalayan mountain wall.

It varies from hot and sub humid tropical in Southern low tracts in temperature, cold alpine and

glacier in Northern and Eastern high mountain ranges. The climate of Lahaul Spiti and Kinnaur

is semi-arid high land type, whereas Kangra, Una, Hamirpur and part of Solan district are less

cold and have a severe hot weather. The tracts line close to the plains of Punjab and Haryana

are the hottest where mercury sours to about 40 ºC. On the other hand Lahual Spiti and Pooh

are the coldest where temperature falls 30 ºC below the freezing point during winter. The rainfall

in state varies from a minimum of 50 mm (in Spiti) to a maximum of 3400 mm in Dharmshala.

Ten rain gauge stations are established in the catchment of Ravi River. The normal annual

rainfall and annual rainfall recorded in millimeters at all these stations for the period 1961 to

1989 is shown in Annexure-6.3.

The catchment area of BHEP-I receives rainfall both during the winter season from November to

March and from the southwest monsoon in the months of July to September. The winter

precipitation in the basin is quite significant as the catchment lies along the track of the western

disturbances advancing from Iraq, Afghanistan and West Pakistan. During South-West monsoon

also, the catchment receives widespread precipitation due to the following weather synoptic

situation:

Extension of the southwest monsoon current in this region.



Movement of monsoons depression or low-pressure system in the neighborhood of the

catchment.

Shifting of the axis of the monsoon towards the catchment area.

Northwestern movement and subsequent dissipation of monsoon depression over the

adjoining foothills.

The orientation of the catchment with respect to the water bearing winds have significant effect

on rainfall. From the available rainfall record the average heaviest monthly rainfall of 2050 mm

has been recorded at Bhandal in March 1992 and average lowest monthly rainfall of 0.1 mm has

been recorded in October, 1974 at Killar. Rainfall pattern observed in this region is uniform

assuring perennial supply of water for hydro-electric generation.

6.5.4 Discharge Data of Budhil River

The discharge data at Budhil HEP diversion site near Thalla is available for the period of 1972 to

2002 & 2007-2011 (about 34 years). The discharge data for the period of 2002 to 2007 (5 years)

is not available. The average annual runoff of Budhil nallah for the two data sets is calculated as

1372.90 mm and 1492.42 mm respectively (refer Annexure-6.4).

Average annual rainfall of 2250 mm for Budhil nallah catchment has been estimated from sub-

zone ‘7’ report for western Himalayas Isohyetal map. The average annual snowfall has been

reported to be 175.0 mm and water equivalent has been considered to be 175 mm as indicated

in Table 6.3.

Table- 6.3: Statistical Characteristics of Budhil nallah Discharge Data

Description Discharge Data Set-I

Discharge Data Set-II

Average

Availability Period 1972-2002 2007-2011 1972-2011

Annual Average Run-off (mm) 1372.90 1492.42 1386.96

Annual Average Rainfall (mm) 2250.00 2250.00 2250.00

Annual snow water equivalent(mm) 175.00 175.00 175.00

Total annual average Precipitation (mm) 2425.00 2425.00 2425.00

Runoff factor = runoff /Total annual average precipitation

0.57 0.62 0.57

After integrating both discharge data, the Annual average runoff is 1386.96 mm and Annual

precipitation is 2425 mm. Runoff factor has been estimated for entire available annual discharge

(year 1972-2002 and 2007-11).

It is observed that the two set of discharge data are consistent with Annual average precipitation.

57.02425

96.1386

ionPrecipitat Average Annual Total

off-Run factor off-Run



6.5.5 Statistical Charectaristics of Two Sets of Discharge Data at Budhil Nallah

The flow data for Budhil River is available for the period of 1972 to 2002 and in January month

of 2003 site was closed. Subsequently, site had opened in year 2007 and discharge data is

available for the period of 2007 to 2011. The statistical characteristics of two sets of discharge

data is indicated in Table-6.4.

Table- 6.4: Comparative Study of Statistical Characteristics of

Two sets of Discharge Data

Description Discharge Data (1972-2002) Set-I

Discharge Data (2007-2011) Set-II

Mean Run-off (mm) 1372.90 1492.42

Standard Deviation 282.40 277.54

Figure-6.3: 10-Daily mean discharges pattern of Budhil River (1972-2002) and (2007-2011)

A graph showing 10-Daily mean discharges pattern of Budhil River at Thalla for the period 1972-

2002, and period 2007-2011 is shown in Figure-6.3. It is interpreted from the graph that the

pattern of flow for the two data sets is consistent with each other.

6.5.6 Development of Water Availability Series (Yield Series)

The observed discharge of Budhil river is available for the period of 1972 to 2002 and 2007 to

2011. To fill the gap in flow data in Budhil River for year 2002 -2007 (about 5 years), a

regression analysis has been carried out between the concurrent period flow data of Budhil

River for the years (1997-2002 and 2007-2011) and flow series for Ravi river having the same

catchment characteristics at diversion site of Bajoli Holi HEP.



Co-relation equation is developed between flow in Budhil River and Ravi River for the period

1997-2002 and 2007-2011 and co-relation curve is plotted and is shownin Figure-6.4.

Based on the co-relation studies between the concurrent period discharges, a regression

equation (y = 0.263*x + 8.451) is obtained. The co-relation study indicates a coefficient of

correlation ‘R’ of 0.84 between the two flow series. It is therefore interpreted that the flow data of

Budhil has a very good degree of co-relation with the flow series of Ravi River. Based on this

correlation equation, the gaps in flow series at Budhil River for the period 2002-2007 have been

filled and a long term flow series at G & D site near Thalla of Budhil River is derived for the

period 1972-2011. The long term flow series for Budhil River at G & D Site near Thalla is

presented in Annexure-6.5. The flow series at BHEP-I intake site has been transposed on the

basis of catchment area ratio of 0.935 and is presented in Annexure-6.6 (based on hydrological

year June - August).

Figure- 6.4: Correlation between Budhil & Ravi River

The long term series developed on the basis of Observed & regression analysis is available for a

period of 39 hydrological years. The same 39 years data has been used for the estimation of

dependable year and for further analysis is presented in Annexure-6.6.

6.5.7 Dependable Flows

The 50%, 75%, and 90% dependable year flow series is obtained from the 39 year flow series

for the period from 1972-73 to 2010-11 as presented in Table-6.5.



Table- 6.5: Calculation of Annual Dependability (1972-73 to 2010-11)

Rank Year Inflow (Mm3)

Weibull's Distribution

m/(n+1)

Dependability

(in %) 1 1975-76 951.53 0.03 2 1977-78 908.06 0.05 3 1978-79 905.00 0.08 4 2010-11 824.87 0.10 5 1976-77 823.77 0.13 6 2009-10 763.31 0.15 7 1973-74 732.80 0.18 8 2005-06 730.70 0.20 9 1972-73 723.25 0.23 10 1982-83 694.11 0.25 11 2001-02 692.54 0.28 12 1999-00 692.26 0.30 13 1974-75 688.30 0.33 14 2008-09 687.50 0.35 15 1981-82 686.70 0.38 16 1980-81 678.80 0.40 17 1979-80 678.63 0.43 18 1997-98 657.75 0.45 19 1998-99 649.26 0.48 20 1983-84 641.04 0.50 50% 21 2002-03 620.15 0.53 22 1989-90 611.53 0.55 23 2000-01 608.74 0.58 24 2003-04 599.06 0.60 25 1992-93 598.37 0.63 26 1987-88 587.04 0.65 27 1993-94 580.19 0.68 28 1984-85 570.06 0.70 29 1996-97 554.73 0.73 30 2006-07 543.08 0.75 75%

31 1985-86 542.08 0.78 32 1988-89 534.89 0.80 33 2007-08 522.78 0.83 34 1995-96 507.15 0.85 35 1986-87 502.18 0.88 36 1994-95 490.87 0.90 90%

37 2004-05 476.73 0.93 38 1991-92 442.24 0.95 39 1990-91 387.17 0.98



The annual discharge data for the year 1972-73 to 2010-11 (on 10-daily average basis) has

been arranged in descending order. The percentage probability of a flow magnitude being equal

or exceeded has been estimated by the Weibul’s formula. If ‘n’ numbers of data are used, the

plotting position of any discharge ‘Q’ is:

%100*1

n

mP

Where, m = order number of discharge

n = total number of data and

P = percentage probability of flow magnitude being equalled or exceeded

In order to estimate the 50%, 75% and 90% Dependable year, annual flows have been used

and as per above formula dependable years have been estimated. The 50%, 75% & 90%

dependable years flow series are presented in Table-6.6.

Table-6.6: 50%, 75% and 90% Dependable flow series at diversion site

Month Period

50% Dependable Year Discharge

(m3/s)


(m3/s)


(m3/s)

1983-84 2006-07 1994-95

Jun I 30.26 16.84 26.35 II 27.96 14.89 32.20 III 34.11 19.86 30.01

Jul I 52.74 30.91 40.11 II 51.14 33.74 48.12 III 57.63 40.07 33.64

Aug I 67.79 42.95 26.94 II 35.80 29.55 24.45 III 27.44 26.62 22.59

Sep I 24.51 23.17 21.72 II 22.02 15.50 23.24 III 34.11 12.33 16.76

Oct I 9.52 11.27 13.30 II 9.89 10.82 10.89 III 11.42 10.56 10.18

Nov I 13.56 10.26 8.94 II 12.62 9.92 8.23 III 10.69 9.79 7.94

Dec I 9.08 9.73 7.26 II 8.74 9.62 6.81 III 8.57 9.55 6.62

Jan I 6.22 7.60 6.45 II 6.00 6.99 6.18 III 5.73 7.60 5.97

Feb I 5.64 8.01 5.45 II 6.19 9.02 6.16 III 6.01 8.12 6.22

Mar I 7.52 10.73 6.06



Month Period


(m3/s)


(m3/s)


(m3/s)

1983-84 2006-07 1994-95 II 8.17 11.09 6.35 III 8.85 12.70 8.16

Apr I 10.45 20.18 8.45 II 11.24 22.54 9.23 III 19.35 23.81 10.76

August I 24.10 17.32 13.11 II 23.40 23.40 19.65 III 23.28 32.91 15.84

As per CBIP manual (2001) on planning design of Small Hydro Electric Schemes for projects

having installed capacity less than 25 MW, 75% dependable hydrological flow series is be

adopted for power potential study. The 75% annual dependability has been worked out to be

(2006-07) and is considered for power potential studies.

6.5.8 Flow Duration Curve

The stream flow varies over a year. A flow duration curve of a stream is a plot of (10- daily

average discharge) against the percent of time the flow was equalled or exceeded. This curve is

also known as discharge –frequency curve.

The entire yield series flow data (1972-73 to 2010-11) has been arranged in a descending order

to arrive at Flow Duration Curve for proposed diversion site.

If ‘n’ numbers of data are used, the plotting position of any discharge Q is given by:

%100*1

n

mP

Where, m=order number of discharge

n=total number of data and

P=percentage probability of flow magnitude being equalled or exceeded

Flow Duration curve has been presented in Figure-6.5



Figure-6.5: Flow Duration Curve for Proposed Diversion Site

6.6 DESIGN FLOOD

As per BIS code IS: 6966 (Part-1 -1989):- Hydraulic Design of Barrages and Weirs-

“For the purpose of design of components other than the free board, a design flood of 50- year

frequency August normally suffice. In such cases where risks and hazards are involved, a

review of this criteria based on this conditions August be necessary. For deciding the free board,

a minimum of 100- year frequency flood August be desirable”.

In this report, three methods have been used for estimating the design flood.

Empirical Method

Flood Frequency Analysis

Hydro-Meteorological Approach (Unit Hydrograph Application)

6.6.1 Empirical Method

Design flood at diversion site has been worked out based on the following empirical methods:

Dicken’s Empirical Formula

Fuller’s Formula

Dicken’s Empirical Formula

The Dicken’s formula is given as follows:

Design Flood Qf = C*A¾



Where,

Qf = Peak Discharge (m3/s)

C = Coefficient of Dicken’s formula and

A = Catchment area in km2

The coefficient ‘C’ is considered as 11.42 in North India.

Considering Rain fed area of Catchment = 210 km2

(Qf ) 50= 11.42× (229)¾ = 629.98 m3/s

Fullers’s Formula

Design flood with recurrence interval of 1 in 100 years can be worked out using Fuller’s formula

694.28 m3/s

6.6.2 Flood Frequency Analysis

The annual peak flow series at project site, i.e. at BHEP-I is not available. The instantaneous

annual peak flow series at Thalla G & D site from 1972 to 2000 (29 years) have been used by

catchment area proportion upto the BHEP-I Diversion site for the frequency analysis to estimate

the flood at various return period at project site. The flood peak discharges at BHEP-I diversion

site have been used in this DPR is extract from the approved DPR of Bharmour HEP (45 MW).

The frequency analysis studies have been carried out using the Gumbel’s standard theoretical

distribution by using the following formula and the diversion flood for different return periods are

given in Table-6.7.

1-T

TloglogBAY 1010T

Where, YT = Return Period Flood in m3/s

T = Return Period in Years

))50log(8.01(

))100log(8.01()Q()Q( 50f100f

log(50)).(

))log(.(.)Q( 100f 801

10080198629



Si.No. Year Annual Peak

Discharge

Annual Peak Discharge in

Descending Order Rank Probability x=log10log10(T/(T-1) X*Y X2

Y N T=(N+1)/M X

m3/s m3/s

1 1972 65.90 173.47 1 30.00 -1.83 -317.80 3.36

2 1973 61.38 144.85 2 15.00 -1.52 -220.67 2.32

3 1974 68.18 134.83 3 10.00 -1.34 -180.61 1.79

4 1975 106.31 120.31 4 7.50 -1.21 -145.16 1.46

5 1976 77.84 119.08 5 6.00 -1.10 -131.15 1.21

6 1977 81.80 113.18 6 5.00 -1.01 -114.72 1.03

7 1978 74.41 110.63 7 4.29 -0.94 -103.75 0.88

8 1979 73.06 106.31 8 3.75 -0.87 -92.56 0.76

9 1980 88.61 88.61 9 3.33 -0.81 -71.77 0.66

10 1981 59.01 81.80 10 3.00 -0.75 -61.70 0.57

11 1982 64.56 77.84 11 2.73 -0.70 -54.68 0.49

12 1983 63.21 74.41 12 2.50 -0.65 -48.66 0.43

13 1984 72.00 73.06 13 2.31 -0.61 -44.41 0.37

14 1985 119.08 72.00 14 2.14 -0.56 -40.60 0.32

15 1986 65.20 71.30 15 2.00 -0.52 -37.18 0.27

16 1987 55.23 68.18 16 1.88 -0.48 -32.74 0.23

17 1988 120.31 67.00 17 1.76 -0.44 -29.47 0.19

18 1989 37.55 65.90 18 1.67 -0.40 -26.37 0.16

19 1990 39.15 65.20 19 1.58 -0.36 -23.52 0.13

20 1991 56.04 64.56 20 1.50 -0.32 -20.75 0.10

21 1992 60.07 63.21 21 1.43 -0.28 -17.80 0.08

22 1993 110.63 61.38 22 1.36 -0.24 -14.80 0.06

23 1994 46.10 60.07 23 1.30 -0.20 -11.97 0.04

24 1995 134.83 59.01 24 1.25 -0.16 -9.18 0.02

25 1996 67.00 56.04 25 1.20 -0.11 -6.10 0.01

26 1997 173.47 55.23 26 1.15 -0.06 -3.20 0.00

27 1998 71.30 46.10 27 1.11 0.00 0.00 0.00

28 1999 144.85 39.15 28 1.07 0.07 2.76 0.00

29 2000 113.18 37.55 29 1.03 0.17 6.36 0.03

Total 2370.26 2370.26 118.85 -17.25 -

1852.20 16.98

Average 81.73 81.73 4.10 -0.59 -63.87 0.59

73.8129

2370.26

N

YY 59.0

29

17.25-

N

XX

91.65))59.0(29-(16.98

81.73)-0.59(29-1852.20-

)XN()X(

)YN(X)(-XY)(B

222

84.42)X(B)Y( A



Line of Best Fit YT= 42.84-65.91×(log10log10(T/(T-1))

Table-6.7 Diversion Flood for Different Return Periods

Return Period (T)

x=log10log10(T/(T-1) Max. Flood YT

Instantaneous Flood (1.15×YT)

10 -1.34 131.13 150.80

25 -1.75 158.27 182.01

50 -2.06 178.40 205.16

100 -2.36 198.39 228.15

500 -3.06 244.57 281.26

6.6.3 Hydro Meteorological Approach

Derivation of Synthetic Unit Hydro Graph by Western Himalayas (Subzone-7) Report

In the absence of short period rainfall and discharge data of monsoon period, a Synthetic Unit

Hydrograph is derived based on recommendation given in “Flood Estimation report for Western

Himalayas Sub-Zone 7” published by the Central Water Commission and the parameters of the

Unit Hydrograph are given below.

Total catchment Area = 471 km2

Snow Fed Area = 261 km2

Rain fed Catchment Area = 210 km2

Max. Length of river (L) = 32.85 km

Length of longest main stream from centroid of C.A. (Lc) = 12.00 km

Equivalent Slope = 75.07 m/km

The parameters of Synthetic Unit Hydrograph have been presented in Table-6.8.

Table-6.8: Parameters of Synthetic Unit Hydrograph

tp 2.498*(L*Lc/S)0.156 3.24 Hrs.

tm (tp +0.5) 3.74 Hrs. say 4 hours

qp 1.048*(tp)-0.178 0.85 m3/s/km2

W50 1.954*(L*Lc/S)0.099 2.30 Hrs.

W75 0.972*(L*Lc/S)0.124 1.19 Hrs.

WR50 0.189*(W50)1.769 0.82 Hrs.

WR75 0.419*(W75)1.246 0.52 Hrs.

TB 7.845*(tp )0.453 13.36 Hrs

QP qp *A 178.57 m3/s

Where

tp = Time from the centre of effective rainfall duration to the U.G.peak.

tr = Unit rainfall duration



tm = time from the start of rise to the peak of U.G.

qp = Discharge per unit area (Cumecs)

W50 = Width of U.G. measured at 50% of peak discharge ordinate (Hr)

W75= Width of U. G. measured at 75% 0f peak discharge ordinate

TB = Base width of Unit Hydrograph (Hr)

Qp = Peak Discharge of Unit Hydrograph (Cumecs)

A = Rain fed Catchment Area

On the basis of above parameters, a synthetic unit hydrograph has been derived, the ordinate of

Synthetic Unit hydrograph is given in Table-6.9 and Unit hydrograph has been shown in Figure-

6.6.

Fig. 6.6: Synthetic Unit Hydrograph

Table-6.9: Ordinates of Synthetic Unit Hydrograph

Time (Hrs.) Unit Hydrograph Ordinates (m3/s)

Time (Hrs.) Unit Hydrograph Ordinates (m3/s)

0 0 7 31 1 21.1 8 21.3 2 50.1 9 13 3 99.6 10 9.5 4 178.5 11 5.5 5 101.1 12 2.5 6 50.1 13 0



Storm Value

24 Hour 50- Year R.P. Storm value has been obtained from the Isohyetal map prepared by IMD

and enclosed in “Flood Estimation report for Western Himalayas- Zone7”.

24- Hour 50 Year R.P. Point Storm value = 27 cm

It is pertinent to mention that unit hydrograph has a time base of 13 hours, (Tb=13 hrs),

therefore, 24-hr, 50 year Areal rainfall has been converted in to 3-hour with a conversion factor

of 0.65.

50 Year 4 Hr. Point Rainfall = 0.65x27 =17.55 cm

Areal Reduction factor = 0.87 (Corresponding to catchment area of 210 km2)

4-hrs 50-year R.P areal catchment rainfall value = 0.87x17.55 = 15.27 cm

Temporal Distribution of Storm

24- Hour temporal distribution of the storm has been given by IMD. The 24 hr Storm has been

converted in to 4-hours distribution of storm as time base of unit hydrograph is 4-hours which

has been presented in Table-6.10.

Table-6.10: 4-hrs Temporal Distribution of Storm

Time (Hrs.) Storm Distribution in percentage

1 62

2 82

3 94

4 100

Design Loss Rate

As per “Flood Estimation report for Western Himalayas –Zone 7”design loss rate has been

considered 0.1 cm/hr for this catchment.

Rainfall Excess Blocks

Rainfall excess (Effective rainfall) blocks for S.P.S. (Standard Project Storm), 50-year R.P. areal

Storm has been presented in Table-6.11.

Table-6.11: Rainfall Excess Block

Duration Distribution Coefficient

Storm Rainfall

Rainfall Increments

Loss Effective Rainfall Increments

cm cm cm cm/hr 1 0.62 9.47 9.47 0.1 9.37

2 0.82 12.52 3.05 0.1 2.95

3 0.94 14.35 1.83 0.1 1.73

4 1.00 15.27 0.92 0.1 0.82



Base Flow

Base flow in this catchment has been considered as 10.5 m3/s (0.05 m3/s /km2) based on “Flood

Estimation report for Western Himalayas- Zone 7”.

Computation of Flood Peak

Total Direct Run-off = 2083.29 m3/s

Base Flow = 10.5 m3/s

Total Flood Peak = 2083.29 + 10.5 = 2093.79 m3/s ≈ 2100 m3/s

Table-6.12: Estimation of Flood Peak

Duration U.G Ordinates

1-hr Effective Rainfall

Direct Run-off

4 178.50 9.37 1672.55 5 101.15 2.95 298.39 6 50.20 1.73 86.85 7 31.10 0.82 25.50

Total 2083.29

Design Flood Hydro Graph

The effective rainfall increment of 50-Year flood peak is reserved to obtain critical sequence and

is shown in following table.

Time Critical Effective

1-hr Sequence

1 0.82 2 1.73 3 2.95 4 9.37

50-Year R.P. flood hydrograph has been presented Figure 6.7 and its ordinates in

Table-6.13.

Table-6.13: Standard Project Flood at Bharmour Stage-I HEP Diversion Site

Time Ordinates of SUG

Rainfall Excess ‘cm’ Direct Run-off

Base Flow

Tota Flow

hr m3/s 1 2 3 4 m3/s m3/s m3/s

0.82 1.73 2.95 9.37 0 0.00 0.00 0.00 10.50 10.501 21.10 17.30 0.00 17.30 10.50 27.802 50.10 41.08 36.50 0.00 77.59 10.50 88.093 99.60 81.67 86.67 62.25 0.00 230.59 10.50 241.094 178.50 146.37 172.31 147.80 197.71 664.18 10.50 674.685 101.10 82.90 308.81 293.82 469.44 1154.96 10.50 1165.466 50.10 41.08 174.90 526.58 933.25 1675.81 10.50 1686.317 31.00 25.42 86.67 298.25 1672.55 2082.88 10.50 2093.388 21.30 17.47 53.63 147.80 947.31 1166.20 10.50 1176.70



Time Ordinates of SUG

Rainfall Excess ‘cm’ Direct Run-off

Base Flow

Tota Flow

hr m3/s 1 2 3 4 m3/s m3/s m3/s

0.82 1.73 2.95 9.37 9 13.00 10.66 36.85 91.45 469.44 608.40 10.50 618.9010 9.50 7.79 22.49 62.84 290.47 383.59 10.50 394.0911 5.50 4.51 16.44 38.35 199.58 258.88 10.50 269.3812 2.50 2.05 9.52 28.03 121.81 161.40 10.50 171.9013 0.00 0.00 4.33 16.23 89.02 109.57 10.50 120.0714 0.00 7.38 51.54 58.91 10.50 69.4115 0.00 23.43 23.43 10.50 33.9316 0.00 0.00 10.50 10.50

Figure-6.7: 50- Year Return Period Flood

6.6.4 Recommendations

Keeping in view the various alternatives studied for the estimation of design flood at proposed

diversion site of Bharmour Stage Stage-I HEP, the design flood for a return period of 50 year

varies from 630 m3/s to 2100 m3/s which is wide range. Hence design flood of 2100 m3/s is

recommended for the design of structure. The design flood of varies return periods are

summurized in the following Table-6.14.



Table-6.14: The Design Flood

Return Period Design Flood

25 1890 50 2100 100 2323 500 2830

6.7 SEDIMENT LOAD

This stream carries significant sediment load in summer and monsoon. During winter, water is

quite clear and free from all kind of impurities. The streambed is characterized by accumulation

of boulders of different sizes along the course of the stream. The sizes of such boulders vary

from small pebbles to big boulders of size upto 3 m in diameter.

BHEP-I is a small hydro power project designed to operate as a pure Run-off the River project.

No pondage is proposed for peak power generation. In view of this, and as per current CWC

recommendations, detailed sedimentation study is not required for a project of this size.

6.8 CONCLUSION AND RECOMMENDATIONS

The water availability series for Budhil nallah at BHEP-I Diversion site have been developed for

the period 1972-2011 on the basis of regression analysis with the long term average discharge

of Budhil River. The 39 years data series (1972-73 to 2010-11) have been used for power

potential study. The 75% annual dependability has been derived for the power potential study.

A design flood of 2100 m3/s is recommended based on unit hydrograph approach. The

proposed Hydro Electric Project is a runoff-the-river scheme without any storage and

accordingly sedimentation studies are not required.



Annexure-6.1 Observed 10-daily Average Discharge Data of Budhil Nallah near Thalla G&D Site

Total Catchment Area = 524 km2 Snow Fed Area = 200 km2 Rain Fed Area = 324 km2 Unit: Cumecs

Month Period 1972-73 1973-74 1974-75 1975-76 1976-77 1977-78 1978-79 1979-80 1980-81 1981-82 1982-83 1983-84 1984-85 1985-86 1986-87 1987-88 1988-89 1989-90

Jun

I 38.61 40.96 26.56 47.36 38.24 35.17 57.58 35.63 27.81 28.78 40.51 33.67 35.10 25.53 20.78 34.90 34.93 31.70

II 38.24 52.72 37.03 48.06 41.27 39.63 54.35 48.29 35.56 31.15 47.67 31.11 39.49 25.90 34.50 39.30 39.31 33.59

III 42.13 52.78 38.70 55.82 41.96 60.29 63.91 70.47 44.95 42.93 41.40 37.95 38.25 27.09 42.21 38.10 38.07 49.87

Jul

I 53.61 53.47 45.12 55.81 45.79 72.24 66.89 63.13 50.73 43.19 50.03 58.68 43.65 30.10 35.36 43.40 43.43 44.34

II 58.87 52.89 58.60 61.56 52.26 76.44 67.72 62.18 66.77 54.83 56.88 56.90 40.88 50.49 31.76 40.70 40.68 54.24

III 52.01 51.17 55.70 78.20 54.70 65.68 63.12 57.80 62.26 62.09 60.85 64.12 46.98 48.23 38.85 46.80 46.75 63.42

Aug

I 47.65 54.47 54.92 68.28 64.81 73.81 59.50 58.83 63.00 54.81 61.09 75.42 38.53 48.10 33.54 38.30 38.34 75.47

II 48.21 60.53 53.95 66.22 64.71 62.28 63.59 57.03 56.66 51.26 54.38 39.83 26.16 38.41 40.03 26.00 26.03 39.86

III 45.00 56.44 49.04 71.60 66.32 49.46 52.84 47.64 39.47 41.50 41.18 30.53 58.92 30.25 23.60 36.10 36.06 30.56

Sep

I 36.56 51.22 39.44 56.92 67.12 46.71 33.63 38.69 34.05 32.50 37.91 27.27 55.71 26.76 20.78 31.20 31.20 27.29

II 29.02 45.78 31.00 56.27 60.41 45.91 28.96 30.00 29.17 23.66 34.88 24.50 37.49 19.91 17.04 22.90 22.89 24.53

III 25.71 38.98 26.00 47.79 50.21 40.58 25.01 22.73 24.65 19.49 31.09 37.95 26.41 18.60 17.28 19.90 19.86 37.99

Oct

I 23.96 29.20 18.89 37.72 42.27 37.27 21.15 19.31 21.26 16.18 26.59 10.59 20.28 17.19 14.66 16.20 16.15 10.60

II 22.13 22.67 16.22 34.10 37.25 34.66 18.25 15.57 18.50 13.90 20.28 11.00 14.14 14.75 12.92 13.50 13.50 11.00

III 20.25 17.78 15.08 31.03 28.35 28.87 16.54 13.03 16.35 12.23 15.57 12.70 11.41 11.41 10.88 11.50 11.52 12.71

Nov

I 17.31 14.62 12.30 29.14 24.42 25.17 115.12 10.76 13.69 11.75 12.88 15.09 9.34 10.61 9.65 10.20 10.23 15.12

II 14.97 13.87 10.58 27.35 22.31 23.31 13.68 9.64 11.93 10.25 9.46 14.04 8.72 9.32 9.00 9.40 9.36 14.05

III 13.19 12.95 8.83 23.13 15.25 21.24 12.89 9.05 10.51 9.51 8.29 11.89 8.32 8.16 8.99 8.80 8.75 11.90

Dec

I 10.88 11.09 9.63 20.94 13.68 15.81 12.59 8.41 10.14 8.98 7.86 10.10 7.91 7.81 8.83 7.90 7.88 10.12

II 9.50 9.44 9.85 18.37 12.26 14.10 11.02 8.06 9.10 8.60 10.31 9.72 7.42 7.86 8.29 7.00 7.04 9.73

III 8.14 8.45 8.50 16.33 10.72 13.25 9.69 7.77 7.91 7.85 8.00 9.53 6.87 8.06 7.35 6.80 6.76 9.54

Jan

I 7.20 7.64 8.54 14.27 9.90 11.08 8.47 7.38 7.57 7.69 6.88 6.92 6.71 7.97 6.89 6.60 8.36 5.45

II 7.81 7.09 7.74 13.32 9.71 10.84 8.22 7.15 7.25 7.45 6.88 6.68 6.19 8.14 6.66 6.69 7.43 5.12

III 7.81 7.20 7.30 11.99 10.26 10.34 8.93 7.26 7.09 7.65 7.26 6.37 5.82 7.86 6.33 6.70 7.04 4.91

Feb

I 7.33 7.41 8.07 12.26 10.12 9.53 9.18 7.49 7.59 8.56 6.02 6.28 5.46 7.79 6.26 6.52 6.69 4.84

II 7.84 7.60 8.41 12.94 10.89 9.58 9.79 7.89 8.47 9.38 5.45 6.89 5.08 7.95 6.85 6.13 6.37 5.19

III 8.54 8.00 8.25 13.04 11.11 9.90 9.78 7.84 10.68 10.16 6.16 6.69 4.77 8.17 7.49 7.38 6.87 5.67

Mar

I 8.63 8.01 9.53 13.36 9.24 10.76 13.87 8.23 11.28 12.78 7.29 8.37 5.13 7.96 8.33 10.50 7.36 5.88

II 9.81 8.40 10.65 13.80 9.40 11.45 13.55 8.34 12.08 14.81 8.37 9.09 5.83 10.61 9.04 13.28 7.62 7.25

III 14.23 10.63 12.21 15.38 9.24 11.27 14.39 9.24 12.88 18.02 10.37 9.85 7.49 11.12 9.80 13.56 8.63 9.36

Apr

I 18.14 12.36 15.16 17.30 11.94 11.94 22.35 11.30 14.86 23.50 13.74 11.63 7.85 12.75 11.59 18.01 10.19 10.78

II 23.03 13.55 17.64 18.18 12.55 16.01 25.78 14.00 16.81 25.14 15.76 12.50 10.71 20.28 12.44 27.14 11.13 12.47

III 32.50 16.06 25.69 19.28 14.27 23.18 30.94 16.30 18.91 31.68 21.19 21.53 14.20 23.30 21.42 25.15 13.34 14.27

August

I 38.07 18.83 32.25 22.89 18.25 35.03 36.26 18.37 22.04 36.50 26.46 26.81 14.80 24.16 26.68 26.67 18.88 18.02

II 35.63 20.89 34.91 26.53 20.80 40.34 34.33 18.19 23.30 34.92 31.60 26.03 16.37 24.57 25.91 30.69 23.06 25.06

III 36.01 25.51 41.85 31.91 24.21 50.11 35.49 18.86 26.80 38.43 30.99 25.90 25.59 21.28 25.78 31.62 27.61 24.75

Average Yearly 25.51 25.85 24.28 33.57 29.06 32.03 31.93 23.94 23.95 24.23 24.49 22.61 20.11 19.12 17.72 20.71 18.87 21.57

Inflow (Mm3) 804.63 815.26 765.75 1058.60 916.47 1010.24 1006.84 754.99 755.18 763.97 772.22 713.18 634.21 603.08 558.69 653.09 595.08 680.35



Annexure-6.1 Observed 10-daily Average Discharge Data of Budhil Nallah near Thalla G&D Site

Total Catchment Area = 524 km2 Snow Fed Area = 200 km2 Rain Fed Area = 324 km2 Unit: Cumecs

Month Period 1990-91 1991-92 1992-93 1993-94 1994-95 1995-96 1996-97 1997-98 1998-99 1999-00 2000-01 2001-02 2007-08 2008-09 2009-10 2010-11

Jun

I 34.14 21.47 35.47 26.94 29.31 23.52 30.39 30.34 18.03 37.54 26.30 35.50 25.25 43.91 42.21 46.62

II 19.66 18.94 38.95 37.66 35.82 22.77 31.66 55.88 24.51 37.81 40.61 38.73 32.70 51.11 38.61 66.71

III 16.82 34.75 47.35 46.28 33.39 35.37 23.41 47.00 33.39 38.17 40.34 41.83 33.49 35.43 51.85 69.12

Jul

I 17.03 37.15 53.18 46.79 44.62 40.05 25.54 29.74 37.73 53.55 45.20 43.59 32.26 61.85 53.99 74.13

II 30.47 32.92 43.89 51.08 53.53 39.43 24.93 30.31 45.72 46.98 54.34 56.35 23.89 58.61 74.16 66.85

III 27.98 25.03 51.09 61.84 37.43 39.59 55.39 34.63 47.94 35.10 50.76 48.95 30.92 54.72 78.56 62.86

Aug

I 21.18 23.21 50.10 58.59 29.97 35.87 35.95 39.61 61.56 32.88 43.13 61.17 34.45 62.34 64.81 62.07

II 14.05 22.22 37.23 51.88 27.20 32.04 26.05 41.11 44.83 38.63 29.97 45.57 27.91 62.26 63.23 61.34

III 16.73 18.43 36.46 41.21 25.13 27.10 26.31 43.88 41.81 31.77 25.70 40.62 31.43 55.26 47.84 62.29

Sep

I 12.74 18.95 31.94 26.94 24.16 22.04 25.05 36.77 28.07 22.32 36.06 26.52 42.77 28.71 56.82 41.18

II 11.06 19.17 29.45 20.34 25.86 19.24 62.19 21.71 29.13 28.82 20.44 32.20 30.59 27.99 33.18 29.09

III 9.92 16.32 22.72 16.70 18.65 16.28 21.80 17.72 23.69 32.45 20.17 27.50 26.74 22.85 30.63 23.73

Oct

I 8.02 12.71 16.91 14.88 14.80 14.16 32.69 34.82 37.22 36.76 34.99 42.38 13.47 18.74 24.91 19.48

II 7.40 11.00 14.10 12.99 12.12 12.51 18.01 16.25 18.55 26.44 17.43 23.91 12.07 15.30 18.05 14.36

III 7.39 10.60 11.93 10.83 11.33 10.90 17.27 14.57 16.30 26.32 16.03 21.64 11.15 12.99 14.06 12.97

Nov

I 7.00 10.37 10.27 9.79 9.95 10.03 16.79 13.33 14.19 20.47 14.49 19.70 10.78 11.75 13.51 11.83

II 6.76 9.59 9.59 8.74 9.16 9.63 15.80 12.36 12.23 17.85 12.90 18.74 9.65 10.83 14.58 10.86

III 6.22 9.27 9.06 8.22 8.83 9.00 15.19 11.48 10.76 16.28 12.44 17.94 9.19 10.14 12.08 10.03

Dec

I 5.80 8.66 8.72 7.69 8.08 8.10 14.20 10.66 10.60 15.04 11.79 15.96 9.41 9.77 11.19 9.75

II 5.06 8.10 8.31 7.38 7.58 7.78 13.25 9.83 10.42 13.83 10.60 14.14 9.93 9.07 10.31 8.92

III 5.60 7.71 7.55 7.12 7.37 7.68 12.31 9.25 10.64 12.82 10.14 13.24 9.46 8.55 9.53 8.68

Jan

I 7.69 7.29 7.00 7.15 7.18 10.89 9.03 9.66 11.93 9.71 12.45 8.29 9.27 8.25 8.97 10.96

II 7.19 7.25 6.81 6.94 6.88 10.12 8.67 8.84 11.31 9.52 11.39 7.95 9.09 8.09 8.29 10.17

III 6.93 7.21 6.59 6.54 6.64 9.03 8.24 7.87 10.68 9.69 10.01 7.74 8.75 7.81 7.95 9.98

Feb

I 7.05 7.11 6.46 6.57 6.06 8.77 8.45 7.30 10.57 9.16 9.33 7.38 8.28 7.71 8.83 11.44

II 7.38 8.28 6.44 6.66 6.85 8.78 7.70 7.06 10.41 9.78 8.55 7.46 7.55 7.71 9.26 13.15

III 8.35 8.20 6.54 7.20 6.92 9.07 8.31 9.70 10.65 9.70 8.86 7.78 5.08 7.72 8.30 12.53

Mar

I 9.06 8.41 6.74 7.34 6.74 10.28 9.00 10.92 11.72 10.29 8.66 8.27 8.53 8.15 9.45 13.50

II 9.31 9.06 7.88 8.67 7.06 12.72 9.03 14.29 11.34 10.95 8.82 9.18 9.98 8.34 9.99 14.62

III 11.22 10.83 8.82 9.29 9.08 13.39 9.31 20.20 11.65 13.86 10.31 10.84 10.31 9.80 10.36 15.58

Apr

I 15.23 12.51 10.01 12.05 9.40 15.03 10.67 22.16 13.88 16.46 12.12 11.02 11.06 12.78 11.10 16.64

II 16.18 14.16 14.41 10.38 10.27 21.31 11.69 22.16 16.62 19.72 13.28 12.77 12.82 14.56 13.40 23.43

III 19.97 17.15 20.47 12.53 11.97 17.73 14.27 31.41 23.56 19.92 18.77 15.78 15.26 16.66 15.37 24.17

August

I 21.92 19.07 25.07 18.96 14.59 17.72 15.40 32.50 25.34 26.52 20.55 16.55 20.15 18.40 21.96 23.77

II 25.29 23.34 22.47 18.96 21.86 16.89 14.55 31.34 27.73 42.74 24.28 30.35 25.10 26.95 25.65 44.60

III 27.91 25.21 29.95 23.72 17.62 19.26 16.01 38.69 39.86 39.32 21.89 31.99 35.19 38.02 36.42 30.18

Average Yearly 13.66 15.60 21.11 20.47 17.32 17.89 19.57 23.20 22.90 24.42 21.48 24.43 18.44 24.25 26.93 29.10

Inflow (Mm3) 430.74 492.01 665.70 645.48 546.11 564.21 617.15 731.77 722.32 770.15 677.24 770.47 581.60 764.86 849.20 917.69



Annexure-6.2 10-daily Average Discharge Data of Ravi River at Bajoli Holi HEP

Catchment Area = 902 km2 Snow Fed Area = 372 km2 Rain Fed Area = 530 km2 Unit: Cumecs Month Period 1996-97 1997-98 1998-99 1999-00 2000-01 2001-02 2002-03 2003-04 2004-05 2005-06 2006-07 2007-08 2008-09 2009-10

Jun

I 121.80 77.20 98.10 46.20 115.20 144.40 92.30 167.90 60.30 68.30 39.10 79.30 96.60 108.80

II 144.90 120.20 124.90 74.70 114.50 150.40 90.00 176.00 69.50 96.90 30.58 221.20 102.70 87.80

III 138.30 148.50 104.70 91.00 131.40 145.10 89.00 159.00 53.70 230.70 51.90 302.90 80.20 128.30

Jul

I 101.60 167.60 123.30 105.70 117.70 168.10 108.20 121.40 56.30 340.50 98.70 251.90 117.60 134.20

II 105.10 176.80 150.90 138.00 139.90 162.50 77.90 76.50 51.90 260.60 110.70 159.20 102.40 164.90

III 116.20 178.00 153.00 155.00 130.20 158.70 67.50 76.10 44.60 211.10 137.50 97.70 96.30 147.60

Aug

I 125.30 214.40 112.70 159.30 140.20 129.80 56.90 69.10 59.60 186.60 149.70 97.20 93.10 128.90

II 118.60 108.40 95.90 136.80 135.50 143.40 95.60 74.60 40.40 160.30 92.90 104.00 128.20 126.60

III 143.00 110.80 86.40 76.30 109.50 133.90 51.40 66.80 89.10 126.20 80.50 49.60 92.60 104.00

Sep

I 112.60 88.20 64.50 53.10 78.20 63.90 72.00 67.60 31.70 114.40 65.90 26.80 76.20 111.40

II 89.60 74.20 67.00 47.70 57.80 42.10 128.90 60.80 32.30 117.30 33.40 16.40 73.90 89.50

III 59.20 51.90 119.90 44.30 48.50 34.20 56.70 49.00 19.60 72.40 20.00 13.90 58.70 67.00

Oct

I 35.50 30.10 55.90 35.30 39.70 27.00 40.20 41.30 30.50 47.70 15.50 10.90 48.50 52.90

II 23.60 21.20 83.70 32.40 34.90 20.20 34.20 34.80 22.70 38.90 13.60 10.40 44.00 52.10

III 20.40 16.00 42.00 27.20 33.20 17.90 25.40 29.40 15.30 25.70 12.50 9.00 41.60 42.50

Nov

I 19.20 13.40 20.60 24.40 29.10 15.50 18.90 24.90 13.70 19.80 11.20 8.70 31.40 27.60

II 19.80 12.70 17.10 22.50 24.70 13.80 15.70 18.20 13.20 11.50 9.80 8.10 27.40 30.40

III 19.40 12.20 14.80 19.50 20.80 11.60 12.30 14.10 12.70 9.60 9.20 7.90 21.50 33.20

Dec

I 17.30 12.10 13.90 18.00 15.80 10.90 10.30 11.80 11.70 8.90 9.00 7.60 21.50 27.60

II 16.40 14.40 12.70 16.30 14.40 10.50 9.00 8.80 11.00 8.20 8.50 7.90 20.80 32.00

III 13.50 11.40 10.80 14.30 12.60 10.00 8.10 7.70 10.90 7.90 8.20 7.60 20.50 35.70

Jan

I 14.51 10.50 10.20 13.10 11.00 9.70 7.20 8.80 11.60 8.80 8.10 8.00 16.30 37.50

II 14.04 9.80 10.00 12.20 9.70 9.30 7.00 8.00 9.80 8.30 7.70 9.50 13.60 34.32

III 13.71 9.30 10.20 11.80 8.80 8.90 6.80 8.50 10.60 8.00 7.70 8.30 12.60 27.81

Feb

I 13.24 12.60 10.00 12.60 8.50 8.50 7.30 8.70 9.90 8.10 7.90 7.60 10.50 34.40

II 12.91 17.80 9.70 12.40 10.70 8.40 10.00 8.50 11.90 8.50 8.60 8.00 10.30 27.13

III 13.98 17.10 9.90 12.20 11.10 8.90 11.80 12.40 10.10 9.10 9.80 10.00 7.40 12.11

Mar

I 15.37 23.00 11.80 12.60 11.90 12.00 16.20 15.20 13.80 9.70 12.70 13.20 10.20 17.85

II 16.53 24.80 11.80 12.60 12.50 16.20 15.70 23.70 20.40 11.40 19.70 13.10 10.20 20.71

III 17.93 29.10 16.40 13.70 13.30 21.20 21.20 22.90 22.80 13.10 23.50 9.70 12.80 26.74

Apr

I 22.14 36.10 19.50 17.10 16.70 32.00 33.00 24.90 21.10 8.80 22.40 8.80 18.60 32.77

II 23.21 39.50 24.80 26.50 62.90 44.20 55.50 34.10 23.70 8.30 26.30 15.60 22.50 30.87

III 35.17 59.60 52.60 41.80 53.80 93.10 79.90 37.20 41.80 8.00 41.00 18.40 29.90 34.26

August

I 56.38 69.10 59.00 70.40 74.60 95.80 98.70 38.10 63.10 22.00 62.00 65.30 41.70 48.02

II 31.87 72.60 60.20 154.30 102.40 98.80 126.10 65.20 62.10 33.20 91.30 86.60 70.60 62.37

III 53.41 100.30 84.30 123.80 131.90 98.50 126.90 64.10 61.10 43.90 85.50 92.00 101.10 81.81

Average Yearly 53.21 60.86 54.81 52.36 57.88 60.54 49.55 48.23 31.79 65.91 40.07 52.01 49.56 62.82

Inflow (Mm3) 1678.15 1919.23 1728.52 1651.35 1825.23 1909.15 1562.61 1520.82 1002.58 2078.49 1263.70 1640.13 1562.78 1981.22



Annexure-6.3 Annual Rainfall Recorded at Twelve Raingauge Stations in Chamba District

Unit: mm Rain Gauge Station No.

1961 1962 1963 1964 1965 1966 1967 1968 1969 1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989

1 1295.7 1197.0 1071.6 1326.7 1273.0 534.5 1338.9 964.0 963.2 1028.5 1175.6 977.4 1311.1

589.0 1069.1 1213.3 1256.2 1494.6 989.0 737.0 717.0 1391.8 1292.8 2178.8 1130.4 1340.9 1798.1 787.2

2 1047.2 977.7 963.6 1273.9 891.2 291.4 864.5 377.8 570.1 893.4 381.0 709.4 1558.1 1106.3 953.5 1598.4 1925.5

438.7

656.0 363.8 339.0 960.8 596.2

3 1233.1 1134.9 1471.8 1733.4 1600.7 674.6 2073.2 1309.2 1108.3 1046.0 1603.1 1224.8 2261.0 2240.5 2488.5 1036.3 1030.5 1301.5 696.5 1240.5 346.5 673.5 713.7 280.2 518.1 184.8 360.0

4 3529.3 1835.1 2357.4 2148.4 1768.6 285.3 2009.6 1653.1 1664.7 1792.1 1345.8 1490.6 1848.6 2378.1 2657.4 1614.0 1809.8 1561.4 2439.5

635.5 2407.2 1598.1 2209.1 1783.8 2635.9

5 1908.9 1450.3 1635.5 1752.0 1524.1 371.5 885.3 379.1 582.0 550.2 173.3 64.8 441.6 1175.2 1361.6 1144.9 831.2 148.5 1003.1 787.3

6 2774.3 2335.2 2746.6 2719.4 1949.8 295.4 1684.2 1076.8 1839.5 2035.3 1447.6 1630.1 2057.5 1885.4 1781.0 2061.2 836.9 674.1 1853.1 446.6 1139.3 986.4 606.0

271.0 368.0 3118.6 1122.8 2391.0

7 1354.4 1244.3 1261.1 1602.7 1106.2 280.0 632.6 567.3 924.3 506.2 846.2 812.3 1165.0 922.5 976.0 1196.0 497.0 598.5 388.1 589.8 307.3

258.8 345.5 1501.9 623.5 793.4 1525.4 1267.0

8 1280.1 846.8 999.8 1587.6 1360.8 533.1 1311.5 690.1 948.4 775.4 292.0 557.6 1417.5 1540.0 880.8 985.9 977.9 814.3 1335.4 1030.4 677.4 903.0 1552.1 1230.3 2097.3 1616.9 1751.3 1367.2 1095.8

9 1242.3 1150.8 989.3 1123.3 1068.6 366.9 865.1 720.5 809.0 590.8 527.8 869.2 1476.0 1936.3 1660.3 1246.7 1156.0 850.8 1063.0 1249.5 677.3 624.0 892.0 954.6 1917.3 631.8

10 567.0 968.2 853.0 1375.5 1131.2 208.1 297.5 209.0 597.5 377.1 631.2 784.1 1546.0 1540.4 1160.0 1033.2 809.2 587.5 800.1 715.2 304.4 489.0 932.0 636.4 1461.0 978.0

11

1064.7 1471.8 1169.7 886.1 875.2 1449.2 881.0 2028.7 813.0 1279.0 775.1 456.1

Average 1623.2 1314.0 1435.0 1664.3 1367.4 384.1 1196.2 794.7 1000.7 959.5 842.4 912.0 1508.2 1636.1 1450.8 1298.6 1108.7 885.8 1254.5 913.1 634.4 713.4 974.5 768.0 1474.5 828.4 1476.6 1281.2 1438.8



Annexure-6.4 Observed 10-daily Average Runoff Depth of Budhil Nallah Upto Thalla G&D Site

Total Catchment Area = 524 km2 Snow Fed Area = 200 km2 Rain Fed Area = 324 km2 Unit: mm

Month Period 1972-73 1973-74 1974-75 1975-76 1976-77 1977-78 1978-79 1979-80 1980-81 1981-82 1982-83 1983-84 1984-85 1985-86 1986-87 1987-88 1988-89 1989-90

Jun

I 63.66 67.54 43.79 78.09 63.05 57.99 94.94 58.75 45.85 47.45 66.80 55.52 57.87 42.10 34.26 57.55 57.59 52.27

II 63.05 86.93 61.06 79.24 68.05 65.34 89.62 79.62 58.63 51.36 78.60 51.30 65.11 42.71 56.89 64.80 64.82 55.39

III 69.47 87.03 63.81 92.04 69.19 99.41 105.38 116.19 74.12 70.79 68.26 62.57 63.07 44.67 69.60 62.82 62.77 82.23

Jul

I 88.40 88.16 74.40 92.02 75.50 119.11 110.29 104.09 83.65 71.21 82.49 96.75 71.97 49.63 58.30 71.56 71.61 73.11

II 97.07 87.21 96.62 101.50 86.17 126.04 111.66 102.53 110.09 90.41 93.79 93.82 67.41 83.25 52.37 67.11 67.08 89.43

III 94.33 92.81 101.03 141.83 99.21 119.13 114.48 104.83 112.92 112.62 110.37 116.30 85.21 87.48 70.46 84.88 84.79 115.03

Aug

I 78.57 89.81 90.56 112.58 106.86 121.70 98.11 97.00 103.88 90.37 100.73 124.36 63.53 79.31 55.30 63.15 63.22 124.44

II 79.49 99.81 88.96 109.19 106.70 102.69 104.85 94.03 93.42 84.52 89.66 65.67 43.13 63.33 66.00 42.87 42.92 65.72

III 81.62 102.37 88.95 129.86 120.29 89.71 95.84 86.41 71.59 75.27 74.69 55.37 106.87 54.87 42.80 65.48 65.40 55.43

Sep

I 60.28 84.45 65.03 93.85 110.67 77.02 55.45 63.79 56.14 53.59 62.51 44.96 91.86 44.12 34.26 51.44 51.44 45.00

II 47.85 75.48 51.11 92.78 99.61 75.70 47.75 49.47 48.10 39.01 57.51 40.40 61.82 32.83 28.10 37.76 37.74 40.45

III 42.39 64.27 42.87 78.80 82.79 66.91 41.24 37.48 40.64 32.14 51.26 62.57 43.55 30.67 28.49 32.81 32.75 62.64

Oct

I 39.51 48.15 31.15 62.19 69.70 61.45 34.87 31.84 35.05 26.68 43.84 17.46 33.44 28.34 24.17 26.71 26.63 17.48

II 36.49 37.38 26.74 56.23 61.42 57.15 30.09 25.67 30.50 22.92 33.44 18.14 23.31 24.32 21.30 22.26 22.26 18.14

III 36.73 32.25 27.35 56.28 51.42 52.36 30.00 23.63 29.65 22.18 28.24 23.03 20.69 20.69 19.73 20.86 20.89 23.05

Nov

I 28.54 24.11 20.28 48.05 40.27 41.50 189.82 17.74 22.57 19.37 21.24 24.88 15.40 17.49 15.91 16.82 16.87 24.93

II 24.68 22.87 17.44 45.10 36.79 38.43 22.56 15.89 19.67 16.90 15.60 23.15 14.38 15.37 14.84 15.50 15.43 23.17

III 21.75 21.35 14.56 38.14 25.15 35.02 21.25 14.92 17.33 15.68 13.67 19.60 13.72 13.45 14.82 14.51 14.43 19.62

Dec

I 17.94 18.29 15.88 34.53 22.56 26.07 20.76 13.87 16.72 14.81 12.96 16.65 13.04 12.88 14.56 13.03 12.99 16.69

II 15.66 15.57 16.24 30.29 20.21 23.25 18.17 13.29 15.00 14.18 17.00 16.03 12.23 12.96 13.67 11.54 11.61 16.04

III 14.76 15.33 15.42 29.62 19.44 24.03 17.58 14.09 14.35 14.24 14.51 17.28 12.46 14.62 13.33 12.33 12.26 17.30

Jan

I 11.87 12.60 14.08 23.53 16.32 18.27 13.97 12.17 12.48 12.68 11.34 11.41 11.06 13.14 11.36 10.88 13.78 8.99

II 12.88 11.69 12.76 21.96 16.01 17.87 13.55 11.79 11.95 12.28 11.34 11.01 10.21 13.42 10.98 11.03 12.25 8.44

III 14.17 13.06 13.24 21.75 18.61 18.75 16.20 13.17 12.86 13.88 13.17 11.55 10.56 14.26 11.48 12.15 12.77 8.91

Feb

I 12.09 12.22 13.31 20.21 16.69 15.71 15.14 12.35 12.51 14.11 9.93 10.35 9.00 12.84 10.32 10.75 11.03 7.98

II 12.93 12.53 13.87 21.34 17.96 15.80 16.14 13.01 13.97 15.47 8.99 11.36 8.38 13.11 11.29 10.11 10.50 8.56

III 11.26 10.55 10.88 17.20 14.66 13.06 12.90 10.34 14.09 13.40 8.13 8.82 6.29 10.78 9.88 9.73 9.06 7.48

Mar

I 14.23 13.21 15.71 22.03 15.24 17.74 22.87 13.57 18.60 21.07 12.02 13.80 8.46 13.12 13.73 17.31 12.14 9.70

II 16.18 13.85 17.56 22.75 15.50 18.88 22.34 13.75 19.92 24.42 13.80 14.99 9.61 17.49 14.91 21.90 12.56 11.95

III 25.81 19.28 22.15 27.90 16.76 20.44 26.10 16.76 23.36 32.68 18.81 17.87 13.58 20.17 17.77 24.59 15.65 16.98

Apr

I 29.91 20.38 25.00 28.53 19.69 19.69 36.85 18.63 24.50 38.75 22.66 19.18 12.94 21.02 19.11 29.70 16.80 17.77

II 37.97 22.34 29.09 29.98 20.69 26.40 42.51 23.08 27.72 41.45 25.99 20.61 17.66 33.44 20.51 44.75 18.35 20.56

III 53.59 26.48 42.36 31.79 23.53 38.22 51.02 26.88 31.18 52.24 34.94 35.50 23.41 38.42 35.32 41.47 22.00 23.53

August

I 62.77 31.05 53.18 37.74 30.09 57.76 59.79 30.29 36.34 60.18 43.63 44.21 24.40 39.84 43.99 43.97 31.13 29.71

II 58.75 34.44 57.56 43.74 34.30 66.51 56.61 29.99 38.42 57.58 52.10 42.92 26.99 40.51 42.72 50.60 38.02 41.32

III 65.31 46.27 75.91 57.88 43.91 90.89 64.37 34.21 48.61 69.70 56.21 46.98 46.41 38.60 46.76 57.35 50.08 44.89

Annual Run-off (mm) 1541.95 1561.10 1469.88 2030.54 1754.97 1936.02 1925.04 1445.14 1446.41 1465.59 1480.21 1366.39 1219.05 1155.25 1069.33 1252.09 1141.64 1304.31



Annexure-6.4 Observed 10-daily Average Runoff Depth of Budhil Nallah Upto Thalla G&D Site

Total Catchment Area = 524 km2 Snow Fed Area = 200 km2 Rain Fed Area = 324 km2 Unit: mm

Month Period 1990-91 1991-92 1992-93 1993-94 1994-95 1995-96 1996-97 1997-98 1998-99 1999-00 2000-01 2001-02 2007-08 2008-09 2009-10 2010-11 Average Runoff

(1972-02 & 2007- 11)

Jun

I 56.29 35.40 58.48 44.42 48.33 38.78 50.11 50.03 29.73 61.90 43.36 58.53 41.63 72.40 69.60 76.87 55.32

II 32.42 31.23 64.22 62.10 59.06 37.54 52.20 92.14 40.41 62.34 66.96 63.86 53.92 84.27 63.66 110.00 63.50

III 27.73 57.30 78.07 76.31 55.06 58.32 38.60 77.50 55.06 62.94 66.51 68.97 55.22 58.42 85.49 113.97 70.55

Jul

I 28.08 61.25 87.69 77.15 73.57 66.04 42.11 49.04 62.21 88.30 74.53 71.87 53.19 101.98 89.02 122.23 77.37

II 50.24 54.28 72.37 84.22 88.26 65.01 41.11 49.98 75.39 77.46 89.60 92.91 39.39 96.64 122.28 110.23 83.32

III 50.75 45.40 92.66 112.16 67.89 71.81 100.46 62.81 86.95 63.66 92.07 88.78 56.08 99.25 142.49 114.01 93.97

Aug

I 34.92 38.27 82.61 96.61 49.42 59.14 59.28 65.31 101.50 54.21 71.12 100.86 56.80 102.79 106.86 102.34 83.69

II 23.17 36.64 61.39 85.54 44.85 52.83 42.95 67.78 73.92 63.70 49.42 75.14 46.02 102.66 104.26 101.14 72.78

III 30.34 33.43 66.13 74.74 45.58 49.15 47.72 79.59 75.83 57.62 46.61 73.67 57.01 100.23 86.77 112.98 73.54

Sep

I 21.01 31.25 52.66 44.42 39.84 36.34 41.30 60.63 46.28 36.80 59.46 43.73 70.52 47.34 93.69 67.90 57.03

II 18.24 31.61 48.56 33.54 42.64 31.72 102.54 35.80 48.03 47.52 33.70 53.09 50.44 46.15 54.71 47.97 49.70

III 16.36 26.91 37.46 27.54 30.75 26.84 35.95 29.22 39.06 53.51 33.26 45.34 44.09 37.68 50.50 39.13 42.58

Oct

I 13.22 20.96 27.88 24.53 24.40 23.35 53.90 57.41 61.37 60.61 57.69 69.88 22.21 30.90 41.07 32.12 37.65

II 12.20 18.14 23.25 21.42 19.98 20.63 29.70 26.79 30.59 43.60 28.74 39.42 19.90 25.23 29.76 23.68 28.85

III 13.40 19.23 21.64 19.64 20.55 19.77 31.32 26.43 29.56 47.74 29.07 39.25 20.22 23.56 25.50 23.52 27.93

Nov

I 11.54 17.10 16.93 16.14 16.41 16.54 27.68 21.98 23.40 33.75 23.89 32.48 17.77 19.37 22.28 19.51 27.72

II 11.15 15.81 15.81 14.41 15.10 15.88 26.05 20.38 20.17 29.43 21.27 30.90 15.91 17.86 24.04 17.91 20.88

III 10.26 15.28 14.94 13.55 14.56 14.84 25.05 18.93 17.74 26.84 20.51 29.58 15.15 16.72 19.92 16.54 18.81

Dec

I 9.56 14.28 14.38 12.68 13.32 13.36 23.41 17.58 17.48 24.80 19.44 26.32 15.52 16.11 18.45 16.08 17.26

II 8.34 13.36 13.70 12.17 12.50 12.83 21.85 16.21 17.18 22.80 17.48 23.31 16.37 14.96 17.00 14.71 16.11

III 10.16 13.98 13.69 12.91 13.37 13.93 22.33 16.78 19.30 23.25 18.39 24.01 17.16 15.51 17.28 15.74 16.49

Jan

I 12.68 12.02 11.54 11.79 11.84 17.96 14.89 15.93 19.67 16.01 20.53 13.67 15.28 13.60 14.79 18.07 14.12

II 11.86 11.95 11.23 11.44 11.34 16.69 14.30 14.58 18.65 15.70 18.78 13.11 14.99 13.34 13.67 16.77 13.52

III 12.57 13.08 11.95 11.86 12.04 16.38 14.95 14.27 19.37 17.58 18.16 14.04 15.87 14.17 14.42 18.10 14.39

Feb

I 11.62 11.72 10.65 10.83 9.99 14.46 13.93 12.04 17.43 15.10 15.38 12.17 13.65 12.71 14.56 18.86 12.99

II 12.17 13.65 10.62 10.98 11.29 14.48 12.70 11.64 17.16 16.13 14.10 12.30 12.45 12.71 15.27 21.68 13.37

III 11.01 10.82 8.63 9.50 9.13 11.96 10.96 12.80 14.05 12.80 11.69 10.26 6.70 10.18 10.95 16.53 11.07

Mar

I 14.94 13.87 11.11 12.10 11.11 16.95 14.84 18.01 19.32 16.97 14.28 13.64 14.06 13.44 15.58 22.26 15.21

II 15.35 14.94 12.99 14.30 11.64 20.97 14.89 23.56 18.70 18.05 14.54 15.14 16.46 13.75 16.47 24.11 16.71

III 20.35 19.64 16.00 16.85 16.47 24.29 16.89 36.64 21.13 25.14 18.70 19.66 18.70 17.77 18.79 28.26 20.94

Apr

I 25.11 20.63 16.51 19.87 15.50 24.78 17.59 36.54 22.89 27.14 19.98 18.17 18.24 21.07 18.30 27.44 22.67

II 26.68 23.35 23.76 17.12 16.93 35.14 19.28 36.54 27.40 32.52 21.90 21.06 21.14 24.01 22.09 38.63 26.78

III 32.93 28.28 33.75 20.66 19.74 29.23 23.53 51.79 38.85 32.85 30.95 26.02 25.16 27.47 25.34 39.85 32.89

August

I 36.14 31.44 41.34 31.26 24.06 29.22 25.39 53.59 41.78 43.73 33.88 27.29 33.22 30.34 36.21 39.19 38.77

II 41.70 38.48 37.05 31.26 36.04 27.85 23.99 51.68 45.72 70.47 40.03 50.04 41.39 44.44 42.29 73.54 44.38

III 50.62 45.72 54.32 43.02 31.96 34.93 29.04 70.17 72.30 71.32 39.70 58.02 63.83 68.96 66.06 54.74 54.09

Annual Run-off (mm) 825.11 940.69 1275.98 1239.06 1044.53 1079.94 1182.78 1402.05 1385.58 1474.27 1295.69 1476.51 1115.67 1467.98 1629.43 1756.59 1386.96



Annexure-6.5

Observed & Correlated 10-daily Average Discharge Data of Budhil Nallah near Thalla G&D Site Total Catchment Area = 524 km2 Snow Fed Area = 200 km2 Rain Fed Area = 324 km2 Unit: Cumecs

Month Period 1972 1973 1974 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991

JAN

I 7.18 7.20 7.64 8.54 14.27 9.90 11.08 8.47 7.38 7.57 7.69 6.88 6.92 6.71 7.97 6.89 6.60 8.36 5.45 7.69

II 7.65 7.81 7.09 7.74 13.32 9.71 10.84 8.22 7.15 7.25 7.45 6.88 6.68 6.19 8.14 6.66 6.69 7.43 5.12 7.19

III 7.60 7.81 7.20 7.30 11.99 10.26 10.34 8.93 7.26 7.09 7.65 7.26 6.37 5.82 7.86 6.33 6.70 7.04 4.91 6.93

FEB

I 7.23 7.33 7.41 8.07 12.26 10.12 9.53 9.18 7.49 7.59 8.56 6.02 6.28 5.46 7.79 6.26 6.52 6.69 4.84 7.05

II 7.72 7.84 7.60 8.41 12.94 10.89 9.58 9.79 7.89 8.47 9.38 5.45 6.89 5.08 7.95 6.85 6.13 6.37 5.19 7.38

III 8.33 8.54 8.00 8.25 13.04 11.11 9.90 9.78 7.84 10.68 10.16 6.16 6.69 4.77 8.17 7.49 7.38 6.87 5.67 8.35

MAR

I 8.47 8.63 8.01 9.53 13.36 9.24 10.76 13.87 8.23 11.28 12.78 7.29 8.37 5.13 7.96 8.33 10.50 7.36 5.88 9.06

II 9.79 9.81 8.40 10.65 13.80 9.40 11.45 13.55 8.34 12.08 14.81 8.37 9.09 5.83 10.61 9.04 13.28 7.62 7.25 9.31

III 14.01 14.23 10.63 12.21 15.38 9.24 11.27 14.39 9.24 12.88 18.02 10.37 9.85 7.49 11.12 9.80 13.56 8.63 9.36 11.22

APR

I 17.96 18.14 12.36 15.16 17.30 11.94 11.94 22.35 11.30 14.86 23.50 13.74 11.63 7.85 12.75 11.59 18.01 10.19 10.78 15.23

II 22.19 23.03 13.55 17.64 18.18 12.55 16.01 25.78 14.00 16.81 25.14 15.76 12.50 10.71 20.28 12.44 27.14 11.13 12.47 16.18

III 31.66 32.50 16.06 25.69 19.28 14.27 23.18 30.94 16.30 18.91 31.68 21.19 21.53 14.20 23.30 21.42 25.15 13.34 14.27 19.97

AUGUST

I 37.15 38.07 18.83 32.25 22.89 18.25 35.03 36.26 18.37 22.04 36.50 26.46 26.81 14.80 24.16 26.68 26.67 18.88 18.02 21.92

II 34.62 35.63 20.89 34.91 26.53 20.80 40.34 34.33 18.19 23.30 34.92 31.60 26.03 16.37 24.57 25.91 30.69 23.06 25.06 25.29

III 35.78 36.01 25.51 41.85 31.91 24.21 50.11 35.49 18.86 26.80 38.43 30.99 25.90 25.59 21.28 25.78 31.62 27.61 24.75 27.91

JUN

I 38.61 40.96 26.56 47.36 38.24 35.17 57.58 35.63 27.81 28.78 40.51 33.67 35.10 25.53 20.78 34.93 34.93 31.70 34.14 21.47

II 38.24 52.72 37.03 48.06 41.27 39.63 54.35 48.29 35.56 31.15 47.67 31.11 39.49 25.90 34.50 39.31 39.31 33.59 19.66 18.94

III 42.13 52.78 38.70 55.82 41.96 60.29 63.91 70.47 44.95 42.93 41.40 37.95 38.25 27.09 42.21 38.07 38.07 49.87 16.82 34.75

JUL

I 53.61 53.47 45.12 55.81 45.79 72.24 66.89 63.13 50.73 43.19 50.03 58.68 43.65 30.10 35.36 43.43 43.43 44.34 17.03 37.15

II 58.87 52.89 58.60 61.56 52.26 76.44 67.72 62.18 66.77 54.83 56.88 56.90 40.88 50.49 31.76 40.68 40.68 54.24 30.47 32.92

III 52.01 51.17 55.70 78.20 54.70 65.68 63.12 57.80 62.26 62.09 60.85 64.12 46.98 48.23 38.85 46.75 46.75 63.42 27.98 25.03

AUG

I 47.65 54.47 54.92 68.28 64.81 73.81 59.50 58.83 63.00 54.81 61.09 75.42 38.53 48.10 33.54 38.34 38.34 75.47 21.18 23.21

II 48.21 60.53 53.95 66.22 64.71 62.28 63.59 57.03 56.66 51.26 54.38 39.83 26.16 38.41 40.03 26.03 26.03 39.86 14.05 22.22

III 45.00 56.44 49.04 71.60 66.32 49.46 52.84 47.64 39.47 41.50 41.18 30.53 58.92 30.25 23.60 36.06 36.06 30.56 16.73 18.43

SEP

I 36.56 51.22 39.44 56.92 67.12 46.71 33.63 38.69 34.05 32.50 37.91 27.27 55.71 26.76 20.78 31.20 31.20 27.29 12.74 18.95

II 29.02 45.78 31.00 56.27 60.41 45.91 28.96 30.00 29.17 23.66 34.88 24.50 37.49 19.91 17.04 22.89 22.89 24.53 11.06 19.17

III 25.71 38.98 26.00 47.79 50.21 40.58 25.01 22.73 24.65 19.49 31.09 37.95 26.41 18.60 17.28 19.86 19.86 37.99 9.92 16.32

OCT

I 23.96 29.20 18.89 37.72 42.27 37.27 21.15 19.31 21.26 16.18 26.59 10.59 20.28 17.19 14.66 16.15 16.15 10.60 8.02 12.71

II 22.13 22.67 16.22 34.10 37.25 34.66 18.25 15.57 18.50 13.90 20.28 11.00 14.14 14.75 12.92 13.50 13.50 11.00 7.40 11.00

III 20.25 17.78 15.08 31.03 28.35 28.87 16.54 13.03 16.35 12.23 15.57 12.70 11.41 11.41 10.88 11.52 11.52 12.71 7.39 10.60

NOV

I 17.31 14.62 12.30 29.14 24.42 25.17 115.12 10.76 13.69 11.75 12.88 15.09 9.34 10.61 9.65 10.23 10.23 15.12 7.00 10.37

II 14.97 13.87 10.58 27.35 22.31 23.31 13.68 9.64 11.93 10.25 9.46 14.04 8.72 9.32 9.00 9.36 9.36 14.05 6.76 9.59

III 13.19 12.95 8.83 23.13 15.25 21.24 12.89 9.05 10.51 9.51 8.29 11.89 8.32 8.16 8.99 8.75 8.75 11.90 6.22 9.27

DEC

I 10.88 11.09 9.63 20.94 13.68 15.81 12.59 8.41 10.14 8.98 7.86 10.10 7.91 7.81 8.83 7.88 7.88 10.12 5.80 8.66

II 9.50 9.44 9.85 18.37 12.26 14.10 11.02 8.06 9.10 8.60 10.31 9.72 7.42 7.86 8.29 7.04 7.04 9.73 5.06 8.10

III 8.14 8.45 8.50 16.33 10.72 13.25 9.69 7.77 7.91 7.85 8.00 9.53 6.87 8.06 7.35 6.76 6.76 9.54 5.60 7.71



Annexure-6.5

Observed & Correlated 10-daily Average Discharge Data of Budhil Nallah near Thalla G&D Site Total Catchment Area = 524 km2 Snow Fed Area = 200 km2 Rain Fed Area = 324 km2 Unit: Cumecs

Month Period 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011

JAN

I 7.29 7.00 7.15 7.18 10.89 9.03 9.66 11.93 9.71 12.45 8.29 10.36 10.78 11.52 10.78 8.45 9.27 8.25 8.97 10.96

II 7.25 6.81 6.94 6.88 10.12 8.67 8.84 11.31 9.52 11.39 7.95 10.31 10.57 11.04 10.65 7.78 9.09 8.09 8.29 10.17

III 7.21 6.59 6.54 6.64 9.03 8.24 7.87 10.68 9.69 10.01 7.74 10.26 10.70 11.25 10.57 8.45 8.75 7.81 7.95 9.98

FEB

I 7.11 6.46 6.57 6.06 8.77 8.45 7.30 10.57 9.16 9.33 7.38 10.39 10.75 11.07 10.60 8.91 8.28 7.71 8.83 11.44

II 8.28 6.44 6.66 6.85 8.78 7.70 7.06 10.41 9.78 8.55 7.46 11.10 10.70 11.59 10.70 10.03 7.55 7.71 9.26 13.15

III 8.20 6.54 7.20 6.92 9.07 8.31 9.70 10.65 9.70 8.86 7.78 11.57 11.73 11.12 10.86 9.03 5.08 7.72 8.30 12.53

MAR

I 8.41 6.74 7.34 6.74 10.28 9.00 10.92 11.72 10.29 8.66 8.27 12.72 12.46 12.09 11.02 11.94 8.53 8.15 9.45 13.50

II 9.06 7.88 8.67 7.06 12.72 9.03 14.29 11.34 10.95 8.82 9.18 12.59 14.69 13.83 11.46 12.34 9.98 8.34 9.99 14.62

III 10.83 8.82 9.29 9.08 13.39 9.31 20.20 11.65 13.86 10.31 10.84 14.04 14.48 14.46 11.91 14.13 10.31 9.80 10.36 15.58

APR

I 12.51 10.01 12.05 9.40 15.03 10.67 22.16 13.88 16.46 12.12 11.02 17.14 15.01 14.01 10.78 22.45 11.06 12.78 11.10 16.64

II 14.16 14.41 10.38 10.27 21.31 11.69 22.16 16.62 19.72 13.28 12.77 23.04 17.42 14.69 10.65 25.08 12.82 14.56 13.40 23.43

III 17.15 20.47 12.53 11.97 17.73 14.27 31.41 23.56 19.92 18.77 15.78 29.45 18.24 19.45 10.57 26.49 15.26 16.66 15.37 24.17

AUGUST

I 19.07 25.07 18.96 14.59 17.72 15.40 32.50 25.34 26.52 20.55 16.55 34.39 18.48 25.04 14.25 19.27 20.15 18.40 21.96 23.77

II 23.34 22.47 18.96 21.86 16.89 14.55 31.34 27.73 42.74 24.28 30.35 41.58 25.59 24.78 17.19 26.03 25.10 26.95 25.65 44.60

III 25.21 29.95 23.72 17.62 19.26 16.01 38.69 39.86 39.32 21.89 31.99 41.79 25.30 24.51 20.00 36.61 35.19 38.02 36.42 30.18

JUN

I 35.47 26.94 29.31 23.52 30.39 30.34 18.03 37.54 26.30 35.50 23.11 52.56 24.30 26.41 18.74 25.25 43.91 42.21 46.62 33.87

II 38.95 37.66 35.82 22.77 31.66 55.88 24.51 37.81 40.61 38.73 29.77 54.69 26.72 33.92 16.56 32.70 51.11 38.61 66.71 42.98

III 47.35 46.28 33.39 35.37 23.41 47.00 33.39 38.17 40.34 41.83 29.85 50.22 22.57 69.05 22.10 33.49 35.43 51.85 69.12 46.86

JUL

I 53.18 46.79 44.62 40.05 25.54 29.74 37.73 53.55 45.20 43.59 40.94 40.35 23.25 97.89 34.39 32.26 61.85 53.99 74.13 41.66

II 43.89 51.08 53.53 39.43 24.93 30.31 45.72 46.98 54.34 56.35 37.27 28.56 22.10 76.90 37.54 23.89 58.61 74.16 66.85 37.79

III 51.09 61.84 37.43 39.59 55.39 34.63 47.94 35.10 50.76 48.95 39.18 28.45 20.18 63.90 44.58 30.92 54.72 78.56 62.86 37.67

AUG

I 50.10 58.59 29.97 35.87 35.95 39.61 61.56 32.88 43.13 61.17 39.47 26.62 24.12 57.47 47.78 34.45 62.34 64.81 62.07 37.66

II 37.23 51.88 27.20 32.04 26.05 41.11 44.83 38.63 29.97 45.57 41.36 28.06 19.08 50.56 32.87 27.91 62.26 63.23 61.34 54.03

III 36.46 41.21 25.13 27.10 26.31 43.88 41.81 31.77 25.70 40.62 30.88 26.01 31.87 41.61 29.61 31.43 55.26 47.84 62.29 31.50

SEP

I 31.94 26.94 24.16 22.04 25.05 36.77 28.07 22.32 36.06 26.52 25.15 26.22 16.79 38.51 25.78 42.77 28.71 56.82 41.18 29.26

II 29.45 20.34 25.86 19.24 62.19 21.71 29.13 28.82 20.44 32.20 22.23 24.44 16.95 39.27 17.24 30.59 27.99 33.18 29.09 27.92

III 22.72 16.70 18.65 16.28 21.80 17.72 23.69 32.45 20.17 27.50 17.19 21.34 13.62 27.48 13.72 26.74 22.85 30.63 23.73 20.43

OCT

I 16.91 14.88 14.80 14.16 32.69 34.82 37.22 36.76 34.99 42.38 31.54 19.32 16.48 21.00 12.54 13.47 18.74 24.91 19.48 14.47

II 14.10 12.99 12.12 12.51 18.01 16.25 18.55 26.44 17.43 23.91 13.71 17.61 14.43 18.69 12.04 12.07 15.30 18.05 14.36 13.12

III 11.93 10.83 11.33 10.90 17.27 14.57 16.30 26.32 16.03 21.64 13.06 16.19 12.49 15.22 11.75 11.15 12.99 14.06 12.97 12.56

NOV

I 10.27 9.79 9.95 10.03 16.79 13.33 14.19 20.47 14.49 19.70 12.33 15.01 12.07 13.67 11.41 10.78 11.75 13.51 11.83 11.85

II 9.59 8.74 9.16 9.63 15.80 12.36 12.23 17.85 12.90 18.74 11.34 13.25 11.94 11.49 11.04 9.65 10.83 14.58 10.86 11.65

III 9.06 8.22 8.83 9.00 15.19 11.48 10.76 16.28 12.44 17.94 10.37 12.17 11.81 10.99 10.89 9.19 10.14 12.08 10.03 11.55

DEC

I 8.72 7.69 8.08 8.10 14.20 10.66 10.60 15.04 11.79 15.96 9.86 11.57 11.54 10.81 10.83 9.41 9.77 11.19 9.75 12.21

II 8.31 7.38 7.58 7.78 13.25 9.83 10.42 13.83 10.60 14.14 9.34 10.78 11.36 10.62 10.70 9.93 9.07 10.31 8.92 11.87

III 7.55 7.12 7.37 7.68 12.31 9.25 10.64 12.82 10.14 13.24 8.92 10.49 11.33 10.54 10.62 9.46 8.55 9.53 8.68 11.80



Annexure-6.6

Observed & Correlated 10-daily Average Discharge Data at Bharmour-I HEP Diversion Site Catchment Area of Budhil at Thalla = 524 km2 Catchment Area upto BHEP-I Diversion Site = 471 km2 Unit: Cumecs

Month Period 1972-73 1973-74 1974-75 1975-76 1976-77 1977-78 1978-79 1979-80 1980-81 1981-82 1982-83 1983-84 1984-85 1985-86 1986-87 1987-88 1988-89 1989-90

Jun

I 34.70 36.82 23.87 42.57 34.37 31.61 51.76 32.03 25.00 25.87 36.41 30.26 31.55 22.95 18.68 31.37 31.40 28.49

II 34.37 47.39 33.28 43.20 37.10 35.62 48.85 43.41 31.96 28.00 42.85 27.96 35.50 23.28 31.01 35.33 35.33 30.19

III 37.87 47.44 34.79 50.17 37.72 54.19 57.45 63.34 40.40 38.59 37.21 34.11 34.38 24.35 37.94 34.25 34.22 44.83

Jul

I 48.19 48.06 40.56 50.17 41.16 64.93 60.12 56.74 45.60 38.82 44.97 52.74 39.24 27.06 31.78 39.01 39.04 39.86

II 52.92 47.54 52.67 55.33 46.97 68.71 60.87 55.89 60.02 49.28 51.13 51.14 36.75 45.38 28.55 36.58 36.57 48.75

III 46.75 45.99 50.07 70.29 49.17 59.04 56.74 51.95 55.96 55.81 54.70 57.63 42.23 43.35 34.92 42.07 42.02 57.01

Aug

I 42.83 48.96 49.37 61.37 58.25 66.34 53.48 52.88 56.63 49.27 54.91 67.79 34.63 43.23 30.15 34.43 34.46 67.84

II 43.33 54.41 48.49 59.52 58.16 55.98 57.16 51.26 50.93 46.08 48.88 35.80 23.51 34.53 35.98 23.37 23.40 35.83

III 40.45 50.73 44.08 64.36 59.61 44.46 47.50 42.82 35.48 37.30 37.01 27.44 52.96 27.19 21.21 32.45 32.41 27.47

Sep

I 32.86 46.04 35.45 51.16 60.33 41.99 30.23 34.78 30.61 29.21 34.08 24.51 50.08 24.05 18.68 28.04 28.04 24.53

II 26.08 41.15 27.86 50.58 54.30 41.27 26.03 26.97 26.22 21.27 31.35 22.02 33.70 17.90 15.32 20.58 20.57 22.05

III 23.11 35.04 23.37 42.96 45.13 36.48 22.48 20.43 22.16 17.52 27.95 34.11 23.74 16.72 15.53 17.89 17.85 34.15

Oct

I 21.54 26.25 16.98 33.90 37.99 33.50 19.01 17.36 19.11 14.54 23.90 9.52 18.23 15.45 13.18 14.56 14.52 9.53

II 19.89 20.38 14.58 30.65 33.48 31.15 16.40 14.00 16.63 12.49 18.23 9.89 12.71 13.26 11.61 12.13 12.13 9.89

III 18.20 15.98 13.55 27.89 25.48 25.95 14.87 11.71 14.70 10.99 14.00 11.42 10.26 10.26 9.78 10.34 10.35 11.42

Nov

I 15.56 13.14 11.06 26.19 21.95 22.62 103.48 9.67 12.31 10.56 11.58 13.56 8.40 9.54 8.67 9.17 9.20 13.59

II 13.46 12.47 9.51 24.58 20.05 20.95 12.30 8.66 10.72 9.21 8.50 12.62 7.84 8.38 8.09 8.45 8.41 12.63

III 11.86 11.64 7.94 20.79 13.71 19.09 11.59 8.13 9.45 8.55 7.45 10.69 7.48 7.33 8.08 7.91 7.86 10.70

Dec

I 9.78 9.97 8.66 18.82 12.30 14.21 11.32 7.56 9.11 8.07 7.07 9.08 7.11 7.02 7.94 7.10 7.08 9.10

II 8.54 8.49 8.85 16.51 11.02 12.67 9.91 7.24 8.18 7.73 9.27 8.74 6.67 7.07 7.45 6.29 6.33 8.75

III 7.32 7.60 7.64 14.68 9.64 11.91 8.71 6.98 7.11 7.06 7.19 8.57 6.18 7.24 6.61 6.11 6.08 8.58

Jan

I 6.47 6.87 7.68 12.83 8.90 9.96 7.61 6.63 6.80 6.91 6.18 6.22 6.03 7.16 6.19 5.93 7.51 4.90

II 7.02 6.37 6.96 11.97 8.73 9.74 7.39 6.43 6.52 6.70 6.18 6.00 5.56 7.32 5.99 6.01 6.68 4.60

III 7.02 6.47 6.56 10.78 9.22 9.29 8.03 6.53 6.37 6.88 6.53 5.73 5.23 7.07 5.69 6.02 6.33 4.41

Feb

I 6.59 6.66 7.25 11.02 9.10 8.57 8.25 6.73 6.82 7.69 5.41 5.64 4.91 7.00 5.63 5.86 6.01 4.35

II 7.05 6.83 7.56 11.63 9.79 8.61 8.80 7.09 7.61 8.43 4.90 6.19 4.57 7.15 6.16 5.51 5.73 4.67

III 7.68 7.19 7.42 11.72 9.99 8.90 8.79 7.05 9.60 9.13 5.54 6.01 4.29 7.34 6.73 6.63 6.18 5.10

Mar

I 7.76 7.20 8.57 12.01 8.31 9.67 12.47 7.40 10.14 11.49 6.55 7.52 4.61 7.15 7.49 9.44 6.62 5.29

II 8.82 7.55 9.57 12.40 8.45 10.29 12.18 7.50 10.86 13.31 7.52 8.17 5.24 9.54 8.13 11.94 6.85 6.52

III 12.79 9.55 10.98 13.82 8.31 10.13 12.93 8.31 11.58 16.20 9.32 8.85 6.73 10.00 8.81 12.19 7.76 8.41

Apr

I 16.31 11.11 13.63 15.55 10.73 10.73 20.09 10.16 13.36 21.12 12.35 10.45 7.06 11.46 10.42 16.19 9.16 9.69

II 20.70 12.18 15.86 16.34 11.28 14.39 23.17 12.58 15.11 22.60 14.17 11.24 9.63 18.23 11.18 24.39 10.00 11.21

III 29.21 14.44 23.09 17.33 12.83 20.84 27.81 14.65 17.00 28.48 19.05 19.35 12.76 20.94 19.25 22.61 11.99 12.83

August

I 34.22 16.93 28.99 20.57 16.40 31.49 32.59 16.51 19.81 32.81 23.78 24.10 13.30 21.72 23.98 23.97 16.97 16.20

II 32.03 18.78 31.38 23.85 18.70 36.26 30.86 16.35 20.94 31.39 28.40 23.40 14.71 22.08 23.29 27.59 20.73 22.53

III 32.37 22.93 37.62 28.68 21.76 45.04 31.90 16.95 24.09 34.54 27.86 23.28 23.00 19.13 23.17 28.42 24.82 22.25

Average Yearly 22.93 23.24 21.83 30.17 26.12 28.79 28.70 21.52 21.52 21.78 22.01 20.33 18.08 17.19 15.92 18.61 16.96 19.39

Inflow (Mm3) 723.25 732.80 688.30 951.53 823.77 908.06 905.00 678.63 678.80 686.70 694.11 641.04 570.06 542.08 502.18 587.04 534.89 611.53



Annexure-6.6

Observed & Correlated 10-daily Average Discharge Data at Bharmour Stage-I HEP Diversion Site Catchment Area of Budhil at Thalla = 524 km2 Catchment Area upto BHEP-I Diversion Site = 471 km2 Unit: Cumecs

Month Period 1990-91 1991-92 1992-93 1993-94 1994-95 1995-96 1996-97 1997-98 1998-99 1999-00 2000-01 2001-02 2002-03 2003-04 2004-05 2005-06 2006-07 2007-08 2008-09 2009-10 2010-11

Jun

I 30.69 19.30 31.88 24.22 26.35 21.14 27.32 27.27 16.21 33.74 23.64 31.91 20.77 47.24 21.84 23.74 16.84 22.70 39.47 37.94 41.90

II 17.67 17.02 35.01 33.85 32.20 20.47 28.46 50.23 22.03 33.99 36.50 34.81 26.76 49.16 24.02 30.49 14.89 29.39 45.94 34.70 59.96

III 15.12 31.24 42.56 41.60 30.01 31.79 21.04 42.25 30.01 34.31 36.26 37.60 26.83 45.14 20.29 62.07 19.86 30.10 31.85 46.61 62.13

Jul

I 15.31 33.39 47.80 42.06 40.11 36.00 22.96 26.73 33.91 48.13 40.63 39.18 36.80 36.27 20.90 87.99 30.91 29.00 55.59 48.53 66.63

II 27.39 29.59 39.45 45.91 48.12 35.44 22.41 27.24 41.10 42.23 48.84 50.65 33.50 25.67 19.86 69.12 33.74 21.47 52.68 66.66 60.09

III 25.15 22.50 45.92 55.59 33.64 35.59 49.79 31.13 43.09 31.55 45.63 44.00 35.22 25.57 18.14 57.44 40.07 27.79 49.19 70.61 56.50

Aug

I 19.04 20.86 45.03 52.66 26.94 32.24 32.31 35.60 55.33 29.55 38.77 54.98 35.48 23.93 21.68 51.66 42.95 30.97 56.03 58.25 55.79

II 12.63 19.97 33.46 46.63 24.45 28.80 23.42 36.95 40.30 34.72 26.94 40.96 37.18 25.22 17.15 45.45 29.55 25.09 55.96 56.83 55.14

III 15.04 16.57 32.77 37.04 22.59 24.36 23.65 39.44 37.58 28.56 23.10 36.51 27.76 23.38 28.65 37.40 26.62 28.25 49.67 43.00 55.99

Sep

I 11.45 17.03 28.71 24.22 21.72 19.81 22.52 33.05 25.23 20.06 32.41 23.84 22.61 23.57 15.09 34.61 23.17 38.44 25.81 51.07 37.01

II 9.94 17.23 26.47 18.28 23.24 17.29 55.90 19.51 26.18 25.91 18.37 28.94 19.98 21.97 15.24 35.30 15.50 27.50 25.16 29.82 26.15

III 8.92 14.67 20.42 15.01 16.76 14.63 19.60 15.93 21.29 29.17 18.13 24.72 15.45 19.18 12.24 24.70 12.33 24.04 20.54 27.53 21.33

Oct

I 7.21 11.42 15.20 13.37 13.30 12.73 29.38 31.30 33.46 33.04 31.45 38.09 28.35 17.37 14.81 18.88 11.27 12.11 16.84 22.39 17.51

II 6.65 9.89 12.67 11.68 10.89 11.24 16.19 14.61 16.67 23.77 15.67 21.49 12.32 15.83 12.97 16.80 10.82 10.85 13.75 16.22 12.91

III 6.64 9.53 10.72 9.73 10.18 9.80 15.52 13.10 14.65 23.66 14.41 19.45 11.74 14.55 11.23 13.68 10.56 10.02 11.68 12.64 11.66

Nov

I 6.29 9.32 9.23 8.80 8.94 9.02 15.09 11.98 12.75 18.40 13.02 17.71 11.08 13.49 10.85 12.29 10.26 9.69 10.56 12.14 10.63

II 6.08 8.62 8.62 7.86 8.23 8.66 14.20 11.11 10.99 16.04 11.60 16.84 10.19 11.91 10.73 10.33 9.92 8.67 9.73 13.11 9.76

III 5.59 8.33 8.14 7.39 7.94 8.09 13.65 10.32 9.67 14.63 11.18 16.13 9.32 10.94 10.62 9.88 9.79 8.26 9.11 10.86 9.02

Dec

I 5.21 7.78 7.84 6.91 7.26 7.28 12.76 9.58 9.53 13.52 10.60 14.35 8.86 10.40 10.37 9.72 9.73 8.46 8.78 10.06 8.76

II 4.55 7.28 7.47 6.63 6.81 6.99 11.91 8.84 9.37 12.43 9.53 12.71 8.40 9.69 10.21 9.55 9.62 8.93 8.15 9.27 8.02

III 5.03 6.93 6.79 6.40 6.62 6.90 11.06 8.31 9.56 11.52 9.11 11.90 8.02 9.43 10.18 9.47 9.55 8.50 7.69 8.57 7.80

Jan

I 6.91 6.55 6.29 6.43 6.45 9.79 8.12 8.68 10.72 8.73 11.19 7.45 9.31 9.69 10.35 9.69 7.60 8.33 7.42 8.06 9.85

II 6.46 6.52 6.12 6.24 6.18 9.10 7.79 7.95 10.17 8.56 10.24 7.15 9.27 9.50 9.92 9.57 6.99 8.17 7.27 7.45 9.14

III 6.23 6.48 5.92 5.88 5.97 8.12 7.41 7.07 9.60 8.71 9.00 6.96 9.22 9.62 10.11 9.50 7.60 7.86 7.02 7.15 8.97

Feb

I 6.34 6.39 5.81 5.91 5.45 7.88 7.60 6.56 9.50 8.23 8.39 6.63 9.34 9.66 9.95 9.53 8.01 7.44 6.93 7.94 10.28

II 6.63 7.44 5.79 5.99 6.16 7.89 6.92 6.35 9.36 8.79 7.69 6.71 9.98 9.62 10.42 9.62 9.02 6.79 6.93 8.32 11.82

III 7.51 7.37 5.88 6.47 6.22 8.15 7.47 8.72 9.57 8.72 7.96 6.99 10.40 10.54 10.00 9.76 8.12 4.57 6.94 7.46 11.26

Mar

I 8.14 7.56 6.06 6.60 6.06 9.24 8.09 9.82 10.53 9.25 7.78 7.43 11.43 11.20 10.87 9.91 10.73 7.67 7.33 8.49 12.13

II 8.37 8.14 7.08 7.79 6.35 11.43 8.12 12.84 10.19 9.84 7.93 8.25 11.32 13.20 12.43 10.30 11.09 8.97 7.50 8.98 13.14

III 10.09 9.73 7.93 8.35 8.16 12.04 8.37 18.16 10.47 12.46 9.27 9.74 12.62 13.02 13.00 10.71 12.70 9.27 8.81 9.31 14.00

Apr

I 13.69 11.24 9.00 10.83 8.45 13.51 9.59 19.92 12.48 14.80 10.89 9.91 15.41 13.49 12.59 9.69 20.18 9.94 11.49 9.98 14.96

II 14.54 12.73 12.95 9.33 9.23 19.15 10.51 19.92 14.94 17.73 11.94 11.48 20.71 15.66 13.20 9.57 22.54 11.52 13.09 12.04 21.06

III 17.95 15.42 18.40 11.26 10.76 15.94 12.83 28.23 21.18 17.91 16.87 14.18 26.47 16.40 17.48 9.50 23.81 13.72 14.97 13.82 21.73

August

I 19.70 17.14 22.53 17.04 13.11 15.93 13.84 29.21 22.78 23.84 18.47 14.88 30.91 16.61 22.51 12.81 17.32 18.11 16.54 19.74 21.37

II 22.73 20.98 20.20 17.04 19.65 15.18 13.08 28.17 24.93 38.42 21.82 27.28 37.37 23.00 22.27 15.45 23.40 22.56 24.22 23.06 40.09

III 25.09 22.66 26.92 21.32 15.84 17.31 14.39 34.78 35.83 35.34 19.68 28.75 37.56 22.74 22.03 17.98 32.91 31.63 34.17 32.74 27.13

Average Yearly 12.28 14.02 18.97 18.40 15.57 16.08 17.59 20.86 20.59 21.95 19.30 21.96 19.66 19.00 15.12 23.17 17.22 16.58 21.80 24.20 26.16

Inflow (Mm3) 387.17 442.24 598.37 580.19 490.87 507.15 554.73 657.75 649.26 692.26 608.74 692.54 620.15 599.06 476.73 730.70 543.08 522.78 687.50 763.31 824.87

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 7-Geology


7. GEOLOGY

7.1 INTRODUCTION

The proposed 24 MW Bharmour Hydro Electric Project Stage-I (BHEP-I) is located in Chamba

District of Himachal Pradesh. The project is located on right bank of River Budhil. The barrage

site is located just downstream of confluence of Choubia nala with Budhil River. Powerhouse

site is located close to Bharmour Town.

Geotech Division of RITES Ltd. carried out geotechnical investigation for the Bharmour Hydro-

electric project in 2002. The investigations involved geological mapping of the project area,

subsurface exploration through drilling and geophysical surveys and field and laboratory tests.

7.2 REGIONAL GEOLOGY

The proposed project is located in Lesser Himalayas in Ravi Basin and is characterized by sharp

crested ridges and deeply dissected valleys. Geologically, the region exposes rocks ranging in

age from early Proterozoic to Mesozoic. The rocks of the area are extensively covered by slope

debris, fluvial terraces and fan deposits of Quaternary to Recent origin. The stratigraphic

succession in the area is given in Table-7.1 (Geology of Himachal Pradesh, Srikantia and

Bhargava, Geological Society of India, Banglore, 1998).

Table-7.1: Stratigraphic Succession in the Project Area

Age Group Formation Lithology

Triassic --- Kalhel

Grayish blue, gray and yellow limestone and dolomite with interbedded gray ortho-quartzite in the upper part. Gray calcareous shale with interbeds of limestone in basal part.

Upper Permian --- Salooni

Dark gray or black carbonaceous pyritous slates with thin lenticles of limestone at places. There are discontinuous bands of varying thickness of amygdaloidal and massive lava flows of basaltic to andesitic composition.

--------------------------------------------------- Unconformity ---------------------------------------------------------

Terminal Proterozoic

Haimanta

Katari Gali (Batal Fm.)

Black, carbonaceous phyllite with interbeds of quartzite. Local limestone bed at the base with magnesite and scale of gypsum.

Neoproterozoic Manjir Polymictic dimictite – poorly sorted, lithologically heterogenous, laminated or banded.

--------------------------------------------------- Unconformity ---------------------------------------------------------

Meso Proterozoic

Salkhala Chamba Dark gray thinly bedded, laminated slates with subordinate bands of quartzites



The rocks exposed in the project area belong to Katari Gali Formation of Terminal Proterozoic

age (Plate.1). They include an assemblage of black, carbonaceous phyllite with interbeds of

quartzite (Table-7.1). The Katari Gali Formation, also known as Batal Formation overlies the

rocks of Manjir Formation of Neoproterozoic age. Manjir Formation comprises pebbly

slate/diamictite, phyllite, shale, sandstone and limestone. The Manjir Formation, in turn, overlies

the Chamba Formation of Salkhala Group with an unconformity. The Salooni Formation is

infolded within the Katari Gali Formation of Permian age. It comprises black shales, slates,

calcareous slates and lenticles of limestone. Associated with it’s rocks, there are basic lava flows

which can be correlated with the Panjal volcanincs of J & K. The Kalhel Formation normally

overlies the Salooni Formation. It comprises mainly grayish blue, gray and yellow limestone and

dolomites with interbedded gray quartzite in the upper part.

7.3 TECTONICS

Within the Himalayan belt, the northernmost conspicuous structural element is the Main Central

Thrust (MCT). From Manali towards east throughout the entire Himalaya almost up to the

eastern syntaxis, this is considered as one of the most important tectonic surfaces. However,

north of Manali it is not clearly discernible. Further south, within the lesser Himalayan package,

the other important tectonic surface is the Vaikrita Thrust (VT). This Himalayan belt is separated

from the Frontal belt (Comprising the Siwalik sequence) by the Main Boundary Thrust (MBT).

The southern limit of the frontal belt is marked by the Main Frontal thrust (MFT) which has its

surface manifestations only at a few places. In between MBT and MFT the belt is traversed by

several subsidiary thrusts some of which have considerable spatial extent, viz. Jwalamukhi

Thrust and Drang Thrust. Evidences of neotectonic activity have been documented at several

places along MBT and in western part of Jwalamukhi Thrust. The frontal belt package is affected

by several regional scale folds, of which Mastgarh and Pror anticlinal axial traces are mappable

for considerable distances.

In addition to this, there are number of fault/lineaments transverse to this fold-thrust belt. The

Sundernagar fault is a dextral transverse structure that extends from higher Himalaya to Frontal

belt. The Ropar fault, occurring North of Chandigarh is postulated to be the continuation of the

Sundernagar Fault. Further east, the Yamuna tear displays sinistral sense of movement.

The project site is located about 60 km from MCT and about 50 km from MBT (Plate.2).

7.4 SEISMO-TECTONICS AND SEISMICITY

A total of 99 seismic events of magnitude ≥ 4.0 have been recorded in the area. Out of these 20

events have magnitude ≥ 5.0 and are mostly confined to depths less than 40 Km. Events having

magnitude between 4.0 and 5.0 are prevalent in the area. Seismic activity is mainly

concentrated along the Himalayan Belt particularly around Chamba. This sector with maximum

clustering of seismic events represents part of Kangra Seismic Zone that continues towards

North. Out of 20 events of magnitude ≥ 5.0; about 18 events define this zone. In this part of the



Himalaya, 4 events having magnitude > 6.0 have been recorded. Out of these, 3 events lie on

MBT, which include the famous Kangra Earthquake of 1905. Six earthquakes in this area have

caused considerable damage. The earliest is the Kangra Earthquake of 4th April, 1905 having

Ms = 8.0, Chamba Earthquake of 22nd June, 1945 also caused considerable damage to the

property. Dharamshala Earthquake of 14th June, 1978, Dharamshala Earthquake of 26th April,

1986 and Chamba Earthquake of 24th March 1995 are the other major earthquakes that caused

considerable damage in the area.

The seismic co-efficient based on the BIS codes (IS: 1893, Part–I; 2002); comes around 0.12

(DBE) horizontal and 0.08 (vertical) as the project area is located in Zone IV of seismic zoning

map of India (Plate.3). However the seismic co-efficient has been taken from Seismic parameter

study carried out for Budhil HEP (60m high dam) located in the vicinity which is 0.16 (Horizontal)

and 0.11 (Vertical) and is considered for checking the stability of barrage.

7.5 DISCONTINUITY

The discontinuity data collection has been carried out for the rock outcrops along the footpath,

roads and at the dam site. Efforts have been made to observe engineering properties of as

many joints as possible in accessible sections for comprehensive assessment of properties of

major discontinuity sets in the project area. The stereographic analysis of the joints data has

been carried out using Georient separately for dam and powerhouse site. The engineering

properties of the joints belonging to different sets are given in Table.7.2 and 7.3.

Table-7.2: Discontinuity Sets and their Engineering Properties at Barrage site and WCS area

Set No.

Feature Dip (Dir./Amt) Continuity (in m)

Aperture (in m)

Filling Surface Roughness Spacing (in cm)

J1 Foliation N030-060°/30-60° >10 Tight to 5 Clay Plannar Smooth 5- 50

J2 Joint N205-225°/50-70° 3 - 7 Tight to 5 Clay Undulating Rough 40 - 150

J3 Joint N290-310°/60-80° 2 - 7 Tight to 2 Clay Undulating to Planner

Smooth 100 - 600

JR Joint N340-355°/70-80° 1 - 10 Tight Nil Undulating to Plannar

Smooth >600

Table.7.3: Discontinuity Sets and their Engineering Properties in Powerhouse area

Set No.

Feature Dip (Dir./Amt) Continuity (in m)

Aperture (in m)

Filling Surface Roughness Spacing (in cm)

J1 Foliation N025-045°/20-45°

<10 Tight to 1

Clay Undulating Rough 10-60

J2 Joint N200-210°/70-80°

<10 Tight to 1

Clay Undulating Rough 20-100

J3 Joint N130-140°/40-50°

5- 10 Tight Nil Plannar Rough 50-150

J4 Joint N025-035°/65-80°

5-10 Tight Nil Plannar Rough 50-100



7.6 GEOLOGY OF PROJECT AREA

The Budhil River flows in a generally ENE-WSW direction in the project area (Plate.4). It has a

very steep average gradient of about 1 in 25 in project reach descending from El 1829 m at

barrage site to El 1723 m at powerhouse site in a short stretch of 3.2 km. For most of the stretch,

it flows through narrow V-shaped valley. The course of the nala is occupied by bouldery RBM.

The river banks are mostly rocky and steep. Higher slopes are vegetated. Colluvial fans have

developed at the base of gullies.

The area is represented by an interbedded sequence of quartzite and phyllite belonging to

Precambrian Chamba Formation. In general, proportion of quartzite is more than phyllite. The

rock is grey in colour and well jointed. The strata, in general, have moderate northeasterly dips.

The rocks are frequently found to be folded for which the bedding dips vary from moderate to

sub-vertical in northeasterly to southwesterly directions. Recumbent and overturned folds are

seen (Photo.7.1). Shearing is expected along all the three joint sets. In particular, shearing along

bedding could be more frequent.

In general, three sets of discontinuities are observed in the area. These include, moderately

steep north easterly dipping foliation joint set J1: N028/33; moderate to steep transverse joint

dipping towards south east J2: N208/71 and longitudinal joint dipping moderately towards south

east J3: N137/44. One random joint have been observed dipping in North West. The stereoplot

of discontinuities found in the project area is produced as Fig.7.1.

Figure-7.1: Stereoplot of Major Joint Sets in the Project Area



Photo-7.1 Isoclinal Fold Seen in Road cut on Left Bank of Budhil River

7.6.1 Barrage Site

The barrage site is located at El 1827 m downstream of the confluence of Choubia nala with

Budhil River (Plate.5). The Chobia nala joins river Budhil at almost perpendicular angle.

Immediately downstream the river takes a sharp turn around a low rocky ridge. The river valley

at the weir site is about 50 m wide with steep rocky banks (Photo-7.2). While, the rocky ridge on

right bank is lower in height, the slopes on left bank extend to much higher elevations (Photo-

7.3). Higher slopes on both banks are vegetated. The slopes near river bed level are

characteristically rocky. Higher slopes are also mostly rocky and are covered with intermittent

shallow colluvium deposits.

The river bed is occupied by river borne material. A narrow deposit of river borne material is

present on left bank that consists of sub-rounded boulders and pebbles of mainly quartzite

(Photo-7.4). A conspicuous semicircular river terrace is developed on left bank of Budhil at the

confluence of Choubia. The terrace is about 3m higher than the river bed and is located about

100m (along the river) upstream of the weir axis (Photo-7.5). A minor gulley is present on left

bank steep slope (Photo-7.5). Debris from this gulley has accumulated at its base.

The main rock type in the area is quartzite. It is exposed on both banks from river bed level itself.

It is almost fresh at the river bed level and slightly to moderately weathered in the higher slopes.

It has moderate northeasterly foliation dips of of N030-060/30-60 (Fig.7.2). Besides foliation

joints, the rocks are dissected by two more sets of joints, viz. N205-225/50-70 and N290-310/60-

80. One random joint have also been observed, viz. 340-355/70-80. The joints are generally

open, undulatory and have continuity of the order of 2-3 m.



Photo-7.2 Barrage Site Downstream View

Photo-7.3 Low Rocky Ridge on Right Bank of River Budhil around Which it takes a Sharp Turn



Photo-7.4 Sub-rounded Boulders in River Borne Material

Photo-7.5 Minor Gully on Left Bank of Budhil View from Confluenceof Chobia Nallah



Figure-7.2: Stereoplot of Major Joint Sets at the Barrage Site

7.6.2 Intake & Desilting Chamber

The 80 m x 10 m x 12.7 m surface desilting chambers are proposed to be located on right bank

of River Budhil at weir site (Photo-7.2, Plate.5). The low rocky ridge of mainly quartzite on right

bank will have to be cut to create space for accommodating desilting chambers (Photo-7.3). The

ridge is covered with shallow colluvium.

7.6.3 Water Conductor System

The head race tunnel is proposed on right bank of Budhill River (Plate.4). The intake portal of

HRT is located in the rocky cliff on right bank (Photo-7.2). The tunnel is expected to traverse

through interbedded quartzite and phyllite with quartzite in greater proportion. The rocks dip in

northeasterly direction (N028/33). The other joint sets intersecting the rock mass are N208/71,

N137/44 and one random joint N312/52. Rocks are frequently folded and variation in dip

direction and amount is seen.

Tunnel alignment is covered with shallow colluvium and is mostly rocky. Higher reaches of the

mountains are covered with fluvio-glacial deposits at places.

7.6.4 Power House

The surge shaft is proposed in rocky slopes near village Nangali (Plate.6). Shallow colluvium is

seen over the slopes intermittently in patches. The penstock is proposed over a rocky slope. The

surface powerhouse is proposed to be located over a wide terrace on right bank of Budhill River

upstream of the bridge near village Nangali (Photo-7.6). The river terrace is about 65m wide

(maximum) and 3-4 m above the river bed level. The slope behind the river terrace is rocky and

steep. Bedrock is exposed at river bed level upstream of the river terrace on right bank and all

along left bank.



The main rock type in the area is interbedded phyllite and quartzite. The rocks have moderate

northeasterly foliation dips of N025-045/20-45 i.e. into the hill. Besides foliation joints, the rocks

are dissected by three more sets of joints, viz. N200-210/70-80, N130-140/40-50 and N025-

035/65-80 (Fig.7.3).

Photo-7.6 General view of powerhouse site from road on right bank of Budhil

Figure-7.3: Stereoplot of Major Joint Sets at the Powerhouse Site



7.7 SUB-SURFACE EXPLORATION

7.7.1 Drilling

In all seven bore holes aggregating 173m length have been drilled at the then proposed barrage

site of Bharmour HEP by Geotech Division of RITES Ltd. Of these, three bore holes, viz. BH-3,

BH-4 & BH-6 lie close to the present barrage site and their results have been used for

estimation of bedrock depth and rock mass condition in the area (Dwg. No. 1335-GD-005).

The summary of drill hole results is presented in Table-7.4 and findings of each hole are

discussed in detail in following paragraphs. The geological logs of bore holes have been

appended as Annexure-7.1.

Table-7.4 Summary of Drill Holes

Bore Hole No.

Location Northing Easting Elevation

Depth of hole (m)

Depth of bedrock (m)

BH-3

Head works area, river bed towards right bank, d/s of weir axis

9736.712 29437.147 1828.257 23 7

BH-4

Head works area, river bed towards right bank, d/s of weir axis

9743.589 29455.554 1829.272 25 5.5

BH-6 Head works area, river bed, u/s of weir axis

9750.413 29522.081 1829.542 25 0.5

BH-3

This bore hole is located at RL 1828.257 m, in Budhil river bed upstream of weir site. The

borehole has been drilled to 23.0 m depth. The overburden material comprising coarse sand,

dark gray pebbles, cobbles and gravels, with Quartzite boulders are recovered up to 7.0 m depth

from surface. Bedrock comprising quartzite with phyllite bands occurs below 7m thick alluvial

overburden. The average core recovery in Quartzite and phyllite varies from 35% to 75%. The

RQD varies up to 73%. Complete water loss during drilling operations is indicative high

permeability of the bed rock.

BH-4

This bore hole has been drilled in the Budhil river bed at RL +- 1829.272 m. The depth of

borehole is 25 m. The bedrock of gray fine-grained quartzite with bands of phyllite has been

encountered at 5.50 m depth. The bedrock is overlain by coarse-grained sand with pebbles and

cobbles of quartzite.



BH-6

The borehole is located on left bank of Budhil River at RL 1829.542 m. The bedrock comprising

quartzite and phyllite are available after 0.50 m thin cover of soil. The average core recovery

varies from 20% to 36%, with RQD varying from 0 to 24% indicating highly jointed nature of

rock. The complete water loss during drilling operations confirms the open jointed nature of rock.

7.7.2 Exploratory Pits

Five exploratory pits of 3 m depth are proposed at powerhouse site (Plate.6). The pits will be

geologically logged in detail and selectively sampled for laboratory testing for soil properties.

7.8 FIELD AND LABORATORY TESTS

7.8.1 Field Tests

In-situ permeability tests have been carried out in bedrock in drill holes at weir site by double

packer method [(IS: 5529 (part-2)]. The permeability values obtained in bedrock in bore range

between 11.1 to 39.4 Lugeon.

7.8.2 Laboratory Tests

It is proposed to test samples from proposed exploratory pits at weir site for soil properties. The

tests for soil properties are listed below.

i. Grain size distribution

ii. Moisture content

iii. Optimum moisture content

iv. Density

v. Shear Parameters (c and Φ)

7.9 GEOTECHNICAL ASSESSMENT

7.9.1 Head Works

The barrage is located on a planar and straight stretch of the river just downstream of a very

sharp bend. The river valley is only about 50 m wide at this location. The thickness of river borne

material is expected to be about 6 m (Plate.7). The barrage will be placed over river borne

material. The emplacement of the weir will involve cutting of the rocky slope on left bank that will

be stabilized suitably. In order to keep the cutting of high rocky cliffs on left bank as minimum as

possible, the weir and desilting basin have been kept close to the right bank as far as possible.

The rocky ridge on the right bank is low and easier for excavation than higher cliff on left bank.



7.9.2 Head Race Tunnel

The inlet portal of the tunnel is proposed in a good quality quartzite downstream of weir site on

right bank. The rock is fresh and massive at river bed level.

The 3.6 m dia, 2485 m long, D-shaped head race tunnel is aligned in ENE-WSW direction for

most of its stretch. Towards downstream, the tunnel alignment takes sharp turn and is aligned

NNE-SSW. The tunnel makes an angle of 60° with strike of the foliation in these stretches. In

general, foliation dips towards upstream in the tunnel and the tunnel is considered to be

favourably oriented.

The maximum vertical cover over the tunnel is more than 260 m (Plate.8). The minimum vertical

cover over the tunnel is about 80 m at approximate RD 2090 m and is considered adequate. In

general, about 73% length of the tunnel has optimum vertical cover of 100 to 200m. No major

drainage cuts across the tunnel alignment.

Problems due to sheared or crushed zones and presence of subsurface water in varying

quantities may be expected during tunneling.

The tunnel is expected to pass through fair to good quality bedrock of interbedded quartzite and

phyllite. Zones of Poor to Very Poor rock classes are expected to be intersected in intermittent

stretches within higher rock class zones. In general, the rock mass classification along the tunnel

alignment is estimated to be Good: 30% (744 m), Fair: 50 % (1240 m), Poor: 15 % (372m) and

Very Poor: 5% (124 m).

Based on rock condition and design criteria, rock support system for tunnel has been adopted.

Primarily, the support system consists of rock bolting, steel fibre reinforced shotcreting (SFRS)

and steel ribs. Primary supports of spot rock bolting and shotcreting, irrespective of rock class,

would be installed as per the advice of the site geologist/ engineer. The main water conductor

system, viz. HRT has been provided concrete lining of 300 mm thickness. Detailed rock support

system for HRT is given in Table-7.5.

Table-7.5 Design Support System for Head Race Tunnel and Adit

S. No. Rock Class “Q” Value Design Support

1 I 40-100 No support

2 II 10-40 25mm Ø, 2m long rock bolts 2.5m c/c spot bolting. 50mm thick shotcrete as required

3 III 4-10 25mm Ø, 2m long rock bolts 2.5m c/c staggered bothways. 100mm thick shotcrete

4 IV 1-4 25mm Ø, 2m long rock bolts 1.5m c/c square spacing. 100mm thick shotcrete with wire mesh

5 V <0.1 Steel rib support ISHB 150 x 34.6 kg/m @ 750mm c/c spacing. Precast RCC lagging.



7.9.3 Surge Shaft

The 10 m dia, 54.70 m deep open to sky surge shaft is proposed over rocky slopes of mainly

quartzite and phyllite (Plate.9). The surge shaft is expected to be excavated through Fair to

Good rock mass. Shear zones or weak planes oriented parallel to foliation direction August be

expected.

7.9.4 Presure Shaft

The 127 m long, 2.8 m dia pressure shaft is proposed within rocky ridge of interbedded quartzite

and phyllite. The pressure shaft comprises initial 33 m long horizontal portion, then 47 m long

vertical shaft followed again by 47 m long horizontal portion. Lateral cover for the vertical shaft

varies from 30 to 87 m and is considered adequate. The pressure shaft is provided with 12 to 24

mm thick steel liner.

7.9.5 Power House

The 56.0 m (L) x 15.0 m (W) x 24.0 m (H) surface powerhouse is proposed on right bank over a

river terrace. The terrace is compact and is about 4 to 5m higher than the water level. The

foundation of the powerhouse is proposed at El 1725.9.m and is expected to be laid over river

borne material. Protection wall is proposed to be provided on river side of the powerhouse. The

rocky hill face behind the surface powerhouse will be treated to a height of about 50m with

shotcrete and rock bolts for protection from vulnerable joint block.

7.10 CONSTRUCTION MATERIAL

The reserve allocation of identified quarry sites for the project is based on the distances of the

quarry sites from the project and their components.

Total concrete quantity required for the project is estimated to about 77,542 cum.

The total requirement of construction material for civil components of the project is as follows:

Fine Aggregate : 34893 m3

Coarse Aggregate : 65910 m3

The total raw material required for coarse and fine aggregate including 38% loss is 1,39,108

cum, say 1,40,000 cum

The required construction material will be arranged from the identified quarry site in the project

area near the HRT alignment downstream of village Nangali (Dwg. No. 1323-GD-004). Detailed

mapping and quantity estimation for the quarry site are yet to be carried out. The site lies mainly

in quartzite. The estimated quantity is about 1 Lac m3.

The excavated muck from subsurface excavations for water conductor system is expected to

provide additional material in significant quantities. The quantity of excavated muck generated



by excavation of HRT is estimated to be about 46000m3. The generated muck will also be tested

for assessing its suitability before using as construction material. It is proposed to meet the

requirement of construction material through use of material from quarry site and muck in 70:30

proportions. The suitability of this material is subject to relevant laboratory tests during

construction stage as per IS codes.

The quarry site is proposed to be used for both coarse and fine aggregate. The tests proposed

to be carried out for determining suitability of the material for use as construction material are

given in Table-7.6

Table-7.6: Physical Tests Proposed to be carried out for Coarse and Fine Aggregates

and the Relevant BIS Codes

S. No. Coarse aggregate Fine aggregate

Particulars Relevant IS Codes Particulars Relevant IS Codes

1 Flakiness Index 2386-1963 (Part I) Sieve Analysis 2386-1963 (Part I)

2 Elongation Index 2386-1963 (Part I) Fineness Modulus 2386-1963 (Part I)

3 Clay Lumps 2386-1963 (Part II) Soft Particles 2386-1963 (Part II)

4 Soft Particles 2386-1963 (Part II) Clay Lumps 2386-1963 (Part II)

5 Specific Gravity 2386-1963 (Part III) Specific Gravity 2386-1963 (Part III)

6 Water Absorption 2386-1963 (Part III) Water Absorption 2386-1963 (Part III)

7 Abrasion Value 2386-1963 (Part IV)

8 Crushing Value 2386-1963 (Part IV)

9 Impact Value 2386-1963 (Part IV)

10 Soundness, % loss 2386-1963 (Part V)

11 Alkali Aggregate Reactivity (Chemical)

2386-1963 (Part VII)

12 Petrographic Studies 2386-1963 (Part VIII)



Annexure-7.1

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 8-Power Potential Studies


8. POWER POTENTIAL STUDIES

8.1 GENERAL

Bharmour-I hydroelectric project (BHEP-I) has been conceived as run-of-river development for

generation of hydropower on Budhil Nallah a tributary of Ravi River. The project consists of

construction of a barrage across Budhl Nallah near village Bharmour. The water so diverted

shall pass through 2 nos. intake structure provided with trash racks – each 6.0m (wide) x 5.0 m

(high), two nos. Dufour type desilting basins each having dimensions of 10.0 m (wide) x 11.5 m

(effective depth) x 80.0 m (long), collection pool, headrace tunnel of size 3.6 m (wide) x 3.6 m

(high), 2485 m long, D-Shaped terminating at a 10 m diameter surge shaft from which emerges

a 2.8 m diameter steel pressure shaft. Three (3) branches would take-off from the penstock to

feed three (3) nos. horizontal axis Francis machines kept in the powerhouse, of 8.0 MW capacity

each to generate 24.0 MW of power. All the three machines are arranged in a surface type

powerhouse located on the right bank of Budhil Nallah. After power generation, water is

discharged to intake pool of Bharmour-II HEP located after the tail race channel.

The assessment of power potential for BHEP-I and determination of optimum installed capacity

has been made in accordance with recommendations and guidelines for pure Run-of-the River

Projects. The basic factors available for power potential assessment are:

Water availability in Budhil River for a long term period from 1972-73 to 2010-11

Flow series corresponding to 50%, 75% & 90% dependable year

Head available for power generation

Estimated turbine and generator efficiency

The methodology adopted for assessment of power potential and determination of optimum

installed capacity based on above parameters is described in this chapter.

8.2 METHODOLOGY

For assessment of power potential and annual energy benefits, 90%, 75% and 50% dependable

flow series have been considered. The 90%, 75% and 50% dependable years are computed

based on annual runoff in each year of the 39 year flow series derived in Chapter:6-Hydrology.

For fixing the installed capacity, a number of alternative installed capacities from 18 MW to 28

MW in suitable steps of 1 MW have been considered. For each of these installed capacities,

incremental energy generation (Δ KWh) for every incremental KW (Δ KW) is computed and the

results are plotted on a graph. Optimum installed capacity is fixed at a value where the fall in the

graph is sharp.



Based on optimum installed capacity, the unit-size and accordingly the number of units are

determined. Number of generating units is kept least as the cost of generating units and related

equipment increases with the increase in number of units. Unit-size is also verified based on

transport limitations, loss of generation probability criteria etc.

The annual design energy is computed for each 10-daily flow in 75% dependable year restricted

to 95% of availability of installed capacity. The total of these 10-daily restricted energies for the

year provides the annual design energy generation estimate for the project.

8.3 WATER AVAILABILITY

As mentioned under Chapter. 6, “Hydrology” recent long-term discharge data of Budhil Nallah at

BHEP-I diversion weir site is not available. As such, the water availability study for Budhil nallah

for 39 years (1972-73 to 2010-11) is estimated based on available long term flow data of Budhil

and Ravi River using catchment area proportion method. The 50%, 75% and 90% dependable

year discharge series are determined using Weibuls distribution method and the inflow series for

the above dependable years are given in Table-8.1. The study has been described in detail in

Chapter. 6, “Hydrology” and the available flow series of BHEP-I for the above 39 years are given

in Annexure-8.1.

Table-8.1: 50%, 75% and 90% Dependable flow series at diversion site of BHEP-I

Month Period 50% Dependable Year

Discharge (m3/s) 75% Dependable

Year Discharge (m3/s) 90% Dependable Year

Discharge (m3/s)

1983-84 2006-07 1994-95

Jun I 30.26 16.84 26.35 II 27.96 14.89 32.20 III 34.11 19.86 30.01

Jul I 52.74 30.91 40.11 II 51.14 33.74 48.12 III 57.63 40.07 33.64

Aug I 67.79 42.95 26.94 II 35.80 29.55 24.45 III 27.44 26.62 22.59

Sep I 24.51 23.17 21.72 II 22.02 15.50 23.24 III 34.11 12.33 16.76

Oct I 9.52 11.27 13.30 II 9.89 10.82 10.89 III 11.42 10.56 10.18

Nov I 13.56 10.26 8.94 II 12.62 9.92 8.23 III 10.69 9.79 7.94

Dec I 9.08 9.73 7.26 II 8.74 9.62 6.81 III 8.57 9.55 6.62



Month Period 50% Dependable Year

Discharge (m3/s) 75% Dependable

Year Discharge (m3/s) 90% Dependable Year

Discharge (m3/s)

1983-84 2006-07 1994-95

Jan I 6.22 7.60 6.45 II 6.00 6.99 6.18 III 5.73 7.60 5.97

Feb I 5.64 8.01 5.45 II 6.19 9.02 6.16 III 6.01 8.12 6.22

Mar I 7.52 10.73 6.06 II 8.17 11.09 6.35 III 8.85 12.70 8.16

Apr I 10.45 20.18 8.45 II 11.24 22.54 9.23 III 19.35 23.81 10.76

August I 24.10 17.32 13.11 II 23.40 23.40 19.65 III 23.28 32.91 15.84

The Ministry of Environment & Forest and Government of Himachal Pradesh guidelines

suggests that all hydel projects shall release a minimum discharge downstream of Diversion

structures called as “Environmental flow” to safeguard flora and fauna of river in the lower

reaches from adverse effects. Keeping in view notification No. MPP-F (1)2/2005-VII of July 2011

issued by Government of Himachal Pradesh, for the purpose of determination of minimum

ecological discharge, the threshold value of not less than 15% of minimum flow observed in lean

season inflow (December – February) is adopted. The minimum lean season flow of BHEP-I at

intake location works out to 4.29 m3/s based on long term flow series from 1972-73 to 2010-11.

Hence, for this project the ecological release being 15% of the minimum inflow i.e.0.64 m3/s has

been considered for ecological & environmental considerations. The computation of

environmental discharge is presented in Annexure-8.1.

The net available discharge for power generation after releasing the environmental discharge is

given in Annexure-8.2.

As the project is being designed for 24.0 MW, for the rated head of 93.0 m, the design discharge

works out to be 29.50 m3/sec and with 15% overload on rated power, the discharge required is

34.74 m3/sec. The availability of design discharge (29.50 m3/sec) in a 75% dependable year is

for about 50 days and in a 50% dependable year, it is for about 80 days. Being a Small Hydro

Project of installed capacity under 25 MW, the project capacity optimization and energy

calculations have been computed for 75% dependable year discharge data.



8.4 HEAD AVAILABLE FOR POWER GENERATION

The BHEP-I proposes to utilize the hydropower potential of Budhil nallah. The gross head

available to the project for exploitation is 99.50 m. The actual net head available to the project

depends on type of Intake structure used, turbine type and selection of water conductor system.

A barrage with Intake is proposed as diversion structure and Horizontal Francis type turbines are

proposed to exploit the hydro power potential of this project. The gross head available to the

project for power generation is accordingly determined based on the water level at Intake

structure and the tail water level in tail race channel. The net head available for power

generation is estimated as follows:

Table-8.2: Project features considered for Net Head Calculation

Full Supply Level at Intake El. 1835.50 m

Full Supply Level at Collection Pool : El. 1835.00 m

Max. Tail Water Level (all the Machines Running with 15% Over Load on rated Power)

: El.1736.30 m

Min. Tail Water Level (One Machine Running with 50% of Design Discharge)

: El.1734.15 m

Normal Tail Water Level (All the Machines are Running with Design Discharge)

: El.1736.00 m

Total Head Loss in Project (with Rated Design Rated Discharge)

: 6.50 m

Max. Net Head (1835.50 - 1734.15 - 0.78) : 100.57 m

Min. Net Head (1835.50 - 1736.30 - 8.46) : 90.74 m

Rated Net Head (1835.50 - 1736.0 - 6.50) : 93.0 m

The summary of net heads for different discharges of the project & the head loss calculations of

the project have been indicated in Annexure-8.3 & 8.4 respectively.

8.5 COMPUTATION OF UNRESTRICTED ENERGY

For estimating unrestricted energy the flow series between 1972-73 and 2010-11, variable net

heads has been considered corresponding to unrestricted flow available at intake of BHEP-I

after releasing the ecological flow.

The power potential studies have been carried out considering the 10-Daily flow series of BHEP-

I at diversion site for the period 1972-73 to 2010-11. The project parameters considered for

power potential studies are presented in the following Table-8.3.



Table-8.3: Project features considered for Power Potential Studies Net Head 93.0 m

Type of Turbine : Horizontal Francis

Efficiency of Turbine : 92.50%

Efficiency of Generator : 96.50%

Combined Efficiency : 89.26%

Based on above parameters, the unrestricted energy that can be generated in various

hydrological years is estimated as per formula given below. The summary of unrestricted energy

corresponding to hydrological years is given in Table-8.4 and detailed summury of unrestricted

energy & restricted energy corresponding to hydrological years are indicated in Annexure-8.5.

The power generated is estimated as:

P = g* Q*H*η/1000

Where, P = Power in ‘MW’

Q = Discharge in ‘m3/s’

H = Net Head in ‘m’

g= Acceleration due to gravity. ‘9.81 m/s2’

η = Combined efficiency ’89.26%’

Based on Power generation potential, the gross energy generation potential is calculated as

E = P*T/1000

Where, E = Energy in ‘GWh’

T = Plant operation time in ‘hrs’

Table-8.4: Un-restricted Energy Corresponding to Hydrological Years

S. No. Year Unrestricted Energy (GWh)

1 1972-73 162.68

2 1973-74 164.94

3 1974-75 155.18

4 1975-76 215.00

5 1976-77 185.55

6 1977-78 204.41

7 1978-79 203.56

8 1979-80 152.75

9 1980-81 153.24

10 1981-82 154.79

11 1982-83 156.02

12 1983-84 144.45

13 1984-85 128.31



S. No. Year Unrestricted Energy (GWh)

14 1985-86 122.70

15 1986-87 113.16

16 1987-88 132.17

17 1988-89 120.47

18 1989-90 137.74

19 1990-91 87.69

20 1991-92 100.26

21 1992-93 134.52

22 1993-94 130.94

23 1994-95 110.50

24 1995-96 114.83

25 1996-97 125.93

26 1997-98 148.14

27 1998-99 146.92

28 1999-00 155.96

29 2000-01 137.51

30 2001-02 156.10

31 2002-03 139.85

32 2003-04 135.75

33 2004-05 109.07

34 2005-06 164.87

35 2006-07 123.26

36 2007-08 118.06

37 2008-09 155.20

38 2009-10 172.26

39 2010-11 186.11

8.6 OPTIMISATION OF INSTALLED CAPACITY

From the hydrological flow series in Table-8.1 and rated net head, power output and annual

energy generation has been computed for 75% dependable year discharge (2006-07).

Restricted as well as unrestricted energy generation has been calculated with installed capacity

ranging from 18 MW to 28 MW with incremental step of 1.0 MW.

In these calculations, three machines have been considered in view of availability of adequate

minimum discharge in the stream. Based on above, the detailed calculations for annual energy

generation for unrestricted as well as restricted power output for 75% dependable discharge

series have been carried out and are indicated in Annexure-8.7.



The annual energy generation for various installed capacities, annual plant load factor (PLF) and

Incremental energy benefit per MW increase in installed capacity have been summarized below

in Table-8.5 for ready reference.

Table-8.5: Summary of Power potential studies for 75% dependable year flow series

Installed Capacity

(MW)

Un-restricted Energy (GWh)

Annual Energy (GWh)

Energy Per MW

(GWh/MW)

Incremental Energy Vs

Incremental Capacity

(∆kWh/∆kW)

Annual Load

Factor (%)

% Capacity

Utilisation

18 123.26 106.43 5.91 - 67.50% 86.35% 19 123.26 109.06 5.74 2.63 65.53% 88.48% 20 123.26 110.92 5.55 1.86 63.31% 89.99% 21 123.26 112.66 5.36 1.74 61.24% 91.40% 22 123.26 114.30 5.20 1.64 59.31% 92.73% 23 123.26 115.78 5.03 1.48 57.46% 93.93% 24 123.26 117.14 4.88 1.36 55.72% 95.04% 25 123.26 118.35 4.73 1.21 54.04% 96.02% 26 123.26 119.35 4.59 1.00 52.40% 96.83% 27 123.26 120.00 4.44 0.65 50.74% 97.36% 28 123.26 120.50 4.30 0.50 49.13% 97.76%

A graph is drawn with Incremental energy on ordinate and installed capacity on abscissa and is

presented in the Figure-8.1

From the Figure, it is observed that Incremental energy Vs Incremental capacity curve is falling

steeply at the Installed capacity 24 MW. The other factors such as ΔkWh/ΔkW, Annual Plant

load factor and Potential exploited for 24 MW are 1.36, 55.72% and 95.04% respectively which

are acceptable values as per the current Hydro power project norms. Hence 24 MW has been

considered as optimum installed capacity of the project. At 15% Continuous over Load (COL)

on rated power have been calculated as 120.28 GWh with a plant load factor of 57.21%. From

the Figure-8.1, it is observed that there is no significant change in Incremental energy benefits

after capacity of 28 MW.



Figure-8.1: Variation of Incremental Annual Energy with Installed Capacity

Similar studies have also been carried out considering saleable energy which has been

calculated after making the allowance for the losses and free power to HPSEB as per details

given below

a) Auxiliary Consumption & Transformation losses - 0.75% of generated energy

b) Transmission losses - 0.50% of generated energy

c) Local Area Development Fund (LADF) charges - 1% of deliverable energy

d) Royalty Charges - 15% of deliverable energy

Thus saleable energy has been calculated for various installed capacities ranging from 18 MW

to 28 MW in 75% dependable year corresponding to 100% plant availability. A graph is drawn

with Incremental Saleable Energy on ordinate and installed capacity on abscissa, and is

presented in the Figure-8.2.

From the Figure, it can be observed that Saleable Incremental energy Vs Incremental capacity

curve is falling steeply at the Installed capacity of 24 MW which indicates that the benefit cost

ratio of project would go below unity by increasing the capacity beyond 24 MW. Hence Optimum

capacity as 24 MW is justified in this case also. Summary of the saleable energy Study is

presented in the Table-8.6.



Thus saleable energy for the first 12 years has been calculated for various installed capacities

ranging from 18 MW to 28 MW in 75% dependable year at 100% plant availability for 39 years.

A graph is drawn with Incremental Saleable Energy on ordinate and installed capacity on

abscissa, and is presented in the Figure-8.2.

From the Figure, it can be observed that Saleable Incremental energy Vs Incremental capacity

curve is falling steeply at the Installed capacity of 24 MW which indicates that the benefit cost

ratio of project would go below unity by increasing the capacity beyond 24 MW. Hence Optimum

capacity as 24 MW is justified in this case also. Summary of the saleable energy Study is

presented in the Table-8.6.

Figure-8.2: Variation of Incremental Annual Saleable Energy with Installed Capacity



Table-8.6: Summary of Saleable Energies in 75% Dependable Year for Various Installed Capacities

Installed Capacity

(MW)

Saleable Energy (GWh)

Energy Per MW

(GWh/MW)

Incremental Energy Vs Incremental Capacity

(kWh/kW)

18 88.28 4.90 -

19 90.47 4.76 2.18

20 92.01 4.60 1.54

21 93.45 4.45 1.44

22 94.81 4.31 1.36

23 96.04 4.18 1.23

24 97.17 4.05 1.13

25 98.17 3.93 1.00

26 99.00 3.81 0.83

27 99.54 3.69 0.54

28 99.95 3.57 0.41

8.7 DESIGN ENERGY OF THE PROJECT

For the gross head of 99.50 m and installed capacity of 24 MW, the design discharge works out

to 29.50 m3/s and the corresponding design head is adopted as 93.0 m. From flow duration

curve, it is seen that discharge of 29.5 m3/s corresponds to 23.70% flow availability.

The energy that can be generated in 50% dependable year and 90% dependable year works out

to be 119.93 GWh & 102.83 GWh and 117.59 GWh & 101.37 GWh corresponding to 100 % &

95% plant availability respectively. Detailed calculations are presented in Annexure-8.6 & 8.8.

The energy that can be generated in 75% dependable year works out to be 117.14 GWh and

115.36 GWh corresponding to100 % & 95% plant availability respectively. The plant load factor

corresponding to 95% plant availability works out to 54.87%. Detailed calculations are presented

in Annexure-8.7.

The energy calculations for incremental capacities corresponding to variable heads are

presented in Annexure-8.9.

8.8 NUMBER OF UNITS TO BE INSTALLED

The annual energy generated by 24 MW plant for various number of machines has been

calculated based on the assumption that the unit shall be operated under the minimum load of

50% of its capacity. The annual energy variation with number of machines is presented in

Figure-8.3.



Figure-8.3: Variation of Annual Energy with the Number of Units

From the above figure, it is observed that the annual energy generation increases with increase

in the number of machines from a single unit to 3 units due to optimum use of available

discharge and beyond that there is no change in the energy generation.

As a general practice, it is preferable to provide at least two units for run-of- the river type

projects as it gives higher flexibility of operation during the lean season flows. It is seen in the

case of BHEP-I with the increase in number of machines from two to three, there is a gain of

6.00 GWh (Approx. 6%) in annual energy. The nominal increase in cost of Civil and Electro-

mechanical works due to the increase in number of units from 2 to 3 is more than adequately

compensated by the increased energy generation. Moreover, increase in annual energy is

stagnant beyond three units. Hence, it is prudent to consider three units as the optimum number

of units.

8.9 CONCLUSIONS

Power potential studies have been carried out considering the 10-Daily derived flow series for

the period 1972-73 to 2010-11. Since the envisaged installed capacity of the project is less than

25 MW, hence, 75% Dependable year is considered for project capacity optimization studies.

Power potential studies indicate that installed capacity of 24 MW, comprising of 3 generating

units of 8.0 MW each, would be the most favorable option. The design energy, which is the

energy generated in the 75 % dependable year with 95 % availability of Installed capacity, works

out to 115.36 GWh with a Plant load factor of 54.87 %.



Annexure-8.1 10-Daily Flow Series at Proposed Diversion Site (1972-73 to 2010-11)

Month Period 1972-73 1973-74 1974-75 1975-76 1976-77 1977-78 1978-79 1979-80 1980-81 1981-82 1982-83 1983-84 1984-85 1985-86 1986-87 1987-88 1988-89 1989-90 1990-91 1991-92

Jun

I 34.70 36.82 23.87 42.57 34.37 31.61 51.76 32.03 25.00 25.87 36.41 30.26 31.55 22.95 18.68 31.37 31.40 28.49 30.69 19.30

II 34.37 47.39 33.28 43.20 37.10 35.62 48.85 43.41 31.96 28.00 42.85 27.96 35.50 23.28 31.01 35.33 35.33 30.19 17.67 17.02

III 37.87 47.44 34.79 50.17 37.72 54.19 57.45 63.34 40.40 38.59 37.21 34.11 34.38 24.35 37.94 34.25 34.22 44.83 15.12 31.24

Jul

I 48.19 48.06 40.56 50.17 41.16 64.93 60.12 56.74 45.60 38.82 44.97 52.74 39.24 27.06 31.78 39.01 39.04 39.86 15.31 33.39

II 52.92 47.54 52.67 55.33 46.97 68.71 60.87 55.89 60.02 49.28 51.13 51.14 36.75 45.38 28.55 36.58 36.57 48.75 27.39 29.59

III 46.75 45.99 50.07 70.29 49.17 59.04 56.74 51.95 55.96 55.81 54.70 57.63 42.23 43.35 34.92 42.07 42.02 57.01 25.15 22.50

Aug

I 42.83 48.96 49.37 61.37 58.25 66.34 53.48 52.88 56.63 49.27 54.91 67.79 34.63 43.23 30.15 34.43 34.46 67.84 19.04 20.86

II 43.33 54.41 48.49 59.52 58.16 55.98 57.16 51.26 50.93 46.08 48.88 35.80 23.51 34.53 35.98 23.37 23.40 35.83 12.63 19.97

III 40.45 50.73 44.08 64.36 59.61 44.46 47.50 42.82 35.48 37.30 37.01 27.44 52.96 27.19 21.21 32.45 32.41 27.47 15.04 16.57

Sep

I 32.86 46.04 35.45 51.16 60.33 41.99 30.23 34.78 30.61 29.21 34.08 24.51 50.08 24.05 18.68 28.04 28.04 24.53 11.45 17.03

II 26.08 41.15 27.86 50.58 54.30 41.27 26.03 26.97 26.22 21.27 31.35 22.02 33.70 17.90 15.32 20.58 20.57 22.05 9.94 17.23

III 23.11 35.04 23.37 42.96 45.13 36.48 22.48 20.43 22.16 17.52 27.95 34.11 23.74 16.72 15.53 17.89 17.85 34.15 8.92 14.67

Oct

I 21.54 26.25 16.98 33.90 37.99 33.50 19.01 17.36 19.11 14.54 23.90 9.52 18.23 15.45 13.18 14.56 14.52 9.53 7.21 11.42

II 19.89 20.38 14.58 30.65 33.48 31.15 16.40 14.00 16.63 12.49 18.23 9.89 12.71 13.26 11.61 12.13 12.13 9.89 6.65 9.89

III 18.20 15.98 13.55 27.89 25.48 25.95 14.87 11.71 14.70 10.99 14.00 11.42 10.26 10.26 9.78 10.34 10.35 11.42 6.64 9.53

Nov

I 15.56 13.14 11.06 26.19 21.95 22.62 103.48 9.67 12.31 10.56 11.58 13.56 8.40 9.54 8.67 9.17 9.20 13.59 6.29 9.32

II 13.46 12.47 9.51 24.58 20.05 20.95 12.30 8.66 10.72 9.21 8.50 12.62 7.84 8.38 8.09 8.45 8.41 12.63 6.08 8.62

III 11.86 11.64 7.94 20.79 13.71 19.09 11.59 8.13 9.45 8.55 7.45 10.69 7.48 7.33 8.08 7.91 7.86 10.70 5.59 8.33

Dec

I 9.78 9.97 8.66 18.82 12.30 14.21 11.32 7.56 9.11 8.07 7.07 9.08 7.11 7.02 7.94 7.10 7.08 9.10 5.21 7.78

II 8.54 8.49 8.85 16.51 11.02 12.67 9.91 7.24 8.18 7.73 9.27 8.74 6.67 7.07 7.45 6.29 6.33 8.75 4.55 7.28

III 7.32 7.60 7.64 14.68 9.64 11.91 8.71 6.98 7.11 7.06 7.19 8.57 6.18 7.24 6.61 6.11 6.08 8.58 5.03 6.93

Jan

I 6.47 6.87 7.68 12.83 8.90 9.96 7.61 6.63 6.80 6.91 6.18 6.22 6.03 7.16 6.19 5.93 7.51 4.90 6.91 6.55

II 7.02 6.37 6.96 11.97 8.73 9.74 7.39 6.43 6.52 6.70 6.18 6.00 5.56 7.32 5.99 6.01 6.68 4.60 6.46 6.52

III 7.02 6.47 6.56 10.78 9.22 9.29 8.03 6.53 6.37 6.88 6.53 5.73 5.23 7.07 5.69 6.02 6.33 4.41 6.23 6.48

Feb

I 6.59 6.66 7.25 11.02 9.10 8.57 8.25 6.73 6.82 7.69 5.41 5.64 4.91 7.00 5.63 5.86 6.01 4.35 6.34 6.39

II 7.05 6.83 7.56 11.63 9.79 8.61 8.80 7.09 7.61 8.43 4.90 6.19 4.57 7.15 6.16 5.51 5.73 4.67 6.63 7.44

III 7.68 7.19 7.42 11.72 9.99 8.90 8.79 7.05 9.60 9.13 5.54 6.01 4.29 7.34 6.73 6.63 6.18 5.10 7.51 7.37

Mar

I 7.76 7.20 8.57 12.01 8.31 9.67 12.47 7.40 10.14 11.49 6.55 7.52 4.61 7.15 7.49 9.44 6.62 5.29 8.14 7.56

II 8.82 7.55 9.57 12.40 8.45 10.29 12.18 7.50 10.86 13.31 7.52 8.17 5.24 9.54 8.13 11.94 6.85 6.52 8.37 8.14

III 12.79 9.55 10.98 13.82 8.31 10.13 12.93 8.31 11.58 16.20 9.32 8.85 6.73 10.00 8.81 12.19 7.76 8.41 10.09 9.73

Apr

I 16.31 11.11 13.63 15.55 10.73 10.73 20.09 10.16 13.36 21.12 12.35 10.45 7.06 11.46 10.42 16.19 9.16 9.69 13.69 11.24

II 20.70 12.18 15.86 16.34 11.28 14.39 23.17 12.58 15.11 22.60 14.17 11.24 9.63 18.23 11.18 24.39 10.00 11.21 14.54 12.73

III 29.21 14.44 23.09 17.33 12.83 20.84 27.81 14.65 17.00 28.48 19.05 19.35 12.76 20.94 19.25 22.61 11.99 12.83 17.95 15.42

August

I 34.22 16.93 28.99 20.57 16.40 31.49 32.59 16.51 19.81 32.81 23.78 24.10 13.30 21.72 23.98 23.97 16.97 16.20 19.70 17.14

II 32.03 18.78 31.38 23.85 18.70 36.26 30.86 16.35 20.94 31.39 28.40 23.40 14.71 22.08 23.29 27.59 20.73 22.53 22.73 20.98

III 32.37 22.93 37.62 28.68 21.76 45.04 31.90 16.95 24.09 34.54 27.86 23.28 23.00 19.13 23.17 28.42 24.82 22.25 25.09 22.66

Average Yearly 22.93 23.24 21.83 30.17 26.12 28.79 28.70 21.52 21.52 21.78 22.01 20.33 18.08 17.19 15.92 18.61 16.96 19.39 12.28 14.02

Annual Inflow (Mm3) 723.25 732.80 688.30 951.53 823.77 908.06 905.00 678.63 678.80 686.70 694.11 641.04 570.06 542.08 502.18 587.04 534.89 611.53 387.17 442.24 Minimum Inflow in Lean Season (Dec-Feb)

6.47 6.37 6.56 10.78 8.73 8.57 7.39 6.43 6.37 6.70 4.90 5.64 4.29 7.00 5.63 5.51 5.73 4.35 4.55 6.39



10-Daily Flow Series at Proposed Diversion Site (1972-73 to 2010-11) Month Period 1992-93 1993-94 1994-95 1995-96 1996-97 1997-98 1998-99 1999-00 2000-01 2001-02 2002-03 2003-04 2004-05 2005-06 2006-07 2007-08 2008-09 2009-10 2010-11

Jun

I 31.88 24.22 26.35 21.14 27.32 27.27 16.21 33.74 23.64 31.91 20.77 47.24 21.84 23.74 16.84 22.70 39.47 37.94 41.90

II 35.01 33.85 32.20 20.47 28.46 50.23 22.03 33.99 36.50 34.81 26.76 49.16 24.02 30.49 14.89 29.39 45.94 34.70 59.96

III 42.56 41.60 30.01 31.79 21.04 42.25 30.01 34.31 36.26 37.60 26.83 45.14 20.29 62.07 19.86 30.10 31.85 46.61 62.13

Jul

I 47.80 42.06 40.11 36.00 22.96 26.73 33.91 48.13 40.63 39.18 36.80 36.27 20.90 87.99 30.91 29.00 55.59 48.53 66.63

II 39.45 45.91 48.12 35.44 22.41 27.24 41.10 42.23 48.84 50.65 33.50 25.67 19.86 69.12 33.74 21.47 52.68 66.66 60.09

III 45.92 55.59 33.64 35.59 49.79 31.13 43.09 31.55 45.63 44.00 35.22 25.57 18.14 57.44 40.07 27.79 49.19 70.61 56.50

Aug

I 45.03 52.66 26.94 32.24 32.31 35.60 55.33 29.55 38.77 54.98 35.48 23.93 21.68 51.66 42.95 30.97 56.03 58.25 55.79

II 33.46 46.63 24.45 28.80 23.42 36.95 40.30 34.72 26.94 40.96 37.18 25.22 17.15 45.45 29.55 25.09 55.96 56.83 55.14

III 32.77 37.04 22.59 24.36 23.65 39.44 37.58 28.56 23.10 36.51 27.76 23.38 28.65 37.40 26.62 28.25 49.67 43.00 55.99

Sep

I 28.71 24.22 21.72 19.81 22.52 33.05 25.23 20.06 32.41 23.84 22.61 23.57 15.09 34.61 23.17 38.44 25.81 51.07 37.01

II 26.47 18.28 23.24 17.29 55.90 19.51 26.18 25.91 18.37 28.94 19.98 21.97 15.24 35.30 15.50 27.50 25.16 29.82 26.15

III 20.42 15.01 16.76 14.63 19.60 15.93 21.29 29.17 18.13 24.72 15.45 19.18 12.24 24.70 12.33 24.04 20.54 27.53 21.33

Oct

I 15.20 13.37 13.30 12.73 29.38 31.30 33.46 33.04 31.45 38.09 28.35 17.37 14.81 18.88 11.27 12.11 16.84 22.39 17.51

II 12.67 11.68 10.89 11.24 16.19 14.61 16.67 23.77 15.67 21.49 12.32 15.83 12.97 16.80 10.82 10.85 13.75 16.22 12.91

III 10.72 9.73 10.18 9.80 15.52 13.10 14.65 23.66 14.41 19.45 11.74 14.55 11.23 13.68 10.56 10.02 11.68 12.64 11.66

Nov

I 9.23 8.80 8.94 9.02 15.09 11.98 12.75 18.40 13.02 17.71 11.08 13.49 10.85 12.29 10.26 9.69 10.56 12.14 10.63

II 8.62 7.86 8.23 8.66 14.20 11.11 10.99 16.04 11.60 16.84 10.19 11.91 10.73 10.33 9.92 8.67 9.73 13.11 9.76

III 8.14 7.39 7.94 8.09 13.65 10.32 9.67 14.63 11.18 16.13 9.32 10.94 10.62 9.88 9.79 8.26 9.11 10.86 9.02

Dec

I 7.84 6.91 7.26 7.28 12.76 9.58 9.53 13.52 10.60 14.35 8.86 10.40 10.37 9.72 9.73 8.46 8.78 10.06 8.76

II 7.47 6.63 6.81 6.99 11.91 8.84 9.37 12.43 9.53 12.71 8.40 9.69 10.21 9.55 9.62 8.93 8.15 9.27 8.02

III 6.79 6.40 6.62 6.90 11.06 8.31 9.56 11.52 9.11 11.90 8.02 9.43 10.18 9.47 9.55 8.50 7.69 8.57 7.80

Jan

I 6.29 6.43 6.45 9.79 8.12 8.68 10.72 8.73 11.19 7.45 9.31 9.69 10.35 9.69 7.60 8.33 7.42 8.06 9.85

II 6.12 6.24 6.18 9.10 7.79 7.95 10.17 8.56 10.24 7.15 9.27 9.50 9.92 9.57 6.99 8.17 7.27 7.45 9.14

III 5.92 5.88 5.97 8.12 7.41 7.07 9.60 8.71 9.00 6.96 9.22 9.62 10.11 9.50 7.60 7.86 7.02 7.15 8.97

Feb

I 5.81 5.91 5.45 7.88 7.60 6.56 9.50 8.23 8.39 6.63 9.34 9.66 9.95 9.53 8.01 7.44 6.93 7.94 10.28

II 5.79 5.99 6.16 7.89 6.92 6.35 9.36 8.79 7.69 6.71 9.98 9.62 10.42 9.62 9.02 6.79 6.93 8.32 11.82

III 5.88 6.47 6.22 8.15 7.47 8.72 9.57 8.72 7.96 6.99 10.40 10.54 10.00 9.76 8.12 4.57 6.94 7.46 11.26

Mar

I 6.06 6.60 6.06 9.24 8.09 9.82 10.53 9.25 7.78 7.43 11.43 11.20 10.87 9.91 10.73 7.67 7.33 8.49 12.13

II 7.08 7.79 6.35 11.43 8.12 12.84 10.19 9.84 7.93 8.25 11.32 13.20 12.43 10.30 11.09 8.97 7.50 8.98 13.14

III 7.93 8.35 8.16 12.04 8.37 18.16 10.47 12.46 9.27 9.74 12.62 13.02 13.00 10.71 12.70 9.27 8.81 9.31 14.00

Apr

I 9.00 10.83 8.45 13.51 9.59 19.92 12.48 14.80 10.89 9.91 15.41 13.49 12.59 9.69 20.18 9.94 11.49 9.98 14.96

II 12.95 9.33 9.23 19.15 10.51 19.92 14.94 17.73 11.94 11.48 20.71 15.66 13.20 9.57 22.54 11.52 13.09 12.04 21.06

III 18.40 11.26 10.76 15.94 12.83 28.23 21.18 17.91 16.87 14.18 26.47 16.40 17.48 9.50 23.81 13.72 14.97 13.82 21.73

August

I 22.53 17.04 13.11 15.93 13.84 29.21 22.78 23.84 18.47 14.88 30.91 16.61 22.51 12.81 17.32 18.11 16.54 19.74 21.37

II 20.20 17.04 19.65 15.18 13.08 28.17 24.93 38.42 21.82 27.28 37.37 23.00 22.27 15.45 23.40 22.56 24.22 23.06 40.09

III 26.92 21.32 15.84 17.31 14.39 34.78 35.83 35.34 19.68 28.75 37.56 22.74 22.03 17.98 32.91 31.63 34.17 32.74 27.13

Average Yearly 18.97 18.40 15.57 16.08 17.59 20.86 20.59 21.95 19.30 21.96 19.66 19.00 15.12 23.17 17.22 16.58 21.80 24.20 26.16

Annual Inflow (Mm3) 598.37 580.19 490.87 507.15 554.73 657.75 649.26 692.26 608.74 692.54 620.15 599.06 476.73 730.70 543.08 522.78 687.50 763.31 824.87 Minimum Inflow in Lean Season (Dec-Feb)

5.79 5.88 5.45 6.90 6.92 6.35 9.36 8.23 7.69 6.63 8.02 9.43 9.92 9.47 6.99 4.57 6.93 7.15 7.80



Annexure-8.2 10-Daily Flow Series Available at BHEP-I Intake for the Power Generation after Environmental Release

Discharge for Environmental Release = 0.64 m3/s

Month Period 1972-73 1973-74 1974-75 1975-76 1976-77 1977-78 1978-79 1979-80 1980-81 1981-82 1982-83 1983-84 1984-85 1985-86 1986-87 1987-88 1988-89 1989-90 1990-91 1991-92

Jun

I 34.06 36.18 23.23 41.93 33.73 30.97 51.12 31.39 24.36 25.23 35.77 29.62 30.91 22.31 18.04 30.73 30.76 27.85 30.05 18.66

II 33.73 46.75 32.64 42.56 36.46 34.98 48.21 42.77 31.32 27.36 42.21 27.32 34.86 22.64 30.37 34.69 34.69 29.55 17.03 16.38

III 37.23 46.80 34.15 49.53 37.08 53.55 56.81 62.70 39.76 37.95 36.57 33.47 33.74 23.71 37.30 33.61 33.58 44.19 14.48 30.60

Jul

I 47.55 47.42 39.92 49.53 40.52 64.29 59.48 56.10 44.96 38.18 44.33 52.10 38.60 26.42 31.14 38.37 38.40 39.22 14.67 32.75

II 52.28 46.90 52.03 54.69 46.33 68.07 60.23 55.25 59.38 48.64 50.49 50.50 36.11 44.74 27.91 35.94 35.93 48.11 26.75 28.95

III 46.11 45.35 49.43 69.65 48.53 58.40 56.10 51.31 55.32 55.17 54.06 56.99 41.59 42.71 34.28 41.43 41.38 56.37 24.51 21.86

Aug

I 42.19 48.32 48.73 60.73 57.61 65.70 52.84 52.24 55.99 48.63 54.27 67.15 33.99 42.59 29.51 33.79 33.82 67.20 18.40 20.22

II 42.69 53.77 47.85 58.88 57.52 55.34 56.52 50.62 50.29 45.44 48.24 35.16 22.87 33.89 35.34 22.73 22.76 35.19 11.99 19.33

III 39.81 50.09 43.44 63.72 58.97 43.82 46.86 42.18 34.84 36.66 36.37 26.80 52.32 26.55 20.57 31.81 31.77 26.83 14.40 15.93

Sep

I 32.22 45.40 34.81 50.52 59.69 41.35 29.59 34.14 29.97 28.57 33.44 23.87 49.44 23.41 18.04 27.40 27.40 23.89 10.81 16.39

II 25.44 40.51 27.22 49.94 53.66 40.63 25.39 26.33 25.58 20.63 30.71 21.38 33.06 17.26 14.68 19.94 19.93 21.41 9.30 16.59

III 22.47 34.40 22.73 42.32 44.49 35.84 21.84 19.79 21.52 16.88 27.31 33.47 23.10 16.08 14.89 17.25 17.21 33.51 8.28 14.03

Oct

I 20.90 25.61 16.34 33.26 37.35 32.86 18.37 16.72 18.47 13.90 23.26 8.88 17.59 14.81 12.54 13.92 13.88 8.89 6.57 10.78

II 19.25 19.74 13.94 30.01 32.84 30.51 15.76 13.36 15.99 11.85 17.59 9.25 12.07 12.62 10.97 11.49 11.49 9.25 6.01 9.25

III 17.56 15.34 12.91 27.25 24.84 25.31 14.23 11.07 14.06 10.35 13.36 10.78 9.62 9.62 9.14 9.70 9.71 10.78 6.00 8.89

Nov

I 14.92 12.50 10.42 25.55 21.31 21.98 102.84 9.03 11.67 9.92 10.94 12.92 7.76 8.90 8.03 8.53 8.56 12.95 5.65 8.68

II 12.82 11.83 8.87 23.94 19.41 20.31 11.66 8.02 10.08 8.57 7.86 11.98 7.20 7.74 7.45 7.81 7.77 11.99 5.44 7.98

III 11.22 11.00 7.30 20.15 13.07 18.45 10.95 7.49 8.81 7.91 6.81 10.05 6.84 6.69 7.44 7.27 7.22 10.06 4.95 7.69

Dec

I 9.14 9.33 8.02 18.18 11.66 13.57 10.68 6.92 8.47 7.43 6.43 8.44 6.47 6.38 7.30 6.46 6.44 8.46 4.57 7.14

II 7.90 7.85 8.21 15.87 10.38 12.03 9.27 6.60 7.54 7.09 8.63 8.10 6.03 6.43 6.81 5.65 5.69 8.11 3.91 6.64

III 6.68 6.96 7.00 14.04 9.00 11.27 8.07 6.34 6.47 6.42 6.55 7.93 5.54 6.60 5.97 5.47 5.44 7.94 4.39 6.29

Jan

I 5.83 6.23 7.04 12.19 8.26 9.32 6.97 5.99 6.16 6.27 5.54 5.58 5.39 6.52 5.55 5.29 6.87 4.26 6.27 5.91

II 6.38 5.73 6.32 11.33 8.09 9.10 6.75 5.79 5.88 6.06 5.54 5.36 4.92 6.68 5.35 5.37 6.04 3.96 5.82 5.88

III 6.38 5.83 5.92 10.14 8.58 8.65 7.39 5.89 5.73 6.24 5.89 5.09 4.59 6.43 5.05 5.38 5.69 3.77 5.59 5.84

Feb

I 5.95 6.02 6.61 10.38 8.46 7.93 7.61 6.09 6.18 7.05 4.77 5.00 4.27 6.36 4.99 5.22 5.37 3.71 5.70 5.75

II 6.41 6.19 6.92 10.99 9.15 7.97 8.16 6.45 6.97 7.79 4.26 5.55 3.93 6.51 5.52 4.87 5.09 4.03 5.99 6.80

III 7.04 6.55 6.78 11.08 9.35 8.26 8.15 6.41 8.96 8.49 4.90 5.37 3.65 6.70 6.09 5.99 5.54 4.46 6.87 6.73

Mar

I 7.12 6.56 7.93 11.37 7.67 9.03 11.83 6.76 9.50 10.85 5.91 6.88 3.97 6.51 6.85 8.80 5.98 4.65 7.50 6.92

II 8.18 6.91 8.93 11.76 7.81 9.65 11.54 6.86 10.22 12.67 6.88 7.53 4.60 8.90 7.49 11.30 6.21 5.88 7.73 7.50

III 12.15 8.91 10.34 13.18 7.67 9.49 12.29 7.67 10.94 15.56 8.68 8.21 6.09 9.36 8.17 11.55 7.12 7.77 9.45 9.09

Apr

I 15.67 10.47 12.99 14.91 10.09 10.09 19.45 9.52 12.72 20.48 11.71 9.81 6.42 10.82 9.78 15.55 8.52 9.05 13.05 10.60

II 20.06 11.54 15.22 15.70 10.64 13.75 22.53 11.94 14.47 21.96 13.53 10.60 8.99 17.59 10.54 23.75 9.36 10.57 13.90 12.09

III 28.57 13.80 22.45 16.69 12.19 20.20 27.17 14.01 16.36 27.84 18.41 18.71 12.12 20.30 18.61 21.97 11.35 12.19 17.31 14.78

August

I 33.58 16.29 28.35 19.93 15.76 30.85 31.95 15.87 19.17 32.17 23.14 23.46 12.66 21.08 23.34 23.33 16.33 15.56 19.06 16.50

II 31.39 18.14 30.74 23.21 18.06 35.62 30.22 15.71 20.30 30.75 27.76 22.76 14.07 21.44 22.65 26.95 20.09 21.89 22.09 20.34

III 31.73 22.29 36.98 28.04 21.12 44.40 31.26 16.31 23.45 33.90 27.22 22.64 22.36 18.49 22.53 27.78 24.18 21.61 24.45 22.02

Average Yearly 22.29 22.60 21.19 29.53 25.48 28.15 28.06 20.88 20.88 21.14 21.37 19.69 17.44 16.55 15.28 17.97 16.32 18.75 11.64 13.38

Annual Inflow (Mm3) 703.1 712.6 668.1 931.3 803.6 887.9 884.8 658.4 658.6 666.5 673.9 620.9 549.9 521.9 482 566.9 514.7 591.3 367 422.1



10-Daily Flow Series Available at BHEP-I Intake for the Power Generation after Environmental Release

Discharge for Environmental Release = 0.64 m3/s

Month Period 1992-93 1993-94 1994-95 1995-96 1996-97 1997-98 1998-99 1999-00 2000-01 2001-02 2002-03 2003-04 2004-05 2005-06 2006-07 2007-08 2008-09 2009-10 2010-11

Jun

I 31.24 23.58 25.71 20.50 26.68 26.63 15.57 33.10 23.00 31.27 20.13 46.60 21.20 23.10 16.20 22.06 38.83 37.30 41.26

II 34.37 33.21 31.56 19.83 27.82 49.59 21.39 33.35 35.86 34.17 26.12 48.52 23.38 29.85 14.25 28.75 45.30 34.06 59.32

III 41.92 40.96 29.37 31.15 20.40 41.61 29.37 33.67 35.62 36.96 26.19 44.50 19.65 61.43 19.22 29.46 31.21 45.97 61.49

Jul

I 47.16 41.42 39.47 35.36 22.32 26.09 33.27 47.49 39.99 38.54 36.16 35.63 20.26 87.35 30.27 28.36 54.95 47.89 65.99

II 38.81 45.27 47.48 34.80 21.77 26.60 40.46 41.59 48.20 50.01 32.86 25.03 19.22 68.48 33.10 20.83 52.04 66.02 59.45

III 45.28 54.95 33.00 34.95 49.15 30.49 42.45 30.91 44.99 43.36 34.58 24.93 17.50 56.80 39.43 27.15 48.55 69.97 55.86

Aug

I 44.39 52.02 26.30 31.60 31.67 34.96 54.69 28.91 38.13 54.34 34.84 23.29 21.04 51.02 42.31 30.33 55.39 57.61 55.15

II 32.82 45.99 23.81 28.16 22.78 36.31 39.66 34.08 26.30 40.32 36.54 24.58 16.51 44.81 28.91 24.45 55.32 56.19 54.50

III 32.13 36.40 21.95 23.72 23.01 38.80 36.94 27.92 22.46 35.87 27.12 22.74 28.01 36.76 25.98 27.61 49.03 42.36 55.35

Sep

I 28.07 23.58 21.08 19.17 21.88 32.41 24.59 19.42 31.77 23.20 21.97 22.93 14.45 33.97 22.53 37.80 25.17 50.43 36.37

II 25.83 17.64 22.60 16.65 55.26 18.87 25.54 25.27 17.73 28.30 19.34 21.33 14.60 34.66 14.86 26.86 24.52 29.18 25.51

III 19.78 14.37 16.12 13.99 18.96 15.29 20.65 28.53 17.49 24.08 14.81 18.54 11.60 24.06 11.69 23.40 19.90 26.89 20.69

Oct

I 14.56 12.73 12.66 12.09 28.74 30.66 32.82 32.40 30.81 37.45 27.71 16.73 14.17 18.24 10.63 11.47 16.20 21.75 16.87

II 12.03 11.04 10.25 10.60 15.55 13.97 16.03 23.13 15.03 20.85 11.68 15.19 12.33 16.16 10.18 10.21 13.11 15.58 12.27

III 10.08 9.09 9.54 9.16 14.88 12.46 14.01 23.02 13.77 18.81 11.10 13.91 10.59 13.04 9.92 9.38 11.04 12.00 11.02

Nov

I 8.59 8.16 8.30 8.38 14.45 11.34 12.11 17.76 12.38 17.07 10.44 12.85 10.21 11.65 9.62 9.05 9.92 11.50 9.99

II 7.98 7.22 7.59 8.02 13.56 10.47 10.35 15.40 10.96 16.20 9.55 11.27 10.09 9.69 9.28 8.03 9.09 12.47 9.12

III 7.50 6.75 7.30 7.45 13.01 9.68 9.03 13.99 10.54 15.49 8.68 10.30 9.98 9.24 9.15 7.62 8.47 10.22 8.38

Dec

I 7.20 6.27 6.62 6.64 12.12 8.94 8.89 12.88 9.96 13.71 8.22 9.76 9.73 9.08 9.09 7.82 8.14 9.42 8.12

II 6.83 5.99 6.17 6.35 11.27 8.20 8.73 11.79 8.89 12.07 7.76 9.05 9.57 8.91 8.98 8.29 7.51 8.63 7.38

III 6.15 5.76 5.98 6.26 10.42 7.67 8.92 10.88 8.47 11.26 7.38 8.79 9.54 8.83 8.91 7.86 7.05 7.93 7.16

Jan

I 5.65 5.79 5.81 9.15 7.48 8.04 10.08 8.09 10.55 6.81 8.67 9.05 9.71 9.05 6.96 7.69 6.78 7.42 9.21

II 5.48 5.60 5.54 8.46 7.15 7.31 9.53 7.92 9.60 6.51 8.63 8.86 9.28 8.93 6.35 7.53 6.63 6.81 8.50

III 5.28 5.24 5.33 7.48 6.77 6.43 8.96 8.07 8.36 6.32 8.58 8.98 9.47 8.86 6.96 7.22 6.38 6.51 8.33

Feb

I 5.17 5.27 4.81 7.24 6.96 5.92 8.86 7.59 7.75 5.99 8.70 9.02 9.31 8.89 7.37 6.80 6.29 7.30 9.64

II 5.15 5.35 5.52 7.25 6.28 5.71 8.72 8.15 7.05 6.07 9.34 8.98 9.78 8.98 8.38 6.15 6.29 7.68 11.18

III 5.24 5.83 5.58 7.51 6.83 8.08 8.93 8.08 7.32 6.35 9.76 9.90 9.36 9.12 7.48 3.93 6.30 6.82 10.62

Mar

I 5.42 5.96 5.42 8.60 7.45 9.18 9.89 8.61 7.14 6.79 10.79 10.56 10.23 9.27 10.09 7.03 6.69 7.85 11.49

II 6.44 7.15 5.71 10.79 7.48 12.20 9.55 9.20 7.29 7.61 10.68 12.56 11.79 9.66 10.45 8.33 6.86 8.34 12.50

III 7.29 7.71 7.52 11.40 7.73 17.52 9.83 11.82 8.63 9.10 11.98 12.38 12.36 10.07 12.06 8.63 8.17 8.67 13.36

Apr

I 8.36 10.19 7.81 12.87 8.95 19.28 11.84 14.16 10.25 9.27 14.77 12.85 11.95 9.05 19.54 9.30 10.85 9.34 14.32

II 12.31 8.69 8.59 18.51 9.87 19.28 14.30 17.09 11.30 10.84 20.07 15.02 12.56 8.93 21.90 10.88 12.45 11.40 20.42

III 17.76 10.62 10.12 15.30 12.19 27.59 20.54 17.27 16.23 13.54 25.83 15.76 16.84 8.86 23.17 13.08 14.33 13.18 21.09

August

I 21.89 16.40 12.47 15.29 13.20 28.57 22.14 23.20 17.83 14.24 30.27 15.97 21.87 12.17 16.68 17.47 15.90 19.10 20.73

II 19.56 16.40 19.01 14.54 12.44 27.53 24.29 37.78 21.18 26.64 36.73 22.36 21.63 14.81 22.76 21.92 23.58 22.42 39.45

III 26.28 20.68 15.20 16.67 13.75 34.14 35.19 34.70 19.04 28.11 36.92 22.10 21.39 17.34 32.27 30.99 33.53 32.10 26.49

Average Yearly 18.33 17.76 14.93 15.44 16.95 20.22 19.95 21.31 18.66 21.32 19.02 18.36 14.48 22.53 16.58 15.94 21.16 23.56 25.52

Annual Inflow (Mm3) 578.2 560 470.7 487 534.5 637.6 629.1 672.1 588.6 672.4 600 578.9 456.5 710.5 522.9 502.6 667.3 743.1 804.7



Annexure-8.3

Head Loss Summary for Different Discharges

Type of Turbine = Horizontal Francis

Sl.No. Description Q (m3/sec)

FRL at Collection Pool (m)

Head Loss (m)

TWL (m)

Net Head (m)

Efficiency % (Turbine)

Efficiency % (Generator)

Efficiency % (Combined)

Power (MW)

1 Design Discharge (QN) 29.50 1835.00 6.00 1736.00 93.00 92.50 96.50 89.26 24.00

2 Discharge for 15% Over Load on Installed Capacity (P15% OL)

34.74 1835.00 7.96 1736.30 90.74

3 Rated Discharge for One Unit (Q1)

9.83 1835.00 1.10 1734.62 99.28

4 50% of rated Discharge for One Unit (Q50%)

4.90 1835.00 0.28 1734.15 100.57

* Crest Level of TRC = 1733.35 m

# Width of TRC = 4.00 m



Annexure-8.4

Head Loss Calculations of the Project Installed Capacity = 24.0 MW Turbine Flow = 29.50 m3/s Number of units = 3 units

Maximum Regulated Water Level (MRWL) = 1835.50 m

Normal Tail Water Level at P/H = 1736.00 m Combined Efficiency =89.26 %

Si.No. Description Formula used No. W1 (or)

Dia. (m)

H1 (m)

W2 (or) Dia. (m)

H2 (m)

A1 (m2)

A2 (m2)

L (m)

Hydraulic depth R

(m) n k

V1 (m/s)

V2 (m/s)

HL (m)

1 HEAD LOSS UPTO DESILTING CHAMBER 0.50

2 Trash rack Losses in Collection Pool 1 5.20 12.00 46.800 0.550 0.630 0.01

3 HRT

a Entrance Losses h=ke.(V2/2g) 1 5.20 5.70 29.64 0.15 1.00 0.01

b Tunnel Friction (Concrete Lining) h=v2*n2*L/(R4/3) 1 3.60 11.729 2485.00 0.910 0.015 2.52 4.01

c Bend Losses h=k.v2/2g 2 3.60 11.729 0.060 2.52 0.04

d Transistion Before Surge Shaft

h=kex.[(V12/2g)-

(V22/2g)] 1 3.60 3.60 3.60 11.729 12.960 0.110 2.52 2.276 0.01

e Transition After Surge Shaft h=kc.[(V22/2g)-(V1

2/2g)] 1 3.60 3.60 3.60 12.960 11.729 0.100 2.28 2.515 0.01

f Surge Shaft Gate Goove Loss h=kg.v2/2g 1 3.00 3.60 10.800 0.100 2.73 0.04

4.13

4 PENSTOCK

a Tunnel Friction (Steel Lining) h=v2*n2*L/(R4/3) 1 2.80 6.158 124.00 0.700 0.010 4.79 0.46

b Bend Losses h=k.v2/2g 2 2.80 6.158 0.150 4.791 0.35

c Branch Losses h=kbr.(Vavg.2/2g) 1 2.80 1.65 6.158 2.138 0.300 4.791 4.599 0.35

d Friction Loss in Unit Penstock h=v2*n2*L/(R4/3) 1 1.65 2.138 20.00 0.413 0.010 4.60 0.14

1.30

5 VALVE LOSSES (MIV)

Butterfly Valve 1 1.50 1.767 0.250 5.56 0.39

Total Head loss 6.32

Say ≈ 6.50



Annexure-8.5

Comparision of Energy Generation

Dependable Years Un-restricted Energy

Restricted Energy Corresponding to 24.00 MW

(GWh) Energy at 100% Plant Availability (GWh)

Energy at 95% Plant Availability (GWh)

50% Dependable Years (1983-84)

144.45 119.93 117.59


123.26 117.14 115.36


110.50 102.83 101.37

Year-1 (1972-73) 162.68 138.39 134.28

Year-2 (1973-74) 164.94 127.44 123.93

Year-3 (1974-75) 155.18 129.66 126.13

Year-4 (1975-76) 215.00 157.92 153.53

Year-5 (1976-77) 185.55 139.22 135.13

Year-6 (1977-78) 204.41 151.28 146.30

Year-7 (1978-79) 203.56 143.76 139.64

Year-8 (1979-80) 152.75 116.16 113.22

Year-9 (1980-81) 153.24 125.95 123.30

Year-10 (1981-82) 154.79 132.02 128.50

Year-11 (1982-83) 156.02 124.83 121.33

Year-12 (1983-84) 144.45 119.93 117.59

Year-13 (1984-85) 128.31 104.79 101.85

Year-14 (1985-86) 122.70 113.46 112.28

Year-15 (1986-87) 113.16 108.96 106.93

Year-16 (1987-88) 132.17 122.13 119.47

Year-17 (1988-89) 120.47 111.49 109.13

Year-18 (1989-90) 137.74 108.19 105.58

Year-19 (1990-91) 87.69 84.73 84.44

Year-20 (1991-92) 100.26 99.42 98.56

Year-21 (1992-93) 134.52 117.99 115.06

Year-22 (1993-94) 130.94 107.94 105.58

Year-23 (1994-95) 110.50 102.83 101.37

Year-24 (1995-96) 114.83 110.71 108.96

Year-25 (1996-97) 125.93 116.26 114.81

Year-26 (1997-98) 148.14 135.40 132.44

Year-27 (1999-99) 146.92 130.85 128.17

Year-28 (1999-00) 155.96 143.25 139.45

Year-29 (2000-01) 137.51 123.62 121.29

Year-30 (2001-02) 156.10 134.67 131.15

Year-31 (2002-03) 139.85 131.19 128.83

Year-32 (2003-04) 135.75 124.54 123.39

Year-33 (2004-05) 109.07 109.06 108.76

Year-34 (2005-06) 164.87 123.09 120.15

Year-35 (2006-07) 123.26 117.14 115.36

Year-36 (2007-08) 118.06 115.27 113.53

Year-37 (2008-09) 155.20 121.25 118.28

Year-38 (2009-10) 172.26 129.00 125.46

Year-39 (2010-11) 186.11 134.27 131.04

Total 5560.85 4788.06 4684.18

Average (GWh) 122.77 120.11

Average PLF 58.40% 57.13%



Annexure-8.6

Energy Generation for the 50% Dependable Year – 1983-84

Full Reservoir Level in Collection Pool = 1835.00 m

Gross Head = 99.50 m

Rated Net Head = 93.0 m

Efficiency (Generator) = 96.50%

Efficiency (Turbine) = 92.50 %

Efficiency (Combined) = 89.26 %

Rated Discharge = 29.50 m3/s

No. of Units = 3

Capacity = 24.00 MW

Month Period Inflow (m3/s)

Discharge Available for

Power Generation

(m3/s)

TWL (m) Head Loss (m)

Net Head (m)

Unrestricted Power (MW)

Unrestricted Energy (GWh)

Restricted Power

(24.00 MW)

Restricted Energy with 100% Plant Availability

(GWh)


(GWh)

Jun

I 29.62 29.50 1736.00 6.50 93.00 24.12 5.79 24.00 5.76 5.47

II 27.32 27.32 1735.87 5.57 94.06 22.50 5.40 22.50 5.40 5.40

III 33.47 29.50 1736.00 6.50 93.00 27.26 6.54 24.00 5.76 5.47

Jul

I 52.10 29.50 1736.00 6.50 93.00 42.43 10.18 24.00 5.76 5.47

II 50.50 29.50 1736.00 6.50 93.00 41.13 9.87 24.00 5.76 5.47

III 56.99 29.50 1736.00 6.50 93.00 46.41 12.25 24.00 6.34 6.02

Aug

I 67.15 29.50 1736.00 6.50 93.00 54.68 13.12 24.00 5.76 5.47

II 35.16 29.50 1736.00 6.50 93.00 28.63 6.87 24.00 5.76 5.47

III 26.80 26.80 1735.84 5.41 94.25 22.12 5.84 22.12 5.84 5.84

Sep

I 23.87 23.87 1735.65 4.28 95.57 19.98 4.79 19.98 4.79 4.79

II 21.38 21.38 1735.49 3.57 96.44 18.06 4.33 18.06 4.33 4.33

III 33.47 29.50 1736.00 6.50 93.00 27.26 6.54 24.00 5.76 5.47

Oct

I 8.88 8.88 1734.54 1.01 99.95 7.77 1.86 7.77 1.86 1.86

II 9.25 9.25 1734.57 1.06 99.87 8.09 1.94 8.09 1.94 1.94

III 10.78 10.78 1734.70 1.29 99.51 9.39 2.48 9.39 2.48 2.48

Nov

I 12.92 12.92 1734.88 1.61 99.01 11.20 2.69 11.20 2.69 2.69

II 11.98 11.98 1734.80 1.46 99.24 10.41 2.50 10.41 2.50 2.50

III 10.05 10.05 1734.64 1.19 99.67 8.77 2.10 8.77 2.10 2.10

Dec

I 8.44 8.44 1734.50 0.96 100.04 7.39 1.77 7.39 1.77 1.77

II 8.10 8.10 1734.47 0.93 100.10 7.10 1.70 7.10 1.70 1.70

III 7.93 7.93 1734.45 0.91 100.14 6.95 1.83 6.95 1.83 1.83

Jan

I 5.58 5.58 1734.22 0.70 100.58 4.91 1.18 4.91 1.18 1.18

II 5.36 5.36 1734.20 0.68 100.62 4.73 1.13 4.73 1.13 1.13

III 5.09 5.09 1734.17 0.66 100.67 4.48 1.18 4.48 1.18 1.18

Feb

I 5.00 5.00 1734.16 0.66 100.68 4.41 1.06 4.41 1.06 1.06

II 5.55 5.55 1734.22 0.70 100.58 4.89 1.17 4.89 1.17 1.17

III 5.37 5.37 1734.20 0.68 100.62 4.73 0.91 4.73 0.91 0.91

Mar

I 6.88 6.88 1734.35 0.81 100.34 6.05 1.45 6.05 1.45 1.45

II 7.53 7.53 1734.42 0.87 100.21 6.61 1.59 6.61 1.59 1.59

III 8.21 8.21 1734.48 0.94 100.08 7.20 1.90 7.20 1.90 1.90

Apr

I 9.81 9.81 1734.62 1.13 99.75 8.57 2.06 8.57 2.06 2.06

II 10.60 10.60 1734.69 1.26 99.55 9.24 2.22 9.24 2.22 2.22

III 18.71 18.71 1735.31 2.80 97.39 15.96 3.83 15.96 3.83 3.83

August

I 23.46 23.46 1735.62 4.16 95.72 19.66 4.72 19.66 4.72 4.72

II 22.76 22.76 1735.58 3.95 95.97 19.12 4.59 19.12 4.59 4.59

III 22.64 22.64 1735.57 3.92 96.01 19.03 5.02 19.03 5.02 5.02

Gross Energy (GWh) 144.45 119.93 117.59 Plant Capacity (GWh) 210.24 210.24

PLF (%) = Gross Energy/Plant Capacity 57.04% 55.93%



Annexure-8.7









No. of Units = 3

Capacity = 24.00 MW



Power Generation

(m3/s)

TWL (m)

Head Loss (m)

Net Head (m)



Restricted Power

(24.00 MW)


(GWh)


(GWh)

Jun

I 16.20 16.20 1735.13 2.23 98.14 13.93 3.34 13.93 3.34 3.34

II 14.25 14.25 1734.98 1.84 98.68 12.31 2.95 12.31 2.95 2.95

III 19.22 19.22 1735.34 2.93 97.23 16.37 3.93 16.37 3.93 3.93

Jul

I 30.27 29.50 1736.00 6.50 93.00 24.65 5.92 24.00 5.76 5.47

II 33.10 29.50 1736.00 6.50 93.00 26.96 6.47 24.00 5.76 5.47

III 39.43 29.50 1736.00 6.50 93.00 32.11 8.48 24.00 6.34 6.02

Aug

I 42.31 29.50 1736.00 6.50 93.00 34.45 8.27 24.00 5.76 5.47

II 28.91 28.91 1735.96 6.21 93.33 23.62 5.67 23.62 5.67 5.39

III 25.98 25.98 1735.78 5.19 94.53 21.50 5.68 21.50 5.68 5.68

Sep

I 22.53 22.53 1735.56 3.89 96.05 18.95 4.55 18.95 4.55 4.55

II 14.86 14.86 1735.03 1.95 98.52 12.82 3.08 12.82 3.08 3.08

III 11.69 11.69 1734.78 1.42 99.30 10.17 2.44 10.17 2.44 2.44

Oct

I 10.63 10.63 1734.69 1.27 99.54 9.27 2.22 9.27 2.22 2.22

II 10.18 10.18 1734.65 1.21 99.64 8.88 2.13 8.88 2.13 2.13

III 9.92 9.92 1734.63 1.14 99.73 8.66 2.29 8.66 2.29 2.29

Nov

I 9.62 9.62 1734.60 1.10 99.80 8.40 2.02 8.40 2.02 2.02

II 9.28 9.28 1734.58 1.06 99.86 8.12 1.95 8.12 1.95 1.95

III 9.15 9.15 1734.56 1.05 99.89 8.00 1.92 8.00 1.92 1.92

Dec

I 9.09 9.09 1734.56 1.04 99.90 7.96 1.91 7.96 1.91 1.91

II 8.98 8.98 1734.55 1.03 99.92 7.86 1.89 7.86 1.89 1.89

III 8.91 8.91 1734.54 1.02 99.94 7.79 2.06 7.79 2.06 2.06

Jan

I 6.96 6.96 1734.36 0.81 100.33 6.11 1.47 6.11 1.47 1.47

II 6.35 6.35 1734.30 0.76 100.44 5.59 1.34 5.59 1.34 1.34

III 6.96 6.96 1734.36 0.81 100.33 6.11 1.61 6.11 1.61 1.61

Feb

I 7.37 7.37 1734.40 0.85 100.25 6.47 1.55 6.47 1.55 1.55

II 8.38 8.38 1734.49 0.96 100.05 7.34 1.76 7.34 1.76 1.76

III 7.48 7.48 1734.41 0.86 100.23 6.56 1.26 6.56 1.26 1.26

Mar

I 10.09 10.09 1734.65 1.20 99.65 8.81 2.11 8.81 2.11 2.11

II 10.45 10.45 1734.68 1.24 99.58 9.11 2.19 9.11 2.19 2.19

III 12.06 12.06 1734.81 1.47 99.22 10.48 2.77 10.48 2.77 2.77

Apr

I 19.54 19.54 1735.36 3.01 97.13 16.62 3.99 16.62 3.99 3.99

II 21.90 21.90 1735.52 3.71 96.27 18.46 4.43 18.46 4.43 4.43

III 23.17 23.17 1735.61 4.07 95.82 19.44 4.67 19.44 4.67 4.67

August

I 16.68 16.68 1735.16 2.33 98.01 14.32 3.44 14.32 3.44 3.44

II 22.76 22.76 1735.58 3.95 95.97 19.12 4.59 19.12 4.59 4.59

III 32.27 29.50 1736.00 6.50 93.00 26.28 6.94 24.00 6.34 6.02

Gross Energy (GWh) 123.26 117.14 115.36

Plant Capacity (GWh) 210.24 210.24




Annexure-8.8









No. of Units = 3

Capacity = 24.00 MW



Power Generation

(m3/s)

TWL (m)

Head Loss (m)

Net Head (m)



Restricted Power

(24.00 MW)


(GWh)


(GWh)

Jun

I 25.71 25.71 1735.77 5.13 94.60 21.29 5.11 21.29 5.11 5.11

II 31.56 29.50 1736.00 6.50 93.00 25.70 6.17 24.00 5.76 5.47

III 29.37 29.37 1735.99 6.44 93.07 23.94 5.74 23.94 5.74 5.46

Jul

I 39.47 29.50 1736.00 6.50 93.00 32.14 7.71 24.00 5.76 5.47

II 47.48 29.50 1736.00 6.50 93.00 38.66 9.28 24.00 5.76 5.47

III 33.00 29.50 1736.00 6.50 93.00 26.88 7.10 24.00 6.34 6.02

Aug

I 26.30 26.30 1735.80 5.27 94.43 21.74 5.22 21.74 5.22 5.22

II 23.81 23.81 1735.65 4.26 95.59 19.93 4.78 19.93 4.78 4.78

III 21.95 21.95 1735.53 3.72 96.25 18.50 4.88 18.50 4.88 4.88

Sep

I 21.08 21.08 1735.47 3.49 96.54 17.82 4.28 17.82 4.28 4.28

II 22.60 22.60 1735.57 3.91 96.02 19.01 4.56 19.01 4.56 4.56

III 16.12 16.12 1735.12 2.21 98.17 13.86 3.33 13.86 3.33 3.33

Oct

I 12.66 12.66 1734.86 1.57 99.07 10.99 2.64 10.99 2.64 2.64

II 10.25 10.25 1734.66 1.22 99.62 8.94 2.15 8.94 2.15 2.15

III 9.54 9.54 1734.60 1.09 99.81 8.34 2.20 8.34 2.20 2.20

Nov

I 8.30 8.30 1734.49 0.95 100.06 7.28 1.75 7.28 1.75 1.75

II 7.59 7.59 1734.42 0.88 100.20 6.66 1.60 6.66 1.60 1.60

III 7.30 7.30 1734.39 0.85 100.26 6.41 1.54 6.41 1.54 1.54

Dec

I 6.62 6.62 1734.33 0.78 100.39 5.82 1.40 5.82 1.40 1.40

II 6.17 6.17 1734.28 0.75 100.47 5.43 1.30 5.43 1.30 1.30

III 5.98 5.98 1734.26 0.73 100.51 5.27 1.39 5.27 1.39 1.39

Jan

I 5.81 5.81 1734.25 0.72 100.53 5.12 1.23 5.12 1.23 1.23

II 5.54 5.54 1734.22 0.70 100.58 4.88 1.17 4.88 1.17 1.17

III 5.33 5.33 1734.20 0.68 100.62 4.69 1.24 4.69 1.24 1.24

Feb

I 4.81 0.00 1733.35 0.46 101.69 4.28 1.03 0.00 0.00 0.00

II 5.52 5.52 1734.22 0.69 100.59 4.86 1.17 4.86 1.17 1.17

III 5.58 5.58 1734.22 0.70 100.58 4.91 0.94 4.91 0.94 0.94

Mar

I 5.42 5.42 1734.21 0.69 100.60 4.77 1.15 4.77 1.15 1.15

II 5.71 5.71 1734.24 0.71 100.55 5.02 1.21 5.02 1.21 1.21

III 7.52 7.52 1734.42 0.87 100.21 6.60 1.74 6.60 1.74 1.74

Apr

I 7.81 7.81 1734.44 0.90 100.16 6.85 1.64 6.85 1.64 1.64

II 8.59 8.59 1734.51 0.98 100.01 7.52 1.81 7.52 1.81 1.81

III 10.12 10.12 1734.65 1.20 99.65 8.83 2.12 8.83 2.12 2.12

August

I 12.47 12.47 1734.84 1.54 99.12 10.83 2.60 10.83 2.60 2.60

II 19.01 19.01 1735.33 2.87 97.30 16.20 3.89 16.20 3.89 3.89

III 15.20 15.20 1735.05 2.02 98.43 13.10 3.46 13.10 3.46 3.46

Gross Energy (GWh) 110.50 102.83 101.37

Plant Capacity (GWh) 210.24 210.24




Annexure-8.9

Computation of Annual Energy for Different Installed Capacities (75% Dependable Year – 2006-07)

Month Period Qnet (m3/s)

Installed Capacity MW











18 19 20 21 22 23 24 25 26 27 28

Qdesgn 21.15 Qdesgn 22.43 Qdesgn 23.72 Qdesgn 25.04 Qdesgn 26.37 Qdesgn 27.72 Qdesgn 29.50 Qdesgn 30.52 Qdesgn 31.95 Qdesgn 33.42 Qdesgn 35.10

Restricted Power (MW)

Energy (GWh)


Energy (GWh)


Energy (GWh)


Energy (GWh)


Energy (GWh)


Energy (GWh)


Energy (GWh)


Energy (GWh)


Energy (GWh)


Energy (GWh)


Energy (GWh)

Jun I 16.20 13.93 3.34 13.90 3.34 13.90 3.34 13.90 3.34 13.90 3.34 13.90 3.34 13.93 3.34 13.90 3.34 13.90 3.34 13.90 3.34 13.90 3.34 II 14.25 12.31 2.95 12.30 2.95 12.30 2.95 12.30 2.95 12.30 2.95 12.30 2.95 12.31 2.95 12.30 2.95 12.30 2.95 12.30 2.95 12.30 2.95 III 19.22 16.37 3.93 16.40 3.94 16.40 3.94 16.40 3.94 16.40 3.94 16.40 3.94 16.37 3.93 16.40 3.94 16.40 3.94 16.40 3.94 16.40 3.94

Jul I 30.27 18.00 4.32 19.00 4.56 20.00 4.80 21.00 5.04 22.00 5.28 23.00 5.52 24.00 5.76 24.70 5.93 24.70 5.93 24.70 5.93 24.70 5.93 II 33.10 18.00 4.32 19.00 4.56 20.00 4.80 21.00 5.04 22.00 5.28 23.00 5.52 24.00 5.76 25.00 6.00 26.00 6.24 26.60 6.38 26.60 6.38 III 39.43 18.00 4.75 19.00 5.02 20.00 5.28 21.00 5.54 22.00 5.81 23.00 6.07 24.00 6.34 25.00 6.60 26.00 6.86 27.00 7.13 28.00 7.39

Aug I 42.31 18.00 4.32 19.00 4.56 20.00 4.80 21.00 5.04 22.00 5.28 23.00 5.52 24.00 5.76 25.00 6.00 26.00 6.24 27.00 6.48 28.00 6.72 II 28.91 18.00 4.32 19.00 4.56 20.00 4.80 21.00 5.04 22.00 5.28 23.00 5.52 23.62 5.67 23.60 5.66 23.60 5.66 23.60 5.66 23.60 5.66 III 25.98 18.00 4.75 19.00 5.02 20.00 5.28 21.00 5.54 21.50 5.68 21.50 5.68 21.50 5.68 21.50 5.68 21.50 5.68 21.50 5.68 21.50 5.68

Sep I 22.53 18.00 4.32 19.00 4.56 19.00 4.56 19.00 4.56 19.00 4.56 19.00 4.56 18.95 4.55 19.00 4.56 19.00 4.56 19.00 4.56 19.00 4.56 II 14.86 12.82 3.08 12.80 3.07 12.80 3.07 12.80 3.07 12.80 3.07 12.80 3.07 12.82 3.08 12.80 3.07 12.80 3.07 12.80 3.07 12.80 3.07 III 11.69 10.17 2.44 10.20 2.45 10.20 2.45 10.20 2.45 10.20 2.45 10.20 2.45 10.17 2.44 10.20 2.45 10.20 2.45 10.20 2.45 10.20 2.45

Oct I 10.63 9.27 2.22 9.30 2.23 9.30 2.23 9.30 2.23 9.30 2.23 9.30 2.23 9.27 2.22 9.30 2.23 9.30 2.23 9.30 2.23 9.30 2.23 II 10.18 8.88 2.13 8.90 2.14 8.90 2.14 8.90 2.14 8.90 2.14 8.90 2.14 8.88 2.13 8.90 2.14 8.90 2.14 8.90 2.14 8.90 2.14 III 9.92 8.66 2.29 8.70 2.30 8.70 2.30 8.70 2.30 8.70 2.30 8.70 2.30 8.66 2.29 8.70 2.30 8.70 2.30 8.70 2.30 8.70 2.30

Nov I 9.62 8.40 2.02 8.40 2.02 8.40 2.02 8.40 2.02 8.40 2.02 8.40 2.02 8.40 2.02 8.40 2.02 8.40 2.02 8.40 2.02 8.40 2.02 II 9.28 8.12 1.95 8.10 1.94 8.10 1.94 8.10 1.94 8.10 1.94 8.10 1.94 8.12 1.95 8.10 1.94 8.10 1.94 8.10 1.94 8.10 1.94 III 9.15 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92

Dec I 9.09 7.96 1.91 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92 7.96 1.91 8.00 1.92 8.00 1.92 8.00 1.92 8.00 1.92 II 8.98 7.86 1.89 7.90 1.90 7.90 1.90 7.90 1.90 7.90 1.90 7.90 1.90 7.86 1.89 7.90 1.90 7.90 1.90 7.90 1.90 7.90 1.90 III 8.91 7.79 2.06 7.80 2.06 7.80 2.06 7.80 2.06 7.80 2.06 7.80 2.06 7.79 2.06 7.80 2.06 7.80 2.06 7.80 2.06 7.80 2.06

Jan I 6.96 6.11 1.47 6.10 1.46 6.10 1.46 6.10 1.46 6.10 1.46 6.10 1.46 6.11 1.47 6.10 1.46 6.10 1.46 6.10 1.46 6.10 1.46 II 6.35 5.59 1.34 5.60 1.34 5.60 1.34 5.60 1.34 5.60 1.34 5.60 1.34 5.59 1.34 5.60 1.34 5.60 1.34 5.60 1.34 5.60 1.34 III 6.96 6.11 1.61 6.10 1.61 6.10 1.61 6.10 1.61 6.10 1.61 6.10 1.61 6.11 1.61 6.10 1.61 6.10 1.61 6.10 1.61 6.10 1.61

Feb I 7.37 6.47 1.55 6.50 1.56 6.50 1.56 6.50 1.56 6.50 1.56 6.50 1.56 6.47 1.55 6.50 1.56 6.50 1.56 6.50 1.56 6.50 1.56 II 8.38 7.34 1.76 7.30 1.75 7.30 1.75 7.30 1.75 7.30 1.75 7.30 1.75 7.34 1.76 7.30 1.75 7.30 1.75 7.30 1.75 7.30 1.75 III 7.48 6.56 1.26 6.60 1.27 6.60 1.27 6.60 1.27 6.60 1.27 6.60 1.27 6.56 1.26 6.60 1.27 6.60 1.27 6.60 1.27 6.60 1.27

Mar I 10.09 8.81 2.11 8.80 2.11 8.80 2.11 8.80 2.11 8.80 2.11 8.80 2.11 8.81 2.11 8.80 2.11 8.80 2.11 8.80 2.11 8.80 2.11 II 10.45 9.11 2.19 9.10 2.18 9.10 2.18 9.10 2.18 9.10 2.18 9.10 2.18 9.11 2.19 9.10 2.18 9.10 2.18 9.10 2.18 9.10 2.18 III 12.06 10.48 2.77 10.50 2.77 10.50 2.77 10.50 2.77 10.50 2.77 10.50 2.77 10.48 2.77 10.50 2.77 10.50 2.77 10.50 2.77 10.50 2.77

Apr I 19.54 16.62 3.99 16.60 3.98 16.60 3.98 16.60 3.98 16.60 3.98 16.60 3.98 16.62 3.99 16.60 3.98 16.60 3.98 16.60 3.98 16.60 3.98 II 21.90 18.00 4.32 18.50 4.44 18.50 4.44 18.50 4.44 18.50 4.44 18.50 4.44 18.46 4.43 18.50 4.44 18.50 4.44 18.50 4.44 18.50 4.44 III 23.17 18.00 4.32 19.00 4.56 19.40 4.66 19.40 4.66 19.40 4.66 19.40 4.66 19.44 4.67 19.40 4.66 19.40 4.66 19.40 4.66 19.40 4.66

August

I 16.68 14.32 3.44 14.30 3.43 14.30 3.43 14.30 3.43 14.30 3.43 14.30 3.43 14.32 3.44 14.30 3.43 14.30 3.43 14.30 3.43 14.30 3.43 II 22.76 18.00 4.32 19.00 4.56 19.10 4.58 19.10 4.58 19.10 4.58 19.10 4.58 19.12 4.59 19.10 4.58 19.10 4.58 19.10 4.58 19.10 4.58 III 32.27 18.00 4.75 19.00 5.02 20.00 5.28 21.00 5.54 22.00 5.81 23.00 6.07 24.00 6.34 25.00 6.60 26.00 6.86 26.00 6.86 26.00 6.86

Total Energy Generated in a Year (GWh)

106.45 109.06 110.92 112.66 114.30 115.78 117.14 118.35 119.35 120.00 120.50

Plant Load Factor (%)

67.50%

65.53% 63.31% 61.24%

59.31% 57.46% 55.72% 54.04% 52.40% 50.74% 49.13%

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 9-Design of Civil Structures


9. DESIGN OF CIVIL STRUCTURES

9.1 GENERAL

The Bharmour Hydro Electric Project Stage-I (BHEP-I) envisages utilization of water available in

Budhil nallah for generation of power. The project components are planned to ensure cost

effective and timely implementation of the project. The proposed civil structures are designed to

divert and convey water from Budhil nallah for generating 24 MW of power by utilizing a gross

head of 99.50 m.

The Bharmour Hydro Electric Project Stage-I (BHEP-I) & Bharmour Hydro Electric Project

Stage-II (BHEP-II) are proposed and operated in tandem between El. 1835.50 m and El.

1648.00 m. After completion of the upstream project (i.e. BHEP-I), the discharge from tail pool of

BHEP-I would be conveyed to intake pool of BHEP-II for power generation through head race

tunnel.

The water from Budhil nallah is proposed to be diverted through a diversion structure proposed

at 300 m D/S from the confluence of Chobia nalla with Budhil nalla. The diversion structure has

been proposed with Intake by providing a barrage across the Budhil nallah. The diverted water

from the nallah will be conveyed through intake structure having two no. of bays each size 6.0

m (W) x 5.0 m (h) connecting to two individual feeder channels to each surface Desanding

basin located on right bank. The silt-free water from Desanding basins will be conveyed to the

Power house through a D-shaped Head Race Tunnel (HRT) and the HRT is exit at surge shaft.

The bottom of the surge shaft connected to a underground main penstock shall be steel lined

having a horizontal length of 8.5 m, 90.00 m long vertical shaft and 21.0 m horizontal length upto

the manifold. The manifold from the main pressure shaft feed water to three horizontal Francis

turbines of each 8.00 MW located into the surface power house. The water from the BHEP-I

power house will be discharged into intake pool of for Bharmour Stage-II HEP located at D/S of

BHEP-I tail race channel exit. An outdoor switchyard has been proposed and the generated

power will be evacuated through a 132 kV proposed Ringmain Scheme and proposed 132/220

kV Bharmour Pooling Sub-station. General layout of the project is shown in Drawing. No. 1335-

CD-0101.

9.2 HEAD WORKS

The head works of BHEP-I consist of the following major structures:

1. Barrage with 5 no. of radial gates each 5.5 m (W) X 8.5 m (H)

i. Intake with two nos. coarse trash racks, service & stop-log gates to divert design flow

ii. Feeder Channels

iii. Two nos. surface desilting basins & Collection Pool



9.2.1 Barrage

Considering the high flood level of 1843.50 m at the diversion site corresponding to the design

flood (Q50) of 2100 m3/s, available site for desanding basin and water depth required in the

basin, barrage crest level has been fixed at river bed level i.e. El. 1827.0 m. Five numbers of

gates including one number of undersluice have been provided on the crest of El 1827.0 m. The

gate openings of size each 5.5 m (W) X 8.5 m (H) has been provided by separating each bay

with 2.0m thick pier to pass the design flood. The full supply level in front of the intake structure

has been fixed at El. 1835.5 m. Being a large size of gate, radial types of gates are provided on

the crest of barrage to reduce the hoisting capacity. From the five no. of bays, one bay of

undersluice has been provided near the Intake trash rack. Spillway and undersluice parts are

separated by a long divide wall which creates a smooth flow at intake and separates the intake

part from the influence of turbulent flow in barrage portion. On the upstream of main radial gates

stop-logs are provided to facilitate maintenance of the main gates.

Four numbers of spillway gates have been provided at crest El. 1827.0 m by separating each

2.0 m thick pier. The discharge capacity of the spill ways has been calculated as per IS:

11223:1985, one gate is considered to be inoperative and the three spillways are operative in

the event of occurrence of design flood which is capable to discharge 1575 m3/s of flood with

the head of 16.50 m on the barrage crest. One number of undersluice can pass 536 m3/s during

the flood time. Hence, three spillway gates and undersluice will be capable of passing 50 years

flood discharge of 2100 m3/s. The top of the barrage has been fixed at El. 1845.00 m i.e. 1.5 m

free board is provided from the high flood level (HFL) of 1843.50 m and is found to be adequate

to pass the 100 year return period flood of 2315 m3/s.

For the given head-discharge-tail water combinations, horizontal stilling basin as an energy

dissipation arrangement is considered. The downstream slope of 3H:1V extended upto El.

1817.0 m based on the hydraulic jump criteria. The stilling basin length of 63.00 m has been

provided from the exit of glacis at an El. 1827.0 m. An end sill of 14.00 m length has been

provided at downstream end of stilling basin with 2H: 1V upward slope. 500 mm thick high

performance concrete has been provided on the upstream floor and downstream glacis of the

barrage crest to minimize the damage to the weir on account of the impact of the rolling boulders

during flood events.

The barrage being founded on alluvial deposit, excessive seepage can be a problem if not

properly considered in the design. A total seepage path of about 130 m keeps the exit gradient

within permissible limits and avoids any piping phenomena. To relieve the uplift pressure, 125

mm dia filter protected drain pipes @ 4m C/C spacing are provided in the stilling apron. The top

level of flood wall at the barrage axis is El. 1845.00 m above the highest flood level and the top

of the flood wall at stilling basin reaches at El. 1836.20 m.

1.0 m thick concrete apron with a 15.0 m deep cut-off at the downstream end and 5.0 m depth of

cut-off at the upstream end of barrage has been provided to take care of the low discharges.



Concrete blocks 1.5 mx1.5 mx0.9 m are placed over the apron, which take care of the impact of

boulders.

The hydraulic design calculation of the barrage is given in Annexure-9.1.

The stability of barrage has been checked as per IS 6512:1984. The earthquake parameters

adopted in stability calculations have been taken from the site specific earthquake parameters of

Budhil dam which is about 8 Km downstream of proposed barrage site (refer Annexure-9.6).

The horizontal and vertical seismic coefficients for DBE condition are 0.16 and 0.11 respectively

and for MCE condition are 0.31 and 0.21 respectively. The stability analysis of barrage has been

carried out for the coefficient values of MCE condition. The sliding forces are resisted by self

weight of the structure. Calculations for stability analysis are presented in Annexure 9.6.

9.2.1.1 Intake Structure

The intake structure is proposed to be constructed on the right bank of the Budhil nallah. Trash

rack has been provided in front of the intake to prevent the floating debris and other unwanted

material from entering the intake. Likewise the bottom of the intake is situated 4.5 meters above

the river bed to exclude the bed load entering into the waterways. The top of the intake structure

is kept at EL 1845.00 whereas the bottom is kept at 1831.50. The intake is equipped with two

coarse trash rack arrangement with openings each of 6.0 m wide and 5.0 m high. The sill level

of trash rack is kept at El 1830.50 m. The size of the trash rack at 40% clogging allows velocity

of 1.5 m/s at normal conditions by adopting mechanical cleaning with trash rack cleaning

machine (TRCM). The details are given in Drawing No. 1335-CD-0204.

Intake structure is provided with 2 nos. of service and stop-log gate grooves for intake opening

each of size 3.0 wide and 4.0 m high. The openings are equipped with vertical gates for flow

regulation. The operating platform of the intake gate is located at El. 1845.0 m. The platform will

have railings and gate hoisting mechanism. The gate is proposed to be operated by rope drum

hoist arrangement. The flow including flushing/ overload discharge will be controlled by intake

gate arrangement. The hydraulic calculations are given in Annexure-9.2.

9.2.1.2 Feeder Channel

Two no. feeder channels an average length of 40.0 m each link the intake with the individual

surface desilting basins. The flow in each feeder channel is regulated by intake gate. The two

bays of size 3.0 m (w) x 3.5 m (H) are connected independently to the inlet transition of desilting

basin. This provision will facilitate the maintenance and cleaning of the individual desilting basin

without disturbing the operation of other bays.

The feeder channels are designed to carry the overload discharge which includes the design

discharge of 29.50 m3/s and the discharge for flushing/ overloading. The bed level of the

channel varies from 1831.50 at the start to 1823.50 at the end of feeder channel. During flood

events, the intake gates will be regulated so that only the required discharge flows in the feeder



channel. The plan and L-Section of feeder channel are given shown in Drawing No. 1335-CD-

0202 & 0204.

9.2.1.3 Desilting Basin and Collection Pool

The length of inlet transition is worked out as 7.00 m whereas the uniform length of the desilting

basin is calculated to be 80 m and the width of each bay is 10 m with a total of 2 no of bays.

The depth of the desilting basin above the hopper is 7.5 m. The hopper is 4.0 m deep with 45˚

side slope. The proposed desanding arrangement has to be designed to allow the settlement of

sand particles of size 0.2 mm and above. The desanding basins are designed for a discharge of

35.40 m3/s (29.5*1.2 = 35.40). The flow through velocity in desanding basin is restricted to 0.18

m/s. The settling velocity of 0.2 mm particles is 0.024 m/s. Detailed hydraulic calculations are

presented in the Annexure-9.3. The flushing of the sediment will be through a 2.0 m wide

flushing channel located at the bottom of the hopper. The reduction of the transition length was

largely due to the extra number of divide wall.

The flushing channels from two desilting basins are provided with two independent flushing

gates, leading to flushing pipe 1.2 m diameter through a transition. The two flushing pipes are

made to converge to one single pipe of 1.2 m dia. 30.0 m long for discharging the silt back to the

Budhil Nallah. The desilting basin is located on the right bank of Budhil Nallah.

Silt-free water from the desanding basins will enter into the collection pool provided at end of

desilting basins by overflowing the weir crest at El 1833.50. A 21.0 m long 12.0 m wide

collection pool is provided with a storage capacity of 4 minutes at 50% of design discharge of

one machine. Thus full supply level and minimum draw down levels in the collection pool are

calculated and provided at El 1835.00 and El 1830.20, respectively.

A 18.0 m long side escape spillway is provided in the collection pool with its crest at El. 1835.20

to discharge the water coming from intake into the river during sudden load rejection conditions.

The general arrangement, Plan and cross section details of the desanding basins are shown on

Drawing. No. 1335-CD-0101, 1335-CD-0202, 1335-CD-0204 & 1335-CD-0205 respectively.

Detailed hydraulic design of collection pool is presented in Annexure-9.4.

9.3 WATER CONDUCTOR SYSTEM

9.3.1 Inlet Portal

The tunnel inlet portal has been proposed at the collection pool outlet at an exposed vertical

rocky cliff. Invert level of tunnel inlet portal is fixed at El. 1823.00 m. An inverted D-shape

headrace tunnel of size 3.6 m (W) x 3.6 m (H) will be excavated from this portal.



9.3.2 Adits

To expedite tunneling, two adit tunnels Adit-I & Adit-II are provided to reduce the excavation of

critical length of tunnel. Adit-I is provided at inlet portal & Adit-II has been proposed at about

950.0 m from inlet portal of the tunnel. Two adit tunnel Adit-III & Adit-IV have been provided at

bottom of surge shaft at RD.2516.0 m and at trifurcation of penstock respectively.

9.3.3 Head Race Tunnel (HRT)

The Head Race Tunnel (HRT) of BHEP-I is aligned on the right bank of Budhil nallah to covey

the water from the collection pool (after desilting chambers) outlet and terminates the HRT at

surge shaft. The invert level of the HRT is fixed at an El.1823.00 m to maintain adequate

submergence at the collection pool intake so that no air enters into the HRT during normal

operating conditions at minimum operating level.

D-shaped tunnel having a width of 3.6 m and height of 3.6 m finished size with concrete lined for

a length of about 2485.0 m is provided. The proposed tunnel alignment has sufficient rock cover

and Good to Fair rock mass quality. The minimum and maximum vertical rock covers over the

tunnel are 60 m and 280 m, respectively. The optimum diameter of the tunnel based on the cost

and revenue was determined as 3.6 m dia D-shaped with velocity of 2.52 m/s during design

discharge. The average thickness of concrete lining in normal section is kept 20 cm. This

thickness can be increased, if required, for very poor to extremely poor rock is encountered

during excavation.

The invert level at the start of the tunnel is fixed at El.1823.00 m whereas the invert level at the

surge shaft is 1804.20 m. The tunnel upto surge shaft has longitudinal slope of 1 in 132 up to

RD 2485.00 m.Drill and blast method of tunneling is proposed for excavation of the Headrace

tunnel. The tunneling will be carried out using mechanised method. Boomer will be used for the

drilling and robotic shotcrete machine for shotcreting, proposed to be used for temporary lining.

The mucking will be done using the dump truck and safely disposed off in the designated place.

Provision for ventilation and lighting will also be provided adequately.

Temporary supports by means of shotcrete and rock bolt will be provided during tunneling. The

permanent lining based on the rock support design will be provided later. Exploratory holes will

be drilled to determine the rock type that can be expected in the next stage. If the rock is found

to be weak, pre-construction grout shall be provided. In addition, in the areas of extremely poor

rock the pull length will be reduced to avoid overbreak problem. Rock bolts will be provided

depending upon the quality of rock mass. In addition, a nominal thickness of shotcreting (5 -15

cm) will be provided depending upon the geological conditions, which will be followed by a

nominal concrete lining of 20 cm. A summary of rock support requirements is given in Table-9.1.

The L-section, excavation and rock support details are presented in Drawing. No. 1336-CD-0401

to 0403.



Table-9.1: Rock Support Requirements along HRT

Length (m)

Description of Rock mass

Indicative Rock mass quality index

Rock support requirements

126 very poor <1.00 Steel ribs, reinforced shotcrete and bolting, Multiple headings

373 poor 1 to 4 Reinforced shotcrete plus pattern bolting plus shotcrete of increased thickness

1240 fair 4 to 10 Pattern bolting and or bolting plus shotcrete

746 good >10 Pattern bolting and shotcrete

9.3.4 Surge Shaft

9.3.4.1 General

In general, a Surge shaft is provided to dampen the water hammer pressure in the tunnel and

penstock during the time of sudden load rejection. It also improves the governing stability by

reducing the distance between the turbine and the nearest free water surface. In addition to this,

Surge tank also provides water supply to the turbines in the case of sudden starting up of

machine.

9.3.4.2 Hydraulic Design of Surge Shaft

The surge shaft will be a restricted orifice and open to sky type (Drawing. No 1335-CD-0405)

and will be connected to the headrace at the base. The diameter of the surge shaft is calculated

satisfying the Thoma’s stability criterion and considering the topographical conditions.

Accordingly, a shaft of 10 m diameter & 1.8 m dia orifice with total height of 59.80 m is provided.

Calculation sequence is basedupon IS:7396 (Part-1)-1985 (reaffirmed 1995) - Criteria for

Hydraulic Design of Surge Tanks - Part 1 : Simple Restricted Orifice and Differential Surge

Tanks. Hydraulic design computations of the surge shaft are enclosed at Annexure-9.5.

It would be seen that as soon as load is rejected, water level would start rising in the surge shaft.

For full load rejection, it would rise to a maximum of El. 1856.15 m. Similarly, on load

acceptance, the water level in the surge shaft would drop to a minimum of El. 1816.88 m.

Accordingly, the invert level of HRT hasbeen kept at El. 1804.20 m so that there is no possibility

of entry of air into the water conductor system under any operational condition of the turbines.

The height of the surge shaft is calculated considering the possible surges due to various

loadings such as overloading of the plant by 15% of rated power, full load rejection, full load

acceptance combinations. The surge levels estimated for these extreme hydraulic conditions are

given in Table-9.2. The surge profiles for load rejection and load acceptance conditions are

presented in Figure-9.1 & 9.2.



Table 9.2: Adopted hydraulic conditions and resulting surge levels

Hydraulic Conditions Up-surge Levels (m) Down-surge Levels (m) Full load rejection due to three units at overloading flow (+15% of rated power) with the full supply level at 1835.00 m

1856.15 1828.75

Full load acceptance due to three units at overloading flow with the MDDL at 1830.20 m

1842.97 1816.88

Top elevation of the surge shaft has been kept at El. 1864.00 m so that a cushion of

7.85 m is available above the maximum surge level mainly to avoid more excavation and to

prevent any overflow from the surge shaft.

Figure 9.1: Mass Oscillation due to Full Load Rejection, with the Full Supply Level at 1835.0 m



Figure 9.2: Mass Oscillation due to Full Load Acceptance, MDDL at 1830.20 m

9.3.5 Surge Shaft Gate

One no. of surge shaft gate of size 3.6 m (W) X 3.6 m (H) has been provided inside the surge

shaft just before start of pressure shaft in order to isolate the pressure shaft from HRT.

9.3.6 Pressure Shaft

9.3.6.1 General

One no. pressure shaft of 2.8 m dia. has been proposed having centre line at El. 1806.00 m.

The pressure shaft emanate from the circumference of the surge shaft. The shaft is rectangular

in the beginning and transitioned to circular shape in a length of 2.5 m. The pressure shafts

follow a horizontal path for a distance of about 8.5 m before bends in the vertical direction. Then

the shaft drop vertically down by about 90.00 m before bends in the horizontal centre line at its

bottom end at El. 1731.90 m and further it goes horizontally for a length of 24.50 m upto

trifurcation. The horizontal run of three numbers unit penstock each is about 21 m up to the

upstream wall of the power house building. The plan and sectional details of pressure shaft are

shown in Drawing No. 1335-CD-0501 & 1335-CD-0502 respectively.



9.3.6.2 Economical Diameter

Economic diameter of the main penstock has been computed using following empirical formulae

given in the Manual on Design, Fabrication, Erection and Maintenance of Steel Penstocks

published by the Hydel Civil Design Directorate of Central Water Commission:

units FPS in

0.466

H

P D'' DiameterEconomic (i)

Where, P is the maximum power generated in horsepower (fps) and H is the rated head in feet.

0.4660.7461.15) (24000

D''3.28089

00.3

D = 9.35 feet = 2.85 m

A diameter of 2.80 m is adopted. The velocity in pressure shaft is 4.80 m/s corresponding to

design discharge of 29.50 cumecs.

9.3.6.3 Pressure Shaft Liner

The pressure shafts will be steel lined in the whole length. The shaft liners have been designed

to withstand internal as well as external pressures. The internal pressure including water

hammer has been considered as location for different sections. External pressure has been

taken equal to the difference between water level equal to FRL in the surge shaft and the

pressure shaft level. In the horizontal reach, internal spiders will be provided to preclude any

deformation of shape. Radiographic examination of shop weld is proposed while all field welds

will be tested by ultrasonic examination.

The thickness of plate in the pressure shaft varies from 12 mm to 16 mm for Fe 250 Grade steel.

No stress relieving is required for plate thicknesses of this order. Total weight of steel required

for Pressure shafts comes out to 180 tonnes. All the joints will be welded joints. All shop welding

of the longitudinal joints will be double V-butt welds. The field welds will be single V-butt welds

with backing strip. All the shop welds will be checked by radiographic examination while all field

welds will be tested by ultrasonic examination.

9.4 POWER HOUSE COMPLEX

9.4.1 General

Based on available topography a surface Powerhouse, Transformer hall has been proposed.

Proposed layout and cross section have been shown in Drawing No 1335-CD-0601 & 0602.



9.4.2 Power House

The general arrangement of powerhouse has been developed for the installation of three, 8.00

MW Horizontal Francis turbines. The Powerhouse complex comprises of Service bay, Machine

bay and Control room Building. The size of the surface power house is proposed as 15.0 m (W)

x 56.0 m (L) 22.0 m (H). A 80/20 T EOT Crane is proposed to lift heaviest part of Stator and

Rotor. The basic amenities like Lighting, Sanitary arrangements, Water supply, Fire fighting

system, Drainage and Dewatering system, Elevators, Communication facilities, Seismic alarm

tripping device, Noise control, Heating, Ventilation, Air conditioning system are proposed in the

Power house complex. The Details are shown in the Drawing No. 1335-MP-4001 & 1366-MP-

4002.

9.4.3 Service bay

The Service bay of Power house is proposed at El. 1737.00 m and the size of control room is

56.0 m (L) x 6.0 m (W) x 4.50 m (H).

9.4.4 Machine bay

The size of Machine bay of Power house is proposed as 15.0 m (W) x 46.0 m (L) x 4.80 m (H).

The Machine bay shall have three Horizontal Francis Turbines and Generators of 8.00MW each.

Machine bay shall also accommodate Main Inlet butterfly Valve and its auxiliaries, turbine

auxiliaries, Generator auxiliaries, Oil handling system, Cooling water system, Fire fighting

system, and compressors etc. Drainage and Dewatering sumps are proposed for pumping out of

seepage, leakage and drainage water from powerhouse building and also dewatering of the

draft tube and spiral and any water conducting component to perform repairing and servicing

underwater parts. The proposed location of different floors is mentioned in the following Table.

S.No Name of Floor Elevation (m)

1 Service bay Floor 1737.00

2 Generator & Turbine Floor 1732.20

3 C/L of Turbine 1733.40

4 Bottom of Draft tube Steel liner 1728.50

9.4.5 Draft Tube

The discharge from draft tube is led by three rectangular shaped Draft tube tunnels of 2.4 (W) x

2.1 m (H) m. Three numbers of Draft tube gates of each 2.4 m (W) x 2.10 m (H) has been

proposed for the purpose of operation & maintenance of tailrace channel & draft tubes.

9.5 TAIL RACE CHANNEL

The discharge from all the three individual draft tubes are combined into a single tail race

channelof size 4.0 m wide and 61.40 m length lead the water to intake pool for the Bhamour –II



HEP. One set of gate of size 4.0 m (W) x 3.3 m (H) has been proposed at the crest of tail race

channel for the operation & maintenance of intake pool and One no. of gate of size 4.0 m (W) x

3.3 m (H) has been proposed perpendicular to the tail race channel for the purpose of spilling

the water back to budhil nalla from the tailrace channel of Bharmour-I HEP during shut of the

downstream project (Bharmour-II HEP). The plan & sectional details of tail race channel is

shown in drawing. No 1335-CD-0801 & 802.

9.6 INTAKE POOL FOR BHARMOUR-II HEP

As stated earlier, the BHEP-I & BHEP-II shall be operated in-tandem, consequently, an intake

pool has been proposed at exit of tailrace channel of BHEP-I Power house to convey the water

to generate the power from BHEP-II. The size, 24.05 m (L) x 15.0 m (W) and height varies from

2.15 m to 11.50 m and the top portion covered with 500 mm thick concrete slab of intake pool

has been designed for a storage capacity of 2 minutes while one unit running with 50% of rated

discharge. The initial length of 18.70 m intake pool is provided with a bed slope of 1:2 and the

remaining length is provided with gentle slope of 1 in 50 upto the intake of BHEP-II. The FSL

has been calculated at El.1735.50 m and the MDDL is fixed at El. 1733.80 m. The operation of

pool will be shutdown in the case of upper project (BHEP-I) shall be stopped and the lower

project (BHEP-II) function should also closed. One service gate has been proposed at the crest

of tail race channel to control the flow regulation into the pool. Escape channel with gate

arrangement is provided in right angled to the tail race channel crest to spill over the flow from

BHEP-I during maintenance of downstream project.



Annexure-9.1 DISCHARGE CAPACITY OF BARRAGE

Checking waterway for 50 year flood ( With 4 gates open )

GATE 5.5/8.5 (B/H)

50 Year Return Period Flood = 2100.00 m3/s 100 Year Return Period Flood = 2315.00 m3/s MWL/HFL = 1843.50 m River Bed Level = 1827.00 m Crest Level = 1827.00 m Total No. of Bays = 5 Width of gate, W = 5.50 m Height of Gate, D = 8.50 m

Design Head, Hd = 14.025 m

IS:69341998, Clause.4.4 - Generally Design Head is Kept as 80% to 90% of the Maximum Head

Contraction Coefficient of Abutement, Ka = 0.1 Contraction Coefficient of Abutement, Kp = 0.01 Pier Thickness = 2.00 m No. of Piers = 4 m Construction Joint Pier Thickness = 2.00 m Total Lenth of Water Way Barrage, L = (5.5 × 5 ) +(2.0* 4 +2.0)

= 37.50 m

Conforming to IS: 11223-1985, Guidelines For Fixing Spillway Capacity

3.6.1 - For gated spillway, the contingency of at least 10% of the gates with a minimum of one gate being inoperative August be considered as an emergency.

As per Is: 6934:1998, Discharge Computatin for the Breast Wall Spillway Capacity is Given by,

Q = Cb D L [2g(Hc+Va2/2g)]0.5

Minimum Stable water Way, (Pw) by Lacy's Formula = 232.39 m As per clause 10.2 of IS 6966(Part I) : 1989, Pw = 4.83*sqrt(Q)

Total Length of Water Way Assumed, L = 37.50 m

Spillway Capacity by 4 Gates are Operative & One Gate is In-operative, and Neglecting Velocity Head

H/Hd = 16.5/14.025 = 1.17600

Discharge Coefficient, Cb = 0.148631+0.945305 (H/Hd)-0.326238(H/Hd)2

= 0.8091 Effective Length, L = L'-2×D (N.Kp+Ka)

= (5.5*4)-{2×8.5×(3×0.01+0.1)} = 19.79 m

Head from HFL upto the centerline of Opening of Gate, Hc = (1843.5-1827.00)-(8.5/2) = 12.25 m

Neglecting Velocity Head Discharge, Q = 0.8091×8.5×19.79×[2×g×(12.25+0)]0.5

= 2110.01 m3/s > 2100 m3/s O.K. Therefore, Provided 5 nos. of Gates of Each Size 5.5 m (W) X 8.5 m (H) with crest level at El. 1827.00 m

Loossness factor = 42.0/232.39

= 0.16

Refer Clause 10.2 of IS 6966 (Part I): 1989



Annexure-9.1 DESIGN OF DOWNSTREAM FLOOR Remarks Maximum Flood Discharge ,50 year flood, (with 4 gates open condition)

U/S TEL

=

1,842.11

m

D/S TEL

=

1,836.09

m From HEC-RAS

Discharge Q for this bay 2100.00 m3/s Bay width 5.50 No. of bay 4.00 con. Factor 1.00

Discharge intnsity, q with concentration factor

95.45

m3/s/m

Head Loss,(HL)

6.02

m =u/s T.E.L. - d/s T.E.L

Assume Average Particle Size, mr

25.00

mm

Lacey Silt Factor, f 8.80 =1.76√mr d1 d2 Fr d2 HL 4.80 17.42 2.90 17.42 6.02

V2

5.48

m/sec =q/d2

Ef2

18.95

m =d2+v22/2g

d/s floor level

1,817.14

m =d/s T.E.L - Ef2

Adopted Cistern Level

1,817.00

m

Min D/s Length of cistern

63.13

m =5 (d2 - d1)

DESIGN OF CUT OFF WALL i) Upstream End

Discharge intensity

95.45

m3/s/m

Intensity of Discharge with no concentration

114.55

m3/s/m

u/s W.L

1,843.5

m under 4 gates open

R

13.65

m =1.35*(q2/f)^1/3

Scour depth of impervious floor

13.65

m =1.0*R

R.L. of scour hole

1,829.85

m

Top of U/s Floor

1,827

m

Depth of u/s toe wall below floor level

-2.85 m

=u/s floor level - R.L. of scour hole

Calculated R.L. of bottom of u/s toe wall

1,830

m

R.L. of bottom of u/s toe wall provided

1,822

m

Therefore, Provided Depth of Cutoff From Upstream Floor Level

5.0

m

ii) At the d/s floor end

d/s W.L

1,831.94

m From HEC-RAS

Scour depth

17.07

m =1.25*R

R.L. of bottom of scour hole

1,814.87

m

Depth of d/s toe wall below floor

2.13

m =R.L. of Cistern-R.L. of scour hole



As per IS- 6531:1994

7.97

m

As per IS:6531:1994, Rough Estimate of d/s cut off=(d/2+0.5), where d= d/s water depth for FSL discharge

Calculated R.L. of bottom of d/s toe wall

1,809.03

m

Adopted R.L. of bottom of d/s toe wall provided

1,809.00

m

Therefore, depth of d/s toe wall provided below floor

8.00

m

Provided features of the barrage

Length of D/S floor

63.00

m

Length of D/S Glacis

30.00

m 1V:3H D/S Glacis Slope

Crest Length

5.00

m

Length of End Sill

14.00

m 1V:2H Inverse Slope upto River Bed El. 1824.00

Length of Upstream Floor

5.00

m

Total Length of Barrage

117.00

m

Say

117.00

CHECK FOR EXIT GRADIENT

Depth of Downstream Cutoff

15.00

m

Maximum Static Head, H

19.50

m U/S HFL-River Bed Level at Tail Water Section

Α

6.00

Λ

3.54

Exit gradient considered

GE

0.22

1 in 4.55

found to be O.K.

Therefore, Total Length of Barrage Provided is

117.00



Annexure-9.2

Hydraulic Calculations of Trash rack at Intake

Full Reservoir Level (FRL) = 1835.50 m

Maximum Turbine Discharge for all units (Q) = 29.50 m3/s

Silt Flushing Discharge (20% of 'Q') = 5.90 m3/s

Total Design Discharge for Intake = 35.40 m3/s

No. of Intake Openings = 2 Nos.

Width of each Opening (W) = 6.00 m

Vertical Height of each Opening (H) = 5.00 m

Angle of Inclination of Trash Rack with Vertical (θo) = 0.00

Effective Height of Trash Rack (Heff.) = 5.00 m

Gross Flow Area at Intake (A) = 60.00 m2

Assuming Bar Area = 30%

Net Flow Area (A1) = 42.0 m2

Velocity at Intake without any clogging (V1) = 0.70 m/s

Assuming clogging = 50%

Net Flow Area at Intake (A2) = 21.0 m2

Velocity at Intake with Net Flow Area (V2) = 1.40 m/s

V2 < 1.5 m/sec, As per Is: 11388 - 1195, Hence

(1) The Trash ack has been provided with 2 Nos. of vertical lift fixed type

(2) Size of each trash rack 6.0 m (wide) x 5.0 m (Effective Height)



Annexure-9.3

HYDRAULIC DESIGN OF DESILTING BASIN

1.0 DESIGN DATA

Design discharge = QN = 29.50 m3/sec

Assuming 20% of Design Discharge for Flushing = = 5.90 m3/sec

Design discharge for Desilting Basin = QO = 35.40 m3/sec

Number of operating basin = nO = 2 Nos.

Number of stand by basin = nS = 0 No. Total number of basins = N = nO + nS = 2

Nos.

Particle size to be removed = d = 0.20 mm

2.0 DISCHARGE AND VELOCITIES

Discharge to pass through settling basin = Q = Qo/nO = 17.7 m3/sec

Flow through velocity (As per R. S. Varshney) = V = 0.66 * (d)1/2 = 0.295 m/sec

Flow through velocity (CBIP No. 280) = = 0.2 m/sec Flow through velocity adopted = V = 0.2 m/sec Settling Velocity:

Vs �= [(1/18) * (p �- w * g * d�)/2]/10000

Density of particle = �p = 2.65 g/cc

Density of water = �w = 1.00 g/cc

Absolute viscocity of water at 10°C = � = 0.0131 g/sec.cm2

Acceleration due to gravity = g = 981 cm/sec2

Settling velocity = Vs or W = 0.0275 m/sec

Adopted Settling velocity = Vs or W = 0.027 m/sec

3.0 CROSS SECTION OF SETTLING BASIN

Bt

hr

Bs hhe

hh Silt Zone

Bb

C/s area required to carry the design discharge = Areq = Q/V = 88.5 m2

Provided top width = Bt = 10.0 m

Provided height of flow in top rectangular portion = hr = 7.50 m

Provided height of bottom hopper portion = hh = 4.00 m



Effective Height of Hopper Portion:

The assumption is to do flushing when 50% of the hopper height is filled with silt. Total percentage of height of hopper in silt = p = 50 %

Silt accumulation starts from bottom. Hence the height of hopper portion in silt vary from 0% at start to 50% during flushing. Hence the discharge capacity shall be calculated considering an average i.e 25% of hopper height in silt and the remaining 75% is effective in carrying the discharge.

Percentage height of hopper in silt = p1 = 25 %

Effective height of hopper portion = hhe = hh * (1-p1/100) = 3.00 m

Side slope of hopper portion = S (1(V) in ---(H)) = 1.0

Bottom width = Bb = Bt - 2 * (hh/S) = 2.0 m

Top width of silt zone = Bs = Bt - 2 * (hhe/S) = 4.0 m

Effective c/s area carrying the discharge = A = Bt*hr+(Bt+Bs)/2*hhe = 96 m2

Actual flow through velocity = Vact = Q/A = 0.18 m/sec Provided size is adequate to carry the discharge.

4.0 LENGTH OF DESILTING BASIN As per CBIP 280 & R.S.Varshney:

Settling depth = y = hr + (1-p1/100)*hh = 10.50 m

Reduction in settling velocity due to turbulence = Α = 0.132/(y)1/2 = 0.0407 m/sec

Moderated settling velocity = Vsm = (1 - α) * Vs = 0.0259 m/sec

Settling period = t = y/Vsm = 405.39 sec

Vact

Ld

Vsm

y

Required length of desiting zone = Lreq = Vact * t = 72.97 m

Provided length of desilting zone = Ld = 80.00 m

Calculation of Efficiency by CAMP's method

122 * W / V = 17.14

Depth of Flow (deffecive ) = Length of Basin

Required Vertical Velocity Wo Forward velocity Vactual

Required Vertical Velocity (Wo) = 0.024

W / Wo = 1.1

From Camp's graph , Removal ratio = 94%



5.0 SIZE OF BOTTOM DRAIN AND SLOPE

Width of bottom drain = Bd = Bb = 2.0 m

Depth at start = ds = 0 m

Slope = S (1 in ------) = 50

Depth at end = de = ds +( Ld / S) = 1.60 m

6.0 DEPTH OF FLOW ABOVE CREST WALL AT END

Discharge Over a Broad Crested Weir

Q = Cd * L * H3/2

Discharge required to pass = Q = 7.375 m3/sec Coefficient of discharge = Cd = 1.7

Length of weir = L = Bt = 5.00 m Required depth of flow = Hreq = [Q/(Cd*L)]2/3 = 0.91 m

Provided depth of flow = H = 1.00 m



7.0 PROVIDED SIZE OF DESILTING BASIN AND ELEVATIONS OF SALIENT POINTS

Length of expansion at start = Le = 7.0 m

Length of desilting zone = Ld = 80.0 m

Total clear length of desilting basin = L = Le+Ld+Lc = 87.0 m

Free board = F.B. = 1.00 m

Width of single basin at top = Bt = 10.0 m

Total Height of rectangular portion (including free board) = Hr = hr +F.B. = 8.50 m

Height of rectangular portion portion = hh = 7.50 m

Height of hopper portion = hh = 4.00 m

Side slope of hopper portion = S (1 in ----) = 1

Width of bottom drain = Bd = 2.0 m

Depth of bottom drain at start = ds = 0 m

Depth of bottom drain at end = de = 1.6 m



Annexure-9.4



Annexure-9.5

HYDRAULIC DESIGN CALCULATION OF SURGE TANK USING THOMAS CRITERION (IS: 7396 PART-I)

Input

Full Reservoir Level FRL/FSL = 1835.00 m

Minimum Draw Down Level MDDL = 1830.20 m

Tail Water Level TWL = 1736.00 m

Design Discharge Qd = 29.50 m3/s

Length of HRT Lt = 2485.00 m

Diameter of HRT (D-Shaped) Dt = 3.60 m

Manning's Coefficient for HRT n = 0.015

Net Head of the Project Hn = 93.00 m

References

IS: 7396(Part-I)-1985, Criteria for Hydraulic Design of Surge Tank

Formula Used

Area Required for Thomas Criteria Ath =

Where,

L = Length of HRT

At = Cross Sectional Area of HRT

β = Coefficient of Hydraulic Losses

g = Accelaration due to Gravity

Hn = Net Head at Turbine

Area of Orifice Required Aor =

Where,

hor = Resistance offered by orifice

Cd = Coefficient of discharge

Resistance offered by the orifice =

Where,

hf = Total loss in tunnel system

Surge height neglecting friction & orifice =

Where,

As = Area of Surge Tank

n

t

H2gβ

AL

2ghC

Q

or2

d

2o

f*

orf

*

h 4

3

2

Z h h

4

1

2

Z

s

to

AG

ALV



Annexure-9.5

HYDRAULIC DESIGN CALCULATIONS OF SURGE TANK

SURGE SHAFT PARAMETERS

Restricted Orifice Surge Tank ( IS 7396 (Part 1) : 1985)

Diameter of Tunnel 3.6 m Coefficient of Discharge Cd

0.7

Length of Tunnel 2485 m hor 13.50 m

Flow in Tunnel 29.5 m3/s Z*

15.44 m

Net Head on Turbines 93.00 m Z*/√2 + hf/4 11.94 m

Friction Formula

2

Z*/√2 +3 hf/4 13.98 m

Manning's n

0.015 Diameter of Pressure shaft

2.8 m

X-Sectional Area of Pressure shaft

6.16 m2

X-Sectional Area of Tunnel At 11.73 m2 No. of Pressure Shafts 1

Velocity in Tunnel 2.51 m/s Velocity in Pressure Shaft 4.79 m/s

h

2.59

Provided diameter 10.00 m

Total Head Loss upto Surge Tank, hf

4.08 m Provided X-sectional area 78.54 m2

b

0.65 Diameter of Orifice (eqiv.) 1.82 m

Thoma area of Surge Tank Ath

24.67 m2 X-Sectional Area of Orifice Ao

2.59 m2

Asmin 39.47 m2

f = As/At 6.70

Enter F.O.S. for Surge Tank

1.60

Min, Diamater Required for Surge Tank 7.09 m

Min, Area of Surge Tank Required = 39.47 m2

Provided Diameter of Orifice = 1.80 m

Provided Diameter of Surge Tank = 10.00 m

Manning's



Annexure-9.6

Stability Analysis of Barrage

Width of raft upto joint = 22.50 m

Length of raft = 123.50 m

Angle of friction = 30.00 degrees

Cohesion = 100.00 kN/m2 Assumed value

Coefficient of horizontal acceleration, αh, MCE = 0.31 Zone IV Coefficient of vertical acceleration, αv = 0.21

Area of concrete in raft = 487.71 m2

Hydrostatic force Water depth at HFL (1843.5‐1827) = 16.50 m

Water depth at FRL (1834‐1827) = 7.00 m

Hydrostatic pressure (HFL) = 161.87 kN/m2

Force (HFL) = 32716.96 kN

Moment (HFL) = 179943.30 kNm

Hydrostatic pressure (FRL) = 68.67 kN/m2

Force (FRL) = 5888.45 kN

Moment (FRL) = 13739.72 kNm

Downward Weight of structure

Description Weight (kN)

Lever arm (m) Moment (kNm)

Weight of raft = 257876.66 51.70 13332997.08

Weight of bridge = 2015.13 117.78 237335.38

Weight of breast wall = 4323.41 112.96 488385.65

Weight of piers = 33945.75 107.61 3652970.05

Weight of abutment = 95104.50 61.11 5812121.31

Total vertical weight W = 393265.45 23523809.46

Earthquake forces Horz. EQ Force = 121912.29 19.14 2332791.66

Vertical EQ = 81274.86 66.16 5377307.27

Uplift Force Uplift force (HFL) = 244881.51 82.33 20161911.14

Uplift force (FRL) = 103889.13 82.33 8553538.06



SLIDING (FRL)

(w‐u)tanφ/1.0 = 120147.44

CA/1.2 = 252145.83

P = 127800.74 kN

FS = 2.91Safe

Should be greater than 1 (As per IS 6512)

SLIDING (HFL)

(w‐u)tanφ/1.0 = 38745.44

CA/1.2 = 252145.83

P = 154629.25 kN

FS = 1.88Safe

Should be greater than 1 (As per IS 6512)

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 10-Power Plant – E&M Works


10. POWER PLANT - ELECTRICAL & MECHANICAL WORKS

10.1 INTRODUCTION

The Bharmour-I HEP Project is located at Budhil Nallah in Chamba district of Himachal Pradesh.

The scheme is planned as Run of River (ROR) type development. The surfacePowerhouse

equipped with Three (3) Horizontal Shaft Francis Turbine generating units of 8 MW (with 15%

Overload) each for a total installed rated capacity of 24 MW. These units shall operate under a

rated net head of 93.00 m with a rated discharge (each machine) of 9.83 m3/s at 428.6 rpm. The

Generating Machines shall be capable of operation in Synchronous Condenser mode.

The following equipments are covered under Electro Mechanical package:

Turbine

Turbine Instrumentation

Governing system

Oil Pressure System for Governing System and Main Inlet Valve

Main Inlet Valve & its Instrumentation

Oil Purification system

Cooling Water system

Drainage and Dewatering system

Fire Fighting system

Electrical Overhead Traveling (EOT) Crane

Mechanical Workshop

Generator

Generator instrumentation

Brake dust collecting system

Excitation system

Generator Step up Transformer

DC supply system

Digital control system and SCADA

Protection system

Cabling system

Auxiliary AC supply system

Communication system & Illumination system



Mechanical & Electrical Workshop

Grounding system

DG sets

10.2 MECHANICAL EQUIPMENT

10.2.1 Introduction

The turbine layout, sizing, calculations and performance are based on general experience of the

developer, worldwide practices and statistical data available for comparable hydraulic units

confirmed by specific model test data for similar available layouts. Equipments are specified

according to the international standards.

The main turbine characteristics have been established in such a way that, in order to ensure

competitiveness among the Bidders, all major suppliers can meet those criteria.

10.2.2 Power Station Characteristics

10.2.2.1 Water Levels

Water levels shown here below represent a summary of the main hydraulic data of the power

scheme used for the hydraulic layout and dimensioning of the turbines.

Water levels Elevation (m. asl)

Remarks

Head Pond

HFL 1843.50

- Maximum Water Level (MWL) 1835.50

- Full Supply Level in collection pool (FSL)

1835.00

- Min. Operating Level (MOL) 1830.20

Powerhouse Tail Water

Minimum TWL 1734.15

10.2.2.2 Gross Heads

The gross head taken into account for the power waterways design and turbine selection are as

follows:

Head (m)

Gross Head 99.50



10.2.2.3 Head Losses

The total head losses of the head race tunnel and surge shaft/penstock is 5.43 m with three

units in operation at the design discharge.

10.2.2.4 Net Heads

The net heads which are relevant for turbine sizing are compiled in the table below:

Net Head (in meters) Net Head

- 3 units in operation

- 2 units in operation

- 1 unit in operation

93.00

96.63

99.28

10.2.2.5 Turbine Layout and Design

Unit Selection

Three Turbine- Generator units, each with unit output of 8 MW are selected based on the

following considerations:

Interconnection to the power system,

Flexibility of operation and maintenance schedule of units.

Transportation of equipment and

Total investment cost of the project.

For rated net head of 93.00 m and 29.5 m3/s (Total rated discharge) available at the power plant

site, three horizontal axis Francis Turbine of 428.6 rpm have been selected. The speed 428.6

rpm (with optimum –ve setting) is selected to accommodate the TG unit in proper layout.

For selection of speed, the parameters of specific speed and turbine setting have been

considered.

S. No: Speed (RPM) Specific Speed Ns (hp-m) Turbine Setting (m)

1 375 146.82 1.230

2 428.6 167.80 (-) 0.595 (Adopted -0.750 m)

3 500 195.76 (-) 3.242

Based on the above analysis, turbine with 428.6 rpm has been selected.

The alternative speed of 375 rpm and 500 rpm were also considered for the turbine selection.

At 500 rpm the Turbine setting is calculated as 3.242 m below minimum tail water level of EL.

1734.15 m.



However, TG speed of one level lower i.e. 428.6 rpm, is recommended. At higher speeds the

tendency towards silt erosion will be more.

At 375 rpm, turbine with same speed of generator increases the weight of the unit, which

increases the cost of TG set, its handling EOT crane & also require more space to

accommodate the TG unit, which increase the powerhouse size.

With respect to TG speed of 428.6 rpm the turbine setting of (-) 0.595 m will be adequate.

Turbine setting of (-) 0.750 m is considered to properly accommodate the TG unit in the layout.

Therefore, considering the best techno-economic viability, ease of operation and maintenance of

machine, Horizontal shaft Francis Turbine with 428.6 rpm speed is selected. For safety margin

towards cavitation, turbine centre line is selected as (-) 0.750 m from Min. TWL i.e. 1734.15 m.

Turbine Rated Power and Discharge

The mechanical rated power of each turbine under design net head of 93.00 m is the input data

used to define the installed capacity of each generating unit.

The installed capacity is understood as the electrical power available at the generator terminals.

Assuming generator efficiency as Gen =96.5%, turbine efficiency T =92.5 %

P = 9.81x 93.00 x 9.83 x 0.925 x0.965 = 8 MW per unit, thus 24 MW total power at generator

terminal.

Turbine Performance

The turbine will be able to operate safely and cavitation free at any head between the maximum

and minimum net head and between 40 & 100% load. Since the head variations in relation to

the total head are rather small, the unit will always operate quite close to the rated head. Turbine

shall be capable to generate 15% continuous overload.

Turbine Dimensions

The turbine dimensions used for the powerhouse layout were established on the basis of

statistical analysis of turbines built by various leading manufacturers over last decades.

Approximation equations have been developed which allow calculation of the main dimensions

as a function of specific speed and runner discharge diameter.

The efficiency is estimated to reach the values given below.

Load [%] 100 90 80 70 60

Turbine Efficiency [%] 92.5 92.3 92.2 91 88



Determination of submergence

The actual turbine setting was checked on the basis of the Thoma coefficient aimed at

preventing the risk of cavitation during turbine operation.

The Thoma coefficient was determined on the basis of experience values collected from similar

type of projects, for Francis turbines supplied by various manufacturers.

A value σ = 0.090 presents safe assessment for establishing the unit setting and allowing all

major turbine suppliers to meet the setting requirement for cavitation free operation and presents

a safety margin for the proposed net head and discharge.

The minimum required submergence is related to tailwater elevation TWL 1734.15 m.

Consequently, the spiral case centre line will be set at EL. 1733.40 m, setting the turbine centre

line at 0.75 m below TWL.

Runaway speed

The runaway speed has been considered as below:

Runaway speed coefficient fr 1.8

Max. runaway speed nr 771.48 rpm

At present, the calculated maximum runaway speed has only an indicative character and the

precise value to be later used for stress calculations of the turbine and generator parts will be

determined during the model tests which have to be carried out by the selected turbine supplier.

Turbine design

The turbine will be hydraulically and mechanically designed for trouble-free operation at all

heads, between the maximum and minimum normal net head, as well as, for any load between

40 and 100 % of the maximum possible load at any particular head.

The Pressure rise shall not be more than 35%. The Speed rise shall not be more than 45%. The

speed rise calculation can be done only when turbine curves will be available from turbine

manufacturer. The TG unit will be selected as the limits of transient stated above.

As per industry practice, the material of Runner & Guide Vane s will be ASTM A743 CA6NM

(13-4 Cr-Ni). The runner discharge diameter will be in the range of 2.2 m.

The spiral case will be formed from high strength welded alloy steel with guaranteed notch

impact properties at low temperatures. Other turbine parts will be made out of various kinds of

high quality structural steels, cast, forged or welded.

For maintenance purpose, a lower drawer will be provided in the draft tube below the turbine

runner. This access will allow the exit of the turbine runner as well as Guide Vane s during



maintenance period. The access will be connected to the EOT Crane for evacuation of

equipment to the maintenance platform.

An electronic governor, in conjunction with the high pressure hydraulic system (approx. 64 bars),

will control the Guide Vane s by means of two hydraulic servomotors and automatically regulate

the turbine speed and power.

The visual inspection of draft tube liner will be through a set of embedded rungs in a vertical

shaft from platform, upstream of the draft tube stoplog grooves, ending at the draft tube floor.

10.2.3 Turbine Governors

10.2.3.1 General

Each turbine wiII be provided with a digital, microprocessor type PID governor. The governing

system will be connected to and be fully compatible with the power station control and

monitoring equipment.

It will be possible to control the turbines remotely from the main Control Room, from the unit

control board (UCB) and locally manually from the governor actuator panel.

The governors will allow for sharing between the units under any conditions of load and speed.

The turbine governor pumping units, the pressure accumulators and the control cabinet for local

control should be placed in Machine Hall.

The digital, programmable electronic governor should preferably be installed in the unit control

board.

The following functions will be included in the governor:

Speed control at no load operation

Automatic start and stop sequences, including automatic synchronisation

Power output control; operation at output limitation with power feed back

Frequency regulation

Water level regulation (if required)

Load sharing between the units in “joint control” mode

Emergency shutdown in two different sequences

Emergency shutdown on electrical failures

Quick shutdown in case of mechanical failures.



10.2.3.2 Performance Data

1) Guide Vane s Servomotor Operating Time

Opening time adjustable; minimum net time less than 30 seconds

Closing time adjustable

2) Range of adjustments

Speed adjustment at no Ioad ± 10% of rated speed

Gate limitation 0 - 100%

Permanent at no load ± 10% of rated speed

Temporary speed droop 1-200%

Time constant of damping device: 0 - 6 seconds

Derivative time constant: 0 - 4 seconds

3) Static Performances

Dead band of the governor (speed sensitivity) <1/10000 of a relative frequency

variation.

Dead time: less than 0.2 seconds

Accuracy of load setting: Iess than 2%

Speed stability at no load: the various parameters of the governor wiIl be adjustable to

warrant a stable speed during no-Ioad operation.

Stability on load ± 1/1000

4) Dynamic Performances of Governor System

Over speed at full Ioad rejection, under the most unfavourable load and head

conditions: less than 45%

Maximum pressure rise at full load rejection, under the most unfavourable load and

head conditions: less than 35%.

10.2.3.3 Standards and Regulations

The following standards are specifically applicable:

DIN 4321, technical requirements for governing systems of hydraulic turbines IEC publications

60308, international Code for Testing of Speed Governing Systems for Hydraulic Turbines

Pressure vessels; ASME section VIII .



10.2.3.4 Design Conditions

Oil pressure in the governing system will not exceed:

For nitrogen filled bladder or piston accumulator: 80 - 120 bar

Pressure will be finalised with the type of system proposed by the supplier.

1) The velocity in pipes will not exceed 2.5 m/s at maximum oil flow

2) Capacity of oil accumulator

The governor system will be provided with an oil/nitrogen type accumulator with a capacity

meeting the following requirements:

a) The oil pumps are assumed to be disabled

b) The oil in the accumulator tank has dropped to the level where the pumps should resume operation

c) The amount of oil still available in the tank will be able to operate 3 full strokes (close-open-close) of the Guide Vane servomotors & Main Inlet Valve.

Oil sump of oil pressure unit

The volume of the oil sump of the oil pressure unit will be at Ieast 10% bigger than the total oil

volume contained in whole governor system Guide Vane servomotors and circuits.

Oil pumps

Each governing hydraulic system will be equipped with two (2) oil pumps having maximum

rotating speed 1500 rpm and each having a capacity per minute of at Ieast one and half (1.5)

times of total volume of the Guide Vane servomotor(s) or Main Inlet Valve.

One service pump will run when the generating unit is in operation or is ready to operate.

The second standby pump will be put into operation automatically in case of abnormal loss of

pressure or if the service pumps fail.

Guide Vane servomotors will be provided with mechanical lock for closed and for open positions.

10.2.4 Butterfly Valves

A Main Inlet Butterfly Valve, able to close safely against the maximum turbine flow will be

installed upstream of each turbine.

The nominal diameter of the valve will be 1.5 m. For the rated turbine discharge of 9.83 m3/s, the

flow velocity through the valve will be about 5.6 m/s.

The valves will be opened by high pressure hydraulics but, for security, they will be closed by

counterweights.



The pumping units for the valves could be placed at the elevation of the Machine Hall.

10.2.5 Draft Tube Gates

The present design is for the draft tube gates to be installed at the downstream end of the

powerhouse. The draft tube gate will be in one section to close off an opening approximately 2.4

m wide and about 2.1 m high. The Draft Tube Gate will be fixed wheel type.

Three sets of gates will be required to allow dewatering of the three units at the same time. The

gates will be raised and lowered by an individual Rope drum hoist of about 20 tons capacity.

The final capacity value depends, however, on the final dimensions of the draft tube outlet and

needs to be reconfirmed after the finalising of the preliminary powerhouse design.

10.2.6 Cooling Water System

The system will be open loop type, taking water from the downstream pool and disposing it to

tail race pool above max. TWL. The system will circulate filtered quality water through TG units.

VTPs/ Submersible Pumps, Piping, Valves, Instruments and all other equipment required for

proper operation of the system will also be provided.

Water temperature of 300C is considered for design of heat exchangers of Cooling Water

System.

The unit wise cooling water pumping & supply system will be provided. One generating unit will

be treated as a unit.

Each unit cooling water system will be located in the Operating Floor of Powerhouse and will

draw raw water from the downstream pool through VTPs / Submersible pumps.. The raw water

will be cleaned through motorized automatic online self cleaning simplex filter (1 working + 1

standby), before supplying it to Generator Air Cooler, Generator’s upper & lower guide bearings,

Turbine Guide Bearing, Shaft Seal, Oil Pressure Unit etc.

10.2.7 Station Drainage & Dewatering System

10.2.7.1 Station Drainage System

The drainage system includes floor drains, leakage water drains, seepage water from all the

walls in contact of water, Powerhouse joints, outside walls with backfill against them and

seepage water from tail race side and upstream side and drainage of water from other

equipment such as turbine shaft glands, dewatering valves etc.

All the drains will be connected through drainage channel to the common station drainage sump,

where two (2) nos. Submersible sump type Pumps (one working & one standby) of equal

capacity driven by suitable rating AC motors will be installed for pumping the drainage water to

tail race after draft tube gate, at level above the HFL.



The Submersible Pumps will be complete with motor of protection class IP 68, set of Automatic

Detachable Pedestal Coupling, Dismantling joint, Guide Rail Pipes, Lifting Chain of GI etc. The

pumps will be capable of handling muddy/turbid water. The main and standby duty of the pumps

will be interchangeable with the help of selector switches provided for the purpose. The system

will be complete with all the accessories.

The drainage sump will be provided with level sensors to facilitate auto starting and auto

stopping of the pumps. Depending on the water level in the sump due to the station drainage,

the number of pumps as pre determined will come into operation. The sump level very high will

be sensed by a separate level sensor and alarm provided.

The quantity of all effluents at its peak into the sump will be considered and the station drainage

pumping system will be sized to handle the same.

If for any reasons the water level in the drainage sump continues to rise beyond the preset level,

high water level alarm and annunciation will be sounded at the local control panel and in the

Control Room.

10.2.7.2 Unit Dewatering System

The dewatering system will be provided for dewatering of Penstock, Main Inlet Valve, Spiral

Casing, Draft Tube, leakage through MIV and Draft Tube Gates, and for access to turbine for

inspection and maintenance. Water will be drained by gravity to the extent possible. Draft Tube

will be connected through a pipe at lowest point of the draft tube to the unit dewatering sump,

from where it will be pumped out of the Powerhouse by a portable Submersible Sump Pump and

discharged above HFL into the Tail Race Channel.

The system will comprise of two set of portable Submersible type pumps (one working & one

standby), of equal capacity driven by suitable rating AC motors.

The Submersible Pump will be complete with motor of protection class IP 68, Flexible discharge

pipe, Lifting Chain of GI etc. The pumps will be capable of handling muddy/turbid water.

The capacity of the dewatering pumps will be such that the turbine water passage between the

downstream of Main Inlet Valve and the draft tube Gate can be emptied in less than 4 (Four)

hours, taking into account maximum anticipated leakages through the Butterfly Valve seals and

through the Draft Tube Gate seals.

10.2.8 Main Lifting Equipment

Powerhouse Crane (80T/20T)

The required total maximum lifting capacity of Powerhouse Crane is determined by the

combined weight of generator stator and rotor which weighs ~ 74 tons.



The main hook of 80 T and an auxiliary hook of 20 T capacity will be provided on the crane and

will run along the main bridge beam; this will be used for handling smaller equipment and for

normal maintenance work such as runner removal etc.

The proposed capacity of the crane has to be confirmed by the turbine & generator supplier.

10.2.9 Powerhouse Heating Ventilation & Air Conditioning Systems

The Powerhouse building will be provided with Exhaust fans below roof Truss.As the Operating

Floor is about 5 m below the ground level, adequate number of Air man coolers will be provided

at operating Floor for circulation of air.

Control Room & offices will be provided with Windows / Split type air conditioner.

10.2.10 Fire Fighting System

The fire fighting system will be provided for the Powerhouse, Auxiliary Buildings and Switchyard

etc. The system shall comprise the following equipment:

CO2 type fire extinguishers

Foam type fire extinguishers

Dry Chemical Power type

Nitrogen injection based fire protection system for Generator Transformer.

The number and type of equipment and the installation of main fire fighting shall be in

accordance with the tariff advisory committee (TAC) regulation and relevant IS codes.

Fire insulation system will be installed around all control and power cables where they enter/exit

the powerhouse and where they pass through any fire retaining wall, such as battery room,

transformer rooms, DG room etc.

An automatic fire detection and alarm system with addressable Multi-sensor & Photoelectric type

detectors will be provided for Electric Room, Control Room, Offices, Battery Room, other

miscellaneous rooms to give audio & visual indication of fire in these areas. Manual Call Points

(MCP) & Exit signs will be provided near each escape. The annunciation system will operate at

110 V DC. Fire detection and annunciation panel will be housed in the Control Room.

10.2.11 Oil Purification Systems

10.2.11.1 General

Oil handling system will be utilized for storing the contaminated lubricating oil from the bearing

pots of the generating units; for storing clean and purified lubricating oil; for filling the bearing

pots with purified oil and for local treatment of oil at the governor oil sumps and bearing oil pots

of the generating units.



10.2.11.2 Lubricating Oil purifying system

The lubricating oil purifying system is intended for Inlet Valve hydraulic system, Turbine

Governor hydraulic system and Turbine/Generator Bearings.

One number mobile tyre mounted centrifuge type lubrication oil purifying plant will be a self

contained & enclosed unit of adequate capacity complete with pumps of suitable rating,

centrifuging chamber and other appurtenances to make the system complete & functional. The

system will also be having oil hoses, hose couplings and other accessories as required. The oil

hoses will be of sufficient length and size to connect lubrication oil purifying plant to various

equipment / components / systems.

The oil transfer pumps will be of vacuum tight, positive displacement gear type complete with

coupling, check valve shut-off valves, safety relief valve high temperature shut down, etc. The

purifier will be capable of processing the lubricating oil on not more than two (2) passes basis at

rated flow to the following specification:

Free water : 100% reduction

Moisture content : Less than 50 PPM

Filtration : Less than 1 micron

Suitable piping both embedded and exposed, fittings, fixtures etc. will be provided for the

Turbine, Governor and Generator.

Alternative to this, Electrostatic Liquid Cleaning (ELC) system in combination with Low Vacuum

Dehydration unit will be provided for particulate and water removal from Oil. The ELC system

uses the principle of electrostatics to collect fluid contaminants even smaller than 0.01 micron.

10.2.11.3 Insulating Oil Purifiers

The insulating oil purifiers will be of filtration and vacuum dehydration type. Unit will consist of

coarse filter, oil transfer pumps, thermostatically controlled ceramic heaters, filtration section,

deoxidizing column, vacuum pumps, discharge pump, two stage degassing system, transformer

evacuation system, thermometers, pressure/ vacuum gauges, flow meters, valves, piping,

control panel with online process monitoring facility and other accessories necessary for

satisfactory operation of purifiers. The insulating oil purifiers will be suitable for indoor and

outdoor duties.

The purifier will be capable of processing the oil on single pass basis at rated flow to the

following specifications:

Moisture content : Less than 5 PPM

Gas content : Less than 0.1% by volume

Dielectric strength : 70 kV across 2.5 mm gap



Filtration : Less than 1 micron

Power Factor Tan Delta at 90 deg C : 0.002

10.2.12 Workshop Equipments

The Workshop equipment will broadly consist of equipment listed below:

Radial Drilling Machine

Lathe Machine

Shaper Machine

Double Ended Pedestal Grinding Machine

Power Hacksaw

Rectifier type Welding Machine

Portable Tools

i) Portable Electrical Drilling Machines with magnetic base

ii) Portable Straight Grinder

iii) Portable Angle Grinder

iv) Portable Flexible Shaft Grinder

v) Portable Sander / Polisher

vi) Portable type of Electric Oven for preheating of welding rod

Lot of hand tools and instruments

10.3 ELECTRICAL EQUIPMENT

10.3.1 Main Single Line Diagram

The power plant consists of conventional type of generating units, employing three (3) nos.

horizontal shaft Hydroelectric Generators driven by horizontal shaft Francis Turbines. Each

Generator is rated at 8.0 MW at 0.90 p.f. with maximum continuous rating of 10.76 MVA, 3-

Phase, 50 Hz, class F insulation with temperature rise limited to class B for stator and rotor

windings.

The Generators are directly connected to 11 kV Switchboard and then a bank of Step-up

Transformers consisting of 3X1PH, 11 MVA, 11/132/√3 kV, 50 Hz rating will be provided for all

units for evacuation of Generated Power. The 132 kV switching scheme employs stepping up of

voltage from 11 kV generating voltage to 132 kV, as shown in drawing no P1335-ED-2001. The

power generated from the power station as well as power from other stations, is proposed to be

evacuated through 132 kV ring main transmission line upto a pooling station at Bharmour for

onward transmission to Chamera-III grid station. For details refer chapter on power evacuation.



The basic insulation levels of different equipment have been selected suiting higher site

elevation (approx.1742m) of the power house above msl.

10.3.2 Generator

The generators will have the following parameters:

Type : Synchronous (Salient Pole)

Rated output : 8.0 MW

Maximum Cont. MVA output : 10.76 MVA

Rated Speed : 428.60 rpm (same as turbine)

Runway speed : 1.8 times rated speed of turbine

Rated voltage : 11 kV ± 10 %

Frequency : 50 Hz ± 5 %

Excitation : Self Excited-Brushless

Rated Power factor : 0.90 (Lag)

Short circuit ratio : 1.0

Temp. Limit : Class B

The generators are envisaged to have continuous over load capacity of 15 % over the rated

output with rated voltage. Provision of this overload capacity is as per convention and will be

useful during planned and forced outage of any unit, as the capacity loss due to such outage

could be partially compensated.

The generator rated voltage has been selected as 11 kV based on the IEC and Technical

standards for construction of electrical plants and electrical lines issued by CEA.

The generator stator and rotor winding will be provided with epoxy insulation of class “F”. The

generator shall be designed to withstand the runaway speed which shall be coordinated with the

turbine supplier. The reactance, short circuit ratio (SCR) & Inertia GD2 shall be consistent with

optimal and stable operation of the units both under steady state and dynamic conditions.

For the rated as well as continuous overload output within the permissible operating conditions,

the temperature, rise limits of the stator and rotor windings will be restricted to class “B”

insulation and the temperature limits will be as per prescribed in standards BIS/IEC.

The generator will be water cooled.

Generator Stator

The stator frame will be of welded plate construction, and core adequately strengthened offering

a high degree of resistance to distortion, buckling and vibration under fault conditions, system



disturbances and also the magnetic forces that tend to deform it as the rotor field rotates. The

stator core will be built up with high-grade non ageing thin laminated silicon steel, each

lamination coated on both sides after punching with an insulated varnish to minimize the eddy

current losses. These laminations are keyed or dovetailed to the stator frame and securely held

in place by clamping flanges at each end.

The stator winding will be Wye (Y) connected with the neutral brought out to ground via a high

impedance connection. The neutral connection includes a single-phase disconnect switch, a

single-phase distribution transformer 11 kV: 110V and a grounding resistance connected to the

low voltage side of the distribution transformer. The stator windings will be made of copper and

insulated with full Class F insulation with a temperature rise limited to class B.

Generator Rotor

The rotor will be built to safely withstand all overloads and stresses encountered during

abnormal or runaway condition. The pole pieces will be built of thin laminations secured by bolts

passing through supporting end plates and the pole faces. The pole pieces are attached to the

rim of the rotor by means of dovetails and corresponding to dovetailed slots in the rotor rim. The

insulation for the rotor winding will be of Class F.

The Generators will be equipped with horizontal bearings. The bearings will be pad type or

sleeve type with Babbitt-metal lined type and oil lubricating. The bearings will be cooled by oil-

to-water heat exchanger. The DE bearing shall be thrust cum journal bearing while NDE bearing

shall be journal bearing.

Instrumentation will be provided to monitor the condition of the Generator during operation. This

instrumentation includes:

Stator winding RTD’s, DTTs and Thermometers

Air temperature RTD’s., DTTs and Thermometers

Bearing metal RTD’s, DTTs and Thermometers.

Bearing oil reservoir RTD’s, DTTs and Thermometers

Field temperature measuring device

Shaft vibration monitoring.

Smoke detectors.

Lubricating oil pressure and level switches.

Brake position.

Shaft circulating current protection

Excitation System

The excitation cum digital automatic voltage regulation system shall be of brushless rotating type

comprising of field in the stator of the exciter & rotating rectifier to be mounted on the shaft. The



surge suppressors are also mounted along with the diodes to protect the diodes. The voltage

regulation system shall be both manual as well as automatic control. The system shall be

capable enough to maintain the output terminal voltage constant within the regulation limits.

The power for the excitation system will be taken from the Generator mains by means of a step

down transformer (normally installed inside the LAVT panel). The excitation system will be self

contained requiring only an external power source for field flashing at unit starting. The field

flashing supply will be taken from the station battery.

10.3.3 Excitation Transformer

The Excitation Transformer will be a dry-type epoxy encased transformer, three-phase, 50 Hz,

natural air cooling with a primary voltage of 11 kV. The power rating and the secondary voltage

are data that will be calculated by the excitation system designer. The windings will be in

copper. The insulation material will be of Class F with a temperature rise of 75º C.

10.3.4 The excitation cubicle

The excitation cubicle shall consists of a microprocessor based digital excitation control module,

panel accessories i.e. panel lamp, space heaters with thermostat, annunciation through LED

based lamps, 110 V DC station battery power for control etc.

10.3.5 11 KV Main Switchgear

The 11 KV Main Switch Board shall be suitable for 11 kV high impedance / UN earthed system

with liberal safety clearances inside the panel.

The 11 KV Main Switch Board shall consists of 6 nos Panels (3 Gen, 2 Aux. transformer, 1 step-

up transformer and two Bus PT Panels). The 11 KV Main Switch Board shall be provided with

horizontally with drawable trolleys and shall be of internal arc proof design. The switchboard

enclosure shall be IP: 4X class. The following are the electrical characteristics of 11kV

switchgear:

Rated voltage & Frequency : 11kV / 50Hz

Highest system voltage : 12.1kV

Rated Normal current of VCB/SF6 : 2500/1250A

Short duration power frequency

Withstand voltage for 1 minute : 38 kVrms

Impulse withstand voltage : 95 kVp (Considering site elevation).

Short circuit breaking capacity : 40 KA for 3 sec.



10.3.5.1 11 kV (UE) XLPE Aluminium Cable

The 11 kV Main Switchboard will be connected to the main step-up transformer through 11 kV,

3X2RX1CX400 Sq. mm Aluminium XLPE (UE) Armoured Cable. The following are the electrical

characteristics of 11kV (UE) XLPE Aluminium Cable:

Rated voltage & Frequency : 11kV / 50Hz

Highest system voltage : 12.1kV

Cable Type : AL XLPE

Rated continuous current in Air : 630A

10.3.5.2 11 kV XLPE Cable & LAVT Panel

The Generator output will be connected to the 11 kV Switchboard & LAVT Panel using single

core, 11 kV (UE) XLPE cable with AL conductor as shown in the Electrical SLD. The LAVT

panel will comprise two sets of three-single phase draw out type epoxy encapsulated potential

transformer. Each potential transformer has a primary voltage rating of 11/ √3 kV and triple

secondary windings of 110/√3 V each. The same enclosure will also include a set of three-metal

oxide lightning arresters and three surge capacitors. The LAVT Panel shall be designed for short

duration power frequency withstand voltage / Impulse withstand voltage 38kVrms/95 kVp.

10.3.6 Step-up Transformer

A bank of Step-up Transformers consisting of 3X1PH, 11 MVA, 11/132/√3 kV, 50 Hz rating will

be provided for stepping up power of all the three units. The ONAN type of cooling is proposed

for the Transformer. The main electrical characteristics of the power transformer will be as

follows:

Table-10.1 Step-up Transformer Main Electrical Characteristics

Description Characteristics

Power Rating: 11 MVA

Phase: 1

Frequency: 50 Hz

HV Rating: at no load 132 kV/√3

LV Rating: at no load 11 kV

Vector group (of 3Ph. Bank) Ynd11

Rated Lightning Impulse withstand voltage of LV winding/bushing

75/125 kVp

Rated Short duration power frequency withstand voltage of LV winding/bushing

28/38 kV rms



Table-10.1 Step-up Transformer Main Electrical Characteristics

Description Characteristics

Rated Lightning Impulse withstand voltage of HV winding/bushing

650 kVp

Rated Short duration power frequency withstand voltage of HV winding/bushing

275 kVrms

Rated Lightning Impulse withstand voltage of neutral conductor /bushing

170kVp

Rated Short duration power frequency withstand voltage of neutral conductor/bushing

70kVrms

Grounding HV neutral solidly grounded

Temperature Rise of Windings 55°C

Cooling: ONAN

Tap Changer: Off-Load

Impedance: Around 12.5 %

The Step-up transformer will be oil type, located in the outdoor switchyard and mounted on rails

along with an oil sump to contain the oil from the transformer and drain it to an oil-water

separator tank. In addition one transformer will be kept as reserve.

The transformer core will be built with non-ageing cold rolled grain oriented silicon steel

laminations having a high permeability and a low loss coefficient. The windings will be made of

electrolytic copper, insulated with cellulose paper and designed to withstand short-circuits and

high voltage stresses without any overheating. The transformer tank will be constructed of

welded sheets of carbon steel, reinforced in order to withstand the most severe conditions of

operation, transport and vacuum treatment.

The outdoor bushings HV, LV & HVN will be selected with higher minimum creepage distance of

35 mm/kV due to considerations for site elevation.

The transformer will be equipped with the following accessories and metering instruments:

An oil conservator made of steel sheets with welded joints. A diaphragm air tight seal is

provided with a breather connected into the air side of the diaphragm.

A pressure relief device to protect against high pressure inside the oil tank.

A gas relay mounted in the pipe connecting the conservator to the transformer tank and

having contacts for alarm and shutdown.

A winding temperature indicator with sets of contacts for alarm and trip.

An oil temperature indicator with alarm and trip contacts.



An oil level indicator with magnetic level gauge and alarm contact.

A manually operated off-circuit tap changer for changing the high voltage winding taps at

no load and no voltage.

Power transformer will be equipped with a weatherproof metal cabinet arranged for separate

mounting or mounting on the transformer unit. Automatic controls, motor starters, protective

devices, switches, terminals, etc. will be assembled and connected in the cabinet.

10.3.7 Grounding System

The ground grid will be designed based on the soil resistivity measured at site and designed

according to IEEE80. The grounding system, which is an integral part of the powerhouse and

the switchyard, will fulfill the following functions:

Protect the personnel and public from dangerous potentials such as transferred potentials,

touch and step potentials during both normal operating and maximum ground fault

conditions

Provide connection to ground for non-current carrying parts of the electrical equipment

and power equipment neutrals

Facilitate the clearing of ground faults through protective system

Dissipate static charges and/or induced current from current carrying lines or parts thereof

that need to be worked on

Dissipate lightning discharges

The grounding system of the power station will comprise of a grid in the powerhouse and switch

yard. The grounding systems will be designed to achieve a ground resistance low enough to

adequately limit the ground potential rise.

The powerhouse and the switchyard ground grids will be connected together. The conductors

used for the power house ground mat and switchyard ground mat will be corrosion resistant

galvanized (flat, bar etc.) steel or MS rod of suitable diameter. The connections between buried

conductors or conductors inside concrete are made by welding process.

10.3.8 Control, SCADA, Instrumentation & Monitoring

PLC based Unit Control board shall be provided, which shall control all functions of the

generating units, transformer and lines etc., both in auto & manual mode. A separate Unit

Control Board shall be provided for each unit and shall comprise of ammeter, voltmeter, power

factor meter, kWH meter, kVAR meter, frequency meter, recorder, push bottons, indicators etc.,

as per the system requirement. The trivector energy meters shall also be provided of 0.2S

accuracy class for measurement of import & export of energy for the system.



10.3.8.1 Unit Control Board (UCB)

Each unit will have its own UCB and SCADA system at Station level from which the unit will be

controlled automatically. It will also contain PLC & associated man/machine interface for the

alarms and sequence of event recording. It shall also be possible, from the UCB, to manually

start and shutdown the unit in normal operation, shutdown in an emergency situation and

manually operate locally the unit during test and maintenance.

10.3.8.2 Temperature & Gauge Panel

The instrumentation panel (close to the governor control panel), will have all necessary

interfacing relays to connect with the unit control board and the SCADA system. This

instrumentation panel will also have protection system as well as the temperature monitoring

system.

10.3.8.3 SCADA

The function of plant central computer control system will be to provide automatic control for all

the units as well as the data acquisition, alarm monitoring and data logging and archiving.

Programmable Logic Controller (PLC), (Part of the SCADA system) located in the UCB, which

will be entirely dedicated to the unit as well as plant control and data acquisition.

One redundant PLC shall be dedicated for each unit in the UCB. The substation will have a

dedicated PLC. Other PLCs and /or RTUs shall be provided for control and data acquisition of

auxiliary services and intake. All PLCs will be connected to a central unit in the control room

through fiber optical cables. The central unit, through a man machine interface (video displays,

functional keyboards, pointers) will be used to provide efficient communication between the

operators and the control system. The SCADA system will also be designed to interface and

communicate with the grid displaying system through a telecommunication system, transmitting

all the required data that is essential to the grid dispatching operator.

10.3.8.4 Philosophy of Tandom Operation of Hydro Power Plants The Bharmour-I HEP & Bharmour-II HEP will operate in Tandom operation. The following

conditions must be met for the Tandem operation of hydro power plants:-

Fundamental principle for tandem operation is that the water of upstream power house is

used to generate power at downstream power house.

The design of both projects shall be such that the design discharge for both plants is

nearly same.

The design as well as working head to be nearly in same ratio as that of their unit as well

as plant rating.

The number of units in both plants shall be same.

Each unit of upstream plant is dedicated to corresponding one unit of downstream plant.



During initial start up the time required to fill and reach from U/s plant to D/s plant shall be

assessed.

Dual and Positive communication link to be available between both plants. This is required

for VOICE, DATA and CONTROL COMMAND to and fro transfer (both ways).

One of station (mostly U/S PH shall be a master station and D/S Station shall be slave

station.

There should be escape between water conductor connecting U/S and D/S stations.

This escape shall be sufficient for escape of discharge from all units of U/S power plant.

This is to cover the eventuality, when D/S plant is closed or trips due to some problem.

Governors of both shall operate in tandem and programmed in such a manner that there is

proportionate increase/decrease in output of D/S plant as soon as the U/S plant output

increases/decreases.

The D/S plant shall be a follower station with U/S plant being a lead station. Hence the

D/S plant to be remote controlled from U/S plant.

V sat or Fibre link to be established.

Based on above, the Bharmour-I HEP Control room will be designed as master control room for

both Bharmour-I & Bharmour-II and will exercise overall/Master control on the Bharmour-II units.

Any tripping/non operation of a unit at Bharmour-I plant will ensure that the corresponding unit at

Bharmour-II also doesn’t generate. For communication of Voice, Data & Control command

between the two stations, Optical fibre cable (OFC) has been included between the two stations.

Separate fibres will be used to provide redundancy for the communication link. The

DCS/SCADA system for the two stations will be designed satisfying the above requirements for

both remote and local modes. Adequate size of escape has also been provided in the water

conducting system between U/S & D/S plants.

10.3.9 Electrical Protection

Suitable Electrical Protection for the Generator & Transformer, mainly consisting of following

shall be provided.

High speed differential protection for Generator & Transformer.

Generator over Voltage protection.

Back up over current protection.

Stator earth fault relay protection.

Negative Phase Sequence Current protection.

Rotor Field Circuit earth Fault Relay & protection.

Loss of excitation.



Generator thermal relay protection

Phase balance relay.

Over fluxing protection.

Restricted earth fault protection.

Step-up transformer winding temperature (Alarm & trip).

Step-up transformer oil temperature (Alarm & trip).

Step-up Transformer Buchholz type gas protection (Alarm & trip).

Step-up Transformer oil level low (Alarm).

Local breaker back-up protection.

Suitable busbar and transmission line protection will be provided as described in next section.

10.3.10 Relaying and Metering

A protective relaying system will be necessary to reliably initiate clearing of electrical faults and

conditions that August be detrimental to the plant equipment. The protection relay equipment

and the operation of the breakers and other plant control/equipment necessary to clear the faults

will be on a protection channel arrangement for high reliability. All relays shall be microprocessor

based/numerical type.

The following are recommended for the protection of the Generator and its step-up transformer

and the associated equipment:

Generator differential, which protects the machine itself.

Generator neutral ground: one ground over-voltage relay, which protects about 95% of the

Generator winding, and a second third harmonic under voltage relay of 100% Generator

winding protection, which protects the machine from faults near the neutral.

Generator negative sequence to protect the Generator rotor from overheating due to

unbalanced phase currents.

Generator over-/under-voltage to protect the stator winding from damage due to voltage

condition outside the operating range.

Generator phase loss to detect blown fuses which could cause disoperation of relays of

the voltage regulator.

Generator field ground to alarm on a field ground at one point and Generator trip with field

ground at two points condition.

Generator synchronicity checks to prevent out-of-phase synchronization.

Generator breaker failure, which causes the following protection zone breakers to trip on

the failure of a Generator breaker to operate due to a fault current or high residual voltage

detected by the protective relaying.



Excitation transformer over current protection, to trip the unit on detection of an internal

fault in the excitation transformer.

Step-up transformers bank differential.

Step-up transformer volts/hertz to protect the machine and transformer cores from

overheating due to over fluxing/ over-excitation.

Differential REF for the 11/132 kV Step-up transformers bank .

The following relays are recommended for the 11 kV & 132 kV systems:

Bus differential protection & Local Breaker backup protection for 132 kV system.

Transmission Line will have distance protection in addition to O/C and S/C protection. The

Distance relay will have builtin feature to indicate fault location on the Line along with the

distance protection.

Bus PT/Line PT Protection (Voltage Balance relays).

Power metering and recording of events provides operators with information concerning the

condition of the plant equipment. The information will be available to the operator locally and

at the plant SCADA system.

The following metering is recommended for the station:

Generators’ three-phase current & Voltage.

Generators’ frequency.

Generators’ MW/MWH/MVar at 11kV.

Excitation Transformer Voltage, current, MW/MWH

Station’s 11 kV & 132 kV voltage & frequency.

Station’s MW/MWH/MVar (Export/Import).

132 kV transmission Line voltage & frequency.

132 kV transmission Line load (MW/MWH/MVar) (Export/Import).

SST voltage, current, MW/MWH (MFM) on Primary & Secondary.

Step-up transformer MW/MWH.

10.3.11 Auxiliary Electrical Services

Two nos. 11kV/433V, 500kVA, 3phase, Dyn11, Dry type station service transformer (SST) shall

be provided to meet auxiliary loads of the unit, powerhouse, switchyard, viz. general lighting, oil

pumps, governor, crane, ventilation and other misc. loads.

Both the transformers (SST-1&2) shall be supplied through the 11kV switchboard bus. Each

transformer is capable of feeding all the unit & station auxiliary loads individually in case of

unavailability of the second transformer. In case of emergency i.e. non availability of bus power,



station auxiliaries (including lighting etc.) shall be supplied through a Diesel Generator. Suitable

interlocking shall be provided in circuit breakers (ACB) connected to SST feeders, one bus

coupler and DG set feeder.

10.3.12 415 V Station Service Boards

Two nos. “Station Service Boards” for operation at 415V, 3 phase, 4wire, 50Hz supply shall be

provided. The SSBs shall comprise of 415 V, conventional air-insulated switchgears made of

vertical mounted cells that enclose draw-out type air circuit breakers. It shall consists Current

transformer, potential transformer, AC voltmeters, KWH meters, fuses etc. in the incomer feeder.

Outgoing feeders shall consist Moduled Case Circuit Breaker (MCCBs) & Motor Protection

Circuit Breaker (MPCBs) to supply unit & station auxiliaries. Both SSBs shall be interlocked, so

that any of the SST shall supply the other SSB in case of unavailability of power from the

corresponding SST.

For reliability & emergency requirement, One of the SSB will receive power from 1 No of 200

KVA DG set in case of unavailability of power from the SSTs. The Emergency DG set shall be

with AMF panel for automatic start of DG when the supply on the 415V from both SST fails. In

case of failure of supply from one of the SSTs, all the loads will automatically shifted to second

SST.

The DG set will be silent type with factory built enclosure and equipped with cold starting kit for

trouble free starting under low temperatures of the project site.

10.3.13 Power Supply during Construction

As there is no available Grid Supply in the vicinity of the project area, DG Power shall be used

during construction stage. Part of the same system shall be used during operation and

maintenance of the Power Station.

10.3.14 Telephone System

The public telephone system communication equipment will be provided for operation & control

of the project. During construction period walky talky system will be provided for communication

in the field and will be retained after construction. The communication systems will be powered

from the plant uninterrupted power system (UPS).

The communication with load dispatch / grid station as well as between different Generating

stations connected to the Line will be through OPGW system envisaged on 132 kV Line for

evacuation of power.

10.3.15 Lighting

For power plant lighting the following normal levels will be adopted for interior and exterior lights

as appropriate. While the majority of the luminaries will be 240 V AC powered while essential

lighting will be DC supplied from station Battery System. The essential lighting will be provided



only for strategic locations e.g. Control Room, exits etc. Lighting will be fed from two lighting

distribution boards namely Normal & Emergency Boards. 33% lamps will be connected to

emergency board:

Table-10.2 Location Illumination Level

Location Illumination Level

Machine hall & Service bay 300 lux

Control room and personnel spaces 500 lux

LT room 300 lux

Cable spreading areas 100 lux

Switchyard 50 lux

10.3.16 Cables and Raceway System

10.3.16.1 Basic Requirements for Cables

All cables and tests on them will meet the requirement of applicable IEC/IS standards. All cables

will be with copper conductor and will be suitable for underground and surface installation in wet

or dry locations as the application dictates. Cable construction will be non-flame propagating and

smoke retardant (FRLS) rodent proof for indoor installation. The cables sheath will be suitable

for operation in ambient temperature of -20 °C to 40 °C.

10.3.16.2 Low Voltage Power Cables, Control Cables & Instrumentation Cables

1100 Voltage grade cables with copper conductors with PVC/XLPE insulation will be provided

for 415 V and 240 V power circuits. Single or multiple conductor cables will be provided with

suitable outer sheath. However Control & Instrumentation cables will be PVC insulated. All

cables will be FRLS type and rodent proof suitable for operation in ambient temperature of -20

°C to 40 °C.

10.3.16.3 Cable Trays

Ladder-type hot dipped galvanized steel trays will be used for medium and low voltage power

and control cables. Solid vented trays will be used for low level signal cables. Different trays will

be used for cables with different voltages. If possible, different trays will be used for the control

of each turbine–Generator unit.

Outdoor routing will be made in trenches or overhead trays as required.

10.3.17 DC and UPS Systems

This section describes the design criteria and technical requirements for DC systems and the

uninterruptible power supply (UPS) system for control, instrumentation and critical loads in the



powerhouse and switchyard. The essential services will consist of a 220V DC system and an

inverted 240 V AC system.

10.3.17.1 Field Flashing, Communication, System Design Criteria

DC systems will be provided to supply uninterruptible power for control and protection systems,

instrumentation equipment and to power critical DC operated equipment. An uninterruptible AC

system will be provided to supply uninterrupted, transient free regulated AC power during all

normal and abnormal plant operating conditions to specific critical AC loads.

The DC and uninterruptible AC system will be required to operate and supply DC and AC loads

in a controlled plant environment. The systems will be required to operate continuously during

normal plant operation, transient plant conditions, start-up, shutdown and when the plant is out

of service for maintenance and overhaul.

The 220 V DC systems will consist of:

Two station battery bank.

Two battery chargers including one (1) spare

Two main distribution panel board (220V)

10.3.17.2 220 V DC Battery Bank

The station battery bank will be comprised of valve regulated lead acid cells of 4 hours backup.

Batteries will be stacked in free-standing racks in a back to back configuration. Approx. capacity

of battery bank would be 600AH.

10.3.17.3 Battery Chargers

Two chargers (boost cum float) will be provided. Each charger will be of 100% capacity. The

battery chargers will be rated to match the requirement of recharging the battery in 10 hours in

addition to meeting the continuous load requirement. Battery and load conditions will be

continually monitored to provide the proper charger output rate determined by the battery

system. As battery voltage reaches preset charger voltage, charging current will taper down to

the charge preserving rate. Each charger will have the following features:

AC input circuit breaker

DC output circuit breaker

DC voltmeter and ammeter

AC voltmeter

Float and equalize charge selection and adjustment

Equalize timer with adjustable setting

High/Low voltage DC alarm

AC power loss alarm

High voltage DC shutdown and alarm



10.3.17.4 220 V DC Switching and Metering Panel (SMP) & DCDB

The chargers will be linked to the battery and the distribution panels via a switching and

metering panel. The panel will consist of 220 V DC bus bars with feeder circuit from the battery

bank, outgoing feeders to the distribution boards and loads, and two incoming feeders from the

chargers. The branches will be protected by circuit breakers and the tie circuit breaker will be

mechanically interlocked with the two charger circuit breakers. It will be possible to operate the

system in various arrangements while ensuring that 220V DC is always available for the bus.

Also included in the SMP will be a low-voltage relay, voltmeter, ammeter and a ground fault

detector. The tie circuit breaker, charger circuit breaker would be motor operated.

10.3.17.5 Uninterruptible AC System (UPS)

A 16kVA, 230V, 50Hz, single phase AC UPS system along with its own dedicated batteries has

been envisaged to feed all AC loads requiring uninterruptible AC power. The capacity of

batteries will be sufficient to feed the connected load for more than two hours (continuously)

during power outages. The UPS will consist of the following components:

A DC to AC inverter with shielded isolating transformer.

Two static transfer switches connected in parallel (one for the inverter branch and one for the bypass branch).

One make before break manual transfer switch to enable transfer to the alternate AC source during maintenance.

A shielded isolation transformer with surge suppression and voltage stabilizer. This will be connected to the alternate source to provide stabilized supply during failure/maintenance of inverter.

Circuit breakers, as required.

A 240 V AC, single phase essential load distribution panel board.

Contacts for alarm in the control room.

10.3.18 132 kV Switchyard Equipment

The 132 kV sub-station will consist of a Bank of step up Power Transformers, Circuit Breaker,

Disconnect Switch, Current Transformer, LA, PT etc. The switchyard will be suitable for

receiving two 132 kV lines for handling of power. All insulators, clearances etc. will be based on

short duration power frequency withstand voltage of 275kVrms for one minute and impulse

withstand voltage of 650kVp. The higher values are selected considering the elevation of site.

It will comprise of a Bank of Step-up transformers cum outgoing line bay. The equipment for

132kV operating voltage will be of the following rating:



Highest System Voltage 145 kV

Power Frequency withstand voltage for one minute (Considering higher elevation of site)

275 kVrms

Impulse Withstand voltage (Considering Higher Elevation of site)

650 kVp

Rated Fault current (To be Confirmed at Design Stage) 40 kA for 3 sec.

Creepage distance considering site elevation 35 mm/kV

Brief particular of major equipments of 132 kV switchyard are as follows:

10.3.18.1 132kV SF6 Circuit Breaker:

The HV Circuit Breaker will be of SF6 type, motor charged spring operated, suitable for 3 phase

operation and mounted on galvanized support structure.

Table-10.3 Electrical characteristics

Type of construction SF6 , Outdoor type,

No. of Poles 3

Nominal System voltage 132 kV

Highest System voltage 145 kV

Rated Frequency 50 Hz

Rated Continuous current 3150 A

Rated operating duty 0 – 0.3 Sec- Co-3 Min CO

Rated short circuit breaking current 40 kA for 3 sec

Power frequency withstand voltage for one minute (Considering Higher Elevation of site)

275 kVrms

Impulse withstand voltage (Considering Higher Elevation of site)

650 kVp

10.3.18.2 132 kV Disconnector Switch With /Without Earth Switch

The disconnect switch will be triple pole, double break , three phase gang operated and outdoor

type, mounted on galvanized support structures. The disconnect switches will be motor operated

type and suitable for remote operation.




Type of Construction Upright mounting, Triple pole, double Break gang operated, Suitable for outdoor installation

No. of Poles 3

Nominal system voltage 132KV

Highest system voltage 145 KV

Rated frequency 50 Hz

Rated Continuous current 1600A


275 kVrms


650 kVp/

Through fault current 40kA for 3 sec

10.3.19 132 kV Current Transformers

The current transformer will be post type, single-phase, oil immersed, sealed and outdoor type,

mounted on galvanized support structures.


Type of construction Oil filled - outdoor type

No. of Poles/Phases 1

Nominal System Voltage 132 KV

Highest System voltage 145 KV



325 kVrms


750 kVp

10.3.20 132 kV Potential Transformer (PT)

The potential transformer will be post type, single-phase, oil insulated and outdoor type,

mounted on galvanized support structures.




Nominal system voltage 132 KV



No. of secondary winding 3


325 kVrms


750 kVp

Transformation Ratio 132 KV / 110 V/ 110V

3 3 3

Connection Star/ Star/Star/ Star

VA Burden 200VA

10.3.21 120 KV Lightning Arrester:

The lightning arrester will be metal oxide without gaps and station type, complete with leakage

current monitor, counter, galvanized support structure.


Nominal system voltage 132 KV


Rated frequency 50 Hz

Rated Arrester Voltage 120 KV

Continuous operating voltage 102 KV

Nominal discharge current 10 KA


325 kVrms


750 kVp

Further following miscellaneous items will be covered under switchyard:

Structure

Post Insulators

Insulator String

Earth wire

ACSR conductor etc.

10.3.22 Electrical Workshop Equipment

For local repair of equipment and proper maintenance of plant a workshop is required with

complete tools and tackles. Local technician and supervisor shall be able to carry out all the



minor repair and maintenance work of the plant. The workshop shall be equipped with: Electric

welding sets, gas welding and cutting sets, drill machines, grinders, hand tools and accessories

etc.

10.3.23 Layout Drawings

The arrangement of various Mechanical and Electrical equipment in powerhouse and switchyard

have been shown in the Drawings appended to the DPR:

1) P1335-EMD-4001 : Power house- Cross-section

2) P1335-EMD-4002 : Power house - Plan

3) P1335-ED-2001 : Single Line Diagram- Relaying & Metering

10.3.24 Establishment

The E & M Works of the project are proposed to be completed within 2.5 years time.

Accordingly, the provision of regular establishment required for execution of E & M works in this

time frame has been made in the estimate.

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 11-Power Evacuation


11. POWER EVACUATION

11.1 INTRODUCTION

The Bharmour I Hydro Electric Project (24 MW) is located in Chamba District of Himachal

Pradesh. The Project proposes an installation of three Nos. Francis Turbines and Generating

units of 8 MW capacity each. It is expected that bulk of the power generated at this Project

would be available in the Northern Region of India. This chapter details the power evacuation

arrangement from the Project to the nearest feasible injection point.

11.2 LOAD DEMAND

As per projections (including Ultra Mega Projects) for the year 2013-14 given by CEA in the

National Electricity Plan 2007, the Northern Region was to be power deficit region with a power

deficit of - 6890 MW during Winter Off Peak, - 11772 MW during Winter Peak, - 4368 MW during

Summer off Peak & - 5535 MW during Summer Peak conditions.

As per Annual Report 2012-13 of NRLDC there was a minimum deficit of 1093 MW in

September, 2012 and a maximum deficit of 4343 MW during January, 2013 (copy of relevant

abstract is enclosed as Annexxure-11.1). During Evening Peak hour this deficit was 3520 MW

on 10.09.2014 (Power Supply Position in Northern Region for 10.09.2014 as available on

NRLDC website and copy enclosed as Annexure-11.2).

Thus, the power deficiency in Northern Region still remains. The proposed Bharmour I HEP shall

partly meet the power deficiency in Northern Region.

Bharmour Hydro Projects Pvt. Ltd. intends to evacuate power from 24 MW Bharmour I HEP to

Northern Region by developing the associated transmission line & connect it to the nearby Grid

Substation of Central / State Utility for onward transmission to Northern Region. About 1200 MW

of power is planned to be generated from upcoming projects and evacuated from Ravi Basin,

Himachal Pradesh by development of suitable evacuation arrangement.

11.3 EXISTING & PROPOSED TRANSMISSION SYSTEM IN PROJECT VICINITY

There is an existing 400 kV S/C line from Chamera-II HEP (300 MW) to Chamera - I HEP (540

MW). Power from Chamera-I HEP is fed to Jallandhar (Punjab) through 400 kV D/C

Transmission Line. Further, Chamera-II HEP (300 MW) is connected to Kishenpur (J&K)

through 400 kV S/C Transmission Line.



CEA has made a Master Plan of Power Evacuation System for Ravi Basin (as per details

available in CEA website & enclosed as Annexure-11.3). As per this Master Plan, PGCIL has

constructed 400/220 kV Pooling station at Chamera (Chamba). Power from different Projects to

be established in Ravi Basin i.e., Kugti HEP (45 MW), Hadsar HEPs (60 MW), Bharmour HEPs

(45 MW), 70 MW Budhil HEP (already commissioned), Bara Bangahal HEP (92 + 108 MW),

Bajoli Holi HEP (180 MW), Kutehr HEP (240 MW), 231 MW Chamera-III HEP (already

commissioned), will be fed to 400/220kV Chamera (Chamba) Pooling Station (already

commissioned). Chamera pooling station is connected to Jallandhar (Punjab) and Kishenpur

(J&K). One more Pooling Station (400/220 kV) near Lahal is proposed to be constructed by

HPPTCL, located downstream of Budhil HEP. This 400/220 kV Pooling Station at Lahal will be

connected to 400/220 kV Chamera Pooling Station through 400 kV D/C Transmission Line as

shown in Master Plan prepared by CEA.

11.4 IDENTIFICATION OF TRANSMISSION SYSTEM

Kugti HEP (45 MW) falls in Dhauladhar Wild Life Sanctuary and its allotment has been kept in

abeyance by Government of Himachal Pradesh. Harsar I (32 MW), Harsar II (20 MW), Harsar III

(Chobia) (18 MW), Bharmour I (24 MW) & Bharmour II (21 MW) HEP’s are located downstream

of Kugti and upstream of Budhil HEP. These five projects are being developed as run of the river

projects on fast track. Accordingly, composite power evacuation scheme on 132 & 220 kV for

these HEP’s is proposed considering 15% overload and simultaneous operation of all Projects.

As per suggestion of CEA, double circuit line is recommended for medium and large projects.

Considering small capacities of Harsar & Bharmour HEPs and to optimise the project costs, 132

kV Double Circuit Ring Main Scheme & 220 kV Single Circuit Transmission Line System has

been proposed.

Composite Power Evacuation Scheme

132 kV D/C Harsar I HEP- 132/220 kV Bharmour Pooling Substation (near Budhil Dam)

Transmission Line (approx. 10.8 kM long) with ACSR PANTHER equivalent AL 59 Conductor

with LILO of one circuit at Harsar I, Harsar II, Harsar III, Bharmour I & Bharmour II HEPs has

been proposed.

Combined Power of Harsar I, Harsar II, Harsar III, Bharmour I & Bharmour II HEPs at 132/220 kV

Bharmour Pooling Substation (near Budhil Dam) shall be fed to 220 kV Chamera III substation

by constructing 220 kV S/C Transmission Line (Approx. Route Length 8 KM) from Bharmour

Pooling Station (near Budhil Dam) to an interconnecting point near Budhil Powerhouse and

thereafter by stringing of One Circuit with ACSR ZEBRA Conductor (Approx. Route Length 20



kM) on existing 220 kV Transmission Line from Budhil HEP to Chamera III HEP. From Chamera

III onwards this combined power shall be injected into Interstate System.

This proposed composite power evacuation arrangement for Harsar & Bharmour HEPs is shown

in Annexure-11.4.

Metering & Scheduling: Individual Metering at each Generating Station & Combined (revenue)

Metering at Chamera III. All interaction with Grid/Load dispatch and sending of data & status of

all units (present & future) to be ensured by Bharmour Pooling Substation including overall

control of all stations.

11.5 POWER EVACUATION FROM BHARMOUR-I HEP

The evacuation of power from Bharmour I HEP shall be through proposed composite 132 kV

Ring Main Scheme and proposed 132/220 kV Bharmour Pooling Substation to be constructed by

the developer which shall be connected to 220 kV Chamera III through already connected 220

kV S/C Budhiil to Chamera-IIITransmission Line (as described above). Cost estimates have

been prepared based for this composite power evacuation scheme & cost for power evacuation

from Bharmour I HEP shall be shared on prorata installed capacity (in MW) basis.

11.6 STATUS OF OPEN ACCESS/CONNECTIVITY

Open Access/ Connectivity shall be applied after clearance of DPR.



Annexure-11.1



Annexure-11.2



Annexure-11.3



Annexure-11.4

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 12-Construction Methodology and Schedules


12. CONSTRUCTION METHODOLOGY AND SCHEDULE

The project envisages construction of a Barrage, Intake, Undersluice, Feeder Channel, desilting

chambers, collection pool & intake, Head race tunnel, Surge Shaft, Pressure Shaft, Power

House, Tail race tunnel and all infrastructure works.

The construction methodology and equipment planning for various works is based on the site

conditions prevailing in the project area. Construction activities are planned in such a way that

the project shall be completed in the shortest possible time period. The following assumptions

have been made for construction methodology and equipment planning of the project.

All the pre-construction activities like land acquisition, infrastructure works and government

approvals are completed before the start of construction works on main components of the

project.

All civil, hydro-mechanical and electro-mechanical works are executed in following main

packages of contract:

CIVIL WORKS

Package I : Civil works of Barrage, Intake Structure, Feeder channel,

Desanding Basin and collection pool.

Package II : Civil works of Head Race Tunnel, Surge shaft and Pressure

Shaft

Package III Civil works of Power House, Switch Yard and Tail Race

Channel

HYDRO-MECHANICAL WORKS

Package IV : Hydro Mechanical works comprising of gates, hoists, erection &

fabrication of Pressure Shaft pipes.

Electro-Mechanical Works

Package V : Generating Units (Turbine & Generator), Cooling Water System,

Drainage/Dewatering System, UnitControl & Automation, Bus duct.,

Valves-MIV& BFV,EOT Crane, Air Conditioning,Ventilation etc. Fire

Fighting, Transformers (Generator Transformer), 6.6 kV Switchgear

Switchyard & Protection metering, Transformer (Dry Type UAT SST),

DC System (Battery & Battery Charger), UPS

Transmission Line Works

Package VI : Transmission line works



However, the actual tendering and contract packaging will be decided during project execution

phase.

12.1 BASIC ASSESSMENT OF CONSTRUCTION METHODOLOGY

The construction of the project will involve simultaneous works on all the packages for civil,

hydro-mechanical and electro-mechanical works for various project components. Tunnelling in

Head race Tunnel is the most critical activity for the project and accordingly, the work is assumed

to continue uninterrupted till its completion.

12.2 PRE CONSTRUCTION ACTIVITIES

The activities proposed to be undertaken during Pre-construction work include the following:

Detailed Topographical Survey and marking the Layout at site, Pre- construction geotechnical investigation

Clearance from Government agencies like Pollution control board, Public health, Irrigation and Forest Clearance

Acquisition of Land including muck disposal areas

Financial closure

Detailed design and preparation of tender documents for Civil, Electro-mechanical, Hydro mechanical works including pre construction investigation.

Award of Contracts

Setting up of Site office and store

Arranging of construction power

Construction of approach roads and bridges

Formation of project team

12.3 APPROACH ROADS

Transportation of heavy machines and equipments will be required for construction purpose.

Construction of new access roads and bridges, widening of existing roads and improvement in

grade of existing roads shall be undertaken before starting construction of main project

components. These roads would be connected through an extensive network of project roads to

various colonies, workshop, quarries etc.

12.4 BASIC CONSIDERATIONS

Construction methodology and equipment planning has been carried out separately for execution

of all project components. The types and sizes of equipment to be used have also been indicated

while describing the construction methodology for each of the components under relevant

subhead.



All construction work shall be executed through contractors. The requirement of equipment as

marked out herein has been utilized for analysis of rates and cost estimates. The cost of

construction equipment is based on the prevalent market prices in India as on August, 2014.

The project area is situated in a region where extensive rainfall occurs during monsoon. The

working season is, therefore, limited to 9 months, beginning from October to June for open

works. The underground works being critical are proposed to be carried out in three shifts of 20

hours/day.

12.5 DETAILED DESIGN AND CONSTRUCTION DRAWINGS

The detailed design will be done in parallel with the pre-construction works. It is envisaged that

the design will be started before the preliminary works are completed. During Tender

engineering, detailed design work will be started and construction drawings will be available by

the time contracts are awarded. The work for tender engineering is expected to be completed

within 3 months after the DPR is cleared by Government of Himachal Pradesh.

Award of work to contractors

After the completion of tender Engineering, bids shall be invited from civil, E&M and H&M

contractors for various project works. Bids are expected to be finalised in a period of about 5

months from the bid invitation date. Contract for civil and electro mechanical works shall be

awarded first and the contract for H&M works shall be awarded about 6 months later

12.6 BASIC ASSUMPTIONS FOR EQUIPMENT PLANNING

“Guidelines for preparation of Detailed Project Reports of River Valley and multipurpose

Projects” issued by Central water Commission have been used for the planning of equipment.

Basic assumptions made for the planning of equipment for various construction activities are

enumerated below:

12.6.1 Working hours of equipment

All works are proposed to be done in three shifts and the effective working hours have been

taken as 20 hours per day, 25 days/month.

12.6.2 Densities of Materials

The calculations have been based on capacity of hauling units without considering the densities

of different types of materials for excavation and the fill material.

12.6.3 Earth Volume conversion factor

Suitable standard norms have been adopted for conversion of volumes in natural, loose and

compacted state.



12.6.4 Operating Efficiency

The operating efficiency of different types of equipment has been taken as 50 min per hour.

12.6.5 Muck Dumping Lead

A lead of 1 km has been considered for dumping of muck that would be generated from

Headworks & Power House and a lead of 2 km is assumed for the dumping of muck that would

be generated from Head Race Tunnel and Surge Shaft.

12.7 CONSTRUCTION POWER

The maximum power required for constructions activities is estimated considering capacity of

electrically driven machines/equipment and requirement of lighting, varies during the construction

schedule and also depends on construction methodology.

It is assessed that about 1 MW of power would be required during peak construction period.

However, construction power requirements during the initial two years would be about 0.75 MW.

The power requirement would be met through nearest 33 KV/11 KV HPSEB lines but it is

planned to have dedicated DG sets at all fronts for uninterrupted power supply during non-

availability of power from the HPSEB grid.

12.8 METHODOLOGY OF CONSTRUCTION FOR VARIOUS CIVIL WORK ACTIVITIES

12.8.1 River diversion during construction

River diversion works has been planned for construction of Barrage and Intake. The construction

of Barrage has to be taken up during non monsoon months of relatively low flow. The river will

be diverted along one side of the river by construction of temporary cofferdams for the

construction of the upstream works. The cofferdam will be made of river bed material properly

compacted to the required level to prevent overtopping. An impervious material will be provided

to prevent seepage through the body of the dam. Rip rap protections will be provided on the

river side to prevent scouring of the dam. It is expected that the cofferdam will be damaged

during the monsoon season which will be repaired for the dry season.

The construction of Barrage structure will be done in two stages and cofferdam will be provided

accordingly. In the first stage, the river will be diverted towards the left bank. During the period,

construction work on the right bank will be done. The work includes construction of Spillway (2

bays), Undersluice, Intake, Feeder Channel, Desilting Chamber, Collection Pool, intake

structures and flood walls, upstream and downstream aprons and stilling basins. Likewise, the

remaining bays of spillway that are on the left bank will be constructed during the second phase.

During the period, the river will be diverted through the Undersluice and gated Spillway. The

cofferdam will create the dry space on the left bank during this period.



12.8.2 Cofferdam works

The deposits on the river bank shall be removed to have enough space for construction

activities. The deposit will be used for the river diversion work and for rip rap protection works.

The construction of cofferdam will be taken up parallel with the removal of deposits. The

construction of Coffer dam would be taken up with 1 number of Dozers (100 HP), 1 number of

Hydraulic Excavators of 1.0 cum bucket capacity, 1 number of Vibratory Roller and sufficient

number of 15/20 T Dumpers. The Coffer Dam is planned to be completed in one month.

12.8.3 Phase-I - Headworks

Construction of 2 bays of Spillway and Intake Structure will be taken up in the first phase of head

works. Total of 40,000 cum of earthwork is involved in these structures and by providing 1 Nos of

Hydraulic Excavator of 1.0 m3 capacity (with stand bye equipment) and fleet of dumpers, daily

progress of 600 m3 is expected. Therefore, the excavation gets completed in 3 months.

Adequate dewatering arrangements would be made during the excavation in foundation at

diversion structure. The excavation for cut-off wall will commence immediately after completion

of river bed excavation. The deep excavation for cut-off wall will be done with Hydraulic

Excavator. The excavation of cut-off wall up to the required level will be done and thereafter RCC

works will follow in the excavated trench. The concrete work for barrage base slab and other

superstructure works will commence immediately after the completion of cut-off wall. Concreting

in the river bed, pertaining to 2 bays of spillway and Intake and adjacent structures will be taken

up on priority in full swing by 1 nos. 20 m3 Batching plant and 1 Stationery 1 m3 Capacity Mixer,

placement of concrete is planned by Transit mixers and concrete pumps. The concreting of

under sluice, 2 bays of spillway and Intake up to sill level will be completed in 2 months before

onset of monsoon. The superstructure works of these structures will commence immediately

after the concreting of the base slab. The Hydro-Mechanical works for these structures will be

executed in parallel to the civil works of these components. All civil and hydro mechanical works

for these components will get completed in 23rd month after the start of work at Barrage site.

During planning it is assumed that all the structures on the right bank that will be affected by the

river flow will be completed in two seasons. After completing the First Phase works on the right

bank, the river will be diverted through under sluice and 2 bays of spillway and the construction

for Phase-II Barrage works will be taken up.

12.8.4 Phase-II - Headworks

Construction of left bank wing wall and remaining bays of Spillway will be taken up in this phase

of Barrage works. 25,000 cum of earthwork is involved in these structures and by providing 1

Nos. of Hydraulic Excavator of 1.0 cum capacity (with stand bye equipment) and fleet of

dumpers, daily progress of 600 m3 is expected. Therefore, the excavation gets completed in 2

months. Adequate dewatering arrangements would be made during the excavation in foundation

at Barrage complex. The excavation for cut-off wall will commence immediately after completion

of river bed excavation. The concrete work for this phase will commence immediately after the



completion of concrete in cut-off walls. Concreting in the river bed, pertaining to remaining bays

of spillway will be taken up after necessary excavation. The concreting of remaining bays of

spillway up to sill level will be completed in 2 months. The superstructure work of this structure

will commence immediately after the concreting of the base slab. All civil works for these

components will get completed in 34 months.

12.8.5 Feeder Channel, Desilting Basin and Collection Pool

The structures like Desilting Basin and Feeder channel can be constructed throughout the year.

The excavation of the Desilting Basin will commence after the completion of flood wall beside the

Desilting Basin. Work at collection pool just downstream of Desilting Basin would be taken up

simultaneously with the Desilting Basin. Excavation and backfilling at Desilting Basin, Collection

Pool and Feeder Channel would be taken up with 1 Nos. of Hydraulic excavator of 1.0 cum

bucket capacity and sufficient nos of 15/20 T Dumpers. Therefore, total earthwork of 25,000 cum

involved in these structures is planned to be completed in 1.5 months. Adequate dewatering

arrangements would be made during the excavation at these fronts. The concrete work will

commence immediately after the completion of excavation/backfilling work at these fronts.

Concreting of the structures will be taken up on priority in full swing by 1 nos. 20 m3 Batching

plant and 1 Stationery 1 m3 Capacity Mixer, placement of concrete is planned by Transit mixers

and concrete pumps. The superstructure civil works for these structures will be carriedout in

parallel to hydro mechanical works. All civil and hydro mechanical works for these components

will get completed in 30th month after the start of work at these fronts.

Equipments required for the construction of Coffer Dam, Spillway, Under Sluice, Intake, Feeder

Channel, Desilting Chambers and Collection Pool are shown in Annexure-12.2.

12.8.6 Headrace tunnel

3.6 m (W) x 3.6 m (H) D shaped, 2.5 km long Head Race Tunnel has been proposed at the end

of Collection pool for carrying water to the pressure shaft. 200 mm thick concrete lining has been

proposed all along the length of the tunnel.



88 m

Face‐1 Face‐2 Face‐3 Face‐4 Face‐5

Adit‐1 Adit‐2

862 m 1550 m

HRT Layout

Adit‐3

Fig - 12.1

The headrace tunnel will be started from the five faces as shown in Fig-12.1. All the adits shall be

completed before the start of excavation of headrace tunnel. Construction of HRT Face-1 and

Face-2 will be taken up from Adit-1 to HRT. Similarly Face-3/Face-4 & Face-5 will be taken up

from Adit-2 and Adit-3 respectively. The critical reach of HRT is about 1550 m between Face-4

and Face-5, so special attention in terms of resources is required at this front for completion of

work in time schedule.

The tunnel will be excavated by conventional drill and blast method using mechanised

equipment. The drilling for headrace tunnel is proposed to be carried out by using single boom

hydraulic drilling jumbo. In order to limit extra overbreaks, profile of tunnel will be marked after

each cycle and periphery drilling will be carried out. The mucking operation will be carried out by

using 0.75 cum side dump loader and 10T capacity dumpers. Adequate number of dumpers will

be provided to cater for lead involved for mucking.

The excavation of tunnel will be carried out in following operations:

SURVEY AND MARKING OF PROFILE DRILLING

Drilling will be done by using single-boom hydraulic drilling jumbo, which can theoretically drill up

to 50m/hr. This progress can however be achieved under ideal conditions and continuous drilling

operations. Since the drilling is to be carried out for large number of holes of limited depth, each

time the location of boom will have to be changed which takes lot of time. As such, practically a

progress of not more than 50m of drilling can be achieved in one hour with the help of single

boom. Periphery holes at 500mm c/c will be provided to minimize over excavation of rock and to

maintain correct profile. The periphery holes will be charged only to an extent of 25%.



CHARGING AND BLASTING

The holes drilled will be loaded by power-gel or equivalent. Non-electric detonators with

millisecond delay are proposed to be used. Non-electric detonators will enable to carry out

charging and drilling in simultaneous operations. After loading of explosive of the entire face is

completed, the equipment and personnel will be withdrawn and blasting will be done.

DEFUMING

Adequate ventilation is essential during excavation of tunnel. The tunnel, during excavation, will

be provided with one exhaust fan with a ventilation duct of 1.0 m diameter. The ventilation

system will not be required once the tunnel excavation has been completed.

SCALING

After excavation of the face, scaling of roof and sides will be carried out. All loose rock fragments

shall be removed during scaling operation. Local drilling and blasting will be done, if required, to

remove any undercut.

MUCKING

In fair to good rock conditions, mucking operations shall be carried out immediately after scaling

of face whereas in poor rock conditions a layer of shotcrete shall be provided first to avoid any

loose rock from falling, and mucking shall be carried out thereafter.

ROCK SUPPORT MEASURES

Shotcreting shall be carried out upto excavated face after each blast whereas rock bolting shall

be provided about 2 pulls behind the excavated face. Both the operations, however, are to be

carried out after each blast. The excavated tunnel will be supported by steel ribs in the reaches

which are geologically weak. The excavated muck will be loaded through one 0.75 cum side

dump loader and transported by dump trucks of 15 T capacity to muck dumping area. After

excavation scaling will be done followed by the rock bolting and shotcreting. Pre-splitting or

smooth blasting technique shall also be adopted to avoid over break.

The proposed cycle time for the excavation and rock support of HRT along with equipment

planning is enclosed as Annexure-12.1.

TUNNEL LINING

The concrete lining of HRT is proposed to be done in two stages i.e. firstly overt section and

thereafter invert portion. The concrete lining of the tunnel shall be done by using 8 m long shutter

formwork. Transit mixer of 4 cum capacity will be used for transportation of concrete from

batching plant to concreting site. Pouring of concrete in the tunnel gantry will be done through by

using 20 cum concrete pump.

CONTACT GROUTING

Contact grouting in the tunnel is proposed to be carried out after concrete lining of tunnel.

Contact grouting is provided to fill any gap between rock and concrete lining, especially at crown

level, which has been left during concreting activity. For this purpose grout holes of 38 mm

diameter will be drilled 500 mm inside the rock and grouting will be done at a low pressure of



about 2 to 2.5 kg/cm2. The grouting will be carried out till refusal. Grout pumps will be utilized to

carry out the grouting operations. The grouting operations will be finished two months after the

concrete lining of tunnel is over.

CONSOLIDATING GROUTING

Consolidation grouting shall be done at locations having poor geology, as decided by the

Engineer-in-Charge. The length of drill hole for consolidation grouting in general shall be 3.5 m

deep in to the rock. Consolidation grouting would be carried out through these holes at a

pressure ranging from 5 to 7 kg/cm2. The grouting in this case is also to be carried out till refusal.

Grouting shall be done using grout pumps.

CLEANING OF HRT

After completion of all activities the tunnel will be thoroughly inspected for any foreign material

left inside during construction. This will ensure that no damage is caused to the machines in case

the undesirable objects find their way to powerhouse through the tunnel. The cleaning operation

will be carried out simultaneously when operations to plug the adits are in progress.

PLUGGING OF ADITS

Once the grouting operations in the tunnel as well as all other activities in adjacent components,

i.e. surge shaft and intake are completed, the adits will be plugged with concrete. For this

purpose, adequate number of shear keys will be provided. To fill any gap between rock and

concrete plug, consolidation grouting will be carried out after plugging operations have been

completed.

Equipment required for the construction of Head Race Tunnel is shown in Annexure-12.2.

12.8.7 Surge shaft

Construction of approach roads to Surge Shaft top and Adit-3 is planned to be completed during

pre-construction works. The construction of Adit-3 would be taken up immediately after the start

of Civil works so that construction of HRT Face-5 can be taken up from this side. The excavation

and rock support of Adit-3 is planned to be completed in 6th month of main package works.

The construction of surge shaft involves following activities:

Open excavation

Shaft excavation and installation of ground support

Concrete lining and grouting works

The excavation operations of surge shaft will be carried out by conventional method using top

down approach and concreting operations will be done from bottom to top. The location of surge

shaft has been so planned that sufficient cover is available on all sides of surge shaft. Sufficient

space has also been ensured for working of a gantry crane at top to facilitate mucking and

supply of concrete for concreting operations.

Open excavation



The excavation for the working platform at surge shaft top would be started from the top level in

stages of 2 to 3 m depth. An independent road has been provided to surge shaft top for carrying

out this activity. The overburden would mostly be removed without blasting while some rock

excavation would be required to reach the platform. As the benching operations progress

downwards, the rock so exposed during excavation would be provided a protective coat of

shotcrete and rock bolting would be done to prevent sliding and weathering. The activity of

protection of slopes would be carried out concurrently.

Shaft excavation and installation of ground support

The drilling equipment will be descended into the shaft using EOT crane erected at the top of

shaft and after completing the drilling the same will be ascended to the top of shaft. Similarly

equipments required for rock support and mucking (mucking buckets of 1-2 cum) will be

descended and ascended in the shaft for the respective operations.

Drilling and blasting would be done for 0.5m depth in one cycle with the help of Jack Hammers

and 500 cfm compressor. For achieving a progress of 0.5m per cycle, drilling would be done up

to 0.75m deep.

After excavation is completed, concreting of the surge shaft will be undertaken. It will be carried

out from bottom to top. The concreting of surge shaft is proposed to be carried out by deploying

a slip form shutter. A period of about two months would be required for casting of ring beam,

installation of slip form and beginning reinforcement erection. The concreting would be done in

lifts of 1.5 m height. A setting time of 24 hours would be given before the slip form is moved up

for next pour. Concrete for surge shaft will be available from batching plant (BM) and

transportation of concrete from BM plant shall be done by 4cum capacity transit mixer. Concrete

pump of 20cum/hr capacity will be used for concrete placement and needle vibrators for vibration

of concrete.

Equipment required for the construction of Surge Shaft is shown as Annexure-12.2

12.8.8 Pressure Shaft

2.8 m dia circular steel lined pressure shaft trifurcating into unit penstocks of 1.65 m dia has been

provided for taking the water to three Francis machines in surface power house. Main Pressure

shaft is approximately 125 m in length before ending up at trifurcation point from where the three

unit penstock starts. The excavation of horizontal underground pressure shaft is planned to be

taken up from Adit-3 side using single -boom drill jumbo, 0.75 cum side dump loader and fleet of

dump trucks. The methodology for excavation of pressure shaft shall be similar to that adopted in

Head Race Tunnel. The erection of steel liner and concrete backfill shall commence once the

excavation of pressure shaft is through. The erection of liner is planned to be done from surge

shaft side to Adit-3. Once the erection of steel liner and backfilling in pressure shaft gets

complete, the plugging of Adit-3 shall be taken up such that all works get complete before the

commissioning of project. Similar methodology is planned to be adopted for the construction of



bottom horizontal limb of pressure shaft near to power house. The construction of bottom

horizontal limb of pressure shaft is planned to be done from Adit-4.

12.8.8.1 Vertical Pressure Shaft

The construction of 2.80 m diameter vertical shaft is planned to be done from Adit- 3 by

conventional method using top down approach and erection of steel liner operations will be done

from bottom to top. Similar methodology as adopted for the surge shaft is planned to be used for

the construction of vertical pressure shaft. The drilling equipment will be descended into the shaft

using electrically operated winch erected at the top of shaft and after completing the drilling the

same will be ascended to the top of shaft. Similarly equipments required for rock support and

mucking (mucking buckets of 1-2 cum) will be descended and ascended in the shaft for the

respective operations.

Drilling and blasting would be done for 0.5m depth in one cycle with the help of Jack Hammers

and 500 cfm compressor. For achieving a progress of 0.5m per cycle, drilling would be done up

to 0.75m deep.

After excavation is completed, erection of steel liner in pressure shaft will be undertaken. It will

be carried out from bottom to top. The erection of steel liner in shaft is proposed to be done by

using power winches installed at both the ends of vertical pressure shaft. After erection of steel

ferrules concrete backfilling behind the liner shall be done using batching plant (BM) and

transportation of concrete from BM plant shall be done by 4cum capacity transit mixer. Concrete

pump of 20cum/hr capacity will be used for concrete placement and needle vibrators for vibration

of concrete

The fabrication of pressure shaft ferrules shall be done in 2 m length in mechanical workshop at

site. The rolling of steel plates to desired diameter ferrule shall be done using rolling machine

which will be followed by longitudinal welding along the length of ferrule. The fabrication of

required number of 2 m length ferrules for entire pressure shaft length will be started as soon as

the contractor gets mobilized at site. The fabrication of pressure shaft ferrules will be followed by

sand blasting and painting and further their stacking in the stock yard.

The fabricated ferrules from workshop will be transported on trucks to the Adit-3 from where they

will be shifted and lowered to the bottom of the vertical shaft by using power winches installed

one each at top and bottom of the shaft. The power driven winches shall be used for pulling of

ferrules on rail tracks from top to down. The entire pressure shaft will be encased with backfill

concrete. The construction equipments required for the construction of Penstock and specials

are annexed as Annexure-12.2.

12.8.9 Powerhouse

A surface Power House has been proposed on the right bank of Budhil River with the installed

capacity of 24 MW comprising 3 units of 8 MW each. Open excavation of 45,000 cum is

assessed in Power House complex and is expected to be completed in 4 months with three



shifts operating. The completion of excavation in power house shall be followed by laying of

earth mat, first stage concrete, erection of draft tube, second stage concrete and erection of

columns and beams in power house building. The erection and commissioning of EOT crane in

power house shall be done once the columns and beams in power house building is complete.

After the erection and commissioning of EOT crane all E&M works are planned to be executed in

co-ordination with civil works. The civil works of control room building are planned to be done in

parallel to other activities in power house complex. Sufficient resources shall be deployed at

power house complex so that both the units get erected before the completion of HRT works of

the project.

Equipment required for the construction of Power House is shown in Annexure-12.2.

12.8.10 Tailrace

After passing through the turbines, water shall be led back smoothly to Budhil River via a short

tailrace. The excavation of Tail Race channel is planned to be done with power house

excavation. The concrete works of tailrace is planned to be done with concrete works in power

house foundation. As the quantum of work involved in tail race channel is less therefore the

raising of this structure is planned to go by power house works progress. The equipments

deployed at power house is planned to be used in tail race channel. Draft tube and tail race end

gate for the tailrace shall be erected simultaneously with the construction of the powerhouse.

12.8.11 Switchyard

The quantum of work involved in Switch Yard is less therefore work on this front can be deferred

with the start of work on other components of the project. The equipments deployed at power

house is planned to be used in switch yard works. Concrete/Building works will immediately

commence after the completion of necessary excavation/muck filling and foundation treatment

works. The completion however, should be finished before the completion of installation of

electromechanical equipment in the powerhouse.

12.8.12 Hydro Mechanical Equipment

The fabrication of Barrage, Undersluice, Intake structure, desilting chamber, Tail Race gates

shall be done partly in manufacturer’s workshop and partly at site. The civil contractors will co-

ordinate with the agencies supplying such equipment and provide them all necessary support at

site. Block outs and first stage anchor plates shall be provided in various structures during first

stage concreting. The second stage embedded parts comprising of sill beams, tracks, seal seats

& guides etc. shall be erected in these block outs before undertaking second stage concreting.

The supply and installation of all Hydro mechanical equipment required at different locations

shall be ensured to be completed in time so that the works related to component



12.9 CONSTRUCTION SCHEDULE

12.9.1 General

A critical path method has been adopted in preparing the Construction Schedule of the

Bharmour-1 Hydro Electric Project, which is shown as Annexure-12.3 of this Chapter. This

construction schedule is developed using a computer software package “Microsoft Project

Planner”.

The construction schedule for the Bharmour-1 HEP is based on a period of 36 months,

beginning from the effective date of civil works contract up to the end of commissioning of all

three units. The main civil construction works are, however, expected to start beginning January

2016 and are scheduled to complete within the period of 36 months i.e. December 2018.

The attached construction schedule refers to the main activities of each individual component

and indicates its interrelationship and dependency with the activities of other component. The

planning unit for the time of construction is considered as days on the basis of 24 hours working

per day. Every Sunday is deemed to be weekend and has been considered as a workday off.

Due to the nature of hydrology, the full phase construction is affected during the monsoon

season i.e. July, August and September when the river discharge gets high, making it impossible

to work at the areas below the flood level. This effect has been taken into account in preparing

the schedule by introducing 2 different calendars. Calendar no 1 reflects no effect of monsoon

and is assigned to construction activities such as headrace tunnel works, electromechanical

works etc., which are not at all affected by floods and rains. Calendar nos. 2 is specially assigned

to surface works activities, which are basically on the course of the river such as headworks

activities. Calendar no. 1 considers the effect of monsoon from the start of July until the end of

September. Three months (July, August and September) are considered as partially non working

months (50% productivity). This calendar is particularly assigned to headworks, surge shaft and

power house activities.

12.9.2 Construction Adits

Bharmour-1 HEP is facilitated with four Adit tunnels, which require about 300 m of underground

excavation. Adit 1 is located at RD-88 m of head race tunnel, which shall be used for the

construction of Face-1 & Face-2 of HRT. The 115 m length, Adit 2 is located at RD-950 m of the

headrace tunnel. It will be used for the excavation and concrete lining of headrace tunnel in

Face-3 & Face-4. Adit-3 is located at the downstream end of the surge shaft and shall be used

mainly for the excavation & concrete lining of HRT Face-5, concrete lining of surge shaft and

excavation & erection of steel liner in vertical pressure shaft.

The construction of all Adits is expected to commence in March 2016. Based on the excavated

lengths of Adits, the completion time differs from one another. However, the successive activity

(the headrace tunnel excavation) shall follow immediately after the completion of the individual

Adit excavation.



12.9.3 River Diversion during Construction

In order to ensure the construction work in the river (headworks), it is necessary to divert the river

by changing its original course to the new defined channel. Therefore, a proper planning is

required in diverting the river without much affecting the main construction sequence.

River diversion works has been planned for construction of Barrage and Intake. The construction

of Barrage has to be taken up during non monsoon months of relatively low flow. The river will

be diverted along one side of the river by construction of temporary cofferdams for the

construction of the upstream works. The cofferdam will be made of river bed material properly

compacted to the required level to prevent overtopping. An impervious layer will be provided to

prevent seepage through the body of the dam.

The construction of Barrage structure will be done in two stages and cofferdam will be provided

accordingly. In the first stage, the river will be diverted towards the left bank. During the period,

construction work on the right bank will be done. The work includes construction of 2 bays of

spillway, Undersluice, Intake, Feeder Channel, Desilting Chamber, Collection Pool, intake

structures and flood walls, upstream and downstream aprons and stilling basins. Likewise, the

remaining bays of spillway on the left bank will be constructed during the second phase. During

the period, the river will be diverted through the2 bays of spillway and Undersluice. The

cofferdam will create the dry space on the left bank during this period.

12.9.4 Phase-I - Headworks

Construction of 2 bays of spillway, Undersluice and Intake will be taken up in the first phase of

head works. The construction for phase-1 works shall be taken up immediately after the

mobilization of contractor at site. The excavation for phase-1 works is planned to be completed in

3 months time and it will be followed by foundation concrete and thereafter superstructure works

of spillway, undersluice and headworks. The concrete and upstream & downstream protection

works of phase-1 works are planned to be completed by 24th month of main package works. The

hydro mechanical works involved shall start after completion of concrete work and all phase-1

works are planned to be completed by 23rd month of construction period.

During planning it is assumed that all the structures on the right bank that will be affected by the

river flow will be completed in two seasons. After completing the First Phase works on the right

bank, the river will be diverted through 2 bays of spillway & under sluice and the construction for

Phase-II Barrage works will be taken up.

12.9.5 Phase-II - Headworks

Construction of left bank wing wall and remaining bays of spillway will be taken up in this phase

of head works. The excavation for phase-2 works is planned to be competed in 1.5 months time

and it will be followed by foundation concrete and thereafter superstructure works of Barrage.

The concrete and upstream & downstream protection works of phase-2 works are planned to be

complete by 35th month of main package works.



12.9.6 Feeder Channel, Desilting Basin and Collection Pool

The structures like Desilting Basin and Feeder channel can be constructed throughout the year.

The excavation of the Desilting Basin will commence after the completion of flood wall beside the

Desilting Basin. Work at collection pool just downstream of Desilting Basin would be taken up

simultaneously along with the Desilting Basin. The construction of these components shall be

taken up immediately after the mobilization of contractor at site. The excavation work is planned

to be competed in 1.5 months time and it will be followed by foundation concrete and thereafter

superstructure works of Feeder Channel, Desilting Basin and Collection Pool. The concrete and

associated protection works for these structures are planned to be completed by 30th month of

main package works. The superstructure civil works for these structures will be carried in parallel

to hydro mechanical works. All civil and hydro mechanical works for these components will get

completed in 30th month after the start of work at these fronts.

12.9.7 Headrace Tunnel

The headrace tunnel will be started from the five faces as shown in Fig-12.1. All the adits shall be

completed before the start of excavation of headrace tunnel. Construction of HRT Face-1 and

Face-2 will be taken up from Adit-1 to HRT. Similarly Face-3/Face-4 and Face-5 will be taken up

from Adit-2 and Adit-3 respectively. The critical reach of HRT is about 1550 m between Face-4

and Face-5, so special attention in terms of resources is required at this front for completion of

work in time schedule. The excavation & rock support in Face-4 & Face-5 are planned to start

and finish in the 6th and 18th month respectively of main works and this shall be followed by

concrete lining, grouting and plugging of adit works in the tunnel. The HRT works of the project

are planned to be completed by the end of 33rd month of main package works.

12.9.8 Surge Shaft

The excavation and slope stabilization at the surge shaft top are planned to be completed in 3

months time. The excavation operations of surge shaft will be carried out by conventional drill

and blast method using top down approach, and concreting operations will be done from bottom

to top. The excavation of the shaft is planned to be completed by the end of 17th month of

construction period. Concrete lining of surge shaft shall commence from bottom to top using slip

form shutter and other miscellaneous & finishing works are planned to be done in parallel to

concrete lining works. The surge shaft works are planned to be completed by 28th month of

construction period.

12.9.9 Presure Shaft

The excavation of top horizontal & vertical pressure shaft is planned to be taken up from Adit-3.

The excavation and rock support in horizontal pressure shaft is planned to be completed by the

7th month. The erection of steel liner and concrete backfill shall commence once the excavation

of vertical pressure shaft is completed. The erection of liner in vertical shaft is planned to be done

from bottom to top from Adit-3. Once the erection of steel liner and backfilling in pressure shaft



and concrete lining of HRT Face-5 gets complete, the plugging of Adit-3 shall be taken up such

that all works get completed by the 34th month of construction period.

12.9.10 Powerhouse complex and Tail Race Channel

The excavation work on power house complex is planned to start during lean season.

Construction activities are planned to move simultaneously on Power House building, Tail race

Channel, Switchyard and Transmission Line. The required excavation in power house is planned

to be completed by the 11th month of construction period. The completion of excavation in power

house shall be followed by laying of earth mat, first stage concrete, erection of draft tube, second

stage concrete and erection of columns and beams in power house building. The erection and

commissioning of EOT crane in power house shall be done once the columns and beams in

power house building is complete. The erection and testing of EOT crane in the power house is

planned to be completed by 21st month of the construction period. After the erection and

commissioning of EOT crane, all E&M works are planned to be executed in co-ordination with

civil works. The civil works of control room building are planned to be done in parallel to other

activities in power house complex. Sufficient resources shall be deployed at power house

complex so that all three units get erected before the completion of HRT works of the project.

The power house complex activities are planned to be completed by the 34th month of main

package works.

12.9.11 Hydro Mechanical Works

12.9.11.1 Gates for various components

The fabrication of gates shall be done partly at the manufacturer’s workshop and partly at site.

The civil contractors will co-ordinate with the HM contractors and provide all necessary support at

site. Block outs and first-stage embedment for the gates shall be provided along with the first-

stage concreting for the structure, leaving the blockouts for 2nd stage embedment. The provision

of 2nd stage embedment comprising of sill beams, tracks, seal seats & guides etc. shall be

carried out along with other civil engineering works. After laying the embedded parts, the 2nd

stage concreting will be carried out. The total work including 2nd stage concreting, installation

and testing of the gates shall be carried out as per technical specifications and relevant BIS

codes in another 15 days period.

The supply and installation of all Hydro mechanical equipment required at different locations

shall be such that all other related works can be completed in scheduled time.

12.9.12 E&M Works

The E&M works in Power House will be taken up in parallel to civil works after the erection of

EOT cranes. The civil contractors will co-ordinate with the EM contractors and provide them all

necessary support at site. Block outs and first-stage embedment shall be provided in various

structures during first-stage concreting. The supply and installation of all EM equipment required



at different fronts shall be such that all other related to be completed in time so that the Power

House works can be completed in scheduled time.



ANNEXURE-12.1

Head Race Tunnel Excavation

Type of Rock

CL II CL III CL IV

A CL IV B CL V

Finished Diameter of HRT m = 3.60 3.60 3.60 3.60 3.60 Linning Thickness m = 0.20 0.20 0.20 0.20 0.20

Payline Thickness m = 0.10 0.10 0.10 0.10 0.10

Shotcrete Thickness m = 0.05 0.05 0.10 0.10 0.10

Steel Rib Thickness m = 0.00 0.00 0.00 0.15 0.20

Excavated Diameter of HRT m = 4.30 4.30 4.40 4.70 4.80

Maximum Working Hours assumed in 24hrs in 3 shift allowing 2hrs for shift change

hrs = 20.00 20.00 20.00 20.00 20.00

Progress per cycle m = 3.00 3.00 2.50 1.50 1.00 i) Drilling and Blasting

Depth of holes to be drilled m = 3.25 3.25 2.75 1.75 1.25

Cross sectional area of Tunnel m2 = 16.50 16.50 17.28 19.72 20.56

Spacing of the holes m = 0.85 0.85 0.85 0.85 0.85

Assuming spacing of holes @0.85m c/c m2 = 0.72 0.72 0.72 0.72 0.72

No. of holes required per face nos. = 23 23 24 28 29

Spacing of the holes m = 0.5 0.5 0.5 0.5 0.5

Heading Perimeter m = 12 12 12 12 12

Additional hole for line drilling / burn hole nos. = 24 24 24 24 24

Total no. of holes nos. = 47 47 48 52 53

Total depth of drilling m = 152.75 152.75 132 91 66.25

Output of Single Boom Drill Jumbo m/hr = 50.00 50.00 50.00 50.00 50.00 1 boom drill jumbo no. = 1 1 1 1 1

Profile Marking & Setting of Operation hr = 0.50 0.50 0.50 0.50 0.50

Drilling Time hr = 3.06 3.06 2.64 1.82 1.33

Charging and blasting hr = 1.00 1.00 1.00 1.00 1.00

Defuming hr = 1.00 1.00 1.00 1.00 1.00

Scaling and cleaning hr = 1.00 1.00 1.00 1.00 1.00

Total time for drilling and blasting hr = 6.56 6.56 6.14 5.32 4.83

ii) Mucking Quantity of muck (bank) cum = 49.51 49.51 43.20 29.57 20.56

Output of 0.75 cum Side dump loader (loose)

cum/hr = 50.00 50.00 50.00 50.00 50.00

Loose density of excavated muck T/m3 = 1.569 1.569 1.569 1.569 1.569

Capacity of Dumper T = 10.00 10.00 10.00 10.00 10.00

Capacity of Dumper cum = 6.37 6.37 6.37 6.37 6.37

Swell factor = 0.63 0.63 0.63 0.63 0.63



Total Loose muck per pull cum = 78.58 78.58 68.57 46.94 32.64

Mucking hours required hr = 1.57 1.57 1.37 0.94 0.65

iii) Cycle Time

Drilling and Blasting hr = 6.56 6.56 6.14 5.32 4.83

Mucking time hr = 1.57 1.57 1.37 0.94 0.65

Time for rock bolt and shotcrete hr = 6.00 6.00 6.00 - -

Erection of steel ribs, lagging and backfilling hr = - - - 8.00 8.00

Forepoling & grouting hr = - - - - 4.00

Total time required hr = 14.13 14.13 13.51 14.26 17.48

No. of cycle nos. = 1.42 1.42 1.48 1.40 1.14

Total progress per month of 25 days m = 106.18 106.18 92.51 52.60 28.61

Percentage of Rock Classification = 7% 68% 10% 10% 5%

Average Cycle Time per 1m Pull hr = 5.90

Cycle Time for 3.5m Pull hr = 17.69

Average progress per month m = 84.79

Say m = 65.00 iv) Requirement of Dumpers

Capacity of Dumper T = 10.00

Loose density of excavated muck T/m3 = 1.569

Capacity of Dumper cum = 6.37

Output of 0.75 cum Side dump loader (loose)

cum/hr = 50.00

Average Lead km = 2.00 Loading Time min = 7.65

Spotting Time min = 0.50

Turning and Dumping Time min = 2.00

Empty Haul @20 km/hr min = 6.00

Loading Haul @15 km/hr min = 8.00

Total cycle time min = 24.15

No. of Trips per working hour 50 minutes nos. = 2.07

Output of Dumpers per 50 minutes cum = 13.20

Total nos. of Dumpers required nos. = 4.00

Overt Concreting

Type of Rock

CL II CL III CL IV

A CL IV B CL V

Concreting area per m length m2 = 2.50 2.50 3.00 3.00 3.00

Percentage of Rock Classification = 7% 68% 10% 10% 5%

Equivalent Concreting area per m length 2.63

Length of shutter m = 8.00

Quantity of concrete required m3 = 21.00

Concrete Pump Capacity m3/hr = 20.00



Average efficiency = 70.00%

Placement rate of concrete m3/hr = 14.00

i) Cycle time of concreting

Releasing gantry from earlier block, cleaning and oiling and shifting to next block

hr = 6.00

Setting to desired line and location and checking

hr = 6.00

Bulkhead erection hr = 2.00

Concrete placement @ 14m3/hr hr = 1.50

Setting time for concrete hr = 24.00

Total Time for One Cycle hr = 39.50

Say hr = 48.00

Progress per month of 25days of One Shutter

m = 100.00

Progress per month of 25days of Two Shutter

m = 200.00

Invert Concreting

i) Cycle time of concreting

Invert cleaing hr = 5.00

Concrete time hr = 6.00

Layout, Fixing of screeds and manual finishing

hr = 4.00

Total Time for One Cycle hr = 15.00

Length of one cycle m = 20.00

Progress per month of 25days m = 666.67

Say m = 500.00

Requirement of 4 Cum Transit Mixer for one 20 cum/hr Concreting Pump

Capacity of Concreting pump Cum/hr = 20.00

Average efficiency of Concreting Pump = 70.00%

Output of concrete pump @80% efficiency Cum/hr = 14.00

Batching & Mixing Plant Capacity Cum/hr = 20.00

Average efficiency of B&M Plant = 70.00%

Output of B&M Plant @ 70% efficiency Cum/hr = 14.00

Capacity of Transit Mixer Cum/hr = 4.00

Average efficiency of Transit Mixer = 80.00%

Output of Transit Mixer @80% efficiency Cum/hr = 3.20

Time per working hour min = 50.00

Average Lead Distance km = 3.00

Loading min = 13.71

Spotting time min = 1.50

Turning min = 2.00



Unloading min = 13.71

Empty haul @ 20km/hr min = 9.00

Loading haul @ 15km/hr min = 12.00

Total Cycle Time min = 51.93

No. of Trips / working Hour nos. = 0.96

Output / working hour cum = 3.08

No. of Transit Mixers Required nos. = 5.00



ANNEXURE-12.2 Equipment deployment sheet

S.No. Equipment Capacity

Weir, Intake, Desilting Chamber,

Collection Pool and Intake Structure

HRT Face-1&2 HRT Face-

3&4 Pressure

Shaft/HRT Face-5 Surge Shaft

Power House

Complex Total

Quantity (Nos) Quantity (Nos) Quantity

(Nos) Quantity (Nos)

Quantity (Nos)

Quantity (Nos)

1 Single Boom Drill Jumbo 1- Boom 1 1 1 3

2 Side Dump Loader (0.75 cum) 0.75 m³ 1 1 1 3

3 Excavators (1.0m³) 1.0 m³ 1 1 1 1 1 1 6

4 Excavator cum Loader (0.7m³) 0.7 m³ 1 1 1 1 4

5 Vibratory Compactor (10T) 10 T 1 1

6 Dump Truck 15T/20T 20T/15T 5 5 5 5 5 25

7 Dump Truck 10T 10 T 3 3 2 8

8 Tippers 8T 8 T 3 3 6

9 Crawler Dozer 100HP 100 HP 2 2 4

10 Air Compressor 500 cfm 500 cfm 2 2 2 1 2 2 11

11 Air Track Wagon Drill 500cfm 500 cfm 1 1 1 3

12 Jack Hammer 120cfm 120 cfm As per Requirement As per

Requirement As per

Requirement As per

Requirement

As per Requirem

ent

As per Requirem

ent

As per Requirement

13 Batching Plant (30m³/hr) 20 m³/hr 1 1 1 3

14 Mobile Concrete Mixers (1 cum)

1.0 m³ 1 1 1 1 1 5

15 Shotcrete Machine (6m³/hr) 6 m³/hr 1 1 1 3








3&4 Pressure


Power House

Complex Total



Quantity (Nos)

Quantity (Nos)

16 Transit Mixer (4.0m³) 4 m³ 4 10 4 18

17 Concrete Pump (20m³/hr) 20 m³/hr 1 1 1 1 1 1 6

18 Aggregate Processing Plant 150 TPH

150 TPH 1 1

19 Grout Pump 20kg/cm² 20 kg/cm² As per Requirement As per

Requirement As per

Requirement As per

Requirement

As per Requirem

ent

As per Requirem

ent

As per Requirement

20 Explosive Van 1T 1.0 T 1 1 2

21 Hydra Lift Crane 12T 12.0 T 1 1 1 1 1 1 6

22 Flat Bed Truck 1 1 1 1 4

23 Tippers 5 T 2 2 4

24 Welding Set 20 KVA As per Requirement As per

Requirement As per

Requirement As per

Requirement

As per Requirem

ent

As per Requirem

ent

As per Requirement

25 Ventilation Blower (120 HP) 120 HP 1 2 1 4

26 Ventilation Blower (80 HP) 80 HP

1 1 2

27 Dewatering Pumps As per Requirement As per

Requirement As per

Requirement As per

Requirement

As per Requirem

ent

As per Requirem

ent

As per Requirement

28 Vibrators As per Requirement As per

Requirement As per

Requirement As per

Requirement

As per Requirem

ent

As per Requirem

ent

As per Requirement

29 Mobile Crane (10T) 10 T 2 1 3








3&4 Pressure


Power House

Complex Total



Quantity (Nos)

Quantity (Nos)

30 Water Sprinkler (12000ltrs) 12000 litres 1 1 2

31 EOT Crane 20T 20 T 1 1

32 Tunnel Gantry for HRT 6 6



ANNEXURE-12.3

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 13-Project Organization


13. PROJECT ORGANIZATION

13.1 GENERAL

The project spreads over a length of about 4 km along the right bank of Budhil River, a tributary

of Ravi River.

The project construction will have to be supported by relevant infrastructure works such as

permanent and temporary colonies, offices, roads, workshops etc., all situated within the project

area.

The project is planned to be completed in a period of 36 months in addition to 12 months

devoted mainly for creation of infrastructure facilities.

The construction of the project is proposed to be carried out through contracting agencies

entrusted with suitable contract packages. Following packages have been envisaged for the civil

works for various project components:

Access roads, slope stabilization and cross drainage works. Permanent and temporary buildings, water supply, electrification of colonies, communication systems, workshops and stores, etc.

Constructions of Barrage, Intake structure, Feeder Channel, desilting chamber, silt flushing conduit and collection pool.

Construction of Head Race Tunnel, Surge Shaft and Pressure Shaft.

Construction of Powerhouse complex and associated works including tail race channel & switchyard.

Hydromechanical works including fabrication and erection of pressure shaft steel liner, gates and trashrack etc. will be a separate contract package.

The complete electro-mechanical works of the project is planned to be done under one single

package.

It is also envisaged that works relating to preparation of detailed designs, technical specifications

and construction drawings for various components of the project would be executed through a

separate contract package by a competent consultant.

Keeping in view the difficult hilly terrain in which the project is located and the quantum of design

and construction work involved, very close coordination would have to be maintained to avoid

time and cost over-runs. The organization of the project has, therefore, been planned keeping

the above in view and is presented in the Organization Chart. Broad features of this organization

structure are described in the following paragraphs.

13.2 PROJECT ORGANISATION

The works would be looked after by a specific unit set up purposefully under the overall control of

a General Manager, for the overall management of the project. All engineering disciplines and



project services would be accountable to the General Manager stationed at Bharmour, the

Project Headquarter. The General Manager would be assisted by separate wings to look after

the planning, construction management, quality control, administration, financial and accounts

aspects of the project. The structure of the organization detailed up to Divisional level, is

proposed in two parts as under:

For initial 12 months for creation of infrastructure facilities, and

For peak construction period.

The organizational set up outlined above will be supported by the necessary support staff.

General Flow diagram showing six wings to be handled by the General Manager (Head Quarter)

is indicated in Figure-13.1

13.2.1 Organization for Creation of Infrastructure Facilities

During the initial 12 months of construction period for infrastructure facilities, the General

Manager would be assisted by two (2) managers to be inducted in the first month along with

required strength of engineers and other supporting staff.

The Senior Manager (Civil construction) would be responsible for taking up Package-

Infrastructure Civil Works for creating infrastructure facilities. The Senior Manager (Civil)

would be assisted by two (2) Engineers (Civil) along with supporting staff (as per

requirement for the initial 12 months) for construction of buildings, roads, water supply as

well as procurement of materials, construction & maintenance of stores, etc.

The Senior Manager (Electrical/Mechanical) would be assisted by two (2) Engineers

(one Electrical and the other Mechanical) to look after the infrastructure requirements for

Power house electrical & mechanical works, switchyard, transmission system,

construction equipment and workshops, construction power, communication & transport,

etc.

The General Manager would be assisted by an Administration Wing headed by a Senior

Manager posted at Project Headquarters to look after the planning, co-ordination,

monitoring, personnel and administration, public health, security etc. The Senior Manager

would be assisted by necessary administrative personnel and administration, medical,

security and liaison staff in-charge of various duties.

The Financial Wing would be headed by a Manager (Chief Accounts) along with two

(2) Accounts Officers and supporting staff, who would be reporting to the General

Manager on the financial and account matters.

13.2.2 Organization for Peak Construction Period

It is proposed that during peak construction period, the above organization would be adequately

strengthened. Besides Finance and Administration, there would be a total of three (3) field

circles, each headed by a senior manager working through out the construction period. The

proposed organization will Consists of:



One General Manager, responsible for the over all execution of the project.

Four (4) senior managers for Quality control, Civil, Planning & Monitoring and

Electrical/Mechanical works. Senior Manager (Civil) will be assisted by three (3) Managers

who will look after the construction of civil works (Barrage site, Water conductor system,

Power house).

One (1) senior Manager (Electrical/Mechanical Works) will be assisted by two (2)

managers who will look after Electro Mechanical and Hydro Mechanical works. Required

number of supporting staff (Assistant managers, Engineers, Assistant Engineers and

junior engineers) will work under the supervision of the respective manager in-charge.

One (1) Manager (Chief Accounts), along with necessary complementary staff, will ensure

proper financial control.

One Senior Manager, with necessary complementary staff, will look after personnel &

administration, public health, liaison work, security, etc.

The above mentioned officers shall be overall in-charge of their respective offices and shall

function as an integrated team, every member of which will not only be conversant with his duties

and responsibilities, but will also get necessary report/feed back regularly from his respective

Division for taking timely corrective measures wherever required, for achieving targeted

completion of the project. Each Division will have technical and secretarial supporting staff as

per requirement.

Flow diagram showing Project organization proposed for peak construction period given in

Figure-13.1

13.3 FUNCTIONS AND RESPONSIBILITIES OF PROJECT TEAM MEMBERS

13.3.1 Senior Manager (Civil)

He will be responsible not only for creating infrastructure facilities, in the first year, but also the

construction of structures, such as Barrage, Intake structure, desilting arrangement, water

conductor system, powerhouse, etc.

He will be assisted by two (3) managers (Civil) for supervising the execution of these works. The

distribution of duties among managers will be as under:

Manager (Barrage site): He will be responsible for the construction of Barrage, Intake

structure, Feeder Channel, Silt Flushing conduit, desilting chambers and collection pool.

Manager (WCS): He will be responsible for construction of Head Race Tunnel, Surge

Shaft and Pressure Shaft.

Manager (Powerhouse): The senior manager in-charge will take care of the construction

of power house switchyard complex and its associated works including tail race channel.



13.3.2 Senior Manager (Quality control)

He will be responsible for organizing all testing of materials and quality control for the entire civil

works and would also be in charge of upkeep and maintenance of all laboratories. In addition,

he will be responsible for control survey of the whole project. For this purpose, he will be

assisted by a team of assistant manager, engineers, assistant engineers and junior engineers

13.3.3 Senior Manager (Electrical and Mechanical Works)

One (1) manager (Electrical) and one manager (Mechanical) will assist the senior manager along

with the required number of assistant manager, engineers, assistant engineers and junior

engineers for executing the following works:

Power house electrical and mechanical works.

Switchyard and Transmission Line,

Procurement of Stores and equipment

Material management

Construction and running of workshops

Communication and Transport

Inspection and maintenance of field machinery and

Construction power.

Stores

The distribution of duties amongst two (2) managers attached to this senior engineer will be as

under:

Manager (Electrical): He will be responsible for execution of all electrical and

mechanical works pertaining to the powerhouse complex as well as construction

power requirement. He will also be responsible for construction of the switchyard

and entire transmission system proposed for the project.

Manager (Mechanical and HydroMechanical): He will be responsible for

fabrication & erection of power pipe, surge pipe, procurement of material

equipment, material management, maintenance of stores, construction and

running of workshops, communication and transport, inspection and maintenance

of field machinery etc.

These managers will be assisted by a team of assistant manager, engineer, assistant engineer

and junior engineers for performance of their duties.



13.4 NEED BASED UNITS

The numbers of units headed by the managers, as proposed above, are based on the functional

and physical requirements of works. The works have been so distributed that appropriate

progress is achieved for critical items of works without affecting progress on other works.

Senior Manager (Electrical & Mechanical) shall execute works in a manner that all items

including critical items of work are completed on schedule to ensure timely commissioning of the

project.

13.5 PROJECT PLANNING AND MONITORING

Senior Manager will be assisted at Project Headquarters directly by a general manager along

with one Engineer in carrying out the functions of monitoring the progress of works, co-ordination

and liaison with various agencies, safety aspects etc.

13.6 FINANCE & ACCOUNTS

The General Manager will have a Manager (Chief Accounts) supported by two Accounts Officer

(AO) attached to his office. The FA & AO will have the assistance of three (3) Accounts Officers

with supporting staff to deal with work accounts, costing regular and work-charged staff

establishment etc.

13.7 PROJECT ADMINISTRATION

Regarding project administration, including maintenance of colonies, running of schools and

dispensaries, public relations, welfare etc., the General Manager will be assisted directly by a

Senior Manager (Administration) posted in his office. The Senior Manager (Administration) will

be assisted by a Security officer along with supporting staff to look after the vigilance and

security aspects of the project areas.

The organization structure will be reviewed and firmed up as part of the detailed planning in the

pre-construction stage.

The project management shall function as a fully integrated team dedicated to the

implementation of the project. Every member of the team shall report regularly to his officer-in-

charge and shall be subject to review of his performance.

While the General Manager assumes responsibility for all aspects of the project, his deputies

have to ensure that their reports reflect the up to date status of the project at that point of time.

They would periodically review the progress of works, identify the problem areas, suggest

remedial measures, see through the implementation of such measures, and have a realistic

forecast of the status of the project in the intermediate time frame.

To achieve the above objective, the Divisional Engineers shall ensure that they and their

personnel are interacting regularly on a day-to-day basis with all the concerned personnel of the



project whose work has a direct impact on the progress of their own work, and take corrective

actions, wherever called for, to adhere to work schedule.

13.8 TECHNICAL ADVISORY COMMITTEE

A technical advisory committee comprising of renowned international experts shall be constituted

by M/s BHPPL. This committee will advise the project team through the General Manager on all

critical aspects of project planning, design and construction activities.

13.9 CONSULTANTS

The General Manager August utilize the services of Technical Consultants who will assist and

advice the project authorities on all aspects of the project implementation, including engineering

design, logistics, costs and schedules, planning, construction and quality control. The

consultants will submit a monthly report indicating the work programme, progress to date, status

of drawings, problem areas and ways and means for solving the same.

13.10 REPORTING / REVIEWS

The project will be subject to monthly reviews so that all concerned are aware of progress to

date. The monthly report will give details of manpower, productivity, schedule and costs. The

purpose of these reviews will be to highlight the problem areas and provide the required

additional supervision and action to resolve the problem. The reports will be prepared using

inputs from consultants, contractors, construction supervisors, procurement officers etc., so that

a realistic picture of the project is available for review and report.

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 14-Infrastructural Facilities


14. INFRASTRUCTURAL FACILITIES

14.1 GENERAL

The BHEP-I is located on the right bank of Budhil nallah, a tributary of Ravi river in Chamba

District of Himachal Pradesh. The project is located about 535 Km from Shimla, capital of

Himachal Pradesh and around 730 Km from Delhi, the capital of India. The nearest broad gauge

railway station for the project is Pathankot which is about 215 Km from the project site

In order to complete BHEP-I over a period of 3 years broad infrastructure requirements are

identified as under:

Access Roads

Project Roads

Power Supply facilities

Telecommunication and other facilities.

Residential and non-residential buildings including electricity, water supply and sanitary facilities.

14.2 ACCESS ROADS

The intake of BHEP-I is located near the Bharmour town. It is situated at an approximate

distance of 95 km Northeast from the district head quarter at Chamba town in Himachal

Pradesh. From Sandi village a 2.0 km long foot track is available to reach the diversion works of

BHEP-I. The powerhouse of BHEP-I lies about 4.5 km upstream from the dam site of existing

Budhil HEP on Budhil nallah. The Slope of hills on the right bank are gentle in this reach and a

trekking route of length 500 m is available for accessing the power house for the project.

14.3 PROJECT ROADS

A network of new roads is required to facilitate completion of the project as per anticipated time

schedule. An approach road length of 3.5 km will be constructed to reach power house by taking

a loop from the existing Bharmour – Chobia PWD road situated near Patodi village.

Also, a 2.2 km road will be constructed after taking a loop from power house road approximately

at RD. 1250 m.

Apart from the above road, about 2-3 km length of approach path network will be required for

approach to the various project components and muck dumping yards.

Apart from roads, Ropeway is also planned for the transportation of equipments and materials to

various project components, if found necessary.

Provision for constructing access roads, ropeway and approach to various project colonies and

work site has been kept in cost estimate chapter of this report.




14.4.1 Construction Power Requirement

The maximum power required for constructions activities is estimated considering capacity of

electrically driven machines/equipment and requirement of lighting. The power requirement

varies during the construction schedule and also depends on construction methodology.

It is assessed that about 1 MW of power would be required during peak construction period.

However, construction power requirements during the initial two years would be about 500 KW.

The power requirement would be met through installation and operation of dedicated DG sets.

14.4.2 Power Supply Facilities

Presently power requirements in the project area are being met through 22 KV lines from

Bharmour town. The project area experiences frequent power cuts and break-downs. The

existing system of power supply in the region is not suitable to meet the Power requirement for

project construction.

14.5 TELECOMMUNICATION FACILITIES

The telecommunication facilities in the project area comprise of fixed line and WLL services from

BSNL. Mobile network is presently not available in the area and nearest mobile network is

available at Bharmour. For effective coordination among various work sites, workshop, colonies,

stores, design office, head office, etc., a reliable tele-communication network is necessary.

Telecommunication link for the Power house of BHEP-I will be provided by extending the

existing telephone network of Post and Telegraph Department through nearest P&T exchange.

An Internal automatic, telephone exchange (EPABX) with 15 lines capacity for the project shall

be provided. All important sites of work, offices and residences of senior officers shall be

connected by telephone. The Power house and permanent colony shall also be provided link to

keep contact with other work stations.

14.6 PROJECT COLONIES/BUILDINGS

The Residential and non-residential facilities are required during construction and O&M phase of

the project. The same will be met by constructing suitable colonies near Power House and

Intake Location.

The temporary colonies would be utilized during construction of the project and permanent

colonies would be utilized for both i.e, during construction and maintenance of the project.

The water supply requirement shall be met with from the flow of nearby streams by gravity flow.

The flow requirement sufficient to meet the likely water demand is about 20 lps.



The entire building construction program would be suitably phased to match with the

construction activities. Priority would be given to the construction of field hostel, stores, offices

and temporary residential and non-residential buildings.

It is also planned to have liaison facilities at Chamba. A suitable storage area would also be

made in Bharmour to keep the buffer for the stock of construction materials for the monsoon

period etc. Guest Houses are also planned at Bharmour.

Types of equipment required for infrastructure works has been assessed and included in the

project estimate and special T&P.

The availability of facilities viz, schools and college education, hospitals, market and recreation

at Bharmour, shall enable the staff posted on the project in the beginning to speed up the

construction of project roads, buildings and also enable to start the main civil works of the project

in the 1st year itself.

The project residence for BHEP-I is planned near Bharmour town. Residential colonies and Field

hostels are proposed to be constructed at these locations. This colony shall have following

facilities.

Portable water supply arrangements

Sanitation and sewerage disposal arrangements

Drainage arrangements

Electrical Supply

Fencing and security.

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 15-Environmental & Ecological Aspects


15. ENVIRONMENT & ECOLOGICAL ASPECTS

15.1 ENVIRONMENTAL BASE LINE DATA

15.1.1 General

The information presented in this chapter is collected from various sources. The majority of the

data on physiography, geology and water resources has been taken from the various EIA

studies carried out for the projects in Budhil Valley. Data on vegetation, fauna, water quality, air

quality, soil characteristics and Meteorological data has been collected from various reports.

Identification of environmental parameters, data collection and impact predictions form the core

of the impact assessment process. In this report, the environmental impacts due to the project

have been predicted on the available baseline data. These have been quantified wherever

possible. Negative and positive impacts are also addressed in this report.

15.1.2 Physiography

The Chamba district in which the project is proposed is bound by districts Lahaul and Spiti in

North, Kangra and Una in South, and Kullu in the South - east directions. The project

components lie between latitudes 32 - 28' 42" E to 32 - 28' 36" E and longitudes 76 32' 07" N

to 76 35' 44"N. The Budhil nallah flows in the East to West direction before joining Budhil

stream flowing downstream which finally joins river Ravi. The Budhil nallah originates at an

altitude of El +5300 m. It traverses a distance of about 33.0 km before it joins Ravi River at El

+1377 m. On an average, this stream has a steep gradient of 1:9.5. This indicates the suitability

for hydropower generation. However, such steep gradients are prone to soil erosion.

15.1.3 Geology

The proposed project is located in Lesser Himalayas in Ravi Basin and is characterized by sharp

crested ridges and deeply dissected valleys. Geologically, the region exposes rocks ranging in

age from early Proterozoic to Mesozoic. The rocks of the area are extensively covered by slope

debris, fluvial Terraces and fan deposits of Quaternary to Recent origin.

The rock formations are part of the pre-tertiary belts of thrust sheets and are believed to be the

northern part of the Indian peninsula. The geological complexity of this zone is primarily due to

the continued deformation, intermittent igneous instructions, successive thrusting and repeated

cycles of metamorphism. The complexity of the structures and intensive metamorphism has led

to divergent views on the genetic evolution of this belt.

The regional geological studies carried out by Geological Survey of India (GSI) have revealed

that the Bharmour project area consists of the following:

a) Rocks of Katarigali formation and bonds of phyllites with shear at places are exposed

b) Right bank slope is steep and might pose a problem during construction



The rock trend is N 55o – 65o W to S 55o 65o E with 60o – 75o dip due northeast direction, i.e. in

upstream direction. Apart from the bedding joint, the other prominent joint sets recorded are

1) N 25o E – S 25o W with 70o dip due southeast direction

2) N 80o W – S 80o E with 60o – 65o dip due south-east direction.

15.1.4 Soil

Detailed analytical soil survey scheme has been under taken in the proposed project. In general,

characteristics of the soil vary from place to place between clay, loam, gravel, sandy loam, and

clayey loam. In most of the places, minerals like calcium, phosphorus, iron, and cobalt are

present.

The physio – chemical characteristics of soil samples are being analyzed. The soil contains

small to large rocky particles. General texture has indicated sandy loam type of soils.

15.1.5 Climate

Climate of the project area is cool and dry. In general, three seasons are prevailing in the area;

winter (October to March); summer (April to June) and monsoon (July to September). Snowfall

generally occurs in December and January at high elevations and most of the region gets cut off

from the district head quarters. The Chamba area as a whole reaches a minimum ambient

temperature as low as -5C in winter. Temperatures recorded at Chamba town show variations

between 5.2oC to 32.5oC. However, at Bharmour and Harsar, the temperatures taper down and

lie mostly in the region of 0oC to 25oC. In winter, the area gets covered with snow and

temperatures further slump down. For all practical purposes, the region beyond Harsar is cut off

during December to February.

August is the wettest month through out the district. Monsoons are occasionally extended up to

South West monsoon. Rainfall is very heavy during monsoon and very little in the winter and

spring seasons.

The major portion of the monsoon rainfall in lower reaches of the catchment finds its way as

surface run off due to steep slopes, contributing to high river discharge in this season. The

winter precipitation falls either as rain or snow depending upon the altitude and other

meteorological conditions. It does not contribute directly to the stream discharge significantly

and mostly feeds the snow/glacier bound area of the Catchment.

15.1.6 Water Resources and Water Quality

Budhil nallah is a perennial river and originates from the slopes of the Kungti pass in the mid-

Himalayas at an elevation of +5300 m. Budhil nallah transverses a stretch of around 33 km

before it merges with the waters of the Ravi river near Kharamukh. A number of tributaries join

the Budhil stream enroute. These include streams that:



a) Join the Right bank 1 Sup Nallah 4 Hal Nallah

2 Ser Nallah 5 Lal Nallah

3 Chobia Nallah 6 Sia Nallah

b) Join the Left bank 1 Khari Nallah 5 Bhujla Nallah

2 Pran Ghala Nallah 6 Sathli Nallah

3 Top Rani Nallah 7 Nalhant Nallah

4 Thanori Nallah 8 Chalatu Nallah

Out of the above, the Chobbia, Chalatu and Gojh nallahs carry substantial discharge.

15.1.7 Hydrometeorology of the Catchment

The Budhil nallah drains a catchment area of 471 km2 upto the diversion works of BHEP-I, out

of which 261 km2 is under permanent snow cover. The inflow in the nallah comes from snow

melt and rainfall. The catchment are contributing to surface runoff is 210 km2.

The Budhil valley receives heavy rains due to the impact of the South-west monsoon from June

to September. Precipitation during winter occurs in the form of snow or rain depending upon the

altitude. Snow cover at higher altitudes gives rise to the gradual buildup of the glacier and it

results in major run-offs during summer.

There are twelve main rain gauge stations in the Ravi Catchment out of which two main rain

gauge stations are at Chitrari & Bharmour. Annual rainfall at Chitrari and Bharmour varies from

600 to 1500 mm and 600 to 2200 mm respectively. On an annual basis, the rainfall in the region

follows the pattern:

Pre-monsoon March to August 25%

Monsoon June to September 65%

Winter rains October to February 10%

The permanent snow line lies above +4000 m, but it has been observed that at locations in the

north of the catchment, snow exists even at elevations of +3050 m. The average annual snowfall

for the area is around 111.88 cm.

15.1.8 Vegetation

The forests of Himachal Pradesh are known for their grandeur and majesty and are like a green

pearl in the Himalayan crown. According to the National Forest Policy (1988), at least two thirds

(66%) of the geographical area should be under forest in the hilly states like Himachal Pradesh.

However, keeping in view that land is a limiting factor and other factors are also not congenial,



the State Government has decided to bring at least 50% of the geographical area under forest

cover.

Himachal Pradesh has a diversified and rich flora because of diverse physio-climate. With the

variation in altitudes, the eco-zone also varies in terms of their vegetative cover, land use and

land capabilities. The forest around project site could be classified broadly into:

Typical Coniferous forests, and

Broad-leaved forests.

Out of a total of 45,000 species of plants found in the country, as many as 3,295 species

(7.32%) are reported in the State. The state has legally classified 37,591 Km2 under forests.

About 8,911 Km2 dense forests and 2,869 Km2 open forest is reported in Himachal Pradesh.

This is about 21% of geographical area of the state.

It has been observed that the topography of the weir site on either side of the river is steep,

sloping almost to vertical. The species observed around project site and in the district are

summarized in Table-15.1.

Table-15.1 Species Found in the District

Scientific Name Vernacular Name

Cedrela serrata Dhauri

Aesculus indica Goon

Acer caesium Mandar

Rhus cotinus Tung

Rhus parviflora Tungla

Dalbergia sissoo Tailor shis Shinshu

Pyrus communis Nakh

Pyrus malus Seo (Green Oak)

Cotoneaster bacillaris Rheuns

Rubus biflorus Akhre (Raspberry Red)

Rubus niveus Akhre (Raspberry Yellow)

Rhododendron arboreum Cheo

Fraxinus floribunda Sanooh (Ash)

Morus alba Karun (Mulberry)

Ficus roxburghii Trambal

Ficus religiosa Pipal

Populus ciliata Chaloon (Wild pomegranate)

Alnus nepalensis Piak (Alder)

Quercus semicarpifolia Kharsu (Red Rhododendron)

Taxus baccata Barmi

Cedrus deodara Diyar (Deodar)

Abies pindrow Rai (Silver Fir)

Picea smithiana Tosh (Chilgoza pine)

Cupressus torulosa Devidiyar (Cyprus)



15.1.9 Fauna

The mountains, forests, streams, abundant food availability, large stretches of inhabitation and

comparatively inaccessible terrain provide favorable factors for sheltering of many kinds of

wildlife. Geographical area of the catchment is large and human population is very low, which

provides a good harbor for the wild life.

The state has 2 National Parks, 3 Game Reserves and 30 Wild Life Sanctuaries. The area

under National Parks and sanctuaries is 1,295 sq km and 3,267 sq km respectively. About 8.2%

of State area is covered by wild life conservation sites against 4% fixed by the Government of

India. The Forest Division in which the project is planned has two wildlife sanctuary viz Kugti

Wildlife Sanctuary & Tundah Wildlife Sanctuary.

The Kugti Wildlife sanctuary is the nearest conservation area to the project site and is at a

distance of about 3.35 km from the project intake and the Tundah Wildlife sanctuary is at a

distance of 12.55 km from the project site. NoC is obtained from the local wild life autharaties for

the same. The common terrestrial and avian fauna found in this Forest Division is detailed in

Tables-15.2 & 15.3 below.

Table-15.2 Common Terrestrial Fauna of the Area

Table-15.3 Birds of the Area

Scientific name Local name English name

Lophophorous impeianus Monal -

Alectoris gracca Chukor -

Gallus gallus Junglee Murga Red Jungle Fowl

Genuocus albicratatus Kalesha -

Caterus wallichi - Cheer pheasant

Varasis macrolopha Koklas Koklas pheasant

Francolinus francolinus Titar Black Partridge

Chalcuphaps indica Ghugi Dove

Couurnix conurnix Koyal Grey Quail

Scientific name Local name English name

Nemorthaedus goral Ghoral -

Muntiacus muntjak Kakkar Barking Deer

Moschus moschiferus Kastura Musk Deer

Panthera pardus Baghera Leopard

Selenarcios thibetanus Kala Bhallu Himalayan Black Bear

Ursus arctos Lal Bhallu Himalayan Brown Bear

Martes flavigula Gorthu Himalayan Pine Martin

Hystrix indica - Indian Porcupine

Hylopetes Ean Flying Squirrel



Chamba district is honey combed by the perennial river and streams with considerable flow of

water. There is scope for pisciculture in the district. Species of Brown Trout are found in flowing

streams and Ravi River.

15.1.10 Human Population

The population density in the catchment is 0.29 per hectare as per the census of 2011. Thalla,

Harsar and Kugti are the nearby villages. The entire population in the catchment area is rural.

Most of the population depends upon agriculture, horticulture and animal husbandry for their

livelihood.

Climatic conditions are suitable for cultivating rajmah and maize but as transportation is difficult,

people generally don't grow these crops with commercial interests. In some cases 14 km

manual carriage is required to reach road head. However, the Kugti rajmah is famous for its

quality of fine grains and unique flavour.

There is no human settlement at proposed weir site and water conductor system. Hence, no

rehabilitation and resettlement is anticipated due to the project.

15.1.11 Public Health

The water supply to catchment area settlements is from rivers / springs. Drinking water in

villages is available through small rivulets of pure mountain water, locally known as ‘chashma’.

Treated piped water supply is available only in Chamba. Water borne diseases are prevalent

due to poor sanitation in the villages.

15.1.12 Seismicity

Chamba region shows active and prolonged seismic history. The project area falls in Zone – IV

of the seismic zoning map of India. As per the seismicity studies carried out by the Geological

Survey of India (GSI) within the Himalayan Belt, the northernmost conspicuous structural

element is the Main Central Thrust.

The area has experienced the Kangra earthquake of 1905 having epicenter located about 20 km

south of the project area and having a magnitude of 8.6. This earthquake was one of the four

great earthquakes of the Himalayan region, which took a toll of 20,000 human lives and caused

colossal loss in the form of complete damage to buildings and generation of numerous

landslides and earth fissures. The other important earthquake is the Chamba earthquake of

22nd June, 1945 having magnitude 6 on the Richter scale and located about 50 km north of the

project area. Recently, the area had experienced micro-earthquake activity in the Dharamshala

earthquakes of 1978 and 1986, having magnitudes 5 and 5.7 respectively. The next Chamba

earthquake occurred in 1995 and caused partial collapse and development of cracks in the

buildings.



The project area lies to the north of the Main Boundary thrust, the Drang thrust and the Vaikrita

thrust. The Jwala Mukhi thrust passes below Dharamshala, south-west of the project area.

The project area lies north of the Dhauladhar range while all the active thrusts namely the Krol

thrust, main boundary fault and tear faults lie south of the range. A major lineament picked up

from lands/imagery, trending N10'E-S10"W and having extent more than 300 km passes

through the project area and lies north of the range and does not cross it. The exact nature and

seismic activity of this lineament has not been investigated. There are two prominent seismic

active zones; one is about 20 km south of the project area, i.e. the Dharamshala - Kangra zone

and the second zone lies 30 to 40 km north of the project area where an earthquake of a

magnitude greater than 5 has taken place. In addition, earthquakes of magnitude 7 (Richter

scale) occurred on 28.02.1908 about 60 km east of the project area. In view of the devastating

earthquakes within the radial distance of 20 to 60 km of the project area, it is necessary that

suitable seismic coefficients should be adopted in the project design.

Detailed geological investigations should be carried out at the project site including borehole

investigations and seismic traverse etc. Based on the available data and the studies that were

carried out, the highest safety factors are being adopted in the design of the project structures.

15.1.13 Land Use

The land use of Himachal Pradesh is summarized in Table-15.4. From this table it is clear that

about 67% of State area is under forest cover. Pastures and grazing lands contribute about

14%.

Table-15.4 Land Use Pattern of Himachal Pradesh State

S. No. Land Use Area (Sq. km) % age

1 Settlements & Non-agriculture Use 1,928 3.5

2 Forest 37,591 67.5

3 Agriculture 5,820 10.5

4 Fallow Lands 740 1.3

5 Culturable wastes 1,268 2.3

6 Tree cultivation 459 0.8

7 Permanent pastures / grazing 7,867 14.10

TOTAL 55,673 100.00

The land use pattern of catchment area has also been worked out. The total geographical area

of catchment upto BHEP-I intake is 471 km2 out of which 261 km2 is under glacier/ permanent

snow. The distribution of land use in the catchment is given in Table 15.5. This table shows that

catchment area under forest is 41.4% and snow cover is 55.41 % while only 3% is under

agriculture.



Table-15.5 Land Use/Land Cover in the Catchment

S.No. Land use System Area (km2) % of Total

1 Total Forest 195 41.40

2 Agriculture Land 15 3.28

3 Barren Land 261 55.41

TOTAL 471 100.00

15.2 INFRASTRUCTURE FACILITIES

15.2.1 Roads

Approach paths and roads have to be constructed to access the various project components as

explained in environment plan of this report.

15.2.2 Residential Facilities

Residential colonies are proposed to be constructed as follows:

The permanent colony for the project will be set up near Bharmour Village. This shall have

buildings required for operation and maintenance staff of the project. The administrative

buildings shall be located at powerhouse after project construction is over.

Temporary residential buildings for the staff deployed for construction supervision at the

intake and powerhouse sites during the construction period shall also be constructed.

The permanent colony at Bharmour shall have a well-equipped medical centre as also

recreation centre, telephone exchange etc. This colony shall have the following facilities:

Potable Water supply arrangements

Sanitation and sewage disposal arrangements


Internal roads and cross-drainage works

Electrification

Fencing and Security.

15.2.3 Telecommunication

Telecommunication links between powerhouse, head works and the colonies shall be provided

by connecting these places by extending the existing telephone network of Post and Telegraph

Department, through nearest P & T exchange.

An internal automatic telephone exchange (EPABX) has been proposed. All important sites of

work, offices and residences of senior officers shall be connected by telephone.



The powerhouse and permanent colony shall also be provided with VHF wireless link to keep

contact with other power stations and substations in the grid. The powerhouse shall ultimately

be connected by carrier communication system.

15.2.4 Power Source & Transmission

The construction power shall be made available by installing and operating diesel power sets.

This arrangement is necessary to provide continuous reliable and stable power to the project.

The distribution lines from these sites shall be laid by the Project Authority. The contractors

engaged on the construction of various project components shall be supplied power at one point

where it shall be metered. The power distribution lines for carrying power to various places of

work shall be installed by the contractors themselves.

The power generated at the power station would be transmitted through by means of 132 kV

D/C transmission line and shall be connected to the Bharmour Hydroelectric Project Stage-II

(BHEP-II) sub-station/switchyard.

15.3 QUALITY OF LIFE STYLE

15.3.1 Socio-Economic Values

Bharmour is the nearest town to the project site. The nearby villages are Harsar & Kugti. The

population density of these villages is about 0.29 people per hectare. The entire population in

the catchment area is rural. Most of the population depends upon agriculture, horticulture and

animal husbandry for their livelihood. The education facilities available at Bharmour are upto

Senior Secondary level. There is no industry in Government or private sector in the area.

All the other project components like the weir, penstock and roads of the project are on

degraded land and hence no major negative impact is envisaged. No removal of

structure/house/room, which could have been used for or was being used for residential or

official or any other purpose has been required for the construction of the project. No family or

person has been dislodged from their place of residence for construction of the project

structures.

15.3.2 Development of Tourism and Agriculture

The Chamba district of Himachal Pradesh is already a thriving tourist area. The Project has

planned necessary steps to ensure that tourist traffic in the area within its command is well

controlled. The impact of tourism and influx of tourist and related influences will be evaluated by

the Ministry of Environment & Forests, Government of India, and necessary mitigation measures

as required by them or otherwise will be taken.

As far as agriculture is concerned, the negative impact of the project is limited to acquisition of

agricultural land for locating the powerhouse. The land would be acquired with the help of the



Government and through direct negotiations with landowners. No increase in eutrophication is

expected as the project is a run-of-the-river scheme.

15.4 ASSESSMENT OF NEGATIVE IMPACTS

15.4.1 Impacts Due to Project Location

During this phase, those impacts which are likely to take place due to the layout of the project

have been assessed. These impacts are:

Resettlement and rehabilitation, if any

Loss of land

Encroachment into forest land and loss of forest produce

Encroachment into nature reserves

Loss of historical and cultural monuments, and

Risk due to earthquakes

15.4.1.1 Rehabilitation and Resettlement

There is no rehabilitation involved in the project area.

15.4.1.2 Loss of Land

About (mainly agricultural land) 2.21 ha of private land (mainly agricultural land) will be lost due

to project activities.

15.4.1.3 Forest Land and Loss of Forest Produce

The total area of forest/government area required for project components, buildings, roads and

other ancillary facilities is about 6.0 ha.

The local population August collect (legally and illegally) a variety of wood and non-wood

products from these areas. These include fuel wood, utility wood, thatch wood for roofing and

leaves for tableware manufacturing.

15.4.1.4 Encroachment into Nature Reserves and Wildlife

There will be no conflict regarding the encroachment on nature reserves, as neither the project

area nor its nearby surroundings have been declared as nature reserves. There are no rare or

endangered species in the project area.

No remarkable environmental changes will occur due to this project. Further, except colony,

roads, buildings, weir, Desanding chamber and switch yard all other water conductor systems

penstock and power house are underground. Moreover, the construction and operation activities

of head race tunnel, valve house will be underground. Therefore, it is not expected that the



project will impede wildlife movement, if any. By virtue of the small and underground

components, the forest area shall also be saved.

15.4.1.5 Loss of Historical and Cultural Monuments

No historical or cultural monuments will be lost in any of the villages and surrounding areas due

to project construction.

15.4.1.6 Risks Due to Earthquakes

The project area falls within the seismic Zone IV as per Seismic Zoning Map of India (IS: 1893 -

2002) where shocks of the intensity of 4 to 5 on Richter scale have been reported. These are

expected to correspond to basic horizontal seismic co-efficient of 0.12 g. Necessary safety

factors have been incorporated in designing the structures under the worst combination of

forces.

15.4.2 Impacts Due to Project Design

The impacts considered due to project design are, the disruption of hydrological balance, and

risk due to earthquake.

15.4.2.1 Impacts Due to Project Location

It is proposed that a minimum 15% water immediately downstream of the diversion structure of

the project at all times as per the policy of Department of Environment, Govt. of HP.

15.4.2.2 Impacts Due to Construction Works

Although environmental hazards related to construction works are mostly temporary in nature,

this does not mean that these should not be considered. Appropriate measures need to be

included in the work plan and budgeted for. The most likely hazards related to the construction

works are:

Soil erosion at construction sites

Pollution by construction spoils and muck

Health risks and cultural hazards

Soil Erosion at construction Sites

Runoff from unprotected excavated areas can result in soil erosion. Mitigation measures include

careful planning and selection of borrow pits, timing of cut and fill operations and re-vegetation

campaigns. In general, construction works are stopped during monsoon season. The

management plans to control soil erosion are discussed in Section 15.8.



Pollution by construction spoils and muck

The construction material will be required for various structures. Generally, such materials are

collected from quarry. Solid waste production because of excavation operation is summarized in

Table-15.6.

Table-15.6 Muck Production by Excavation

S.No. Place Excavated Muck (in cubic metres)

A. OPEN AND UNDERGROUND EXCAVATION

1 Upstream works 98446

2 Roads 10000

3 Tunnel & Adit portals 46145

4 Surge Shaft & Pressure Shaft 17100

5 Power house & Tail Race Channel 42300

6 Switchyard 74865

Subtotal-A 2,88,856

Health Risk

Health risks include disease hazards due to lack of sanitation, water supply and human waste

disposal, vector-borne diseases and hazards to local carriers. Mitigation measures include

proper sanitary health care and human waste disposal facilities. Sanitation facilities are included

in the project estimate to take care of cost to be borne towards waste treatment/disposal

facilities.

15.4.2.3 Cultural Hazards

Problems could arise due to differences in customs of workers and local residents. These risks

could be reduced by providing adequate facilities in workers camps and by employment of

preferably local labour.

15.4.2.4 Impacts Due to Project Operation

The likely impacts due to project operation are erosion, Sandation risk, change in water quality,

risk of and increased incidence of water related diseases.

15.4.2.5 Erosion and Sandation Risks

It can be expected that most of the Sand load of the main area will come from run-off. As

mentioned earlier, raised overflow type weir is proposed without any storage.

The average flow in this stream is about 250-300 mg/L. However, during heavy monsoons, this

value August reach as high as 1000 mg/L. The sand load does not pose any Sandation risk to

water storing structures. It is anticipated that most of the Sand shall be trapped and flushed out



by the Desanding basins. The project being run-of-the-river scheme, the sediment will be

washed-off along with the water or the undersluice gate is also function as a silt ejector by

hydraulic flushing with operating the gate periodically.

15.4.2.6 Change in Water Quality and Risk of Eutrophication

The change in water quality due to leached soil nutrient and runoff sediment August sometimes

lead to eutrophication of surface waters. Eutrophication is mainly due to the presence of

nutrients such as nitrate and phosphate. Most of the catchment is either covered with forest or

snow. As there is very little agriculture in the area, the concentration of these nutrients is very

less. Hence, the problem of eutrophication is not anticipated due to the proposed water storage.

15.4.2.7 Increase Incidence of Water Related Deceases

The main factors for the proliferation of water related diseases are vectors and pathogens. The

stagnant water and vegetation provide favourable breeding places for vectors like mosquitoes

and snails. Being a run of the river project, water will be flowing and thereby the chance of vector

life to thrive is less. Additional health facilities will improve future status.

15.4.2.8 Impact on Fish

The main species of fish observed in Budhil stream down stream is brown trout. The spawn

could not sustain more than 0.4 km per hour of stream velocity. The spawning features and

velocity (Mitra 1968) required are as follows:

S.No. Spawning Features Velocity (km/hr.)

1 Spawn dispersed irregularly 0.00

2 All spawning stationary 0.09

3 Spawning Migrate upstream and some taking shelters

0.14-0.29

4 Spawn carried downstream 0.36-0.42

Since the velocity of flow in nallah varies from 2 km/hr to 3.6 km/hr, i.e. even the minimum

velocity is higher than the velocity required for spawning, no spawning habitat for fish is found in

the stream. However, there August be some pockets of still water where spawning August be

possible. A provision of fish ladder will be kept in the barrage.

15.4.2.9 Public Health Facilities

Public health facilities, such as water supply and sanitation are much needed at colony,

construction sites and powerhouse. In all about 150 people are likely to stay in the colony at

peak time.



Water requirement for the project shall have the following components:

Domestic requirements @ 135 litres/capita/day: 20250 L/day for a maximum of 150

people

During construction 45 lpcd for 15 people: 675 L/ day

The water available could be utilised after sedimentation, filteration and chlorination. A small

domestic water facility needs to be developed by the contractor for his camp and for

powerhouse. Similarly, sanitation facilities need to be planned as discussed in environment plan.

15.5 ASSESSMENT OF POSITIVE IMPACTS

Based on project particulars and the existing environmental conditions, potential positive and

negative impacts have been identified that are likely to result from the proposed project, and

where ever possible these have been quantified. The negative impacts were discussed in the

previous section. This section deals with the positive impacts that have been listed under the

following headings:

Higher power generation

Employment opportunities

Recreation and tourism potential

Reduction in fuel consumption

Reduction in air pollution, and

Benefits to economy.

15.5.1 Higher Power Generation

The construction of BHEP-I will add another 24 MW to the power generation capability of this

region. The scheme would therefore be very useful for improving power scenario in Himachal

Pradesh as well as the Northern Region.

15.5.2 Employment opportunities

The project will provide short and long term employment opportunities, as it is likely to be

completed in 3 years. During this period manpower will be needed to take part in various project

activities. About 150 people are likely to work during peak construction activity. In the post-

construction phase, about 15 people will be employed for operation and maintenance of the

project. These employments will be at all levels starting from unskilled worker to administrator to

plant operator. Thus the project would provide substantial direct employment and in addition to

these, more people would be indirectly employed for allied activities.



15.5.3 Recreation and tourism potential

The project area and its surroundings possess a good potential for the development of tourism

due to the available natural environment. With the development of infrastructure, tourists can be

attracted in a large number. Accordingly, more tourist resorts could be made and recreation

facilities could be provided around the area, in addition to those existing at Chamba. The villages

in the area are not exposed to the rest of the world and are sovereign in socio-economic,

religious and administrative set up. The inhabitants of the village participate in village

administration.

15.5.4 Less fuel consumption

In a coal or oil fired thermal power plant, about 1 kg of coal or 350 ml of oil per KWh is required.

To generate 100.84 GWh, about 99,997.63 tonnes of coal or 35,000.92 tonnes of oil will be

required. As the process in a thermal power plant involves combustion, air pollution is bound to

take place. The development of this hydro project will facilitate a saving of about Rs. 350 million

per year.

15.5.5 Less Air Pollution

In case alternate energy source were to be provided, 7608 tonnes per year of air pollutant will be

emitted to generate 18 MW of power from diesel. The pollutants likely to be emitted per year

from the Diesel fired power plant will be as follows:

Particulate Matter - 1,474 tonnes

Sulphur Di-oxide - 536 tonnes

Carbon mono-oxide - 804 tonnes

Nitrogen Oxides - 2,972 tonnes

Hydrocarbons - 1,821 tonnes

With the implementation of the project, the cumulative reduction in pollutants will be about 0.38

million tonnes in 50 years life span of project. This will have a positive impact at global level, by

reducing global warming, green house effect and ozone depletion. However, if coal fired power

plant is used, the pollutants will be much more than Diesel fired as reported above.

15.5.6 Benefits to Economy

Since water is a renewable resource it can be effectively harnessed for sustainable socio-

economic development purposes. Hydropower development planning based on the sustainable

development strategy would be necessary for careful exploitation and utilization of these natural

resources. The development strategy would incorporate and maintain balanced harmony with

the prevailing ecosystem. Thus, hydropower development would play a vital role in the overall

economic, social and industrial development in the region.



The country will gain 115.68 GWh energy annually. It will also provide employment to

approximately 150 and 15 people during construction and operation phases of the project

respectively. Thus, this will benefit the economy at natural and local levels.

15.6 CHECKLIST OF IMPACTS

Based on the positive and negative impacts as discussed in the above sections, a checklist of

positive and negative impacts has been prepared and is presented in Table-15.7.

Impacts are further classified as short – term and long – term impacts. These are presented in

Table-15.8. It is evident from these tables that most of the negative impacts are short-term in

nature.

Table-15.7 Checklist for Impacts Due To the Proposed Project

Project Phase/ Environment Impacts

Positive Negative No change

A. Impact due to project location i) Rehabilitation and Resettlement *ii) Loss of forest land * iii) Loss of land * iv) Encroachment into nature reserves * v) Loss of historical / cultural monuments *vi) Risks due to earthquakes *

B. Impact due to project design i) Disruption of hydrological balance * ii) Impact on fish population *

C. Impact due to construction works i) Soil erosion at construction sites * ii) Pollution by construction spoils * iii) Health risks *

D. Impact due to project operation i) Soil erosion risk * ii) Change in water quality * iii) Risk of eutrophication * iv) Water borne diseases * v) Vector-borne disease *

E. Positive Impacts i) Power generation √ ii) Employment potential √ iii) Recreation and tourism potential √ iv) Additional habitat for aquatic wildlife √



Table–15.8 Short Term and Long Term Impacts

Environmental Impacts Long Term Short Term

Negative Impacts

i) Loss of Forest *

ii) Loss of Land *

iii) Soil erosion at construction site *

iv) Pollution by construction spoils *

v) Health risks *

vi) Cultural hazards *

vii) Water-borne disease *

viii) Vector-borne disease *

Positive Impacts

i) Power generation √

ii) Employment potential √

iii) Recreation and tourism potential √

iv) Additional habitat for aquatic wildlife √

v) Less Fuel consumption √

vi) Less Air Pollution √

15.7 ENVIRONMENT MANAGEMENT PLAN

The BHEP-I project will provide opportunities for employment, enhancement in career

opportunities for the local rural population and will herald a positive move towards less fossil fuel

consumption, low air pollution and greater generation of power. However, to maintain the

sustainability of the project, certain environmental problems due to the project shall also be dealt

with by techniques like reforestation to reduce/ curb soil erosion, proper disposal of muck, etc.

The environmental issues likely to develop during project construction and operation phases

could be minimized by making necessary provisions in the project design and adopting an

Environmental Management Plan (EMP).

Based on planned project activities, environmental baseline data and impacts assessed in

earlier sections, this section enumerates the set of measures to be taken during implementation

and operation, to eliminate, avoid or offset adverse environmental impacts or to reduce them to

acceptable levels, together with the action to be taken for their implementation.

The most reliable way to achieve integration of the plan into the overall project planning and

implementation is to establish the plan as a component of the project. This ensures that it will



receive funding and supervision along with the other investment components. For optimal

integration of the EMP into the project, the following infrastructure links should be provided for:

Funding

Management and training, and

Monitoring

The purpose of the first is to ensure that proposed actions are adequately financed. The second

link helps in imparting training, technical assistance, staffing and other institutional strengthening

items needed to implement the mitigation measures in the overall management plan. The third

link is necessary to provide a critical path for implementation and to enable sponsors and the

funding agency to evaluate the success of mitigation as part of project supervision and as a

means to improve future project. This section covers the following preventive measures:

Mitigation measures

Disaster management, and

Emergency measures.

For every issue discussed in the above measures, the implementing agency as well as staffing,

equipment, phasing and budgeting have been presented as far as possible. All required funds

would be channelised through Project Authorities.

15.7.1 Mitigation Measures

Based on the impact assessment study, it is proposed to provide mitigation measures for the

following:

Compensatory Afforestation

Provision for Fuel wood

Compensation for land

Draining of water from Barrage/Tunnel/Power House

Muck Disposal

Water supplies and Sanitation

Refuse Disposal

Lighting

Health Facilities

Anti-poaching Activity

Mitigation Measures due to Tunnel Blasting

Catchment Area Treatment Plan

Compensatory Afforestation

The Department of Forest, Government of Himachal Pradesh is responsible for the construction

and management of forests in the project area. The Forest Conservation Act of 1980 stipulates



strict forest protection measures and outlines procedures for compensatory afforestation if the

department accepts conversion of forestlands for non-forest purposes:

If non-forest land is not available, compensatory forest plantation is to be raised on

degraded forest land to the extent of twice the affected or lost forest area;

If non-forest land is available, compensatory afforestation is to be raised over an area

equivalent to the affected / lost area of the forest.

According to the results of the present study it is found that about 6.12 ha of forest land will be

lost due to the project. No non - forest land is available, hence double the area has to be

reafforested in degraded forest available nearby. Thus, compensatory afforestation will be

carried out in an area of 12.24 ha.

In addition to this, efforts need to be made to plant trees at appropriate places on completion of

the works along the road. The objectives of the reafforestation program should be to develop

natural areas in which ecological functions could be maintained on substantial basis. Therefore,

planting of miscellaneous indigenous tree species should be carried out. The recommended

species are given in Table 15.9. The afforestation work will be carried out by Department of

Forests. The cost of afforestation is estimated as Rs. 2,00,000/- per ha. Therefore, the total cost

of afforestation would be Rs. 24,48,000/-.

Table–15.9 Recommended Tree Species for Reafforestation

S. No. Local Name Botanical Name

1. Deodar Cedrus spp.

2. Kail Pinus

Provision of Fuel Wood

Fuel Supply Plan

There is no major rehabilitation of oustees from the project. However, in order that influx of

labourers in the project area does not lead to deforestation, necessary arrangements for supply

of coal/ LPG/kerosene to the labourers on an individual basis will be made by the Company in

association with its contractors with the help of the local Government. Long-term orders will be

placed on Government agencies like the Indian Oil or Bharat Petroleum Ltd. to provide

LPG/kerosene at the project site for distribution to the labour engaged for work at site. Similarly,

purchase orders for fuel wood/charcoal will be placed for regular fuel supply to the labourers

from authorized fuel/ wood/ charcoal depots of the district.

Compensation for Private Land

About 2.2 ha of private land will be utilised for project components. Compensation shall be paid

as per the norms of Govt. of India / Himachal Pradesh. The compensation for the loss of private

land has been estimated later in this report. It is proposed to adopt the concept of land for land



for the loss of land. In case land cannot be made available, compensation in cash could be

made. The compensation on crops could be paid to the farmers through land and Revenue

Department of Government of Himachal Pradesh from the project funds or directly with their

consent.

Draining of Water from Barrage/Tunnel/Power House

Problems of water flow associated with tunneling are bound to take place. In bore tunneling,

continuous draining of water is essential for better working conditions. Pumping is an

economical alternative wherever essential.

The well point system is recommended for dewatering as the volume of water to be pumped out

is not large. The deep well system is adopted where the water is collected over a large depth in

a small area. The deep wells can be installed either inside or outside the diaphragm walls or

inside the cut.

A suitable piezometer is installed to monitor the water table constantly and to see how much

lowering has been effectively done. The dewatering should not be stopped unless it is ensured

from design calculations that the load of the constructed box component has reached a stage

where it will counter act the hydrostatic pressure from below.

About 1 m3/ hr per meter length of seepage water is likely to come into the tunnel and

powerhouse during construction. Seepage in barrage during construction is estimated as 100

Lps. This will necessitate dewatering, which can be achieved by:

Leading the ground water to a sump by drains and then pump out the water from the

sump. To prevent loss of fineness, inverted filter August have to be used.

Dewatering as suggested above August not be effective in preventing sand flows.

Lowering of the water by properly designed single or double stage well points will be

effective in such cases.

The construction of diaphragm walls of concrete along the side of channels, before the

commencement of excavation will be required.

The water from sump wells is put into water drain after settlement of solids to avoid any load on

stream / river. These water drains will finally join natural existing streams.

Muck Disposal

Construction of project is a specialized and complex task. Soil collection, transportation, disposal

and its treatment needs to be carried out in a systematic manner. The soil collection should be in

containers from the dredging sites/ places. These containers should be such that soil should not

spill during movement to disposal sites. The excavated soil will be first collected at dumping

ground and then transferred to disposal sites.



Dumping sites are essential to store the excavated earth temporarily for back filling at later date

and final disposal. Out of the total excavated quantity of about 3,90,400 m3 (with 40% of swelling

factor) about 1,17,120 m3 (30%) will be reused in making roads, back filling and concreting and

the balance of about 2,73,280 m3 (70%) will be disposed off at disposal sites.

It is proposed to have the height of dumps about 3.5 m being hilly area. About 5 ha of land will

be required to dispose of the excavated earth.

The final dumping sites shall be first cleaned for vegetation. Then the surface shall be treated to

make it impervious to avoid any leaching of chemicals. After filling the disposal area, it needs to

be leveled and revegetated.

Water Supply and Sanitation

The public health facilities, such as water supply, sanitation and toilets would be provided as

required at the project sites. The Central Public Health and Environmental Engineering

Organization (CPHEEO) has recommended a provision of 45 litres of water per day per person

for such work sites. Water sources will be treated before use upto WHO drinking water

standards. For people working in the powerhouse during project operation phase, about 4,500

litres of water per day would be made available at the site. A conventional water treatment plant

will be provided for this purpose.

The collection and safe disposal of human wastes are among the most important problems of

environmental health. The sewerage carried in water solves the excreta disposal problems. The

individual sewerage disposal problems through septic tank could be adopted for sewage

disposal. The capacities are indicated in Table-15.10.

Table-15.10 Capacity of Septic Tank for Individual Dwellings

S.

No.

Maximum No.

Persons served

Liquid Capacity

of tank, gallons

Recommended Dimensions (m)

Width Length Liquid

depth

Total

depth

1 8 1100 1.22 2.60 1.37 1.68

2 10 1300 1.22 3.05 1.37 1.68

3 12 1500 1.37 3.05 1.37 1.68

Refuse Disposal

Refuse includes many different substances such as garbage, rubbish, deal animals, street

sweepings and ash. Health problems August arise since some of the refuse attracts insects and

rodents.

The refuse disposal program should include waste segregation, storage, collection and disposal.

The solid waste from contractor’s camp needs special attention. The solid waste will be

segregated into organic and in-organic waste in separate collection containers. The organic



waste will then be converted into compost and used as fertilizer for horticulture purpose in

colony areas as well as muck disposal sites.

The capacity of these containers should not exceed 120 liters and these should be equipped

with side handles to facilitate handling. The containers used for garbage storage should not

exceed 50 liters and should preferably be equipped with a flexible cover. To avoid odour and

accumulation of fly – supporting materials, garbage containers should be washed at frequent

intervals. The remaining inorganic solid waste would be disposed at designated disposal sites.

Lighting

It is proposed to adopt the norms followed in such type of underground structures for illumination

as summarized in Table-15.11.

Table–15.11 Illumination at Different Locations

Locations/Premises Illumination (Lux)

Entrance to Power House 250

Concourse 200

Staircase areas 60

Toilets 100

Offices 300

Emergency light and public utilities 15

Health Facilities

The medical infrastructure available at Bharmour would be would be used for BHEP-I. About

150 people will be working during the peak construction phase. According to the criteria of

Ministry of Health, GOI and World Health Organisation (WHO), one Health Center (HC) with one

doctor and minimum one health personnel (nurses, compounders, etc.) will be required with

atleast one beds. In addition, several provisions towards providing a comprehensive health plan

have been made.

Mobile Dispensary

One ambulance will be procured and provided by the project for meeting immediate and urgent

medical calls in and around the project area including emergency calls from local villages.

Medical Infrastructure

An additional provision shall be made for medical assistance to be provided in the project area

during the period of 3 years in which the project will be implemented. The expenditure would be

incurred on the maintenance and upkeep of medical/ health assistance to the project employees

and the surrounding village population by procuring and providing medical testing/ diagnostics,



emergency medical facilities like Oxygen (Cylinders), fracture attendance, pre natal and post

natal care for mother and child etc.

The project authority shall also make necessary provisions for employing the services of Medical

Officers, compounders, drivers and other helping staff to provide the medical facilities.

Roads

To approach the various project sites, construction of following project roads totaling 1.0 km in

length is proposed:

A 5 m wide and 1.0 km long approach road to the Power House from HPPWD road.

Part of the excavated muck shall be employed in paving the roads.

Colony

The permanent colony shall have the following facilities:

Potable water supply arrangements

Sanitation and sewage disposal arrangements


Internal roads and cross-drainage works

Electrical supply

Fencing and security

The project implementation will not involve the participation of a large labour force throughout

the construction stage. The peak labour requirement is estimated at 150 people. The estimated

number includes the family of the labourers who would also be residing in the accommodation

provided to them in authorized residential areas during the peak construction period of the

project.

Government land required by the company for temporary works during the construction of the

project, will be arranged on short term lease basis for a period not exceeding ten years, on such

terms, conditions and rates as August be prescribed/fixed by the Government from time to time.

The labour strength is expected to peak during the second year of construction and continue

uptil the third year. While the strength will be around 150 persons during the 2nd, and 3rd year

of construction, it is not likely to exceed 75 persons during the first year of construction.

The labour will be provided individual dwelling units made of G.I. sheets and locally available

building material like boulders etc. The dwelling units will be supported by common toilets and

bathing facilities duly segregated for male and female labour. Piped water supply will be made

available.



Quarries

Suitable quarry sites will be developed as required in the project area. Tunnel muck will also be

used as construction material. If additional material is required, it will be collected from the

quarries that shall be approved by Govt. of Himachal Pradesh.

Anti-poaching activity

The Project area does not fall in a reserved forest sanctuary. There are also no rare and

endangered species in the project area. The Kugti Wildlife sanctuary is the situated 3.35 km

from the project area.

Mitigation Measures Due To Tunnel Blasting

Underground excavation involves mainly the construction of a headrace tunnel, and adits

tunnels. The tunnels are provided through the hills and have been so aligned that adequate

lateral and vertical rock covers are ensured. The tunnels would be excavated using

conventional drill and blast method. As the excavated cross-sectional area of the headrace

tunnels is very small and the depth of the holes is insignificant as compared to the lateral and

vertical rock covers, no perceptible tremors are likely to be generated on account of blasting. In

view of the above, it is felt that no additional measures are called for to mitigate the effects of

tremors on account of blasting.

Catchment Area Treatment (CAT) Plan

“To control the rate of soil erosion in the catchment and also to check the silt inflow into the river,

Catchment Area Treatment (CAT) is an ineluctable part of any hydropower project. The CAT

plan pertains to preparation of a management plan for treatment of erosion prone areas of the

catchment through biological and engineering measures; however, a comprehensive CAT plan

should also include the social dimensions associated directly or indirectly with the catchment. A

well designed CAT plan should not only control the sedimentation but should also provide a life

support system to the local population through their active involvement.

Proposed Bharmour project is upstream project of the existing Budhil HEP being operating by

Lanco Group, it is also found that the entire catchment up to the existing Budhil HEP was

considered during preparation of Catchment Area Treatment (CAT) Plan for Budhil HEP and the

same was approved by Govt. of India during issue of Environment Clearance for the project.

Hence separate CAT Plan is not proposed for Bharmour-I HEP.

15.7.2 Disaster Management

Disaster is an unexpected event due to sudden failure of the system, external threats, internal

disturbances, earthquakes, fire and accidents. The first step is to identify the causes, which pose

unexpected danger to the structural integrity of structures. The potential causes are excessive



load, cracks, failure of sensing instruments, accident etc. These need to be looked into with

care.

No disaster is anticipated, as the project is run-off-the river scheme and the weir is on the

riverbed itself. Rock protection measures would be implemented to protect the riverbank from

soil erosion. Based on topographic details of the area, no damage to any settlement is

anticipated.

The underground and on ground structures have to be designed by adopting suitable factors in

the design of structures. Moreover, in case of disaster either by natural or man-made causes, it

is proposed to draw guidelines for reporting procedures, communication system and emergency

action committee as follows:

Reporting Procedures

The level at which a situation will be termed a disaster shall be specified. This shall include the

stage at which the surveillance requirements should be increased both in frequency and detail.

The engineer-in-charge should notify the officer for the following information:

Exit points for the people.

Safety area in underground structures, and

Nearest medical facilities.

Communication Systems

An efficient communication system is absolutely essential for the success of any disaster

management plan. This has to be worked out in consultation with local authorities. More often,

the entire communication system gets disrupted when a disaster occurs. The damage areas

need to be clearly identified and provided with permanent and foolproof communication system.

Emergency Action Committee

To ensure coordinated action, an Emergency Action Committee should be constituted. The civic

administrator August be the Chairman of this committee. The committee August comprise of:

Police Officer of the area,

Transport Corporation representatives,

Home Guard representative,

Fire Bridges representative,

Health Department representative,

Department of Information and Publicity, and

Non-Governmental Organisation of the area.



Emergency Action Committee will prepare the evacuation plans and procedures for

implementation based on local needs and facilities available. The plan should include:

Demarcation of the areas to be evacuated with priorities,

Safe route to be used, adequacy of transport for evacuation, and traffic control.

Safe areas,

Security of property left behind in the evacuated areas, and

Functions and responsibilities of various members of evacuation teams.

All personnel involved in the Emergency Action Plan should be thoroughly familiar with all the

elements of the plan and their responsibilities. They should be trained through drills for the

Emergency Action Plan. The staff at the site should be trained for problem detection, evaluation

and emergency remedial measures. Individual responsibility to handle the segments in

emergency plan must be allotted.

Success of an emergency plan depends on public participation, their response to warning

notifications and timely action. The local public has to be educated on the hazards and key role

in disaster mitigation by helping in the planned evacuation and rescue operations.

Further during the execution of our project, we shall adhere safeguards and mitigation measures

related to the proposed project as laid down in Directorate of Energy Letter reference No

HPDoE/CE (Energy) Disaster management /2013-1763-1808 dated 12/06/2014.

15.7.3 Emergency Measures

The emergency measures are adopted to avoid any failure in the system such as lights, fire,

means of escape, ventilation shafts etc. The aim of Emergency Action Plan is to identify areas,

population and structures likely to be affected due to a catastrophic event or accident. The action

plan should also include preventive action, notification, warning procedures and co-ordination

among various relief authorities. These are discussed in following sections:

Emergency Lighting

The emergency lights operating on battery power would be provided at Power House. The

battery system would supply power to atleast 25% of the lights in powerhouse for a period of 2

hours.

Fire protection

The building materials would meet appropriate fire resistance standards for underground

structures. The fire resistance period would be atleast 4 hours for underground and overhead

structures respectively. Wood shall not be used for any purpose, excluding artificial wood

products, which are flame resistant. The materials which have zero surface burning

characteristics shall be used. The design of a powerhouse will include provision for the following:



Fire prevention measures,

Fire detection systems,

Means of escape,

Access for firemen, and

Means of fire fighting.

Accumulation of refuse of any inflammable material like paper and plastic cartons constitute a

major fire hazard and shall not be permitted. Smoking shall be strictly prohibited at all locations

in the powerhouse. All aspects of fire prevention and control will be dealt in close collaboration

with the local fire fighting authorities.

In fire of electrical origin, water cannot be used until the electric system has been made dead

and earthed. For electrical fires, non-aqueous agents like ABC powder, Chloro Bromo Methane

or CO2 gas shall be utilized for fire fighting. Fire extinguishers for this purpose shall be liberally

provided at stationary installations.

Generally, there is often more casualty from smoke inhalation than from burning. Smoke needs

to be transported away from the site of the fire. In order to achieve this, provision for suction of

fresh air into the underground section and for exhaust gases from other sections shall be made.

15.7.4 Soil Erosion Control

Due to the impact of rainfall on open excavation, large areas would be reduced of vegetation of

such lands. Most of the project components are underground. This problem will take care by the

greenbelt proposed.

15.7.5 Cost For Implementing Environmental Management Plan

The total amount to be spent for implementation of environmental management plan (EMP) is

Rs. 140 Lakhs (excluding O&M cost for implementing environmental management plan, cost of

implementing environmental monitoring programme during construction & operation stage). The

summury of cost of each component including the cost of O & M and environment management

programme is given in Table-15.12.



Table–15.12 Cost of Implementing Environmental Management Plan

15.8 ENVIRONMENTAL MONITORING PLAN

Environmental monitoring programme is a vital process of any management plan of the water

resources project. This helps in signaling the likely potential problems to result from the

proposed project and will allow for prompt implementation of effective corrective measures. The

environmental monitoring will be required during construction and operational phases. The

following parameters will need to be monitored:

Water & Waste water Quality

Air Quality

Noise

Minimum Environmental Flow

15.8.1 Water & Waste Water Quality

(i) Construction Phase

The water quality monitoring shall be carried out on regular basis. Frequency of monitoring will

vary from site to time and as we progress during the construction phase and shall be decided

with the help of HPSPCB. The sampling sites shall typically be Colony area, Barrage site;

downstream of Barrage site, submergence area, etc. The monitoring is proposed to be done for

entire period of construction i.e. 3 years.

Frequency of Sampling & no of identified locations-Water Quality:

The water quality monitoring shall be carried out in Quarterly intervals i.e. four times a year. Four

sampling sites have been identified i.e. upstream of barrage site, downstream of barrage site,

S.No. Item Cost in Lakhs

1 Compensatory afforestation 11.96

2 Provision of Fuel Supply 23.64

3 Redressal of Muck Disposal site 0.66

4 Health facilities 91.64

5 Training & Extension 5.18

6 Redressal of Construction Areas 2.25

7 Environment Monitoring Plan 4.93

Total 140.00



upstream of powerhouse and downstream of powerhouse. The total cost for analysis of samples

work out to Rs.1.44 lakhs per year (@ Rs.9000/- per sample i.e. Rs.9000/- x 4 sites x 4

Quarters).

Frequency of Sampling & no of identified locations-Waste Water Quality:

The waste water quality monitoring shall be carried out in Quarterly intervals i.e. four times a

year. One sampling sites have been identified i.e. from worker colony. The total cost for analysis

of samples work out to Rs.0.12 lakhs per year (@ Rs.3000/- per sample i.e. Rs.3000/- x 1 sites x

4 Quarters).

(ii) Operation Phase

Frequency of Sampling & no of identified locations-Water Quality:

The water quality monitoring shall be carried out in Quarterly intervals i.e. four times a year. Two

sampling sites have been identified i.e. upstream of barrage site, TRT out fall /downstream of

powerhouse. The total cost for analysis of samples work out to Rs.0.72 lakhs per year (@

Rs.5000/- per sample i.e. Rs.5000/- x 2 sites x 4 Quarters).

Frequency of Sampling & no of identified locations-Waste Water Quality:

The waste water quality monitoring shall be carried out in Quarterly intervals i.e. four times a

year. One sampling sites have been identified i.e. from worker colony. The total cost for analysis

of samples work out to Rs.0.12 lakhs per year (@ Rs.3000/- per sample i.e. Rs.3000/- x 1 sites x

4 Quarters).

15.8.2 Air Quality


The ambient air quality monitoring during construction phase will be carried out through State

Pollution Control Board or any agency approved by them. Every year monitoring is to be done in

Quarterly. Four sampling sites have been proposed for monitoring.

A total budget of Rs.0.64 lakh/year (@ Rs.4000/- per sample per season i.e. Rs.4000/- x 4

stations x 4 Quarters) has been earmarked for air quality monitoring for 3 years.


During operation stage, two sampling sites have been proposed for monitoring Same schedule

and rates, as followed during construction phase, would be continued for operation phase as

well. A total budget of Rs 0.32 lakh/year (@ Rs.4000/- per sample per season i.e. Rs.4000/- x 2

stations x 4 Quarters) has been earmarked for air quality monitoring.



15.8.3 Noise


Noise emissions from vehicular movement, operation of various construction equipments August

be monitored during construction phase at major construction sites. The frequency of monitoring

could be once in Quarterly. Therefore for this purpose a lumpsum amount of Rs.1.00 lakh per

year has been earmarked for noise level monitoring for 3 years.


Noise monitoring also carried during operation phase at Barrage, power house sites etc.

For this purpose a lumpsum amount of Rs.0.50 lakh per year has been earmarked to be carried

out during operation.

15.8.4 Minimum Environmental Flow

(i) Operation Phase

During operation phase of the project, most crucial environmental aspect is the monitoring of

flow released from the project to ensure that minimum flow is maintained at all times. Therefore,

monitoring mechanism will be established as per the requirement of HPSPCB to monitor river

flow immediately downstream of the diversion structure.

(ii) Financial Requirement

A sum of Rs 140 lakhs has been allocated to implement various activities and programme

envisaged under EMP and the details are given in Table 15.12. The detailed matrix of EMP

listing all the activities to monitored and implementing agency has been given in Table 15.13.

Table–15.13 Cost Estimates for Environmental Monitoring Programme

S.No. Item to be Monitored Parameters Monitoring Agency

Budget (Rs. Lakhs)

Construction Phase

1 Ambient Air Quality SO2, NOx, PM10, PM2.5 etc. HPSPCB 1.92

2 Noise Quality Monitoring Sound Levels HPSPCB 4.32

3 Waste Water Quality Monitoring BOD, COD, TSS, O&G, pH etc. HPSPCB 0.36

4 Water Quality Monitoring pH, TSS, DO & Conductivity HPSPCB 1.00

Total Amount 7.60

Operation Phase

1 Ambient Air Quality SO2, NOx, SPM HPSPCB 12.80

2 Noise Quality Monitoring Sound Levels HPSPCB 28.80

3 Waste Water Quality Monitoring BOD, COD, TSS, O&G, pH HPSPCB 4.80

4 Water Quality Monitoring pH, TSS, DO & Conductivity HPSPCB 20.00



S.No. Item to be Monitored Parameters Monitoring Agency

Budget (Rs. Lakhs)

5 Release of Minimum Flow Inflow & Release in river at diversion structure

HPSPCB 25.00

Other Monitoring Activities

1 Reporting, Documentation of Various activities, submission of six monthly monitoring reports

20.00

Total Amount 86.40

Note: Above mentioned cost against Monitoring is based on the HPSPCB suggested costs for

monitoring, this August be revised based on the actual estimate received from HPSPCB during

construction & Operation of the project.

15.9 CONCLUSION

The BHEP-I Project is considered environment - friendly since it does not involve any large

submergence of areas, no resettlement and rehabilitation, minimal disturbance to the natural

habitat and provides environment - friendly industrial growth in a very poor region of the country.

Above all, the proposed project is a run-off-the-river scheme with relatively less gestation period

which will provide peaking power to the power starved Northern Region of the country.

ECOLOGICAL ASPECTS OF HYDRO-ELECTRIC PROJECTS

1 Detailed Basic Information affecting the environment

1.01 Predominant existing land-use pattern (agricultural land;

Reserve and other forests, etc.) in project area or upto

100 km. upstream, whichever is less.

The existing landuse pattern in the land to be

acquired for project region is around 41.40% in

government/forest land, 53.26% in snow-

covered land

The detailed breakup of the project catchment

is as follows:

Agriculture/Private land: 15 km2

Forest (Government land): 195 km2

Snow-covered land: 261 km2

Total Catchment: 471 km2

1.02 Break up of submerged area: Total submerged area: The project is a run-of-the-river scheme and

therefore the submergence involved is minimal.

Forest/ Government land Not Applicable.

Cultivated land Not Applicable

Shrubs & Fallow Not Applicable

Rocky outcrop Not Applicable

Wetland Not Applicable

Open Water Not Applicable

Other use Not Applicable



1.03 (a) Forest type in catchment and submerged areas:

(indicate type of trees, whether sparse or thickly

wooded and other details)

The project catchment consists of reserved

and unreserved forests with the major species

being Deodar, Pine, Oak, Silver Fir, Cyprus

sp., Mulberry, Raspberry, etc . Open

scrublands with small bushes also exist.

(b) Extent and nature of forest to be cut for the

construction of roads, colony and other appurtenent

works.

Degraded unreserved forest land to the extent

of about 12.65 ha. is required to be cleared for

construction of various project components.

Measures for compensatory afforestation and

catchment area treatment have been proposed

in this report.

1.04 Duration of project construction stage: 36 months

1.05 Estimated Peak labour strength: Estimated peak strength is 150 people.

40 skilled

110 unskilled

Locally available labour force would be

preferentially employed for project

construction. Skilled & specialist labour about

40 in number would be drawn from nearby

areas like Chamba and Harsar. As the area

has seen the construction of the Chamera –

I,IIand III projects, it is very likely that skilled

labour would be locally available.

Local unskilled labour of about 110 shall be

employed.

Skilled

Unskilled

Labour to be recruited from affected population

Skilled

Unskilled

1.06 Population density in the area per sq. km. The area is very sparsely populated with an

average population density of 0.29 persons per

hectare, i.e. 29 people per 100 hectare.

1.07 Number of villages and population to be displaced; No displacement of population and villages

No. of villages NIL

Size of villages NIL

Affected families in each village NIL

ST NIL

SC NIL

Other NIL

Occupation of the affected people: NIL



Agriculture, Industrial labour, artisans, forest based,

others…

NIL

Owner cultivators by size of land holdings: NIL

Marginal (1.0 - 2.5 hect.) Not Applicable

Small (1.0 - 2.5 hect.) Not Applicable

Medium (2.5 - 5.0 hect.) Not Applicable

Big (over 5.0 hect.) Not Applicable

1.08 Resettlement As per the survey, resettlement is not involved.

Is a rehabilitation committee being constituted: Not applicable

Existing guidelines, if any for compensation in cash &

kind

Number of oustee families likely to be settled in new

settlements:

Size of proposed new settlements

Layout plans/ Master plans for new settlements:

Distance of new settlements from the present habitat: Not applicable

1.09 Number and facilities (eg. School, post offices, bank,

panchayat ghar, police station, approach road,

drainage, and water supply, etc.) proposed to be

provided:

Not applicable

1.10 Is the affected area covered by development

programmes like IRD, SFD, Drought prone area, tribal

development. Etc.

No

Any proposals to provide / create employment for

oustees:

No project oustees as per the survey report.

Nature and quantum of employment to be provided: Not Applicable

Vocational training programmes envisaged, if any: Not Applicable

1.11 What is the expected rate of Sandation? Average rate of Sandation is around 250-300

ppm. In heavy monsoons, it can increase to

around 1000 ppm.

Details of how the Sandation problem is proposed to be

handled

Sandation is proposed to be handled by

vegetating the barrage face and treating the

catchment for soil erosion by the catchment

area treatment plan.



1.12 Is downstream area subject to flooding? No

1.13 Wind rose at Dam Site (Diagram giving statistical

information concerning the direction and speed of the

wind at the site)

Wind at barrage site normally blows from east

to west direction.

1.14 Hurricane, tornadoes, cyclones NIL

Frequency of occurrence Not Applicable

Wind velocity: Average Not Applicable

Maximum Not Applicable

1.15 Plan of area, on the reservoir periphery, subject to

erosion, slides and slips:

Run-of-the-river scheme, therefore, Not

Applicable.

1.16 The depth of ground water table

Maximum Not Applicable.

Minimum Not Applicable.

Quality of ground water:

Potable/non-potable, fit for irrigation or industry Fit for irrigation and drinking purposes.

1.17 Present ground water use pattern in the command area

under irrigation

The project is solely meant for generation of

hydropower and is not an irrigation project.

1.18 Based on the experience of similar projects in the area,

specify the interaction between the altered surface

water patterns and underground acquifers and their

recharge.

Being Run-of-the-river scheme, there is no

alteration of underground water patterns. A

minimum surface discharge of 15% of the

stream average lean season inflow will be

maintained to sustain the aquatic ecology of

the stream.

2 Environmental Status

2.01 a) Indicate known pollution sources in the region: (indicate the industries like chemicals, textiles and others, thermal power units, mining operations, etc.)

Nil

b) Indicate the industrial and other development projects

likely to be taken up in the area during the next five to

ten years.

Small and cottage industries, Tourism projects,

service and fabrication units to be executed by

the State Government.

2.02 a) Does the area support economically viable aquatic

life - fish, crocodiles?

Yes. Brown trout is seen in the Budhil stream.



b) Are there any fish/crocodile breeding grounds in the

river/tributaries in the submergence area?

Not Applicable

2.03 Does the site contain a wildlife (including birds) habitat,

breeding area, feeding area, migration route including

the number of wildlife available in the area.

No.

2.04 Is the site a potential wild life sanctuary? The Kugti wildlife sanctuary lies about 3.5 km. from project intake site and the Tundah wildlife sanctuary lies about 12.55 km from project site.

2.05 Specifying any rare or endangered species of flora and

fauna found in the affected area alongwith their

approximate number and measures to

salvage/rehabilitate them.

Not Applicable.

2.06 Is the area a tourist resort? Chamba town which is 80 km from the project

site is frequently visited by tourists from all

over.

2.07 Are any mountains / sites of cultural, historical, religious,

archaeological or recreational importance including

wildlife sanctuaries and national parks, etc. likely to be

affected by the proposed project. If so, details thereof.

No. The project will in no way disturb/ disrupt

any wildlife sanctuary.

2.08 Does the proposed area suffer from endemic health

problems due to water/ soil borne diseases?

No.

3 Environmental Impacts

3.01 What measures are planned to develop the site to

enhance its aesthetic aspects (i.e. recreation and water-

sport facilities, and picnic sites, etc.)?

Apart from the measures to be undertaken by

the State Tourism department, proper

landscaping shall be undertaken by the project

authority to merge the project in its natural

surroundings thereby enhancing its visual

appeal.

3.02 Will the project help in flood control reduction or even

eradication of flood havoc downstream?

Not relevant.

3.03 Are any changes in water salinity expected? If yes, give

details of proposed measures to counteract this.

No.



3.04

Are problems of water logging envisaged in the

command area? If so, give details of proposed steps to

combat the problem.

No.

3.05 Will the reservoir be used for fisheries development (fish

culture as well as fish breeding), crocodile farming, etc?

If yes, give details thereof.

No

3.06 Will fish ladders/lifts and like arrangements be provided

to allow movement of important migratory fish

population?

Not Applicable.

3.07 Measures proposed to prevent grazing and cultivation

on reservoir slopes to avoid erosion and pre-mature

Sanding-up of the impoundment.

Not Applicable.

3.08 Will any important natural resources (minerals,

commercial timber, etc) be lost or their use precluded

because of the presence or operation of the project? If

yes, specify the resource and the magnitude of the

estimated loss.

An estimated 12.65 ha of degraded forest land

will be used for construction of project

components. Compensatory afforestation on

25 ha., i.e. double the degraded forest land has

been proposed.

3.09 What is the potential loss in aquatic production on site,

up and downstream? (Fish and other useful aquatic

animals and plants).

Brown trout has been seen in the stream.

However, provision of fish ladders is being kept

for the barrage.

3.10 Will the formation and use of the water body result in

the introduction or enhancement of water borne

diseases?

No.

3.11 Will the impounded reservoir lead to: Not Applicable as the structure is a barrage.

a) Noxious aquatic weeds like salvinia, water hyacinth,

etc.?

Not Applicable

b) Intermittent host (vectors) like snails, mosquitoes,

etc.

Not Applicable

3.12 How will aquatic weeds be controlled in submerged

areas so as to provide an improved habitat for fishery

exploitations.

Not Applicable



3.13 Will the project induce adverse climatological changes

(regarding temperature, humidity, wind and precipitation

including modifications to micro and macro climate)?

No. The project is a run-of-the-river HEP and

will not contribute adversely to the climate of

the area.

3.14 What impact is expected on geological factors (eg.

Seismic impact of reservoir loading?)

Run-of-the-river scheme therefore, no water

impoundment and reservoir induced seismicity

is not applicable.

3.15 Indicate the magnitude of impact due to population

pressure on:

a) Felling of trees for firewood; No felling of trees for the purpose of firewood is

envisaged as provision of fuel supply to the

labour force during construction period has

been proposed by the project proponent..

b) Forest fires Not Applicable.

c) Over-grazing leading to depletion of the pastures Not Applicable.

d) Visual pollution and damage to scenic values NIL. Proper landscaping of construction areas

shall be carried out to merge the project with its

natural surroundings.

3.16 What arrangements are being made:

a) To meet fuel requirements of the labour force during

construction period to prevent indiscriminate felling of

trees for firewood?

Fuel (coal/LPG) from government department

free of cost to the labour force. Therefore, no

felling of trees for the purpose of firewood is

envisaged.

b) For compensatory afforestation? Budget for compensatory afforestation of

double the forestland proposed to be diverted

for the project is proposed.

c) To enforce anti-poaching laws? The construction labour & project staff will be

educated on the relevant anti-poaching laws in

consultation with the forest department. Also,

notice boards will be put up at appropriate sites

to warn people against poaching in the area.

d) To control flow of sediments and pollutants due to

fertilizer and pesticide run-off for cultivated areas;

Not Applicable as this is a hydel project.

e) For restoration of land in construction areas (filling,

grading, and reforestation, etc. to prevent erosion and to

erase the scars), and

Proper landscaping of construction areas shall

be carried out so as to restore & reclaim the

land at dumping areas.

f) For soil conservation in the catchment? A complete catchment area treatment has to

be prepared in consultation with the Chamba

Forest Division for soil conservation in the

catchment to prevent soil erosion. The exercise



would include afforestation and civil

engineering measures.

4 Cost of Environmental studies, Project management

and Monitoring:

4.01 Provision for Environment Studies / surveys needed for

this project

Adequate compensation measures have been

defined as per this report for probable impacts

of the project on the environment.

4.02 Cost of proposed remedial and mitigative measures, if

any, to protect the environment.

A provision has been incorporated in the

project budget to cover cost of afforestation

activities, redressal of constructed project

areas, provision of alternate fuel for labour,

cost of environmental & monitoring cell, etc.

4.03 Has the cost of environmental studies / protection

measures been considered in the cost-benefit analysis

of the project?

Yes. Due consideration has been made during

site selection so that any adverse socio-

environmental impact may be kept to the

minimum.

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 16-Rate Analysis


16. RATE ANALYSIS

16.1 GENERAL

The analysis of unit rate for various items of civil works is based on the standard practices,

guidelines and following assumptions

Guidelines for preparation of estimates for the river valley project” issued by CWC and

Indian standard IS: 4877 “ Guide for preparation of estimate for River valley project

The analysis of rates for various items have been worked out in consideration of the cost

of materials, carriage, handling, storing, labor and equipment required for various items of

work and including overheads.

Overhead charges and contractor’s profit have been kept at 20% in accordance with

guidelines.

The Base line of estimate is based on August 2014 price level and all costs are expressed

in Indian rupees.

16.2 METHODOLOGY

Basic rate of various materials have been considered at nearest available locations to the

project site. For these basic rates, other charges like carriage, handling, storing, labor and

equipment required for various items of work and including overheads are added to estimate the

rate of the items at BHEP-I Power House site. For these rates, material transporation charges

upto the diversion site are added to obtain the rates at diversion site. Detailed analysis of various

items at Diversion site and Power house site are presented in Annexure-16.1.



Annexure-16.1

S No. Item Description

Use Rate per hour-2014 Level

1 Compressed Air for 100 cfm Rs. 183.00

2 a) Heavy Duty Jack Hammer 120 cfm Rs. 599.00

3 Heavy Duty Pavement Breaker Rs. 522.00

4 AutoFeed Rs. 95.00

5 Drilling Platform(rail mounted) Rs. 3,996.00

6 L 2D Boomer/Drill Jumbo Rs. 5,220.00

7 Muck Car 1.0 cum capacity Rs. 1.50

8 Convey Mucker 0.38 cum capacity(electric) Rs. 737.00

9 Battery Locomotive 3.5 Tonne Rs. 675.00

10 Rear Dumper 15 Tonnes (8.33 cum) Rs. 1,334.00

11 Rear End Tipper (4.5 cum) Rs. 942.00

12 Material Truck 10 Tonne Rs. 39.00

13 Crawler dozer 180 HP Rs. 1,857.00

14 Crawler/Tractor dozer 90 HP Rs. 1,565.00

15 Front End Loader 1.50 cum Rs. 2,000.00

16 Hydraulic Excavator 1 cum Rs. 1,694.00

17 Diesel Shovel 1.15 cum Rs. 1,352.00

18.1 Electric Shovel 1.91 cum Rs.

18.2 Electric Shovel 3 cum Rs. 3,132.00

18.3 Disel Shovel 3 cum Rs. 6,355.00

19 High Pressure grout pump Rs. 942.00

20 Shortcrete machine 10 cum Rs. 4,522.00

21 Concrete pump 5cum/hr capacity Rs. 795.00

22.1 Transit Mixer 2.0 cum(Truck mounted) Rs. 1,500.00



23 Portable Concrete pump 25 cum/hr. capacity Rs. 2,380.00

24 Centrifugal Pump 20 HP Rs. 415.00

25 Centrifugal Pump 10 HP Rs. 264.00

26 Batching and Mixing Plant 40 cum/hour capacity Rs. 1,729.00

27 Batching and Mixing Plant 25 cum/hour capacity Rs. 1,667.00

28 Batching and Mixing Plant 10 cum/hour capacity Rs. 889.00

29 Ventilation Blower 5000 cfm Rs. 159.00

30 Ventilation Blower 10000 cfm Rs. 185.00

31.1 Aggregate processing and classification plant 30 T Rs. 2,839.00



32 Raise Climber Rs. 3,595.00

33 Snow Cutter Rs. 1,794.00

34 Wagon drill/Air Track Rs. 1,480.00

35 Tower Crane(5cum) Rs. 1,886.00



Working Rates for Principal Items of Civil Works

S No. Description Rates

1 POL Charges (per Ltr) Rs. 64.00

2 STEEL REINFORECEMENT/STRUCTURAL STEEL

2.1 Fabrication and erection of steel reinforcement (Except PH) Rs. 63,029.00

2.2 Fabrication and erection of steel reinforcement (in PH) Rs. 64,000.00

2.3 Fabrication & Erection of Structural Steel (Per MT) (in PH) Rs. 82,593.00

2.4 Fabrication & Erection of Structural Steel (Per MT) (in PH) Rs. 95,135.00

2.5 Hand Rails Rs.

2.6 Fabrication & Erection of Penstock Steel Liner Rs. 1,04,983.50

3 DRILLING Rs.

3.1 Drilling Holes by Jack Hammer upto 5m depth(per meter) Rs. 277.00

3.2 Drilling Holes by Wagon Drill(per meter) Rs. 257.00

4 EXCAVATION Rs.

4.1 Excavation in over burden & loose rock (per cum) Rs. 196.00

4.2 Excavation in rock (unit per cum) Rs. 417.00

4.3 Rock Excavation in tunnel / horizontal penstock (per cum) Rs. 2,450.00

4.4 Excavation of Surge Shaft Rs. 2,750.00

4.5 Excavation of Pressure Shaft by topdown Method Rs. 3,250.00

5 BACK FILLING

5.1 Placing earthfill material for Coffer Dam & Barrage-embankment(per cum)

Rs. 258.00

5.2 Stone Pitching (hand packed) Rs. 640.00

5.3 Stone fill crates in wire nets Rs. 1,040.00

6 MASONARY WORK

6.1 Stone Masonary in Cement Mortar 1:3 Rs. 2,843.00

6.2 Stone Masonary in Cement Mortar 1:6 Rs. 2,521.00

7 ROCK BOLTING

7.1 Rock Bolting Rs. 660.00

7.2 Rock Bolting 4.0 m long in surge shaft Rs. 900.00

8 GROUTING

8.1 Consolidation Grouting Rs. 912.00

8.2 Contact Grouting Rs. 1,112.00

8.3 Dewatering Rs. 20.00

9 CONCRETE

9.1 - Barrage, Intake & Desilting Tank (Surface Works)

9.1.1 M-10 Rs. 4,746.00

9.1.2 M-15 Rs. 5,381.00

9.1.3 M-20 Rs. 6,146.00

9.1.4 M-25 Rs. 7,374.00

9.2 - In Tunnel

9.2.1 M-10 Rs. 4,498.00



9.2.2 M-15 Rs. 5,623.00

9.2.3 M-20 Rs. 6,388.00

9.2.4 M-25 Rs. 7,766.00

9.3 - Power House

9.3.1 M-15 Rs. 5,685.00

9.3.2 M-20 Rs. 6,459.00

9.3.3 M-25 Rs. 7,706.00

10 SHOTCRETE

10.1 Shotcreting Sqm Rs. 604.00

10.2 Shotcreting with wiremesh Rs. 1,666.00



ANALYSIS OF RATES FOR ITEMS OF CIVIL WORKS

Supply of HSD (Unit per Ltr) I) Cost of HSD per KL at Gagal HSD including Sales tax @ 7%

60,990.00

II) Carriage of HSD from Gagal HSD Depot to stores at Project site@Rs. 28.00/km by trucks of 10 T capacity having lead of 300 km one way

29.00 10.00 300

Sub-Total 60,990.00

vi)Storage charges at Project stores @ 3% 1,829.70

vii)Loading & Carriage from Store to Work site by truck @ Rs.28.00/km having an average lead of 6 kms one way

29.00 10.00 6

viii) Unloading & stacking at work site 50.00

ix)Supervision Charges@2% (item I to viii) 1,257.39

Total Cost per M 64,127.09

Cost per Ltr 64.13

Say 64.00

Supply of Cement (Unit per Bag) I) Cost of Cement per MT at Gagal Cement including Sales tax @ 8%

6,000.00

ii) Cost of Additive for reducing Alkali

iii) Loading in Truck per MT 50.00 iv) Carriage of Cement from Gagal Cement Factory to stores at Project site@Rs. 28.00/km by trucks of 10 T capacity having lead of 300 km one way

29.00 10.00 300

v)Unloading&stacking of stores 50.00

Sub-Total 6,100.00

vi)Storage charges at Project stores @ 2% 122.00

vii)Loading & Carriage from Store to Work site by truck @ Rs.28.00/km having an average lead of 6 kms one way

29.00 10.00

6

viii) Unloading & stacking at work site 50.00

ix)Supervision Charges@2% (item I to viii) 125.44

Total Cost per MT 6,397.44

Cost per Bag 319.87 Say 320.00



Supply of TOR Steel reinforcement (per MT) i) Cost for TOR Steel at Jallandhar stockyard including Sales tax @ 2%

47,430.00

ii)Loading in Truck iii)Carriage from Chandigarh to stores at Project site @ Rs. 29 /km by trucks of 10 T capacity having lead of 275 km one way

29.00 10.00 400.00 2,320.00

Sub Total 49,750.00 iv)Storage charges at Project stores @ 3%

1,492.50

v)Unloading&stacking at Project site per MT

Sub-Total 51,242.50

Hence rate of TOR steel reinforcement per MT at project store

51,242.50

Say 51,243.00 Supply of Structural Steel (per MT) i) Cost for Structural Steel at Jallandhar stockyard including Sales tax @ 4%

45,000.00

ii)Loading and Carriage from ChandiGARH at Project site @Rs. 29 /km by trucks of 10 T capacity having lead of 275 km one way

29.00 10 400 2,320.00

Sub Total 47,320.00 iii)Storage charges at Project stores @ 3% 1,419.60 iv)Unloading&stacking at Project site per MT 1,000.00 Sub-Total 49,739.60 Hence rate of Structural steel per MT at project store

49,739.60

Say 49,740.00 Fabrication and erection of steel reinforcement (per MT) (Except Power House)



A. Materials

i) Cost of steel bars at site 51,243.00 ii) Add for wastage & incidentals to work @ 2.5 % of (I) above 1,281.08

Total of item (A) 52,524.08

B. Handling & Placing

(I) Bending & Cutting @ 4% of (A) above 2,100.96 (ii) Handling @2.5% of (A) above 1,313.10 (iii) Placing & Welding @ 3% of (A) above 1,575.72 (iv) Bending Wire and other material @3% of (A) above 1,575.72

Total of item (B) 6,565.51 Abstract of charges

A. Materials 52,524.08

B. Handling and Placing 6,565.51 Prime Cost 59,089.58 Add over head charges and contractor's profit @20% of

handling and placing charges + 5% handing charges for steel 3,939.31

Grand Total 63,028.89 say 63,029.00

\



Fabrication and erection of steel reinforcement (per MT) (in Power House)

A. Materials

i) Cost of steel bars at site 51,243.00 ii) Add for wastage & incidentals to work @ 2.5 % of (I) above 1,281.08

Total of item (A) 52,524.08

B. Handling & Placing

(I) Bending & Cutting @ 4% of (A) above 2,100.96 (ii) Handling @4% of (A) above 2,100.96 (iii) Placing & Welding @ 3% of (A) above 1,575.72 (iv) Bending Wire and other material @3% of (A) above 1,575.72

Total of item (B) 7,353.37 Abstract of charges

A. Materials 52,524.08

B. Handling and Placing 7,353.37 Prime Cost 59,877.45 Add over head charges and contractor's profit @20% of

handling and placing charges + 5% handing charges for steel 4,096.88

Grand Total 63,974.32 say 64,000.00



Fabrication & Erection of Structural Steel(Per MT) (Except Power House)

A. Materials Cost of 1.025 MT structural steel at project store

including 2.5% wastage and incidentals to work 49,740.00

1.03 50,983.50

B. Fabrication i) Marking rolled [email protected]% the cost of steel(A)

above

1,274.59

ii)Cutting @3% of (A) above 1,529.51 iii)Bending of rolled section@5% of (A) above

2,549.18 iv)Welding a) Cost of electrodes including rejects @7% of (A)

above

3,568.85 b)Labour and electric charges @8% of (A) above 4,078.68 c)Handling of material during fabrication @4% of (A)

above

2,039.34 d)Temporary fixture @6% of (A) above 3,059.01 Total Welding charges (a+b+c+d) 12,745.88 Total fabrication charges (i+ii+iii+iv) 18,099.14

C. Erection Transportaion of material out of workshop,

operation handling final matching and field welding etc. @12% of (A) above.

6,118.02

Prime cost (A+B+C) 75,200.66 Add over head charges and contractor's profit

@20% of Fabrication and Erection charges + 5% handing charges for steel

7,392.61

Rate per MT, Grand Total 82,593.27 Say 82,593.00



Fabrication & Erection of Structural Steel(Per MT) (in Power House)

A. Materials Cost of 1.025 MT structural steel at project store

including 2.5% wastage and incidentals to work 49,740.00

1.03

50,983.50

B. Fabrication

i) Marking rolled sections@4% the cost of steel(A) above

2,039.34

ii)Cutting @4% of (A) above 2,039.34 iii)Bending of rolled section@6% of (A) above 3,059.01 iv)Welding a) Cost of electrodes including rejects @9% of (A)

above

4,588.52

b)Labour and electric charges @12% of (A) above 6,118.02 c)Handling of material during fabrication @8% of (A)

above

4,078.68

d)Temporary fixture @10% of (A) above 5,098.35 Total Welding charges (a+b+c+d) 19,883.57 Total fabrication charges (i+ii+iii+iv) 27,021.26

C. Erection Transportaion of material out of workshop,

operation handling final matching and field welding etc. @15% of (A) above.

7,647.53

Prime cost (A+B+C) 85,652.28 Add over head charges and contractor's profit

@20% of Fabrication and Erection charges + 5% handing charges for steel

9,482.93

Rate per MT, Grand Total 95,135.21 Say 95,135.00



Drilling Holes by Jack Hammer upto3 m depth(per meter)

Cost of drilling Use Rate of Jack Hammer with Auto-feed per hour 99.00

Average rate of drilling 35mm dia holes per hour

i)Rate of drilling per meter 3.00 199.67

ii)Cost of drill rod per meter of drilling 24.00 iii)Labour, lighting & scaffolding etc @40% of sub item(ii) 9.60 iv)Ventilation & workshop charges @30% of sub-item(ii) 7.20 Prime Cost (i+ii+iii+iv) 240.47 Add overhead charges and contractor's profit @15% of Prime Cost 36.07 Total 276.54 Say 277.00

Drilling Holes by Wagon Drill(per meter)

Cost of drilling per meter 1,480.00 Average rate of drilling per hour 20.00 Considering 50% progress due to space limitations, expected

progress per hour 10.00

I)Cost of drilling 148.00 ii)Cost of drill steel per meter 42.00 iii)Cost of changing of drill steel @40% of sub item(ii) 16.80

iv)Ventilation & Lighting charges@40% of sub-item(ii) 16.80 Prime Cost (i+ii+iii+iv) 223.60 Add overhead charges and contractor's profit @ 15% of

Prime Cost 33.54

Total 257.14 Say 257.00



Excavation in over burden & loose rock (per cum) Actual output per hour (cum) 80.00 Dumper 15Tcapacity (cum) 8.33 Machinery charge a)Shovel Use rate per working hour

2,029.00

Output per working hour 50.00

Rate per cum = Use rate of shovel / 60 40.58 b)Dumper 8.33 Average lead(Km) 1.00 Swell factor 0.78 Body capacity = 8.33 x 0.78 6.50 Say Cycle time: i)Loading time, in min = Body capacity / Shovel output 7.80 ii)Spotting time, in min 0.50 iii)Turning & dumping time, in min 2.00 iv)Empty haul @20km/hr = (1.0 x 60) / 20 20.00 3.00 v)Loaded haul @15km/hr = (1.0 x 60) / 15 15.00 4.00 Total cycle time, 17.30 No. of dumper trips in 50 min 50.00 2.89 working hour = 50 / 11.70 Output of dumper per working hour 18.78 Use rate of dumper 1,334.00 Hence rate per cum 71.03 c)Tractor dozer at site of excavation 180 HP capacity

Assuming that one shovel will work at one place and one tractor dozer will be enough for one shovel

Output of shovel, in cum 50.00



Use rate of tractor dozer per working hour 1,857.00 Rate per cum, 4085 / 60 37.14 Total machinery charges (a+b+c) Rs.

148.75 Electric energy @ 2% , Haul roads @ 5%, and levelling & trimming @ 3% charges

14.87

Prime cost Rs. 163.62 Add overhead charges & contractor’s Profit @20% of prime cost

Rs. 32.72

Total Rs. 196.34 Say Rs. 196.00



Excavation in rock (unit per cum)

A. Drilling and blasting

a) Drilling charges Rock drilling for excavation will be carried out by the jack hammer on the basis of Table 13.4 on page 370 of construction

planning, equipment and methods by R.L. Peurifory (Fifth Edition). Drilling and blasting data are as follows considering one linear ft. (0.3 m) hole sufficient for blasting 0.93 Cu. yd. (0.70 cum) of rock

Size of Hole in mm Hole pattern meter

Area per hole Sq m

Quantity of Rock

per linear meter of hole in

cum

Quantity of explosives per linear meter of hole in

kg

kg of Explosive per cum of rock

% of hole drilled

1.00

0.75

0.50 1 2 3 4 5 6 7 8 38.00 1.52x1.52 2.31 2.31 1.34 0.58 0.43 0.28

Depth of drilling per 100 cum of rock = 100 /2.31

43.29

meter

Horizontal drilling and pull effect =

43.29 x (50%)

21.65 meter

Total drilling per 100 Cum of rock

64.94 meter

Say 65.00 meter Cost of drilling

Rate of drilling per hour 6.00 meter 277.00 Cost of drilling by jack hammer

18,005.00

b)Cost of drill steel

Cost of drill steel per meter 18.00

Cost of drill steel for 65 meter drilling = 18 x 65

1,170.00

c)Blasting i)Cost of gelatine/kg

72.00

Assuming that the drill holes can be filled with dynamite to upto 50% of their capacity, the quantity of explosive required per100 cum of rock

Cost of 28 kg. gelatine@ 72.00 28.00 2,016.00 ii)Cost of electric detonator 16.50

Average depth of hole(Meters) 1.75

Quantity of rock per linear meter of hole (cum)

2.31

Quantity of rock per 1.75m deep hole = 1.75 x 2.31 4.04

No of holes required per 100 cum = 100 / 4.04 24.74

Say 25.00 Using one detonator per hole then no.

of detonators per 100 Cum rock 1.00 25.00



Cost of 25 Nos. electric detonators @Rs.16.50 each

= 25 x 16.50

412.50

iii) Blasting batteries, primer, prime

cord and lead wires etc. per 100 Cum. @ 30% of cost of detonators

123.75

iv) Stemming charges @30% of cost of detonators

123.75

Total Charges blasting (i) to (iii) 2,676.00

= 2016 + 412.50 + 206.25 + 165 Total charges for drilling, blasting

including cost of drill steel (a+b+c) 21,851.00

=13,975.00 + 1560.00 + 2799.75 Hence rate for drilling & blasting 100

cum 21,851.00

Add for secondary drilling and blasting @8.5%

1,857.34

Total 23,708.34 Hence rate for 100cum 23,708.00 B. Carriage of blasted rock

a)Diesel shovel capacity 1.15

Dumper 15 T 8.33

Cum

Swell factor 0.67

Machinery charges

i) Shovel 1.15 cum

Use rate of shovel per working hour 1,352.00

Output per working hour 80.00

Rate per cum 16.90 b) Dumper 15 T capacity

Average lead 1.50

Swell factor 0.67

Body capacity = 8.33 x 0.67 5.58 Cum

Cycle time

i) Loading time = 5.58 x 60 /60 5.58 min

ii) Spotting time 0.50 min

iii) Turning and dumping time 2.00 min

iv) Empty haul @20 km/hr 3 min



20.00

v) Loaded haul @15km/hr. 15.00

4.0 min

Total cycle time 15.08 min

No. of dumper trips per working hour of 50 min.

50.00

3.32

Output of dumper per working hour 18.50

Use rate of dumper per hour 1,334.00

Hence rate per Cum. 72.09

Say 72.00

c)Tractor dozer at site of excavation 90 HP capacity

Assuming that one shovel will work at one place and one tractor dozer will be enough for one shovel

Output of shovel 80.00

Use rate of tractor dozer/hr 1,565.00

Rate per cum 19.56

Total machinery charges(a+b+c) per cum

108.46

= 45.92 + 130.00 + 68.08 Total machinery charges per 100 cum 100.00 10,846.25

Total rate per 100 cum (A+B) 34,554.25

Say 34,554.00

Add for electric energy charges 2% of (A+B) Construction and maintenance of roads @3%

1,727.70

Prime Cost 36,281.70

Add overhead charge and contractor’s profit @15% of prime cost

5,442.26

Grand total 41,723.96

Say 41,724.00 Rate of 100 Cum. of rock 100.00 417.24

Rate of excavation/Cum. 417.00



Rock Excavation in tunnel (per cum) Shape of tunnel- D shaped

Tunnel Finished dia 3.60 m

Thickness of lining excluding Shotcrete

0.30 m

Excavated dia = 3.6+ 2 x 0.2 + 2 x 0.10 + 2 x 0.1

4.40 m

Cross sectional area of tunnel 17.29 sq. m

= (3.14/4 x 4.4x 4.4 /2 + 4.4 x 2.2)

Assumed Progress per cycle 3.00 m / cycle

(This includes drilling, blasting, mucking, rock bolting etc.)

Hence quantity of excavation per cycle

51.87

No. of working shifts of 8 hours each 3.00

Quantity of excavation per shift 17.29

Cycle time

(I) Mapping and Surveying 1.00

(ii) Drilling 3.00 3.98

(iii) Charging and shifting drilling platform 1.00

(iv) Blasting and defuming 1.00

(v) Scaling 1.00

(vi) Mucking and Loading 4.00

(vii) Tunnel support, Rock bolting, Shotcreting, Rib erection and Backfilling

13.00

Total time 24.00

I Direct Labour

Foreman - 1No. 1.00 398.00 398.00

Electrician -1No. 1.00 270.00 270.00

Hole cleaner -1 No. 1.00 180.00 180.00

Mucker- 2 No. 2.00 180.00 360.00

Beldar - 2 No. 2.00 180.00 360.00

Wireman - 1 No. 1.00 270.00 270.00

Explosive chargeman - 1 No. 1.00 270.00 270.00

Helper - 1 No. 1.00 180.00 180.00



Direct labour charges 1,200.00 2288.00

Add for hidden costs @ 50% of direct charges

600.00 1144

Total labour charges 1,800.00 3432.00

Total Labour Charges for3 shifts 10,296.00

Rate of labour/Cum 51.87 198.51

II Machinery charges

S.No. Item No. Working hrs/ cycle

Total Working hrs/ cycle

Unit Rate(Rs.)

Amount(Rs.)

1 Drill Jumbo(Boomer) 1.00 3.00 3.00 5,220.00 15660.002 Grinder 1.00 1.00 1.00 LS 30.003 Convey mucker

/Shovel/Excavator(1.00 Cum) 1.00 4.00 4.00 1,694.00 6776.00

4 Muck cars/Dumpers/Tippers 4.00 4.00 16.00 942.00 15072.005 Dozer 90 H.P 1.00 0.50 0.50 1,565.00 782.50 Total 38320.50 Machinery charges per cum = 51100.00 /

51.84 738.84

III A) Material charges a) Drilling Charges It is proposed that to attain 3 meter

progress per cycle, 3.3 meter hole will be drilled

3.30

Cross-sectional area of the tunnel 17.28

Assume average spacing of holes 0.80

Area of rock cross-section per hole 0.64

Number of holes per face = 17.28 / 0.64

27.00

Total Depth of drilling = 27 x 3.30 89.10

Cost of drill steel = 89.10 x 42.00 3,742.20

Rate of drilling steel/Cum = Total cost / 51.84

72.15

b) Explosives

i) Gelatine required Kg/Cum .00 51.87

Cost of gelatine @ Rs. 52.0/Kg 2.00 72.00

ii) 27 Detonators & fuse coils required for one hole = 27 x 16.50

6.50 445.50



Cost@Rs. 16.50 each

Rate per Cum = 445.50 / 51.87 8.59

iii)Other consumables etc., at 50 % of b (i) above

36.00

Total charges for explosives 116.59

Total Drilling and Blasting charges (a+b)

188.74

B) Provision for pipe lines for air &

water for wet drilling per cum LS 20.00

C) Misc. supplies such as wire ropes , clamps etc.

20.00

D) Cost of concrete , timber , steel

etc for temporary supports 20.00

Total Material charges (A+B+C+D) 248.74 = 188.74 + 60.00 + 60.00 + 60.00

IV Charges for ventilation Hourly use rate 5 H.P.blower with

250 m long pipe 159.00

Assuming that 7 blowers will be working per face

Hourly use rate of blower system = 7 x 160

1,113.00

Charges for blowers per cycle = 15 x 1120

16,695.00

Rate per cum = 16800 /51.84 321.89

V. Shop Charges

i)Structural shop 25.00

ii) Machine shop including Foundry and Smithy LS

25.00

iii)Air and water pipe shop 25.00

iv)Carpentary shop 25.00

v)Steel metal shop 25.00

Total shop charges/cum 125.00

VI. Misc. Charges i)Electrical material 30.00

ii)Track/Road mentaince charges 40.00



iii)Compressed air charges 25.00

iv)Water charges 25.00

v) Drill steeel charges 150.00 Total Misc. charges/cum 270.00

Abstract of charges Direct labour charges 198.51

Machinery charges 738.84

Material charges 248.74

Ventilation charges 321.89

Shop charges 125.00

Misc. charges 270.00 Total charges 1,902.99 Add for construction & maintenance

of haul roads at 5% of total charges 95.15

Add for electric energy at 2% 38.06 Total prime cost 2,036.20 Add 20% for profit/overheads 407.24 Total 2,443.44 Say 2,443.00



Excavation of Pressure Shaft by Top down Method

Shape of tunnel - Circular

Excavated dia (Meters) 4.20 m

= 2.8 + 2 x 0.60 + 2 x 0.10

Cross sectional area of shaft (Sq. meters)

13.85 Sq .m

= 3.14 x 4.2 x 4.2

Progess per cycle (Meters) 1.00 m

Excavation per metre 13.85

Depth of drill holes for 3.0 m pull 3.25 m

No. of drill holes 33.23 say 34.00

Drilled meters/cycle = 34*1.25 110.50

Three jack hammers can be mounted on the Raise Climber with effective rate of drilling of about 4 m/hr (Hrs) = 82.5 / (3 x 4)

9.21

Cycle time

Preparation time(Hrs) 1.50

Drilling time(Hrs) 3.00

Charging and blasting(Hrs) 1.00

Ventilation(Hrs) 1.20

Scaling & rock bolting(Hrs) 2.50

Mucking & loading (Hrs) 12.00

Total time(Hrs) 21.20 say 22.00 hrs

No. of 8 hrs shift 2.75

Direct labour

Foreman - 1No. -

398.00 -

Electrician -1No. 1.00 270.00 270.00

Explosive loader -1 No. 1.00 180.00 180.00

Hole cleaner -1 No. 1.00 180.00 180.00

Helper to Electrician -1 No. 1.00

180.00

180.00



Wireman -0 No. - 270.00 -

Explosive chargeman -1 No. 1.00 270.00 270.00

Mucker - 3 No. 3.00 180.00 540.00

Beldar -3No. 2.00 180.00 360.00

Direct labour charges 1,980.00


990.00

Total Labour Charges 2,970.00

Total Labour Charges for 2.25 shifts 8,167.50

Cost of Labour/cum 196.61

Say 197.00


Sr.No. Item No. Working hrs/

cycle


Unit Rate (Rs.)

Amount (Rs.)

1 Power winch(10T) 1.00 15.00 15.00 500.00 ,500.00

2 Jack hammers 3.00 10.00 30.00 599.00 17,970.00

3 Convey mucker /Shoval(1.0 Cum) -

4.00 - 1,694.00 -

5 Muck car/Tsippers 1.00 4.00 4.00 942.00 3,768.00

6 Scaling etc LS 100.00

7 Dozer 90 H.P 1.00 0.50 0.50 ,565.00 782.50

Total 30,120.50

Machinery charges per cum 725.06

III Material charges

a) Drilling Charges

Cost of drill steel @ Rs. 42.00 per m = 82.5 x 42.00 4,641.00

Rate of drilling steel/Cum = 3465.00 / 41.55

335.15

b) Explosives

i) Gelatine required/Cum 1.00 72.00 72.00

Cost of gelatine@ 72.0/Kg

ii) Detonators & fuse coils required for one hole

25.00 16.50 412.50

Cost@Rs. 16.50 each



Rate per Cum ' = 412.50 / 41.55 29.79

iii) Other consumables etc., at 50 % of b (i) above

36.00


Total Drilling and Blasting charges (a+b)

- 472.94

c) Provision for pipe lines for air & water

35.00

d) Misc. supplies such as wire ropes , clamps etc.

35.00

e) Cost of concrete , timber , steel etc for temporary supports

35.00

Total Material charges (a+b+c+d+e) 577.94

IV Charges for ventilation

Hourly use rate 5 H.P.blower with 250 m long pipe

159.00


Hourly use rate of blower system 4.00

636.00

Charges for blowers per cycle 20.00

2,720.00

Rate per cum =9600 / 41.55 918.58

V. Shop Charges

I)Structural shop 25.00

ii)Machine shop 25.00





VI. Misc. Charges

I)Electrical material 25.00

ii)Track charges 25.00





Total Misc. charges/cum 100.00

Abstract of charges

Direct Labour charges 197.00

Machinery charges 725.06



Shop charges 125.00

Misce. Charges 100.00

Total 2,643.58

Add for construction & maintenance of haul roads at 5% of total charges

132.18

Add for electric energy at 2% 52.87

Total prime cost 2,828.63

Add 15% for profit/overheads 424.30

Total 3,252.93

Say 3,250.00



Excavation of Surge Shaft by Top down Method

Shape of tunnel - Circular

Excavated dia (Meters) 11.50 m

Cross sectional area of shaft (Sq. meters)

103.82 Sq .m

= 3.14 x 4.2 x 4.2

Progess per cycle (Meters) 0.50 m

Excavation per metre 51.91

Depth of drill holes for 0.5 m pull 0.75 m

No. of drill holes 124.58 say 125.00

Drilled meters/cycle 93.75

Three jack hammers shall be used for drilling

7.81

Cycle time

Preparation time(Hrs) 1.50

Drilling time(Hrs) 8.00

Charging and blasting(Hrs) 1.50

Ventilation(Hrs) 1.00

Scaling & rock bolting(Hrs) 3.00

Mucking & loading (Hrs) 6.00

Total time(Hrs) 21.00 say 22.00 hrs

No. of 8 hrs shift 2.75

Direct labour

Foreman - 1No. - 398.00 -

Electrician -1No. 1.00 270.00 270.00

Explosive loader -1 No. 1.00 180.00 180.00

Hole cleaner -1 No. 1.00 180.00 180.00

Helper to Electrician -1 No. 1.00 180.00 180.00

Wireman -0 No. - 270.00 -

Explosive chargeman -1 No. 1.00 270.00 270.00

Mucker - 3 No. 3.00

180.00

540.00



Beldar -3No. 2.00 180.00 360.00

Direct labour charges 1,980.00


990.00

Total Labour Charges 2,970.00

Total Labour Charges for 2.25 shifts 8,167.50

Cost of Labour/cum 314.69

Say 315.00


Sr.No. Item No. Working hrs/ cycle


Unit Rate (Rs.)

Amount(Rs.)

1 Power winch(10T) 1.00 15.00 15.00 500.00 ,500.00

2 Jack hammers 3.00 10.00 30.00 599.00

3 Convey mucker /Shoval(1.0 Cum) - 4.00 - ,694.00 -

5 Muck car/Tsippers 1.00 4.00 4.00 942.00 ,768.00

6 Scaling etc LS 100.00

7 Dozer 90 H.P 1.00 0.50 0.50 1,565.00 782.50

Total

Machinery charges per cum ,160.53

III Material charges

a) Drilling Charges

Cost of drill steel @ Rs. 42.00 per m = 93.75 x 42.00 3,937.50

Rate of drilling steel/Cum = 3937.5.00 / 41.55

75.86

b) Explosives

i) Gelatine required/Cum 1.00 72.00 72.00

Cost of gelatine@ 72.0/Kg

ii) Detonators & fuse coils required for one hole

25.00 16.50 412.50

Cost@Rs. 16.50 each

Rate per Cum ' = 412.50 / 41.55 7.95

iii) Other consumables etc., at 50 % of b (i) above

36.00




Total Drilling and Blasting charges (a+b) -

191.80

c) Provision for pipe lines for air & water 35.00

d) Misc. supplies such as wire ropes , clamps etc.

35.00

e) Cost of concrete , timber , steel etc for temporary supports

35.00

Total Material charges (a+b+c+d+e) 296.80

IV Charges for ventilation

Hourly use rate 5 H.P.blower with 250 m long pipe

159.00


Hourly use rate of blower system 4.00 636.00

Charges for blowers per cycle 20.00 2,720.00

Rate per cum =9600 / 41.55 245.05

V. Shop Charges

I)Structural shop 25.00

ii)Machine shop 25.00





VI. Misc. Charges

I)Electrical material 25.00

ii)Track charges 25.00





Total Misc. charges/cum 100.00

Abstract of charges

Direct Labour charges 315.00

Machinery charges 1,160.53



Shop charges 125.00

Misce. Charges 100.00

Total 2,242.38

Add for construction & maintenance of haul roads at 5% of total charges

112.12

Add for electric energy at 2% 44.85

Total prime cost 2,399.35

Add 15% for profit/overheads 359.90

Total 2,759.25

Say 2,750.00



Placing earthfill material for Coffer Dam & Barrage-embankment (per cum)

Average lead (Km) 1 Km

Diesel shovel capacity 1.15 Cum

Actual output per hour 60 Cum

Capacity of 15 T dumper 8.33 Cum

Swell factor 0.78

1 Machinery charges

a) Shovel

Use rate per working hour 1,352.00

Output per working hour 60

Rate per cum 22.53

b) Dumper

Average lead(Km) 1.0

Swell factor 0.78

Capacity of Dumper = 8.33 x 0.78 6.50

Cycle time(Min):

i)Loading time = Body capacity / Shovel output per min 6.5 6.50 min

ii)Spotting time 0.50 min

iii)Turning & dumping time 2.00 min

iv)Empty haul @ 25 km/hr 25 2.40 min

v) Loaded haul @ 20 km/ m = 1.0 x 60 / 20 20 3.00 min

Total cycle time 14.40 min

No. of dumper trips in 50 min = 50/ 18.0 50 3.47

Working hour

Output of dumper per working hour = 6.5 x2.78 22.56 cum

Use rate of dumper 1,334.00

Hence rate per cum = 1770 / 18.00 59.13

c)Crawel dozer

Assuming that one shovel will work at one place and 1/2 tractor dozer will be enough for one shovel at site of excavation.

Output of shovel 60 Cum

Use rate of dozer per working hour 1,565.00

Rate per cum 13.04

Total machinery charges(a+b+c) 94.71

Sub-total 170.00

d)Spreading charges with 180 HP dozer



Charges for 180 hp dozer per hour 1,857.00

Output per hour 180 Cum

Rate per cum 10.32

Total machinery charges 180.32

Add for

i)Processing @ 5% of total charges 9.02

ii)Vetting charges @5% of total charges 9.02

iii)Compaction @5% of total charges 9.02

Total 207.36

2 Construction and maintenance of haul roads 4% of total above

8.29

3 Electricity charges @2% of total above 4.15

4 Extra labour etc at site @ 2% of total above 4.15

Prime cost 223.95

Add overhead charges & contractor’s profit @ 15% of Prime cost

33.59

Grand Total 257.55

Say 258.00



Rock Bolting

A. Drilling i)Hourly use rate of Drill Jumbo 5,220.00 Average rate of drilling 35 mm dia hole per hour 100

Hence rate of drilling/m = 5390 / 100 52.20

ii) Cost of drill rod per mtr. of drilling 42.00

iii) Labour lighting & scaffolding etc per mtr 20.00

iv) Ventilation & workshop charges L.S. 15.00

Total(i to iv) 129.20

B. Supply and making the bolt

i) Rock bolts 28 mm @Rs.55.00 per kg for 3.95kg. per m

217.25

ii)Wastage and cutting @ 5.0% of B(i) above 10.86

iii)Cutting and making tip L.S. 20.00

iv)Threading L.S. 25.00

v)Cost of nuts and plates L.S. 60.00


C. Installation i)Placing rock bolt in position L.S. 30.00

ii)Grouting rock bolt L.S. 35.00

iii)Misc. works L.S. 15.00

Total (I to iii) 80.00 Prime Total (A+B+C) 542.31 = 130.90 + 333.11 + 80.00 Add overhead charges & Contractor’s profit @20%

of Prime cost 108.46

Grand Total 650.78

Say 660.00

Hence rate per m 660.00



Rock Bolting in Surge Shaft

A. Drilling i)Hourly use rate of Jack Hammer 599.00 Average rate of drilling 35 mm dia hole per hour 3

Hence rate of drilling/m = 599 / 3 199.67

ii) Cost of drill rod per mtr. of drilling 42.00

iii) Labour lighting & scaffolding etc per mtr 20.00

iv) Ventilation & workshop charges L.S. 15.00


B. Supply and making the bolt

i) Rock bolts 28 mm @Rs.55.00 per kg for 3.95kg.

per m 217.25

ii)Wastage and cutting @ 5.0% of B(i) above 10.86

iii)Cutting and making tip L.S. 30.00

iv)Threading L.S. 30.00

v)Cost of nuts and plates L.S. 100.00


C. Installation i)Placing rock bolt in position L.S. 30.00

ii)Grouting rock bolt L.S. 35.00

iii)Misc. works L.S. 15.00

Total (I to iii) 80.00 Prime Total (A+B+C) 744.78 = 130.90 + 333.11 + 80.00 Add overhead charges & Contractor’s profit @20%

of Prime cost 148.96

Grand Total 893.74

Say 900.00

Hence rate per m 900.00



Supply of coarse aggregate and sand

It is proposed to install 30 MT capacity Aggregate crushing and classification plant near quarry site. The Power house site is about 10 kms from the quarry site. Major requirement of coarse and fine aggregates shall be met with from the excavated material of this quarry.

A Drilling & Blasting

a) Rock drilling at quarry site is proposed to be carried out by ROC.

One foot drilling is sufficient for blasting 0.59 cu.yd of rock (Ref

Purefoy Edition five, page 307)

Depth of drilling per 100 cum of rock 67.99

= (100) / (0.59 x 0.76 x 3.28)

Add for horizontal drill and pull effect @50% of above 34.00

Total drilling 101.99

Say 102.00

i)Roc/Wagon Drill charges.

Hourly use rate of Wagon drill/Roc Charges 1,480.00

Considering rate of drilling as 10 m / hour, Cost of drilling 15,096.00

= (102 x 1480) / 10

ii)Drill rod charges

Cost of drill rod for 102m drilling 4,284.00 = 102 x 42.00

b)Blasting

i)Explosive charges

Assuming that drill holes can be filled with dynamite upto 75% of their capacity, quantity of explosive reqd. for 100 cum of rock (Ref Purifoy) = 0.43 x 100

43.00

Cost of explosive(72.00 per Kg) 3,096.00 ii)Detonator charges

Average depth of hole 1.75

No. of hole = 102 / 1.75 58.29 Say 59.00 Cost of 59 No. detonators @Rs.16.50/detonator 973.50



iii)Blasting batteries and loading wires etc.@15% of cost of gelatin

464.40

iv)Stemming @7% of cost of gelatine 216.72

Total drilling charge i/c cost of drill road 19,380.00

Total charges for blasting 4,750.62 = 3096 + 973.50 + 1548 + 216.72 Total charges for drilling and blasting per 100 cum 24,130.62 40% material will be available for blasted rock for works rate

per 100 cum. 9,652.25

Rate per cum(Bulk volume) 96.52

Assuming losses for 100 cum aggregate as under

i) 3% in transit from quarry to processing plant

ii)10%process reject

iii)20% reject at quarry

iv) 5% in transit from processing plant to batching and mixing plants.

Total Losses are 38%

Rate per 100 cum after adding for rejection and losses 14,960.98

Swell factor 0.63

(For blasted rock, ref Purifoy Edition V page 701)

Rate/100 cum(Bulk volume) of aggregate after adding for

rejection & losses 9,425.42

Rate/cum 94.25

B Carriage of blasted rock upto crushing plant Lead 1.00

i)Shovel output/hr 60.00 Cum

Machinery Rate of Shovel per cum 1,352.00

Rate/cum = 2755 / 60 22.53

ii)Dumper 15 Tonne

Capacity of 15T dumper in cum 8.33

Cycle time

Loading time, in min. 8.33 min

Dumping, turning & spotting time, in min. 2.50 min

Speed of loader dumper, in km/hr 15.00 km/hr

Speed of empty dumper, in km/hr 20.00 km/hr

Average speed 17.50 km/hr



Haulage time, in min. 3.43 min

Total cycle time, in min. 14.26 min

No. of trips per hour taking 50 min

Working hour = 50 / 14.26 3.51

Output of dumper per working hour = 3.51 x 8.33 29.21

Use Rate of Dumper 1,334.00

Rate per cum = Hourly rate of dumper / 29.21 = 1770/29.21 45.67

iii)Crawler dozer 180 HP

Output of Crawler dozer = Output of shovel 60.00 Cum

Use Rate of Crawler Dozer 1,857.00

Rate per cum = 4085 / 60 30.95

Total machinery charges(i+ii+iii) 45.2 + 60.59 + 68.08

99.15

Rate per cum (Borrow measure) =Total machinery charges 175.00

Rate per cum(Bulk volume) 175.00

Rate per cum after adding for rejection and transit losses =Rate(Bulk volume)

241.50

C Crushing & Processing of Aggregate

Crushing & Processing plant charges 244.00 Cum

D Loading charges

Loading into dumpers shall be done by Front end loader of 1.50 cum capacity

Use rate of front end loader 2,000.00

Taking basic cycle time from front end loader, in min. 0.50 min

No of cycles in 50 min working hour = 50 / 0.5 100.00

Actual output of front end loader, in cum 88.00 Cum

Rate per cum = 2230 / 88 22.73

Rate of Coarse aggregate at plant site after loading =(A+B+C+D)

602.48

= 98.49 + 108.50 + 245.00 + 25.34 Say 602.00

Crushed aggregate and sand at batching & mixing plant at power house site

Carriage of Crushed aggregate upto batching & mixing plants located at power house site shall be done by 15 T (8.33 cum) dumpers

I. Coarse Aggregate Lead, in km 10.00 km



Cycle time Loading time, in min. 5.68 min

Spotting time,in min. 0.50 min

Turning and dumping , in min. 2.00 min

Loaded haul @20km/hr = 10 x 60 / 20 30.00 min

Empty haul @25km/hr = 10 x 60 / 25 24.00 min


No of trips in 50 min. working hour = 50 / 62.18 0.80

Output of dumper per hour, in cum = 0.80 x 8.33 6.70 Cum


i)Carriage charges per hour = 1,770/ 6.58 199.15

Add 3% for transportation losses per cum 205.13

= 1.03 x 264.24

Abstract of charges i)Coarse aggregate at Crushing & processing plant after

loading 602.00

ii)Carriage upto batching & mixing plant 205.13 iii)Misc supplies L.S. 30.00

Sub. Total 837.13 Add for construction & maintenance of haul @5% and for

electric energy charges @2% of Sub total 58.60

Grand total 895.73

Say 896.00

Rate per cum 896.00

II. Sand (Crushed) Rate of coarse charges per cum 896.00

Add extra charges for Secondary, Crushing, Screening, Washing and Wastage during sand processing @ 50% of Primary crushing charges = 167 / 2

122.00

Total 1,018.00

Add for construction & maintenance of haul roads @5% and electric energy charges @2%

71.26

Grand total 1,089.26 Say 1,089.00 Rate of sand at power house site 1,089.00

Crushed aggregate and sand at batching & mixing plant at Surge Shaft site





Cycle time












= 1.03 x 516.68 Abstract of charges i)Coarse aggregate at Crushing & processing plant after

loading 602.00

ii)Carriage upto batching & mixing plant 401.09

iii)Misc supplies L.S. 30.00

Sub. Total 1,033.09

Add for construction & maintenance of haul @5% and for electric energy charges @2% of Sub total

72.32

Grand total 1,105.40 Say 1,105.00

Rate per cum 1,105.00

II. Sand (Crushed)

Rate of coarse charges per cum 1,105.00


122.00

Total 1,227.00


85.89


Crushed aggregate and sand at batching & mixing plant at Barrage site





Cycle time












= 1.03 x 608.47 Abstract of charges i)Coarse aggregate at Crushing & processing plant after

loading 602.00

ii)Carriage upto batching & mixing plant 472.34

iii)Misc supplies L.S. 30.00

Sub. Total 1,104.34

Add for construction & maintenance of haul @5% and for electric energy charges @2% of Sub total

77.30


Say 1,182.00


II. Sand (Crushed) Rate of coarse charges per cum 1,182.00


122.00

Total 1,304.00


91.28




Concrete at Batching and Mixing Plant at power house site Concrete M:7.5

I. Materials Sr.No. Item Qty Unit Rate

(Rs.) Amount (Rs.)

1 Cement 3.57 * Bag 320.00 1,142.40 2 Sand 0.45 Cum 1,089.00 490.05 3 Coarse Aggregate 0.90 Cum 896.00 806.40 4 Water LS 60.00 5 Admixture LS 38.00

Total: 2,536.85 *5% wastage and incidentals to work. 126.84

II. Batching and mixing charges of 20 cum capacity plant

63.00

Total (I+II), in cum 2,726.69 Say 2,727.00 Concrete M:10


(Rs.) Amount (Rs.)

1 Cement 4.83 * Bag 320.00 1,545.60

2 Sand 0.45 Cum 1,089.00 490.05

3 Coarse Aggregate 0.90 Cum 896.00 806.40

4 Water LS 60.00

5 Admixture LS 38.00

Total: 2,940.05

*5% wastage and incidentals to work. 147.00 II. Batching and mixing charges of 20 cum

capacity plant 63.00

Total(I+II) in cum 3,150.05 Say 3,150.00



Concrete M:15


(Rs.) Amount (Rs.)

1 Cement 6.30 * Bag 320.00 2,016.00

2 Sand 0.45 Cum 1,089.00 490.05


4 Water LS 60.00


Total: 3,410.45

*5% wastage and incidentals to work. 170.52


63.00

Total(I+II) 3,643.97 Say 3,644.00 Concrete M:20


(Rs.) Amount (Rs.)

1 Cement 8.40 * Bag 320.00 2,688.00

2 Sand 0.43 Cum 1,089.00 468.27


4 Water LS 60.00


Total: 4,024.83



63.00

Total(I+II) in cum 4,289.07 Say 4,289.00



Concrete M:25


(Rs.) Amount (Rs.)

1 Cement 11.55 * Bag 320.00 3,696.00

2 Sand 0.42 Cum 1,089.00 457.38


4 Water LS 60.00


Total: 5,014.02



63.00

Total(I+II) in cum 5,327.72

Say 5,328.00



Concrete at Batching and Mixing Plant at barrage site

Concrete M:7.5

I. Materials

Sr.No. Item Qty Unit Rate (Rs.)

Amount (Rs.)

1 Cement 3.57 * Bag 320.00 1,142.40

2 Sand 0.45 Cum 1,089.00 490.05

3 Coarse Aggregate 0.90 Cum 1,089.00 980.10

4 Water LS 60.00


Total: 2,710.55


II. Batching and mixing charges of 20 cum


Total(I+II) in cum 2,909.08 Say 2,909.00 Concrete M:10


(Rs.) Amount (Rs.)

1 Cement 4.25 * Bag 320.00 1,360.00

2 Sand 0.45 Cum 1,089.00 490.05


4 Water LS 60.00


Total: 2,928.15

*5% wastage and incidentals to work. 146.41 II. Batching and mixing charges of 20 cum

capacity plant 3.00

Total(I+II) in cum

3,137.56 Say 3,138.00



Concrete M:15

I. Materials

Sr.No. Item Qty Unit Rate

(Rs.) Amount (Rs.)

1 Cement 6.30 * Bag 320.00 2,016.00

2 Sand 0.45 Cum 1,089.00 490.05


4 Water LS 60.00


Total: 3,584.15




Total(I+II) in cum 3,826.36 Say 3,826.00 Concrete M:20


(Rs.) Amount (Rs.)

1 Cement 8.40 * Bag 320.00 2,688.00

2 Sand 0.43 Cum 1,089.00 468.27


4 Water LS 60.00


Total: 4,190.81



63.00

Total(I+II) in cum 4,463.35 Say

4,463.00



Concrete M:25


(Rs.) Amount (Rs.)

1 Cement 11.55 * Bag 320.00 3,696.00

2 Sand 0.42 Cum 1,089.00 457.38


4 Water LS 60.00


Total: 5,166.14




Total(I+II) 5,487.45

Say 5,487.00

Concrete M:40


(Rs.) Amount (Rs.)

1 Cement 11.50 * Bag 320.00 3,680.00

2 Sand 0.42 Cum 1,089.00 457.38


4 Water LS 75.00


Total: 5,227.14




Total(I+II) 551.50 Say 551.00



Concrete at Batching and Mixing Plant at Intake site

Concrete M:7.5


(Rs.) Amount

(Rs.)

1 Cement 3.57 * Bag 320.00 1,142.40

2 Sand 0.45 Cum 1,089.00 490.05


4 Water LS 60.00


Total: 2,710.55


II. Batching and mixing charges of 20

cum capacity plant 63.00

Total(I+II) in cum 2,909.08

Say 2,909.00

Concrete M:10

I. Materials

Sr.No. Item Qty Unit Rate

(Rs.) Amount

(Rs.)

1 Cement 4.50 * Bag 320.00 1,440.00

2 Sand 0.45 Cum 1,089.00 490.05


4 Water LS 60.00


Total: 3,008.15



63.00

Total(I+II) 3,221.56 Say 3,222.00



Concrete M:15


(Rs.) Amount

(Rs.)

1 Cement 6.30 * Bag 320.00 2,016.00

2 Sand 0.45 Cum 1,089.00 490.05


4 Water LS 60.00


Total: 3,584.15


II. Batching and mixing charges of 20

cum capacity plant 63.00

Total(I+II) 3,826.36 Say 3,826.00 Concrete M:20


(Rs.) Amount

(Rs.)

1 Cement 8.40 * Bag 320.00 2,688.00

2 Sand 0.43 Cum 1,089.00 468.27


4 Water LS 60.00


Total: 4,190.81



63.00

Total(I+II)

4,463.35 Say

4,463.00



Concrete M:25 I. Materials Sr.No. Item Qty Unit Rate

(Rs.) Amount

(Rs.)

1 Cement 11.55 * Bag 320.00 3,696.00

2 Sand 0.42 Cum 1,089.00 457.38


4 Water LS 60.00


Total: 5,166.14



63.00

Total(I+II) 5,487.45 Say 5,487.00



Placement of Concrete at Barrage and Desilting Tank

Concrete M-10 a)Cost of concrete per cum at Batching &

Mixing Plant 3,138.00

b)Carriage of concrete Carriage of concrete by 6.0 cum Capacity transit

mixer

Lead in km 1.00 km

Average speed in km/hr 10.00 km/hr

Hauling time, in min. = (1.0 x 2 x 60) / 10 12.00 min

Loading time, in min. = (6.0 x 60) / 40 9.00 min

Spotting & waiting time, in min. 2.00 min

Turning & unloading time, in min. 3.00 min

Total, in min. 26.00 min

No of trips of transit mixer in 50 min. working hour

= 50 / 26.0 1.92

Output of transit mixer/hr in cum = 1.92 x 6 11.54 Use rate of 6.0 Cum. transit mixer per hour 1,860.00 Charges per cum = 2105 / 11.54 161.20 c)Placement of concrete Concrete shall be placed through Tower Crane of

50 cum per hour capacity

Efficiency of concrete pump 80%

Actual output of pump in cum 40.00 Cum

Hourly use rate of Tower Crane 1,886.00

Rate per cum = 1980 /40 47.15 i)Concrete pump charges per cum 47.15

ii)Labour charges per cum L.S. 50.00

iii)Vibrating charges per cum L.S. 30.00

iv)Cleaning slurry, curing and finishing L.S 30.00

v)Catwalk and other aids for concreting L.S 30.00



vi)Electric energy, compressed air & workshop charges L.S.

30.00

vii)Misc.supplies such as hose pipes, gum boots etc L.S.

30.00

Total(i to vii) 247.15

d)Shuttering charges L.S. 250.00 Abstract of charges a)Cost of concrete at Batching & Mixing plant 3,138.00

b)Carriage of concrete 161.20

c)Placement of concrete 247.15

d)Shuttering charges 250.00

Prime Cost 3,796.35

Add for Contractor’s profit @20% 759.27 Rate per Cum. 4,555.62

Say 4,556.00 Concrete M-15 a)Cost of concrete M-15 per cum at Batching &

Mixing plant 3,826.00

b)Carriage of concrete(same as for M-10) 161.20

c)Placement of concrete(same as for M-10) 247.15


Prime Cost 4,484.35

Add for Contractor’s profit @20% 896.87 Rate per Cum 5,381.22

Say 5,381.00 Concrete M-20 a)Cost of concrete M-20 per cum at Batching &


b)Carriage of concrete(Same as for M-10) 161.20



Prime Cost 5,121.35



Add for Contractor’s profit @20% 1,024.27


Say 6,146.00 -

Concrete M-25 a)Cost of concrete M-25 per cum at Batching &


b)Carriage of concrete(Same as for M-10) 161.20



Prime Cost 6,145.35 Add for Contractor’s profit @20% 1,229.07


Say 7,374.00

Concrete M-40 a)Cost of concrete M-40 per cum at Batching &


b)Carriage of concrete(Same as for M-10) 161.20 c)Placement of concrete(same as for M-10) 247.15 d)Shuttering charges 300.00 Prime Cost 6,259.35 Add for Contractor’s profit @20% 1,251.87 Rate per cum 7,511.22 Say 7,511.00



Placement of Concrete at Intake

Concrete M-10 a)Cost of concrete per cum at Batching & Mixing Plant 3,222.00

b)Carriage of concrete Carriage of concrete by 6.0 cum Capacity transit mixer

Lead in km 1.00 km


Hauling time, in min. = (1.0 x 2 x 60) / 10 12.00 min

Loading time, in min. = (6.0 x 60) / 40 9.00 min

Spotting & waiting time, in min. 2.00 min

Turning & unloading time, in min. 3.00 min


No of trips of transit mixer in 50 min. working hour = 50 /

26.0 1.92

Output of transit mixer/hr in cum = 1.92 x 6 11.54 Use rate of 6.0 Cum. transit mixer per hour 1,860.00 Charges per cum = 2105 / 11.54 161.20 c)Placement of concrete Concrete shall be placed through Tower Crane of 50 cum

per hour capacity

Efficiency of concrete pump 80%

Actual output of pump in cum 40.00 Cum

Hourly use rate of Tower Crane 1,886.00

Rate per cum = 1980 /40 47.15

ii)Labour charges per cum L.S 50.00 iii)Vibrating charges per cum L.S 30.00 iv)Cleaning slurry, curing and finishing L.S 30.00 Total (i to iv) 157.15 d)Shuttering charges L.S 250.00 Abstract of charges a)Cost of concrete at Batching & Mixing plant 3,222.00 b)Carriage of concrete 161.20 c)Placement of concrete 157.15 d)Shuttering charges - Prime Cost 3,540.35 Add for Contractor’s profit @20% 885.09 Rate per cum 4,425.44 Say 4,425.00



Concrete M-15

a)Cost of concrete per cum at Batching & Mixing Plant 3,826.00 Abstract of charges

a)Cost of concrete at Batching & Mixing plant 3,826.00

b)Carriage of concrete(same as for M-10) 161.20

c)Placement of concrete (same as for M-10) 157.15

d)Shuttering charges (same as for M-10) 250.00

Prime Cost 4,394.35

Add for Contractor’s profit @20% 878.87 Rate per cum 5,273.22

Say 5,273.00 Concrete M-20 for Cellular wall a)Cost of concrete per cum at Batching &Mixing Plant 4,463.00 b)Carriage of concrete(same as for M-15) 161.20

c)Placement of concrete 47.15

i)Labour charges per cum L.S. 60.00

ii)Vibrating charges per cum L.S. 45.00

iii)Cleaning slurry, curing and finishing L.S. 45.00

iv)Catwalks and other aids for concreting L.S. 45.00

v)Electric energy, compressed air & workshop charges L.S.

45.00

vi)Misc. such as hose pipes, gum boots etc L.S. 45.00

Total(i to vi) 285.00

d)Shuttering charges L.S. 250.00

Prime Cost 5,206.35

Add for Contractor’s profit @20% 1,041.27 Rate per cum 6,247.62

Say 6,248.00 Per cum



Placement of Concrete in tunnel Concrete M-10 a) Cost of concrete per cum at Batching & Mixing Plant

3,138.00

b) Carriage of concrete

Carriage of concrete by 2.0 cum Capacity transit mixer

Lead (Average), in km 2.00 km


Spotting time, in min 1.00 min

Loading time, in min 2.00 min

Hauling time in min = (2 x 2x 60) / 10 24.00 min

Unloading time, in min 3.00 min

Total 30.00 min No of trips of Transit mixer in 50 min. working hour = 50 / 30

1.67

Quantity of concrete carried per hour, in cum = 2 x 1.67

3.33 cum

Hourly use rate of 2.0 Cum Transit mixer 1,500.00 Charges per Cum. = 1500 / 3.3 450.00

c)Placement of concrete

i)In overt portion of tunnel Concrete shall be placed through concrete pump

Capacity of pump, in Cum/hr 5.00 cum/hr

Output of pump at 70% efficiency 3.50 cum/hr

Hourly use rate of pump 795.00

Rate per cum = 820 / 3.5 227.14

i)Placement charges of concrete invert portion -

ii)Labour for placement of concrete including gantry L.S.

100.00

iii)Vibration L.S. -

iv)Cleaning slurry, curing and finishing L.S. 20.00

v)Catwalk and other aids for concreting L.S. 20.00

vi)Misc. charges L.S. 20.00

Total 160.00 d)Shuttering charges L.S. -

Prime cost 3,748.00


Say 4,498.00



Concrete M-15 a)Cost of concrete at Batching & Mixing plant 3,826.00

b)Carriage charges(same as for M-10) 450.00

c)Placement of charges(same as for M-10) 160.00


Total 4,686.00 Add for Contractor’s profit @20% 937.20 Rate per cum 5,623.20

Say 5,623.00 Concrete M-20 a)Cost of concrete M-20 per cum at Batching & Mixing plant

4,463.00

b)Carriage of charges(Same as for M-10) 450.00



Total 5,323.00


Say 6,388.00

Concrete M-25 a)Cost of concrete M-25 per cum at Batching & Mixing plant

5,487.00

b)Carriage of charges(Same as for M-10) 450.00



Total 6,472.00


Say 7,766.00



Placement of Concrete at Power House -sub-structure

Concrete M-15 a) Cost of M-15 concrete at Batching & Mixing plant

3,644.00

b) Carriage charges

Concrete shall be carried through transit mixer of 2.0 cum capacity

2.00 cum

Average lead, in km 1.50 km

Loading time, in min = (2.0 x 60 / 40) 3.00 min

Spotting & waiting time, in min 1.50 min

Hauling time @10km/hr, in min. = (1.5 x 60 x 2)/10

18.00 min

Unloading and turning time, in min. 3.00 min


No of trips in 50 min working hour = 50/25.50

1.96 No

Output of transit mixer per hour = 2.0 x 1.96 3.92 cum

Use rate of transit mixer per hour 1,500.00

Rate per cum = 1500 / 3.92 382.50

c) Placement of charges

Concrete shall be placed through portable concrete pump of 25 cum per hour capacity

25.00 cum

Use rate of concrete pump / hr 2,380.00

Efficiency of pump 70%

Actual output of pump 17.50 cum

i) Rate per Cum = 2565 / 17.5 136.00

ii) Labour charges for placement L.S. 60.00

iii) Vibration charges L.S. 40.00

iv) Cleaning slurry, curing and finishing L.S. 40.00

v) Catwalk and other aids for concreting L.S. 45.00

vi) Electric energy & workshop chargesL.S. 45.00

vii) Misc. supplies such as hose pipes, gum boots etc L.S.

45.00

Total (i to vii) 411.00

d) Shuttering charges @Rs.275 per cum 275.00

Prime cost (a+b+c+d) 4,712.50

Add for Contractor’s profit @20% 942.50

Rate per cum 5,655.00 Say 5,655.00



Concrete M-20 a) Cost of concrete M-20 per cum at Batching & Mixing plant

4,289.00

b) Carriage of charges(Same as for M-15) 382.50

c) Placement of charges(same as for M-15) 411.00

d) Shuttering charges 275.00

Prime cost (a+b+c+d) 5,357.50



Say 6,429.00 Concrete M-25 a) Cost of concrete M-25 per cum at Batching & Mixing plant

5,328.00

b) Carriage of concrete(Same as for M-15) 382.50

c) Placement of concrete(same as for M-15) 411.00

d) Shuttering charges 275.00

Total 6,396.50


Rate per Cum. 7,675.80

Say 7,676.00



Placement of Concrete at Power House -super-structure

Concrete M-15 a)Cost of concrete M-15 at Batching & Mixing plant 3,644.00

b)Carriage charges(same as for sub-structure) 382.50

c)Placement of charges(same as for substructure) 411.00


Prime cost (a+b+c+d) 4,737.50 Add for Contractor’s profit @20% 947.50

Rate per Cum 5,685.00

Say 5,685.00


4,289.00

b)Carriage of charges(Same as for sub-structure) 382.50

c)Placement of charges(same as for sub-structure) 411.00


Prime cost(a+b+c+d) 5,382.50


Rate per Cum. 6,459.00

Say 6,459.00


5,328.00

b)Carriage of concrete(Same as for sub-structure) 382.50

c)Placement of concrete(same as for sub-structure) 411.00


Prime Cost(a+b+c+d) 6,421.50 Add for Contractor’s profit @20% 1,284.30


Say 7,706.00



Stone Masonry in Cement Mortar 1:3

A. Material i) 1.10cum collection & carriage of stone to site

@Rs.150.00 per cum 165.00

ii) Dressing of 1.10 Cum stone @Rs. 60/Cum 66.00

iii) 3.6 cement bags at site of work @Rs.297 per bag 1,152.00

iv) 0.38 cum cost of sand at site of work i/c carriage @ Rs. 1200/Cum

413.82

Total (i to iv) 1,796.82

B. Labour for 100 cft Mason -1.No @ Rs.270 per shift 270.00

Dressing Mason -1No. @ Rs.270 per shift 270.00

Beldars -2 Nos. @ Rs.180 per shift 360.00

Bhisti -1No. @ Rs.180 per shift 180.00

Sub-total 1,080.00

Add for hidden cost of labour @50% of direct labour

charges 540.00

Grand total 1,620.00 Therefore labour rate per cum(1620*35.31)/100 572.02

Prime cost (A+B) 2,368.84


Say 2,843.00



Stone Masonary in Cement Mortar 1:6

A. Material

i) 1.10cum collection & carriage of stone to site @Rs.150.00 per cum

165.00

ii) 1.10 cum stone dressing charges @ Rs 60 per Cum

66.00

iii) 1.8 no. cement bags at site of work i/c carriage @ Rs. 297 per bag

576.00

iv) 0.32 cum cost of sand at site of work including carriage @Rs. 1200.00 per cum

384.00

Total (i to iv) 1,191.00

B. Labour for 100 cft

Mason -1.No @ Rs.270 per shift 270.00

Dressing Mason -1No. @ Rs.270 per shift 270.00

Beldars -2 Nos. @ Rs.180 per shift 360.00

Bhisti -1No. @ Rs.180 per shift 180.00

Sub-total 1,080.00

Add for hidden cost of labour @50% of direct

labour charges 540.00


Therefore labour rate per cum = (1620 x 35.31) / 100

572.02


Add for Contractor’s profit @20% 352.60 Grand total 2,115.63 Rate per cum 2,521.03

Say 2,521.00



Shotcreting for 50 mm

A. Cost of M-30 concrete for tunnel 6,500.00

B. Transportation charges of mix to site 300.00

C. Placement charges 459.00

Use rate of shotcrete machine of 10 cum capacity 4,522.00

Use rate of shotcrete machine per cum taking 80% efficiency

= 4555.00 / (10 x 0.8)

565.25

D. Lighting workshop charges and other misc item

@100% of use rate of shotcrete machine 565.25

Prime cost (A to D) 8,389.50 Add for Contractor’s profit @20% except for the cost of

cement 1,677.90

Grand Total 10,067.40 Add for rebound/ losses @20% 2,013.48

Hence rate of shotcrete per cum 12,080.88 Hence rate of shotcrete per sq m 604.04

Say 604.00



Shotcreting with wiremesh for 100 mm

Prime cost for 1 Sqm of shotcreting

(same as for item 4.2.22) with 2 layers of 50 mm

838.00

Cost of wire net/sqm

Weight of wire net/Sqm, in kg 2

Cost of 2 Kg wire net @Rs.100.00 200

Fixing charges L.S. 50

Prime cost 1,088.00

Add for Contractor’s profit @20% 217.60

Rate per Sq.m 1,305.60

Say 1,306.00



Stone-fill crates in wire nets

A. Material i)1.10cum collection & carriage of stone to site @

Rs.150.00 per cum 165.00

ii)Wire net for crates @ 3.2 kg wire @ Rs.120.60/kg 385.92

Total (i to ii) 385.92

B. Labour for 100cft Mason -1.No @ Rs.270 per shift 270.00

Blacksmith (Netting) [email protected] per shift 270.00

Beldars -2 [email protected] per shift 360.00

Sub-total 900.00 Add for hidden cost of labour @50% of direct labour

charges 450.00

Total labour charges 1,350.00

Therefore labour rate per cum = (1350 x 35.31) / 100 476.69

Prime cost (A+B) 862.61 Add for overhead charges & contractor’s profit @20% on

prime cost 172.52


Say 1,040.00



Stone pitching ( hand packed )

A. Material i)1.15 cum collection & carriage of stone to site

@ Rs.150.00/cum 172.50

B. Labour for 100 cft

Mason -1/2 No @Rs.270 per shift 135.00

Beldars -3 Nos.@Rs. 180 per shift 540.00

Sub-total 675.00

Add for hidden cost of labour @50% of direct

labour charges 337.50


Therefore labour rate per cum 357.51

Prime cost (A+B) 530.01 Add for overhead charges & contractor’s profit

@20% on prime cost 106.00

Rate per cum 636.02

Say 640.00



Consolidation Grouting

1 Cement and sand

i)Cost of 1.05 bag of cement at site including 5% wastage incidentals to work @ 297.00 per bag

336.00

ii)Cost of sand in 1:2 mix for one bag i.e. 0.071 cum @ 1350 per cum(Average rate)

95.85

Total 431.85

2 Washing the hole i)Cost of Equipment LS 60.00

ii)Cost of labour LS 40.00

Total 100.00

3 Machinery charges

i)Grouting machine charges 942.00

Use rate of grouting machine

Taking 8 bags progress of machine per hour, grouting charges per bag

117.75

ii)Cost of labour L.S. 40.00

Total 157.75

4 Other Misc. items such as G.I, pipe fittings and

pressure testing etc.L.S. 40.00

Prime cost (1+2+3+4) 729.60 Add for overhead charges & contractor’s profit @20% on

prime cost 182.40

Total 912.00

Hence rate of grouting per bag of 50 kg 912.00



Contact grouting i)Drilling Cost of drilling per meter

(by jack hammer) (vide item 4.2.6.2)

199.67

Average requirement of cement per meter in bags 1

Cost for drilling per bag = 228 / 4 199.67 ii)Grouting

Cost of grouting per bag (vide item 4.2.26)

912.00

Total cost per meter = (i+ii) 1,111.67

Hence rate per bag for contact grouting (including

drilling) 1,112.00



Fabrication and Erection of Penstock Steel Liner Steel plates of various thickness and conforming to SAILMA 350 shall be used for

fabrication of penstock liner

A. Materials

Average cost of steel plates i/c transportaion to fabrication

shop(per T). 49,740.00

Add for wastage and incidentals @2.5% 1,243.50

Total 50,983.50

B. Fabrication, Transporation and Erection Charges

i)Fabrication of steel liner including hydro-static & radiographic testings and transportation to project site L.S.

25,000.00

ii)Erection of penstock at site and painting etc. complete in all respects L.S.

20,000.00


Add for overhead charges and Contractor’s profit @20% of prime cost less cost of steel plates

9,000.00

Total 104,983.50

Rate of penstock liner per T 104,983.50



Fabrication and Erection of Trash Rack

A. Materials i)Cost of 1.0 T structural steel such as beams, angles, flats etc. 49,740.00

ii)Add wastage @ 2.5% of sub item (i) during various operations & handling

1,243.50

Sub-total of A 50,983.50

B. Fabrication (i)Straightening & Marking @3% of cost of steel (A) 1,529.51

(ii)Cutting @ 5% of cost of steel (A) 2,549.18

(iii)Drilling & Machining @8% of cost of steel (A) 4,078.68

(iv)Welding @15% of cost of steel (A) 7,647.53

(v)Handling of materials during fabrication @8% of cost of steel (A)

4,078.68

Sub-total of B 19,883.57

C. Transporataion and Erection charges i)Transportaion and position of trash rack at site of work @ 8%

of cost of steel/T 4,078.68

ii)Erection of embedded parts and painting of trash rack @30% of cost of steel/T

15,295.05

Total 19,373.73

Abstract of Charges

A. Material charges/T 50,983.50

B. Labour charges/T 19,883.57

C. Transportaion and erection/T 19,373.73

Prime cost 90,240.80

Add overhead charges and contractor’s profit @20% of prime cost less cost of steel +5% handling charge for steel

10,400.63

Total 100,641.43

Hence rate of Trash rack per T 100,641.00



Fabrication and Erection of stoplogs

A. Materials i)Cost of 1.0 T structural steel such as

beams,angles, flats etc. 49,740.00

Add wastage @ 2.5% of sub item (i) during various operations & handling

1,243.50

Sub-total 50,983.50

ii)1.5cum Acetylene @Rs.650 per cum 1,350.00

iii)7.5 cum Oxygen @Rs. 350 per cum 3,375.00

iv)200 Nos. M.S. Electrodes @Rs.9 each 1,800.00

v)12Kg gun-metal ingots @Rs. 450 per Kg 5,400.00

vi)2.5mt. rubber seal @Rs. 375 per m 937.50

vii)Misc. materials i.e. screws, bolts paints etc. @5% of items(i)

2,487.00

Total (ii to vii) 15,349.50

Total cost 66,333.00

B. Labour charges i)Fabrication including cutting, welding and

marking @20% of cost of steel/T 9,948.00

ii)Machining including turning, drilling threading, boring and teeth cutting @12% of cost of steel/T

5,968.80

iii)Casting @ 12% of cost of steel/T 5,968.80

iv)Black smithy and forging charges @8% of cost of steel/T

3,979.20

v)Misc. labour charges in handling of Job @ 4% of cost of steel/T

1,989.60


C. Transporataion and Erection charges

i)Transportaion of stoplog gates to site of

works @ 8% of cost of steel/T 4,974.00

ii) Erection of embedded parts and painting of stoplogs @ 10% of cost of steel/T

4,974.00

Total 9,948.00 Abstract of Charges




B. Labour charges/T 27,854.40

C. Transportaion and erection/T 9,948.00



10,109.66

Total 114,245.06

Say 114,245.06

Rate per T 114,245.00



Fabrication and erection of barrage gates

A. Materials i)Cost of 1.025* structural steel such as mild steel

plates beams channels and flats etc. 50,983.50

ii)Special steel @20% of cost of mild steel 10,248.60

iii)Rubber seals @8% of cost of steel 4,078.68

iv)Misc. purchases @ 15% of cost of steel 7,647.53

v)Bearing @15%of cost of steel 7,647.53

vi)Forged and cast steel items @12% of cost of steel 6,118.02

Total 86,723.85

*(including 2.5% wastage)

B. Fabrication i)Straightening @3% of cost of steel 1,529.51

ii)Marking @2% of cost of steel 1,019.67

iii)Cutting @5% of the cost of steel 2,549.18

iv)Drilling and machining @15% of cost of steel 7,647.53

v)Welding @ 12% of cost of steel 6,118.02

vi)Handling of materials during fabrication @ 8% of cost of steel

4,078.68

vii)Temporary jigs and fixtures @ 8% of cost of steel 4,078.68

Total 27,021.26

C. Transporation and erection charges i)Transporation and erection charges including

painting of gates @ 25% of cost of steel 12,745.88

Abstract of Charges


B. Fabrication charges 27,021.26

C. Transportation and erection charges 12,745.88





17,650.67

Total 144,141.65

Say 144,141.65

Rate per T 144,141.65



Sluice Gate

A. Materials (per T.)

i)1.0 T structural steel such as mild steel plates,

beams,channels & flats etc 49,740.00

Add for @2.5% of sub-item (I) during various operations and handling

1,243.50

Total 50,983.50

ii) 0.6T Pig iron @Rs. 15000 per T 9000

iii)450 Nos. MS Electrodes @Rs.6.00 each 2700

iv)1.8 Cum Acetylene @Rs.650 per cum 1170

v)13.5 Kg Cum Oxygen @Rs. 350 per cum 4725

vi)13.5 kg Gum metal @Rs. 375 per kg 5062.5

vii)4.0 m rubber seal @Rs. 375 per m 1500

viii)Job Miscellaneous materials like nuts and bolts, oil, paints, hard coke, patternwood, grease nipples and thrust bearing etc @15% of Item-(i) above

7461.00

Total cost of materials 82,602.00

B. Labour charges (per T)

i)Fabrication including cutting, straightening marking and

welding @20% of cost of mild steel at item A(i) 9948.00

ii)Machining including turning, drilling, threading, boring, teeth cutting and painting @35% of cost of mild steel at item A(i)

17409.00

iii)Casting @10% of cost of steel at item A(i) 4974.00

iv)Black smithy and forging charges @12% of cost of steel at item A(i)

5968.80



v)Temporary jig & fixture and miscellaneous labour charges in handling of job to different shops @6% of cost of steel at item A(i)

2984.40

Total labour charges 41284.20

C. Transportation & Erection charges (per M.T.) i)Transportation of sluice gates an guides to site of work @

6% of cost of steel at item A(i) 2984.40

ii)Erection charges of sluice gate and guides @20% of cost of steel at item A(i)

9948.00

Total transportation and Erection charges 12932.40

ABSTRACT OF CHARGES

A. Material 82,602.00

B. Labour 41284.20

C. Transporation and erection charges 12932.40

Prime Cost 136,818.60 Add overhead charges and contractor’s profit @20% of

prime cost less cost of steel +5% handling charge for steel 19,716.20

Total 156,534.80

Say 156,534.80

Rate of sluice gate per T 156,535.00

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 17-Cost Estimate


17. COST ESTIMATES

17.1 GENERAL

The Bharmour-Stage-I HEP (24 MW)- Upstream Project and Bharmour Stage-II HEP (21 MW)

shall operate in tandem, therefore, the total estimated cost for both the projects have been

calculated separately and has been combined for financial analysis.

Cost estimate of Bharmour-I H.E. Project has been prepared at August 2014 price level,

calculating the quantities of different work items involved and with the applicable unit rates. The

applicable unit rates are based upon the August 2014 cost of material, cost of transportation and

labor rates as applicable in Himachal Pradesh. Details of cost estimation are given in Annexure-

17.1.

17.2 BASIS OF THE COST ESTIMATE


the civil works including infrastructure facilities, Electro Mechanical Works and Hydro Mechanical

works required for BHEP-I. The estimated project cost of generating works (Pre-Operative

Works, Civil & Electro Mechanical & Transmission Line Works) works out to Rs. 208.75 Crores

(exclusive of fund management expenses, IDC, Escalation, CAT & LADA).

Similarly, the estimated project cost of generating works (Pre-Operative Works, Civil & Electro

Mechanical) works out to Rs. 196.00 Crores (exclusive of Transmission Line Works, Fund

management expenses, IDC, Escalation, CAT & LADA).

In view of the BHEP-I & BHEP-II shall operate in tandem, therefore, the total project cost for both

the projects including Transmission line and excluding Transmission line have been worked out

as Rs. 421.80 Crores and Rs. 393.64 Crores respectively and the details are given in the beow

table & detailed calculations are attached as Annexure-17:

Description Project Cost With Transmission

Line (in Rs. Crores)

Project Cost WithoutTransmission


Civil Works 208.05 208.05

Electro-Mechanical works 87.53 87.53

Transmission line 23.90 -------

Pre-operative works 27.54 27.54

IDC, Financial Charges & Escalation

58.32 55.16

LADA & CAT 16.46 15.36

Total completion cost of Combined Projects

421.80 393.64



The estimates are generally based on the third revised edition of the “Guidelines for formulation

of Detailed Project Report for Hydroelectric schemes- April 2012” by Central Electricity Authority.

17.3 DESCRIPTION OF ITEM

The cost estimate of Bharmour-I HEP has been worked out as per CEA guidelines.

17.3.1 Civil works

Under this heading, provision has been made for Civil works of various components of the

Project as detailed here under:

Direct Charges

I- works

A-Preliminary

Under this heading provision has been made for surveys and investigations conducted or those

which are required to be conducted to arrive at the optimum designs of project components.

B-Land

This covers the provision for acquisition of land for construction of the project colonies, offices,

roads and stores and compensation for houses and standing crops. Compensation for forest

trees in the project area has also been included.

C-Civil Works and J-Power Plant Civil Works

These cover the cost of Civil engineering structures comprising river diversion work, Intake

structure, feeder channel, de-sanding arrangements, surge tank and power house, tailrace

channel, switchyard and their associated works. Analysis of rates for principal items of work are

included under Rate analysis.

K-Buildings

Buildings, both residential and non-residential have been grouped separately under temporary

and permanent construction. Included under the permanent category are all those buildings,

which will be subsequently utilized for the running and maintenance of project utilities. The cost

has been worked out on the basis plinth area rate prevalent in the project area.

M-Plantation

A provision of Rs. 16 lakhs has been kept for plantation and maintenance of plants along project

roads and around water conductor system.



O-Miscellaneous

A provision of Rs. 292.50 lakhs has been made for meeting Capital and Running &

Maintenance cost of various items such as electrification, water supply, sewage disposal,

wireless communication etc.

P-Maintenance

A total provision of Rs.119 lakhs has been kept under this heading. As per applicable norms,

this has been worked out as 1.0% of total of C-Works, J- Power Plant, -Civil Works, K-

Buildings, M- Plantation, O – Miscellaneous, R – Communication, X - Environment, Ecology &

Forestation.

Q-Special T & P

Provision for special tools and plants is based upon the detailed requirement of machinery

worked out for machinery items taken into account the Capital cost of the equipment and its

percentage utilization.

R-Communications

Provisions under this head cover the cost of roads. The road widths have been planned to

cater to the anticipated traffic including movement of heavy trailers.

S-Power Plant & Electro – Mechanical System

Provisions under this head cover Electro mechanical equipment for power plant, and

associated substation works.

a) Electrical / Mechanical Works

Total cost of electrical works at August 2014 price level works out to Rs. 44.47 Crores. The

cost of main electrical equipment such as turbines and generators are based on the budgetary

quotations received from reputed manufactures in India and abroad. The cost provision for

other electrical and mechanical works such as EOT cranes, transformers batteries, control and

relay panels etc. have been kept as per prevalent market prices in India. Provision of excise

duty @10.30% and cess @ 2% has been taken into account. The freight and insurance

charges @ 4% and erection and commissioning charges @ 8% have been considered keeping

in view the experience on similar projects.

The establishment, engineering and consultancy charges have been kept separately.

Establishment charges have been kept @ 2% of the cost of the equipment and lump sum

provisions has been kept for the consultancy charges.



b) Transmission Line

Total Cost of the works pertaining to transmission line works out to Rs. 12.75 Crores.

The evacuation of power from Bharmour I HEP shall be through proposed composite 132 kV

Ring Main Scheme and proposed 132/220 kV Bharmour Pooling Substation to be constructed

by the developer which shall be connected to 220 kV Chamera III Substation through 220 kV

S/C Transmission Line to be constructed by the developer.

X-Environments, Ecology & Forestation

A provision of Rs. 140 lakhs has been made under this head for maintaining & improving the

environmental status of the project area and for forestation of the affected area.

Y-Loses on Stock

A provision of Rs. 29 lakhs has been made under this sub-head. As per applicable norms, this

has been worked out @ 0.25 % of I-works less A-Preliminary, B-Land and Q-Special T & P.

II - Establishment

An Establishment cost @ 8% of I-works, B-Land & X-Environmental and Ecology works has

been included under this heading.

III – T & P

Lump sum cost of 139.59 lakhs has been made under this heading.

IV – Suspense

No cost on suspense account has been considered.

V-Receipts and Recoveries

This provision covers estimated recoveries by way of resale or transfer of special T & P and

temporary and permanent buildings. An amount of Rs. 46 lakhs has been worked out as total

credit for receipts and recoveries.

Indirect Charges

These charges cover the cost towards fees for audit and accounts which has been taken as

1% of I-Works as per norms. In addition an amount of Rs 7.20 Lakhs has been provided

towards capitalization of abatement of land revenue @ 5% of the cost of the cultivable land.

Total provision of Rs. 146.79 lakhs has been kept for indirect charges.



Annexure-17.1

Bharmour-I & Bharmour-II HEP's Works (24 MW + 21 MW)

Summary of Project Cost (August 2014 Price Level)

(Without Transmission)

S. No.

Item Amount (Rs. In Crores)

A. Generating Works

1 Cost of pre-operative works 27.54

2 Cost of Civil Works 208.05

3 Cost of Electrical works 87.53

B. Transmission Works

Cost of 132kV Double Circuit Line from Bharmour-I to Bharmour-II including cost sharing portion of the pooling station

0.00

Sub Total - I (Generation + Transmission) 323.12

Escalation During Construction (Annexure-18.1, Chapter, 18) 16.49

Interest During Construction (Annexure-18.1, Chapter, 18) 35.91

Fund - Management Expenses (Annexure-18.1, Chapter, 18) 2.76

D. TOTAL COST 378.28

E. CAT @ 2.5% of Total Cost 9.46

F. LADA @ 1.5 % of Total Project Cost 5.90

Total Project Cost 393.64



Bharmour-I & Bharmour-II HEP's Works (24 MW + 21 MW)


(With Transmision)

S. No.

Item Amount (Rs. In Crores)

A. Generating Works

1 Cost of pre-operative works 27.54

2 Cost of Civil Works 208.05

3 Cost of Electrical works 87.53


Cost of 132kV Double Circuit Line from Bharmour-I to Bharmour-II including cost sharing portion of the pooling station

23.90

Sub Total - I (Generation + Transmission) 347.02

Escalation During Construction (Annexure-18.1, Chapter, 18) 17.24

Interest During Construction (Annexure-18.1, Chapter, 18) 38.12

Fund - Management Expenses (Annexure-18.1, Chapter, 18) 2.95

D. TOTAL COST 405.34

E. CAT @ 2.5% of Total Cost 10.13

F. LADA @ 1.5 % of Total Project Cost 6.33

Total Project Cost 421.80



Bharmour-I HEP Works (3x8 MW)


S. No. Item Amount (Rs. In Crores)

A. Generating Works Including Transmission Line

Excluding Transmission Line

1 Cost of pre-operative works 17.42 17.42

2 Cost of Civil Works 134.11 134.11

3 Cost of Electrical works 44.47 44.47


Cost for Bharmour I HEP Power Evacuation on prorata installed capacity (MW)

12.75 0.00

Total Basic Cost 208.75 196.00

Bharmour-II HEP Works (3x7 MW)


S. No. Item Amount

(Rs. In Crores)

A. Generating Works Including Transmission Line

Excluding Transmission Line

1 Cost of pre-operative works 10.12 10.12

2 Cost of Civil Works 73.94 73.94

3 Cost of Electrical works 43.06 43.06


Cost for Bharmour I HEP Power Evacuation on prorata installed capacity (MW)

11.15 0.00




Bharmour-I HEP Works (3x8 MW)

Abstract of Cost Estimatesfor Civil Works (August 2014 Price Level)

DIRECT CHARGES

I - WORKS Amount (Rs. In Lacs)

1 A. Preliminary 96.50 2 B-Land 435.00 3 C - Works

River diversion Works 45.00

Diversion Barrage 3166.00

Desilting arrangement 1426.00

Intake 914.00

Taxes 329.95

Sub Total C - Works 5,880.95

4 J - Works

Head race tunnel 2031.00

Surge Shaft 672.00

Pressure shaft 576.00

Power House Complex 1212.00

Switchyard 216.00

Taxes 279.78

Sub Total J - Works 4,986.78

5 K - Buildings 117.60 6 M - Plantation 16.00 7 O - Miscellaneous 292.50 8 P - Maintenance 119.00 9 Q - Special T & P 99.00 10 R - Communication 404.71 11 X - Environment, Ecology & Afforestation 140.00 12 Y - Losses on Stock @0.25%(Works -A-B-M-O-P-Q-X) 29.00 13 HM works 1,342.42 TOTAL OF I - WORKS 13,959.46

II Establishment @ 8% of I - Works - B-Land - X - Environment & Ecology

1,070.76

III T & P @ 1% of I - Works 139.59



IV Suspense

IV Receipts & Recoveries (-) 46.00

TOTAL OF DIRECT CHARGES 15,123.81

INDIRECT CHARGES

(a) Audit & Accounts @ 1% of I - Works 139.59 (b) Capitalisation of abatement of land revenue @5% of the

culturable land

7.20

TOTAL OF INDIRECT CHARGES 146.79

TOTAL OF DIRECT AND INDIRECT CHARGES

15,153.01

Pre Operative ( (I) + (II) + (III) + Indirect charges (a) ) 1,741.85 Say (Amount in Crores) 17.42

CIVIL WORKS COST 13,411.15

Say (Amount in Crores) 134.11



A. PRELIMINARY

Sl. No.

DESCRIPTION QTY. AMOUNT(Rs. lakhs)

1 Expenditure on investigations L.S. 24

2 Pre - Construction and Construction stage investigations

- Topographical Survey L.S. 5

- Hydrological & meteorological data collection for 5 years L.S. 8

- Geological and geophysical explorations Geo-technical testing and data collection, seismological observations and laboratory tests

L.S. 6

- Construction material testing and Establishing soil and rock testing laboratory

L.S. 5

- Hydraulic model studies and testing for Dams, spillways and desilting tank

L.S. 15

- Environment and ecological Studies and Testing L.S. 2

3 Training of Engineers and Technicians L.S. 2

4 Development Expenses

i) Consultants (Technical, EIA & Legal) L.S. 0

ii) Project advisory Fees ( U$ 5.0 Million) L.S. 0

5 Construction of access paths, retaining structure and temporary store at site.

L.S. 2.5

6 Inspection vehicle & Special Tools and Plants for investigation

L.S. 5

7 Survey, drawings & mathematical and camp office equipment

L.S. 2.5

8 Publication of brochures, Project reports comprising design reports,estimates, bullettins etc.

L.S. 2.5

9 Stationery & office equipment like fax, photostat machine, typewriter, computer etc.

L.S. 5

10 Project Development team / office expenses L.S. 12

TOTAL 96.50



B. LAND Rate of Govt./Forest Land per Hactare (Lacs) 24 Rate of Private Land per Ha (Lacs) 30

Sl. No.

DESCRIPTION QTY. UNIT RATE (Rs.in Lacs)

AMOUNT( Rs. lacs )

1 Acquisition of land

Barrage/Weir Govt./Forest land 1.500 Ha 24.000 36.00 Pvt. land 0.000 Ha 30.000 0.00 Colonies/Offices Govt./Forest land 0.000 Ha 24.000 0.00 Pvt. land 0.500 Ha 30.000 15.00 Road

Project roads & other roads to colony, Adits, Powerhouse, tailrace outlet, surgeshaft road, batching and mixing plants, dam site, diversion work, quarry site & dumping yards.

Govt./Forest land 1.800 Ha 24.000 43.20

Pvt. land 1.800 Ha 30.000 54.00 Plant areas


Pvt. land 0.000 Ha 30.000 0.00 Storage reservoir inclusive of submergence

area

Govt./Forest land 1.000 Ha 24.000 24.00 Pvt. land 0.000 Ha 30.000 0.00 Head Race Tunnel & Adit


Pvt. land 0.000 Ha 30.000 0.00 Powerhouse & Tailpool


Pvt. land 0.000 Ha 30.000 0.00 Switchyard


Pvt. land 0.000 Ha 30.000 0.00 Dumping area


Pvt. land 2.500 Ha 30.000 75.00 Explosive Magazine Site


Pvt. land 0.000 Ha 30.000 0.00

Sub - Total of Govt Land 7.850 188.40

Sub - Total of Pvt Land 4.800 144.00



Total 12.650 Ha 332.40

2 Compensation for houses L.S. 0.003 Compensation for crops L.S. 10.004 Solatium charges on compulsory aquisition

@30% of cost of private land 43.20

5 Legal charges @ 1% on items 1 to 3 3.42

6 Interest charges @12% on items 1 to 3 for 2 years on 25% of total compensation

20.54

7 Establishment charges on items 1 to 3 @6.25% 21.40

8 Labour & Materials for land demarcation @1% of item 1 only

3.32

TOTAL 434.29 Say Say 435.00



C. WORKS ABSTRACT OF COST

Sl.No. DESCRIPTION REVISED AMOUNT

(Rs. in lakhs)

1 River Diversion 45.00 2 Barrage 3,116.00

3 Desilting Arrangement 1,426.00

4 Intake & Feeder channel 914.00

Total without Tax 5,551.00 Construction workers cess tax @ 1% 55.51 Service Tax @ 4.944% 274.44 Total C works including Taxes 5,880.95



River Diversion works

Sl.No. DESCRIPTION QTY UNIT RATE (Rs.)

AMOUNT(Rs. in lakhs)

1 Upstream and Downstream Coffer Dam

1.1 River bed clearance including of boulders and bushes, etc. for construction of U/s and D/s Coffer Dam

L.S. 1.00

1.2 Excavation in river bed 100.00 Cum 196.00 0.20

1.3 Boulders and earth filling in U/s and D/s coffer dams including compaction.

12,000.00 Cum 258.00 30.96

1.4 Impervious material 1,500.00 Cum 350.00 5.25

1.5 Stone Pitching 500.00 Cum 640.00 3.20

d) Dewatering @5% of Cost of works except L.S.

2.03

Total 42.64

Add contingencies & work charge establishment @5% (except L.S. items)

2.03

TOTAL 44.67

Say 45.00



BARRAGE


AMOUNT (Rs. in lakhs)

1 Site clearance including of boulders and bushes

L.S. 2.00

2 Surface Excavation of overburden

45,250.00 Cum 196.00 88.69

3 Surface Excavation in rock 19,400.00 Cum 417.00 80.90

4 Concreting

M-10 2,070.00 Cum 4,556.00 94.31

M-25 28,900.00 Cum 5,487.00 1,585.74

High performance concrete 803.00 Cum 7,511.00 60.31

5 Tor steel reinforcement 1,490.00 T 63,029.00 945.44

6 Stone filled wire crates 2,640.00 Cum 1,040.00 27.46

7 Back fill 17,975.00 Cum 258.00 46.37

Miscellaneous works: Hand rails caged ladders

2.00 T 82,593.00 1.65

Sub - Total 2,926.57

Instrumentation for barrage @ 1% of Cost of works except L.S.

29.27

Dewatering @2% of Cost of works except L.S.

58.53

3,014.37 Add contingencies & work

charge establishment @5% (except L.S. items)

150.72

TOTAL 3,165.08 Say 3,166.00



DESILTING ARRANGEMENT



1 Site clearance

LS 2.00

2 Surface excavation in overburden

16,426 Cum 196.00

32.20

3 Surface excavation in rock

7,040 Cum 417.00

29.36

4 Compacted back fill

3,741 Cum 258.00

9.65

5 Cement Concrete

a) M-10

3,504 Cum 4,556.00

159.66

b) M-25

11,657 Cum 5,487.00

639.63

6 Tor steel reinforcement

699 T 63,029.00

440.84

Miscellaneous works:handrail caged ladders LS 5.00

Sub - Total 1,318.33

Instrumentation for desilting basin @1% of Cost of works except L.S.

13.18


26.37

Sub total 1,357.88

Add contingencies & work charge establishment @5% (except L.S. items)

67.89

TOTAL 1,425.78

Say 1,426.00



INTAKE & FEEDER CHANNEL

Sl.No. DESCRIPTION QTY UNIT RATE

(Rs.) AMOUNT

(Rs. in lakhs)

1 Site clearance

LS 1.00

2 Surface excavation

a) in over burden

5,115.00 Cum 196.00 10.03

b) In rock

5,115.00 Cum 417.00 21.33

3 Filter

100.00 Cum 1,372.00 1.37

4 Waterstop

1,000.00 Rm 500.00 5.00

5 Rock protection

500.00 Cum 640.00 3.20

6 Compacted backfill

9,162.00 Cum 258.00 23.64

7 Concreting

M - 10

327.65 Cum 4,556.00 14.93

M - 25

8,795.93 Cum 5,487.00 482.63

8 Tor steel reinforcement

440.00 T 63,029.00 277.33

Miscellaneous works: Hand rails caged ladders

LS T 5.00 5.00

Sub total I 845.45

Instrumentation for Intake & feeder channel @1% of Cost of works except L.S.

8.45


16.91

Sub -Total II 870.82

Add contingencies and work charge establishment @ 5%( except L.S items)

43.54

TOTAL 914.36

Say 914.00



J. POWER PLANT CIVIL WORKS

ABSTRACT OF COST

Sl.No. DESCRIPTION AMOUNT (Rs. in lakhs)

1 Head race tunnel 2,031.00

2 Surge Shaft 672.00

3 Pressure shaft 576.00

4 Power house complex 1,212.00

6 Switchyard 216.00

Total without Tax

4,707.00 Construction workers cess tax @ 1% 47.07 Service Tax @ 4.944%

232.71

Total J works including Taxes 4,986.78



HEAD RACE TUNNEL Sl.No. DESCRIPTION QTY UNIT RATE

(Rs.) AMOUNT

(Rs. in lakhs)

1 a) Undergound Tunnel excavation 41,600.00 Cum 2,450.00

1,019.20

b) Overbreak 4160 Cum 612.50

25.48

2 a) Concrete - M-20 In tunnel lining & Adit Plug

7,061.00 Cum 6,888.00

486.36

b) Concrete M-10 for backfilling Overbreak 700.00 Cum 4,498.00

31.49

3 Shotcreting: a) 100 mm (with wiremesh) 2650.00 Sqm 1,306.00

34.61

b) 50 mm 25,900.00 Sqm 604.00

156.44

4 Precast concrete sleepers 195.00 Cum 12,467.00

24.31

5 Reinforcement steel 5.00 T 63,029.00

3.15

6 Structural Steel 60.00 T 82,593.00

49.56

7 Rock Bolting 25mm dia 7,100.00 Rm 660.00

46.86

8 Contact grouting 1,723.00 Bags 1,112.00

19.16

Sub total 1,896.61

9 Instrumentation for HRT @ 1% of Cost of works except L.S.

18.97

10 Dewatering @1% of Cost of works except L.S.

18.97

Sub total 1,934.54

Add contingencies & work charge establishment @5% ( except L.S items )

96.73

Total 2,031.27

Say 2,031.00



SURGE SHAFT



1 Open excavation 400.00 cum 196.00

0.78

2 Underground excavation

a) Excavation 7,000.00 Cum 2,750.00

192.50

b) Overbreak 700 Cum 687.50

4.81

3 a) Concreting M-10 200 Cum 4,498.00

9.00

b) Concreting M-25 2350.00 Cum 6,888.00

161.87

4 Shotcreting 100 mm with wire mesh 350.00 Sq m 1,306.00

4.57

5 Shotcreting 50 mm with wire mesh 1,800.00 Sq m 604.00

10.87

6 Rock bolting 25 dia.4 m long @2 m c/c

1,212.00 M 900.00

10.91

7 Rock bolting 25 dia. 2.5 m long @ 1.5 m c/c

486.00 M 660.00

3.21

8 Consolidation grouting 0.00

a) Drilling 64.29 M 277.00

0.18

b) Grouting 25.00 Bags 912.00

0.23

9 Contact grouting 40.00 Bags 1,112.00

0.44

10 Reinforcement 352.50 T 63,029.00

222.18

Sub - Total 621.55

11 Instrumentation for surge shaft @1% of Cost of works except L.S.

6.22


12.43

Sub total 640.19

Add contingencies & work charge establishment @ 5% (except L.S items )

32.01

TOTAL 672.20 Say 672.00 *raise climber not used for excavation



PRESSURE SHAFT Sl.No. DESCRIPTION QTY UNIT RATE

(Rs.) AMOUNT (Rs. in lakhs)

1 Underground excavation

a) In horz. portion 1,484.00 Cum 2,450.00

36.36

b) Overbreak 148.4 Cum 612.50

0.91

c) in Vertical portion 516.00 Cum 3,250.00

16.77

d) Overbreak 51.6 Cum 812.50

0.42

e) Inlet Adit to pressure shaft 6,800.00 Cum 2,450.00

166.60

2 a) Concreting M-15 1232.71 Cum 6,124.00

75.49

b) Concreting M-15 for filling overbreak 96.93 Cum 6,124.00

5.94

3 Shotcreting 100 mm with wire mesh 860 Sq m 1,306.00

11.23

4 Rock bolting 25 dia. 800.00 M 660.00

5.28

5 Consolidation grouting

a) Drilling 144.23 M 277.00

0.40

b) Grouting 56.00 Bags 912.00

0.51

6 Contact grouting 89.00 Bags 1,112.00

0.99

7 Reinforcement 25.00 T 63,029.00

15.76

8 Steel liner

E250 Fe 410 180 T 104,984.00 188.97

9 Steel supports for steel liners L.S 15.00

Sub - Total 540.62

10 Instrumentation for pressure shaft @0.5% of Cost of works except L.S.

2.70


5.41

Sub total 548.73

Add contingencies & work charge establishment @ 5% (except L.S items )

27.44

TOTAL 576.17 Say 576.00



POWER HOUSE COMPLEX



1 Common Excavation 37100.00 m3

196.00 72.72

2 Excavation in Rock 16000.00 m3 417.00

66.72

3 Concrete M-10 130.00 m3 4,556.00

5.92

4 Concrete M-20 8964.16 m3 6,429.00

576.31

5 Concrete M-25 100.00 m3 7,706.00

7.71

6 Steel Superstructure 30 MT 95,135.00

28.54

7 Steel Reinforcement 540.00 MT 64,000.00

345.60

8 Boulder Protection 500 m3 640.00

3.20

9 Random backfill around Powerhouse 3900.00 m3 258.00

10.06

10 Gabion wall with wire crate 2000 m3 1,040.00

20.80

Sub-Total (1-10) 1,137.57

11 Misc. and architectural works 5% 56.88

Sub total (1-11) 1,194.45

Instrumentation for powerhouse @.5%

of Sub-Total (1-10) 0.5%

5.69

Dewatering for powerhouse @.5% of Sub-Total (1-10)

0.5% 5.69

Contingencies for powerhouse @.5% of

Sub-Total (1-10) 0.5%

5.69

TOTAL

1,211.52 Say

1,212.00



SWITCHYARD



1 Open excavation in overburden 67378.5 Cum 196.00

132.06

2 Open Excavation in Rock 7486.5 Cum 417.00

31.22

3 Concrete M-20 in toe walls 100 Cum 6,429.00

6.43

4 Grouted Anchor bolts 20 mm dia. 100 M 660.00

0.66

5 Concrete M-25 in foundations, cable trenches etc.

250 Cum 7,706.00

19.27

6 Reinforcement Steel 17.5 MT 63,029.00

11.03

7 Fencing L.S 5.00

Sub total 205.66

Add for contingencies & work charge establishment @ 5% ( excluding L.S. items )

10.28

TOTAL 215.95

Say

216.00



K. BUILDINGS ABSTRACT OF COST

Sl.No. DESCRIPTION AMOUNT(Rs. in lakhs)

1 Residential buildings

Permanent 59.00

Temporary 9.00

2 Non-residential buildings 43.00

-------------------- Total 111.00

Total without Tax 111.00

Construction workers cess tax @ 1% 1.11 Service Tax @ 4.944% 5.49 Total K works including Taxes 117.60



NON-RESIDENTIAL BUILDINGS

Sl.No. DESCRIPTION PLINTH AREA (Sqm)

RATE (Rs.)


NON RESIDENTIAL BUILDINGS

A. PERMANENT

Colonies

Building cost 165 15000 24.75

Water supply & Sanitary fittings, Electrical Installations & Development charges at site @ 14.5%

3.59

Retaining walls @8% 1.98

30.32

B. TEMPORARY

Building Cost 90 12000 10.80

Water supply & Sanitary fittings, Electrical Installations & Development charges at site @ 12.5%

1.35

Retaining walls @8% 0.86

13.01 TOTAL (A+B) 43.33 Say 43.00



RESIDENTIAL BUILDINGS

Sl.No. DESCRIPTION PLINTH AREA (Sqm)

RATE(Rs.)


A. PERMANENT

Colonies

Building cost 300 15000 45.00

Water supply & Sanitary fittings @ 10% 4.50

Electrical installations @7% 3.15

Development charges of site @6% 2.70

Retaining walls charges @8% 3.60 Total 58.95

Say 59.00

B. TEMPORARY

At work sites 60 12000 7.20

Water supply, sanitary @8% 0.58

Electrical installations @5% 0.36

Development charges of site @6% 0.43

Retaining walls charges @8% 0.58

Total 8.57

Say 9.00 68.00



M PLANTATION

Sl.No. DESCRIPTION QTY UNIT RATE(Rs.)


1 Cost of planting trees along project roads, barrage/weir area, forebay reservoir banks and in the residential colonies and office area

10000 Nos 10.00 1.00

2 Cost of digging pits 10000 Nos 40.00 4.00

3 Cost of protection by barbed wire 10000 Rm 75.00 7.50

4 Beldar -2 no's for protection and plantation for 3 years @ Rs. 180 per day

2190 day 180.00 3.94

Total 16.44

Say 16.00



O. MISCELLANEOUS

Sl.No. DESCRIPTION QTY UNIT RATE(Rs.)


1 Capital cost of

Hospital (building and equipment) -Already considered in environmental cost

L.S. 0.00

Electrification L.S. 10.00

Water supply including purification & distribution L.S. 7.50

Sewage disposal & storm water drainage works

L.S. 7.50

Fire fighting L.S. 3.75

Telephone facilities L.S. 3.75

Post Office L.S. 1.50

Fountain L.S. 0.75

Construction Power L.S. 18.75

Construction of Creches L.S. 3.00

P.O.L. Pumps L.S. 3.75

Recreation Facilities L.S. 1.50

Wireless Communication L.S. 7.50

2 Maintenance & Service

Medical Assisstance for 4 years (taken separately in Environmental Cost)

3 0 0.00

Electrification @Rs.1 lac per year for 3 years. 3 1 3.00

Water supply including purification & distribution. Works @Rs.1 lac per year for 3 years.

3 1 3.00

Sewage disposal & storm water drainage works @Rs. 1 lac per year for 3 years.

3 1 3.00

Recreation @ Rs. 1 lac per year for 3 years. 3 1 3.00

Post office, telephone and telegraph office @Rs. 1 lac/year for 3 years.

3 1 3.00

Wireless communication system @Rs. 0.5 lacs per year for 3 years.

3 0.5 1.50

Security arrangements @Rs.1 5 lac/year for 3 years.

3 1.5 4.50

Fire fighting equipments @ Rs. 0.5 lac/year for 3 years.

3 0.5 1.50

Running and Maintenance of inspection vehicles @ Rs 5 lac/year for 3 years.

3 5 15.00

Running and Maintenance of transport for labour & staff @ Rs. 3 lac/year for 3 years.

3 3 9.00

Running & Maintenance of transit camps/ rest sheds/guest houses/rest houses/ inspection bungalows @Rs.9 lacs per year for 3 years.

3 9 27.00

Running and Maintenance of School @ Rs. 5 lac/year for 3 years.

3 5 15.00

Running and Maintenance of creches @ Rs. 1.5 lac/year for 3 years.

3 1.5 4.50

Other items

Visits of dignatories L.S. 3.00

Technical records, Photographic records etc L.S. 3.00

Inaugural and dedication ceremonies L.S. 3.00

Insurance to workmen L.S. 15.00

Boundary pillars and stones, distance marks and bench marks.

L.S. 3.00



Power supply including diesel generating sets as standby

L.S. 50.00

Models and exhibits L.S. 3.00

Publicity information L.S. 5.00

Subsidy for schools L.S. 3.00

Canteen facilities L.S. 1.50

Co-operative stores L.S. 3.00

Library facilities L.S. 1.50

Time keeping cabins L.S. 2.25

Seismological Studies L.S. 1.50

Providing flood warning system L.S. 1.50

Retrenchment compensation L.S. 15.00

Police station L.S. 3.00

Community centre L.S. 10.00

Photographic equipments L.S. 1.50

Completion Report L.S. 1.50

TOTAL 292.50

P MAINTENANCE

Sl.No. DESCRIPTION QTY UNIT AMOUNT (Rs. in lakhs)

1% of following works

C-Works 5,880.95

J- Power Plant -Civil Works 4,986.78

K- Buildings 117.60

M- Plantation 16.00

O - Miscellaneous 292.50

R - Communication 404.71

X - Environment, Ecology & Afforestation 140.00

TOTAL 11,838.54 1% of Total 118.39 Say 119.00



Q SPECIAL TOOLS AND PLANTS

Sl.No. DESCRIPTION QTY UNIT RATE (Rs. In lakhs)

% Utilisation

AMOUNT (Rs.in lakhs)

1 D.G. Sets 100 kw 1 Nos. 4 0.37 1.47 2 D.G. Set 200 KW 1 Nos. 8 0.37 2.93 3 Trucks 1 Nos. 14 0.55 7.70 4 Pick up vans 1.5 MT 1 Nos. 6.5 0.69 4.47 5 Buses, 52 seater 1 Nos. 15 0.55 8.25 6 Cars (Petrol) 1 Nos. 7 0.69 4.81 7 Jeeps(Petrol/Diesel) 1 Nos. 7 0.69 4.81 8 Ambulence Van 1 Nos. 9 0.69 6.19 9 Explosive Van 1 Nos. 7 0.375 2.63 10 C.F.Pump 10 HP 1 Nos. 0.3 0.46 0.14 11 C.F. Pump 20 HP 1 Nos. 0.4 0.46 0.18 12 Electric C.F. Pump 7.5 HP 1 Nos. 0.2 0.46 0.09 13 Wheel Dozer 180 HP 1 Nos. 25 0.37 9.17 14 Road Roller 1 Nos. 8.5 0.37 3.12 15 Jack Hammer (Rock Drill) 4 Nos. 0.5 0.37 0.73 16 Concrete Mixer 14/10 cft. 1 Nos. 2 0.37 0.73 17 Air Compressor 500 cfm(D) 1 Nos. 2 0.37 0.73 18 Mobile Crane 10 T 1 Nos. 20 0.37 7.33 19 Immersion Type Concrete Vibrator 1 Nos. 8.5 0.37 3.12 20 Water Sprinkler (7000) Litres with

Pump 1 Nos. 10 0.37 3.67

21 Dewatering Pump 5 HP 1 Nos. 0.2 0.37 0.07 22 Diesel Tanker 10 KL 1 Nos. 15 0.37 5.50 23 Petrol Tanker 8 KL 1 Nos. 13 0.37 4.77 24 Workshop Equipment LS 15.00

Cost of Personnel carriers (3,4,5,6,7,8)

36.23

Say 37.00 Cost of Q-Spl. T&P other than

personnel carriers 61.38

say 62.00

TOTAL 99.00



R COMMUNICATION



1 Project Roads 7 m wide (Average width). Surface dressing with two coats of bitumen over subgrade and soling,provision of retaining wall, guard rail wherever necessary including dewatering complete in all respect.

i)Road to Barrage 2.22 Km 60.00 133.20

ii)Road to Adit-2 0.81 Km 60.00 48.30

iii)Road to Surge Shaft top 0.14 Km 45.00 6.39

iv)Road to Adit-3 0.67 Km 60.00 40.26

v)Road to muck dumping yard-3 0.24 Km 60.00 14.22

vi)Road to powerhouse & Adit-4 1.00 Km 60.00 60.00

2 Bridge over Budhil stream 1.00 No. 0.00 0.00

3 Improvements to road from Kharamukh to Harsar & Bharmour Villages (easing of curves, strengthening of bridges etc.)

Job LS 50.00

4 Snow Clearance of approach roads

No. of years = 4, No. of months / year = 3

No. of hours/month = 30 x 4 = 120

Total no. of hours = 120 x 3 x 4 = 1440

Hourly Rate of Snow Cutter 1,440.00 hrs 2,015.00 29.02

Total Cost

TOTAL 381.39

Total without Tax 382.00

Construction workers cess tax @ 1% 3.82

Service Tax @ 4.944% 18.89

Total R works including Taxes 404.71



X ENVIRONMENT, ECOLOGY AND AFFORESTATION

Sl.No. DESCRIPTION QTY UNIT AMOUNT (Rs. in lakhs)

A Environment Management Plan

1 Compensatory Afforestation for diversion of forest land for the project

job L.S. 11.96

2 Fuel Supply to labour force + fuel depot job L.S. 23.64

3 Health Plan job L.S. 91.64

4 Redressal of Muck Disposal Site job L.S. 0.66

5 Training and Extension job L.S. 5.18

6 Redressal of Construction areas job L.S. 2.25

B Environment monitoring Plan

Environment Division job L.S. 4.93

TOTAL 140.25 say 140.00

Y LOSSES ON STOCK

Sl.No. DESCRIPTION Amount (in Lakhs)

Provision made @0.25 on the cost of I-works

less A-Preliminary, B-Land ,O-miscellaneous,M-Plantation,P-Maintenance,Q-Special T&P and X environment and ecology

28.47

Losses on stock 28.47

say 29.00



V RECEIPTS AND RECOVERIES

Sl.No. DESCRIPTION QTY RATE (Rs.)


1 Q-Special T&P @20% of Total value of Q-SPECIAL T&P 99.00 0.2 19.80

2 BUILDINGS

Cost recoverable on account of resale value of

temporary buildings @10.5% of cost of buildings for Residential Buildings.

30.32 0.105 3.18

Cost recoverable on account of resale value of

temporary buildings @15% of cost of buildings for Non- Residential Buildings

13.01 0.15 1.95

Total credit for receipt and recoveries 24.94

Say 46.00



ABSTRACT OF COST ESTIMATE FOR POWER EVACUATION FROM BHARMOUR I HEP (24 MW)

(Figures in Rs. Lacs)Sl. No. Description Amount

1 132 kV D/C Harsar I - Bharmour Pooling Station Transmission Line (Ring Main Scheme)- 10.8 KM (Refer 17-Cost Estimate H-I-BPS) 1369.59

2 132/220 kV Bharmour Pooling Station (Refer 17-Cost Estimate -BPS) 2782.10

3

220 kV S/C from Bharmour Pooling substation near Budhil dam (on left bank D/s of Budhil dam) to interconnecting point with existing 220 kV line near Budhil PH - 8km (Refer 17-Cost Estimate -BPS-IP) 1166.34

4 220 kV S/C Stringing on Connecting Point- Chamera III Transmission Line -20 KM (Refer17-Cost Estimate- IP C-III) 450.75

5 220 kV Receiving End Bay at Chamera III (Refer REB - C-III) 338.46

TOTAL FOR COMPOSITE SCHEME FOR FOLLOWING HEPS 6107.24

i Harsar I HEP (32 MW)

ii Harsar II HEP (20 MW)

iii Harsar III (Chobia) HEP (18 MW)

iv Bharmour I HEP (24 MW)

v Bharmour II HEP (21 MW)

Total Installed Capacity of the above HEPs -115 MW

Cost for Bharmour I HEP Power Evacuation on prorata installed capacity (MW) 1274.55

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 17-Cost Estimate H-I-BPS




ANNEXURE-D

ESTIMATE OF COST FOR 132 kV D/C RING MAIN TRANSMISSION SCHEME

Sl. No. Sub-Head Qty. Amount Total (km.) per /km. (Lakhs)

1 132kV D/C Transmission Line in Ring Main Scheme for Harsar-I, Harsar-II, Harsar-III (Chobia), Bharmour-I & Bharmour-II HEPs Annexure - D1

10.8 79.41 857.61

TOTAL 857.61

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 17-Cost Estimate BPS-IP


ABSTRACT OF COST ESTIMATE FOR 220 kV S/C TRANSMISSION LINE BETWEEN BHARMOUR

POOLING STATION (NEAR BUDHIL DAM) AND INTERCONNECTING POINT WITH EXISTING 220kV TRANSMISSION LINE NEAR BUDHIL POWER HOUSE

(Figures in Rs. Lacs)

Sl. No. Description Amount

1 Preliminary Works (Annexure - A) 6.00

2 Deatiled Surveying and Stacking (Annexure - B) 5.60 3 Compensation for land, trees, crops etc. incl. Forest trees &

compensatory afforestation (Annexure-C) 144.14

4 Transmission Line (Annexure - D) 750.15

SUB - TOTAL 905.89

5 Contingencies @3% on item 1 to 4 27.18

SUB -TOTAL 933.07

6 Departmental Charges @25% 233.27

GRAND TOTAL FOR TRANSMISSION SYSTEM 1166.34

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 17-Cost Estimate IP-C-III


Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 17-Cost Estimate REB-C-III


Cost Estimates of 220kV Bay EXTENSION AT CHAMERA-III

(Abstract for Cost Estimates for Electro Mechanical Works)

(Electrical Equipment for Switchyard)

S.No. Item Particular Unit Qty Rate

(Lakhs) Amoun

t

Excise duty @ Total

Amount Rate % Amount

1 2 3 4 5 6 7 8 6+8

1 SF6 CIRCUIT BREAKER

Circuit Breaker of 245 KV,50Hz ,3150 Amps ,40 KA/3secs, SF-6,duty 0-0.3sec-CO-3min-CO, Electrical motor operated(uni-polar operated) of 220 V dc , dual trip coil with capacitor tripping No 1 20.00 20.00 10.30% 2.06 22.06

2 CURRENT TRANSFORMERS

Current Transformer,220 KV Class, 40KA/3sec short time rating, Current Rating 600-300/(1-1-1-1-1)A & ,5 core in which core 1,2,4,5 of class-PS,Core of class PS, Core 3 of class 0.2s. No 3 5.50 16.50 10.30% 1.70 18.20

Current Transformer,220 KV Class, 40KA/3sec short time rating, Current Rating 600/(1-1)A & ,2 core in which core 1,2 of class-0.2s ,5 VA for the purpose of comercial metering No 3 5.50 16.50 10.30% 1.70 18.20

Current Transformer,220 KV Class, 40KA/3sec short time rating, Current Rating 600/1 A & ,1 core in which core 1 of class-0.2s ,5 VA for the purpose of comercial metering (optional item). No 3 5.50 16.50 10.30% 1.70 18.20

3 LIGHTNING ARRESTERS

Lightning Arrestors, 198 KV, with Porcelain housing, Metal Oxide type gapless, Discharge class 3, Nominal dischare current 10 KA No 3 1.10 3.30 10.30% 0.34 3.64

4 ISOLATORS

Isolators of 220 kV class, 800A, 40KA/3Sec short time rating, remote electrically cum manually operated double break with insulators and Marshalling box,without Earth Break Switch No 3 5.75 17.25 10.30% 1.78 19.03

Isolators of 220 kV class,800A, 40KA/3Sec short time rating, remote electrically cum manually operated double break with insulators and Marshalling box,with Earth Break Switch No 1 6.25 6.25 10.30% 0.64 6.89

5 POTIENTIAL TRANSFORMERS

Potential Transformers of 220 KV Class, Voltage Rating (220 KV/√3)/( 110V/√3)–(110V/√3),2 cores in which, Core 1,2 is of class 0.2s,10 VA for the purpose of commercial metering No

3

5.50 16.50 10.30% 1.70 18.20

Potential Transformers of 220 KV Class, Voltage Rating (220 KV/√3)/( 110V/√3),2 cores in which, Core 1 is of class 0.2s,10 VA for the purpose of commercial metering(optional item). No

3

5.50 16.50 10.30% 1.70 18.20

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 17-Cost Estimate REB-C-III


6

Capacitive Voltage Transformers of 220 kV Class,2 Core of Voltage Rating (220 KV/√3)/( 110V/√3)–(110V/√3) in which core 1 is of class 3P for Protection 50 VA,Core 2 of 0.2,50 VA for Metering No

3

5.50 16.50 10.30% 1.70 18.20

7 CONTROL & PROTECTION PANEL

220 Kv Feeder Control and Protection Panel Set 1 18.00 18.00 10.30% 1.85 19.85

220kV Busbar Protection Pheripheral unit Set 1 1.00 1.00 10.30% 0.10 1.10

8 245 kV Bus Post Insulator Lot 1 1.00 1.00 10.30% 0.10 1.10

9

220 kV ,800 A 0.5mH,40 kA/3 sec short time rating Wave Trap suitable for pedestal mounting and complete with main coil,lightning arrester,tuning potand bridge barriers and insulator stack No 2 3.5 7.00 10.30% 0.72 7.72

10 Control and Power Cables (different rating and sizes) copper cable L.S 1 8 8.00 10.30% 0.82 8.82

11 Cable trays and accessories for switchyard L.S 1 1 1.00 10.30% 0.10 1.10

12

Ground mat and Earthing for Switchyard L.S 1 2 2.00 10.30% 0.21 2.21

13 PLCC Equipment set 1 30 30.00 10.30% 3.09 33.09

14 Sub Total(1-13) 213.80 22.02 235.82

15 220 Kv Bus bar Material L.S 1 2.00 2.00 10.30% 0.21 2.21

16 Commercial Metering Box including 2 Nos TVMs set 1 2.00 2.00 10.30% 0.21 2.21

Commercial Metering Box including 1 No TVM (optional item) set 1 1.00 1.00 10.30% 0.10 1.10

17 Spares for item no.14 @ 3% 6.41 10.30% 0.66 7.07

18 Sub -total (15 - 17) 11.41 1.18 12.59

19 Total (14 & 18) 248.41

20 Centeral Sales Tax @ 2% on 19 4.97

21 Transportation & Insurance @ 6% on 19 14.90

22 Errection and Commissioning @ 8% on 19 excl. spares 19.87

23 Sub-total (19+20+21+22) 288.16

24 Service Tax @ 12.36% on (21 + 22) 4.30

25 Sub Total (23 + 24) 292.46

26 Contingencies @ 3% 8.77

27 Departmental charges @ 11% 33.14

28 Service tax 12.36% on dept. charges 4.10

29 Total (25+26+27+28) 338.46

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 17-Cost Estimate BPS


Cost Estimates of BHARMOUR POOLING Sub Station (220/132 kV)

(Abstract for Cost Estimates for Electro Mechanical Works)

(Electrical Equipment for Switchyard)


(Lakhs) Amount

Excise duty @ Total


1 2 3 4 5 6 7 8 6+8

220/132kV Single Phase Step-up Auto Transformer and Associated Switchyard Equipments

1

220/132kV, Single Ph, Step-up Auto Transformer -25/30 MVA ONAN/ONAF along With Neutral current transformer of 300/(1-1)A core-1,Cl:PS ,Core 2,CL:5P20, Rate:Rs 600/KVA No 6 180.00 1080.00 10.30% 111.24 1191.24 Fire Protection for Step-Up Transformer by Nitrogen Injection No 6 1.00 6.00 10.30% 0.62 6.62 Station Service Transformer for the purpose of Aux Power supply (rating 250 KVA,11/0.433 kV) ,Rate:Rs 600/KVA No 2 1.50 3.00 10.30% 0.31 3.31

2 SF6 CIRCUIT BREAKER

Circuit Breaker of 245 KV,50Hz ,3150 Amps ,40 KA/3secs, SF-6,duty 0-0.3sec-CO-3min-CO, Electrical motor operated(uni-polar operated) of 220 V dc , dual trip coil with capacitor tripping No 3 20.00 60.00 10.30% 6.18 66.18

Circuit Breaker of 132 KV,50Hz ,1250Amps ,40 KA/3secs, SF-6,duty 0-0.3sec-CO-3min-CO, Electrical motor operated(uni-polar operated) of 220 V dc , dual trip coil with capacitor tripping No 4 8.58 34.32 10.30% 3.53 37.85

3 CURRENT TRANSFORMERS

Current Transformer,220 KV Class, 40KA/3sec short time rating, Current Rating 600-300/(1-1-1-1-1)A & ,5 core in which core 1,2,4,5 of class-PS,Core of class PS, Core 3 of class 0.2s. No 9 5.50 49.50 10.30% 5.10 54.60

Current Transformer,220 KV Class, 40KA/3sec short time rating, Current Rating 600/(1-1)A & ,2 core in which core 1,2 of class-0.2s ,5 VA for the purpose of comercial metering No 3 5.50 16.50 10.30% 1.70 18.20

Current Transformer,220 KV Class, 40KA/3sec short time rating, Current Rating 600/1 A & ,1 core in which core 1 of class-0.2s ,5 VA for the purpose of comercial metering (optional item). No 3 5.50 16.50 10.30% 1.70 18.20

Current Transformer,132 KV Class, 40KA/3sec short time rating, Current Rating 850-600-450-300-150/1-1-1-1A & ,4 core in which core 1,4 of class-PS,Core 2 of class 5P20, Core 3 of class 0.2s. No 12 1.18 14.16 10.30% 1.46 15.62

4 LIGHTNING ARRESTERS

Lightning Arrestors, 198 KV, with Porcelain housing, Metal Oxide type gapless, Discharge class 3, Nominal dischare current 10 KA No 9 1.10 9.90 10.30% 1.02 10.92

Lightning Arrestors, 96 KV, with Porcelain housing, Metal Oxide type gapless, Discharge class 3, Nominal dischare current 10 KA

No 12 0.90 10.80 10.30% 1.11 11.91

5 ISOLATORS



Isolators of 220 kV class, 800A, 40KA/3Sec short time rating, remote electrically cum manually operated double break with insulators and Marshalling box,without Earth Break Switch No 5 5.75 28.75 10.30% 2.96 31.71

Isolators of 220 kV class,800A, 40KA/3Sec short time rating, remote electrically cum manually operated double break with insulators and Marshalling box,with Earth Break Switch No 1 6.25 6.25 10.30% 0.64 6.89

Isolators of 132kV class, 1250 A, 40KA/3Sec short time rating, remote electrically cum manually operated double break with insulators and Marshalling box,without Earth Break Switch No 5 2.97 14.85 10.30% 1.53 16.38

Isolators of 132kV class, 1250 A, 40KA/3Sec short time rating, remote electrically cum manually operated double break with insulators and Marshalling box,with Earth Break Switch No 2 2.97 5.94 10.30% 0.61 6.55

6 POTIENTIAL TRANSFORMERS

Potential Transformers of 220 KV Class,Connected to Bus, Voltage Rating (220 KV/√3)/( 110V/√3)–(110V/√3),2 cores in which, Core 1 is of class 3P for protection,50 VA, Core 2 of 0.2,50VA FOR metering

No

3

5.50 16.50 10.30% 1.70 18.20

Potential Transformers of 220 KV Class, Voltage Rating (220 KV/√3)/( 110V/√3)–(110V/√3),2 cores in which, Core 1,2 is of class 0.2s,10 VA for the purpose of commercial metering No

3

5.50 16.50 10.30% 1.70 18.20

Potential Transformers of 220 KV Class, Voltage Rating (220 KV/√3)/( 110V/√3),2 cores in which, Core 1 is of class 0.2s,10 VA for the purpose of commercial metering(optional item).

No

3

5.50 16.50 10.30% 1.70 18.20

Potential Transformers of 132 KV Class,Connected to Bus, Voltage Rating (132 KV/√3)/( 110V/√3)–(110V/√3),2 cores in which, Core 1 is of class 3P for protection,50 VA, Core 2 of 0.2,50VA FOR metering

No

3

1.14 3.42 10.30% 0.35 3.77

7

Capacitive Voltage Transformers of 220 kV Class,2 Core of Voltage Rating (220 KV/√3)/( 110V/√3)–(110V/√3) in which core 1 is of class 3P for Protection 50 VA,Core 2 of 0.2,50 VA for Metering

No

3

5.50 16.50 10.30% 1.70 18.20

8 CONTROL & PROTECTION PANEL

132/220kV Auto Transformer Control & Protection Panel Set 2 22.00 44.00 10.30% 4.53 48.53

220 Kv Feeder Control and Protection Panel Set 1 18.00 18.00 10.30% 1.85 19.85

220kV Busbar Protection Panel Set 1 18.00 18.00 10.30% 1.85 19.85

132 kV feederControl and Protection Panel Set 2 16.00 32.00 10.30% 3.30 35.30

9 245 kV Bus Post Insulator Lot 1 4.40 4.40 10.30% 0.45 4.85

132 kV Bus Post Insulator Lot 1 4.40 4.40 10.30% 0.45 4.85

10

SCADA System with two no Operator work station,1 No Engineering work station,1 No Gateway Station,1 no Laser work Station,2 No Inverters,1no Laser printer,1 no Dot matrix Printer with complete set up including Ethernet switches LIV,and all other accessories. Lot 1 40.00 40.00 10.30% 4.12 44.12



11 220 kV ,800 A 0.5mH,40 kA/3 sec short time rating Wave Trap suitable for pedestal mounting and complete with main coil,lightning arrester,tuning potand bridge barriers and insulator stack No 2 3.5 7.00 10.30% 0.72 7.72

12 Control and Power Cables (different rating and sizes) copper cable L.S 1 75 75.00 10.30% 7.73 82.73

13 Cable trays and accessories for switchyard L.S 1 10 10.00 10.30% 1.03 11.03

14 Ground mat and Earthing for Switchyard L.S 1 15 15.00 10.30% 1.55 16.55

15 PLCC Equipment set 1 30 30.00 10.30% 3.09 33.09

16 DC Batteries

DC Batteries,Battery Charger Equipment,DC Distribution Board with DC Switchgear(Rating 220 V,250 AH) No 2 17 34.00 10.30% 3.50 37.50

DC Batteries,Battery Charger Equipment,DC Distribution Board with DC Switchgear for PLCC (Rating 48V,250 AH) No 1 1.7 1.70 10.30% 0.18 1.88

17 LTAC Switchboards for Aux Power Supply to Outdoor Switchyard Complete No 1 2.5 2.50 10.30% 0.26 2.76

18 Air Conditioning Lot 2 0.5 1.00 10.30% 0.10 1.10

19 Diesel Generating Set (rating 63 KVA) No 1 2 2.00 10.30% 0.21 2.21

20 Sub Total(1-19) 1764.89 181.78 1946.67

21 Structures,fencing and hardware etc Ton 5 0.88 4.40 10.30% 0.45 4.85

22 132 KV Bus bar Material L.S 1 12.00 12.00 10.30% 1.24 13.24

220 Kv Bus bar Material L.S 1 14.00 14.00 10.30% 1.44 15.44

23 Commercial Metering Box including 2 Nos TVMs set 1 2.00 2.00 10.30% 0.21 2.21

Commercial Metering Box including 1 No TVM (optional item) set 1 1.00 1.00 10.30% 0.10 1.10

24 Spares for item no.20 @ 3% 52.95 10.30% 5.45 58.40

25 Sub -total (21 - 24) 86.35 8.89 95.24

26 Total (20 & 25) 2041.91

27 Centeral Sales Tax @ 2% on 26 40.84

28 Transportation & Insurance @ 6% on 26 122.51

29 Errection and Commissioning @ 8% on 26 excl. spares 163.35

30 Sub-total (26+27+28+29) 2368.62

31 Service Tax @ 12.36% on (28 + 29) 35.33

32 Sub Total (30 + 31) 2403.95

33 Contingencies @ 3% 72.12

34 Departmental charges @ 11% 272.37

35 Service tax 12.36% on dept. charges 33.66

36 Total (32+33+34+35) 2782.10



Cost estimates of Bharmour Stage-I Hydro Electric Project (3 X 8 MW)

(Abstract of Cost Estimate of Electro Mechanical Works)

S.No. Item Qty. Rate Unit Amount

( Rs. In lakhs)

1 2 3 4 5 6 A Generating Station Equipment 1 Preliminary - Annex-S (1) 105.00

2 Generating Plant & Equipment

a) Generating turbine & accessories - Annex- S (2) 2,185.18

b) Auxiliary electrical equipment for power station -Annex-S (3) 897.51

c) Auxiliary Mechanical equipment and services for power

station- Annex-S (4) 173.82

Sub Total (2a, 2b & 2c) 3,256.51

d) Central Sales Tax @ 2% on 2 a), b), c) 65.13

e) Transportation, handling and insurance charges @ 6% of 2 a),

b), c) 195.39

f) Erection & Commissionning charges @ 8% of 2 a), b), c)

excluding spares 250.55

Total (Generating Plant & Equipment) 3,767.58

3 a) 145kV Substation Equipment - Annex-S (5) 441.14

b) Central Sales Tax @ 2% on 3 a) 8.82 c) Transportation, handling and insurance charges @ 6% of 3 a) 26.47

d) Erection & Commissionning charges @ 8% of 3 a) excluding

spares 34.47

Total (Substation equipment, receiving end bay and

auxiliary equipment & service of Switchyard) 510.90

4 Sub-Total ( Items 1 to 3)

4,383.48

5 Service Tax (as applicable) on 1,2e, 2f, 3c, 3d, (incl.

Consultancy Charges) @ 10.3% 63.02

6 Grand Total 4,446.50



Annex-S(1)

Cost estimates of Bharmour Stage-I Hydro Electric Project (3 X 8 MW) (Abstract of Cost Estimate of Electro Mechanical Works)

Preliminary

S.No. Item / Particulars Qty. Rate Amount Excise duty Total

( Rs. In lakhs) Rate Amount

1 2 3 4 5 6 7 5 +7

1 Consultancy charges / studies including all investigation

L.S. 105.00 105.00

Total 105.00 105.00



Annex- S(2) Cost estimates of Bharmour Stage-I Hydro Electric Project (3 X 8 MW)


(Turbine, Generator and Accessories )

Sl.N. Item/ Particulars Unit Qty.

Unit Rate

(Rs. In Lakhs)

Amt.

Excise Duty Total

(Rs. in Lakhs) Rate(%) Amt.

1 2 3 4 5 6 7 8 6+8

1

a) Horizontal Shaft Francis Turbine Units each of 8.29 MW (with 15% COL), 428.60 rpm, 93.0 m Head complete with steel housing and nozzles with allied equipments such as suitable bearings system and lubrication system (Including first fill of oil).

Sets 3 165.80 497.40 10.30% 51.23 548.63

b) Microprocessor based Electrohydraulic Governer with Digital control, Oil Pressure Pumping Units, Pressure Vessel, piping components and their accessories

Sets 3 30.00 90.00 10.30% 9.27 99.27

c) Horizontal Shaft Synchronous Generator of 8 MW rating 428.60 rpm, 0.9 pf, 50 Hz, 11 kV generating voltage and with inherent continuous overloading of 15% complete with air cooler, Brushless Excitation system with digital AVR with auxilliary excitation equipment

Sets 3 216.00 648.00 10.30% 66.74 714.74

d) Microprocessor based programmable logic controllers for units and plant (Auto Sequence control and data logging system for power house) with Auto Synchronizer

Set 1 120.00 120.00 10.30% 12.36 132.36

e) Cooling water system complete with pumps, strainers, piping, fitting with all electrical and mechanical accessories

Lot 1 60.00 60.00 10.30% 6.18 66.18

f) OPU with N2 Accumulator / Compressed Air System (if required) complete with all electrical and mechanical accessories including air pressure vessels for governor oil system and for Brakes

Set 3 12.00 36.00 10.30% 3.71 39.71

g) Drainage & Dewatering Lot 1 40.00 40.00 10.30% 4.12 44.12

2 Spare on item (1) at 5 % 72.57 10.30% 7.47 80.04

3 Total of item (1 & 2) 1,563.97 161.09 1,725.06



4 A) 11 KV, XLPE cable for Generator & 11 kV Switchboard connection of required length along with three (3) sets of surge protection & Neutral Earthing System.

LS 1 60.00 60.00 10.30% 6.18 66.18

B) Control & Protection Relay Panel for Generator set 3 25.00 75.00 10.30% 7.73 82.73

5 MIV Butterfly Valve (Φ =1500 mm)

Nos 3 90.00 270.00 10.30% 27.81 297.81

6 Spares @ 3% of item 4 to 5 12.15 10.30% 1.25 13.40

7 Sub Total (Item 4 to 6)

417.15 42.97 460.12

Grand Total of item (3 & 7)) 1,981.12 204.06 2,185.18





(Auxiliary Electrical Equipment for Power Station )

Sl.N. Item/ Particulars Unit Qty. Unit rate

Amt. Excise Duty

Total (Rs. in Lakhs) Rate(%) Amt.

1 2 3 4 5 6 7 8 6+8

1 Step up Single phase transformer including oil for first filling, transformer cooling equipment.Rating 11/132 KV, 11 MVA

No 4 82.50 330.00 10.30% 33.99 363.99

2 Station Service Transformer (Rating 500 kVA, 11/.433 KV Dry type) No 2 7.50 15.00 10.30% 1.55 16.55

3 11 KV Distribution Board for auxiliary power supply (consists of 6 feeders/VCBs) L.S 1 64.00 64.00 10.30% 6.59 70.59

4 LT AC Switchboards for aux. Power supply to power house and outdoor switchyard complete. LS 1 60.00 60.00 10.30% 6.18 66.18

5 DC Batteries, Battery charging equipment, D.C. Distribution Board with D.C. switchgear (Rating 220 V, 600 AH)

No 2 42.00 84.00 10.30% 8.65 92.65

6 11kV, cable (between 11 kV Switchboard & bank of Step-up transformers)

Lot 1 20.00 20.00 10.30% 2.06 22.06

7 Communication System(Public Address System,EPABX etc.) L.S 1 2.00 2.00 10.30% 0.21 2.21

8 Diesel generating set (Rating 200 KVA) for Power House No 1 30.00 30.00 10.30% 3.09 33.09

9 Control & Power cables (Different Rating & sizes) copper cable L.S 1 75.00 75.00 10.30% 7.73 82.73

10 Cable racks and accessories (Tons) for P.H & Switchyard L.S 1 10.00 10.00 10.30% 1.03 11.03

11 Ground mat and earthing for P.H & Switchyard area L.S 1 30.00 30.00 10.30% 3.09 33.09

12 Illumination of Dam, Power House,Switchyard etc. L.S 1 30.00 30.00 10.30% 3.09 33.09

13 Electric Test Laboratory & Oil filtration plant L.S 1 30.00 30.00 10.30% 3.09 33.09

14 16 kVA UPS System with Batteries etc & 415V, AC Distribution Board Lot 1 10.00 10.00 10.30% 1.03 11.03

15 Sub. Total (items 1 to 14) 790.00 81.37 871.37

16 Spares for items 15 @ 3% 23.70 10.30% 2.44 26.14

Grand Total (15 & 16) 897.51





(Auxiliary Mechanical Equipment and Services for Power Station )

Sl.No. Item/ Particulars Unit Qty. Rate Amt. Excise Duty Total

(Rs. in Lakhs) Rate(%) Amt.

1 2 3 4 5 6 7 8 6+8

1 Electrical Overhead Travelling crane (Capacity 80/20 T)

No. 1 88.00 88.00 10.30% 9.06 97.06

2

Fire fighting equipment with Portable Fire Extinguishers including fire protection for Generator Transformer by Nitrogen Injection

Lot 1 20.00 20.00 10.30% 2.06 22.06

3 Air conditioning, ventilation and heating equipment.

Lot 1 15.00 15.00 10.30% 1.55 16.55

4 Filtered water supply system for power house.

Lot 1 2.00 2.00 10.30% 0.21 2.21

5 Oil handling equipment with pipes, valves, tanks, purifiers.

Set 1 18.00 18.00 10.30% 1.85 19.85

6 Workshop Machines and equipment L.S. 1 10.00 10.00 10.30% 1.03 11.03

7 Sub-Total 153.00 15.76 168.76

8 Spares for item No. 7 @ 3% 4.59 10.30% 0.47 5.06

Total (Item No. 7 & 8) 173.82




(Abstract of Cost Estimate of Electro Mechanical Works) (Substation Equipment, receiving end bay & Aux. Equipment & Services for Switchyard )


(Lakhs) Amount

Excise duty @ Total


1 2 3 4 5 6 7 8 6+8

145 kV Switchyard Equipments

1 145 KV, 3150A, 40kA/3 sec. Gang Operated SF6 Circuit Breaker

No 3 12.00 36.00 10.30% 3.71 39.71

2 145 kV PT Nos 9 4.00 36.00 10.30% 3.71 39.71

3 145 kV Current Transformer Nos 9 4.50 40.50 10.30% 4.17 44.67

4 120 kV Lightning Arrestors with Surge Monitors

Nos 9 0.90 8.10 10.30% 0.83 8.93

5 145 kV Horizontal Centre Rotated Double Break Isolator with ES including Insulator

No 2 4.50 9.00 10.30% 0.93 9.93

6 145 kV Horizontal Centre Rotated Double Break Isolator without ES including Insulator

No 4 4.00 16.00 10.30% 1.65 17.65

7 Control & Protection Panel for (3 no O/G + 1 no Transformer I/C)+ Bus Bar Protection Panel

Set 4 40.00 160.00 10.30% 16.48 176.48

8 145 kV Bus Post Insulator Lot 1 6.00 6.00 10.30% 0.62 6.62 9 Metering system consisting PT,

CT & TVMs (Main & Check and Backup)

Set 2 9.00 18.00 10.30% 1.85 19.85

10 Sub -total (1 -9) 311.60 32.09 343.69

11 Structures, fencing and hardware etc

Ton 60 0.90 54.00 10.30% 5.56 59.56

12 Bus bar Material L.S 1 25.00 25.00 10.30% 2.58 27.58

13 Spares for item no. 10 @ 3% 9.35 10.30% 0.96 10.31

14 Sub -total (11 - 13) 88.35 9.10 97.45

Total (10 & 14) 441.14

Note: OPGW forms part of T.L.

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 18-Financial & Economic Evaluation


18. FINANCIAL & ECONOMIC EVALUATION

18.1 GENERAL

The Bharmour Stage-I HEP (24 MW) (BHEP-I) & Bharmour Stage-II HEP (21 MW) (BHEP-II)

are proposed to be operated in tandem, therefore, the total estimated cost of both the projects

have been added together for the purpose of financial analysis.

The estimated cost including transmission line of BHEP-I is Rs.208.75 Crores and BHEP-II is

Rs.138.28 Crores (excluding IDC, Escalation, financial charges, CAT & LADA) at August, 2014

price level. Similarly, the estimated cost excluding transmission line of BHEP-I is Rs.196.00

Crores and BHEP-II is Rs.127.13 Crores (excluding IDC, Escalation, financial charges, CAT &

LADA) at August, 2014 price level.

Considering an escalation during construction stage of 36 months for each project at 5% per

annum for Civil Works and 2% per annum for Electro Mechanical works, the escalated cost,

IDC, FC, LADA and CAT of combination of both the HEP’s including and excluding cost of

transmission line are estimated to Rs. 421.80 Crores and Rs. 393.64 Crores respectively. The

details are given in Chapter-17: ‘Cost Estimates’.

Pre-construction activities and infrastructure development works for BHEP–I would be carried

out prior to start of the main civil works. A total construction period of 36 months has been

considered for completion of the project excluding 6 months for preconstruction activities.

Both the projects are estimated to be financed in a Debt Equity ratio of 70:30, with the financing

terms including Interest of 12.5% per annum on loan and Loan repayment of 12 years post

construction including five years moratorium period.

The Design Energy (Energy at 95% plant availability) of the BHEP-I & BHEP-II is assessed as

115.36 MU & 100.70 MU respectively at the generator terminals. After considering the allowance

for the losses and free power to HPSEB, Net saleable energies have been estimated as 178.77

MU for first twelve years of operation and 168.13 MU for beyond 12 years.

The financial analysis have been carried out following the applicable CERC tariff norms, which

inter-alia allows 15.5% post-tax return on the equity are given in the Annexures-18. The

combined first year and Levelised tariff including transmission line is worked out to Rs. 5.13 per

kWh and Rs. 4.68 per kWh respectively. Similarly, the combined first year and Levelised tariff

excluding transmission line is worked out to Rs. 4.79 per kWh and Rs. 4.36 per kWh

respectively.

18.2 ASSUMPTIONS

The major assumptions and findings of the analysis are given below for the both projects of

BHEP-I & BHEP-II having capacities of 24 MW & 21 MW respectively:



18.2.1 Combined Project Cost

Description Without Transmission Line (Rs. in Crores)

With Transmission Line (Rs. in Crores)


Escalation 16.49 17.24 Fund Management Expences

2.76 2.95

Interest During Construction

35.91 38.12

CAT Charges @ 2.5% 9.46 10.13

LADA Charges @ 1.5% 5.90 6.33

Total Project Cost 393.64 421.80

Cost per MW 8.75 9.37

18.2.2 Capital Structure (Rs. in Crores)

Description Without Transmission Line (Rs. in Crores)

With Transmission Line (Rs. in Crores)

Equity (30%) 118.09 126.54

Debt (70%) 275.55 295.26

Total 393.64 421.80

18.2.3 Debt Financing Terms

Term of Loan (Post construction)

Including 5 years moratorium period 12 years

Interest Rate on loan 12.5%

Interest on working capital 12.5%

18.2.4 Plant Details

Unit Capacity BHEP-I & BHEP-II 8.0 MW & 7.0MW respectively

No of Units 3 units for each project

Plant Gross Capacity of BHEP-I & BHEP-II 24.0 MW & 21.0 MW

Auxiliary Consumption 0.25 %

Transformation Loss 0.5 % of generated energy

Transmission losses 0.75% of generated energy

18.2.5 Saleable Energy Details for Both Projects

Total Energy Billed in Million Units for first 12 years in MU 178.77

Total Energy Billed in Million Units from 13th to 40th Year in MU 168.13



18.2.6 Return of Equity

ROE considered, as per CERC Norms 15.5%

18.2.7 O & M

Annual O&M as a % of Project Cost 4.00 %

Annual O&M Escalation 2.50%

18.2.8 Taxes

Tax Exemption u/s 80 I for 10 years 100%

Tax rate under MAT provisions 20.01%

Tax rate under normal provisions 33.2%

18.2.9 Working Capital

Interest on Working Capital 12.5 %

18.2.10 Depreciation

Depreciable Value 90%

18.2.11 DSCR Summary

Maximum DSCR 1.90

Minimum DSCR 1.15

Average DSCR 1.29

18.2.12 Tariff (Calculated as per CERC Norms)

Description Without Transmission


With Transmission Line (in Rs. Crores)

First Year Tariff for Combined Projects

4.79 5.13

Levelized Year Tariff for Combined Projects

4.36 4.68

18.3 CONCLUSION

The financial parameters mentioned above suggest that Bharmour-I Hydro Electric Project is

technically feasible & economically viable for implementation. With easy accessibility to the

project, it can be taken up for infrastructure development and active construction immediately.



Annexure-18

FINANCIAL STATEMENTS FOR COMBINED PROJECTS (Bharmour-I & Bharmour-II HEP's)

(Without Transmission)

Construction Period (Yrs) 3.00

CAPITAL COST (Rs.Crores) 393.64

Cost per MW (Rs. / crores ) 8.75

DEBT/EQUITY RATIO (70%:30%) 2.33 :1

RATE OF INTEREST ON LOAN 12.5%

Income Tax Rate (%) 33.22%

Tax Relief 100% For 10 years

REPAYMENT OF LOAN Yrs 12

TARIFF RATE Rs/Kwh 4.79

Yr 1-12 Yr 13-30 Yr 31-40

ANNUAL GENERATION (Million Unit)

90% Dependable year based on annual runoff at 95% plant availability 216.06 216.06 216.06

Free Power For 1st 12 Years, 13 to 30 years and thereafter 16.00% 21.00% 21.00%

AUXILIARY CONSUMPTION 0.25% 0.25% 0.25%

Transformation Losses 0.50% 0.50% 0.50%

TRANMISSION CHARGES/ LOSSES 0.75% 0.75% 0.75%

NET SALEABLE ENERGY (Million Unit) 178.77 168.13 168.13

INDICATORS

TARIFF COST Ist Year Rs/kWh 4.79

Levellized Rs/kWh 4.36

MINIMUM DSCR 1.15

MAXIMUM DSCR 1.90

AVERAGE DSCR 1.29



FINANCIAL STATEMENTS FOR COMBINED PROJECTS (Bharmour-I & Bharmour-II HEP's)

(With Transmission)

Construction Period (Yrs) 3.00

CAPITAL COST (Rs.Crores) 421.80

Cost per MW (Rs. / crores ) 9.37

DEBT/EQUITY RATIO (70%:30%) 2.33 :1

RATE OF INTEREST ON LOAN 12.5%

Income Tax Rate (%) 33.22%

Tax Relief 100% For 10 years

REPAYMENT OF LOAN Yrs 12

TARIFF RATE Rs/Kwh 5.13

Yr 1-12 Yr 13-30 Yr 31-40

ANNUAL GENERATION (Million Unit)

90% Dependable year based on annual runoff at 95% plant availability

216.06 216.06

216.06

Free Power For 1st 12 Years, 13 to 30 years and thereafter 16.00% 21.00% 21.00%

AUXILIARY CONSUMPTION 0.25% 0.25% 0.25%

Transformation Losses 0.50% 0.50% 0.50%

TRANMISSION CHARGES/ LOSSES 0.75% 0.75% 0.75%

NET SALEABLE ENERGY (Million Unit)

178.77 168.13

168.13

INDICATORS

TARIFF COST Ist Year Rs/kWh 5.13

Levellized Rs/kWh 4.68

MINIMUM DSCR 1.15

MAXIMUM DSCR 1.90

AVERAGE DSCR 1.29



Annexure-18.2 ASSUMPTIONS FOR TARIFF CALCULATIONS (Without Transmission Line)

S.NO. PARTICULARS Proposed

I Capacity for Bharmour-I HEP & Bharmour-II HEP 24 MW & 21 MW

= 45.0 = (3X8 MW) + (3x7 MW)

Crores contingen preop basic escalation finance fee idc total

II Project Cost for BHEP-I & BHEP-II (Rs crores)

Land 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Building & Civil Works - 208.05 0.00 19.38 227.44 11.61 1.94 25.28 266.26

Plant & Machinery (E&M and Transmission) - 87.53 0.00 8.15 95.68 4.88 0.82 10.63 112.02

Misc Fixed Assets 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Technical Know how 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Environmental Ecology - 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Preliminary exps 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

total 295.58 0.00 27.54 323.12 16.49 2.76 35.91 378.28 Esca+fina+idc

0.00 378.28 for the

total 295.58 purpose

add preop expns 27.54 year 1 year 2 year 3 year 4 year 5 total of dep

Building & Civil Works 15.00% 40.00% 45.00% 0.00% 0.00% 100%

Plant & Machinery (E&M and Transmission) 10.00% 25.00% 65.00% 0.00% 0.00% 100%

Basic Cost - 208.05 31.21 83.22 93.62 0.00 0.00 208.05 Civil

87.53 8.75 21.88 56.89 0.00 0.00 87.53 E&M

* total - 295.58 39.96 105.10 150.52 0.00 0.00 295.58

Basic Cost (Escalated ) 312.08 39.96 109.70 162.41 0.00 0.00 312.08

add contingencies 0% 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Technical Know how 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Pre operating Expenses 27.54 4.13 11.01 12.39 0.00 0.00 27.54

Financial Management - 2.76 2.76 0.00 0.00 0.00 0.00 2.76

Interest During Construction - 35.91 2.11 9.85 23.95 0.00 0.00 35.91

Margin money for Working Capital 0.00 0.00 0.00 0.00 0.00 0.00 0.00

CAT @ 2.5% of Total Cost 9.46 1.42 3.78 4.26 0.00 0.00 9.46

LADA @ 1.5 % of Total Project Cost 5.90 0.89 2.36 2.66 0.00 0.00 5.90

Preliminary exps 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total - 393.64 51.26 136.71 205.67 0.00 0.00 393.64

III * Escalation (% ) Civil 5.00% 1.00 1.05 1.10

E&M 2.00% 1.00 1.02 1.04

IV Cost per MW (Rs. / crores ) - 8.75



V Construction Period (Yrs) 3.00

VI Financing Promotors

Debt 70% INDIAN

Equity 30% 100%

Equity

- (%age of project cost) - 30% 100%

- (Rs crores) 118.09 118.09

Debt

- (%age of project cost) 70% 70%

- (Rs crores) - 275.55 275.55

Construction Period 3.00 3.00

- Moratorium (Yrs) - 5.00 5.00

- Repayment (Yrs) - 12.00 12.00

- Interest ( % ) ON LOANS 0.00 12.50%

VII Return on Equity (%)

NORMAL 15.50%

VIII FINANCIAL EXPNS FM Exp.on loan from FIs (%) 1.00%

IX Interest on Working Capital (%) 12.50%

XII O&M (including insurance)

- Cost as % of project cost 4.00%

- Escalation factor 2.50%

X Income Tax Rate (%) 33.22% Tax Relief 100.00% For 10 years

XII Depreciation

Depreciation (As per ES Act.) 3.40%

Depreciation (As per IT Act.) 15.00%

Total Depreciable Amount 90.00%

XII Capital Subsidy (Not Considered) 0.00 crores

Annual CDM Benefit (Not Considered) 0.00 Crores/ year

XIII ENERGY CALCULATION



a Energy Generation (MU) at 100% available 219.40 Million units PLF 55.66%

aa Design Energy

b Energy Generation at 75 dependable year

with 95% plant availability 216.06 216.06 PLF 54.81% 0.000

d Auxiliary consumption (%) 0.25% 0.54 0.54 0.50% 0.00

e Transformation Losses (%) 0.50% 1.08 1.08 0.50% 0.00

Transmission losses (%) 0.75% 1.62 1.62 0.75% 0.00

f Net Energy 212.82 212.82 0.00

i Free Power (%) For 1st 12 Years For 13 to 30 year For 31 to 40 year

16.00% 21.00% 21.00%

Total Energy Loss 34.05 44.69 44.69

Remaining Energy for Sale 178.77 168.13 168.13



ASSUMPTIONS FOR TARIFF CALCULATIONS (With Transmission Line)

S.NO. PARTICULARS Proposed

I Capacity for Bharmour-I HEP & Bharmour-II HEP 24 MW & 21 MW

= 45.0 = (3X8 MW) + (3x7 MW)

Crores contingen preop basic escalation finance fee idc total

II Project Cost for BHEP-I & BHEP-II (Rs crores)

Land 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Building & Civil Works - 208.05 0.00 17.93 225.99 11.23 1.92 24.83 263.97

Plant & Machinery (E&M and Transmission) - 111.43 0.00 9.60 121.03 6.01 1.03 13.30 141.37

Misc Fixed Assets 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Technical Know how 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Environmental Ecology - 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Preliminary exps 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

total 319.48 0.00 27.54 347.02 17.24 2.95 38.12 405.34 Esca+fina+idc

0.00 405.34 for the

total 319.48 purpose

add preop expns 27.54 year 1 year 2 year 3 year 4 year 5 total of dep

Building & Civil Works 15.00% 40.00% 45.00% 0.00% 0.00% 100%

Plant & Machinery (E&M and Transmission) 10.00% 25.00% 65.00% 0.00% 0.00% 100%

Basic Cost - 208.05 31.21 83.22 93.62 0.00 0.00 208.05 Civil

111.43 11.14 27.86 72.43 0.00 0.00 111.43 E&M

* total - 319.48 42.35 111.08 166.05 0.00 0.00 319.48

Basic Cost (Escalated ) 336.72 42.35 115.80 178.58 0.00 0.00 336.72

add contingencies 0% 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Technical Know how 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Pre operating Expenses 27.54 4.13 11.01 12.39 0.00 0.00 27.54

Financial Management - 2.95 2.95 0.00 0.00 0.00 0.00 2.95

Interest During Construction - 38.12 2.23 10.38 25.52 0.00 0.00 38.12

Margin money for Working Capital 0.00 0.00 0.00 0.00 0.00 0.00 0.00

CAT @ 2.5% of Total Cost 10.13 1.52 4.05 4.56 0.00 0.00 10.13

LADA @ 1.5 % of Total Project Cost 6.33 0.95 2.53 2.85 0.00 0.00 6.33

Preliminary exps 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total - 421.80 54.13 143.77 223.89 0.00 0.00 421.80

III * Escalation (% ) Civil 5.00% 1.00 1.05 1.10

E&M 2.00% 1.00 1.02 1.04

IV Cost per MW (Rs. / crores ) - 9.37



V Construction Period (Yrs) 3.00

VI Financing Promotors

Debt 70% INDIAN

Equity 30% 100%

Equity

- (%age of project cost) - 30% 100%

- (Rs crores) 126.54 126.54

Debt

- (%age of project cost) 70% 70%

- (Rs crores) - 295.26 295.26

Construction Period 3.00 3.00

- Moratorium (Yrs) - 5.00 5.00

- Repayment (Yrs) - 12.00 12.00

- Interest ( % ) ON LOANS 0.00 12.50%

VII Return on Equity (%)

NORMAL 15.50%

VIII FINANCIAL EXPNS

FM Exp.on loan from FIs (%) 1.00%

IX Interest on Working Capital (%) 12.50%

XII O&M (including insurance)

- Cost as % of project cost 4.00%

- Escalation factor 2.50%

X Income Tax Rate (%) 33.22% Tax Relief 100.00% For 10 years

XII Depreciation

Depreciation (As per ES Act.) 3.40%

Depreciation (As per IT Act.) 15.00%

Total Depreciable Amount 90.00%

XII Capital Subsidy (Not Considered) 0.00 crores

Annual CDM Benefit (Not Considered) 0.00 Crores/ year

XIII ENERGY CALCULATION



a Energy Generation (MU) at 100% available 219.40 Million units PLF 55.66%

aa Design Energy

b Energy Generation at 75 dependable year

with 95% plant availability 216.06 216.06 PLF 54.81% 0.000

d Auxiliary consumption (%) 0.25% 0.54 0.54 0.50% 0.00

e Transformation Losses (%) 0.50% 1.08 1.08 0.50% 0.00

Transmission losses (%) 0.75% 1.62 1.62 0.75% 0.00

f Net Energy 212.82 212.82 0.00

i Free Power (%) For 1st 12 Years For 13 to 30 year For 31 to 40 year

16.00% 21.00% 21.00%

Total Energy Loss 34.05 44.69 44.69

Remaining Energy for Sale 178.77 168.13 168.13



COMPUTATION OF PROJECT COST - DRAW DOWN SCHEDULE (Without Transmission Line)

Unit : Rs / Crores

PARTICULARS Year-1 Year-

2 Year-

3 Year-

4 Year-

5 TOTAL

(a) Basic cost 39.96 105.10 150.52 0.00 0.00 295.58

(b) Basic cost (with escalation ) 39.96 109.70 162.41 0.00 0.00 312.08

(bb) Contingencies 0.00 0.00 0.00 0.00 0.00 0.00

Technical Know how 0.00 0.00 0.00 0.00 0.00 0.00

add preop expns 4.13 11.01 12.39 0.00 0.00 27.54

(c) Financial mgmt. exp. 2.76 0.00 0.00 0.00 0.00 2.76

Preliminary exps 0.00 0.00 0.00 0.00 0.00 0.00

(d) Margin money for W.C. 0.00 0.00 0.00 0.00 0.00 0.00

sub total 46.85 120.72 174.80 0.00 0.00 342.37

(e) IDC on borrowings 2.11 9.85 23.95 0.00 0.00 35.91

(f) CAT @ 2.5% of Total Cost 1.42 3.78 4.26 0.00 0.00 9.46

(g) LADA @ 1.5 % of Total Project Cost 0.89 2.36 2.66 0.00 0.00 5.90

TOTAL (in Rs. Crores) 51.26 136.71 205.67 0.00 0.00 393.64

cumulative (in Rs. Crores) 51.26 187.98 393.64 393.64 393.64

MEANS OF FINANCING

Year - 1

Year- 2

Year- 3

Year- 4

Year- 5 TOTAL

A LOANS :-

(a) Rupee Loan 33.77 85.85 120.02 0.00 0.00 239.64

(b) IDC on (a) 2.11 9.85 23.95 0.00 0.00 35.91



B EQUITY 15.38 41.01 61.70 0.00 0.00 118.09


393.64

CALCULATION OF INTEREST ON DEBT CAPITAL

PARTICULARS Year -

1 Year-

2 Year-

3 Year-

4 Year-

5 TOTAL

I.D.C.

(a) Rupee Loan at the end 33.77 121.73 251.60 0.00 0.00 239.64

(b) Intt. on (a) 2.11 9.85 23.95 0.00 0.00 35.91

TOTAL IDC 35.88 131.58 275.55 0.00 0.00 275.55



COMPUTATION OF PROJECT COST - DRAW DOWN SCHEDULE (With Transmission Line)

Unit : Rs / Crores

PARTICULARS Year-1 Year-

2 Year-

3 Year-

4 Year-

5 TOTAL

(a) Basic cost 42.35 111.08 166.05 0.00 0.00 319.48

(b) Basic cost (with escalation ) 42.35 115.80 178.58 0.00 0.00 336.72

(bb) Contingencies 0.00 0.00 0.00 0.00 0.00 0.00

Technical Know how 0.00 0.00 0.00 0.00 0.00 0.00

add preop expns 4.13 11.01 12.39 0.00 0.00 27.54

(c) Financial mgmt. exp. 2.95 0.00 0.00 0.00 0.00 2.95

Preliminary exps 0.00 0.00 0.00 0.00 0.00 0.00

(d) Margin money for W.C. 0.00 0.00 0.00 0.00 0.00 0.00

sub total 49.43 126.81 190.97 0.00 0.00 367.21

(e) IDC on borrowings 2.23 10.38 25.52 0.00 0.00 38.12

(f) CAT @ 2.5% of Total Cost 1.52 4.05 4.56 0.00 0.00 10.13

(g) LADA @ 1.5 % of Total Project Cost 0.95 2.53 2.85 0.00 0.00 6.33



MEANS OF FINANCING

Year - 1

Year- 2

Year- 3

Year- 4

Year- 5 TOTAL

A LOANS :-

(a) Rupee Loan 35.66 90.26 131.21 0.00 0.00 257.13

(b) IDC on (a) 2.23 10.38 25.52 0.00 0.00 38.12



B EQUITY 16.24 43.13 67.17 0.00 0.00 126.54


421.80

CALCULATION OF INTEREST ON DEBT CAPITAL

PARTICULARS Year -

1 Year-

2 Year-

3 Year-

4 Year-

5 TOTAL

I.D.C.

(a) Rupee Loan at the end 35.66 128.16 269.74 0.00 0.00 257.13

(b) Intt. on (a) 2.23 10.38 25.52 0.00 0.00 38.12

TOTAL IDC 37.89 138.53 295.26 0.00 0.00 295.26



Year Year

Year Ended C O S T R U C T I O N P E R I O D 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40

OUTFLOW

CAPITAL EXPENDITURE 51.26 136.71 205.67

(LESS: IDC & MARGIN

NET WORKING CAPITAL 0.00 0.00 0.00 2.52 0.06 0.06 0.07 0.07 0.07 0.07 0.07 0.07 0.08 0.08 0.08 0.08 0.00 0.09 0.09 0.09 0.09 0.10 0.10 0.10 0.10 0.11 0.11 0.11 0.11 0.12 0.12 0.12 0.13 0.13 0.13 0.14 0.14 0.14 0.15 0.15 0.15 0.16 0.16

INFLOW

PBIDT 0.00 0.00 0.00 70.50 70.51 69.08 66.22 63.36 60.50 57.64 54.78 51.91 49.05 52.50 50.10 47.66 45.17 44.08 44.40 44.68 44.94 45.17 45.38 45.58 45.95 47.21 47.23 47.24 47.25 37.07 28.02 28.04 28.06 28.07 28.09 28.10 28.12 28.14 28.16 28.18 28.20 28.22 28.24

LESS: PROVISION FOR 0.00 0.00 0.00 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 10.89 11.35 11.76 12.14 12.47 12.78 13.05 13.29 13.52 13.71 13.89 14.26 15.50 15.50 15.50 15.50 12.12 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11

SALVAGE VALUE OF

SALVAGE VALUE OF

NET INFLOW -51.26 -136.71 -205.67 63.40 65.87 64.44 61.58 58.71 55.85 52.99 50.12 47.26 44.40 41.54 38.67 35.81 33.04 31.52 31.53 31.54 31.55 31.56 31.57 31.58 31.59 31.60 31.61 31.62 31.64 24.84 18.80 18.81 18.82 18.84 18.85 18.86 18.88 18.89 18.91 18.92 18.94 18.95 18.97

-51.26 -187.98 -393.64 -124.57 -58.70 5.74 67.32 126.03 181.88 234.87 284.99 332.25 376.65 418.19 456.86 492.68 525.71 557.24 588.77 620.31 651.86 683.43 715.00 746.58 778.17 809.77 841.39 873.01 904.65 929.49 948.29 967.10 985.92 1004.76 1023.61 1042.47 1061.35 1080.24 1099.15 1118.07 1137.01 1155.96 1174.93

IRR (AFTER TAX) 11.7%

FOR SHAREHOLDERS

NET INFLOW -15.38 -41.01 -61.70 31.17 31.17 8.20 8.20 8.20 8.20 8.20 8.20 8.20 8.20 8.20 8.20 8.20 8.20 31.17 31.17 31.17 31.17 31.17 31.17 31.17 31.17 31.17 31.17 31.17 31.17 24.36 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30


-15.38 15.79 46.95 55.16 86.32 94.53 102.73 110.93 119.14 127.34 135.54 143.75 151.95 160.15 168.36 176.56 184.76 215.93 247.10 278.26 309.43 340.59 371.76 402.93 434.09 465.26 496.42 527.59 558.75 583.11 601.42 619.72 638.02 656.33 674.63 692.94 711.24 729.55 747.85 766.15 784.46 802.76 821.07

IRR CALCULATION (Without Transmission Lines)



Year Year

Year Ended C O S T R U C T I O N P E R I O D 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40

OUTFLOW

CAPITAL EXPENDITURE 54.13 143.77 223.89

(LESS: IDC & MARGIN

NET WORKING CAPITAL 0.00 0.00 0.00 2.70 0.07 0.07 0.07 0.07 0.07 0.08 0.08 0.08 0.08 0.08 0.09 0.09 0.00 0.09 0.10 0.10 0.10 0.10 0.11 0.11 0.11 0.11 0.12 0.12 0.12 0.13 0.13 0.13 0.13 0.14 0.14 0.15 0.15 0.15 0.16 0.16 0.16 0.17 0.17

INFLOW

PBIDT 0.00 0.00 0.00 75.55 75.55 74.03 70.96 67.89 64.83 61.76 58.69 55.63 52.56 56.63 54.02 51.37 48.67 47.48 47.79 48.08 48.33 48.56 48.77 48.96 49.34 50.59 50.60 50.62 50.63 39.72 30.03 30.04 30.06 30.08 30.10 30.11 30.13 30.15 30.17 30.19 30.21 30.23 30.26

LESS: PROVISION FOR 0.00 0.00 0.00 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 12.03 12.49 12.90 13.27 13.61 13.91 14.18 14.42 14.64 14.84 15.02 15.38 16.61 16.61 16.61 16.61 12.98 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76

SALVAGE VALUE OF

SALVAGE VALUE OF

NET INFLOW -54.13 -143.77 -223.89 67.94 70.58 69.05 65.98 62.91 59.85 56.78 53.71 50.64 47.57 44.51 41.44 38.37 35.40 33.78 33.79 33.80 33.81 33.82 33.83 33.84 33.85 33.86 33.87 33.89 33.90 26.62 20.14 20.16 20.17 20.18 20.20 20.21 20.23 20.24 20.26 20.27 20.29 20.31 20.33

-54.13 -197.91 -421.80 -129.97 -59.39 9.66 75.64 138.56 198.40 255.18 308.89 359.53 407.11 451.62 493.06 531.43 566.83 600.61 634.40 668.20 702.01 735.83 769.65 803.50 837.35 871.21 905.09 938.97 972.87 999.49 1019.63 1039.79 1059.96 1080.14 1100.34 1120.55 1140.78 1161.02 1181.28 1201.56 1221.85 1242.16 1262.48


FOR SHAREHOLDERS

NET INFLOW -16.24 -43.13 -67.17 33.40 33.40 8.79 8.79 8.79 8.79 8.79 8.79 8.79 8.79 8.79 8.79 8.79 8.79 33.40 33.40 33.40 33.40 33.40 33.40 33.40 33.40 33.40 33.40 33.40 33.40 26.10 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61


-16.24 17.16 50.55 59.34 92.74 101.53 110.32 119.11 127.90 136.69 145.48 154.27 163.06 171.85 180.64 189.43 198.22 231.61 265.01 298.40 331.80 365.19 398.59 431.98 465.38 498.77 532.17 565.57 598.96 625.06 644.67 664.29 683.90 703.51 723.13 742.74 762.35 781.97 801.58 821.20 840.81 860.42 880.04

IRR CALCULATION (With Transmission Lines)



CALCULATION OF TARIFF (Without Transmission Lines)

Cons. Period Yr- 1 Yr- 2 Yr- 3 Yr- 4 Yr- 5 Yr- 6 Yr- 7 Yr- 8 Yr- 9 Yr-10 Yr-11 Yr-12 Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25 Yr-26 Yr-27 Yr-28 Yr-29 Yr-30 Yr-31 Yr-32 Yr-33 Yr-34 Yr-35 Yr-36 Yr-37 Yr-38 Yr-39 Yr-40

A ANNUAL CAPACITY CHARGES

(i) Interest on Loan Capital 34.4 34.4 33.0 30.1 27.3 24.4 21.5 18.7 15.8 12.9 10.0 7.2 4.3 1.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

(ii) Depreciation/Advance Depreciation 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 6.05 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

47.3 47.3 45.9 43.0 40.1 37.3 34.4 31.5 28.6 25.8 22.9 20.0 17.2 14.3 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 6.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

B ANNUAL PRIMARY ENERGY CHARGES % of Cost Es. Rate

(i) O & M, Insurance Expenses 4.00% 2.50% 15.1 15.5 15.9 16.3 16.7 17.1 17.5 18.0 18.4 18.9 19.4 19.9 20.3 20.9 21.4 21.9 22.5 23.0 23.6 24.2 24.8 25.4 26.0 26.7 27.4 28.1 28.8 29.5 30.2 31.0 31.7 32.5 33.3 34.2 35.0 35.9 36.8 37.7 38.7 39.6

(ii) Interest on Working Capital 0.3 0.3 0.3 0.3 0.3 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.7 0.7 0.7 0.7 0.7 0.7 0.8 0.8 0.8 0.8

(iii) Provision for Income Tax 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 10.9 11.3 11.8 12.1 12.5 12.8 13.0 13.3 13.5 13.7 13.9 14.3 15.5 15.5 15.5 15.5 12.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1

(iv) Return on Equity 118.09 15.5% 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3

TOTAL PRIMARY ENERGY CHARGES 38.3 38.7 39.1 39.5 39.9 40.4 40.8 41.2 41.7 42.2 49.0 49.9 50.8 51.7 52.6 53.5 54.3 55.1 55.9 56.7 57.5 58.5 60.4 61.1 61.7 62.4 59.8 57.5 58.2 59.0 59.8 60.6 61.5 62.3 63.2 64.1 65.0 65.9 66.9 67.9

C TOTAL PAYMENT (NORMATIVE LEVEL) (A+B) 85.6 86.0 85.0 82.5 80.1 77.6 75.2 72.8 70.4 68.0 71.9 70.0 68.0 66.0 65.5 66.3 67.1 68.0 68.8 69.6 70.4 71.4 73.3 73.9 74.6 75.3 65.8 57.5 58.2 59.0 59.8 60.6 61.5 62.3 63.2 64.1 65.0 65.9 66.9 67.9

D INCENTIVES

Incentive For Excess Availability

Normative Availability 85.00%

For Actual Availability 0.00%

Return on Equity for each 1% increase 0.7%

in availability (As per Govt. Guidelines)

TOTAL INCENTIVES 0.0% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

E TOTAL PAYMENT INCLUDING INCENTIVES (C+D) 85.6 86.0 85.0 82.5 80.1 77.6 75.2 72.8 70.4 68.0 71.9 70.0 68.0 66.0 65.5 66.3 67.1 68.0 68.8 69.6 70.4 71.4 73.3 73.9 74.6 75.3 65.8 57.5 58.2 59.0 59.8 60.6 61.5 62.3 63.2 64.1 65.0 65.9 66.9 67.9

NET TO BE RECOVERED (E) 85.6 86.0 85.0 82.5 80.1 77.6 75.2 72.8 70.4 68.0 71.9 70.0 68.0 66.0 65.5 66.3 67.1 68.0 68.8 69.6 70.4 71.4 73.3 73.9 74.6 75.3 65.8 57.5 58.2 59.0 59.8 60.6 61.5 62.3 63.2 64.1 65.0 65.9 66.9 67.9

F CALCULATION OF TARIFF

Net Units available for Sale MILLION 178.8 178.8 178.8 178.8 178.8 178.8 178.8 178.8 178.8 178.8 178.8 178.8 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1

Tariff rate per unit Rs/Kw h 0% 4.79 4.81 4.75 4.62 4.48 4.34 4.21 4.07 3.94 3.80 4.02 3.91 4.05 3.93 3.89 3.94 3.99 4.04 4.09 4.14 4.19 4.24 4.36 4.40 4.44 4.48 3.92 3.42 3.46 3.51 3.56 3.61 3.65 3.71 3.76 3.81 3.87 3.92 3.98 4.04

Year 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40Discount Factor for computing levelised cost 13.5% 1.00 0.88 0.78 0.68 0.60 0.53 0.47 0.41 0.36 0.32 0.28 0.25 0.22 0.19 0.17 0.15 0.13 0.12 0.10 0.09 0.08 0.07 0.06 0.05 0.05 0.04 0.04 0.03 0.03 0.03 0.02 0.02 0.02 0.02 0.01 0.01 0.01 0.01 0.01 0.01

Annual discounted unit cost 4.79 4.24 3.69 3.16 2.70 2.31 1.97 1.68 1.43 1.22 1.13 0.97 0.89 0.76 0.66 0.59 0.53 0.47 0.42 0.37 0.33 0.30 0.27 0.24 0.21 0.19 0.15 0.11 0.10 0.09 0.08 0.07 0.06 0.06 0.05 0.05 0.04 0.04 0.03 0.03

Levellized Unit cost 4.79 4.80 4.79 4.75 4.71 4.67 4.62 4.58 4.54 4.50 4.48 4.46 4.44 4.43 4.42 4.41 4.40 4.39 4.39 4.39 4.39 4.38 4.38 4.38 4.38 4.38 4.38 4.38 4.38 4.37 4.37 4.37 4.37 4.37 4.37 4.36 4.36 4.36 4.36 4.36

FINANCIAL PACKAGE

Loan Component 275.55 Repayment Period Moratorium Period =

-Indian 275.55 12 YEARS 5 years including construction period

Equity component 118.09

LOANS REPAYMENT SCHEDULE Cons. Period Yr- 1 Yr- 2 Yr- 3 Yr- 4 Yr- 5 Yr- 6 Yr- 7 Yr- 8 Yr- 9 Yr-10 Yr-11 Yr-12 Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25 Yr-26 Yr-27 Yr-28 Yr-29 Yr-30 Yr-31 Yr-32 Yr-33 Yr-34 Yr-35 Yr-36 Yr-37 Yr-38 Yr-39 Yr-40

RUPEE Outstanding Term loan 275.55 275.55 275.55 252.59 229.62 206.66 183.70 160.74 137.77 114.81 91.85 68.89 45.92 22.96 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Term loan instalment 0.00 0.00 22.96 22.96 22.96 22.96 22.96 22.96 22.96 22.96 22.96 22.96 22.96 22.96 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Interest on Term loan 34.44 34.44 33.01 30.14 27.27 24.40 21.53 18.66 15.79 12.92 10.05 7.18 4.31 1.44 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total Yearly (instalment + interest) 34.44 34.44 55.97 53.10 50.23 47.36 44.49 41.62 38.75 35.88 33.01 30.14 27.27 24.40 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00



CALCULATION OF DEPRECIATION

A DEPRECIATION (IT ACT)

Detailed calculation of dep Rate

i) Land 0.00 0% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

ii) Building & Civil Works 266.26 10% 266.26 239.64 215.67 194.11 174.70 157.23 141.50 127.35 114.62 103.16 92.84 83.56 75.20 67.68 60.91 54.82 49.34 44.41 39.96 35.97 32.37 29.13 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63 26.63

depreciation 26.63 23.96 21.57 19.41 17.47 15.72 14.15 12.74 11.46 10.32 9.28 8.36 7.52 6.77 6.09 5.48 4.93 4.44 4.00 3.60 3.24 2.51 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

cumulative 26.63 50.59 72.16 91.57 109.04 124.76 138.91 151.65 163.11 173.42 182.71 191.06 198.58 205.35 211.44 216.92 221.86 226.30 230.30 233.89 237.13 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64 239.64

Plant & Machinery & mis fixed assets 112.02 25% 112.02 84.01 63.01 47.26 35.44 26.58 19.94 14.95 11.21 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20 11.20

depreciation 28.00 21.00 15.75 11.81 8.86 6.65 4.98 3.74 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

cumulative 28.00 49.01 64.76 76.57 85.43 92.08 97.06 100.80 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82 100.82

Technical Know how & environment e 0.00 10% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

and other Prelm. Exp 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

total cost/ depreciation 378.28 54.63 44.97 37.32 31.22 26.33 22.37 19.13 16.47 11.47 10.32 9.28 8.36 7.52 6.77 6.09 5.48 4.93 4.44 4.00 3.60 3.24 2.51 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sum at charge 378.28 323.65 278.68 241.36 210.14 183.81 161.44 142.31 125.83 114.36 104.04 94.76 86.40 78.88 72.11 66.02 60.54 55.61 51.17 47.17 43.57 40.34 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83 37.83

Depreciation for the year (IT Act) 54.63 44.97 37.32 31.22 26.33 22.37 19.13 16.47 11.47 10.32 9.28 8.36 7.52 6.77 6.09 5.48 4.93 4.44 4.00 3.60 3.24 2.51 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Cumulative Dep. (IT Act) 54.63 99.60 136.92 168.14 194.47 216.84 235.98 252.45 263.92 274.24 283.52 291.88 299.40 306.17 312.26 317.74 322.67 327.11 331.11 334.71 337.94 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45

B DEPRECIATION (ES ACT)

Yearly Depreciation (ES Act) 378.28 340.45 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 6.05 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Advance Dep.for loan Repayment 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Depreciation for the year (ES Act) 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 6.05 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Cumulative Dep. (ES Act) 0 12.86 25.72 38.58 51.45 64.31 77.17 90.03 102.89 115.75 128.62 141.48 154.34 167.20 180.06 192.92 205.78 218.65 231.51 244.37 257.23 270.09 282.95 295.82 308.68 321.54 334.40 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45 340.45

REQUIREMENT OF WORKING CAPITAL

A WORKING CAPITAL REQUIREMENT 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40

i) O & M 2 2.52 2.58 2.65 2.72 2.78 2.85 2.92 3.00 3.07 3.15 3.23 3.31 3.39 3.48 3.56 3.65 3.74 3.84 3.93 4.03 4.13 4.24 4.34 4.45 4.56 4.68 4.79 4.91 5.03 5.16 5.29 5.42 5.56 5.70 5.84 5.98 6.13 6.29 6.45 6.61

ii) Spares lumpsum 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total working capital reqd 2.52 2.58 2.65 2.72 2.78 2.85 2.92 3.00 3.07 3.15 3.23 3.31 3.39 3.48 3.56 3.65 3.74 3.84 3.93 4.03 4.13 4.24 4.34 4.45 4.56 4.68 4.79 4.91 5.03 5.16 5.29 5.42 5.56 5.70 5.84 5.98 6.13 6.29 6.45 6.61

B MARGIN MONEY

i) O & M 0% 100% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

ii) Spares 0% 25% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total margin money required 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C Total Bank Finance (A+B) 2.52 2.58 2.65 2.72 2.78 2.85 2.92 3.00 3.07 3.15 3.23 3.31 3.39 3.48 3.56 3.65 3.74 3.84 3.93 4.03 4.13 4.24 4.34 4.45 4.56 4.68 4.79 4.91 5.03 5.16 5.29 5.42 5.56 5.70 5.84 5.98 6.13 6.29 6.45 6.61

D Interest on Bank Borrowing 12.5% 0.32 0.32 0.33 0.34 0.35 0.36 0.37 0.37 0.38 0.39 0.40 0.41 0.42 0.43 0.45 0.46 0.47 0.48 0.49 0.50 0.52 0.53 0.54 0.56 0.57 0.58 0.60 0.61 0.63 0.65 0.66 0.68 0.69 0.71 0.73 0.75 0.77 0.79 0.81 0.83

PROFITABILITY STATEMENT Cons. Period 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40

Sales (Tarif f rate x Net Units) 85.6 86.0 85.0 82.5 80.1 77.6 75.2 72.8 70.4 68.0 71.9 70.0 68.0 66.0 65.5 66.3 67.1 68.0 68.8 69.6 70.4 71.4 73.3 73.9 74.6 75.3 65.8 57.5 58.2 59.0 59.8 60.6 61.5 62.3 63.2 64.1 65.0 65.9 66.9 67.9

A EXPENSES

i) O & M, Insurance Expenses 15.13 15.51 15.90 16.29 16.70 17.12 17.55 17.99 18.44 18.90 19.37 19.85 20.35 20.86 21.38 21.91 22.46 23.02 23.60 24.19 24.79 25.41 26.05 26.70 27.37 28.05 28.75 29.47 30.21 30.96 31.74 32.53 33.35 34.18 35.03 35.91 36.81 37.73 38.67 39.64

ii) PBIDT 70.5 70.5 69.1 66.2 63.4 60.5 57.6 54.8 51.9 49.1 52.5 50.1 47.7 45.2 44.1 44.4 44.7 44.9 45.2 45.4 45.6 46.0 47.2 47.2 47.2 47.3 37.1 28.0 28.0 28.1 28.1 28.1 28.1 28.1 28.1 28.2 28.2 28.2 28.2 28.2

B INTEREST

i) Rupee Term Loan 34.4 34.4 33.0 30.1 27.3 24.4 21.5 18.7 15.8 12.9 10.0 7.2 4.3 1.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

ii) Working Capital 0.3 0.3 0.3 0.3 0.3 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.7 0.7 0.7 0.7 0.7 0.7 0.8 0.8 0.8 0.8



C PBDT = (PBIDT less Interest) 35.7 35.7 35.7 35.7 35.7 35.7 35.7 35.7 35.7 35.7 42.1 42.5 42.9 43.3 43.6 43.9 44.2 44.5 44.7 44.9 45.1 45.4 46.7 46.7 46.7 46.7 36.5 27.4 27.4 27.4 27.4 27.4 27.4 27.4 27.4 27.4 27.4 27.4 27.4 27.4

Depreciation 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 12.86 6.05 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Operating Profit 22.88 22.88 22.88 22.88 22.88 22.88 22.88 22.88 22.88 22.88 29.19 29.65 30.07 30.44 30.78 31.08 31.35 31.60 31.82 32.02 32.20 32.56 33.81 33.81 33.81 33.81 30.42 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41

Less:Provision for Tax 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 10.89 11.35 11.76 12.14 12.47 12.78 13.05 13.29 13.52 13.71 13.89 14.26 15.50 15.50 15.50 15.50 12.12 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11

Net Profit After Tax 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30 18.30

D Gross Cash Accrual (PAT+Dep) 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 24.4 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3

Dividend (Rate % ) 1st 12 year 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%

Dividend (Amount) after 12 year 0.0% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Dividend Tax 0% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Net Cash Accrual 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 24.4 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3

F Debt Servicing (Rs. Million)

- Interest on Loan 34.4 34.4 33.0 30.1 27.3 24.4 21.5 18.7 15.8 12.9 10.0 7.2 4.3 1.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

- Term Loan Instalment 0.0 0.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

TOTAL 34.4 34.4 56.0 53.1 50.2 47.4 44.5 41.6 38.7 35.9 33.0 30.1 27.3 24.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

DSCR 1.90 1.90 1.15 1.15 1.16 1.17 1.18 1.20 1.21 1.23 1.25 1.27 1.3 1.3 2924140187443790. 0 2924140187443790. 0 2924140187443790. 0 2924140187443790. 0 2924140187443790. 0 2924140187443790. 0 2924140187443800. 0 2924140187443790. 0 2924140187443790. 0 2924140187443790. 0 2924140187443790. 0 2924140187443790. 0 2285281180963650. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0 1717406508536890. 0

MINIMUM DSCR 1.15

MAXIMUM DSCR 1.90

AVERAGE DSCR 1.29

BALANCE SHEET Cons. Period 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40

ASSETS

i) Gross Block 393.64 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6 393.6

ii) Less Depreciation 0.00 12.9 25.7 38.6 51.4 64.3 77.2 90.0 102.9 115.8 128.6 141.5 154.3 167.2 180.1 192.9 205.8 218.6 231.5 244.4 257.2 270.1 283.0 295.8 308.7 321.5 334.4 340.5 340.5 340.5 340.5 340.5 340.5 340.5 340.5 340.5 340.5 340.5 340.5 340.5 340.5

iii) Net Block 393.64 380.8 367.9 355.1 342.2 329.3 316.5 303.6 290.7 277.9 265.0 252.2 239.3 226.4 213.6 200.7 187.9 175.0 162.1 149.3 136.4 123.5 110.7 97.8 85.0 72.1 59.2 53.2 53.2 53.2 53.2 53.2 53.2 53.2 53.2 53.2 53.2 53.2 53.2 53.2 53.2

iv) Working Capital 0.00 2.5 2.6 2.6 2.7 2.8 2.9 2.9 3.0 3.1 3.1 3.2 3.3 3.4 3.5 3.6 3.7 3.7 3.8 3.9 4.0 4.1 4.2 4.3 4.5 4.6 4.7 4.8 4.9 5.0 5.2 5.3 5.4 5.6 5.7 5.8 6.0 6.1 6.3 6.4 6.6

v) Surplus Cash 0.00 31.2 62.3 70.5 78.7 86.9 95.1 103.3 111.6 119.8 128.0 136.2 144.4 152.6 160.8 191.9 223.1 254.3 285.4 316.6 347.8 378.9 410.1 441.3 472.4 503.6 534.8 559.1 577.4 595.7 614.0 632.3 650.6 668.9 687.3 705.6 723.9 742.2 760.5 778.8 797.1

vi) Misc exp to the extent not w /off 0.00 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

TOTAL 393.64 414.5 432.8 428.2 423.7 419.1 414.5 409.9 405.3 400.7 396.1 391.6 387.0 382.4 377.8 396.2 414.6 433.0 451.4 469.8 488.2 506.6 525.0 543.4 561.8 580.3 598.7 617.1 635.5 654.0 672.4 690.8 709.3 727.7 746.1 764.6 783.0 801.5 819.9 838.4 856.9

LIABILITIES

i) Share Capital 118.09 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1 118.1

ii) Retained Earnings 0.00 18.3 36.6 54.9 73.2 91.5 109.8 128.1 146.4 164.7 183.0 201.3 219.7 238.0 256.3 274.6 292.9 311.2 329.5 347.8 366.1 384.4 402.7 421.0 439.3 457.6 475.9 494.2 512.5 530.8 549.1 567.4 585.7 604.0 622.3 640.7 659.0 677.3 695.6 713.9 732.2

iii) LOANS 275.55 275.5 275.5 252.6 229.6 206.7 183.7 160.7 137.8 114.8 91.8 68.9 45.9 23.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

iv) Bank borrow ings 0.00 2.5 2.6 2.6 2.7 2.8 2.9 2.9 3.0 3.1 3.1 3.2 3.3 3.4 3.4 3.5 3.6 3.7 3.8 3.8 3.9 4.0 4.2 4.3 4.4 4.5 4.6 4.7 4.8 5.0 5.1 5.2 5.3 5.5 5.6 5.8 5.9 6.0 6.2 6.4 6.5

TOTAL 393.64 414.5 432.8 428.2 423.7 419.1 414.5 409.9 405.3 400.7 396.1 391.6 387.0 382.4 377.7 396.1 414.5 432.9 451.3 469.7 488.1 506.5 524.9 543.3 561.8 580.2 598.6 617.0 635.4 653.9 672.3 690.7 709.2 727.6 746.1 764.5 782.9 801.4 819.9 838.3 856.8

TAX LIABILITY

Yearly Profit/Loss -18.89 -9.22 -1.58 4.52 9.41 13.38 16.61 19.27 24.27 25.43 32.77 34.16 35.41 36.53 37.55 38.46 39.28 40.02 40.68 41.28 41.82 42.91 46.67 46.67 46.67 46.67 36.47 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41

Cumulative Profit/Loss (+/-) -18.89 -28.1 -29.7 -25.2 -15.8 -2.38 14.23 33.51 57.77 83.20 115.97 150.13 185.5 222.07 259.62 298.08 337.36 377.38 418.07 459.35 501.17 544.09 590.75 637.42 684.09 730.76 767.24 794.65 822.06 849.47 876.88 904.29 931.70 959.11 986.52 1013.93 1041.34 1068.75 1096.16 1123.57

Carryforw ard Losses -18.89 -28.1 -29.7 -25.2 -15.8 -2.38 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Taxable Profits 0.00 0.00 0.00 0.00 0.00 0.00 14.23 19.27 24.27 25.43 32.77 34.16 35.41 36.53 37.55 38.46 39.28 40.02 40.68 41.28 41.82 42.91 46.67 46.67 46.67 46.67 36.47 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41

Tax Relief % 0% 0% 0% 0% 0% 0% 100% 100% 100% 100% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

amt 0.00 0.00 0.00 0.00 0.00 0.00 14.23 19.27 24.27 25.43 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00



Net Taxable Profits 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 32.77 34.16 35.41 36.53 37.55 38.46 39.28 40.02 40.68 41.28 41.82 42.91 46.67 46.67 46.67 46.67 36.47 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41 27.41

Tax liability 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10.89 11.35 11.76 12.14 12.47 12.78 13.05 13.29 13.52 13.71 13.89 14.26 15.50 15.50 15.50 15.50 12.12 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11

MAT 20.01% 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 5.84 5.93 6.02 6.09 6.16 6.22 6.27 6.32 6.37 6.41 6.44 6.51 6.76 6.76 6.76 6.76 6.09 5.48 5.48 5.48 5.48 5.48 5.48 5.48 5.48 5.48 5.48 5.48 5.48 5.48

Portion of Tax on Incentives 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Balance Tax Eligible for Pass Through 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 4.58 10.89 11.35 11.76 12.14 12.47 12.78 13.05 13.29 13.52 13.71 13.89 14.26 15.50 15.50 15.50 15.50 12.12 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11 9.11

INCENTIVE FOR AVAILABILITY 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

TOTAL Incentives 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

FUND FLOW STATEMENT

SOURCES OF FUNDS Cons. Period 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40

i) Share issue 118.09 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

ii) Profit before taxation w ith int added ba 0.00 57.6 57.6 56.2 53.4 50.5 47.6 44.8 41.9 39.1 36.2 39.6 37.2 34.8 32.3 31.2 31.5 31.8 32.1 32.3 32.5 32.7 33.1 34.4 34.4 34.4 34.4 31.0 28.0 28.0 28.1 28.1 28.1 28.1 28.1 28.1 28.2 28.2 28.2 28.2 28.2

iii) Depreciation provision for the year 0.00 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 12.9 6.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

iv) Increase in Long term Rupee Loans 275.55 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

v) Increase in bank borrow ings for w ork 0.00 2.5 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.0 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.2 0.2 0.2

TOTAL (a) 393.64 73.0 70.6 69.1 66.3 63.4 60.6 57.7 54.8 52.0 49.1 52.6 50.2 47.7 45.2 44.2 44.5 44.8 45.0 45.3 45.5 45.7 46.1 47.3 47.3 47.4 47.4 37.2 28.1 28.2 28.2 28.2 28.2 28.2 28.3 28.3 28.3 28.3 28.3 28.4 28.4

DISPOSITION OF FUNDS

i) Capital expenditure for the project 393.64 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

ii) Loan Installment 0.00 0.0 0.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 23.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

iii) Interest on

Rupee Loans 34.4 34.4 33.0 30.1 27.3 24.4 21.5 18.7 15.8 12.9 10.0 7.2 4.3 1.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Working Capital 0.3 0.3 0.3 0.3 0.3 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.7 0.7 0.7 0.7 0.7 0.7 0.8 0.8 0.8 0.8

iv) Taxation 0.00 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6 10.9 11.3 11.8 12.1 12.5 12.8 13.0 13.3 13.5 13.7 13.9 14.3 15.5 15.5 15.5 15.5 12.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1 9.1

v) Dividends - Equity 0.00 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

vi) Dividends - Tax 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

vii) Increase/decrease in w orking capital 0.00 2.5 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.0 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.2 0.2 0.2

Total (b) 393.64 41.9 39.4 60.9 58.1 55.2 52.4 49.5 46.6 43.8 40.9 44.4 42.0 39.5 37.0 13.0 13.3 13.6 13.9 14.1 14.3 14.5 14.9 16.2 16.2 16.2 16.2 12.8 9.8 9.9 9.9 9.9 9.9 9.9 10.0 10.0 10.0 10.0 10.0 10.1 10.1

1 Opening Balance of cash in hand & at 0.0 0.0 31.2 62.3 70.5 78.7 86.9 95.1 103.3 111.6 119.8 128.0 136.2 144.4 152.6 160.8 191.9 223.1 254.3 285.4 316.6 347.8 378.9 410.1 441.3 472.4 503.6 534.8 559.1 577.4 595.7 614.0 632.3 650.6 668.9 687.3 705.6 723.9 742.2 760.5 778.8

2 Net surplus/deficit (A-B) 0.0 31.2 31.2 8.2 8.2 8.2 8.2 8.2 8.2 8.2 8.2 8.2 8.2 8.2 8.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 31.2 24.4 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3 18.3

Closing Balance of cash in hand 0.0 31.2 62.3 70.5 78.7 86.9 95.1 103.3 111.6 119.8 128.0 136.2 144.4 152.6 160.8 191.9 223.1 254.3 285.4 316.6 347.8 378.9 410.1 441.3 472.4 503.6 534.8 559.1 577.4 595.7 614.0 632.3 650.6 668.9 687.3 705.6 723.9 742.2 760.5 778.8 797.1



CALCULATION OF TARIFF (With Transmission Lines)

Cons. Period Yr- 1 Yr- 2 Yr- 3 Yr- 4 Yr- 5 Yr- 6 Yr- 7 Yr- 8 Yr- 9 Yr-10 Yr-11 Yr-12 Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25 Yr-26 Yr-27 Yr-28 Yr-29 Yr-30 Yr-31 Yr-32 Yr-33 Yr-34 Yr-35 Yr-36 Yr-37 Yr-38 Yr-39 Yr-40

A ANNUAL CAPACITY CHARGES

(i) Interest on Loan Capital 36.9 36.9 35.4 32.3 29.2 26.1 23.1 20.0 16.9 13.8 10.8 7.7 4.6 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

(ii) Depreciation/Advance Depreciation 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 6.49 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

50.7 50.7 49.2 46.1 43.0 39.9 36.8 33.8 30.7 27.6 24.5 21.5 18.4 15.3 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 6.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

B ANNUAL PRIMARY ENERGY CHARGES % of Cost Es. Rate

(i) O & M, Insurance Expenses 4.00% 2.50% 16.2 16.6 17.0 17.5 17.9 18.3 18.8 19.3 19.8 20.2 20.8 21.3 21.8 22.4 22.9 23.5 24.1 24.7 25.3 25.9 26.6 27.2 27.9 28.6 29.3 30.1 30.8 31.6 32.4 33.2 34.0 34.9 35.7 36.6 37.5 38.5 39.4 40.4 41.4 42.5

(ii) Interest on Working Capital 0.3 0.3 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.7 0.7 0.7 0.7 0.7 0.7 0.8 0.8 0.8 0.8 0.8 0.9 0.9

(iii) Provision for Income Tax 4.9 4.9 4.9 4.9 4.9 4.9 4.9 4.9 4.9 4.9 12.0 12.5 12.9 13.3 13.6 13.9 14.2 14.4 14.6 14.8 15.0 15.4 16.6 16.6 16.6 16.6 13.0 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8

(iv) Return on Equity 126.54 15.5% 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6

TOTAL PRIMARY ENERGY CHARGES 41.1 41.5 41.9 42.3 42.8 43.2 43.7 44.2 44.7 45.2 52.8 53.8 54.8 55.7 56.6 57.5 58.4 59.2 60.1 60.9 61.8 62.8 64.7 65.4 66.2 66.9 64.0 61.6 62.4 63.2 64.1 65.0 65.8 66.8 67.7 68.7 69.6 70.6 71.7 72.7

C TOTAL PAYMENT (NORMATIVE LEVEL) (A+B) 91.8 92.2 91.1 88.4 85.8 83.2 80.6 78.0 75.4 72.8 77.4 75.3 73.2 71.0 70.4 71.3 72.1 73.0 73.9 74.7 75.5 76.6 78.5 79.2 79.9 80.7 70.5 61.6 62.4 63.2 64.1 65.0 65.8 66.8 67.7 68.7 69.6 70.6 71.7 72.7

D INCENTIVES

Incentive For Excess Availability

Normative Availability 85.00%

For Actual Availability 0.00%

Return on Equity for each 1% increase 0.7%

in availability (As per Govt. Guidelines)

TOTAL INCENTIVES 0.0% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

E TOTAL PAYMENT INCLUDING INCENTIVES (C+D) 91.8 92.2 91.1 88.4 85.8 83.2 80.6 78.0 75.4 72.8 77.4 75.3 73.2 71.0 70.4 71.3 72.1 73.0 73.9 74.7 75.5 76.6 78.5 79.2 79.9 80.7 70.5 61.6 62.4 63.2 64.1 65.0 65.8 66.8 67.7 68.7 69.6 70.6 71.7 72.7

NET TO BE RECOVERED (E) 91.8 92.2 91.1 88.4 85.8 83.2 80.6 78.0 75.4 72.8 77.4 75.3 73.2 71.0 70.4 71.3 72.1 73.0 73.9 74.7 75.5 76.6 78.5 79.2 79.9 80.7 70.5 61.6 62.4 63.2 64.1 65.0 65.8 66.8 67.7 68.7 69.6 70.6 71.7 72.7

F CALCULATION OF TARIFF

Net Units available for Sale MILLION 178.8 178.8 178.8 178.8 178.8 178.8 178.8 178.8 178.8 178.8 178.8 178.8 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1 168.1

Tariff rate per unit Rs/Kw h 0% 5.13 5.16 5.09 4.95 4.80 4.65 4.51 4.36 4.22 4.07 4.33 4.21 4.35 4.22 4.19 4.24 4.29 4.34 4.39 4.44 4.49 4.55 4.67 4.71 4.76 4.80 4.20 3.66 3.71 3.76 3.81 3.86 3.92 3.97 4.03 4.08 4.14 4.20 4.26 4.33

Year 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40Discount Factor for computing levelised cost 13.5% 1.00 0.88 0.78 0.68 0.60 0.53 0.47 0.41 0.36 0.32 0.28 0.25 0.22 0.19 0.17 0.15 0.13 0.12 0.10 0.09 0.08 0.07 0.06 0.05 0.05 0.04 0.04 0.03 0.03 0.03 0.02 0.02 0.02 0.02 0.01 0.01 0.01 0.01 0.01 0.01

Annual discounted unit cost 5.13 4.54 3.95 3.38 2.89 2.47 2.11 1.80 1.53 1.30 1.22 1.05 0.95 0.81 0.71 0.63 0.57 0.50 0.45 0.40 0.36 0.32 0.29 0.26 0.23 0.20 0.16 0.12 0.11 0.10 0.09 0.08 0.07 0.06 0.05 0.05 0.04 0.04 0.03 0.03

Levellized Unit cost 5.13 5.14 5.13 5.09 5.05 5.00 4.95 4.91 4.86 4.82 4.80 4.78 4.76 4.75 4.74 4.73 4.72 4.71 4.71 4.70 4.70 4.70 4.70 4.70 4.70 4.70 4.70 4.70 4.69 4.69 4.69 4.68 4.68 4.68 4.68 4.68 4.68 4.68 4.68 4.68

FINANCIAL PACKAGE

Loan Component 295.26 Repayment Period Moratorium Period =

-Indian 295.26 12 YEARS 5 years including construction period

Equity component 126.54

LOANS REPAYMENT SCHEDULE Cons. Period Yr- 1 Yr- 2 Yr- 3 Yr- 4 Yr- 5 Yr- 6 Yr- 7 Yr- 8 Yr- 9 Yr-10 Yr-11 Yr-12 Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25 Yr-26 Yr-27 Yr-28 Yr-29 Yr-30 Yr-31 Yr-32 Yr-33 Yr-34 Yr-35 Yr-36 Yr-37 Yr-38 Yr-39 Yr-40

RUPEE Outstanding Term loan 295.26 295.26 295.26 270.65 246.05 221.44 196.84 172.23 147.63 123.02 98.42 73.81 49.21 24.60 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Term loan instalment 0.00 0.00 24.60 24.60 24.60 24.60 24.60 24.60 24.60 24.60 24.60 24.60 24.60 24.60 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Interest on Term loan 36.91 36.91 35.37 32.29 29.22 26.14 23.07 19.99 16.92 13.84 10.76 7.69 4.61 1.54 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total Yearly (instalment + interest) 36.91 36.91 59.97 56.90 53.82 50.75 47.67 44.60 41.52 38.45 35.37 32.29 29.22 26.14 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00



CALCULATION OF DEPRECIATION

A DEPRECIATION (IT ACT)

Detailed calculation of dep Rate

i) Land 0.00 0% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

ii) Building & Civil Works 263.97 10% 263.97 237.57 213.81 192.43 173.19 155.87 140.28 126.25 113.63 102.27 92.04 82.84 74.55 67.10 60.39 54.35 48.91 44.02 39.62 35.66 32.09 28.88 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40 26.40

depreciation 26.40 23.76 21.38 19.24 17.32 15.59 14.03 12.63 11.36 10.23 9.20 8.28 7.46 6.71 6.04 5.43 4.89 4.40 3.96 3.57 3.21 2.49 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

cumulative 26.40 50.15 71.53 90.78 108.10 123.68 137.71 150.34 161.70 171.93 181.13 189.41 196.87 203.58 209.62 215.05 219.94 224.35 228.31 231.87 235.08 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57 237.57

Plant & Machinery & mis f ixed assets 141.37 25% 141.37 106.03 79.52 59.64 44.73 33.55 25.16 18.87 14.15 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14 14.14

depreciation 35.34 26.51 19.88 14.91 11.18 8.39 6.29 4.72 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

cumulative 35.34 61.85 81.73 96.64 107.82 116.21 122.50 127.22 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24 127.24

Technical Know how & environment e 0.00 10% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

and other Prelm. Exp 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

total cost/ depreciation 405.34 61.74 50.26 41.26 34.15 28.50 23.97 20.32 17.34 11.38 10.23 9.20 8.28 7.46 6.71 6.04 5.43 4.89 4.40 3.96 3.57 3.21 2.49 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sum at charge 405.34 343.60 293.33 252.07 217.92 189.42 165.44 145.12 127.78 116.40 106.18 96.97 88.69 81.23 74.52 68.49 63.05 58.16 53.76 49.80 46.23 43.02 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53 40.53

Depreciation for the year (IT Act) 61.74 50.26 41.26 34.15 28.50 23.97 20.32 17.34 11.38 10.23 9.20 8.28 7.46 6.71 6.04 5.43 4.89 4.40 3.96 3.57 3.21 2.49 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Cumulative Dep. (IT Act) 61.74 112.00 153.27 187.42 215.92 239.89 260.21 277.56 288.94 299.16 308.37 316.65 324.10 330.81 336.85 342.29 347.18 351.58 355.54 359.11 362.32 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80

B DEPRECIATION (ES ACT)

Yearly Depreciation (ES Act) 405.34 364.80 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 6.49 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Advance Dep.for loan Repayment 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Depreciation for the year (ES Act) 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 6.49 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Cumulative Dep. (ES Act) 0 13.78 27.56 41.34 55.13 68.91 82.69 96.47 110.25 124.03 137.82 151.60 165.38 179.16 192.94 206.72 220.50 234.29 248.07 261.85 275.63 289.41 303.19 316.97 330.76 344.54 358.32 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80 364.80

REQUIREMENT OF WORKING CAPITAL

A WORKING CAPITAL REQUIREMENT 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40

i) O & M 2 2.70 2.77 2.84 2.91 2.98 3.06 3.13 3.21 3.29 3.37 3.46 3.55 3.63 3.73 3.82 3.91 4.01 4.11 4.21 4.32 4.43 4.54 4.65 4.77 4.89 5.01 5.14 5.26 5.40 5.53 5.67 5.81 5.96 6.10 6.26 6.41 6.57 6.74 6.91 7.08

ii) Spares lumpsum 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total working capital reqd 2.70 2.77 2.84 2.91 2.98 3.06 3.13 3.21 3.29 3.37 3.46 3.55 3.63 3.73 3.82 3.91 4.01 4.11 4.21 4.32 4.43 4.54 4.65 4.77 4.89 5.01 5.14 5.26 5.40 5.53 5.67 5.81 5.96 6.10 6.26 6.41 6.57 6.74 6.91 7.08

B MARGIN MONEY

i) O & M 0% 100% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

ii) Spares 0% 25% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total margin money required 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

C Total Bank Finance (A+B) 2.70 2.77 2.84 2.91 2.98 3.06 3.13 3.21 3.29 3.37 3.46 3.55 3.63 3.73 3.82 3.91 4.01 4.11 4.21 4.32 4.43 4.54 4.65 4.77 4.89 5.01 5.14 5.26 5.40 5.53 5.67 5.81 5.96 6.10 6.26 6.41 6.57 6.74 6.91 7.08

D Interest on Bank Borrowing 12.5% 0.34 0.35 0.35 0.36 0.37 0.38 0.39 0.40 0.41 0.42 0.43 0.44 0.45 0.47 0.48 0.49 0.50 0.51 0.53 0.54 0.55 0.57 0.58 0.60 0.61 0.63 0.64 0.66 0.67 0.69 0.71 0.73 0.74 0.76 0.78 0.80 0.82 0.84 0.86 0.88

PROFITABILITY STATEMENT Cons. Period 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40

Sales (Tariff rate x Net Units) 91.8 92.2 91.1 88.4 85.8 83.2 80.6 78.0 75.4 72.8 77.4 75.3 73.2 71.0 70.4 71.3 72.1 73.0 73.9 74.7 75.5 76.6 78.5 79.2 79.9 80.7 70.5 61.6 62.4 63.2 64.1 65.0 65.8 66.8 67.7 68.7 69.6 70.6 71.7 72.7

A EXPENSES

i) O & M, Insurance Expenses 16.21 16.62 17.03 17.46 17.90 18.34 18.80 19.27 19.75 20.25 20.75 21.27 21.81 22.35 22.91 23.48 24.07 24.67 25.29 25.92 26.57 27.23 27.91 28.61 29.33 30.06 30.81 31.58 32.37 33.18 34.01 34.86 35.73 36.62 37.54 38.48 39.44 40.43 41.44 42.47

ii) PBIDT 75.5 75.6 74.0 71.0 67.9 64.8 61.8 58.7 55.6 52.6 56.6 54.0 51.4 48.7 47.5 47.8 48.1 48.3 48.6 48.8 49.0 49.3 50.6 50.6 50.6 50.6 39.7 30.0 30.0 30.1 30.1 30.1 30.1 30.1 30.2 30.2 30.2 30.2 30.2 30.3

B INTEREST

i) Rupee Term Loan 36.9 36.9 35.4 32.3 29.2 26.1 23.1 20.0 16.9 13.8 10.8 7.7 4.6 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

ii) Working Capital 0.3 0.3 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.7 0.7 0.7 0.7 0.7 0.7 0.8 0.8 0.8 0.8 0.8 0.9 0.9



C PBDT = (PBIDT less Interest) 38.3 38.3 38.3 38.3 38.3 38.3 38.3 38.3 38.3 38.3 45.4 45.9 46.3 46.7 47.0 47.3 47.6 47.8 48.0 48.2 48.4 48.8 50.0 50.0 50.0 50.0 39.1 29.4 29.4 29.4 29.4 29.4 29.4 29.4 29.4 29.4 29.4 29.4 29.4 29.4

Depreciation 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 13.78 6.49 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Operating Profit 24.52 24.52 24.52 24.52 24.52 24.52 24.52 24.52 24.52 24.52 31.65 32.11 32.52 32.89 33.22 33.52 33.79 34.04 34.26 34.45 34.63 34.99 36.23 36.23 36.23 36.23 32.60 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37

Less:Provision for Tax 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 12.03 12.49 12.90 13.27 13.61 13.91 14.18 14.42 14.64 14.84 15.02 15.38 16.61 16.61 16.61 16.61 12.98 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76

Net Profit After Tax 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61 19.61

D Gross Cash Accrual (PAT+Dep) 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 26.1 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6

Dividend (Rate % ) 1st 12 year 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%

Dividend (Amount) after 12 year 0.0% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Dividend Tax 0% 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Net Cash Accrual 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 26.1 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6

F Debt Servicing (Rs. Million)

- Interest on Loan 36.9 36.9 35.4 32.3 29.2 26.1 23.1 20.0 16.9 13.8 10.8 7.7 4.6 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

- Term Loan Instalment 0.0 0.0 24.6 24.6 24.6 24.6 24.6 24.6 24.6 24.6 24.6 24.6 24.6 24.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

TOTAL 36.9 36.9 60.0 56.9 53.8 50.7 47.7 44.6 41.5 38.4 35.4 32.3 29.2 26.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

DSCR 1.90 1.90 1.15 1.15 1.16 1.17 1.18 1.20 1.21 1.23 1.25 1.27 1.3 1.3 - 3133299463906810. 0 - 3133299463906810. 0 - 3133299463906810. 0 - 3133299463906810. 0 - 3133299463906810. 0 - 3133299463906810. 0 - 3133299463906810. 0 - 3133299463906810. 0 - 3133299463906810. 0 - 3133299463906810. 0 - 3133299463906810. 0 - 3133299463906810. 0 - 2448743849537970. 0 - 1840249970098990. 0 - 1840249970098990. 0 -1840249970098990. 0 -1840249970098990. 0 - 1840249970098990. 0 - 1840249970098990. 0 - 1840249970098990. 0 - 1840249970098990. 0 - 1840249970098990. 0 - 1840249970098990. 0 - 1840249970098990. 0 - 1840249970098990. 0 - 1840249970098990. 0

MINIMUM DSCR 1.15

MAXIMUM DSCR 1.90

AVERAGE DSCR 1.29

BALANCE SHEET Cons. Period 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40

ASSETS

i) Gross Block 421.80 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8 421.8

ii) Less Depreciation 0.00 13.8 27.6 41.3 55.1 68.9 82.7 96.5 110.3 124.0 137.8 151.6 165.4 179.2 192.9 206.7 220.5 234.3 248.1 261.8 275.6 289.4 303.2 317.0 330.8 344.5 358.3 364.8 364.8 364.8 364.8 364.8 364.8 364.8 364.8 364.8 364.8 364.8 364.8 364.8 364.8

iii) Net Block 421.80 408.0 394.2 380.5 366.7 352.9 339.1 325.3 311.5 297.8 284.0 270.2 256.4 242.6 228.9 215.1 201.3 187.5 173.7 160.0 146.2 132.4 118.6 104.8 91.0 77.3 63.5 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0

iv) Working Capital 0.00 2.7 2.8 2.8 2.9 3.0 3.1 3.1 3.2 3.3 3.4 3.5 3.5 3.6 3.7 3.8 3.9 4.0 4.1 4.2 4.3 4.4 4.5 4.7 4.8 4.9 5.0 5.1 5.3 5.4 5.5 5.7 5.8 6.0 6.1 6.3 6.4 6.6 6.7 6.9 7.1

v) Surplus Cash 0.00 33.4 66.8 75.6 84.4 93.2 102.0 110.7 119.5 128.3 137.1 145.9 154.7 163.5 172.3 205.7 239.1 272.5 305.9 339.2 372.6 406.0 439.4 472.8 506.2 539.6 573.0 599.1 618.7 638.3 658.0 677.6 697.2 716.8 736.4 756.0 775.6 795.3 814.9 834.5 854.1

vi) Misc exp to the extent not w /off 0.00 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

TOTAL 421.80 444.1 463.8 458.9 454.0 449.0 444.1 439.2 434.3 429.4 424.5 419.6 414.7 409.8 404.9 424.6 444.3 464.0 483.7 503.4 523.1 542.9 562.6 582.3 602.0 621.8 641.5 661.2 681.0 700.7 720.5 740.2 760.0 779.7 799.5 819.3 839.0 858.8 878.6 898.4 918.2

LIABILITIES

i) Share Capital 126.54 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5

ii) Retained Earnings 0.00 19.6 39.2 58.8 78.5 98.1 117.7 137.3 156.9 176.5 196.1 215.8 235.4 255.0 274.6 294.2 313.8 333.4 353.0 372.7 392.3 411.9 431.5 451.1 470.7 490.3 510.0 529.6 549.2 568.8 588.4 608.0 627.6 647.3 666.9 686.5 706.1 725.7 745.3 764.9 784.5

iii) LOANS 295.26 295.3 295.3 270.7 246.0 221.4 196.8 172.2 147.6 123.0 98.4 73.8 49.2 24.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

iv) Bank borrow ings 0.00 2.7 2.8 2.8 2.9 3.0 3.1 3.1 3.2 3.3 3.4 3.5 3.5 3.6 3.6 3.7 3.8 3.9 4.0 4.1 4.2 4.3 4.4 4.6 4.7 4.8 4.9 5.0 5.2 5.3 5.4 5.6 5.7 5.9 6.0 6.2 6.3 6.5 6.6 6.8 7.0

TOTAL 421.80 444.1 463.8 458.9 454.0 449.0 444.1 439.2 434.3 429.4 424.5 419.6 414.7 409.8 404.8 424.5 444.2 463.9 483.6 503.3 523.0 542.8 562.5 582.2 601.9 621.7 641.4 661.2 680.9 700.6 720.4 740.1 759.9 779.7 799.4 819.2 839.0 858.7 878.5 898.3 918.1

TAX LIABILITY

Yearly Profit/Loss -23.44 -11.96 -2.96 4.15 9.80 14.33 17.98 20.96 26.92 28.07 36.23 37.60 38.84 39.96 40.97 41.87 42.68 43.42 44.07 44.67 45.20 46.28 50.01 50.01 50.01 50.01 39.08 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37

Cumulative Profit/Loss (+/-) -23.44 -35.4 -38.4 -34.2 -24.4 -10.09 7.89 28.85 55.77 83.85 120.07 157.68 196.5 236.48 277.45 319.31 362.00 405.41 449.49 494.16 539.36 585.64 635.65 685.66 735.67 785.67 824.76 854.13 883.50 912.87 942.24 971.61 1000.98 1030.35 1059.72 1089.09 1118.46 1147.83 1177.20 1206.57

Carryforw ard Losses -23.44 -35.4 -38.4 -34.2 -24.4 -10.09 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Taxable Profits 0.00 0.00 0.00 0.00 0.00 0.00 7.89 20.96 26.92 28.07 36.23 37.60 38.84 39.96 40.97 41.87 42.68 43.42 44.07 44.67 45.20 46.28 50.01 50.01 50.01 50.01 39.08 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37

Tax Relief % 0% 0% 0% 0% 0% 0% 100% 100% 100% 100% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%

amt 0.00 0.00 0.00 0.00 0.00 0.00 7.89 20.96 26.92 28.07 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00



Net Taxable Profits 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 36.23 37.60 38.84 39.96 40.97 41.87 42.68 43.42 44.07 44.67 45.20 46.28 50.01 50.01 50.01 50.01 39.08 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37 29.37

Tax liability 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 12.03 12.49 12.90 13.27 13.61 13.91 14.18 14.42 14.64 14.84 15.02 15.38 16.61 16.61 16.61 16.61 12.98 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76

MAT 20.01% 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 6.33 6.42 6.51 6.58 6.65 6.71 6.76 6.81 6.85 6.89 6.93 7.00 7.25 7.25 7.25 7.25 6.52 5.88 5.88 5.88 5.88 5.88 5.88 5.88 5.88 5.88 5.88 5.88 5.88 5.88

Portion of Tax on Incentives 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Balance Tax Eligible for Pass Through 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 4.91 12.03 12.49 12.90 13.27 13.61 13.91 14.18 14.42 14.64 14.84 15.02 15.38 16.61 16.61 16.61 16.61 12.98 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76 9.76

INCENTIVE FOR AVAILABILITY 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

TOTAL Incentives 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

FUND FLOW STATEMENT

SOURCES OF FUNDS Cons. Period 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40

i) Share issue 126.54 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

ii) Profit before taxation w ith int added ba 0.00 61.8 61.8 60.2 57.2 54.1 51.0 48.0 44.9 41.8 38.8 42.8 40.2 37.6 34.9 33.7 34.0 34.3 34.6 34.8 35.0 35.2 35.6 36.8 36.8 36.8 36.9 33.2 30.0 30.0 30.1 30.1 30.1 30.1 30.1 30.2 30.2 30.2 30.2 30.2 30.3

iii) Depreciation provision for the year 0.00 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 13.8 6.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

iv) Increase in Long term Rupee Loans 295.26 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

v) Increase in bank borrow ings for w ork 0.00 2.7 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.0 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.2 0.2 0.2 0.2 0.2 0.2

TOTAL (a) 421.80 78.2 75.6 74.1 71.0 68.0 64.9 61.8 58.8 55.7 52.6 56.7 54.1 51.5 48.7 47.6 47.9 48.2 48.4 48.7 48.9 49.1 49.4 50.7 50.7 50.7 50.8 39.8 30.2 30.2 30.2 30.2 30.2 30.3 30.3 30.3 30.3 30.4 30.4 30.4 30.4

DISPOSITION OF FUNDS

i) Capital expenditure for the project 421.80 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

ii) Loan Installment 0.00 0.0 0.0 24.6 24.6 24.6 24.6 24.6 24.6 24.6 24.6 24.6 24.6 24.6 24.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

iii) Interest on

Rupee Loans 36.9 36.9 35.4 32.3 29.2 26.1 23.1 20.0 16.9 13.8 10.8 7.7 4.6 1.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Working Capital 0.3 0.3 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.4 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.7 0.7 0.7 0.7 0.7 0.7 0.8 0.8 0.8 0.8 0.8 0.9 0.9

iv) Taxation 0.00 4.9 4.9 4.9 4.9 4.9 4.9 4.9 4.9 4.9 4.9 12.0 12.5 12.9 13.3 13.6 13.9 14.2 14.4 14.6 14.8 15.0 15.4 16.6 16.6 16.6 16.6 13.0 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8 9.8

v) Dividends - Equity 0.00 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

vi) Dividends - Tax 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

vii) Increase/decrease in w orking capital 0.00 2.7 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.0 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.2 0.2 0.2 0.2 0.2 0.2

Total (b) 421.80 44.9 42.2 65.3 62.2 59.2 56.1 53.0 50.0 46.9 43.9 47.9 45.3 42.7 39.9 14.2 14.5 14.8 15.0 15.3 15.5 15.7 16.1 17.3 17.3 17.3 17.4 13.8 10.5 10.6 10.6 10.6 10.6 10.6 10.7 10.7 10.7 10.7 10.8 10.8 10.8

1 Opening Balance of cash in hand & at 0.0 0.0 33.4 66.8 75.6 84.4 93.2 102.0 110.7 119.5 128.3 137.1 145.9 154.7 163.5 172.3 205.7 239.1 272.5 305.9 339.2 372.6 406.0 439.4 472.8 506.2 539.6 573.0 599.1 618.7 638.3 658.0 677.6 697.2 716.8 736.4 756.0 775.6 795.3 814.9 834.5

2 Net surplus/deficit (A-B) 0.0 33.4 33.4 8.8 8.8 8.8 8.8 8.8 8.8 8.8 8.8 8.8 8.8 8.8 8.8 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 26.1 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6 19.6

Closing Balance of cash in hand 0.0 33.4 66.8 75.6 84.4 93.2 102.0 110.7 119.5 128.3 137.1 145.9 154.7 163.5 172.3 205.7 239.1 272.5 305.9 339.2 372.6 406.0 439.4 472.8 506.2 539.6 573.0 599.1 618.7 638.3 658.0 677.6 697.2 716.8 736.4 756.0 775.6 795.3 814.9 834.5 854.1

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 19-Recommendations


19. RECOMMENDATIONS

19.1 GENERAL

The project involves construction of conventional civil structures as detailed below. The project

construction work is recommended to be taken up on fast track basis and construction shall be

completed in a period of 42 months including 6 months for development of infrastructure

facilities. The project component includes:

Barrage

Intake Structure & Feeder Channel

Desilting Basin

Head Race Tunnel

Surge Shaft

Pressure Shaft

Power House

Tail Race Channel

Switchyard

19.2 PRELIMINARY AND PRE-CONSTRUCTION WORKS

To ensure project completion in 36 months, it is essential to accomplish the following activities in

a period of 6 months before start of Main Civil works. However some of the activities will

continue during phase-II. The following main activities are required for preconstruction and

construction phases of the project:

Techno economic Clearance

Pre-construction investigation

Environment, Forest and other statutory clearances

Acquisition of land

Completion of main infrastructure facilities such as roads and buildings, bridges

Completion of detailed design and specifications

Power Purchase Agreement

Financial Closure

Tender and Award of main Civil, Hydro Mechanical and Electro Mechanical works.

Commissioning related activities.

19.3 CIVIL AND HYDRO MECHANICAL WORKS

A total time period of 36 months has been considered for main Civil and Hydro-mechanical

works. The HRT & Penstock lies in critical path. Adequate construction equipment planning has

been done to achieve the desired progress rates.

Bharmour Hydro Projects Pvt. Ltd. Detailed Project Report Bharmour-I HEP (24 MW) 19-Recommendations


Timely completion of construction works also depends on the timely supply of construction

material to Diversion site, Powerpipe, through existing approach roads and ropeways and by

development of project roads. Sufficient storage shall be ensured at project site to ensure

continuous construction between April to December without stoppage due to shortage of

materials.

19.4 ELECTRO-MECHANICAL WORKS

Three 8.0 MW Horizontal Francis machines have been proposed to generate 24.0 MW of power.

The orders for Electro-Mechanical equipments will be placed in line with civil works so as not to

cause any delay in completion of civil works.


Availability of adequate construction power plays a major role in the scheduled completion of

construction works. Construction power required for various components shall be mainly

arranged by contractors. Power for project offices and colony shall be supplied through

dedicated D.G.Sets. However, if power is available in the local grid the same shall also be

utilized for construction of the project.

19.6 BENEFITS

The annual energy benefit from the BHEP-I project in 75% dependable year at 95% machine

availability is 115.36 MU.

19.7 PROJECT COST

The basic cost of the Bharmour stage-I HEP is worked out to be Rs.196.00 Crores without

transmission line and Rs.208.75 Crores with transmission line. The combined cost for

completion of BHEP-I & BHEP-II projects is Rs. 393.64 Crores without transmission line (at

August, 2014 price level) and the corresponding levelised tariff is Rs. 4.36 per kWh. Similarly,

the combined cost for completion of BHEP-I & BHEP-II projects with transmission line is Rs.

421.80 Crores (at August, 2014 price level) and the corresponding levelised tariff is Rs. 4.68 per

kWh

19.8 RECOMMENDATION

The 24.0 MW Bharmour-I HEP utilises a rated net head of 93.00 m and rated discharge of 29.50

m3/s to generate 115.36 MU of energy annually in 75 % dependable year at 95% machine

availability.

The installed capacity of 24.0 MW proposed in this DPR is techno-economically viable and the

project is recommended for implementation.

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