chhatru hydro electric project (3x36 =108 mw) - Ministry of Power

CHHATRU HYDRO ELECTRIC PROJECT (3X36 =108 MW)
HIMACHAL PRADESH
1. INTRODUCTION
The Chhatru Hydroelectric Project located in Lahaul & Spiti district of
Himachal Pradesh envisages utilization of the waters of the river Chandra
for power generation on a run of river type development, harnessing a
head of about 177m.
The project with a proposed installation of 108 MW (3x36 MW) would
afford an net annual energy generation of 455.72 GWH, in a 90 %
dependable year. The tariff energy from the project at present day cost
would be Rs 2.28/unit (levellised) at power house bus bars.
The diversion site is located between Latitude 32 o 18'11" North Longitude
77 o 24'41"East. The barrage site is approachable from Chandigarh by road
being at a distance of 410 kms approx. The nearest rail head is located at
Kiratpur and nearest airport is located at Bhunter.
2. SCOPE OF WORKS
The Chhatru HE project envisages construction of :
a 19m high diversion barrage across river Chhatru to provide a net
live storage of 87.50 hacm. with FRL at 3421.00m and MDDL at
3413.50m;
two numbers desanding basins of length 381m(L) and size 13m
(W)x19.60m(H) to remove silt particles of size 0.20 mm and
above;
a 6.5 km long and 5.10m dia. modified horse shoe shaped head
race tunnel terminating in a surge shaft;
a 91.80m high ,15m dia surge shaft;
350m long, 4.70m dia pressure shaft;
a surface power house having an installation of 3 Francis driven
generating units of 36 MW each operating under a net head of 160
m; and
1150m long tail race tunnel to carry the power house releases back
to the river Chandra.
The power generated from the project would be evacuated through. 220
kV double circuit line from Khoskar to 400 KV pooling point at Tandi,
1

eyond which the evacuation will be through 400 KV double circuit net
work to pooling station near Panarsa to feed power to the power grid .
The Salient features of the project are given at Annex-I and a layout map
at Plate-I
3. HYDROLOGY
The river Chandra drains a catchment area of about 1583 Sq. km. at the
proposed barrage site. The discharge data of rivder Chandra at diversion
site of Chhatru HEP has been derived from June 1973- May 2000 from the
discharge data of river Chandra at Ghousal (site Monitored by CWC).
Discharge data of river Chandra at Ghousal has been reduced on
catchment area basis at diversion site. For design flood, flood frequency
analysis has been carried out by Gumble Method.The design flood has
been assessed as approx. 1500 cumecs.
4. POWER POTENTIAL STUDIES
The computed inflow series for 27 years viz June 1973 to May, 2000 has
been considered in the assessment of a power benefits from the project. As
per GOI notification for tariff, the year 1992-93 corresponds to 90%
dependable year. An installation of 108 MW comprising 3 generating
units of 36 MW each has been proposed. The energy availability from the
project in a dependable and an average year has been summarized below:
Particulars
Annual Energy Generation
Dep. Yr. Avr. Yr.
Gross annual Energy Generation (GWH) 455.72 475.80
Annual Load Factor (%) 50.00 52.00
Generation during Lean Flow Season (Dec.-Feb.)
Energy Output (GWH) 41.86
Load Factor (%) 18.00
The design energy at 95 % machine availability in a 90% dependable year
has been worked out at 455.72 GWH.
A net live pondage of 75.00 ham. has been provided in the diversion
barrage, which would enable the station to operate as peaking station. The
pondage is equivalent to 280.79 MWH which is sufficient to operate the
station for 3 hours.
2

5. POWER EVACUATION ASPECTS
The power generated from the project would be evacuated through. 220
kV, double circuit lines from Khoskar to 400 KV pooling point at Tandi,
beyond which the evacuation will be through 400 KV double circuit net
work to pooling station near Panarsa to feed into the Grid which in turn
connected to National Grid
6. ENVIRONMENTAL ASPECTS
The project is located in Lahaul & Spiti valley of H.P. Based on
assessment of environmental impacts, management plans have to be
formulated for Catchment Area Treatment, compensatory afforestation
and other environmental issues. These issues would be addressed during
investigations for preparation of DPR.
7. ESTIMATES OF THE COST
The project is estimated to cost Rs. 585.15 crores at power house bus bars
including IDC at Oct., 2003 price level. The preliminary cost estimate of
the project has been prepared as per guidelines of CEA / CWC. The break
down of the cost estimates is given below:
Civil works : Rs. 386.79 Crores
Electro Mechanical works : Rs. 136.12 Crores
Sub total (Generation) : Rs. 522.91 Crores
Transmission works : Rs. 8.45 Crores
Total Cost : Rs. 531.36 Crores
On Generation works
Interest During Construction : Rs. 62.24 Crores
Total : Rs. 585.15 Crores
8. FINANCIAL ASPECTS
As indicated above, the Chhatru HE project with an estimated cost of Rs.
585.15 (including IDC of Rs.62.24 crores) at power house bus bars with
net energy of 455.72 GWH in a 90% dependable year. The project is
proposed to be completed in a period of 4½ years. The tariff has been
worked out considering a debt-equity ratio of 70:30, 16% return on equity,
annual interest rate on loan at 10% .The tariff for first year and levellised
tariff have been work out Rs. 2.89 /kWh & Rs. 2.28/kwh respectively at
power house bus bars.
3

9. CONCLUSIONS
The economy of the Himachal Pradesh predominantly depends on
agricultural and allied sectors. The electric power being a vital and
essential infrastructure has a significant role to play in economic
upliftment of the state. The construction of project will provided
employment to the local people. The project has a distinct advantage of
being located along a motorable road making it possible to be completed
within four and half year.
4

GENERAL PROJECT FEATURES
5
Annexure-I
LOCATION
State Himachal Pradesh
District Lahaul Spiti
River Chandra river(Chenab Basin)
Barrage site ± 5 km. u/s of Chhatru village
Power house site ± 3.5 km d/s of Chhatru village
on right bank of Chandra river
HYDROLOGY
Catchment Area
at diversion site 1583 Sq. km.
Snow catchment 48 Sq. km. above El. 4200m
Probable maximum flood 1500cumecs
Standard project flood
Observed maximum flood 828.00 cumsecs
RESERVOIR
Full reservoir (FRL) 3421.00m
Maximum reservoir level (MRL) 3422.00m
Maximum draw down level (MDDL) 3413.50m
Gross storage upto FRL 112.50 Hect-m
Live storage 87.50 Hect-m
Net live storage 70.00 Hect-m
DIVERSION STRUCTURE
Type Barrage
Max. height from R.B.L. 19m
Elevation of top of dam or bridge ±3424.00m
Average bed level ±3405.00m
SPILLWAY
Design flood 1500cumecs
Type Gated spillways with radial gates
Nos. of spillways, Crest elevation 6 Nos. El. 3407.00m
Length of gated spillways 5.00m each.

Energy dissipation
Length 98.00m
Down stream bed level ±3403.00m
INTAKE STRUCTURE
Type Surface
Sill level El. 3410.00m
No. & size of opening 8 Nos., 5.50mx3.0m
APPROACH TUNNEL
No. 1
Size and type 6.00m dia, Circular concrete Lined
Velocity 3.30m/sec
Length 200m
Design discharge from intake 93.75 cum/sec
DESANDING BASIN
Type Underground, central gutter type
No. of basins 2 nos.
Length of each basin 381m
Size of basins Width13.00m,Depth 19.60m
Minimum particle size to be removed 0.2mm
Flushing tunnel, size 4.00m, D-Shaped
Flushing tunnel, length 1000m
HEAD RACE TUNNEL
No. 1
Size & Shape 5.10m diameter, Modified
Horse shoe shaped Concrete lined
Length 6500 m
Design discharge 75 cumecs
Slope 1 in 120.50 m
Velocity 3.63m/sec
Adit 275m leangth 5m D- shaped
SURGE SHAFT
Type Underground, restricted orifice type
Size 15m dia, 91.80m high
Orifice 2.50m dia
Maximum upsurge level El. 3436.10m
6

Minimum down surge level El. 3396.60m
Bottom level El. 3350.50m
Top level El. 3436.00m
Adit to top of surge shaft 4mx6m, D-Shaped
2no. 75m each
PRESSURE SHAFT
Type Underground
Size:
Main 1 No., 4.70m dia,
± 350m long
Branches 3 Nos., 2.70m dia, ± 50m
long each
Velocity 4.32 m/sec.
POWER HOUSE
Type Underground
Installed capacity 108 MW
No. and capacity of unit 3 Nos. 36 MW
Size of machine hall 67mx15m
Service bay elevation EL 3250m
Type of turbine Francis, Vertical axis
Speed of turbine 428.60 RPM
Gross Head 177.33 m
Normal tail water level El. 3240.00m
Max. net operating head for
design discharge 182.50m
Minimum net operating head for
design discharge 173.50m
Net operating head for design
discharge 160.00m
Peaking duration 3.00 hrs.
Maximum discharge during peaking hours 75 cumecs.
Firm discharge in 90% dep. Year 11.18 cumecs
TAIL RACE
Size and shape 6.00 m diameter,
D-Shaped concrete lined
Length ± 1150 m
7

SWITCHYARD
Type underground
TRANSMISSION LINE
No. of circuits D/C Line
Length of each 150Km
Voltage 220.KV
POWER GENERATION
Installed capacity 3x36 MW
Annual energy generation 455.72 MUs
90% dep. Year
8

50 000 MW HYDROELECTRIC INITIATIVE
Government of India
Ministry of Power
Central Electricity Authority
108 MW CHHATRU
H.E. PROJECT
HIMACHAL PRADESH
Preliminary Feasibility Report
(HYDROLOGY AND POWER POTENTIAL STUDIES)
MARCH ,
22000044
Consultant:
fgekpy izns'k jkT; fctyh cksMZ
Himachal Pradesh State Electricity Board
( H.P.Government Undertaking )

CHAPTER - V
HYDROLOGY
5.1 RIVER CHENAB AND CATCHMENT CHARACTERISTICS.
V -
The river orginates from the snow covered slopes of Great Himalayan of
Pir-Panjal ranges in Lahaul Spiti district and flows in a steep gradient with
a series of loopes and bends. The river is formed by the two major
tributaries in the head reaches namely Chandra and Bhaga.The river
Chandra originates from Bara Lachala and is further augmented by
Chandra Tal. The river Bhaga takes off from Suraj Tal in the vicinity of
Bara Lachala and is further joined by Jhankar and Millang nallahs in the
head reaches. The catchments of these two major tributaries have snow
covered peaks at height ranging from ± 3500 m to 5500 m elevation. The
Chandra river and Bhaga river joins at Tandi to form Chandra-Bhaga i.e.
the Chenab. Further downstream of confluence, it is joined by other
significant tributaries namely Shansha nallah near Rashil, Thirot nallah at
Thirot, Miyar nallah at Udaipur, Saichu nallah at Dawag, Mahal Nallah at
Killar & Dheda nallah at Lujai d/s of Killar. Chenab river drains a
catchments of about 7500 Sq. Km. before it crosses in to J&K border.
5.1.1 HYDROMETEOROLOGY OF THE CATCHMENT
This region is a low rainfall area as most of the precipitation in the region
is in the form of snow. The rainfall takes place during the monsoon months
only and the catchment experiences snowfall during the remaining period
2

V -
of the year. There is only one rain gauge station in this region, installed at
Keylong and the rainfall data has not been recorded regularly even at this
station. It is observed that the most of the runoff in the river results from
the melting of snow.
5.2 DISCHARGE DATA AND WATER AVAILABILITY
The discharge data of river Chandra at diversion site of Chhatru HEP has
been derived from June 1973-May 2000 from the discharge data of river
Chandra at Ghousal (site monitored by CWC).
Discharge data of river Chandra at Ghousal is given in table 5.1 while the
computed discharge data reduced on catchment area basis at diversion site
is given in Table– 5.2
Based upon ten daily discharge data, a flow duration curve has been
developed. From this curve, it is seen that flow corresponding to 90% &
50% availability works out to 10.41 cumecs & 26.30 cumecs respectively.
The design discharge of 75 cumecs is available for 32.15 % of the period.
Flow duration curve for lean-season (Dec. to Feb.) has also been
developed . From this curve , it is seen that flow corresponding to 90% &
50% availability works out to 6.96 cumecs & 12.95 cumecs respectively.
5.2.1 CO-RELATION STUDY
W.B. Langbein’s log deviation method has been used to obtain the coefficient
of co-relation between discharges of river Chandra at Ghousal and
discharges of river Bhaga at Tandi.
The Co-relation factors are as follows:
June-July = 0.92
3

Aug.-Sept. = 0.96
Oct.-May = 0.96
These calculations have been shown in Table- 5.3
V -
Similarly coefficient of co-relation has been obtained between discharges
of river Chenab at Udaipur and the sum of discharges of river Chandra at
Ghousal & river Bhaga at Tandi.
June-July = 0.94
Aug.-Sept. = 0.96
Oct.-May = 0.88
These calculations have been shown in Table-5.4
From the above co-relation factors it is evident that the discharges of river
Chandra at Ghousal & river Bhaga at Tandi including river Chenab at
Udaipur are consistent. Thus the discharges of river Chandra at Ghousal
have been approved by CWC and used for carrying out studies which
stands submitted to the CWC and comments are awaited.
5.3 DESIGN FLOOD
The project falls in Western Himalayas Zone seven in map of India. The
total catchment area of river Chenab in India is about 31,047 Sq. Kms. The
catchment is mostly fed by snow. The majority percentage of the runoff in
the catchment is derived from the snow & glaciers which constitutes a
potential reservoir. Winter precipitation which occurs in the form of snow
goes on accumulating till summer. As the summer advances, the
accumulated snow melts and releases water into the stream.
Design Flood has been computed on the basis of Flood Estimation report
for Western Himalayas-zone 7 & accordingly hydrographs have been
prepared. The max.. flow due to rain contribution comes out to be 291.59
4

V -
cumecs which has return period of 1 in 50 years. The maximum flow for
return period of 1 in 100 years is 321.38 cumecs. The snow contribution
has been taken to be 342.09 cumecs ie the maximum discharge of flow
during 2 nd week of July in flow series at diversion site. Thus the total
design flood works out to be 663.47 cumecs. Flood frequency analysis has
also been carried out by Gumble’s method.
Return period of 1 in 1000 years has been considered for computing the
SPF which works out to be 1377.59 cumecs. The designed flood has been
taken as 1500 cumecs. The computations have been shown in Annexure-
V-1.
5.4 SEDIMENTATION ASPECTS
Detailed studies shall be carried out at DPR stage. However 20% of the
live storage has been proposed to be kept reserved for silt deposition in the
reservoir.
5

V -
6

PARA DESCRIPTION PAGE
5.1 RIVER CHENAB AND CATCHMENT
CHARACTERISTICS
V -
5.1.1 HYDROMETEOROLOGY OF THE CATCHMENT V-1
5.2 DISCHARGE DATA AND WATER AVAILABILITY V-2
5.2.1 CO-RELATION STUDIES V-2 TO V-3
5.3 DESIGN FLOOD V-3 TO V-4
5.4 SEDIMENTATION ASPECTS V-4
5.5 COMMENTS BY CWC V-4
TABLE – 5.1 TEN DAILY AVERAGE DISCHARGE DATA OF
RIVER CHANDRA AT GHOUSAL
TABLE – 5.2 COMPUTED DISCHARGE DATA AT DIVERSION
SITE
V-1
INFLOWS OF RIVER CHANDRA AT GHOUSAL V-15
INFLOWS OF RIVER BHAGA AT TANDI V-16
TABLE-5.3 CO-RELATION BETWEEN DISCHARGES OF
RIVER CHANDRA AT GHOUSAL & RIVER
BHAGA AT TANDI
INFLOWS OF RIVER CHENAB AT UDAIPUR V-23
INFLOWS OF RIVER BHAGA AT TANDI PLUS
RIVER CHANDRA AT GHOUSAL
TABLE-5.4 CO-RELATION BETWEEN DISCHARGES OF
RIVER CHENAB AT UDAIPUR & THE SUM OF
DISCHARGES OF RIVER CHANDRA AT
GHOUSAL & RIVER BHAGA AT TANDI
7
V-5 TO V-9
V-10 TO V-14
V-17 TO V-22
V-24
V-25 TO V-30
ANNEX.-5 DESIGN FLOOD COMPUTATIONS V-31 TO V-40
PLATE -5.1 FLOW DURATION CURVE (OVER ALL) V-41
PLATE -5.2 FLOW DURATION CURVE (LEAN SEASON) V-42
PLATE -5.3 SYNTHETIC UNIT HYDROGRAPH V-43
PLATE -5.4 DESIGN FLOOD HYDROGRAPH V-44
ANNEXURE-V COMMENTS

1. INTRODUCTION
HIMACHAL PRADESH STATE ELECTRICITY BOARD
EXECUTIVE SUMMARY
As a part of an exercise to assess the balance hydro potential of the country
Central Electricity Authority(CEA ) identified more than 399 Hydro-electric
Projects with probable installed capacity of 1,50,000 MW. After carrying
out ranking studies, 162 projects have been identified for preparation of
Preliminary Feasibility Reports. Chhatru in Chenab basin has been
identified as one of these projects for preparation of PFR by HPSEB so that
it could be taken up for further development during the 10th & 11th Plans.
The identified Chhatru HEP in Lahaul & Spiti valley in HP by CEA
involved construction of diversion weir on Chandra river
(32°18’11”Latitude 77°24’41”Longitude) 5 km. upstream of village Chhatru
and river Beas and a power house about 3.5 km d/s of Chhatru village on
right bank of Chandra river (32°20’9”- Latitude 77°20’51” Longitude) with
an installed capacity of 108 MW.
A site visit was made to the area by engineers of HPSEB and Geologists of
GSI during January, 2004 for identification /selection of suitable site. The
identified/ proposed Chhatru Hydro-electric Project is located about 5 km.
u/s of village Chhatru (El. ± 3405m). The project has been found technoeconomically
feasible. It is located along a motorable road. The diversion
site of project is also well connected to road, whereas project roads have
been proposed to power house and surge shaft. The project is about 410
km. approx. from Chandigarh.
2. SCOPE OF THE PROJECT

The project comprises a diversion barrage on river Chandra +19m high
above river bed level, an intake arrangement on the right bank, for drawing
discharge of 93.75 cumecs, through 6m dia approach tunnel leading to an
underground desilting arrangement comprising two no chambers each
(381mx13mx19.60m), to exclude all particles down to 0.20mm, 5.10m dia,
6500m long modified horse shoe shaped tunnel designed for a discharge of
75 cumecs, opening into one 15m dia underground restricted orifice type
surge shaft, one pressure shaft of 4.70m dia 350m long bifurcating into three
2.70m dia, 50 long each branch pressure shafts feeding three Francis vertical
axis generating units of 36 MW each, through a net head of 160m in an
underground power house on the right bank of Chandra river about 3.50 km.
d/s of Chhatru village. The project will enable energy generation of 455.72
GWH in 90% dependable year at power house bus bars.
3. HYDROLOGY
The river orginates from the snow covered slopes of Great Himalayan of
Pir-Panjal ranges in Lahaul Spiti district and flows in a steep gradient with a
series of loopes and bends. The river is formed by the two major tributaries
in the head reaches namely Chandra and Bhaga.The river Chandra originates
from Bara Lachala and is further augmented by Chandra Tal. The river
Bhaga takes off from Suraj Tal in the vicinity of Bara Lachala and is further
joined by Jhankar and Millang nallahs in the head reaches. The catchments
of these two major tributaries have snow covered peaks at height ranging
from ± 3500 m to 5500 m elevation. The Chandra river and Bhaga river
joins at Tandi to form Chandra-Bhaga i.e. the Chenab. Further downstream
of confluence, it is joined by other significant tributaries namely Shansha
nallah near Rashil, Thirot nallah at Thirot, Miyar nallah at Udaipur, Saichu
nallah at Dawag, Mahal Nallah at Killar & Dheda nallah at Lujai d/s of
Killar. Chenab river drains a catchments of about 7500 Sq. Km. before it
crosses in to J&K border.

This region is a low rainfall area as most of the precipitation in the region is
in the form of snow. The rainfall takes place during the monsoon months
only and the catchment experiences snowfall during the remaining period of
the year. There is only one rain gauge station in this region, installed at
Keylong and the rainfall data has not been recorded regularly even at this
station. It is observed that the most of the runoff in the river results from the
melting of snow.
The discharge data of river Chandra at diversion site of Chhatru HEP has
been derived from June 1973-May 2000 from the discharge data of river
Chandra at Ghousal (site monitored by CWC). W.B. Langbein’s log
deviation method has been used to obtain the co-efficient of co-relation
between discharges of river Chandra at Ghousal and discharges of river
Bhaga at Tandi.
The design flood works out to be 663.47 cumecs. Flood frequency analysis
has also been carried out by Gumble’s method. The designed flood has been
taken as 1500 cumecs. Similarly coefficient of co-relation has been
obtained between discharges of river Chenab at Udaipur and the sum of
discharges of river Chandra at Ghousal & river Bhaga at Tandi.
From the above co-relation factors it is evident that the discharges of river
Chandra at Ghousal & river Bhaga at Tandi including river Chenab at
Udaipur are consistent. Thus the discharges of river Chandra at Ghousal
have been approved by CWC and used for carrying out studies which stands
submitted to the CWC and comments are awaited.
4. POWER POTENTIAL STUDIES
Chhatru Hydro-electric Project has been contemplated as a peaking station
to operate in Western part of North Regional Grid. Installed capacity of the
project has been presently kept as 108 MW comprising 3 units of 36 MW

each. The project will generate 455.72 GWH in 90% dependable year.
Accordingly energy exploitation of 62.08% with plant load factor of 50% in
90% dependable year will be accomplished.
5. POWER EVACUATION ASPECTS
During the 14 th meeting of the Standing Committee on Transmission system
planning of Northern Region held on 30.12.02, it has been decided that
PGCIL will construct a Parbati Pooling Point at downstream of Parbati-III
HEP which will cater to Allain-Duhangan, Malana-II and other
projects/small HEPs of Himachal Pradesh. Hence, it is proposed to
evacuate power generated at Chhatru project by laying a 15 km. long, 220
KV D/C line from Khoksar to 400 KV pooling point at Tandi.Beyond which
the evacuation will be through 400 KV D/C net work to Pooling point at
Panarsa sub station of PGCIL.
6. ENVIRONMENTAL ASPECTS
Environmental Management Plan (EMP) aims at the preservation of
ecological system by considering certain mitigating measures at the
proposed site. The EMP is required to ensure sustainable development in
the study area of 10 km. radius of the proposed Chhatru HEP site.
Government regulating agencies like Pollution Control Board working in
the region and more importantly the people living in the area need to extend
their co-operation and contribution in this direction.
It has been evaluated that the study area shall not be affected adversely with
the proposed activity , but is likely to get new economical fillip due to hydel
power generation, not only for the study area but also for the region as
whole.

7. ESTIMATES OF COST
The estimates of cost has been prepared on the basis of “CEA Guidelines for
rates and cost of civil and electrical works for Preliminary Feasibility
Reports of Hydro-electric Projects” received during Oct. 2003.
Accordingly cost of project works out to be Rs.386.79 crore for civil works,
Rs. 136.12.crore for electrical works and Rs. 8.45 crore for transmission
works.
8. FINANCIAL ASPECTS
The financial & economic evaluation has been carried out as per CEA
guide lines considering Interest During Construction (IDC) @ 10% and
interest on working capital @ 9.75%. The life of hydro-electric project has
been considered as 35 years. The 455.72 GWH energy units are available
at power house bus bars in 90% dependable year and cost per unit at power
house bus bars works out to Rs. 2.89 per Kwh in the first year of operation.
The levelised tariff rate of energy works out to be Rs.2.28 per Kwh.
9. CONCLUSION
The economy of the Himachal Pradesh is predominantly dependent on
agricultural and allied sectors. The electric power being a vital and essential
infrastructure has a significant role to play in economic upliftment of the
state. The construction of project will provide employment to the local
people. The project has a distinct advantage of being located along a
motorable road making it possible to be completed within four and half
years period.

INDEX
SR.NO. DESCRIPTION PAGE
CHAPTER-I SUMMARY I-1 TO I-6
CHAPTER-II BACKGROUND INFORMATION II-1 TO II-2
CHAPTER-III PROJECT AREA III-1 TO III-2
CHAPTER-IV TOPOGRAPHIC AND GEOTECHNICAL
ASPECTS
IV-1 TO IV-7
CHAPTER-V HYDROLOGY V-1 TO V-52
CHAPTER-VI CONCEPTUAL LAYOUT & PLANNING VI-1 TO VI-35
CHAPTER-VII POWER POTENTIAL STUDIES VII-1 TO VII-45
CHAPTER-VIII POWER EVACUATION VIII-1 TO VIII-10
CHAPTER-IX ENVIRONMENTAL ASPECTS IX-1 TO IX- 22
CHAPTER-X INFRASTRUCTURE X-1 TO X-7
CHAPTER-XI CONSTRUCTION PROGRAMME XI-1 TO XI-7
CHAPTER-XII COST ESTIMATE XII-1 TO XII-34
CHAPTER-XIII ECONOMIC EVALUATION XIII-1 TO XIII-14

PARA DESCRIPTION PAGE
1.0 SUMMARY I-1
1.1 GENERAL PROJECT FEATURES I-4
1.2 STUDIES UNDERTAKEN I-4 TO I-5
1.3 COST ESTIMATE & FINANCIAL ASPECTS I-5 TO I-6
PLATE 1.1 ALTERNATIVE PROPOSAL

1.0 SUMMARY
CHAPTER – I
SUMMARY
The Chhatru Hydro-electric Project has been contemplated as a power
generation development on river Chandra in Lahul & Spiti District of H.P.
It is an upstream development of Proposed Khoksar Hydro-electric Project
(90MW) preliminary feasibility report of which has been submitted to CEA
recently by HPSEB and is located about 410 km. from Chandigarh. The
project envisages utilization of river Chandra water through a gross head of
177.33m for generation of 108MW of power in a power station.
GENERAL PROJECT FEATURES
LOCATION
State Himachal Pradesh
District Lahaul Spiti
River Chandra river(Chenab Basin)
Barrage site ± 5 km. u/s of Chhatru village
Power house site ± 3.5 km d/s of Chhatru village on right
bank of Chandra river

HYDROLOGY
Catchment Area
at diversion site 1583 Sq. km.
Snow catchment 48 Sq. km. above El. 4200m
Probable maximum flood 1500cumecs
Standard project flood
Observed maximum flood 828.00 cumsecs
RESERVOIR
Full reservoir (FRL) 3421.00m
Maximum reservoir level (MRL) 3422.00m
Maximum draw down level (MDDL) 3413.50m
Gross storage upto FRL 112.50 Hect-m
Live storage 87.50 Hect-m
Net live storage 70.00 Hect-m
DIVERSION STRUCTURE
Type Barrage
Max. height from R.B.L. 19m
Elevation of top of dam or bridge ±3424.00m
Average bed level ±3405.00m
SPILLWAY
Design flood 1500cumecs
Type Gated spillways with radial gates
Nos. of spillways, Crest elevation 6 Nos. El. 3407.00m
Length of gated spillways 5.00m each.
Energy dissipation
Length 98.00m
Down stream bed level ±3403.00m
INTAKE STRUCTURE
Type Surface
Sill level El. 3410.00m
No. & size of opening 8 Nos., 5.50mx3.0m
APPROACH TUNNEL
No. 1
Size and type 6.00m dia, Circular concrete Lined
Velocity 3.30m/sec
Length 200m
Design discharge from intake 93.75 cum/sec
DESANDING BASIN
Type Underground, central gutter type
No. of basins 2 nos.

Length of each basin 381m
Size of basins Width13.00m,Depth 19.60m
Minimum particle size to be removed 0.2mm
Flushing tunnel, size 4.00m, D-Shaped
Flushing tunnel, length 1000m
HEAD RACE TUNNEL
No. 1
Size & Shape 5.10m diameter, Modified
Horse shoe shaped Concrete lined
Length 6500 m
Design discharge 75 cumecs
Slope 1 in 120.50 m
Velocity 3.63m/sec
Adit 275m leangth 5m D- shaped
SURGE SHAFT
Type Underground, restricted orifice type
Size 15m dia, 91.80m high
Orifice 2.50m dia
Maximum upsurge level El. 3436.10m
Minimum down surge level El. 3396.60m
Bottom level El. 3350.50m
Top level El. 3436.00m
Adit to top of surge shaft 4mx6m, D-Shaped
2no. 75m each
PRESSURE SHAFT
Type Underground
Size:
Main 1 No., 4.70m dia,
± 350m long
Branches 3 Nos., 2.70m dia, ± 50m
long each
Velocity 4.32 m/sec.
POWER HOUSE
Type Underground
Installed capacity 108 MW
No. and capacity of unit 3 Nos. 36 MW
Size of machine hall 67mx15m
Service bay elevation EL 3250m
Type of turbine Francis, Vertical axis

Speed of turbine 428.60 RPM
Gross Head 177.33 m
Normal tail water level El. 3240.00m
Max. net operating head for
design discharge 182.50m
Minimum net operating head for
design discharge 173.50m
Net operating head for design
discharge 160.00m
Peaking duration 3.00 hrs.
Maximum discharge during peaking hours 75 cumecs.
Firm discharge in 90% dep. Year 11.18 cumecs
TAIL RACE
Size and shape 6.00 m diameter, D-Shaped
concrete lined
Length ± 1150 m
SWITCHYARD
Type underground
TRANSMISSION LINE
No. of circuits D/C Line
Length of each 150Km
Voltage 220.KV
POWER GENERATION
Installed capacity 3x36 MW
Annual energy generation 455.72 MUs
90% dep. Year
1.2 STUDIES UNDERTAKEN
The Layout of the Chhatru HEP has been finalized keeping in view various
studies undertaken by HPSEB from time to time to conceive a most
economical and viable scheme on Chandra river above the proposed
Khoksar HEP.

Proposal-I
The proposed Chhatru HEP envisages diversion of river Chandra about
5km. u/s of Chhatru village in Lahaul & Spiti Distt. of Himachal Pradesh at
El. 3405m by constructing a diversion Barrage comprising 6 nos. spill bayse
bays each of size 5.00mx6.00m with crest El. at 3407m to pass the design
flood of 1500 cumecs. The reservoir formed u/s of the barrage shall provide
a peaking storage for 3 hrs. The diverted flows will be carried to
underground desilting tank designed to exclude all silt particles down to
0.20 mm size. The inflows will further be carried to surge tank 91.80 high,
15m dia, through 5.10m modified house shoe shaped head race tunnel ±
6.50 km. long . From surge tank, the flow will be carried to underground
power house located on right bank of Chandra river through a 4.70m dia.
Pressure shaft bifurcating near the power house to feed 3 nos. vertical axis
generating units of 36 MW (108MW) installed capacity each, utilizing a
design discharge of 75 cumecs and net head of 160 m. Further the water
shall be discharge to Chandra river through underground tail race ± 1150m
long and 6.00m dia D-shaped tunnel.
Proposal-II
About 600m d/s of the Proposal-I the diversion barrage has been proposed,
where river terrace of about 200m width is available as proposed in GSI
report. The proposal envisages the diversion at El. ± 3397m, to pass a
design flood of 1500 cumecs. The diverted flow will be further carried to
underground desilting tank, designed to exclude all silt particles down to
0.20mm size. The inflow will further be carried to surge tank 91.80 high,
15m dia, through 5.10m modified horse shoe shaped head race tunnel
±6.00km. The flow will be carried to under ground power house to feed 3
nos. generating units each of 33 MW (99MW) installed capacity each,
utilizing a design discharge of 75 cumecs and net head of 151m. The HRT

after Chhatru nallah, surge shaft, pressure shaft, power house and tail race
are the same of as Proposal-I.
The proposal has been rejected on the fact that the installed capacity of the
project has been reduced from 108 MW to 99 MW and there is always threat
of Hamta glacier to damage the diversion structure of the project.
The alternative proposals are shown in Plate-1.1.
1.3 COST ESTIMATE & FINANCIAL ASPECTS
COST ESTIMATE
Capital cost of the project (At Price level Oct.2003):
Civil works Rs. 386.79 Crore
Electrical works
(P-Production) Rs. 136.12Crore
Cost of generation Rs. 522.91 Crore
T-Transmission Rs. 8.45 Crore
Total Rs 531.36 Crore
Capital cost of Generation Rs. 585.15 Crore
(Including IDC Rs. 62.24Crore)
Loan 70% Rs. 409.60Crore
Equity 30% Rs. 175.54Crore
FINANCIAL ASPECTS
Cost of generation per MW of
Installed capacity Rs. 4.84Crore
Levelized tariff at PH
Bus bars in 90% dep. Year
Rs. 2.28/Kwh

Energy available in 90% dep. Year
at power house bus bars
455.72GWH

PARA DESCRIPTION PAGE
2.0 BACK GROUND INFORMATION II-1
2.1 GENERAL INFORMATION II-1
2.2 POWER SCENARIOS & EXISTING
INSTALLATIONS
2.2.1 POWER ABSORPTION IN NORTH REGION II-1
2.2.2 POWER LOAD DEVELOPMENT II-1 TO II-2
2.3 NECESSITY OF THE PROJECTS AND
RELATED ASPECTS
PLATE 2.1 MASTER PLAN OF BEAS BASIN
II-1
II-2

CHAPTER – II
BACKGROUND INFORMATION
2.0 BACKGROUND INFORMTION
2.1 GENERAL INFORMATION
Hydel potential of Chenab basin in H.P. has been identified as 3155.30 MW
as indicated in Plate –2.1 for this basin. The hydel projects under operation
are Sisu (0.10 MW),Biling(0.20 Mw), Shansha(0.20 MW), Killar (0.30
MW) and Thirot (4.50 MW) in this basin. The proposed projects as per
CEA ranking study are Chhatru (108 MW), Khoksar (90 MW), Gondhala
(144 Mw), Bardang(114 MW) and Sach-Khas (70 MW) in addition to
Tunsha(150 MW), Rashil(150 MW), Palam(60 MW), Tingal(81 MW),
Miyar(90 MW), Seli(600 MW), Dugli(360 MW), Sagpari(210 Mw) and
Dugar (360 mw). The investigation of Gyspa (240 MW) is already under
investigation.
2.2 POWER SCENARIOS & EXISTING INSTALLATIONS
2.2.1 POWER ABSORPTION IN NORTHERN REGION
2.2.2 POWER LOAD DEVELOPMENT
The Northern Region comprises the states of Himachal, Haryana, Punjab,
Rajashtan, Jammu & Kashmir, Uttar Pradesh and Union territory of Delhi
and Chandigarh. The Northern Regional Power Grid comprises the power
system controlled by the Electricity Boards of above states/Union territories
and Bhakhra Beas Management Board.
The Power system in this region is now operating in an inter-connected and
co-ordinated manner. Even in co-ordinated operation of existing hydro,
nuclear and thermal power stations, including benefits from the ongoing

projects and as well from the new schemes cleared by CEA, the Northern
region is expected to face severe power deficits in the 10 th Five Year Plan.
2.3 NECESSITY OF THE PROJECT AND RELATED ASPECTS
From the growth of peak demand and anticipated installed generation
capacity on the basis of schemes proposed for benefits under
construction/consideration during 9 th and early 10 th Five Year Plan period it
is observed that power supply position in the Northern region would become
all the more acute from the start of 10 th Five Year Plan and power region
shortages would have to be faced unless additional schemes are taken up
immediately and implemented to derive timely benefits. The most
important source of power development in the Northern region is its
abundant hydro resources located in Himachal Pradesh, Uttar Pradesh and
Jammu & Kashmir. Priority would have to be given to the development of
these untapped resources because of the following distinguishing features of
the hydro stations.
i) They estimate the most economic source of power development.
ii) They provide the cheapest source of peaking capacity.
iii) They enable improvement in the utilization of thermal/nuclear power
stations in the region.
iv) They provide much needed operation & flexibility to the system.
Thus there is an urgent need of rapid hydro potential exploitation for
providing additional generation capacity in the Northern region. Among the
various sites, available for hydro development, Gharopa Hydro-electric
Project is considered very attractive from point of view of deriving benefits
during 11 th Five Year Plan. The project is located on NH-21 and all the
sites are well connected with NH-21. The existing communication facilities
will be of considerable utility in cutting down the pre-construction time.

PARA DESCRIPTION PAGE
3.0 PROJECT AREA III-1
3.1 DESCRIPTION OF PROJECT INCLUDING
RIVER SYSTEM
III-1
3.2 SOCIO ECONOMIC AND OTHER ASPECTS III-2

CHAPTER – III
PROEJCT AREA
3.0 PROJECT AREA
3.1 DESCRIPTION OF PROJECT INCLUDING RIVER SYSTEM
Himachal Pradesh has the unique distinction of providing water both to the
Indus and Ganges basins. The major river systems of the region are
Chander Bhaga or Chenab , the Ravi, the Satluj and the Yamuna. These
perennial rivers are both snow and rain fed and are protected by fairly
extensive cover of natural vegetation.
River Chandra originates from the snow covered slopes of Great Himalayan
of Pir Panjal ranges in Lahaul Spiti Distt. flows in a steep gradient. The
river is formed by the two major tributaries namely Chandra & Bhaga.
This project comprises a diversion barrage on river Chandra, ± 19m high
above river bed level near village Chhatru, an intake arrangement on the
right bank for drawing discharge of 93.75 cumecs through two approach
tunnels leading to an underground desilting arrangement to exclude all silt
particles down to 0.2mm, 5.10m dia, 6500m long modified horse show
shaped tunnel designed for a discharge of ± 75 cumecs opening into one
15m dia, underground restricted orifice type surge shaft, one pressure shaft
of 4.70m dia 350m long bifurcating into three 2.70m dia, 50m long each
branch pressure shafts, feeding three Francis vertical axis generating units of
36 MW each through a net head of 160m in an underground power house
on the right bank of Chandra river. The project will enable energy
generation of 455.72 GWH in 90% dependable year of flows.

3.2 SOCIO-ECONOMIC AND OTHER ASPECTS
The economy of the Himachal Pradesh is predominantly dependent on
agricultural and allied sectors. The per capital income of Himachal Pradesh
in 1997-98 was Rs. 8747 as compared to Rs. 10400 at the national level.
The electric power being a vital and essential infrastructure has a significant
role to play in economic upliftment of the state. The construction of project
will provide employment to the local people. When completed it will be
another step towards realization of the dreams of the state and exploiting its
power potential for heralding an era of progress and prosperity for not only
of Himachal Pradesh but for the entire northern region.

PARA DESCRIPTION PAGE
4.0 GEOLOGY IV-1
4.1 INTRODUCTION IV-1
4.2 REGIONAL GEOLOGY IV-1 TO IV-3
4.3 STRUCTURE & TECTONICS IV-4 TO IV-5
4.4 SEISMO TECTONICS AND SEISMICITY IV-5 TO IV-6
4.5 GEO-TECHNICAL APPPRAISAL IV-6 TO V-7
4.6 REFERENCES IV-7
PLATE- 4.1 GEOLOGICAL MAP

CHAPTER – IV
TOPOGRAPHIC & GEO-TECHNICAL
ASPECTS
The geo-technical studies of project area have been got carried out from GSI
during Jan. 2004 which is appended in below;
4.0 GEOLOGY OF AREA AROUND CHHATRU HYDROELECTRIC
PROJECT, CHENAB BASIN, LAHAUL AND SPITI DISTRICT,
HIMACHAL PRADESH.
4.1 INTRODUCTION
The Central Electricity Authority in an effort to assess the balance
hydroelectric potential in the country have identified 1,50,000 MW of
balance hydroelectric potential which can be harnessed through 399
proposed schemes. After carrying out ranking studies, the CEA have
selected a few schemes in Chandra valley of which Chhatru is one that is
being taken up in the first phase for preparation of Pre Feasibility Reports.
The proposed Chhatru Hydroelectric Project is located on Chandra river,
upstream of its confluence with Bhaga river and upstream of the village
Chhatru in Lahaul and Spiti district of Himachal Pradesh.
The proposed scheme is a run of river scheme that envisages construction of
a diversion dam/ weir across the river Chandra, 5 Km upstream of the
village Chhatru (32 0 18’00” N: 77 0 28’ 00” E; 52 H/7), a water conductor
system comprising 12 km long head race tunnel and a powerhouse on the
right bank of Chandra River, about 3.5 km upstream of Chhatru bridge
(32 0 19’00” N: 77 0 27’00” E; 52 H/7) with probable installed capacity of 140
MW.
4.2 REGIONAL GEOLOGY
The area where project is located forms a part of Great Himalayan Range
and constitutes both northern and southern slopes of Chandra Valley. The
altitude in the area, varies between 2750m and 6020m. The terrain in upper
reaches of tributaries shows typical glacial landscape characterized by
rugged towering peaks, cirque glaciers and moraine deposits. Chandra river
forms the main drainage of the area. It is joined by a number of tributaries
on its either bank. These are mostly snow/ glacier fed. These tributaries

show sub-dendritic to trellis pattern. The higher reaches of slopes on either
side of Chandra river have a number of glaciers which form the perennial
source of discharge in tributaries. There are several conspicuous moraines
that are well developed towards left bank. There are a number of water falls
in the area of which the one at Sissu village and that about 4 km upstream of
Sissu Nala are prominent ones. The presence of abundant waterfalls in the
area, besides glacier fed discharge is attributable to thick-bedded nature of
rocks and flat disposition of beds. Besides drainage, the lakes are a common
feature in glacial terrain. The lower Chandra valley is characterized by the
river terraces that are being used for habitation and cultivation by local
inhabitants. Although three levels of terraces have been identified in Sissu
area, only one prominent terrace has been identified in Chhatru and Khoksar
areas. These terraces are very thick and extend up to 3225 m elevation in
lower reaches i.e. near Sissu and Retil villages.
The valley slopes in the area are characterised by the stretches of unusually
abundant debris. These could have been due to the fractured or weathered
rocks transported in abundance by snow, avalanches and landslides to the
lower elevations on the banks of the river.
The area around the proposed projects exposes the rocks belonging to
Rohtang Group of Pre-Cambrian age (Prashara & Kumbkarni, 1986-87).
But same has been named as Lahul Group by Prashra (1992). At higher
elevations, it is succeeded by the rocks belonging to Haimanta Group in the
east and those belonging to Vaikrita Group extending from Chandra area in
west.
The Pre-Cambrian stratigraphic succession in the area given by Prashra at El
(1986-87) and Prashra (1992) is given below:-
GROUP FORMATIO
N
Haimanta
Kunzum La
Batal
Chola Thach
LITHOLOGY AGE
Greenish grey siltstone, shale &
dolomite
Quartzite, phyllite, carbonaceous and
pyritous
( It also includes Manjir and Katarigali
Formations)
Garnetiferous schist and quartzite
Proterozoic

Lahaul or Rohtang
Gneissic Group
Gufa
Damphung
Kulti
Granite gneiss, migmatite and meta
sediments
Matamorphites with subordinate gneiss
and migmatite
Granite gneiss, migmatites with high
grade metamorphites
According to Prashra (1992), the rocks of Lahaul Group are divisible into
two lithological units i.e. Rohtang Gneissic Complex and Chola Thach
Formation. While the Rohtang Geneissic Complex is predominantly made
up of gneisses, granites and migmatites with subordinate metasediments, the
latter represents primarily metasedimentary sequence. The Rohtang Gneissic
Complex has further been subdivided into different formations namely
Kulti, Damphung and Gufa.
Kulti is the oldest Formation and is exposed between Khoksar and Chhota
Dara in the valley of Chandra river, the area in which the project is located.
It comprises mostly migmatite and granite gneisses which from about 80%
of lithology. Schists and quartzites form intercalations within gneisses and
migmatites. The individual gneiss bands are thin (0.25m to 1. 0m) and these
attain thickness up to 5.0m between Kulti and Chhatru on left bank of
Chandra River. Quartzite is generally light grey, fine grained and micaceous
and with increase in mica content it grades into mica- schist.
The rocks belonging to Damphung Formation/ Member conformably overly
the rocks of Kulti Formation. These are well exposed on both the slopes of
Chandra Valley upstream of Khoksar- Damphung area. These comprise
mica schist, micaceous quartzite and quartz schist. This schist is commonly
kyanite, staurolite, garnet and occasionally sillimanite bearing on the eastern
slopes of Chhatru Nala. Grey to dark grey-banded quartzite appears at same
stratigraphic level as of Damphung Formation indicating that these two are
facies variant of each other. The rocks of Damphung Formation pass into
those of Gufa Formation. Lithologically these resemble the rocks belonging
to Kulti Member and comprises predominantly granitic and migmatitic
gneisses besides subordinate schist and quartzite.
The rocks belonging to Chola Thach Formation represent the sedimentary
sequence in Lahaul or Rohtang Group and overlie the rocks of Gufa
Formation with gradational contact. This Formation is exposed in low-lying
stretches around Sissu and Teling areas. It consists of grey fine-grained
quartzite, quartz schist and mica schist that are partly garnetiferous.
Proterozoic

Haimanta Group of rocks has been divided into Batal and Kunzum- La
Formations. In the southeastern part of the Lahaul i.e. in the valley of
Chenab or Chandra-Bhaga, the Batal Formation of this group is regarded to
be represented by Manjir and Katarigali Formations of Vaikrita Group in
Chamba area. Here Rapa & Gadhoke (1984) mapped two formations i.e.
Bagotu and Dunai which were regarded equivalents of Manjir and Salooni
Formations of Chamba area. Subsequently unfossiliferous part of Salooni
Formation was renamed as Bharmour Formation and correlated it with
Katarigali Formation of Jammu & Kashmir. These formations have not been
defined in the rest of Lahaul area except that the pelites underlying the
Tandi Group were correlated with Salooni and conglomerate exposed at
Chobia and Trilokinath with Manjir Formation by Raina and Prashara
(1973).
Manjir Formation conformably overlies the Chamba Formation which is
considered extension of the Batal Formation of Lahaul. It is characterized by
diamictite, shale, slate and quartzite. The frame work of clasts is constituted
of quartzite, vein quartz, phyllite, slate, limestone and granite. The clasts of
pelitic rocks show considerable stretching and diamictite facies at places
change into grit and quartz wacke.
The rocks belonging to Katarigali Formation conformably overlie those of
Manjir Formation. These are mainly composed of quartzite, slate & phyllite.
The area encompassing the project exposes the rocks belonging to Katarigali
Formation
4.3 STRUCTURE AND TECTONICS
Tectonically, the present area forms part of Central Axial Zone of
Himalayas. The structural elements of the area can be grouped in two i.e.
non-diastrophic and diastrophic structures. The non-diastrophic structures
include colour and compositional banding, current bedding in the quartzites
of Manjir and Katarigali Formations etc. The diastrophic structures include
schistosity, crenulation cleavage, fracture cleavage, joints etc. Schistosity is
most penetrative planar structure in the area and has general NW-SE trend
with shallow dips (10 o -25 o ). It is developed parallel to axial plane of first
folds and is parallel to sub parallel to bedding. Crenulation cleavage has
developed parallel to axial plane of second phase folds. It has folded
bedding as well as schistosity. General trend of this structural plane is NW-
SE with 15 o -30 o dips towards NE. Fracture cleavage is represented by
fractures developed parallel to the axial plane of third phase folds. It’s trend
varies from NNE-SSW to NNW-SSE and dips sub-vertically to vertically.
Broadly there are three prominent sets of joints having NNE-SSW, E-W and
NNW-SSE to N-S trends and have steep to very steep dips.

Three phases of folding are identifiable in the area. The folds belonging to
first phase (F1) are rarely preserved. These are invariably tight in nature and
have NW-SE trend in general. The mesoscopic folds belonging to second
phase (F2) are most common folds in the area. These are open to tight and
upright to recumbent. These are coaxial with folds of F1 phase and have
NW-SE general trend with 5 o -10 o plunge towards NW. The third phase folds
(F3) are represented by open warps. These are transverse to F1 and F2 folds
and have a general low plunge towards N to NE. The rocks of this area are
disposed in the form of a regional anticline, the axes of which coincides
with the Chandra river. This anticline is represented by a broad upright warp
with large crestal area. It shows 5 o -10 o plunge towards NW exposing the
younger formations towards downstream.
4.4 SEISMOTECTONICS AND SEISMICITY
Seismotectonically, the area encompassing the proposed project is located in
Central Himalayas on the western margin of Shimla Seismic Block of
Narula (1999). The Shimla Seismic Block is bound by Sunder Nagar Fault
in west and Kaurik Fault in east. As per Seismotectonic Atlas of India and
its environs (Narula et al., 2000), the litho tectonic packets of Himalayan
Orogenic Belt in the region are poorly metamorphosed litho units of
Tethyan Unit, high and low grade assemblages of Central crystalline and
Lesser Himalayan Belt along with granitoids and basic volcanics. The
southern fringe of Himalayan belt is occupied by the cover rocks of frontal
belt.
Within Himalayan Belt, the northern most conspicuous structural element is
the Main Himalayan Thrust (MCT). From Manali towards east up to eastern
syntaxes through out the entire Himalayas, this is considered as most
important tectonic surface. However, it is not clearly discernible northwest
of Manali. Further south, within the lesser Himalayas, the most important
tectonic surface is Vaikrita Thrust (VT). The Lesser Himalayan Belt is
separated from the Frontal Belt by the Main Boundary Thrust (MBT).
Further south, the southern limit of the Frontal Belt is marked by the Main
Frontal Thrust (MFT) that has its surface manifestations at a few places only
within MBT and MFT, the belt is traversed by several subsidiary thrusts that
have considerable spatial extent.
In addition to the structural discontinuities sub-parallel to regional trend,
there are a number of faults and lineaments transverse to this fold-thrust
belt. The Sunder Nagar Fault located in the project area is a dextral
transverse structure that extends from Higher Himalayas to Frontal Belt.
The Ropar Fault (Tear ?) is postulated to be continuation of Sunder Nagar
Fault. Another fault similar to above has been identified in south east of
Chandigarh. All these transverse faults including Yamuna Tear located
further southeast exhibit neo-tectonic activity.

A total of about 80 seismic events having magnitude >4.0 have been
recorded in the Himalayan Belt in the area. Out of these 17 events had
magnitude >5 and were mostly confined to the depths less than 40 km. The
events having magnitude >4 and >5 are predominant in the area. Seismic
activity is concentrated mainly in the Himalayan Belt, particularly in NW
sector around Chamba- Kangra in adjoining Kangra Seismic Block. Out of
the 17 events having magnitude >5, 14 events are located in this zone. In
this region of Himalayas, 4 events having magnitude >6 were recorded and
three out of these including the Great Kangra earthquake of 1905 are located
along MBT and one event on the surface trace of Sunder Nagar Fault. Six
earthquakes from the area have caused considerable damage and these
include Kangra Earthquake of 4 th April 1905 (Ms=8.0); Chamba
Earthquake of 22 nd June, 1945 (Ms=6.5.); Dharamshala earthquake of 14 th
June, 1978 and 26th April, 1986 and Chamba Earthquake of 24 th March,
1995 . Keeping in view the seismic status and seismotectonic setup in view,
the area has been kept on the margins of Zones V and IV as per Map of
India showing Seismic Zones (IS: 1893 (Part-I):2002). Therefore it is
suggested that suitable seismic coefficient be specifically evolved for the
area and incorporated in the design of the appurtenant structures of the
projects.
4.5 GEOTECHNICAL APPRAISAL
The site was visited on 24.8.2003 along with Shri A.K. Gupta, Director
Planning, HPSEB, Sundernagar and other HPSEB officers. The proposed
Chhatru Hydroelectric Project is located in the upper reaches of Chandra
Valley where both terrain and climate are hostile. The valley flanks are
dotted with recent and sub-recent avalanches which have accumulated as
talus cones which go upto 100 m above river bed at places. The proposed
dam site is located about 5 km upstream of Chhatru. The river Chenab
flows towards west. The area exposes granitic gneiss belonging to Rohtang
Gneissic Group. The rocks are folded into an anticline and river flows along
this anticlinal axis. The river bed is about 100 m wide. The talus cones
extend on abutments upto about 100 m above river bed. This site does not
appear to be suitable for dam as bed rock is expected to be deep both in the
river bed and on the abutments. The abutments are covered with boulders
upto 5 m in size. It is suggested that temporary diversion structure founded
on permeable strata be considered here. Similarly, the site for locating
intake structure for HRT in bed rock is not available at least up to 2 km on
both sides from the site of diversion structure. Therefore the tunnel
alignment in the initial reaches has to be explored for delineating the bed
rock so that proper intake structure is constructed. Upto the point where
adequate rock cover is available over the tunnel the same will have to be
designed as structural tunnel with false portal. The desilting arrangement
has to be designed underground due to topographic and climatic constraints.

About 600 m downstream of the proposed site, the ridge between two
hanging glaciers can be utilized for temporary diversion structure. The
diversion structure could be located in the ridge upstream of Hamta Glacier.
However, the behavior of glacier has to be investigated at this site. About
200 m wide terrace is available for transferring discharge to right abutment
where bed rock is exposed right from terrace. The intake structure can be
located in bed rock. The 8 km long HRT will encounter granitic gneiss.
These are foliated and jointed. The foliation trends NW-SE and dips about
25 o -30 o towards NE. The HRT will be crossing Chhatru Nala. It is
suggested that HRT be aligned in such a way that adequate rock cover is
available over the structure. The possibility of locating an intermediate
construction adit in Chhatru Nala may be looked into.
The proposed powerhouse with 100 MW installed capacity is located on
right bank of Chenab about 2.5 km downstream of Chhatru Bridge. The
proposed site is located between two nalas which have debris cones at their
mouth. The site has thin debris fans comprising boulders up to about 50 m
above riverbed. Above it, the granite gneiss is exposed on steep slope upto
200 m above riverbed. The rock is jointed. The site is suitable for an
underground powerhouse. There is also possibility of locating the
switchyard on left bank of the river on a terrace where sufficient space is
available. Otherwise the same may be kept underground.
4.6 REFRENCES
Narula, P.L., (1991) Seismotectonic evaluation of NW Himalaya, Rec. Geo.
Surv. Ind., 127(8), 14949.
Narula, P.L., Acharayya, S.K. and Banerjee, J. (2000) Seismotectonic Atlas
of India and its environs. Pub. Geol. Surv. Ind.
Prashara, K.C., Des Raj and Kumbkarni, S. (1986- 87). Geology of Parts of
Chandra Valley, Lahaul and Spiti district, Himachal Pradesh, Unpubl. G S I
Report for F S: 1986-87
Prashara, K.C. (1992) Final Report on Geology of Lahaul and Spiti District,
Himachal Pradesh., Unpublished GSI Compilation
Raina, V. K. and Prashara, K. C., (1973). Geological Mapping in Parts of
Pangi Valley, Chamba and Lahaul Spiti districts, Himachal Pradesh,
Unpublished GSI Report for F. S. 1971- 72 .
Rapa, D.A. and Gadhoke, S.K. (1983). Geology of Parts of Chamba district,
Himachal Pradesh, Unpub. GSI Report for F.S. 1982- 83

PARA DESCRIPTION PAGE
5.1 RIVER CHANNEL AND CATCHMENT
CHARACTERISTICS
5.1.1 HYDROMETEOROLOGY OF THE CATCHMENT V-1
5.2 DISCHARGE DATA AND WATER AVAILABILITY V-2
5.2.1 CO-RELATION STUDY V-2 TO V-3
5.3 DESIGN FLOOD V-3 TO V-4
5.4 SEDIMENTATION ASPECTS V-4
TABLE-5.1 TEN DAILY AVERAGE DISCHARGE DATA OF
RIVER CHANDRA AT GHOUSAS FROM JUNE 1973
TO MAY 2000
TABLE-5.2 TEN DAILY AVERAGE DISCHARGE DATA
DIVERSION SITE
TABLE-5.3 INFLOW OF RIVER CHANDRA AT GHOUSAL &
INFLOW OF RIVER BHAGA AT TANDI
TABLE-V-5.3(1)
TO 5.3(6)
REGRESSION ANALYSIS BETWEEN DISCHARGES
OF TANDI & GHOUSAL
TABLE- 5.4 INFLOWS OF RIVER CHANDRA AT UDAIPUR &
INFLOWS OF RIVER BHAGA AT TANDI PLUS
RIVER CHANDRA AT GHOUSAL
TABLE- 5.4(1)
TO 5.4 (6)
REGRESSION ANALYSIS BETWEEN DISCHARGES
OF TANDI PLUS GHOUSAL AND UDAIPUR
V-1
V-5- TO V-9
V-10 TO V-14
V-15
V-16
V-17 TO V-22
V-23
V-24
PLATE –5.1 FLOW DURATION CURVE (OVER ALL) V-31
PLATE-5.2 FLOW DURATION CURVE (LEAN PERIOD) V-32
V-25 TO V-30
ANNEXURE-V-1 ESTIMATE OF DESIGN FLOOD V-33 TO V-45
ANNEXURE-V-2 COMMENTS RAISED BY CEA/CWC ON
HYDROLOGY
ANNEXURE-V-3 REPLY TO THE COMMENTS ON HYDROLOGY V-52
V-46 TO V-51

CHAPTER – V
HYDROLOGY
5.1 RIVER CHENAB AND CATCHMENT CHARACTERISTICS.
The river orginates from the snow covered slopes of Great Himalayan of
Pir-Panjal ranges in Lahaul Spiti district and flows in a steep gradient with a
series of loopes and bends. The river is formed by the two major tributaries
in the head reaches namely Chandra and Bhaga.The river Chandra originates
from Bara Lachala and is further augmented by Chandra Tal. The river
Bhaga takes off from Suraj Tal in the vicinity of Bara Lachala and is further
joined by Jhankar and Millang nallahs in the head reaches. The catchments
of these two major tributaries have snow covered peaks at height ranging
from ± 3500 m to 5500 m elevation. The Chandra river and Bhaga river
joins at Tandi to form Chandra-Bhaga i.e. the Chenab. Further downstream
of confluence, it is joined by other significant tributaries namely Shansha
nallah near Rashil, Thirot nallah at Thirot, Miyar nallah at Udaipur, Saichu
nallah at Dawag, Mahal Nallah at Killar & Dheda nallah at Lujai d/s of
Killar. Chenab river drains a catchments of about 7500 Sq. Km. before it
crosses in to J&K border.
5.1.1 HYDROMETEOROLOGY OF THE CATCHMENT
This region is a low rainfall area as most of the precipitation in the region is
in the form of snow. The rainfall takes place during the monsoon months
only and the catchment experiences snowfall during the remaining period of
the year. There is only one rain gauge station in this region, installed at
Keylong and the rainfall data has not been recorded regularly even at this
station. It is observed that the most of the runoff in the river results from the
melting of snow.

5.2 DISCHARGE DATA AND WATER AVAILABILITY
The discharge data of river Chandra at diversion site of Chhatru HEP has
been derived from June 1973-May 2000 from the discharge data of river
Chandra at Ghousal (site monitored by CWC).
Discharge data of river Chandra at Ghousal is given in table 5.1 while the
computed discharge data reduced on catchment area basis at diversion site is
given in Table– 5.2
Based upon ten daily discharge data, a flow duration curve has been
developed. From this curve, it is seen that flow corresponding to 90% &
50% availability works out to 10.41 cumecs & 26.30 cumecs respectively.
The design discharge of 75 cumecs is available for 32.15 % of the period.
Flow duration curve for lean-season (Dec. to Feb.) has also been developed .
From this curve , it is seen that flow corresponding to 90% & 50%
availability works out to 6.96 cumecs & 12.95 cumecs respectively.
5.2.1 CO-RELATION STUDY
W.B. Langbein’s log deviation method has been used to obtain the coefficient
of co-relation between discharges of river Chandra at Ghousal and
discharges of river Bhaga at Tandi.
The Co-relation factors are as follows:
June-July = 0.92
Aug.-Sept. = 0.96

Oct.-May = 0.96
These calculations have been shown in Table- 5.3
Similarly coefficient of co-relation has been obtained between discharges
of river Chenab at Udaipur and the sum of discharges of river Chandra at
Ghousal & river Bhaga at Tandi.
June-July = 0.94
Aug.-Sept. = 0.96
Oct.-May = 0.88
These calculations have been shown in Table-5.4
From the above co-relation factors it is evident that the discharges of river
Chandra at Ghousal & river Bhaga at Tandi including river Chenab at
Udaipur are consistent. Thus the discharges of river Chandra at Ghousal
have been approved by CWC and used for carrying out studies which stands
submitted to the CWC and comments are awaited.
5.3 DESIGN FLOOD
The project falls in Western Himalayas Zone seven in map of India. The
total catchment area of river Chenab in India is about 31,047 Sq. Kms. The
catchment is mostly fed by snow. The majority percentage of the runoff in
the catchment is derived from the snow & glaciers which constitutes a
potential reservoir. Winter precipitation which occurs in the form of snow
goes on accumulating till summer. As the summer advances, the
accumulated snow melts and releases water into the stream.

Design Flood has been computed on the basis of Flood Estimation report for
Western Himalayas-zone 7 & accordingly hydrographs have been prepared.
The max.. flow due to rain contribution comes out to be 291.59 cumecs
which has return period of 1 in 50 years. The maximum flow for return
period of 1 in 100 years is 321.38 cumecs. The snow contribution has been
taken to be 342.09 cumecs ie the maximum discharge of flow during 2 nd
week of July in flow series at diversion site. Thus the total design flood
works out to be 663.47 cumecs. Flood frequency analysis has also been
carried out by Gumble’s method.
Return period of 1 in 1000 years has been considered for computing the
SPF which works out to be 1377.59 cumecs. The designed flood has been
taken as 1500 cumecs. The computations have been shown in Annexure-V-
1.
5.4 SEDIMENTATION ASPECTS
Detailed studies shall be carried out at DPR stage. However 20% of the live
storage has been proposed to be kept reserved for silt deposition in the
reservoir.

Annexure-V-3
Reply to the comments raised by Director Hydrology, CWC, New Delhi on hydrology
vide letter no. 1/HP/26/2004/CWC/131 dated 19.04.04, further intimated by Dy.
Director, HPI, CEA vide letter No. 7/91/HPSEB/2004/HPI/877/dated 21.04.04.
Design flood
1. The water way and free board in barrage have been designed as per design flood of
1500 cumecs workout by flood frequency analysis for 1000 years return period,
which is already on higher side. However, the same shall be revised at DPR stage
after the finalization of design flood as suggested.
2. As suggested efforts to collect data of annual instantaneous flood peak series at
Ghousal G&D site from CWC Jammu are being made. The results as per best fit
distribution shall be carried out at DPR stage.
3. SPE values from IMD and instantaneous peaks at Ghousal have not been received
so far, as such study will be carried out as DPR stage.
4. As agreed the design flood shall be reviewed at DPR stage.
5. Recommendations:-
i) The new gauge discharge observation may be opened before the preparation
of DPR .
ii) Few SRRG, ORG, station, weather stations may be established in the
project area to collect more information regarding precipitation and snow
melt contribution.
iii) The above mentioned suggestions shall be taken care of the immediately
after the availability of funds for investigation in near future.

PARA DESCRIPTION PAGE
6.0 CONCEPTUAL LAYOUT OF PROJECT
COMPONENTS
VI-1
6.1 FINALIZATION OF CONCEPTUAL LAYOUT VI-1
6.2 PRELIMINARY DESIGN FEATURES VI-2
6.2.1 BARRAGE VI-2
6.2.1.1 GENERAL VI-2
6.2.1.2 RESERVOIR VI-2
6.2.1.3 BARRAGE BAYS VI-3
6.2.1.4 ENERGY DISSIPATION VI-3
6.2.2 RIVER DIVERSION WORKS VI-3 TO VI-4
6.2.2.1 INTAKE STRUCTURE VI-4
6.2.3 DESANDING ARRANGEMENT VI-4 TO VI-5
6.2.4 HEAD RACE TUNNEL VI-5
6.2.4.1 GENERAL VI-5
6.2.4.2 CROSS SECTION VI-6
6.2.5 SURGE SHAFT VI-6
6.2.5.1 GENERAL VI-6
6.2.5.2 HYDRAULIC PARAMETERS VI-6
6.2.5.3 CONCRETE LINING VI- 7
6.2.6 PRESSURE SHAFT VI-7
6.2.6.1 GENERAL VI-7
6.2.6.2 ECONOMIC DIAMETER VI- 8
6.2.7 POWER HOUSE VI-8
6.2.7.1 GENERAL VI-8
6.2.7.2. TYPE VI- 9

6.2.7.3 MACHINE HALL VI-9 TO VI-
10
6.2.7.4 TRANSFORMER HALL VI-10
6.2.8 AUXILIARY SURGE SHAFT AND TAIL RACE
TUNNEL
VI-10
6.3 PRELIMINARY DRAWINGS VI-11
6.4 DESIGN COMPUTATIONS VI-12 TO VI-
33
DRAWINGS
CHHATRU-
FR-1
CHHATRU-
FR-2
CHHATRU-
FR-3
CHHATRU-
FR-4
CHHATRU-
FR-5
CHHATRU-
FR-6
CHHATRU-
FR-7
CHHATRU-
FR-8
CHHATRU-
FR-9
CHHATRU-
PLATE-6.1
VICINITY MAP 1 SHEET
MASTER PLAN OF CHENAB BASIN (CEA
SCHEMES)
1 SHEET
CATCHMENT AREA PLAN 1 SHEET
GENERAL LAYOUT PLAN 1 SHEET
DIVERSION BARRAGE, INTAKE,& DESANDING
BASIN
HEAD RACE TUNNEL, SURGE SHAFT & PRESSURE
SHAFT
POWER HOUSE AND TRANSFORMER HALL PLAN,
L- SECTION AND SINGLE LINE DIAGRAME
2 SHEETS
1 SHEET
3 SHEETS
CONSTRUCTION FACILITIES 1 SHEET
CONSTRUCTION PROGRAME 1 SHEET
AREA CAPACITY CURVE 1 SHEET

CHAPTER – VI
CONCEPTUAL LAYOUT
AND PLANNING

CHAPTER – VI
CONCEPTUAL LAYOUT
AND PLANNING
6.0 CONCEPTUAL LAYOUT OF PROJECT COMPONENTS
6.1 FINALIZATION OF CONCEPTUAL LAYOUT
The proposed Civil Engineering Structures have been planned and designed
to divert and conduct 75 cumecs of water, from river Chhatru for generating
108MW of power in an underground power house by utilizing a gross head
of 177.33m. The main works of the project comprise a diversion barrage,
intake, underground desanding basins for removing all particles down to
0.20mm size, 6500m long head race tunnel, a restricted orifice type surge
shaft and an underground power house to accommodate 3 vertical axis,
Francis turbines driven generating units each of 36 MW. After diversion, all
the civil engineering components have been kept underground keeping in
view the topography of the area. Comments on the draft PFR of the project
issued by Director, HCD (NW&S) of CWC vide no. CWC
U.O.NO.22/1/03/HCD(NW&S) dated have been
incorporated. A brief geological site specific feasibility note titled “Geotechnical
appraisal” founded on preliminary site inspection about each
component is appended as Para 4.5 in chapter-IV titled “Geographic & Geotechnical
Aspects”.

6.2 PRELIMINARY DESIGN FEATURES
6.2.1 BARRAGE
6.2.1.1 GENERAL
The slope of river at the diversion site u/s of Chhatru village is of the order
of 1:23. Peak annual flood of river Chandra at diversion site has been
adopted as 1500 cumecs for design of spillways/barrage bays. Barrage 185m
long including abutments with crest level of barrage bays at El. 3407m &
non over flow section has been proposed to pass the estimated design flood
at FRL El. 3421.00m. The proposed barrage comprises 6 bays of 5.00m
each with 3.00m thick piers and is capable of passing the estimated design
flood even when one bay is considered inoperative during period of high
floods. The max. pond level/ FRL (El. 3421.00m) attained during winter
months shall also cater to peaking requirement . During high flood max.
water level to be attained has been proposed as 3422.00m. Radial gates in
the barrage bays shall be provided from top of crest El. 3407m to the bottom
of RCC breast wall El. 3413.00m spanning between the piers. The breast
wall is supported on the piers and is provided between El. 3413.00m and El.
3424.00m.
6.2.1.2 RESERVOIR
The full reservoir level (FRL) is fixed at El. 3421.00. The minimum draw
down level (MDDL) has been fixed at El. 3413.50m. The reservoir so
formed has a gross storage capacity of 112.50 ha-m at FRL and 25.00 ha-m
at MDDL. Available diurnal storage of 70.00 ha-m ( 87.50 -20% reserved
for silt deposits) is sufficient for running the power station as a peaking
station at full installed capacity for 3.00 hrs. The discharge availability in
lean period(Nov. to Feb) in 90% dep. year is 11.18 cumecs. The reservoir
spreads over an area of 16.00 hectares and is about 1.00 km long. The area

capacity curve for the reservoir has been drawn from the available contour
plan of the area on 1:2500 scale and is shown in Plate No. 6.1
6.2.1.3 BARRAGE BAYS
6 barrage bays 5.00m wide each have been provided to pass the design flood
discharge i.e. 1500 cumecs. Total floor of 136m length has been proposed
comprising u/s floor, sloping glacis u/s & d/s (4:1) and d/s floor of 50m
including end still. A 4 m deep cut off extending up to 3401m at u/s side of
the floor and 5.00m deep cut off at the end of d/s floor extending up to El.
3390m have been provided to protect the u/s and d/s floor from scour/
piping action. Cement concrete blocks extending 10m each beyond u/s and
D/s floors have been provided. Protection to cement concrete blocks have
been provided with stone filled wire crates extending 10m beyond u/s & d/s
floors. Consolidation grouting has not been proposed in the river bed,
keeping in view the fact that rock is not available upto reasonable depth in
the river bed.
6.2.1.4 ENERGY DISSIPATION
Dissipation of energy is proposed to be done by providing a horizontal
stilling basin depressed below the river bed level (El. 3395m) with solid end
sill to facilitate formation of hydraulic jump. Layout & details of barrage
have been shown in drawing No. CHHATRU-FR-5.
6.2.2 RIVER DIVERSION WORKS
The river diversion works have been designed for a discharge of 600
cumecs. The construction of diversion works i.e. half of barrage, intake
structure from inlet have been proposed to be taken up by making Ist Stage
coffer dam of length 300m allowing flow of water along the left bank of
river. After the completion of diversion barrage upto El. 3407m & Power

intake upto El. 3410m the Ist stage coffer dam shall be removed and water
shall be diverted on right bank of river through barrage constructed, by
making 2 nd stage coffer dam. Thereafter, the construction of remaining half
of the barrage shall be completed. The construction of diversion works has
been proposed to be completed within three months period. Construction of
coffer dam is proposed to be modified as per site conditions after each
monsoon season.. The provision for construction of coffer dam has been
made accordingly, adding 50% quantum of work being involved due to
repetition of job after each season in the cost estimate of the project. The
provision of plain cement concrete of grade M-10 has been made on the top
and side slopes of coffer dam to prevent the seepage of water towards
working area.
6.2.2.1 INTAKE STRUCTURE
The intake structure comprising single intake with eight no. openings,has
been proposed on the right bank of river, to handle a discharge of 93.75
cumecs. A semi circular trash rack structure with reinforced concrete
columns has been proposed for intake. Crest elevation of intake is proposed
as 3410m. Stop logs has been proposed for controlling flow through intake
bays 8 nos.(5.50mx3m) each during repairs. A suitable transition is
provided to convert the rectangular opening into a 6.00m dia circular
approach tunnel. Approach tunnel is 200m long and shall lead the water into
two desanding basins. Details are shown in drawing No. CHHATRU-FR-5.
6.2.3 DESANDING ARRANGEMENT
An underground desanding arrangement to exclude all silt particles down to
0.20mm has been proposed ±100m d/s of barrage on the right bank of river
Beas. A lateral rock cover more than 1.5xexcavated width has been ensured
for locating chamber No. 1. Rock cover of the order of twice the width of

excavated cavity of the chamber has been ensured in between the two
chambers. Stop logs will be provided at the inlet and outlet of all the
chambers to facilitate closing of any chamber for maintenance/repairs, while
the others will enable continuous operation of the power station. Layout
and details of desilting arrangement are given in drawing No. CHHATRU-
FR-5.
6.2.4 HEAD RACE TUNNEL
6.2.4.1 GENERAL
The head race tunnel 5.10m dia, 6500m modified horse shoe type has been
proposed to carry a design discharge of 75 cumecs from the junction point
of feeder tunnels of desilting chamber with HRT to the surge shaft. The
tunnel is located along right bank of river Chandra. Layout of the tunnel has
been fixed keeping in view the topography of the area and location of
construction adit from Chhatru nallah for completing the tunnel excavation
work on schedule. Adequate rock cover has been ensured in entire reach of
the tunnel. The invert level of tunnel at RD-0 is at El. 3402.50m and at
outlet end at El. 3348.45m resulting in a slope of 1 in 120.
Three adits each 5m D-shaped at inlet, outlet and at intermediate location
(RD 3500m) have been provided to facilitate construction of HRT from four
faces. The inlet and outlet adits are so provided that they shall separate the
construction activity of the head race tunnel from that of desilting chambers
and surge shaft. The layout of the tunnel and other details are indicated in
Drawing. No. CHHATRU-FR-6.

6.2.4.2 CROSS SECTION
Based on geological, hydraulic, structural and functional considerations,
modified horse shoe shaped cross section, 5.10m dia has been adopted. The
tunnel is proposed to be lined with concrete M:20.
6.2.5 SURGE SHAFT
6.2.5.1 GENERAL
The underground restricted orifice type surge shaft of 15m dia and 91.80m
height has been proposed at the outlet end of Head race tunnel at RD 6500.
Top level of surge shaft is proposed at El. 3448.00m. Two adits each 6m Dshaped,
one approaching the top at El. 3438.00m and other at the bottom at
El. 3348.00m have been proposed. The bottom adit will also be utilized to
facilitate excavation of surge shaft and horizontal portions of pressure shaft.
After execution of the project this adit will be plugged near junction of
pressure shaft and rest of it will be used as a drainage gallery. General
layout and details of surge shaft are shown in drawing No. Gharopa-FR-6.
6.2.5.2 HYDRAULIC PARAMETERS
Surge shaft area has been worked out by using Thomas’s criteria for
incipient stability with factor of safety as 1.6m conforming to IS:7396 (Part-
I) 1979. Maximum upsurge and minimum down surge levels have been
computed by computer analysis as per above mentioned IS code. Maximum
upsurge level works out to be 3436.00m and minimum down surge level as
3996.60m. For calculating maximum upsurge and minimum down surge
levels the friction co-efficient have been taken as 0.012 and 0.016
respectively.

6.2.5.2 CONCRETE LINING
It is proposed to provide reinforced concrete lining for surge shaft. Lateral
cover around surge shaft at all heights has been kept more than three times
the excavated diameter of the surge shaft. It is assumed that upsurge being
of very short duration will not cause any saturation in the surrounding rock
mass.
6.2.6 PRESSURE SHAFT
6.2.6.1 GENERAL
A 4.70m dia pressure shaft with centre line at El. 3351.00m will take off
from surge shaft for leading the water in to turbines. In the initial 75m
horizontal reach, a valve gallery has been proposed to accommodate
butterfly valve.The inclined length of main pressure shaft is 340m. Three
nos. branch pressure shaft of 2.70m dia totalling 50m in length ,takes off
from the main pressure shaft to feed three units in the power house. The
entire length of the pressure shaft will be steel lined. An adit at an elevation
±3348.00m to valve gallery has been provided to facilitate excavation of
the top horizontal reach and some inclined portion from the top and will also
be utilized as drainage gallery to relieve external pressure. The excavation
of remaining inclined portion will be carried out from power house cavity.
The space between liner and excavated rock will be back filled with M-20
conc. Adequate contact grouting will be done at contact points of concrete
with liner and rock. Consolidation grouting has also been proposed in the
reach, where the pressure shaft will pass through poor rock. Details of
pressure shaft are shown in Drawing No. CHHATRU-FR-6.

6.2.6.2 ECONOMIC DIAMETER
Economical dia of the pressure shaft has been worked out by cost
optimization studies for various diameters. Accordingly, a diameter of
4.70m has been adopted to carry the design discharge of 75 cumecs with
velocity of flow as 4.32m/sec. The diameters of branches has been kept as
2.70m.
6.2.7 POWER HOUSE
6.2.7.1 GENERAL
The proposed underground power house is located about 3.50km. d/s of
Chhatru village on right bank of Chandra river. This site has been
considered suitable for underground power house as per geo-technical
appraisal note received from GSI (Ref. Chapter-IV). The tail race tunnel
from power house will discharge in to river Chandra. The erection bay and
transformer hall floor levels, are proposed at El. 3250m. The approach to
power house and transformer hall cavern is through 7m D-shaped main
excess tunnel. The machine hall and transformer hall are proposed in
underground parallel cavities at suitable spacing. The control room is
proposed in power house cavity while the SF6 switchgear is proposed in
transformer hall cavity. A cable cum ventilation gallery/tunnel is proposed,
which will initially be used for carrying out excavation and providing
support system in the crown portion of power house and transformers hall
cavities. Vertical and lateral cover each of ±200m approx. respectively has
been provided in machine cavity and transformer hall cavity. The safety of
power house complex from flooding, from tail water end during
construction stage will be adequately ensured.

6.2.7.2 TYPE
Reconnaissance surveys for location of underground or surface power house
were undertaken during the site visit of project area by HPSEB engineers
and GSI authority during Jan. 2004. Surface power house has been ruled
out due to the reason that the power house area remains under snow cover
for maximum period in the year.
Keeping in view the above fact, an underground power house with
underground transformer hall has been proposed on right bank of Chandra
river. Also the GIS unnderground 220 KV Switchyard has been proposed
keeping in view the terrain and reliability of the system.
6.2.7.3 MACHINE HALL
The internal dimensions of power house cavity has been proposed as length
67m and width 15m. The unit bay will be 36m long at 11.50m spacing
while the erection bay and control bay have been proposed 15m and 15m
long respectively . For support system in crown portion of cavity 6m long
mechanically anchored , tensioned and grouted rock bolts 1.50m spacing,
staggered has been proposed. 100mm thick shotcreting reinforced with
welded mesh has been proposed in crown portion and sides of cavity. The
spacing of rock bolts in sides has been kept at 2m c/c staggered. The
columns in unit bay and erection bay have been kept 1.60m x 0.80m. For
columns a nich in the side measuring 0.80mx0.80m has been proposed
which will be supported by grouted anchors 25mm dia at 1m spacing. All
rock bolts will be tensioned to 12 tonnes immediately after installation and
pull out tests will be carried out on 2% rock bolts.
The control bay is proposed on opposite side of erection bay in the end of
power house. Cavern for housing control room and various
auxiliaries/offices, 5 nos. floor have been proposed at El. 3248m, El.

3250m, El. 3254m, El. 3257.50m and El. 3260.50m respectively. The main
inlet valve is proposed to be housed in power house cavity just u/s of
turbine. EOT crane of 125/25 tonnes capacity has been proposed in erection
bay and unit bay to facilitate erection and repair of heavy equipment
including main inlet valves.
6.2.7.4 TRANSFORMER HALL
The size of transformer hall cavity has been proposed as 60m long, 15m
wide. The clear spacing between these two cavities has been kept at 30m.
In addition to main generator transformers, space for spare transformers and
station transformer has also been provided in the cavern. The transformer
hall cavern will be connected to erection bay by 5mx7m D-shaped gallery
for carriage of transformers at erection stage and for repairs. NG rail track
is proposed between transformer hall and erection bay for transportation of
transformers. The transformer hall will be connected by 3 nos. bus duct
galleries 3m D-shaped.
The detail of power house has been shown in Drg. No. Chhatru-PF-7.
6.2.8 AUXILLIARY SURGE SHAFT AND TAIL RACE TUNNEL
The outflow from the end of draft tube will be taken through 3 nos. separate
branch tail race tunnels. Vertical lift gates have been proposed in these
branch tail race tunnels to prevent entry of silt etc. into draft tube and for
facilitating repair in turbines. Downstream of this, all the branch tail race
tunnels will be joined to one main tail race tunnel 6m D shaped .
Auxiliary surge shaft has been proposed at the beginning of main tail race
tunnel, which is ±1150m long. Broad crested weir has been proposed at its
outfall.

6.3 PRELIMINARY DRAWINGS
Drg. No.Chhatru-FR-1 Vicinity map 1 Sheet
Drg. No.Chhatru-FR-2 Master Plan of Chenab basin(CEA schemes) 1 Shhet
Drg. No.Chhatru-FR-3 Catchment Area Plan 1 Sheet
Drg. No.Chhatru-FR-4 General Layout Plan 1 Sheet
Drg. No.Chhatru-FR-5 Diversion Barrage, Intake, Desanding basin 2 Sheets
Drg. No.Chhatru-FR-6 Head race tunnel, Surge shaft & Pressure shaft 1 Sheet
Drg. No.Chhatru-FR-7 Power House & Transformer Hall 3 Sheets
Drg. No.Chhatru-FR-8 Construction Facilities 1 Sheet
Drg. No.Chhatru-FR-9 Construction Programme 1 Sheet
Plate-6.1 Area Capacity Curve 1 Sheet

6.4 DESIGN COMPUTATIONS
A. Diversion Barrage ( REF. DRG. NO. CHHATRU-FR-5)
i) Design Parameters
Design flood discharge = 1500 cum/sec.
Average bed level of the river = ± 3405m
Safe exit gradient of Nallah material (assumed) = 1 in 4
The water bays of the barrage has been so proposed that design flood
discharge i.e. 1500 cum/sec passes through all the bays of barrage.
However, stilling basin has been designed corresponding to max. observed
discharge in Chenab river i.e. 928 cumecs Say 1000 cumecs.
Hence design flood discharge for stilling basin = 1000 cumecs
ii) Fixation of crest level and water bay
Average bed level of river = ± 3405m
The crest level of barrage bays has been kept 2m higher than the average
bed level at El. ±3407m . Six No. bays each 5.00m wide with 3m thick pier
has been provided. The total water bay of overflow portion works out to be
48.00m[(6x5)+(3.00x6)] . Two meter wide fish ladder Originating from
reservoir, left bank at M.D.D.L. El. ± 3413.50m joining river bed d/s has
been provided.
iii) Storage capacity
The live storage available in barrage reservoir between M.D.D.L. El.
3413.50m and F.R.L. El. 3421m is 87.50 Hect. m. (Ref. area capacity
curve). This storage capacity will run the power station at full installed
capacity for 3 hrs. a day.
CHECKING OF LEVELS AND CALCULATIONS FOR SIZE OF
GATES
Design discharge for power generation = 75 cumecs
Total discharge i/c flushing discharge @ 20% = 75/(1-0.20)
=75/80 = 93.75 cumecs
Fixing crest level of intake = ± 3410m

a) F.R.L. Condition
M.D.D.L. = ± 3413.50m
F.R.L. = ± 3421.00 m
Providing one no. power intake, having 8 no. bays each of size
= 5.50 m(b)x3m(h)
Intake crest behaves as a rectangular large orifice
H1
H2
Discharge Passed
= 11.00m
= 750m
Q1 = 2/3xCdxLx√ 2g (H1 3/2 -H2 3/2 )
= 2/3x0.61x44√2x9.81 (11.00 3/2 –7.50 3/2 )
= 316.47 cumecs >93.75 cumecs
Hence O.K.

) M.D.D.L CONDITION
H1 = 3.50m
H2 = 0.50m
Q = 2/3xCdxLx√2g (H1 3/2 -H2 3/2 )
= 2/3x0.61x44x√2x9.81 (3.50 3/2 -0.50 3/2 )
= 2/3x0.61x44x4.43x619 =491.00 cumecs > 93.75 cumecs
Hence O.K.
CHECK FOR VELOCITY THROUGH TRASH RACK
Aligning trash rack at 75°
Design discharge through intake/trash rack = 93.75 cumecs
F.R.L. Condition
Length of trash rack = xm
19.50/x = Sin75°
x = 19.50/Sin75° = 12.42m
Area = 12.42x44 = 546.62 Sqm.
Less 25% area for trash rack bars = 546.62-546.62x0.25= 409.96 Sqm.
Considering 50% clogging of trash rack bars
Net area available during floods = 409.96/2 = 204.98 Sqm.

Velocity through trash rack = 93.75/204.98 0.46m/sec.
M.D.D.L. condition
Length of trash rack = 3.50/x = Sin75°
x = 3.50/Sin75
x = 3.62 m
Area available = 3.62x44 = 159.28 Sqm.
Less 25% area of rack bars
Net area = 159.28-159.28x0.25 =119.46 Sqm.
Considering 50% area of trash rack bars
Net area = 119.46-119.46x0.50 = 59.73 Sqm.
Velocity through trash rack = 93.75/59.73 = 1.50m/sec.
Hence size of intake provided and levels fixed are O.K.
Gated barrage is to be provided
Parameters will be as under;
R.B.L. = 3405m
Crest level = 3407m
of barrage bays (fixed)
M.D.D.L. = 3413.50m
F.R.L. = 3421m
M.R.L. = 3422m
Top of barrage = 3424m
Height of structure = 3424-3405 =19m
Design flood = 1500 cum/sec.
Size of gate = 8mx8.50m
No. of gate = 3 No.
Storage available between El. MDDL 3413.50m and F.R.L. 3421m

Live storage = 112.50-25.00 = 87.50m
Less 20% for sedimentation
Net = 87.50-17.50 = 70 hect .m.
Time in hr = 70x10 4 /(75-10.41)x3600 = 3.01 hours
For Base Load Station
90% available discharge = 10.41 cumecs
Design discharge = 51 cumecs
Power = 9.81x51x150x0.92/1000 = 69 MW
Hydraulic design of free flowing/ungated structure
Design discharge for power generation = 75 cumecs
Modified discharge including 20% flushing
Discharge in desanding basin = 75/(1-0.20)= 93.75 cum
If it is the head over intake crest to pass 93.75 cumecs discharge
Q = CLH 3/2
93.75 = 1.70x44xH 3/2
H 3/2 = 93.75/1.70x44
H = 1.16m
R.B.L. = 3405m
Crest level of over flow bay = 3407m
Crest level of intake crest = 3410m
Head over crest to pass 93.75 cumecs discharge = 1.16m
Say 1.20m
Water level = 3410+1.20 = 3411.20m
Hence if ungated barrage is to be provided the level of
Ungated crest will have to be kept as 3411.20m
Height of structure =3411.20-3405 = 6.20m
Live storage (Between El. 3410& 3411.20m)= 12.50-6.25 = 6.25 hacm.
Time in hours = 6.25x10 4 /(75-10.41)x3600 = 0.27 hrs.
If height of structure is kept upto El. 3415m
Height of structure = 3415-3405 = 10m
Live storage (Between El. 3410 & El. 3415) = 36.89-6.25= 30.64 hacm.

Time in hrs = 30.64x10 4 /(75-100.41)x3600 = 1.31 hrs.
Time to filling up of this storage = 8 months.
CALCULATIONS FOR SIZE OF GATES IN BARRAGE BAYS
As per I.S. recommendations, 10% gates are considered to be inoperative during
floods(with min. one gate)
R.B.L. = 3405m
Crest level = 3407m
M.D.D.L. = 3413.50m
F.R.L. = 3421.00m
M.R.L. = 3422.00m
No. of barrage bays = 6 nos.
Width of each barrage bay =5m
Providing radial gate from El. 3407m to El. 3411.00m & breast wall
Thereafter upto El. 3424m
Size of gate = 5mx6m
Discharge through breast wall spillway is estimated by the equation
Q = Cb.L.D. [2g(He+Vo 2 /2g] 0.50
Where L = Total width of water bays available
= 5x6 =30m
D = Height of opening = 6.00m
He = Head from C/L of spillway
He =[(3413.00-3407)/2]+[3421-3413.50]
= 3.00+7.50 =10.50m
Vo = Vel. of approach of flood water
= 1500/185x 10.50 = 0.77m/sec.

Vel. head = Vo 2 /2g = 0.77 2 /2x9.81 = 0.03
For calculating discharge co-efficient
Head H = 3421-307 = 14.00m
Considering that design head may be exceeded by 25%
H/Hd = 1.25
Design head Hd = H/1.25 = 14/1.25 = 11.20m
Choosing Hd = 11.50m
H/Hd = 1.4/11.50 = 1.22
Corresponding value of Cb = 0.809
When all the bays are open
Discharge passed =Q = Cb.L.D. [2g(He+Vo 2 /2g) ] 0.50
When one barrage bay is inoperative
Q = 0.809x30x6.00 [2x9.81(10.50+0.03) ] 0.50
= 2093.07 cumecs
Q = Cb.L.D. [2g(He+Vo 2 /2g) ] 0.50
= 0.809x24x6.00 [2x9.81(10.50+0.03) ] 0.50
= 1674.45 cumecs
HYDRAULIC DESIGN OF STILLING BASIN
Fixation of pre-jump velocity and depth of flow
The theoretical velocity at the start of the jump is calculated by the following relation:
VT = √ 2g (H-0.50 Hd)
Where VT = Theoretical velocity in m/sec.
H = Difference in u/s reservoir
El. and stilling basin invert in meters
H = 3422-3395 = 27m
H = Head over crest of barrage bays in meters

= 3422-3407 = 15m
g = Acceleration due to gravity in m/sec = 9.81 m/sec.
VT = √ 2x9.81 (27.00-0.50x15.00)
VT = 19.55m/sec.
Due to surface friction, the actual velocity is less than VT
Considering VA= VT = 19.55m/sec
Discharge equation
Q = A1xV1
Where
1000 = A1x19.55 VA=V1 20.53m/sec.
A1 = 1000/19.55 = 51.15 Sqm. Q = Design flood discharge of
Stilling basin =1000 cum
L.D1 = 51.15
45.00xD1 = 51.15 ∴ D1 = 51.15/45.00 =1.14m
Froude No. (F) = V1/√ gd1 = 19.55/√9.81x1.14m
= 5.85
For Froude no. 5.85>4.50, U.S.B.R. type-III stilling basin is recommended.
D2 = Depth Conjugate to D1
D2 = D1/2+√2q 2 /D1g +D1 2 /4
Here
q = 1000/45.00 =22.22 cum/sec
D2 = -1.14/2+√2x22.22 2 /1.14x9.81+1.14 2 /4
= -0.57+9.41 = 8.84m
Length of basin = 5xD2 = 5x8.84
= 44.21m Say 50m
The floor of the basin is set at such a level at to provide 5% more water depth than
Y2
Hence depth of basin = 8.89x1.05 = 9.28m

Cistern level = 3405-9.28 = 3395.72m
Hence provided cistern level = 3395m is O.K.
SIZE OF APPROACH TUNNEL
Design discharge Q = 75/0.80 = 93.75 cum/sec.
No. of main tunnels = 1 no.
Discharge through each tunnel = 93.75 cum/sec.
Vel. in the tunnel = 3.30m/sec
Dia of tunnel = √(93.75/3.30)/4/Π = 6m
After bifurcation
Q through each tunnel = 46.87
V = 3.30 cum/sec.
Dia of each tunnel √ 46.87x4/3.30xΠ = 4.25m
After Desilting
Total design discharge, Q = 75 cum/sec.
No. of tunnels = 2 nos.
Discharge through each tunnel = 75/2 =37.50 cum/sec
Dia = 4.00m
² =
V = 37.50/Π/4(4.00)
2.98m/sec.
DESIGN OF APPROACH TUNNEL & INTAKE STRUCTURE
A. APPROACH TUNNELS ( Ref. Drawing No. Chhatru-FR-5 sheet 2 of 2)
Design discharge to be drawn i/c flushing discharge = 93.75 cum/sec.
No. of tunnels = 1 nos.
Discharge through each tunnel = 93.75 cum/sec.

Provide size of tunnel = 6m, circular concrete lined
Area of each tunnel = Π/4(d²) = Π/4(6)² = 28.27 Sqm.
Vel. through each tunnel = 93.75/28.27 = 3.31 m/sec.
Length of tunnel = 200m
B. INTAKE STRUCTURE
Considering bell mouth intake with bottom flat
Width of opening = 1.42857 D D = Size of conduit i.e. tunnel
= 28.57x6.00 = 8.57m
Height of opening
h = h1+h2
h1 [(1.21 tan 2 φ +0.0847) 1/2 +1/2 cosφ -1.1 tanφ )]D
Where φ is the angle of inclination with Horizontal = 0°
h1 = [(1.21 tan 2 0+0.0847) 1/2 +(1/2cos 0-1.1 tan0 )] xD
= [(0+0.0847)1/2 + ½]x6
= (0.291+0.50) 6 = 4.75m
h2 = [0.791/ +0.077 tan0]xD
= (0.791+0) x 6 = 4.75m
h = h1+h2 =4.75+4.75 = 9.50m
Provide clear opening for intake = 8.60x9.50m
The opening is rectangular and depress it to circular from starting of intake face to
a distance of 1.1 D = 1.1x6 = 6.60m
Here
a = 6.60m
b = 3.50m

Hence size of bell mouth entrance 8.60m(b)x9.50m(d) from 6m circular section
Min. water cushion provided above the opening of intake
= 0.3 he = 0.3x9.50 = 2.85m
El. at top of intake = 3413.50-2.85 = 3410.65m
C/L of intake = 3410.65-4.75/2 = 3405.90m
C/L of approach tunnel = 3405.90m
Hence invert level of approach tunnel at RD 0 =3405.90-6/2
=3402.90m
And C/L of approach tunnel at inlet = 3405.90m
Invert level as invert = 3402.90m
At inlet of desanding basin
Invert level = 3402.50m
Overt level = 3402.50+4.25m
= 3406.75m
HYDRAULIC DESIGN OF DESANDING BASIN (Underground )
(Ref. Drawing No. Chhatru-FR-5 sheet 2 of 2)
Design criteria = All particles down to 0.20mm shall be removed
Parameters
Design discharge for power generation = 75 cumecs
Design discharge i/c 20% for deflushing in desanding basin=75/0.80 = 93.75 cumecs
HYDRAULIC DESIGN
Particle size to be removed = 0.020mm and above
Permissible flow through vel. as per camp’s formula
V = 44√d for 1mm>d>0.10mm
V = 44√0.020 = 19.67 cm/sec

Provide v = 19.50 cm/sec
Effective area of flow = 93.75/0.1950 = 480.76 Sqm.
Provide 2 No. chambers in the desanding basin
Width of each basin = 13.00m
Total width = 13x2 = 26m
Effective area of flow of each chamber = 480.76/2
= 240.38 Sqm.
CHECK FOR CROSS SECTIONAL AREA
Arch Portion
r = (C²+4h²)/8h = (13²+4x3.50²)/8x3.50 = 7.78m
Sin α/2 = C/2/2 = 6.50/7.78 = 0.835
α/2 = 56.66° α = 113.33°
Length of arch =Π/180xαxr
L =Π/180x113.33x7.78
= 15.38m
A Area of Arch Portion
A1
A1
= ½[r.L-C(r-h)]
= ½[(7.78x15.38)-13(7.78-3.50)]
= ½(119.65-55.64)
= 32 Sqm.

A2 = Area of rectangular Portion
= 13x16.10 = 209.30Sqm.
Total area = A1 + A2 =32+209.30 =241.30 Sqm.>240.38 Sqm.
Hence O.K.
0.20mx0.20m openings are proposed to be provided at the bottom of each
pit 10m
c/c to carry the silt to gallery 1.50x1.80m rectangular shaped, from where silted
water will be flushed back to Beas river.
Settling vel. = 2.35cm/sec corresponding to 0.20mm particle
size
Vel. correction W 1 = 0.132xv/√h = 0.132x0.195/√19.60
W 1 = 0.00581
Corrected settling vel. = W-W 1 = 0.02350-0.00581 = 0.017685
Length of desanding basin
L = hxV/W-W 1 = 19.60x0.195/0.017685
L = 216.11m Provide L = 381m
Hence size of each chamber = 381m(L)x13m(b)x19.60m(h)
No. of chambers = 2 nos.
CHECK FOR THE SIZE
Settling time t is given by
t = h/W-W 1 = 19.60/0.017685 = 1108.28 sec.
Water conveyed during this period
Qxt = Discharge per chamber x settling time
= (93.75/2) x 1108.28 = 51950.80 cum
Capacity of one chamber = 241.30x381= 91935 cum>51950.80
cum
Hence O.K.
Removal efficiency of particle size of 0.20mm
ηt = 1-(e) –WxL/vxh
= 1-e –2.35x381/19.50x19.60 = 1-0.0960
= 90.40%
Design of transitions

Inlet transition length
= B-b/2tan 12.5º = 13-4.25/2tan 12.5º
= 19.73m Say 20.00m
Outlet transition length
= 13-4.25/2tan 12.5º = 19.73m Say 20.00m
HEAD RACE TUNNEL(REF. DRAWING NO. CHHATRU-FR-6)
Parameters
Design discharge = 75 cumecs
Shape of the tunnel (adopted) = Modified horse shoe shaped
Length of head race tunnel = 6500m
M.D.D.L. = 3413.50m
Min. down surge level
(as per computer analysis) = 3396.96m
Co-efficient of friction = 0.014
HYDRAULIC DESIGN
Calculation for economic diameter
The most economical dia of tunnel would be such as to result in a minimum total
value of the sum of the following.
a) Recurring annual expenditure
According to Manning formula’s
V = 1/nx R 2/3 S 1/2
Where
V = Average vel.
X = Rugosity co-efficient = 0.014
R = Hydraulic mean radius = 0.506287 r
D = Diameter S = Slope

Now
V = 1/n R 2/3 S 1/2 = 1/n (D/4) 2/3 S 1/2
S = 6.40 V²n²/D 1.33 -(i)
In this equation S gives value of head loss in meter or hydraulic gradient
If η is the overall efficiency of generation
Then
Power lost Pe = 9./80xQxSxη KW -(ii)
Where
Q = VxΠ/4 (D²)
Or V = 1.275Q/D² -(iii)
From equation (i) & (iii) we got
S = 6.40n²/D 5.33 x[1.275Q/D²]² - (iv)
Substituting the value of S in (ii) we get
revenue lost per year
Pe = 9.80Q [6.40n²/D 5.33 (1.275Q/D²)²]x η KW (A)
Pe = 101.96 Q 3 / D1.33 xn²xη KW
Revenue lost per year
Re = Pex24x365x C0 (B)
From equation A&B
Re = [ 101.96 Q 3 /D5.33xn²xη]x24x365xC0
Re = 8.95x10 5 x Qª/D 5.33 xn 2 xηxC0
Re = 8.95x10 5 x Qª/D 5.33 xηxn 2 xC0
C0 = Selling rate of power per unit = Rs. 2.50
η = Overall efficiency = 0.92
Q = Equivalent discharge =Design discharge x Load factor
= 75x0.50 = 37.50 cum/sec.

∴ Re = [8.95x10 5 x(37.50) 3 x0.92x(0.014)²x2.50] /D 5.33
Re = 2.127x10 7 /D 5.33
Annual expenditure/Cost per year (Ae)
Assuming lining thickness = D/16 (Including OB)
Qty. of excavation per meter length = Π/4 (D+2xD/16)² = Π/4x81/64 D²
= 0.994 D²
Rate of Excavation
Good rock = 903x0.60 = Rs. 541.80
Moderately jointed rock = 1499x0.20 = Rs. 299.80
Poor rock = 1906x0.20 = Rs. 381.20
Total = Rs. 541.80+299.80+381.20 = Rs. 1222.80
Rate of over break per cum = 2.3x1222.80 = Rs. 815.20/ cum
Cost of excavation including over break = 1222.80+81.52 (10% of Rs.815.20)
= Rs. 1304.32
Rate of excavation per cum
= Rs. 1304.32
Say Rs. 1305.00
Rate of lining M:20 = Rs. 3177 per cum
Qty. of steel for ribs @ 18 kg.per cum = 0.018x56037 = Rs. 1008.66
Say Rs. 1009.00
Total cost of lining = 3177+1009 = Rs. 4186.00
Area of lining = Π(D+D/16)D/16 = 0.2086 D²
Cost of excavation = 0.994 D²x1305 = 1297.17 D²
Cost of lining = 0.2086D²x4186 = 873.19D²
Total cost = 1297.17 D²+873.19 D²= 2170.36D²
Total cost including over head charges @ 15% on total cost =
2495.91D²

Ae = Annual expenditure @ 15.50% of above cost =
= 2495.91D²x0.155 = 386.87 D 2
Now T Re+Ae
T = 2.13x10 7 /D 5.33 +386.87D²
For mix. value
DT/Dd = 0
T = 2.13x10 7 /D 5.33 +386.87 D² =2.13x10 7 xD -5.33 +386.87D²
For min. value
DT/Dd = -5.33 D -6.33 x2.13x10 7 +2D(386.87) = 0
-1.135x10 8 D -6.33 = -773.74D
D 7.33 = 1.135x10 8 /773.74 = 146690.10
D = 5.07m Say 5.10m
Hence dia of H.R.T. (fixed) = 5.10m
Vel. in the H.R.T. = 75/20.63 = 3.63m/sec.
D = 5.10m
R = 5.00/2 = 2.55m
r = 0.987580 R =0.987580x2.55 = 2.52m

R = RARIUS OF HYDRAULICALLY EQUIVALENT CIRCLE
AREA OF SECTION = 3.253 572 r 2 = 20.63 Sqm.
PERIMETRE OF SECTION = 6.426 334r = 16.19m
HYDRAULIC RADIUS = 0.506 287 r = 1.27m
A = 0.780 776 r = 1.97m
B = 1.561 553 r = 3.93m
θ = 31º-22’-01”
SURGE SHAFT (REF. DRAWING NO. CHHATRU-FR-6)
Hydraulic Design
Design discharge = 75 cumecs
Size & shape of head
race tunnel = 5.10m, Modified horse shoe shaped
Length of head race tunnel = 6500m
Value of rugosity co-efficient (assumed) = 0.012 to 0.016
Computations
As per IS: code 7396 Part-I
Thoma area of surge tank is given by the formula
Ath
L.At/B V1 2 H0 V1 2 /2g
Sectional area of H.R.T. 5.10m modified horse shoe shaped
At = 20.63 Sqm
Vel. in H.R.T. = 3.63 m/sec.
BV1 2
= Friction losses in the tunnel & other losses
= 6.4x3.63 2 x0.014 2 x6500/(5.10) 1.33 = 12.30m

For computation of Thoma area using min. value of rugosity co-fficient
Head losses with n=0.014, = 12.30m
Head losses with n=0.012, = 9.04m Say 9m
Other losses in trash rack approach tunnel & desilting tank = 0.30m
BV1 2
= 12.30+0.30 = 12.60m For n=0.014
And 9.00+0.30=9.30m
With n=0.012
Now, Ho = Net head on turbines
Ho = Net head - losses in the system
Total losses = Losses upto surge shaft + penstock losses
Penstock losses, hf = 0.0085x350x4.32²/2x9.81x4.80 D= 4.80m
= 0.589m Say 0.60m
L= 465m
Q= 75 cumecs
V= 4.32m/sec.
F = 0.0085
Total losses = 12.60+0.60 = 13.20m Say 11m with n=.014
And = 9.30+0.60 = 9.90m with n=0.012
Say 10m
H0= (3418.50-3247.00)-10 = 161.50m
Ath = 6500x20.63x3.63²/161.50x10x2x9.81 = 55.76m 2
Factor for safety = 1.60
Ath = Area required 55.76x1.60 = 89.22m 2
Provide 15m φ surge shaft
Area of surge shaft = Π/4(15)² = 176.71 Sqm.

CALCULATIONS FOR AREA OF ORIFICE
Orifice area is so provided as to satisfy Calame and Gaden condition for max. flow
as given below
2*/√2 + ¼ hf ≤ hor ≤ Z*/√2+¾ hf
Here
Z* = Vo √L/gxAt/As =3.63 √ 6500/9.81*20.63/176.71
For N = 0.016
Hf in tunnel system = 16.06m
= 31.92m
= 31.92/√2+16.06/4 ≤ hor ≤ 31.92/√2+3/4x16.06
For n=0.012
Then
= 22.57+4.01≤ hor ≤ 22.57+12.04
= 26.58 ≤ hor ≤ 34.61
31.92/ √2+9.00/4 ≤ hor 31.92/√2+3/4x9.00
22.57+2.25 ≤ hor 22.57+6.75
24.82 ≤ hor 29.32
Adopt Head loss across orifice = 30m
Now
hor = Q0 2 /Cd 2 xA0 2 x2g
A0 = Q/Cd √2g hor = 75/0.62x√19.62x30
A0 = 4.98 Sqm.
D = √4.98x4/Π
D = 2.52m
Provide orifice dia = 2.50m

Max. up surge = 13.10m
As per surge analysis on
computer
Min. Down surge = 11.90m
Max. upsurge level FRL= 3421+14.96 =3435.96m Say 3436.00m
Min. downsurge level MDDL = 3413.50-16.86 =3396.64m
Say 3396.60m
CALCULATIONS FOR SLOPE OF TUNNEL
Invert level of tunnel at RD 0 of tunnel = 3402.50m
C/L of the tunnel at RD 0 = 3402.50+5.10/2
= 3402.50+2.55
= 3405.05m
C/L of tunnel at outlet = MDDL-Losses in HRT- 1.5x orifices losses-
depth of orifice-radius of HRT
= 3413.50-12.30-1.5(30)-2.50-2.55
= 3413.50-12.30-45-2.50-2.55 = 3351.01m
Say 3351.00m
Difference in levels = (3402.50-2.55)-3351 = 54.05m
(RD 0 & RD 6500)
Length of tunnel = 6500m
Slope of tunnel = 6500/54.05 = 1:120.25
Say1:120
Now
V1 = Q/A = 75/20.63 = 3.63m/sec.
V2 = 1/4 R 2/3 S ½ = 1/0.014x1.27 2/3 (1/120) ½
V2>V1 Hence O.K.
= 7.46m/sec.
PRESSURE SHAFT (Ref. Drawing No. Gharopa-FR-6.)

Parameters
Design discharge = 75 cumecs
Design net head H = 160m
Length of penstock = ± 350m
Efficiency of turbine = 94%
Rated HP of turbine
P =1000x75x160x0.94/75 = 150400 H.P.
No. of pressure shaft = 1 No.
Hydraulic Design
Economical dia of Pressure shaft
a) By DOLOND’s FORMULA
Diameter = D = 0.176 (P/H) 0.466
= 0.176 (150400/160) 0.466 = 4.27m
b) As per R.S. Nigam’s Hand Book
D ≤ [ 1xfxc 1 xk2xQ 3 xt/ 1100xK1xH] 1/7
Where
H = 160+20% Water hammer effect
= 192m
c 1 = 2444 kg/cm 2 -Allowable stress insteel
(0.2x1347+0.8x2728)
f = 0.0085 = Friction factor
K1
= 75x0.1250 = 9.37 Rs./kg. = Annual cost of pressure shaft per kg.
K2 = 2.00 = Value of KWH at generator terminal in same
unit
t = 365x24x0.50 = 4380 hrs. = Annual duration of operation in hrs.

D = [1x0.02x2444x2.00x(75) 3 x4380/ 1100x9.37x192]1/7= 5.11m
Taking average dia of (a) & (b)
Average diameter = 4.27+5.11/2 = 4.69m
Velocity in pressure shaft
Say 4.70m
V = 75/ Π/4(4.70)²
= 4.32m/sec.
Dia of Branch penstock (3 units)
Discharge = 75/3 = 25 cumecs
V = 4.32m/sec.
D = √25x4/4.32 x 4/Π = 2.71m
Say 2.70m
CALCULATIONS FOR GROSS HEAD & NET HEAD
F.R.L. in reservoir = 3421.00m
MD.D.L = 3413.50m
Normal water level = 3413.50+7.50x2/3
= 3413.50+5 = 3418.50m
Min. tail water level = 3239.50m
Normal tail water level = 3240.00m
Max. tail water level = 3247m
Max. gross head = Normal reservoir level-Min. tail water
level
= 3418.50-3239.50 = 179m
Min. Gross head = Max. reservoir level -Max. tail water
level
= 3421-3247 = 174m
Design gross head = 174+2/3 (179-174)

= 177.33m
Total losses from intake
to power house = 17.33m
Design Net Head = 180.83-17.33 = 160m
TAIL RACE TUNNEL (Ref. Drawing No. Gharopa-FR-7( Sheet 2 of 3).
Data
Design discharge = 75 cumecs
Size shape = 6m, D-shaped
Length of tunnel = 1150m
Assumed value of Rugosity co-efficient= 0.014
Hydraulic design
i) Under normal conditions the TRT will behave as a free flow tunnel
V = 1/0.014x( 12.60/10.20) 2/3 (1/182.50) .5 = 6.08m/sec.
Discharge passed = 12.60/6.08 = 76.69cum/sec.
ii) Under HFL conditions the TRT will behave as a pressurized conduit
Gross cross sectional area of tunnel = [(6x3)+(Π/4x6²/2)] = 32.13
Sqm.
Velocity in tail race tunnel = 75/32.13
= 2.33m/sec.
Fixation of crest level of T.R.T.
i) Crest level at outfall will behave as a broad crested weir
Now
Q = CLH 3/2
75 = 1.71x6xH 3/2
H = [ 75/1.71x6] 3/2 = 3.76 m
Crest level at outfall = 3240.00-3.76 = 3236.24m

PARA DESCRIPTION PAGE
7.0 GENERAL VII-1
7.1 PATTERN OF FLOWS IN 90% DEPENDABLE AND 50%
MEAN YEAR
VII-1
7.2 HEAD FOR POWER GENRATION VII-2
7.2.1 DESIGN HEAD VII-2
7.2.2. MAXIMUM HEAD VII-2
7. 2.3 MINIMUM HEAD VII-3
7.3 POWER GENERATION IN A 90% DEPENDABLE YEAR
AND 50% MEAN YEAR
VII-3
7.4 INSTALLED CAPACITY STUDIES VII-4
TABLE-7.1 YEARWISE COMPUTATIONS FOR UN-RESTRICTED
ENERGY IN GWH.
TABLE-7.2 COMPUTATION FOR DEPENDABLE YEAR ON THE
BASIS OF ENERGY
VII-5 TO
VII-9
VII-10
TABLE –7.3 90% DEPENDABLE AND 50% MEAN YEAR DISCHARGE VII-11
TABLE- 7.4
& TABLE 7.5
TABLE –7.6
& TABLE 7.7
POWER & ENERGY GENRATION IN 90% DEPENDABLE
YEAR
VII-12 TO
VII-22
POWER & ENERGY GENRATION IN 50% MEAN YEAR VII-23 TO
VII-33
TABLE 7.8 SUMMARY VII-34
TABLE- 7.9 SUMMARY 90% DEPENDABLE YEAR VII-35
TABLE –7.10 SUMMARY 50% MEAN YEAR VII-36
PLATE-7.1 INSTALLED CAPACITY CURVE VII-37
PLATE-7.2 TOTAL ENRGY VS I.C. CURVE VII-38
ANNE.-VII-1 COMMENTS ON POWER POTENTIAL RAISED BY CEA
DT.12.04.04
ANNE.-VII-2 REPLY TO THE COMMENTS RAISED BY CEA
DT.12.04.04
ANNX-V11-3 COMMENTS ON POWER POTENTIAL RAISED BY CEA
DT.13.05.04
ANNX-V11-4 REPLY TO THE COMMENTS RAISED BY CEA
DT.13.05.04
VII-39 -40
VII-41
VII-42-43
VII-44-45

7.0 GENERAL
CHAPTER – VII
POWER POTENTIAL STUDIES
Chhatru Hydro-electric Project is essentially a run- of- the river
development for generation of hydro-power on Chandra river in Himachal
Pradesh. It has been contemplated as a peaking station to operate in western
part of Northern Regional Grid. Installed capacity of the project has been
presently kept as 108 MW comprising 3 units of 36 MW each with overall
efficiency of generation as 0.92.
7.1 PATTERN OF FLOWS IN 90% DEPENDABLE AND 50% MEAN
YEAR
The 27 years discharge data from June 1973 to May, 2000 of Chandra river
at Ghousal has been used to develop a series at diversion site of Chhatru
HEP on catchment area basis for power generation. Energy generation has
been worked out for all the years as appended in Table 7.1. .Pattern of flows
in 90% dependable and 50% mean years has been worked out on the basis
of energy generation in 27 years by using Welbull’s relationship P= n/m+1,
where P is percentage exceedence of occurrence, n is the event no. in
descending order and m is total no. of events, presented in Table 7.2. Flows
in 90% dependable and 50% mean years, so worked out are given in Table
7.3.
7.2 HEAD FOR POWER GENERATION

7.2.1 DESIGN HEAD
Gross head for power generation has been worked as 178.50 m between
weighted reservoir El. 3418.50 m and normal tail water level El. 3240 m.
Losses in water conductor system corresponding to design discharge of 75
cumecs from intake to generating units has been worked out as 18.33 m.
Design net head therefore has been taken as 160 m. The calculations are as
follows:
Full Reservoir Level (FRL) = ± 3421.00 m
Min. Draw Down Level (MDDL) = ± 3413.50 m
Normal Tail Water Level (NTWL) = ± 3240.00 m
Weighted Reservoir Level = MDDL+2/3(FRL- MDDL)
= 3413.50+2/3 (3421.00 – 33413.50)
= 3218.50 m
Gross Head = Weighted Reservoir Level – NTWL
= 3418.50 – 3240 = 178.50 m
Losses = 18.33 m
Net Head = Gross Head – Losses
= 178.50 – 18.33 = 160.17m say 160.00m
7.2.2 MAXIMUM HEAD
Maximum gross head has been calculated as the difference of Maximum
water level ( ± 3422 m ) & Minimum Tail water level ( ± 3239.50 m) &
works out to be 182.50 m.
7.2.3 MINIMUM HEAD

Minimum gross head has been taken as difference between MDDL( ±
3413.50 m) & Maximum tail water level ( 3247 m) & works out to be
166.50 m.
7.3 POWER GENERATION IN A 90% DEPENDABLE YEAR AND
50% MEAN YEAR
Power generation studies in a 90% dependable year corresponding to
installed capacity varying from 78 MW to 159 MW are given in Table 7.4
The energy generation in 90% dependable year corresponding to the
installed capacity of 108 MW is 468.83351.91 GWH. The energy generation
in 90% dependable year corresponding to 95% machine availability works
out to be 455.72 GWH as shown in Table 7.5.
Power generation studies in a 50% mean year corresponding to installed
capacity varying from 75 MW to 159 MW are given in Table 7.6 The
energy generation in 50% mean year corresponding to the installed capacity
of 108 MW is 488.85 GWH. The energy generation in 90% dependable year
corresponding to 95% machine availability works out to be 475.80 GWH as
shown in Table 7.7.

7.4 INSTALLED CAPACITY STUDIES
Power generation studies for 90% dependable and 50% mean pattern of
flows with installed capacity varying from 78 MW to 159 MW have been
done.From the study the incremental increase Vs installed capacity curve &
total energy Vs installed capacity curve have been drawn as shown in Plate
7.1 and Plate 7.2 respectively. The fall in incremental energy occurs beyond
130 MW. Moreover the plant load factor for lean season ( Dec. to Feb. ) is
just below 16% from 126 to 159 MW. While deciding the installed capacity
of the project it was seen that during 90% dependable year (1992-93),
minimum discharge of 10.41 cumecs ( obtained from overall flow duration
curve) and design flow is available in only four 10 daily blocks which is
only 25% of the period in 90% dependable year.
Since the project is planned as a peaking station for 3 hours to meet with
peaking power shortage in the country , the installed capacity of the project
has been fixed at 108MW with over all PLF of 50%. It was further studied
that the minimum discharge during lean season ( Dec. to Feb.) in 90%
dependable year is 11.18 cumecs and therefore peaking of 3 hrs. minutes
can be done.
The live pondage capacity of 70 Hac-m in terms of MW hours worksout to
280.79MW hours. The rest of the MW hours shall be met with from
minimum flow available during peaking hours.
It is therefore concluded that the installed capacity of 108 MW shall be
economically optimum. An overview of hydrological & Power studies has
been given in summary table 7.8,7.9 and 7.10 respectively.

Annexure-VII-2
Reply to the comments raised by Dy. Director HPI, CEA, New Delhi on power
potential chapter vide letter No. 7/9/HPSEB/HP&I/2004-778 dated
12.4.2004(Annexure-I).
1. The computations to fix FRL, MDL and tail water have been given in the design
computations incorporated in Chapter VI, Para No. 6.4(A).
2. The live pondage capacity in terms of MW hours and nos. of peaking hours have
been given in Chapter-VII- Para No. 7.4.
3. The area capacity curve have been annexed as Plate-6.1 in Chapter-VI.
4. The drop between TWL (El. 3240m) of Chhatru & FRL(3212.40m) of Khoksar
could not be utilized due to the reason that during the site inspection of these
projects, no suitable site for location of power house of Chhatru below El. 3240m
and diversion site for Khoksar up stream of El. 3212.40m was found as per
topography of the area and geological conditions.
5. Summary study of power potential aspects has been incorporated in the Chapter-VII
Table 7.8, 7.9 & 7.10.
6. Recommendation for DPR stage:-
The project has been planned as per contour interval of 20m on the S.O.I. sheet
available in Scale of 1:25000. After carrying out the detailed survey of the project
area at higher scale the exact topography of the area shall be depicted and there is
possibility of increase/decrease in the head considered at present. As such the
installed capacity may fluctuate at DPR stage.

Annexure-VII-4
Reply to the comments of CEA on draft PFR of Chhatru HEP (108 MW) in
HP, sent by Director (HP&I) vide letter No. 7/9/HPSEB/HP&I/2004/1008
dated 13.05.04.
General Comments
1. Initial Environmental studies alongwith Satellite Remote Sensing
Based Inputs from NRSA, Hyderabad has been incorporated in
Chapter IX, as per scope of work.
2. CEA guidelines for financial parameters have been adopted while
preparing the Economic Evaluation of the project in Chapter XIII.
3. The cost of the project has been worked out as per CEA guide lines
and tariff calculations for present day cost with IDC @ 10% p.a.
4. The necessary recommendation for further studies have been given
in Chapter-V-3 “Hydrology” P-V-52 & Chapter-VII “Power
Potential Studies” P-VII-41.
5. Hydrology adopted in PFR has been approved by CWC, by Director
Hydrology, vide letter No. I/HP/26/2004 dated 19.4.04 endorsed by
Director (HP&I) letter No. HPSEB/HPI/877 dated 21.4.04 (P-V-46
& 51).
6. The advice of CWC on the layout planning of the project shall be
taken care of at the stage of preparing the Detailed Project Report of
the project.
7. The view of SP&PA Division of CEA on power evacuation shall be
obtained at the final DPR stage, however, the power evacuation
system has been proposed as per proposed evacuation plan Chenab
Valley (Ref. Plate VIII-1 attached).
8. Executive Summary has been incorporated as per CEA guide lines
dated 2 nd Dec. 2003.
9. The geo-technical studies have been got carriedout by GSI and
incorporated in Chapter-IV.

Power Potential Studies
Comments of power potential studies earlier received vide CEA letter No.
7/9/HPSEB/HP&I/2004-778 dated 12.4.2004 have been incorporated on
P-VII-30-40 as Annexure-VII-1 and reply to the same including
recommendations for further studies has been appended in Annexiure-VII-2
P-VII-41.

PARA DESCRIPTION PAGE
8 POWER EVACUATION VIII-1
8.1 APPRAISAL OF EXISTING POWER EVACUATION
FACILITIES
VIII-1
8.2 GENERATION EQUIPMENT FOR POWER HOUSE VIII-2
8.2.1 MECHANICAL EQUIPMENT VIII-2
8.2.1.1 TURBINES VIII-2
8.2.1.2 GOVERNOR VIII-2 TO VIII-3
8.2.1.3 MAIN INLET VALVES VIII-3
8.2.1.4 COOLING WATER AND FIRE PROTECTION
SYSTEM
VIII-3
8.2.1.5 POTABLE WATER AND SANITARY DRAINAGE VIII-4
8.2.1.6 DRAINAGE AND DEWATERING SYSTEM VIII-4
8.2.1.7 COMPRESSED AIR SYSTEM VIII-4
8.2.1.8 OIL SYSTEM VIII-5
8.2.1.9 VENTILATION AND AIR CONDITIONING VIII-5
8.2.1.10 POWER HOUSE CRANE VIII-5
8.2.2 ELECTRICAL EQUIPMENT VIII-5
8.2.2.1 GENERATOR VIII-5 TO VIII-6
8.2.2.2 EXCITATION SYSTEM VIII-6
8.2.2.3 GENERATOR SWITCH GEAR AND CONNECTING
CABLES
VIII-6 TO VIII-7
8.2.2.4 GENERATOR TRANSFORMERS VIII-7
8.2.2.5 CONTROL AND MONITORING EQUIPMENT VIII-7 TO VIII-8
8.2.2.6 STATION SERVICE /AUXILLARY SUPPLY VIII-8
8.2.2.7 POWER PLANT GROUNDING VIII-8
8.2.2.8 LIGHTING VIII-8
8.2.2.9 SWITCHYARD AND SWITCHING SCHEME VIII-9
8.3 PROPOSED EVACUATION ARRANGEMENT TO
NEAREST FACILITIES
PLATE VIII- PROPOSED EVACUATION PLAN FOR CHENAB
I
VALLEY
VIII-9
VIII-10

8. POWER EVACUATION
CHAPTER – VIII
POWER EVACUATION
8.1 APPRAISAL OF EXISTING POWER EVACUATION FACILITIES
At present there is only 33 KV network in the valley which is connected to
132/33 KV Sub-Station, Bajaura (Sarabai) through 33 KV Sub-Station at
Manali. Independent evacuation system for the up-coming power houses in
the valley will have to be evolved. Number of power houses, namely Sach-
Khas (70 MW), Gondala (90 MW), Khoksar (90MW), Chhatru (108 MW)
and Bardang (114 MW) are envisaged to come up in the valley. Individual
evacuation system from these power houses will not be possible due to
inhospitable terrain and corridor problems. The power from these power
houses will have to be pooled in at some centrally located suitable place and
then evacuated through D/C 400 KV system to 400 KV pooling in substation
being planned/set up by POWERGRID for Parbati-III HEP near
Panarsa in Kullu valley. It is proposed to pool in the power of hydro electric
projects coming up in Chenab valley at Tandi near Keylong which has fairly
flat area for construction of sub-station and then evacuate the pooled in
power through 125 Kms, 400 KV D/C line to pooling in sub-station being
set up by POWERGRID at Panarsa via Rohtang Pass. The cost of pooling
in sub-station at Tandi, expansion at Panarsa and 400 KV line between
Tandi and Panarsa which is approximated as 240 Crores has not been
included in the project cost. This system will be executed by Central/State
Agency. The executing agency of this system will charge the wheeling
charges from the promoters of these HEPs.

8.2 GENERATION EQUIPMENT FOR POWER HOUSE
8.2.1 MECHANICAL EQUIPMENT
8.2.1.1 TURBINES
The vertical shaft, Francis turbine of 36.90 MW capacity with a rated
synchronous speed of 428.6 rpm has been found to be suitable in view of
the over all economy of the power house. As per the study there is only
minor difference in the width of power house, hence lower speed has been
adopted which has resulted in a suction head of 6.96mtrs. below the
minimum tail water level. Lower speed has however increased the overall
cost of the equipment marginally, but will be compensated with the
reduction in the wear & tear of under water parts of turbine due to silt which
is usually high in Himalayan rivers. Each turbine shall be provided with
suitable oil pressure unit, electro hydraulic governor and other requisite
control equipment.
8.2.1.2 GOVERNOR
Since Chhatru power house will be connected with 400 KV Pooling in
Tandi sub-station being set up by Central/State Agency for evacuation of
power from all the projects located in the valley, it is of prime importance
that the governor accuracy and sensitivity is of high order so as to ensure
proper behaviour of the regulators. For any change in the system load to
avoid hunting and over regulation, it is proposed to provide Electro
Hydraulic governor. The governing system for each unit will have an
individual oil pressure system consisting of oil to air mixer and an oil tank
with two pumps as well as the automatic control equipment. Speed etc.
would be indicated both on the governor cubicle and on the unit control

oard to facilitate supervision of operation of the unit. The controls would
include provision for emergency shut down of unit in case of :-
Loss of Pressure in the oil pressure vessel of Governor oil system.
Excessive temperature rise in Bearing.
Excessive speed rise of the unit.
Electrical faults.
8.2.1.3 Main inlet valves
A main inlet valve of the Butterfly with flow guides type would be provided
at each turbine inlet for maintenance of the turbine and for emergency
isolation of the turbine in the event of governor failure. Each valve shall be
actuated by means of servomotor which shall be fed from an independent
oil pressure unit. Closing of the valve shall be through counter weights.
Each valve unit shall constitute a complete independent unit with its own
operating system for opening and closing, which will be connected to the
automatic start and stop sequence of the respective turbine unit.
8.2.1.4 COOLING WATER AND FIRE PROTECTION SYSTEM
A pumping system would be provided to supply adequate quantity of water
from the tail race for cooling of the turbine and generator bearings,
generator air coolers and selected plant services.
Water for fire protection would be taken from an elevated reservoir
providing both reliable operation and ample capacity to fight fire in the
power house. A back up water supply to this reservoir would also be
provided.

8.2.1.5 POTABLE WATER AND SANITARY DRAINAGE
Water from the cooling water system would be used to supply the plant’s
potable and sanitary water needs. The potable water would be filtered and
chemically treated as required. Sanitary sewerage would be treated in a
septic system before discharge in to tail race of power plant.
8.2.1.6 DRAINAGE AND DEWATERING SYSTEM
A separate drainage and de-watering system with suitable number of pumps
would be provided to drain and pump out miscellaneous inflows and ground
water seepage in the power house.
Starting and stopping of the pumps would be automatic and controlled by
level switches in the drainage sump.
8.2.1.7 COMPRESSED AIR SYSTEM
A high pressure compressed air plant would be installed to meet the
requirements of the governor oil system and the oil pressure system of the
spherical valves.
A low pressure compressed air plant would also be installed to meet the
requirements of the station pneumatic tools, breaking and other general
purpose in the power house.
8.2.1.8 OIL SYSTEM
A portable dehydration unit comprising of oil heaters, Filters, tank etc.
would be provided in the power station for the treatment of governor/
Bearings and switch gear oils.

8.2.1.9 VENTILATION AND AIR CONDITIONING
Power house would be provided with ventilation system as required for the
underground power house work areas and offices. An air conditioning
system would be provided to maintain the control room at the selected
design temperature and humidity levels. The temperature and humidity level
would be selected to suit the requirements of equipment and staff.
8.2.1.10 POWER HOUSE CRANE
In order to expedite the completion of various construction activities of the
power house and keeping in view the dimension of power house, electric
over head travelling bridge crane having capacity of 125/25 tonnes would be
installed in the power house primarily for erection, maintenance and repair
of the generating units. The crane would be equipped with motor control
system providing suitable procedure for equipment erection.
8.2.2 ELECTRICAL EQUIPMENT
8.2.2.1 GENERATOR
Each generator shall be of vertical shaft, salient pole type, Synchronous
generator directly coupled to the hydro turbine and having a rated out put of
40 MVA with 0.9 lag power factor. The generator bearing arrangement
shall be of conventional type i.e. suspended type. It is proposed to equip the
generators with dynamic braking in addition to the friction brakes. The
generator shall have class-F insulation in line with modern practice and
temperature restricted to class-B insulation.
The generator will be air cooled with a closed ventilation system using air
water heat exchanger placed around the stator frame. The generators are

proposed to be equipped with the following electrical protection
equipment:-
High speed differential protection for generator.
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 relay schemes.
Generator thermal relay protection.
Phase balance relay.
8.2.2.2 EXCITATION SYSTEM
The excitation system of the generator will be of static type and will include
static type voltage regulator of latest design, field suppression equipment
and the associated accessories.
The power for the excitation system will be taken from the generator main
bus by means of a dry type or epoxy encased step down transformer. 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.
The excitation system including the voltage regulator will be placed in the
cubicles adjacent to the generator pit.
8.2.2.3 GENERATOR SWITCH GEAR AND CONNECTING CABLES

Each generator shall be connected to its step up transformer by means of 11
kV bus ducts. Current transformers required for protection, control and
metering will be located and form part of the bus ducts assemblies.
The generator switch gear will be of the metal enclosed type placed in a
separate room close to the generator. It will include the generator phase
equipment and connections shown in the attached single line diagram. The
equipment for the generator neutral side will be placed in a cubicle adjacent
to the generator pit.
8.2.2.4 GENERATOR TRANSFORMERS
10 Nos. generator transformers of 15 MVA, 11/ 220/ / 3 kV , single phase,
50 Hz rating will be provided and placed in a separate cavern on the down
stream side of power house. The OFWF type of cooling is proposed for
generator transformer.
8.2.2.5 CONTROL AND MONITORING EQUIPMENT
The plant will be designed to be operated as an attended type. Unit control
will be provided locally while central control will be from various control
panels located in the control and relay room of the power house. Control
equipment will include metering and control panels, protections for
supervision and operation of the generator turbine, 11 kV switch gear ,
auxiliary power system, transformers and 220 kV switch gear.
The control equipment will also include the PLC and Telecommunication
equipment required for the transmission lines. Provision for connection to
the state load dispatch center will also be provided. The control system
shall be fully computerized.

8.2.2.6 STATION SERVICE/ AUXILIARY SUPPLY
The station service supply is proposed to be taken through 11 kV Local
Distribution system. In addition, for reliability, 500 KVA DG sets shall also
be provided for the black start capability. This will also feed local area ,
Colony, head works etc. The unit auxiliaries shall be fed through 11/0.415
kV, 500 KVA transformers connected to each generator. The auxiliaries can
also be fed from 2 Nos., 11/0.415 kV, 1 MVA station service transformers,
which are connected to 11 kV bus connected to 11 kV local supply.
8.2.2.7 POWER PLANT GROUNDING
8.2.2.8 LIGHTING
The power station will be provided with a complete earthing system. All
exposed conductive parts and equipment in the power house and switch yard
will be connected to the grounding system. The grounding system will be
designed to minimize the “Step” and “Touch” potential within acceptable
limits.
The power plant lighting , following normal practice, will comprise of
interior and exterior lights as appropriate. While the majority of the
illuminaries will be AC powered, emergency lighting will be DC supplied
from station battery system. The emergency lighting will be provided only
for essential locations e.g. control room, exit tunnels etc.
8.2.2.9 SWITCH YARD AND SWITCHING SCHEME
Keeping in view the terrain at the power house and reliability of the system,
GIS underground 220 KV Switchyard with double bus and single breaker
has been envisaged. Provision of Bus Coupler has also been made. It will

e located above the generator transformers in the transformer cavern.
Switchgear shall be connected to the generator transformers through 220
KV oil to SF-6 connectors. The Switchgear shall be connected through app.
250 mtr long 220 KV Bus ducts to the pothead yard through bus duct tunnel.
This has been envisaged because power of this power house (108 MW) shall
be pooled in with the down stream Khoksar (90MW) power house
transmission system by LILOing one Ckt of Khoksar- Tandi 220KV line for
final pooling in at Tandi 400 KV pooling point. Space requirements for pot
head yard will be app. 60 X 20 mtrs.
8.3 PROPOSED EVACUATION ARRANGEMENT TO NEAREST
FACILITIES
It is proposed to evacuate the power generated at Chhatru project by
LILOing one ckt. of 220KV D/C line from Khoksar to 400 kV Pooling point
at Tandi which is proposed in this basin . Beyond this point, the evacuation
will be through 400 KV D/C Network to Panarsa Pooling in Sub-Station of
PGCIL .

PARA DESCRIPTION PAGE
9.1 DESCRIPTION OF THE PROJECT IX-1
9.2 DESCRIPTION OF ENVIRONMENT IX-1
9.2.1 PHYSICAL RESOURCE IX-1
9.2.2 HYDROLOGY IX-1
9.2.3 GEOLOGY IX-1
9.2.4 SOIL IX-2
9.3 ECOLOGICAL RESOURCE IX-2
9.3.1 FORESTS IX-2
9.3.2 FLORA AND FAUNA IX-2
9.3.3 FLORA IX-2
9.3.4 MECHICINAL PLANTS IX-2
9.3.5 FAUNA IX-3
9.4 BASELINE ENVIRONMENTAL STATUS IX-3
9.4.1 CLIMATE AND TEMPERATURE IX-3
9.4.2 TEMPERATURE, RAINFALL AND SNOWFALL DATA
OF PATSCO (ADJOINING LAHAUL VALLEY)
9.5 ENVIRONMENTAL IMPACT ASSESSMENT AND
EVALUATION
IX-3 TO IX-4
IX-5
9.5.1 IMPACT IDENTIFICATION IX-5
9.5.2 IMPACT IDENTIFICATION DURING CONSTRUCTION
PHASE
9.5.3 IMPACT IDENTIFICATION DURING OPERATIONAL
PHASE
IX-5
IX-6
9.5.4 PREDICTION OF IMPACTS IX-7
9.5.5 IMPACT ON AIR ENVIRONMENT IX-7
9.5.6 IMPACT ON NOISE ENVIRONMENT IX-7
9.5.7 IMPACT ON WATER ENVIRONMENT IX-7
9.5.8 IMPACTS ON FLORA AND FAUNA IX-7
9.6 E.R&R ASPECTS IX-7

9.7 ENVIRONMENTAL MANAGEMENT PLAN
(MITIGATION MEASURES)
IX-8
9.7.1 ENVIRONMENTAL MANAGEMENT IX-8
9.7.2 ENVIRONMENTAL MANAGEMENT AT
CONSTRUCTION STAGE
IX-8
9.7.3 SITE PREPARATION IX-8
9.7.4 CONSTRUCTION IX-8
9.7.4.1 AIR ENVIRONMENT IX-8
9.7.4.2 NOISE ENVIRONMENT IX-9
9. 7.4.3 WATER ENVIRONMENT IX-9
9.7.4.4 GREEN BELT DEVELOPMENT (COMPENSATORY
AFFORESTATION)
IX-9
9.7.4.5 DISPOSAL OF MUCK IX-10
Annexure-IX-
1
SATELLITE REMOTE SENSING BASED INPUTS FOR
INITIAL ENVIRONMENTAL STUDIES FROM NRSA
STUDY BACKGROUND IX-11TO IX-12
OBJECTIVE IX-12 TO IX-
13
SALIENT FEATURES OF THE CHHATRU HYDRO
POWER SITE
SATELLITE DATA USED IX-14
BRIEF METHODOLOGY OF SATELLITE DATA
ANALYSIS
IX-13 TO IX-
14
IX-14 TO IX-
15
OUTPUTS PROVIDED IX-15 TO IX-
16
LIST OF TABLE IX-16
TABLE-1 LANDUSE-LAND COVER INFORMATION WITHIN THE
SUBMERGENCE AREA.
TABLE-2 LANDUSE-LAND COVER INFORMATION WITHINTHE 7
KM RADIUS FROM THE DAM SITE AT CHHATRU
IX-16
IX-16

CRITICAL ANALYSIS OF SATELLITE BASED INITIAL
ENVIRONMENTAL STUDY
IX-17 -
TO IX-18
CONCLUSION & RECOMMENDATION IX-18
LIST OF MAPS
1.a IRS ID PAN+LISS III MERGED SATELLITE IMAGE OF
21 ST SEPTEMBER, 2001.
1.b SATELLITE DERIVED LANDUSE-LAND COVER MAP
OF SORROUNDINGS OF PROPOSED HYDRO POWER
SITE AT CHHATRU, HIMACHAL PRADESH.
1.c LANDUSE-LAND COVER MAP OF SURROUNDINGS
UPSTREAM OF PROPOSED DAM SITE AT CHHATRU
1.d MAP OF NATIONAL PARKS /SANCTUARIES AND THE
LOCATION OF CHHATRU HYDRO POWER SITE AND 7
KM RADIUS CIRCLE FROM THE DAM SITE.
IX-19
IX-20
IX-21
IX-22

CHAPTER IX
ENVIRONMENT ASPECTS
9.1 A. Description of the Project
This Project is a run-of-river scheme on river Chandra with diversion barrage at
about 5 km upstream of Chhatru. The Power house is located about 3.5 km
downstream of Chhatru village. The Project falls in Tehsil Keylong, District Lahaul
& Spiti of Himachal Pradesh.
The Project envisages construction of diversion structure + 19m high, for the
diversion of + 75 cumecs of discharge through a +6.5 km long tunnel to an
underground Power House utilizing a gross head of + 177.33m for generating 108
MW of power.
9.2 B. Description of Environment
9.2.1 B.1 Physical Resource
9.2.2 B.1.1 Hydrology
Chenab is a major river of the Indus Basin originating from the snow covered
slopes of Great Himalaya of Pir-Panjal ranges in Lahaul Spiti district and flows in a
steep gradient with a series of loops and bends. The two major rivers in the head
ridges namely Chandra and Bhaga form the Chanra Bhaga (Chenab) river.
The river Chandra originates from Bara lacha and is further augmented by Chandra
Tal. The river, after flowing for more than 48 km in south westerly direction turns
abruptly to the west and flows for another 64 km until it meets the Bhaga river at
Tandi. The average fall of the river is 1 in 60. The first 80 km of the valley is
completely uninhabited, represented by barren, eroding mountain slopes, with large
alluvial flats and fans at places.
The Chandra Bhaga (Chenab) flows North West and maintains an average fall of 1
in 176. After traversing a distance of about 101 km from the confluence at Tandi, it

passes at karunala in to Pangi valley of Chamba District. From Thirot onwards the
river, in places, passes through rocky gorges several metres deep.
9.2.3 B.1.2 Geology:
Great mass of the mountains is composed of ancient rocks of the lurian age, chiefly
Schists, Slates and Balaini conglomerates. The principal rock formation is Mica
schist, Shale and Sandstone. Taken as a whole, the rock system is very fragile and
liable to erosion, which is often accentuated by the rigours of severe winter,
avalanches and the strong winds that accompany them.
The insulation and absence of any water action has led to the accumulation of
abundant detrital products on dry uplands and valleys forming the mantle rock of
regolith of fresh, un decomposed fragments. The bare mountains thus exhibit
typical desert colouration of rocks due to peculiar solar weathering. The right bank
is generally rocky with steep slopes.
9.2.4 B.1.3 Soil:
The soil is generally grey and light, charactrised by scanty plant cover and low
fertility status. In the absence of any substantial leaching of minerals from the soil,
the bases are continuously added to the soil complex, rendering pH to the alkaline
side.
The soil in the Chandra valley is loam to sandy loam with gravel. Its depth varies
inversely with slope. Generally on ridges, spurs, precipitous slopes and southern
aspects soil tends to be shallow and dry with numerous outcrops of bare rocks or its
strew with boulders. In the vicinity of villages and nearby areas, denuded slopes are
subjected to year round concentrated grazing leading to poor soil. On northern
aspects, in folds and hollows as also on easier slopes the soil is fairly deep and
fertile for tree growth.
9.3 B.2 Ecological Resource
9.3.1 B.2.1 Forests
The area is totally devoid of any vegetation except for a small patch of Birch forerst
on the left bank. The reason for absence of vegetation is high altitude, rocky
mountains and very cold climate. However some plantation of Broad leafed species
has been raised.
9.3.2 B.2.2 Flora and Fauna
9.3.3 B.2.2.1 Flora

The only Trees species found in the area is Birch- Betula utilis.
9.3.4 B.2.2.2 Medicinal plants
Important Medicinal Plants found in the area are:
S.N. Common Name Botanical Name
1 Patish Aconitum heterophyllum
2 Mitha Telia Aconitum violaceum
3 Gandha Artemisia maritima
4 Karoo Picorhiza kurroo
5 Ban Kakri Podophyllum hexandrum
6 Dhup Jurinea macrocephala
7 Shingli Mingli Dioscorea deltoides
8 Patishan roots Heracleum candicans spp.
9 Chora Angelica glauca
9.3.5 B.2.3 Fauna:
No mammal, Bird or Fish worth its name is found in this area.
9.4 C. Baseline Environmental status
9.4.1 C.1 Climate and temperature
The high mountains of Central Himalaya act as a barrier and block the rain bearing
winds from the south and as such, receive very little or no rain during the whole
year. However, during winters, which usually starts from the end of September in
most of the areas receives snowfall and this continues even up to May. Summers
are brief while winters are quite long.
9.4.2 C.1.1 Temperature, rainfall and snowfall data of Patseo (adjoining Lahaul
Valley)
Year Month Temperature o C Snow Fall-cm Rain Fall-mm
Max Min
1983 Nov 1.14 -4.54 0 0
Dec -0.22 -5.76 1.25 0
Jan -1.86 -8.76 4.57 0
1984 Feb -2.21 -8.15 4.37 0
Mar 2.83 -5.44 7.07 0
April 3.20 -3.62 5.28 0
May 5.22 -1.07 0 0.75
Nov 1.59 0.389 1.5 0

1985
1986
1987
1988
1989
1992
1993
1994
Dec -1.54 -5.65 14.70 0
Jan
-3.41 -8.96 6.74 0
Feb -1.41 -9.37 4.28 0
March 1.00 -4.63 6 0
April 2.96 -2.94 11.08 0
May 4.77 -0.99 15.5 0
Nov 1.55 -3.59 0 0
Dec -0.04 -5.25 5.44 0
Jan -1.81 -8.58 1.5 0
Feb -1.48 -8.30 6.3 0
March -0.58 -6.78 6.91 0
April 2.35 -4.44 7.67 0
May 3.93 -1.87 3.67 0
Nov 1.70 -4.08 11.37 0
Dec -2.09 -8.06 12.45 0
Jan -1.93 -9.06 8.6 0
Feb -1.33 -7.67 6.86 0
March 1.05 -6.36 6.7 0
April 2.33 -4.15 19.46 0
May 2.02 -4.32 0 0
Dec 1.60 -4.63 5 0
Jan -2.09 -6.96 4.57 0
Feb -0.96 -6.89 8.42 0
March -0.02 -6.91 13.96 0
April 2.87 -3.29 0
Nov 1.56 -3.59 3.69 0
Dec 0.24 5.40 5.72 0
Jan -1.74 -7.99 8.29 0
Feb -1.88 -7.28 5.30 0
march 1.31 -5.51 5.13 0
April 2.07 -4.38 4 0
Nov 3.15 -3.82 3.40 0
Dec 0.35 -6.53 3.67 0
Jan -2.44 -8.61 9.31 0
Feb 0.14 -5.96 7.64 0
march 0.22 -6.90 20.78 0
April 3.90 -4.42 10 0
Nov 2.50 -4.04 6.5 0
Dec 0.77 -7.06 0 0
Jan -1.72 -8.42 9.62 0
Feb -0.84 -10.26 7.45 0
March 2.83 -5.96 5.22 0
April 3.32 -4.26 8.44 0

1995
1996
1999
2000
May 5.94 -1.40 9.16 0.6
Nov 2.89 -4.07 0 0
Dec -0.84 -6.07 7.35 0
Jan -2.59 -10.72 5.67 0
Feb -1.12 -7.32 5.89 0
March 0.90 -6.72 5.90 0
April 2.66 -3.58 8.87 0
Nov -1.14 -6.59 3.00 0
Dec -10.6 -18.7 5.31 0
Jan -1.74 -8.04 13.36 0
Feb 1.30 -7.75 15.68 0
March 1.55 -5.60 9.56 0
April 2.78 -3.82 9 0
Nov 2.31 -4.99 4 0
Dec 1.76 -6.44 1 0
Jan -0.07 -7.99 0 0
Feb 0.18 -7.87 0 0
March 1.71 -8.95 5.80 0
April 4.14 -2.24 2.17 0
May 8.14 0.74 0 0
Air, Water, Soil and Sound data will be collected at the time of doing detailed EIA.
Since this is pre feasibility report, this has not been done at this stage.
9.5 D. ENVIRONMENT IMPACT ASSESSMENT AND EVALUATION
9.5.1 D.1 Impact Identification
Environmental impacts both direct and indirect on various environmental attributes
due to Chhatru Hydropower project in the surrounding environment, during
construction & operational Phase are discussed.
9.5.2 D.1.1 Impact identification during construction phase
The impacts due to the construction of Chhatru HEP and power house installation
commence from the exploration activities, construction of barrage, tunnels and
approach roads, etc., may continue up to generation of hydel power, with the nature
and extent of impacts varying throughout the stage of project development.
Activities like site preparation, approach roads, excavation, drilling, blasting,
foundations, tunneling, deployment of machinery, erection, transportation ,dumping
are taken up during construction phase. The likely impacts on the environment due
to these activities are listed in table.
Tunneling and foundation works will involve land excavation, filling and concrete
works effecting environment by noise and dust pollution. Structural, deployment of

machinery, approach roads construction and erection work will also result in dust,
noise pollution and vehicular traffic. Material handling and transportation may
significantly increase noise pollution.
The labour for various activities during the construction phase shall be engaged
from the surrounding villages. Some essential services are also required to be
provided. This will have an impact on drinking water supply and sanitary facilities.
Economy of the nearby area will be improved due to increased job opportunities
with corresponding increase in income. Other associated business activities like
transport, hotels, consumer goods etc., will also be benefited.
The major environmental parameters likely to be effected during construction phase
are noise, dust pollution and sanitation. Water spraying during high dust will
minimise the dust level to some extent. A proper temporary housing with water
supply and sanitation for workers should be planned. The effect due to construction
phase is however, of temporary in nature and has no permanent effect on
environment.
Construction Phase Activity Potential Environmental
Impact
Site work / providing other
facilities.
Construction of approach
roads, tunneling works and
construction of under
ground Power Station
Clearing and grading Negligible
Temporary facilities, such
as, sheds approach roads,
sanitary facilities.
Earth work comprising of
excavation and trenches.
Dust emission and change
in traffic intensity.
Soil erosion, run off,
increase in traffic, Dust
emission
Dust, visual and noise
pollution
Dust and noise pollution
Foundation work, piling and
construction of check dams.
Construction of permanent
structures like roads, colony
etc
Mechanical erection and Dust, noise and visual
utility systems.
impact.
Excavation Dust, soil erosion,
wastewater generation and
noise
Drilling and blasting Dust, noise and health
hazards
Dumping Dust, noise and visual
Transportation Dust, noise and visual
9.5.3 D.1.2 Impact identification during operational phase

There would be little environmental and ecological changes during the operational
phase. The main activities that may cause environmental impact on the surrounding
environment during project completion and after during operation are:
i. Transportation of excessive solid waste material (muck)
ii. Dumping of solid waste material
iii. Removal of temporary facilities, cleaning etc.
9.5.4 D.2 Prediction of Impacts
The impact during the construction of Chhatru HEP on environment (air, water,
noise, land etc. are predicted in this section. The construction activity may cause
some adverse impacts on the surrounding environment unless proper environmental
management plan is adopted.
9.5.5 D.2.1 Impact on air environment.
Considerable amount of air pollution will be caused during different stages of
construction of tunnels, barrage, roads and other operations such as excavation,
drilling, blasting, loading and transportation of material. Suspended Particulate
Matter (SPM) is the main pollutant during construction. Most of the dust arises
from drilling, blasting, excavation, crushing and transportation operations. Large
quantities of dust become wind borne and are carried away from overburden
dumps. The fugitive dust released during the construction activities may cause
immediate effect on the construction workers who are directly exposed to the
fugitive dust. Vegetation will also be adversely affected as deposition of dust on the
leaves will choke the photosynthesis activity, which, in turn, will have adverse
effect on the health of the plants. However, the dust does not travel to longer
distance because the project site is located in between hills and V-shaped valleys.
9.5.6 D.2.2 Impact on noise environment
The noise will be generated at the time of construction of barrage, powerhouse,
tunnel boring machine operations, pumps, drilling machines, dumpers, etc.
Continuous exposure of workers to high level of noise may result in annoyance,
fatigue, and may cause temporary shift of threshold limit of hearing and even
permanent loss of hearing. During operational phase, noise level will be increased
due trouncing machinery and vehicular movement in the area. However, these
impacts are only localized.
9.5.7 D.2.3 Impact on water environment.
During the construction of barrage, tunnel, and power house surface water (river
water) may get polluted due to the generation of large quantities of suspended

particulate matter at the time of transportation of muck and waste water (sewage)
coming from temporary arrangements like offices, labour camp sheds, etc.,
9.5.8 D.2.4 Impacts on Flora and Fauna
Since there is no vegetation worth its name nor any wild life, there will not be any
adverse impact. There is no Wild Life Sanctuary or National Park in the Project
area.
However, Compensatory afforestation will be done as per the general stipulations
given by the Govt. of India MOEF at the time of sanction of diversion of
Forestland
9.6 E. R & R Aspects
Since the Project is a run-of-the-river type and there is no storage, therefore, there is
no submergence. Hence, no dwellings, houses or hamlets will be submerged. So,
there is no displacement and resettlement is involved.
9.7 F. ENVIRONMENTAL MANAGEMENT PLAN (MITIGATION
MEASURES)
Environmental Management Plan (EMP) aims at the preservation of ecological
system by considering certain mitigating measures at the proposed site. The
mitigation measures are used to minimize or prevent adverse impacts on
environment due to the proposed development activity. Some of the major criteria
governing the environmental measures will be adopted, and the same is described in
the following paragraphs.
9.7.1 F.1 Environmental Management
The EMP is required to ensure sustainable development in the area of 10 Km radius
of the proposed Chhatru HEP site.
It is expected that the study area shall not be affected much with the proposed
activity and likely to get new economic fillip due to hydel power generation, not
only for the study area but also for the region as a whole.
The majority of the environmental impact pertains to the construction phase. It is
planned to take corrective measures to ensure that these effects are kept to bare
minimum. The EMP will therefore, be initiated during planning stage itself.
Catchment Area Treatment Plan, which will be prepared at a later stage, will form
part of the Environmental Management Plan. However, there is not much scope of
plantation in the area.

9.7.2 F.1.1 Environmental management at construction stage
9.7.3 F.1.1.1 Site preparation
Dust emission (fugitive) and solid waste will be generated during initial site
preparation activity and there will be slight increase in the noise levels around the
site. The environmental impacts during the clearing or clearing for site preparation
will be temporary, localised and negligible. Water sprays at appropriate location
will be provided for dust suppression, hence reducing the impacts. Solid waste will
be disposed off along with the muck at the designated sites.
9.7.4 F.1.1.2 Construction
9.7.4.1 Air environment
As discussed earlier, construction of Chhatru HEP and powerhouse activities will
generate large quantities of dust during drilling, blasting, loading and transportation
operations. The following measures are required be taken to mitigate the fugitive
dust from different operations.
To avoid the dust generation from the drilling operations, wet-drilling methods will
be adopted.
Ceasing dust -generating activities during high winds
Covering of vehicles carrying solid waste (muck).
Watering of haul roads and other roads at regular intervals
Plantation near muck disposal places and dumping yards.
9.7.4.2 Noise environment
The major noise generating sources from the proposed activity are working
machinery, blasting and movement of vehicles. The following control measures are
to be undertaken to bring down the noise levels.
Traffic (vehicular movement) to be managed to produce a smooth flow instead of a
noisier stop -and start flow.
Ensuring timely preventive maintenance of the equipment involved. Since a well
maintained equipment is generally quieter than poorly maintained equipment.
Ensuring usage of personal protective devices i.e., earmuffs and earplugs by
workers, working in high noise activity centers.

Plantation in the vicinity of the construction area will further reduce the noise
levels.
9.7.4.3 Water environment
During construction phase the wastewater (sewage) coming from temporary
arrangements like offices, labour camp sheds, canteens etc., and impact due to soil
erosion during monsoon period may cause surface water pollution.
Some of the control measures adopted for controlling water pollution are as
follows:
Establishing septic tanks followed by soak pits to treat the domestic waste water
generated from the offices, canteens, labour camp sheds.
Construction of Check dams /rock fill dams, wherever necessary to reduce siltation
and suspended solids.
9.7.4.4 Green belt development (Compensatory Afforestation)
Afforestation is proposed to be done in open areas with moderate slope. This has to
be supplemented with engineering/vegetative works like gully plugging and check
dams etc where ever required. There is very limited scope of plantation. Where ever
plantation is undertaken it should be closed to grazing, lopping etc. For proper
protection, it is necessary that the area is fenced and the fence is maintained
properly. Plants need to be protected till they attain a height, which is above grazing
level.
9.7.4.5 DISPOSAL OF MUCK
By constructing a 6.5 km long tunnel, the quantity of muck to be generated is
estimated to be more than 0.50 lac M 3 . After applying the swell factor, the volume
to be disposed off will be about 0.75 lac M 3 . It is expected that 25-35 % of this will
be used for making aggregates. The rest will require to be disposed off in a planned
manner.
This is the most important aspect to be dealt with. It is proposed that at different
locations dumping sites will be identified at suitable places. Retaining walls will be
constructed. After the filling is done, rehabilitation of this site will be done to
ensure that neither it flows in to the water stream nor it poses any other
environmental threat. Plantation, wherever possible, will also be done on these sites
so that these get stabilised over a period of time and do not pose any environmental
problem.

Annexure-IX-1
REPORT OF SATELLITE DATA ANALYSIS
SATELLITE REMOTE SENSING BASED INPUTS FOR
INITIAL ENVIRONMENTAL STUDIES
IN
RESPECT OF 6 PROPOSED HYDRO-POWER SITES
IN CHENAB BASIN IN HIMACHAL PRADESH
NAME OF THE HYDRO-POWER SITE : CHHATRU
1. Study Background
Central Electricity Authority (CEA) under Ministry of power, Govt. of India
has earlier identified 399 potential hydroelectric sites in the country with an
installed capacity of 1,07,000 Megawatt ( MW). With a view to preparing
an action plan to develop this hydroelectric potential and prioritizing the
implementation of hydro-electric projects, a Ranking study was taken up by
the CEA in 2001. This Ranking study identified 162 most potential sites
with a total installed capacity of 50,560 MW for development.
Preparation of Pre-Feasibility Reports (PFR) of these 162 sites has been
initiated by the CEA in 2002 with works entrusted to a number of
Consultants, namely, National Hydroelectric Power Corporation (NHPC),
North Eastern Electric Power Corporation (NEEPCO), Water and Power
Consultancy Services India Limited (WAPCOS), Satluj Jal Vidyut Nigam
Limited (SVJNL), Himachal Pradesh State Electricity Board (HPSEB),
Uttaranchal Jal Vidyut Nigam Limited (UJVNL) and Kerala Power
Corporation Limited (KPCL) with time target of completion of the whole
exercise by September 2003. To oversee the progress of the PFRs
preparation in time and with full cooperation of the Central Government
agencies, a Central Coordination Committee consisting of Central
Electricity Authority (CEA), Central Water Commission (CWC), India
Meteorological Department (IMD), Ministry of Environment & Forest,
Survey of India, Geological Survey of India (GSI) and National Remote

Sensing Agency (NRSA) was constituted by the CEA with Member
(Hydro-power) as its representatives of the Consultants to take stock of the
completion of the studies. One of the mandates of PFR preparation is
“Initial Environmental Study” with respect to each of the 162 proposed sites
using satellite remote sensing data.
As is well known in India and elsewhere in the world, space technology
plays a very important role in terrain mapping and scientific assessment of
the ground condition at speed, and is ideally suitable for inaccessible
mountainous regions where majority of these hydroelectric dam/diversion
site are located. Computer processing of satellite digital data of the dam/
diversion site and their immediate environ provides wealth of information
for preparation of the Pre-Feasibility Reports. The Potential of this
technology was amply demonstrated in the preliminary ranking study of the
81 proposed hydro-electric sites in Indus Basin completed by NRSA in
October 2001 on behalf of CEA. In view of this, NRSA has been
approached by a number of consultants, namely, NHPC and HPSEB to take
up Initial Environmental Studies in respect of 37 proposed hydro- power
sites located in the States of Arunachal Pradesh., Himachal Pradesh, Jammu
& Kashmir and Madhya Pradesh using most recent satellite remote sensing
data.
Himachal Pradesh State Electricity Board (HPSEB), Sundernagar has
approached NRSA for satellite remote sensing based inputs for initial
environmental study of 6 hydro- power sites located in Chenab Basin in
Himachal Pradesh.
This Report deals with Chhatru hydro-power site.
2. Objective
Principal objective of the satellite based study is to acquire Indian Remote
Sensing satellites (IRS IC/1 D ) LISS-III and PAN sensor digital data of
the hydro- power sites and to make quick analysis of these data in terms of

estimation of the submergence area at proposed Full Reservoir Level (FRL)
and mapping of land use-land cover information within and in immediate
surrounding of the proposed submergence area as inputs for Initial
Environmental Study (IES) of the Pre-Feasibility Report.
The specific objectives and scope of the study are :
• To estimate the area of submergence at proposed FRL of the proposed
hydro- power sites.
• To analyse the satellite data for identifying broad land use-land cover
categories like agricultural land, forest land, barren land, scrub land,
water bodies, settlements, infrastructural features (roads and bridges)
and to estimate the area under each of the categories within and in
immediate surrounding of the proposed submergence area at FRL.
• To prepare land use- land cover map at 1:50,000 scale and/or 1:25,000
scale of the submergence area and its immediate surrounding for each
hydro-power site.
3. Salient Features of the Chhatru Hydro-Power Site
Proposed hydro-power site is located at Chhatru in Chenab River Basin
in Himachal Pradesh falling in Survey of India topo sheeets No. 52 H/3
& 52 H/7. The proposed project scheme at Chhatru envisages
construction of a Dam on Chandra river and a power house. The Head
Race Tunnel from the dam to the power house is proposed to be 8.5 km
in length. The river water will be stored in the reservoir which will be
diverted through the Head-Race Tunnel to the Power House for hydropower
generation. The geographic location of Dam and Power House
for this hydro-power site given below:

Dam Power House
Latitude : 32°18’08” N 32°20’ 9” N
Longitude : 77° 24’ 41” E 77° 20’ 51” E
4. Satellite data Used
Indian Remote Sensing Satellite, IRS-ID LISS and PAN sensors data of 21 st
September,2001 covering the study site were procured from the NRSA
Data Centre (NDC) after intensive browsing of the available satellite data
for cloud-free and radiometric suitability, IRS-Id covers the study site by
satellite geo- reference number Path 95 and Row 48. These data are
geometrically and radiometrically corrected digital data products which can
be used readily in Window based image analysis platform.
5. Brief Methodology of Satellite Data Analysis
Image processing and analysis was done using ERDAS Imagine image
analysis software in Windows platform. Satellite data of IRS ID LISS III
sensor provides 23.5 m spatial resolution and PAN sensor provides 5.8 m
spatial resolution. The two sensor data were geocoded and digitally merged
using IHS transformation technique. Baseline information layers (like
rivers/streams) and infrastructural features (like roads and bridges),
settlements/ villages were initially interpreted on the digital image scene.
Subsequently, image classification technique was performed to obtain the
land use-land cover categories of the study area.
Output maps were composed in the image processing system which provide
the land use/land cover information alongwith other interpreted information
such as roads, settlements etc. , within the 7 Km. radius from the dam site.
The Full Reservoir Level (FRL) boundary, provided by the HPSEB,
Sundernagar was superimposed on the satellite data as well as on the land
use- land cover map. Area statistics of different land use-land cover

categories were generated within the submergence area at FRL and within
the 7 Km. radius circle from the dam site.
6. Outputs provided
Based on the analysis of satellite data and other available ancillary
information, the following outputs were generated:
• Map 1 (a) Shows IRS 1 D PAN + LISS III merged satellite
image of 21 st September, 2001 on 1:50,000 scale covering 7 km.
radius from the dam site overlaid with FRL, location of dam site and
power house.
• Map 1 (b) Shows satellite derived landuse- landcover map on
1:50,000 scale covering 7 km radius from the dam site overlaid
with FRL, location of dam site and power house. Land use/land
cover map shows the following categories: Forest (High and
Medium and low Dense Forest), Agricultural Land, Open Scrub,
Barren and Rock Outcrop, Snow, River course/ Dry River Bed.
• Map 1 (c) Show the land use – land cover classes and their
corresponding area statistics in hectares within the submergence area
on 1:25000 scale overlaid with FRL, location of dam site and power
house.
• Map 1 (d) Shows the location of the National parks/Wildlife
Sanctuaries vis-à-vis the location of the dam/Power House and 7 km
radius area around the dam site.
• Table. 1 Landuse-landcover Information within the
Submergence Area.

S. No. Landuse-land cover Area under % of the total
category
submergence(Ha) submergence area
1. High Dense Forest Nil Nil
2. Medium Dense
Forest
Nil Nil
3. Low Dense forest Nil Nil
4. Open scrub Nil Nil
5. Barren/Rock
Outcrop
9.25 55.22
6. Snow Nil Nil
7. Agriculture land Nil Nil
8. Human Settlement Nil Nil
9. River Course
including dry river
bed
7.50 44.78
Total 16.75 100
• Table. 2 Landuse-landcover Information within the 7 Km
Radius from the Dam site at Chhatru
S. No. Landuse-land cover Area under % of the total
category
submergence(Ha) submergence area
1. High Dense Forest - -
2. Medium Dense
Forest
98 0.64
3. Low Dense forest 42 0.27
4. Open scrub 4270 27.74
5. Barren/Rock
Outcrop
8665 56.29
6. Snow 2210 14.36
7. Agriculture land 108 0.70
Total Area 15393 100.00

7. Critical Analysis of Satellite based Initial Environmental Study
• Total area under submergence at proposed FRL is estimated to be
16.75 ha (Table 1).
• It is observed that the landuse -landcover is mostly dominated by
barren /rock outcrop which is 9.25 ha (55.22% of the submergence
area). It is followed by open scrub, which is present to the extent of
7.5 ha (44.78% of the submergence area at the proposed FRL).
• There is no agricultural area present within the proposed
submergence area which is positive sign to develop the
proposed hydropower site.
• There are no surface water bodies other than the river course.
The area under river course including dry river bed is
estimated to be 7.50 ha.
• In the absence of available information from other sources
about the existence and spatial extent of national parks and
Wildlife sanctuaries, best efforts were made to collect
information from the Internet. The information available in
website of United Nations Environment programme World
Conservation Monitoring Center (http;//www.unep-
wcmc.org) regarding Himachal Pradesh State and its
National Parks/Wild Sanctuaries, were browsed through.
The information at hand is made use in preparing map 1 (d)
which depicts the latitude and longitude of dam site and the
sanctuaries/national parks. 7 km. radius circle around the
dam is plotted and the radial distance to the various national
park/sanctuary were estimated around the nearest national
park/sanctuary which are of significant only are measured on
the map 1 (d). The following points are observed from the
map 1(d).

- The nearest sanctuaries are Mani, Kais and Kanwar which are about
at distance of 28 Km, 38 Km. and 45 Km. respectively whose sizes
interms of aerial extent are in the figure 1(d).
- Since 7 Km. radius around the dam site was considered as the area of
study, efforts were made to check whether the geo-coordinates of
this Wildlife Sanctuary is falling within the area of study. The map
No. 1(d) explains the location of the sanctuary vis-à-vis the dam site
and the power house.
8. Conclusion & Recommendation
1. Satellite based study has provided insight into the landuselandcover
pattern and their spatial extent within the
submergence area at FRL and within the 7 Km radius
vicinity of the proposed dam site. Such detail information on
a scale of 1:25,000 are not available from any other sources
at present.
2. There is no agricultural land within submergence area. The
environmental cost on this score is therefore nil.
3. Settlements in the submergence area looks to be Nil. This has
to be verified on the ground for detailed information.
4. The forest vegetation in the submergence area is nil, hence it
is a positive thing in respect of environmental impact due to
the development of proposed hydro power site.
5. The submergence area landuse-landcover mainly comprises
of barren (denuded hills).
6. The nearest sanctuaries are Mani, Kais and Kanawar which
are about at distance of 28 Km. 38 Km and 45 Km
respectively. The respective sizes of these sanctuaries are
3180 ha, 1419 ha and 6070 ha. Hence, in view of the small
sizes of these sanctuaries, development of this hydro power
site may not have any significant impact on these sanctuaries

since the fetch distance of the reservoir submergence will be
around 1.3 km. only.

PARA DESCRIPTION PAGE
9.0 DESCRIPTION OF THE PROJECT IX-1
9.1 Description of environment IX-1 TO IX-2
9.2 Ecological resource IX-2 TO IX-3
9.3 Baseline Environmental status IX-3 TO IX-6
9.4 Environment impact assessment and evaluation IX-6 TO IX-10
9.5 R&R aspects IX-10
9.6 Environmental management plan (mitigation
measures)
9.7 INITIAL ENVIRONMENTAL STUDIES IX-13
IX-10 TO IX-13
ANNEXURE-IX-1 REPORT OF SATELLITE DATA ANALYSIS IX-14 TO IX
iRS ID PAN + LISS III MERGED SATELLITE
IMAGE OF 21 ST SEPTEMBER,2001.
satellite derived land use- LAND COVER MAP OF
SURROUNDINGS OF PROPOSED HYDRO
POWER SITE AT KHOKSAR, HIMACHAL
PRADESH.
LAND USE-land cover map of immediate
surroundings upstream of proposed dam site at
khoksar.
MAP OF NATIONAL PARKS/SANCTUARIES
AND THE LOCATION OF KHOKSAR HYDRO
POWER SITE AND 7 KM. RADIUS CIRCLE FROM
THE DAM SITE.
MAP- 1 (a)
MAP- 1 (b)
MAP- 1 (c)
MAP- 1 (d)

PARA DESCRIPTION PAGE
10.0 IDENTIFICATION OF THE BROAD INFRASTRUCTURAL
REQUIREMENT FOR IMPLEMENTATION OF PROJECT
10.1 ROADS X-1
10.1.1 GENERAL X-1
10.1.2 PROJECT ROADS X-2
10.2 BUILDINGS X-2
X-1

10.2.1 COLONY AT SUNDERNAGAR X-2
10.2.2 COLONY AT VILLAGE CHHATRU X-3
10.2.3 OFFICE COMPLEX FOR OUTLET SIDE WORKS X-3
10.2.4 SCHOOL & HOSPITAL X-4
10.2.5 FIELD HOSTEL AND REST HOUSE X-4
10.3 DUMP AREA X-4
10.4 JOB FACILITIES X-4
10.5 QUARRY SITES X-4
10.6 TELEPHONES X-5
10.6.1 INTERNAL TELEPHONE SYSTEM X-5
10.6.2 EXTERNAL TELEPHONE SYSTEM X-5
10.7 WIRELESS SYSTEM X-5
10.8 PLANT AREA X-5 TO
X-6
10.9 FIELD WORKSHOP X-6
10.10 CONSTRUCTION POWER X-6
10.11 SAFETY X-6 TO
X-7

CHAPTER – X
INFRASTRUCTURE
10.0 IDENTIFICATION OF THE BROAD INFRASTRUCTURAL
REQUIREMENT FOR IMPLEMENTATION OF THE PROJECT
10.1 ROADS
Chhatru Hydel Project is situated in Lahaul & Spiti Distt. of Himachal
Pradesh. The barrage site on Chandra river about 5 km. u/s of Chhatru
village is located about 407 Kms. from Chandigarh, which is approachable
through an all weather road from Chandigarh to Manali(315 km)by NH-21,
from Manali to Gramphu (Shiprang) motorable road (June to Oct.),70 km.
and then to diversion site motorable raod (July to Sept.) 22 km. along
Manali-Leh road. Power House site is only approachable by constructing a
link road about 7 km. from suspension bridge on Manali-Leh road. The
power house is about 8.50 km. d/s of proposed diversion site.
Adequate provision for residential and non-residential accommodations with
necessary amenities has been made for construction and design staff
proposed for the project. Workshop, stores, POL pumps, explosive
magazine and other infrastructural facilities have also been provided in the
estimate. Necessary provision for telecommunication, medical , educational
facilities and safety /security measures have also been made in the report.
All infrastructure facilities proposed ro this project has been shown in Drg.
No. Chhatru- FR-8.

10.1.1 GENERAL
A total of about 2 km. length of (5/7m. wide) road shall be needed to
connect the existing motorable road with the various project components.
The widening of existing roads in the total length of 8.50 kms. has been
proposed.
10.1.2 PROJECT ROADS
Approach road 5/7 m. wide, 4.9 Km. long will connect different work sites
of the project with the existing motorable road.
The following roads have been proposed.
1. C/O proposed road to top of surge shaft
and power house
= 10.00 km.
2. C/O proposed road to adit of HRT = 4.00 km
3. C/O proposed road from main road to colony,
Dumping areas & quarry site etc. = 6.00 km.
4. Re-aligning of existing main road along
proposed reservoir = 2.00 km
Total = 17.00 km.
5. Widening of existing motorable road from
Diversion site of Khoksar HEP to power house
of Chhatru HEP = 17.00 km.
Total = 17.00 km.
6. Provision of R..C.C.bridge in place of
existing suspension bridge = 1No.

10.2 BUILDINGS
It is proposed to construct residential and non-residential colonies for this
project at village Baran in private land.
10.2.1 COLONY AT SUNDERNAGAR
A permanent residential/non-residential complex for design organization will be
constructed at Sundernagar. The same can be used for monitoring/planning liaison
purpose after the completion of the project.
10.2.2 COLONY AT VILLAGE CHHATRY
Residential/non-residential colony for the construction of the project is
proposed to be constructed at village Chhatru which is about 5 km from barrage
and 3.50 km. from power house. Labour huts , stores and field offices will be
constructed nearby the project components on the small terraces available.
10.2.3 OFFICE COMPLEX FOR OUTLET SIDE WORKS
Office complex for the construction of power house complex, penstock, surge
shaft and tunnel from outlet end is proposed on the terrace available near the
inlet of main access tunnel to power house.
10.2.4 SCHOOL & HOSPITAL

Adequate provision of buildings for Hospital, school etc.has been made in the
project estimate under Sub-Head K-buildings to cater for construction force.
First aid posts shall be provided at all project sites.
10.2.5 FIELD HOSTEL & REST HOUSE
Field hostel is proposed to be constructed in the project area near residential
colony.
10.3 DUMP AREA
The muck of open & underground excavation shall be dumped in dump areas
located d/s of diversion structure and inlet of HRT. The dumping station for
power house muck may be proposed at 4.50 km from power house. Dump
areas chosen are located much above the river/nallah banks and are provided
with suitable retaining walls etc. Bull dozers shall be deployed in dump areas
for spreading and compaction of dumped material.
10.4 JOB FACILTIES
Flat terraces available near the project components wherever possible shall be
utilized for job facilities like stacking of construction material, D.G. sets, truck,
trailers, cement carriers, road rollers and site office stores etc.
10.5 QUARRY SITES
The material in the river bed may be suitable for aggregate. Rock from
different quarries in the vicinity of the project may also be identified, to assess
their suitability for manufacturing aggregate.

10.6 TELEPHONE
10.6.1 INTERNAL TELEPHONE SYSTEM
It is proposed to have an independent telephone exchange for this project. All
important work sites, offices within the project area will be connected by
telephones. A 50-lines capacity private automatic exchange (PBX) for the
project will be provided .
10.6.2 EXTERNAL TELEPHONE SYSTEM
Telecommunication link between project sites and outside places will be
provided by existing communication net work of Post & Telegraph
Department connected to the nearest P&T exchange at Manali. This system
would be operated and maintained by P&T Department on rental basis.
Power Line communication carrier system is also proposed for the project.
10.7 WIRELESS SYSTEM
On the pattern of other on going hydel projects in H.P., fixed type VHF
Wireless link is proposed to be provided between project sites and design office
at Kullu, which will be further connected to existing wireless system of HPSEB
at Shimla.
10.8 PLANT AREAS
Plant area for different sites of work have been provided near respective sites.
It is proposed to install a central aggregate crushing, processing and
classification plant near quarry site proposed at 15 miles station which will
fulfill the requirements of aggregates for barrage & inlet end works and

powerhouse site to cater for the requirements of works of HRT from outlet end,
surge shaft, penstock and powerhouse and appurtenant works. An adequate
capacity batching and mixing plant will be installed near barrage to cater the
requirements of concrete for all inlet side works including tunnel lining. Other
batching and mixing plants of requisite capacity will be provided near power
house site for concreting work in power house complex , pressure shaft, head
race tunnel and surge shaft.
Central compressor houses will be located near tunnel portal to meet up the
requirements of the compressed air.
10.9 FIELD WORKSHOP
The workshops/repair shops are proposed to be established near barrage site &
power house site.
10.10 CONSTRUCTION POWER
10.11 SAFETY
Requirement of construction power will be met form existing transmission net
work in the area by suitably augmenting the same to meet requirement of the
project at various sites. Necessary provision for providing power lines and
distribution system has been made in the project estimate.
Adequate provision for stand by diesel generating sets has been made in the
project estimate to meet up power requirements in the event of power failures,
shutdowns / breakdown.
Safety is an essential job requirement for a highly mechanized work set up.
Adequate provision for fire fighting arrangements and security arrangements

has been made in the project estimate by way of police post/check-post and
check barriers etc.
Adequate safety/preventive measures against accidents are proposed to be taken
in accordance with the following Indian Standard Codes:
IS: 4756 For safety in tunneling work.
IS 3996 For scaffolds and ladders.
(Part I&II)
IS: 3764 For excavation work.
IS: 4081 For blasting and related drilling operations.
IS: 4138 For working in compressed air.

PARA DESCRIPTION PAGE
11.0 CONSTRUCTION PLANNING & SCHEDULE XI-1
11.1 GENERAL APPROACH FOR CONSTRUCTION PLANNING FOR
EXECUTION OF PROJECT COMPONENTS
XI- 1
11.1.1 CONSTRUCTION METHODOLOGY & EQUIPMENT PLANNING XI-1
11.1.2 GENERAL XI-1
11.1.3 COMPLETION TIME AND AVAILABLE WORKING SEASON XI-2
11.1.4 APPROACH ROAD AND THE LOCATION OF THE PROJECT XI- 2
11.1.5 CONSTRUCTION MATERIAL XI- 2
11.1.5.1 CEMENT XI- 2
11.1.5.2 STEEL XI-2 TO XI-3
11.1.5.3 AGGREGATE XI- 3
11.1.6 STORES, LUBRICATION& WORK SHOP XI- 3
11.1.7 AGGREGATE PROCESSING PLANTS. XI- 3
11.1.8 PLANT AREAS XI-3 TO XI-4
11.1.9 DUMP AREAS XI-4
11.1.10 PRE-CONSTRUCTION FACILITIES XI-4
11.1.11 EQUIPMENT PROVISION XI- 4
11.2 CONSTRUCTION SCHEDULE XI- 5
11.2.1 INFRASTRUCTURAL WORKS XI-5
11.2.2 DIVERSION BARRAGE XI-5
11.2.3 INTAKE STRUCTURE XI-5 TO XI-6
11.2.4 DESILTING TANK XI- 6
11.2.5 MECHANICAL WORKS FOR THE ABOVE FEATURES XI- 6
11.2.6 HEAD RACE TUNNEL XI-6 TO XI-7
11.2.7 SURGE SHAFT XI- 6 TO XI-7
11.2.8 PRESSURE SHAFT XI-7
11.2.9 POWER HOUSE XI- 7
11.2.10 TAIL RACE TUNNEL XI- 7
11.2.11 INSTALLATION TESTING AND COMMISSIONING XI-7

CHAPTER – XI
CONSTRUCTION PLANNING & SCHEDULE

11.0 CONSTRUCTION PLANNING & SCHEDULE
11.1 GENERAL APPROACH FOR CONSTRUCTION PLANNING AND
EXECUTION OF PROJECT COMPONENTS
11.1.1 CONSTRUCTION METHODOLOGY & EQUIPMENT PLANNING
11.1.2 GENERAL
Chhatru Hydel Project is a 108 MW capacity run of the river scheme in
Lahaul & Spiti District of H.P envisages utilization of 75 cumecs of design
discharge and 177.83m of gross head. Diversion barrage about 5 km. u/s of
Chhatru village and power house about 3.50 km d/s of Chhatru village has
been proposed . The project comprises following main civil structures:
Barrage
Intake structure
Desilting arrangement
Head Race Tunnel
Surge Shaft
Pressure shaft
Power House
Tail race tunnel
11.1.3 COMPLETION TIME AND AVAILABLE WORKING SEASON
Construction programme, selection of methodology and equipment have
been planned with the aim of commissioning of the project in four and half
years. Available working season in a year shall be of 12 months for all

underground works, 9 months for surface works above river bed and eight
months for the works in the river bed.
11.1.4 APPROACH ROAD AND THE LOCATION OF THE PROJECT
A total of about 22 Km road (5/7 m wide) shall be needed to connect the
existing motorable road with the project components i.e. Adit to HRT,
surge shaft area, Power house and colony area .
11.1.5 CONSTRUCTION MATERIAL
11.1.5.1 CEMENT
11.1.5.2 STEEL
ACC cement factory located at Barmana in Distt. Bilaspur (HP), on NH-21
and at a distance of 215 Kms from the project site shall be the main source
of cement for meeting the entire cement requirement of the project. Bagged
cement shall be transported in trucks and stored in project stores at different
sites.
Steel stockyard at Parwanoo, 400 Kms. from main project store, shall be the
main source of structural and reinforcement/ tor. steel. Sizeable quantities of
reinforcement steel and structural steel shall have to be stocked and
replenished regularly. Penstock steel plates if not available indigenously
however, may have to be imported to suit the design specifications.
11.1.5.3 AGGREGATE
The material in the river bed may be suitable for aggregate, however, the
same has to be got tested at detailed investigation stage.

Rock from different quarries in the vicinity of the project may also be got
identified, to assess their suitability for manufacturing aggregate. Rock
extracted from the quarries as well as from tunnel will be crushed and
classified to various sizes of aggregate in batching and mixing plant one
near the barrage site and other near power house ( for excavated material
from tunnel).
11.1.6 STORES, LUBRICATION & WORK SHOP
The Petrol/diesel pumps, explosives magazine, workshops and other
construction facilities shall be provided to facilitate execution of the project.
While central stores for storage of cement, T&P articles, steel yard as well
as timber yard and main workshop shall be provided . Site stores and field
workshops will be established near respective sites. Petrol/diesel pump shall
be established near the power house site.
11.1.7 AGGREGATE PROCESSING PLANTS
Two aggregate crushing classification and sand manufacturing plants shall
be installed near each site of work and 2 nos. batching and mixing plants
shall be located near Power house& barrage site.
11.1.8 PLANT AREAS
Plant areas for locating air compressor house, cement, aggregate, T&P
stores and water storage tanks etc., shall be located near each site of work
and 2 nos. batching and mixing plants shall be located near Power house&
barrage site.
11.1.9 DUMP AREAS

The muck of underground excavation shall be dumped in dump areas
located within 1to 4.5 km from each portal. Dump areas for over ground
excavation in barrage shall be at a maximum distance of 1 km and power
house area at a distance of 4.50 km.. Dump areas chosen are located much
above the river/nallah banks and are provided with suitable retaining walls
etc. Bull dozers shall be deployed in dump areas for spreading and
compaction of dumped material.
11.1.10 PRE-CONSTRUCTION FACILITIES
Pre construction facilities such as land acquisition for labour huts, plant
areas, stores, residential and non residential buildings, approach roads,
construction of bridges and explosive magazine in the valley shall be made
available to facilitate construction of the project.
11.1.11 EQUIPMENT PROVISION
Since main works of the project are proposed to be executed on contract
basis except the required infrastructural facilities as such the necessary
provision of machinery like material trucks, trailors, cement carriers, motor
grader and road rollers etc. has been made under Q-special-T&P, for
carrying out the works of infrastructural facilities. Provisions for personal
carriers, ambulance and field workshop equipment have also been made
under project estimate.
11.2 CONSTRUCTION SCHEDULE
The project has been proposed to be completed in 4½ years. Method of execution of
various components and selection of equipments have been done with the object of
commissioning first hydro unit by the end of 3 rd month of the fifth year, the second unit

y the end of 5 th month of fifth year and the third unit by the end of 6 th month of fifth
year.
11.2.1 INFRASTRUCTURAL
It is proposed that all infrastructural works on the project comprising roads, buildings,
adits, workshops, stores, utility works, surveys, development of quarries, leveling of area
for installation of equipment and plants, pre-qualification of tenders, award of contracts,
detailed design of components and other preliminary works shall be continued upto 4 th
year of project execution.
11.2.2 DIVERSION BARRAGE
i) Coffer dam:- During 7 th month of project construction.
ii) Excavation of barrage Const. Ist stage
From 8 th month to 13 th month of project construction.
iii) Concreting of barrage Ist stage
From 10 th month to 21 st month.
iv) Coffer dam 2 nd stage
During 22 nd month.
v) Excavation of barrage 2 nd stage
From 23 rd month to 31 st month.
vi) Concreting of barrage 2 nd stage
From 32 nd month to 36 th moth.
11.2.3 INTAKE STRUCTURE
Excavation:- From 22 nd month to 25 th month.
Concreting:- From 26 th month to 37 th .
11.2.4 DESILTING TANK

Excavation:- From 7 th month to 15 th month.
Concreting:- From 13 th month to 36 th month.
11.2.5 MECHANICAL WORKS FOR THE ABOVE FEATURES
From 19 th to 48 th months.
11.2.6 HEAD RACE TUNNEL
Excavation from RD 0 to 3440m and 7000m to 3440m
From 4 th month to 37 th month.
Concreting from RD 0 to 3440m and 7000m to 3440m.
From 38 th month to 46 th month.
Grouting :- From 47 th month to 48 th month.
From RD 700m to 9150m and 11300m to 9150m.
Excavation from 13th month to 33rd month.
Concreting from 34 th month to 39 th month.
Grouting from 40th month to 41 st month.
11.2.7 SURGE SHAFT
Excavation from 13th month to 23rd month.
Concreting:- From 24 th month to 31 st month.
Grouting & Clean up:- From 32 nd month to 36 th month.

11.2.8 PRESSURE SHAFT
Excavation:- From 13 th month to 21 st month.
Concreting& linner:- From 22nd month to 38th months.
11.2.9 POWER HOUSE
Excavation:- From 13 th month to 26th month.
Concreting:- From 27th month to 40th months.
11.2.10 TAIL RACE TUNNEL
Excavation:- From 19 th month to 22nd month.
Concreting:- In 43 rd month.
11.2.11 INSTALLATION, TESTING AND COMMISSIONING
Installation of hydro units shall be started from the 32 nd month. A period of
3 months for testing and commissioning of each unit has been provided with
first unit proposed to be commissioned in 51 st month and second unit in 53 rd
month of construction and 3 rd unit in 54 th month thus completing the
construction of the project as a whole in 54 month duration.

PARA DESCRIPTION PAGE
12.0 GENERAL XII-1
12.1 BASIS OF THE ESTIMATE XII-1
12.2 DESCRIPTION OF ITEMS XII-2
12.2.1 UNIT-I CIVIL WORKS XII-2 TO XII-4
12.2.2 UNIT-III ELECTRICAL WORKS XII-5
12.2.2.1 P-PRODUCTION XII-5
12.2.2.2 T-TRANSMISSION XII-5
12.3 DETAILED ESTIMATE OF COST XII-5 TO XII-34

12.0 GENERAL
12.1 BASIS OF ESTIMATE
CHAPTER – XII
COST ESTIMATES
The estimate of Unit-I Civil Works has been prepared to arrive at the capital
cost of the Chhatru Hydel Project. The price level of the estimate Oct.,
2003. It is presumed that major civil works will be executed on contract
basis. The cost estimate does not include following items:-
- Escalation after Oct., 2003
- Interest during construction.
Detailed estimate of cost for Unit-I civil works is based mainly upon
various designs/drawings finalised for appurtenant structures and the rates
for principal items of works as per guide lines furnished by CEA vide letter
dt. 24 th Oct. 2003. A provision of 3% has been made for contingencies for
C-works under Unit-I works. Guidelines for preparation of project estimate
issued by CWC during March, 1997 have also been followed for
formulation of the estimate.
12.2 DESCRIPTION OF ITEMS
12.2.2 UNIT-I CIVIL WORKS
Under the heading civil works provision has been made for various
components of the project as detailed here under;

A-Preliminary
Under this sub-head, provision of Rs. 501.25 lac has been made for surveys
and investigations conducted or 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 components, colonies, offices and store complexes and
compensation for trees and standing crops. Provision for forest trees in the
project area has also been included. A L.S.provision for Rs. 350.00 lac has
been made under this sub-head in the absence of data , which could not be
collected being project area under snow cover during winter.
C-Works
This covers the cost of civil engineering structures comprising coffer dam
and diversion barrage. The cost on this sub head worksout to Rs.9572.95
Lac.
J Power Plant
This covers the cost of Intake ,desanding chamber, head race tunnel, surge
shaft, pressure shaft, underground power house complex and tail race
tunnel. The total cost works to be Rs. 20057.42 lac.

K- Buildings
Buildings both residential and non- residential have been grouped separately
under permanent and temporary catagories. Under the permanent catagories,
all those buildings have been included which will be subsequently utilised
for the operation and maintenance of project whereas, under the temporary
category, credit to the extent of 15% has been given to the project on
account of resale thereof. The cost has been worked out on basis of plinth
area rates as notified by HPPWD.. A provision of Rs.1341.94 lac has been
made under this sub-head.
X-Environment & Ecology
A provision of Rs.470 lac has been made under this sub-head maintaining
and improving the environmental status of the project area and fir
afforestation of affected area.
II-Establishment
A provision under this head has been made for Rs. 2760.24 lac i.e. 8% of I-
Works.
V-Receipts & Recoveries
This provision covers estimated recoveries by way of resale or transfer of
special T&P and temporary buildings. The amount thus works out to Rs.
328.84 lac only.

M-Plantation
This covers the cost of plantation and protection of plants to be planted
along project roads, colonies and in project area. Accordingly a provision of
25.00 lac has been made under this sub-head.
O- Miscellaneous
A provision of Rs. 966.77 lac has been made for meeting cost of various
items listed therein.
Q-Special T&P
As the major civil works have been proposed to be got done on contract
basis. Machinery required for departmental activities like infrstructural
works, there subsequent repair/ maintenance and supervison works has
mainly been includeed under theisd sub-head. A provision of Rs. 496.71 lac
has been made under this sub-head.
R-Communication
A provision of Rs. 656.70 lac under this sub-head covers the cost of roads.
The road width have been planned to cater to the anticipated traffic
including movement of heavy trailors. Cost of roads is based on the rates
as notified by State HPPWD .
A provision of Rs. 38679.07 Lac.has been made to cover the costs under
this subhead.

12.2.2 UNIT-III ELECTRICAL WORKS
12.2.2.1 P-PRODUCTION
Cost of generating plants and equipments is based on current budgetory
prices. Prices of auxiliary equipments and services are based on historical
prices.Excise duty has been considered @ 16% of the component. CST,
Insurance and transport to site has been taken @ 6% of the cost of
respective component. Erection and commissioning charges have also been
taken @ 10% as per experience gained on similar installations in the state. A
provision of Rs. 13612.06 lacs has been made to cover the costs under this
sub-head.
12.2.2.2 T-TRANSMISSION
It is proposed to evacuate the power generated at Chhatru project by
LILOing of 220 KV D/C line from Khoksar to 400 KV Pooling point at
Tandi which is proposed in this basin. Beyond this point the evacuation will
be through 400 KV D/C net work to Panarsa Poolung in sub station of
PGCIL. The cost is based on detailed analysis on actual requirement and
amounts to Rs. 844.68 lacs.
12.3 DETAILED ESTIMATE OF COST
Detailed estimate of cost as explained in above paras is given in succeeding
paras.

PARA DESCRIPTION PAGE
13.0 GENERAL XIII-1
13.1 CAPITAL COST OF THE PROJECT XIII-1 TO XIII-2
13.2 ECONOMIC JUSTIFICATION XIII-2
13.3 CAPITAL STRUCTURE XIII-3
13.4 REVENUE ANTICIPATION XIII-3
13.5 REPAYMENT PERIOD XIII-3
13.6 COST PER MW XIII-3
13.7 INTEREST DURING CONSTRUCTION XIII-4
13.8 ENERGY AVAILABLE FOR SALE XIII-4
13.9 RATE OF DEPRECIATION XIII-4
13.10 OPERATION AND MAINTENANCE
CHARGES
XIII-4
13.11 CALCULATION OF TARRIF XIII-5
13.12 INDIRECT BENEFIT XIII-6
13.13 MERITS OF THE PROJECT XIII-6
13.14 CONSTRUCTION SCHEDULE XIII-6
ANNEXURE-13.1-(a)
TO 13.1(c)
ABSTRACT OF COST ESTIMATES OF
CIVIL WORKS, P-PRODUCTION & T-
TRANSMISSION
ANNEXURE-13.2 YEARWISE PHASING OF FUNDS XIII-10
ANNEXURE-13.3 CALCULATION OF INTEREST DURING
CONSTRUCTION AT POWER HOUSE
BUS BARS
ANNEXURE-13.4 WEIGHTED AVERAGE DEPRECIATION
ANNEXURE-13.5 LEVELLISED TARRIF OF ENERGY FOR
90% DEPENDABLE YEAR AT POWER
HOUSE BUS BARS.
XIII-7 TO XIII-9
XIII-11
XIII-12
XIII-13TO XIII-
14

13.0 GENERAL
CHAPTER-XIII
ECONOMIC EVALUATION
Chhatru Hydro- electric Project has been contemplated as a run of the river
development on Chandra River in Lahul & Spiti district of Himachal
Pradesh. This project is estimated to cost Rs. 531.36 Cr. at price level of
Oct,,2003. The cost at power bus bar worksout to Rs. 522.91 Cr.Abstract
of cost estimate of Civil works, P-Production and T-Transmission have been
given as per Annexure13.1-(a) to13.1-(c). Year wise phasing of expenditure
for capital required on this project is given as per Annexure-13.2. Interest
during construction has been considered as per Annexure- 13.3.

Depreciation on Civil and Electrical works has been worked out as 3.00% as
per Annexure-13.4.The levelised tariff of energy generated at power house
bus bars has been worked out as Rs. 2.28 per unit during 90% dependable
year as per Annexure-13.5. The cost of energy in the Ist year of operation
worksout to Rs. 2.89 per unit.
13.1 CAPITAL COST OF THE PROJECT
Abstract of the capital cost of the project, to the price level of Oct., 2003 is
as under: -
S.No. Description Amount
(Rs. in Cr.)
1. Unit-I Civil works 386.79
2. P-Production (Electrical works) 136.12
Total Generation Cost 522.91
3. Transmission 8.45
Grand total 531.36
13.2 ECONOMIC JUSTIFICATION
PGCIL will construct a Parbati pooling point at down stream of Parbati
stage-III HEP at Pnarsa and which will cater the power of Chhatru HEP
through 220 KV D/C to Khoksar and then to 400 KV Tandi pooling point..
As laid down to CEA and CERC Guidelines, economic justification of a

hydel project is to be done by comparing cost of alternative sources
of energy in that region. The levelized tariff of this project in 90%
dependable year works out as Rs. 2.28/ unit at power use bus bars as per
Annexure-13.5 ).This project will provide power at cheaper rates in
comparison to thermal power rate which , at present is more than Rs.3.75 /
unit. Additionally this project will provide pollution free power for years
together at much cheaper rates considering the escalation in coal prices for
Thermal Power.
13.3 CAPITAL STRUCTURE
Capital structure has been assumed as 70% debt from Financial Institution
and 30% equity from Govt.
13.4 REVENUE ANTICIPATION
Power tariff for supply of power at powerhouse bus bars has been assumed
as Rs. 2.75 per unit. Revenue has been assessed accordingly for 90%
dependable year as Rs. 125.32 cr.
13.5 REPAYMENT PERIOD
.
Normally, the leading financial institutions in India prescribe a repayment
period of 15 years including 3 to 4 years moratorium period. A period of 12
years has therefore been taken into account, as repayment period in fixation
to tariff.

13.6 COST PER MW
The estimated cost of the project at Oct 2003 price level is Rs. 531.36 Cr.
including transmission and Rs. 522.91 Cr. at power bus bar for an installed
capacity of 108W. This gives a capital cost of Rs. 4.92 Cr.per MW of
installed capacity including cost of transmission and Rs. 4.84 Cr. per MW
at generation. At present price level, the cost of medium hydro-electric
project at Rs. 6.00 crore per MW is considered to be reasonable. From this
criterion, the cost per MW for Gharopa Hydel Project is reasonable making
the project suitable for exploitation.
13.7 INTEREST DURING CONSTRUCTION
The detail of expenditure during the construction period and the calculation
of interest during construction have been shown in Annexure-13.3. It is
seen that IDC @ 10.00 % on loan works out to Rs. 62.24. at power house
bus bars.
13.8 ENERGY AVAILABLE FOR SALE
As per power studies of the project, the total energy generation in 90%
dependable year has been arrived at 455.72 MUs. As per Govt. of India
Guide Lines, an auxiliary consumption @ 0.7% and transformation losses
@ 0.5% have been considered at power house bus bars .
13.9 RATE OF DEPRECIATION
As per the revised guide lines circulated by Govt. of India, Ministry of
Power, Vide notification dated 29 th March, 1994, the weighted rate of
depreciation has been worked out on the basis of straight line formula. The

ate of depreciation works out to 3.00% of the project cost as per
Annexure-13.5.
13.10 OPERATION AND MAINTENANCE CHARGES
As per the guide lines of Ministry of Power, Govt. of India, the Operation
and Maintenance charges inclusive of insurance have been taken as 1.50 %
of the capital cost.
11 CALCULATION OF TARIFF
Calculation of tariff for primary energy during 35 years of operation for
90% dependable year has been worked out as per GOI notification shown in
Annexure-13.5 comprising the following.
i) Interest on loan from PFC @ 10.00 % p.a.
ii) Interest on working capital @ 9.75 % required for 2 months of
average billing for sale of electricity and operation and maintenance
expenses for one month.
iii) O&M charges including insurance charges @ 1.5% p.a.
iv) Income tax @ 35% and surcharge @ 10% on income tax has been
considered.
v) Discounting rate @ 12% for tariff calculation .
vi) Free power for home state @ 12%.

At power house bus bar, it will be seen that sale rate of power shall be Rs.
2.89 per unit during Ist year of operation and Rs. 1.37 per unit during 13 th
year i.e after repayment of loan. The levelised tariff rate works out to Rs.
2.28 per unit at power house bus bars.
13.12 INDIRECT BENEFIT
Besides providing pollution free power at a cheap rate to the Northern Grid;
discussed in preceding paras, this project, located in Lahul & Spiti district of
HP will help in the overall development of the people of the area..
Employment to skilled/non-skilled labour of the area, industrial and
economic development are additional benefits from this project. Keeping
these points in view, this project merits consideration for an implementation.
13.13 MERITS OF THE PROJECT
Gharopa HEP (108 MW) is a down stream development of proposed
Khoksar (90 MW). Following are the strengths and weaknesses of the
project.
i) Project sites are located on the right bank of existing motorable
road.
ii) No resettlement of people required for construction of project.
iii) Construction material is locally available.
iv) Almost all the major sites of the project viz. Diversion, inlet portal
and adit portal of HRT and power house are connected with NH-21.
v) The levellised tariff works out to be Rs. 2.28 per unit at power
house bus bar which is on lower side.

13.14 CONSTRUCTION SCHEDULE
The construction of the project has been proposed to be completed in four
and half years of period. The construction schedule has been presented in
drawing No. Gharopa-FR-8 (attached).

CONSTRUCTION ORGANISATION
PRE CONSTRUCTION STAGE
FOR FIRST ONE YEAR
S.E. (C/M ) 1/2
E.E.-I (C) E.E.-II (C) E.E.-III (M) E.E.-IV (E)
Land Acquisition Detialed surveys, R/M of w / shop, Arrangement of
c/o residential & non collection of G&D vehicles & procure - construction power
residential buildings data, c/o adits & ment of stores & electrification of
and project roads. W/shop facilities. Equipments. Resd. Buildings.
CONSTRUCTION STAGE
Chief Enginer (C) Chief Enginer (E)
Construction 1/2 Construction 1/3
Four year Four year
S.E.-Admn.& Works. S.E.-Admn&Works.
(C/M) ( E)
E.E.Admn. E.E.Works E.E.Admn. E.E.Works
(C/M) (C/M) (E) (E)
S.E.-Civil. -I S.E.-II (M ) 1/2 S.E.-P/H( E) S.E.T(E)1/2
A.O. C/M A.O. C/M A.O. C/M A.O. C/M
E.E. I (C) E.E.I I (C) E.E.III (C) E.E.IV (C) E.E.I (M) E.E.II (M) E.E. I (E) E.E.I I (E) E.E.III (E) E.E.IV (E) E.E.I (E) E.E.II (E)
Barrage Rana aqueduct,HRT Surge shaft Power house & Tail Work shop, Pen stock fabrication, Power house , Sub station & Testing & Planning &
Intake & Adits. & pressure Race works. Transport & fabrication & errection Works. Switch yard. commissioning Monitoring. Transmation & P L C C
& Control survey, shaft Colony at Snail/ Stores. of Gates, hoist & Const.
D/Tank colony & road maint.
G/D data collection
& Silt lab.
civil works Anti Roads trash racks etc.
HIMACHAL PRADESH STATE ELECTRICITY BOARD
DIRECTOR PLANNING CIRCLE NO.I
SAWRA KUDDU 110 MW
CONSTRUCTION ORGANISATION CHART
DSGN. CHKD. RECM.
DRWN. SUBM. APPED.
SUNDERNAGAR , APRIL-2003 DRG.NO.SAWRA KUDDU-PR-19

DESIGN ORGANISATION
PRE CONSTRUCTION STAGE
FOR FIRST HALF YEAR
Director-D(C)1/4 Director-D(E)1/4
E.E.-I(C) E.E.-I(E)
Design of bridges &
Roads, Preparation &
processing of tenders
etc., infrastructure
facilities like adits,
w/shop & stores
Const. power,
preliminary enquiry
for generating
equipment &
turbines etc.
Chief Engineer (C/M) Chief Engineer(E)
Construction 1/3 Construction 1/3
S.E. Admn & Four year Two year
Works(C/M)
Director Design C/M Director Design (E) S.E.Admn & Works
E.E.Works E.E.Works Thrre year (E)
(C/M) (C/M)
E.E.I(C/M) E.E.II(C/M) E.E.III(C/M) E.E.IV(C/M) E.E.I(E) E.E.II(E) E.E.III(E) E.E.IV(E)
Design of
infrastructure,
job facilities,
preparation &
prosesing of
tenders,
estimation,
scheduling
const.
material
Monitoring cost
control & PERT/CPM
planning, mech.
desining of gates,
hoisting, trash rack &
penstock
instrumentation & soil
testing
Specification
design &
const. design
of barrage,
intake
structure,
D/tanks.
Construction Stage
Specification,
design & const.
design of HRT,
S/shaft, Power
House & Tail
race
Specification,
design &
tenders of
Generation
equipments.
Specification,
design & tenders
of Power house
auxiliaries.
Design &
procurement
of
Transmission
lines &
equipments
DSGN. CHKD. RECM.
DRWN. SUBM. APP.
E.E.Admn. E.E.Works
(E) (E)
Specification,
design & const.
design of substation
& switch
yard
HIMACHAL PRADESH STATE ELECTRICITY BOARD
DIRECTOR PLANNING CIRCLE NO.I
SAWRA KUDDU 110 MW
DESIGN ORGANISATION CHART
SUNDERNAGAR , APRIL-2003 DRG.NO.SAWRA KUDDU--PR-18

S No. Description Quantity Unit 1st Year 2nd Year 3rd Year 4th Year 5th Half year
A PRE-CONSTRUCTION
1 INFRASTRUCTURE
i) a) Preliminary Job
ii) b) Land Acquisition Job
iii) c) Procurement Job
2 AGGREGATE PROCESSING Job
B WORK SCHEDULE
1. Diversion Barrage
i) Coffer dam Ist Stage Job
ii) Excavation of barrage 1st stage 325300 Cum
iii) Concreting of barrage 1st stage 54166 Cum
iv) Coffer dam 2nd stage Job
v) Excavation 2nd stage 325300 Cum
vi) Concreting of 2nd stage 54166 Cum
2. Iuntake structure
i) Excavation 7890 Cum
ii) Concreting 1830 Cum
3. Desilting Tank
i) Excavation 239450 Cum
ii) Concreting 51900 Cum
4. Mechanical works for the above features
5. HRT
a) Excavation from RD 0 to 3500 104760 Cum
i) Concreting 18170 Cum
ii) Grouting & clean up Job
b) Excavation from RD 6500 to 3500 89240 Cum
i) Concreting 15480 Cum
ii) Grouting & clean up Job
6 Surge shaft
i) Excavation 15900 Cum
ii) Concreting 3977 Cum
iii) Grouting & cleanup Job
7. Pressure Shaft
i) Excavation 29900 Cum
ii) Concreting & steel lining 3720 Cum
8. Power house
i) Excavation 61000 Cum
ii) Concreting
a) Sub-structure 9000 Cum
b) Super structure 8000 Cum
9. Auxilliary surge shaft
and Tail Race Tunnel
i) Excavation 45900 Cum
ii) Concreitng 5100 Cum
10. Installation, testing
Unit No.I Job
Unit No.II Job
Unit No.III Job
Months 3 6 9 12 15 18 21 24 27 30 33 36 39 42 45 48 51 54

S. NO. DESCRIPTION UNIT RATE
A EXCAVATION
1 Common excavation Cum 125.00
2 Excavation in hard rock Cum 300.00
3 Excavation in rock in tunnel Cum 1000.00
4 Surge shaft excavation
Without raise climber Cum 1200.00
B
C
D
E
F
APPENDIX-A
RATES FOR MAJOR ITEMS OF CIVIL WORKS
With raise climber Cum 1500.00
Rock support
Rock bolting (including drilling)
25 mm RM 400.00
32 mm RM 525.00
36mm RM 625.00
Shotcret rate without wiremesh Cum 4000.00
Wiremesh Sq M 200
Steel supprt
Earth dam/Rockfill dam
MT 42000.00
1 Rate per cum earth fill in Dam (for lead 1 km.
2 Rate per cum rock fill in Dam (for lead 1 km.)
Cum 142.00
From excavated material Cum 156.00
From quarry Cum 318.00
3 Rate per cum of impervious core in Dam( lead 1 km.) Cum 154.00
4 Inverted filter (for lead 1 km) Cum 701.00
5 Stone pitching (for lead 1 km Cum 581.00
6 Incremental rate for each additional lead of 1 km. or par Cum 20.00
Concreteing (including form work)
1 Concrete lead 10 km (For lead of 10 Km. for aggegate quarry)
M 25 Cum 3610.00
M 20 Cum 3390.00
M 15 Cum 2930.00
M 10 Cum 2560.00
2 Incremental rate for each additional lead of 5 km. or par Cum 100.00
3 Concrete Cut-off wall Sq m 20000.00
4 Precast lagging including cost of reinforcement Cum 7000.00
5 Concrete linging in DT & HRT ( M 20)
Reinforcement Steel and Steel and Structural Steel
Cum 4000.00
1 Reforcement MT 27000.00
2 Penstock liner MT 70000.00
Hydro-Mechanical Work
1 Radial gate MT 100000.00
2 Sluicegate MT 100000.00
3 Stoplog gate MT 60000.00
4 Trashrack MT 50000.00
5 Embedded parts MT 50000.00
6 Hoist (Based on lifting capacity) MT 100000.00

APPENDIX-B
RIVER DIVERSION ARRANGEMENT
COFFER DAM (U/S & U/S)
S. NO.
1.0 Surface Excavation
DESCRIPTION UNIT QTY. RATE (Rs.)
Amt.in
Lac
1.1 Common excavation Cum 25000 125.00 31.25
2.0 Embankment Construction
2.1 Earth/rock rill Cum 50000 156.00 78.00
2.1 Impervious core Cum NIL
2.3 Filter Cum NIL
3.0 Concrete
3.1 M 10 Cum 7600 2560.00 194.56
3.2 M 15 Cum NIL
3.3 Concrete cut-off wall if required Cum NIL
Sub-Total (A) of 1 to 3
4.0 Miscellaeneous
4.1
Various Miscellaneous works like wiremesh/steel fibre
reinforcement , drilling & grouting, etc. (0.0 to 0.50% of Sub-
Total (A) dpending upon the iste conditions & type of
303.81
structure)
0.50% 303.81 1.52
Sub-Total (B) of 1 to 4 305.33
5.0 Dewatering (3% of Sub-Total (B)
6.0 Contingencies (3% of Sub-Total (B) except on
3% 305.33 9.16
L.S. items) 3% 305.33 9.16
7.0 Work Charges Establishment (2% of Sub-Total(B)
except on L.S. items)
2% 305.33 6.11
Total of 1 to 7 329.76

BARRAGE, CELLULAR WALL, RETAINING WALL & FISH LADDER
S. NO. DESCRIPTION UNIT QTY. RATE (Rs.)
Amt.in
Lac
1.0 Surface Excavation
1.1 Common excavation Cum 325300 125.00 406.63
1.2 Rock Excavation Cum 325300 300.00 975.90
2.0 Support System
2.1 Rock bolts M 300.00 525.00 1.58
2.2 Shotcreting Cum 65.00 4000.00 2.60
3.0 Fill Works
3.1 Compacted Earthfill Cum NIL
3.2 Compacted clay fill Cum 3000 156.00 4.68
4.0 Concrete including form work
4.1 Precast Concrete Block M-20 Cum 3500 7000.00 245.00
4.2 M-15 Cum 26910 2930.00 788.46
4.3 M-20 in Upstream Floor, road bridge Cum 7790 3390.00 264.08
4.4 M-25 downstream floor and spillway glacis of barrage, piers
& breast walls, trunion beam, fish ladder, retaining wall if
required. Cum 70133 3610.00 2531.80
4.5 Concrete lining in Channel Sides M-20 Cum NIL
5.0 Steel
5.1 (i) Reinforcement Steel Ton 7800 27000.00 2106.00
5.2 (ii) Structrul Steel Ton 1200 70000.00 840.00
6.0 Stone Pitching
Cum. 4000 581.00 23.24
Sub-Total (A) of 1 to 6 8189.97
7.0 Miscellaeneous
7.1
Various Miscellaneous works like Site Clearance, drilling &
grouting, PVC pipes & waterstops, Metal works, Launching
Apron, Crate Work, Filter Below C.C. Block, Masonary
Works, Archetectural Works (4-5% of Sub-Total (A)
depdnding upon the site conditions & type of structure. 4-5% 0.05 8189.97 368.55
Sub-Total (B) of 1 to to 7 8558.51
8.0 Instrumentation ( 1% of Sub-Total (B) 1% 8558.51 85.59
9.0 Dewatering (2% of Sub-Total (B) 2% 8558.51 171.17
10.0 Contingencies (3% of Sub-Total (B) except on 3% 8558.51 256.76
L.S. items)
11.0 Work Charges Establishment (2% of Sub-Total(B) 2% 8558.51 171.17
except on L.S. items)
Sub-Total (B) of 1 to to 11 9243.19

INTAKE STRUCTURE
APPENDIX-C
S. NO. DESCRIPTION UNIT QTY.
RATE
(Rs.) Amt.in Lac
1.0 Surface Excavation
1.1 Common excavation Cum 1050 125.00 1.31
1.2 Rock excavatin Cum 6840 300.00 20.52
2.0 Underground excavation Cum NIL
3.0 Support System
3.1 Rockbolts M NIL
3.2 Steel Rib Supports Ton NIL
3.3 Shotrreting Cum NIL
3.4 Concrete lagging if required Cum. NIL
4.0 Concrete
4.1 M-10 Cum 100 2560.00 2.56
4.2 M 15 Cum NIL
4.3 M 20 Cum NIL
4.4 M 25 Cum 1730 3610.00 62.45
5.0 steel
5.1 (i) Reinforcing Steel Ton 173 27000 46.71
5.2 (Ii) Structural Steel Ton 100 27000 27.00
Sub-Total (A) of 1 to 5 160.56
6.0 Miscellaeneous and Ancillary Works
6.1 Various Miscellaneous works like
wiremesh/steel fibre reinforcement , drilling &
grouting, PVC pipes for drainge, slope
protection works etc. (1-2% of Sub-Total (A)
dpending upon the iste conditions & type of
structure) 1 to 2% 1.50% 160.56 2.41
Cum
Sub-Total (B) of 1 to 6 162.96
7.0 Instrumentation ( 1% of Sub -Total )B) 1% 162.96 1.63
8.0 Dewatering (1% of Sub-Total (B) 1% 162.96 1.63
9.0 Contingencies (3% of Sub-Total (B) except
on L.S. items) 3% 162.96 4.89
10.0 Work Charges Establishment (2% of Sub-
Total(B) except on L.S. items) 2% 162.96 3.26
Total of 1 to 10 337.34

DESANDING CHAMBER
S. NO. DESCRIPTION UNIT QTY. RATE (Rs Amt.in Lac
1.0 Surface Excavation
1.1 Common excavation Cum NIL
1.2 Rock excavatin Cum NIL
2.0 Underground excavation Cum 239450 1000.00 2394.50
3.0 Support System
3.1 Rockbolts M 69500 625 434.38
3.2 Steel Rib Supports Ton 605 42000 254.10
3.3 Shotrreting Cum 6720 4000 268.80
3.4 Concrete lagging if required Cum. NIL
4.0 Concrete
4.2 M 15 Cum 17100 2930.00 501.03
4.3 M 20 Cum 34800 4000.00 1392.00
4.4 M 25 Cum NIL
5.0 Reinforcing Steel Ton 350 27000 94.50
Sub-Total (A) of 1 to 5 5339.31
6.0 Miscellaeneous and Ancillary Works
6.1
Various Miscellaneous works like
wiremesh/steel fibre reinforcement , drilling &
grouting etc. (3-4% of Sub-Total (A) dpending
upon the iste conditions & type of structure) 3 to 4% 3.50% 5339.31 186.88
Sub-Total (B) of 1 to 6 5526.18
7.0 Instrumentation ( 1% of Sub -Total )B) 1% 5526.18 55.26
8.0 Dewatering (2% of Sub-Total (B) 2% 5526.18 110.52
9.0 Contingencies (3% of Sub-Total (B) except
on L.S. items) 3% 5526.18 165.79
10.0 Work Charged Establishment (2% of Sub-
Total(B) except on L.S. items) 2% 5526.18 110.52
Total of 1 to 10 5968.28

HEAD RACE & TAIL RACETUNNEL
S. NO. DESCRIPTION UNIT QTY.
RATE
(Rs.) Amt.in Lac
1.0 Surface Excavation
1.1 Common excavation Cum 100 125.00 0.13
1.2 Rock excavatin Cum 400 300.00 1.20
2.0 Underground excavation Cum 239900 1000.00 2399.00
3.0 Support System
3.1 Rockbolts M 92700 625 579.38
3.2 Steel Rib Supports Ton 1342 42000 563.64
3.3 Shotrreting Cum 10800 4000 432.00
3.4 Concrete lagging if required Cum. NIL
4.0 Concrete
4.2 M 15 Cum 22400 2930.00 656.32
4.3 M 20 Cum 16350 4000.00 654.00
4.4 M 25 Cum NIL
5.0 Reinforcing Steel Ton 795 27000 214.65
Sub-Total (A) of 1 to 5 5500.31
6.0 Miscellaeneous and Ancillary Works
6.1 Various Miscellaneous works like
wiremesh/steel fibre reinforcement , drilling &
grouting, PVC pipes for drainge etc. (7-8% of
Sub-Total (A) dpending upon the iste
conditions & type of structure) 7 to 8% 8% 5500.31 440.02
Sub-Total (B) of 1 to 6 5940.33
7.0 Instrumentation ( 1% of Sub -Total )B) 1% 5940.33 59.40
8.0 Dewatering (2% of Sub-Total (B) 2% 5940.33 118.81
9.0 Contingencies (3% of Sub-Total (B) except
on L.S. items) 3% 5940.33 178.21
10.0 Work Charges Establishment (2% of Sub-
Total(B) except on L.S. items) 2% 5940.33 118.81
Total of 1 to 10 6415.56

SURGE SHAFT
S. NO. DESCRIPTION UNIT QTY.
1.0 Surface Excavation
1.1 Common excavation Cum NIL
1.2 Rock excavatin Cum NIL
RATE
(Rs.) Amt.in Lac
2.0 Underground excavation
2.1 Surge Shaft excavation Cum 15900 1200 190.8
2.2 Surge shaft excavation with raise borer Cum NIL
2.3 Concrete lagging if required Cum NIL
3.0 Support System
3.1 Rockbolts M 9100 525 47.775
3.2 Steel Rib Supports Ton 162 42000 68.04
3.3 Shotcreting Cum 500 4000 20
4.0 Concrete
4.1 M 20 Cum 3840 3390 138.62
4.2 M 25 Cum 137 3610 4.6443
5.0 Steel Works
5.1 Reinforcing Steel Ton 263 27000 71.01
5.2 Steel liner Ton 92 70000 64.4
Sub-Total (A) of 1 to 5 605.29
6.0 Miscellaeneous
6.1 Various Miscellaneous works like site
clearance , drilling & grouting,wire mesh
reinforcement, Airpipess, Lift arrangement,
other steel works etc. (1-2% of Sub-Total (A)
dpending upon the iste conditions & type of
structure) 1 to 2% 1.50% 605.29 9.08
Sub-Total (B) of 1 to 6 614.37
7.0 Instrumentation ( 1% of Sub -Total )B) 1% 614.37 6.14
8.0 Dewatering (2% of Sub-Total (B) 2% 614.37 12.29
9.0 Contingencies (3% of Sub-Total (B) except
on L.S. items) 3% 614.37 18.43
10.0 Work Charges Establishment (2% of Sub-
Total(B) except on L.S. items) 2% 614.37 12.29
Total of 1 to 10 663.52
Add cost provision for auxilliary s/shaft @
30% of cost of main surge shaft 30% 663.52 199.057
G Total 862.58

PRESSURE SHAFT
S. NO. DESCRIPTION UNIT QTY.
RATE
(Rs.) Amt.in Lac
1.0 Underground excavation Cum 29900 1000.00 299.00
2.0 Support System
2.1 Rock bolts M 6200 525.00 32.55
2.2 Steel ribs Support Ton NIL
2.3 Shotcreting Cum 7970 4000.00 318.80
3.0 Concrete
3.1 M 15 backfill concrete Cum 3720 2930.00 109.00
4.0 Penstock steel liners Ton 1460 70000 1022.00
Sub-Total A) of 1 to 4 2643.93
5.0 Miscellaeneous and Ancillary Works
5.1 Various Miscellaneous works like
wiremesh/steel fibre reinforcement , drilling &
grouting, PVC pipes for drainge, slope
protection works etc. (2-3% of Sub-Total (A)
dpending upon the iste conditions & type of
structure) 2- 3% 2.50% 2643.93 66.10
Sub-Total (B) of 1 to 5 2710.02
6.0 Instrumentation ( 1% of Sub -Total )B) 1% 2710.02 27.10
7.0 Dewatering (1% of Sub-Total (B) 1% 2710.02 27.10
8.0 Contingencies (3% of Sub-Total (B) except
on L.S. items) 3% 2710.02 81.30
9.0 Work Charges Establishment (2% of Sub-
Total(B) except on L.S. items) 2% 2710.02 54.20
Total of 1 to 9 2899.73

POWER HOUSE COMPLEX
S. NO. DESCRIPTION UNIT QTY.
RATE
(Rs.) Amt.in Lac
1.0 Surface Excavation
1.1 Common excavation Cum
1.2 Rock excavation Cum 1000 300.00 3.00
2.0 Underground excavation if underground
Power House
2.1 Excavation of P/H cavern, transformer cum
MIV cavern and draft tube gate Cum 60000 1000.00 600.00
3.0 Support System
3.1 Rockbolts M 30000 625 187.50
3.2 Steel Rib Supports Ton 300 42000 126.00
3.3 Shotrreting Cum 1300 4000 52.00
3.4 Concrete lagging if required Cum
4.0 Concrete
4.1 M 15 Cum NIL
4.2 M 20 Cum 17000 4000 680.00
4.3 M 25 Cum. NIL
5.0 Reinforcing Steel Ton 1200 27000 324.00
6.0 Structural Steel for roof trusses etc. Ton NIL
Sub-Total A) of 1 to 6 1972.50
7.0 Miscellaeneous and Ancillary Works
7.1 Various Miscellaneous works like site
clearance,wiremesh/steel fibre reinforcement
, drilling & grouting, flooring, water proofing
system, swellex anchor, doors & windows,
painting , lift arrangement, architectural
works, other metal works etc. (4-5% of Sub-
Total (A) dpending upon the iste conditions &
type of structure)
4 to 5 % 5% 1972.50 98.63
Sub-Total (B) of 1 to 7 2071.13
8.0 Instrumentation ( 1% of Sub -Total )B) 1% 2071.13 20.71
9.0 Dewatering (2% of Sub-Total (B) 2% 2071.13 41.42
10.0 Contingencies (3% of Sub-Total (B) except
on L.S. items) 3% 2071.13 62.13
11.0 Work Charges Establishment (2% of Sub-
Total(B) except on L.S. items) 2% 2071.13 41.42
Total of 1 to 11 2236.82

SWITCHYARD
S. NO. DESCRIPTION UNIT QTY.
RATE
(Rs.) Amt.in Lac
1.0 Under ground Excavation
1.1 Common excavation Cum
1.2 Rock excavation Cum 11696 1000.00 116.96
2.0 Supports System
2.1 Rockbolts M 1200 525 6.30
2.2 Steel ribs suppots (if required) Ton 70 42000 29.40
2.3 Shotcreting Cum
3.0 Earth work in filling if required
4.0 Concrete
4.1 M 15 Cum 1400 2930.00 41.02
4.2 M 20 Cum 100 3390.00 3.39
4.3 M 25 Cum. NIL
5.0 Reinforcing Steel Ton 43 27000 11.61
6.0 Stone/Brick Masonary Cum NIL
Sub-Total (A) of 1 to 6 208.68
7.0 Miscellaeneous
7.1 Various Miscellaneous works like Site
clearence, PVC pippes,Control block building
work like flooring,doors,windowes etc.
including wate supply and sewerage, Boulder
pitching,Metalworks etc. (4-5 % of Sub
Total(A) depending on thte site conditions &
type pf structure) 4 to 5% 4.50% 208.68 9.39
Sub-Total (B) of 1 to 7 218.07
8.0 Dewatering (2% of Sub-Total (B) 2% 218.07 4.36
9.0 Contingencies (3% of Sub-Total (B) except
on L.S. items) 3% 218.07 6.54
10.0 Work Charges Establishment (2% of Sub-
Total(B) except on L.S. items) 2% 218.07 4.36
Total of 1 to 10 233.34

ADITS
S. NO. DESCRIPTION UNIT QTY.
RATE
(Rs.) Amt.in Lac
1.0 Surface Excavation
1.1 Common excavation Cum 100 125.00 0.13
1.2 Rock excavation Cum 200 300.00 0.60
2.0 Under ground excavation
2.1 Excavation of adits Cum 32650 1000 326.50
3.0 Supports System
3.1 Rockbolts M 16000 625 100.00
3.2 Steel ribs suppots (if required) Ton 280 42000 117.60
3.3 Shotcreting Cum 2830 4000 113.20
3.4 Concrete lagging if required Cum NIL
4.0 Concrete
4.1 M 10 Cum 750 2560 19.20
4.2 M 15 Cum NIL
4.3 M 20 Cum. NIL
4.3 M 25 Cum. NIL
5.0 Reinforcing Steel Ton NIL
Sub-Total (A) of 1 to 5 677.23
6.0 Miscellaeneous
6.1 Various Miscellaneous works like drilling &
grouting, wiremesh reinforcement ,masonary
works,PVC pipes for drainage etc. (3-4 % of
Sub Total(A) depending on the site conditions
& type pf structure)
3 to 4% 3.50% 677.23 23.70
Sub-Total (B) of 1 to 6 700.93
7.0 Instrumentaion (1% of Sub-Total (B) 1% 700.93 7.01
8.0 Dewatering (2% of Sub-Total (B)
Contingencies (3% of Sub-Total(B) except on
2% 700.93 14.02
9.0 L.S. items)
Work Charges Establishment (2% of Sub-
3% 700.93 21.03
10.0 Total(B) except on L.S. items) 2% 700.93 14.02
Total of 1 to 10 757.00

Hydro-Mechaniocal Works
S. NO. DESCRIPTION UNIT QTY.
1.0 DIVERSION TUNNEL WORKS
Gate (size) Ton Ton
Embeded Parts Ton NIL
Rope drum Hoist (as per capacity) Set NIL
Hoist supporting structure & trestle Set NIL
RATE
(Rs.) Amt.in Lac
2.0 SPILL WAY STRUCTURE
a Radial gates (Size) 5.00mx6m Ton 120 100000 120.00
Embedded parts (including anchorage) Ton 42 50000 21.00
Hydraulic hoist Set 2 100000 2.00
b Bulk head gates (size )5.00mx6m Ton 12.4 100000 12.38
Embedded parts Ton 4.3 50000 2.17
Gantry Crane Set 1 500000 5.00
3.0 INTAKE STRUCTURE
a Intake Gate (size) Ton NIL
Embedded parts for Intake gates Ton NIL
Rope Drum Hoist (as per capacity) Set NIL
Hoist Plateform & trustle Set NIL
b Bulk head gates (size) 5.50mx3m Ton 40 100000 40.00
Embedded Parts For Bulk Head Gates Ton 15 50000 7.50
Gantry Crane as per capacity Set 1 500000 5.00
4.0 THRASH RACKS/TRASH RACK CLEANING MACHINE
a Trash Rack Cleaning Machine Set 1 100000 1.00
b Thrash Racks and embedded parts Ton 49 50000 24.50
5.0 Desanding Basin
Stoplogs Ton 70 60000 42.00
Embedded parts Ton 26 50000 13.00
Gantry Crane Set 1 500000 5.00
6.0 DRFT TUBE GATE
gates (size) 4mx6.50m Ton 7.500 100000 7.50
Embedded Parts For Draft Tube Gates Ton 2.500 50000 1.25
Gantry Crane (as per capacity) Set 1 500000 5.00
7.0 TAIL RACE
a Outlet Stoplogs Set NIL
b Embedded parts Ton NIL
8.0 SURGE SHAFT
a Stoplogs Ton 35 60000 21.00
b Embedded parts Ton 13 50000 6.50
c Travelling Hoist Set 1 500000 5.00
G/Total (1to8) 346.79

J - Power Plant and Civil Works
S.No. Description Unit Qty. RATE (Rs Amt.in Lac
I) Coffer Dam 329.76
II) Barrage 9,243.19
C-Works 9572.95
III) Intakes Structure 337.34
IV) Desanding Chamber 5968.28
V) Head Race Tunnel & Tailrace Tunnel 6,415.56
VI) Surge Shaft 862.58
VII) Pressure Shaft 2899.73
VIII) Power House Complex 2236.82
IX) Switch Yard 233.34
X) Adits 757.00
XI) Hydro-Mechaniocal Works 346.79
Total J-Power Plant 20,057.42

Chhatru HEP (108MW ) in Chenab Basin of HIMACHAL PREDESH
ABSTRACT OF COST OF CIVIL WORK
Annex -D
S.N. Description
Amount in Lac
A CIVIL WORKS
1 DIRECT CHARGES
I-Works
A-Priliminary 501.25
B-Land 350.00
C-Works 9572.95
J-Power Plant Civil Works 20,057.42
K- Buildings 1341.94
M-Plantation 25.00
O-Miscelleoneous 966.77
P- Maintenance 335.05
Q- Special Tools & Plants 496.71
R- Communication 656.70
X- Envoirment & Ecology 470.00
Y- Losses on Stock 79.27
Total of I-Works 34853.06
II - Establishment @ 8% of cost of I-Works 2760.24
Less B- Land
III - Tools & Plants @ 1% of cost of I - Works 348.53
IV _ Suspence 680.04
V - Recipts & Recoveries ( - )
2 INDIRECT CHARGES
a) Capatilised Value of Abatement of Land Revenue
@5% of cost of land
328.84
TOTAL DIRECT CHARGES 38313.03
17.50
b) Audit & Account Charges @ 1% of cost of I - Works 348.53
TOTAL INDIRECT CHARGES 366.03
TOTAL DIRECT & INDIRECT CHARGES 38679.07
Lac.

ABSTRACT OF COST
A Civil Works 38679.07 Lac.
B Electrical Works
P- Production 13612.06 Lac.
T-Transmission 844.68 Lac.
TOTAL COST 53135.80 Lac.

S.N.
1 Land Required for
A. Reservoir submergence area
B. Project features
C. Township,store area and roads
D. Quarry site
E. Muck disposal Area & Job facilities
F. Transit Camp And Guest Houses & Colony
G. Project roads
Name of Project Component
H. Land for Rehablitation Purpose
Total A
Forest/
Govt.
/Pvt.
Land
Rates in
Rs.Lacs./Ha
Govt. 20.00 Nil
Pvt.
Area in
Hac.
Govt. 10.00 Nil
Govt. 2.00 Nil
Pvt. 4.00
Govt. 1.50 Nil
Govt. 1.00 Nil
Pvt. 4.00
Pvt. 6.00
6.00
NIL Nil
2 Cost for impletation of R&R Plan L.S
Total B
3
Cost of establishment for land acquisition
and Rehablitation @6.25 % of item B
6.25% 0.00
4 Solitanium Charges @30 % of the cost of
the private land
5 Interest Charges on amount of award for
the period between taking over the possetion
of land date of award @12 % per annum on
25% of cost of total compensation for thte 2
30% 0.00
yearsof the cost of the private land
12% 0.00 2
6
Lega charges @1 % of total compensation
7 Labour and material charges for
measurment & demarkation of land
1% 0.00
/Properties @ 1% of cost of land acquisition
1% 0.00
Total
Total land
B - LAND
LS
54.50 Hac.

Total Govt. land
Total Private land
40.50 Hac.
14.00 Hac.

S.N. DESCRIPTION OF BUILDING UNIT
TOTAL
PLINTH
AREA
RATE IN Rs.
1.0 Residential Building
1.1 Permanent residential building Sq. m. 8800 4200
Service Charges @ 31%
1.2 Tem,porary Buildings Sq. m. 6000 3780
Service Charges @ 27%
Total Residential buildings
2.0 Non - Residential Buildings
2.1 Permanent Non - Residential Buildg. Sq. m. 9800 3800
Service Charges @ 22.50%
2.2 Temporary Non Residential Buildg. Sq. m. 2755 3420
Service Charges @ 20.50%
Total Non - Residential buildings
K -BUILDING
Grand Total (Residential + Non - Residential )

S.N. DESCRIPTIOPN
QTY. UNIT RATE
1.0 CAPITAL COST
1.1 Electrification 5 YEAR 90000
1.2
1.3
1.4
2
2.1 Maintenance & Power arrangements
2.2 R &M of water supply facilities
i.e. 8% of capital cost
5 YEAR 3.40
2.3 R & M of sanitation & drainage facilities
i.e. 8% of capital cost
2.4 R & M of Telecommunication system and
5 YEAR 3.40
post offfice
5 YEAR 0.42
2.5 R & M of Hospital
5 YEAR 10.00
2.6 R & M of rest house and field hostel
5 YEAR 1.00
2.7
2.8
2.9
Water supply, purification and distribution
arrangements including puchase of water
tankers, cost of tanks and chlorination
Providing sewerage disposal and storm water
drains at various coloney sites.
Furnishing & equiping rest houses field
hostels, hospitals schools etc.
Maintenance & Service charges during
execution period
R & M of Research & Quality control
laboratories
Labour welfare compensation and
retrenchment benfits
O-MISCELLANEOUS
Providing sequrity police including R & M of
Posts
LS
LS
LS
5 YEAR 25.00
5 YEAR 15.00
5 YEAR 5.00
2.10 R & M of inspection vehicles and staff cars 5 YEAR 35.00

2.11 R & M of school buses and staff buses @ 2.5
lakh per vehicle
2.12
5 YEAR 10.00
5 YEAR 8.00
2.13 R &M of field workshops
5 YEAR 0.42
2.14 Maintenance & Running of schools
5 YEAR 35.00
3.0 Miscelleonous
3.1 Foundeation stone laying
L.S
3.2 Model exhibition
L.S
3.3 Group insurance
L.S
3.4 Compensation of accidents
L.S
3.5
R & M of Ambulence @ RS 2.50 Lakh per
Year per Vehicle
Trainning of personnel abroad including
study courses and visits
L.S
3.6 Others
L.S
TOTAL

Amount
Rs.Lacs.
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0
0
0
0
350.00

AMT. IN
LAC.
369.60
114.58
226.80
61.24
772.21
372.40
83.79
94.22
19.32
569.73
1341.94

AMOUNT
4.5
43
43
50
17.01
17.01
2.10
50.00
5.00
125.00
75.00
25.00
175.00

50.00
40.00
2.10
175.00
5.00
8.00
15.00
25.00
8.00
8.00
966.77

A-Preliminary
Sr.No. Description Unit Qty. Rate Amount
(lacs)
1. Exprenditure on investigations alredy conducted 14.00
2. Pre-construction and const. Stage investigations:
I) Topographical surveys by the deptt. and survey
of India L.S. 50.00
ii) Hydro-meteorological data collection for 5 years
including stablishing self rcording rain/snow
gauge stations, climato-logical laboratory,
silt laboratory and conducting sediment
silt & water tests etc. L.S. 47.25
iii) Geological and geophysical explorations,
geotechnical testing and data collection
sieismological observations and laboratories L.S. 40.00
iv) Construction material testinmg, establishing
soil and rock testing laboratory L.S. 45.00
v) Environment and ecological surveys L.S. 10.00
vi) Hydraulic model studies and testing L.S. 55.00
3. Training of engineers and technicians L.S. 30.00
4. Construction of access paths and jeepable
roads, for investigation. L.S. 45.00
5. Inspection vehicles for investiqation I/c
R/M charges L.S. 25.00
6. Surveys, drawing mathematicqal and office
equipment like photo-copier, ammonia
printing machine etc. L.S. 40.00
7. Consultants fees L.S. 35.00
8. Publication of brochures, project reports .
comprising design reports, estimates, bulletins
completion reports,history of the poject etc L.S. 40.00
9. Personal computer along with CGA,
printer and plotter etc. L.S. 25.00
Total 501.25

Q- Special T&P
S.No. Description Unit Qty. Rate Amount
(in Rs.) (lacs)
1. Hydraulic excavator Bucket capacity Nos 2 7500000 150
2.0 cum "
2. Dumper 20 ton capacity " 8 3200000 256
3. Working platform 2 4000000 80
4. Grouting pump " 1 700000 7
5. Grout hole drilling crawler " 1 1500000 15
6. Hydraulic rubber-wheel based drilling " 2 1500000 30
2-boom jumbo
7. Tower crane 25m/3 tons " 1 1E+07 100
8. Concrete pump 40 cum/hr. 2 4500000 90
9. Motor grader 10 tons 145 HP " 1 6500000 65
10. Concrete lorry with 2.5 cum rotary drum " 1 1900000 19
mixer 2.5 rotary drum mixer
11. Draining pump (8 bar water hydrophore) " 20 75000 15
30 HP
12. Draining pump 10 HP " 20 50000 10
13. Internal vibrator with electric motor
& converter " 1 30000 0.3
14. Transformer 315 KVA " 3 215000 6.45
15. Shotcreting robot 1 8000000 80
16. Hydraulic excavator 1.0 cum " 1 5000000 50
17. Batching plant " 2 4800000 96
18. Wheel loader 1.15 cum " 1 2200000 22
19. Crawler dozer 180 HP " 1 4050000 40.5
20. Air compressor electric 500 cfm " 5 750000 37.5
21. Air compressor diesel 500 cfm 148 HP " 5 750000 37.5
22. Jack hammer 52 lbs " 5 30000 1.5
23. Pavement breaker " 1 30000 0.3
24. Concrete mixer 10/7 cft " 4 80000 3.2
25. Transit mixer 14/10 cft " 1 130000 1.3
26. Pneumatic concrtete placer " 1 100000 1
27. Grout pump " 1 700000 7
28. Tipper 4.5 cum " 1 630000 6.3
29. Material truck " 1 800000 8
30. Coarse aggregate processing plant 30 ton " 2 3000000 60
31. wagon drill " 1 800000 8
32. Bus " 3 800000 24
33. Car " 9 400000 36
34 Jeep 20 400000 80
35 Pick up van 4 450000 18
36 Ambulance 2 450000 9
37 Workshop equipment L.S 15
Total cost of Q-Special T&P 1485.85
Cost of personal carriers 167
Cost of Q-Special T& P other than personal
carriers 1318.85
Cost of Q-Special T & P chargeable to estimate
25% of (cost of Q-Special T&P other than
personal carriers) 1318.9 25% 329.71
Cost of personal carrier chargeable to
estimate=100% 167 100% 167.00

Total 496.71

R-Comunication
S.No. Description Unit Qty. Rate Amount
(in lacs) (lacs)
1
2
3
4
C/O proposed road from main road (suspension bridge) to
surge shaft and power house 5/7m wide i/c metalling &
tarring.
C/O proposed road from main road to adit of HRT 5/7m
wide i/c metalling & tarring.
C/O proposed road from main road to colony 5/7m wide i/c
metalling & tarring.
Realignment of existing main road along the reservoir 5/7m
wide i/c metalling & tarring.
Km. 10 17.9 179.00
Km. 4 17.9 71.60
Km. 6 17.9 107.40
Km. 2 17.9 35.80
5 Widening of existing motorable road from diversion of
Khoksar HEP to diversion of Chhatru HEP 5/7m wide i/c
metalling & tarring.
Km. 17 14.3 243.10
6 Proposed permanent RCC bridge in place of existig
suspension bridge 7.50m wide.
Rmt 22 0.9 19.80
Total 656.70

S.No. Description Unit Qty. Rate Amount
(in Rs.) (lacs)
X-Environment and Ecology
I) Cost of compensatory afforestation in project L.S. 20.00
2) Cost of fule wood L.S. 30.00
3)Cost of health facility L.S. 3.00
4) Cost of catchment area treatment plan L.S. 400.00
5) Cost of reclamation and plantation L.S. 9.00
60 Cost of environment monitoring cell L.S. 8.00
V-Receipt & Recoveries
I) Temporary Buildings -
Total 470.00
Cost of temporary buildings 321.02 15% 48.15
Credit @15 % -
ii) Q-Special T&P Recoveries under the -
sub-head
'@ 75% of Q-Special T&P charged to estimate -
other than personal carriers 329.71 75% 247.28
-
iii) Cost recoverable on a/c of resale value of personal
carrier @20% of capital cost 167 20% 33.40
Total 328.84

Y- Losses on stock
Provision made @ 0.25% on the cost of I-Works less
A-Preliminary, B-Land, M-Plantation, O-Misc., P-Maintenance,
Q-Special T&P and X-Environment & Ecology. 31,708.28
I-Works 34,853.06
Less:
A-Preliminary 501.25
B-Land 350.00
M-Plantation 25.00
O-Miscellaneous, % of I Works less (A+B+Q) 966.77
P-Maintence 335.05
Q-Speci8al Tools & Plant 496.71
X-Environment and Ecology 470.00
Total 3144.78
P - Maintenance
0.25% 79.27
1% of I- works less (A+B+Q) 1% 33505.10 335.05
I-Works 34853.06
less - A- Preliminary 501.25
B-Land 350.00
Q- Special T&P 496.71
Net Total 33505.10

Name of project:- Chhatru HEP (108MW ) in Chenab Basin
of Himachal Predesh
ABSTRACT OF COST OF CIVIL WORK
S.N.
Annexure -13.1 (a)
Annex -D
Amount (in
Crores) (June
2003)
A CIVIL WORKS
1 DIRECT CHARGES
I-Works
A-Priliminary 501.25
B-Land 350.00
C-Works 9572.95
J-Power Plant Civil Works 20057.42
K- Buildings 1341.94
M-Plantation 25.00
O-Miscelleoneous 966.77
P- Maintenance 335.05
Q- Special Tools & Plants 496.71
R- Communication 656.70
X- Envoirment & Ecology 470.00
Y- Losses on Stock 79.27
Total of I-Works 34853.06
II - Establishment @ 8% of cost of I-Works Less B- Land 2760.24
III - Tools & Plants @ 1% of cost of I - Works 348.53
IV _ Suspence 680.04
2 INDIRECT CHARGES
Description
V - Recipts & Recoveries ( - )
a) Capatilised Value of Abatement of Land Revenue
@5% of cost of land
328.84
TOTAL DIRECT CHARGES 38313.03
17.50
b) Audit & Account Charges @ 1% of cost of I - Works 348.53
TOTAL INDIRECT CHARGES 366.03
TOTAL DIRECT & INDIRECT CHARGES 38679.07

CHHATRU HYDRO-ELECTRIC-PROJECT (108 MW)
Annexure -13.1 (b)
COST ESTIMATES OF ELECTRO-MECHANICAL WORKS FOR PRE-FEASIBILITY REPORT
Sl.No Item Qty Rate Amount Excise Duty* Total
Rs.(Lakhs) Rate Amount Amount
(Rs. Lakhs) (Rs. Lakhs)
1 2 3 4 5 6 7 8
1 Generating Unit and 11 KV Bus Duct 36MW,
428.6 RPM with net Head of 160 mtrs.
3 Rs.5600/KW 6048.00 16% 967.68 7015.68
2 Step-up transformer, 11/220KV,15MVA,single
phase
10 Rs.260/KVA 390.00 16% 62.40 452.40
3 Auxiliary Electrical Equipment for Power
Stations (Except transformer) (5% of item 1).
302.40 16% 48.38 350.78
4 Auxiliary Equipment and Services for Power
Stations (5% of item-1)
302.40 16% 48.38 350.78
5 220 KV Switchyard GIS. 6 bays 300 Lacs/bay 1800.00 16% 288.00 2088.00
6 Spares (5% of 1 and 3% of 2-5) 386.24 16% 61.80 448.04
7 Sub-Total-1: 9229.04 10705.68
8 Central Sales Tax ** 4% of item 1 to 6 428.23
9 Transportation & Insurance 6% of item-7 642.34
10 Erection and Commissioning 8% of item-7
(except spares)
820.61
11 Sub-Total-2 : 12596.86
12 Establishment, Contingency, other charges
11% of item-7 (excluding duties)
1015.20
Grand Total :- 13612.06
Say Rs. 13612 Lacs

Annexure -13.1 ( c )
CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
MAIN ABSTRACT OF COST OF TRANSMISSION
Sr.No. Description Amount ( in Lacs)
1 Preliminary Works ( Annex. 1) 5.10
2 Detailed Surveying ( Annex. 2) 1.74
3 Compensation for land, Trees,
Crops, Tree cutting and
afforestation ( Annex. 3)
13.20
4 Transmission Line ( Annex. 4) 626.00
5 Terminal Equipment at Tandi
(LILO of one ckt. of Khoksar-
Tandi 220Kv D/C line)
0.00
6 PLCC Equipment at Tandi 69.6
7 Buildings 15
8 Vehicles and Workshop
machinery ( Annex. 13)
34
Sub Total-I 764.64
9 Contingency @ 3% on Item 1 to
8
22.94
Sub Total-II 787.58
10 Establishment charges @ 4%, 57.10
GRAND TOTAL 844.68
Say Rs. 845 LACS

YEAR- WISE PHASING OF FUNDS
Installed Capacity 108MW (3*36 MW)
108 MW
Peaking Capacity 108 MW
Energy @ 90% Dependable Year (Over all Efficie
455.72 Million Units
Rate of Interest
10.00%
Discounting Rate
12.00%
ea
Civil Works
Electrical Works
Transmission
TOTAL
Rs in Crores
386.79
136.12
8.45
531.36
Civil Works Electrical Works
Transmission
Generation
Gen.+
Trans
2 3 4 5 6 7 col. 3+5 Col3+5+7
% Funds
Reqd.
Rs in
Crores
%
Funds
Reqd.
Annexure 13.2
Rs in
Crores % Funds Reqd. Rs in Crores Rs in Crores
Rs in
Crores
1 5.0% 19.34 0.0% 0.00 0.0% 0.00 19.34 19.34
5.0% 19.34 2.5% 3.40 0.0% 0.00 22.74 22.74
2 7.5% 29.01 5.0% 6.81 5.0% 0.42 35.82 36.24
7.5% 29.01 5.0% 6.81 5.0% 0.42 35.82 36.24
3 15.0% 58.02 10.0% 13.61 10.0% 0.84 71.63 72.48
15.0% 58.02 17.5% 23.82 15.0% 1.27 81.84 83.11
4 17.5% 67.69 20.0% 27.22 22.5% 1.90 94.91 96.81
17.5% 67.69 20.0% 27.22 22.5% 1.90 94.91 96.81
5 10.0% 38.68 20.0% 27.22 20.0% 1.69 65.90 67.59
T 100% 386.79 100.0% 136.12 100.0% 8.45 522.91 531.36

ESCALATED COST
Annexure
Escalation on civil works 0.00% (Yerly)
Escalation on elect. works 0.00% (Yerly)
Gen.+
ea Civil Works Electrical Works
Transmission
Generation Trans
Envisaged Escalated Envisaged Escalated Envisaged Escalated Escalated Escalated
2 3 4 5 6 7 col 3+ 5 col 3+5+7
E
x
p
.
A
l
r
e
a
d
y
i
n
c
u
r
r
e
d 0.14 0.14 0.14 0.14
19.20 19.20 0.00 0.00 0.00 0.00 19.20 19.20
19.34 19.34 3.40 3.40 0.00 0.00 22.74 22.74
29.01 29.01 6.81 6.81 0.42 0.42 35.82 36.24
29.01 29.01 6.81 6.81 0.42 0.42 35.82 36.24
58.02 58.02 13.61 13.61 0.84 0.84 71.63 72.48
58.02 58.02 23.82 23.82 1.27 1.27 81.84 83.11
67.69 67.69 27.22 27.22 1.90 1.90 94.91 96.81
67.69 67.69 27.22 27.22 1.90 1.90 94.91 96.81
38.68 38.68 27.22 27.22 1.69 1.69 65.90 67.59
T
G
386.65 386.65 136.12 136.12 8.45 8.45 522.77 531.22
.
T
386.79 386.79 136.12 136.12 8.45 8.45 522.91 531.36
o
Esclation: 0.00 0.00 0.00 0.00 0.00

COST OF THE PROJECT INCLUDING IDC. (At power house bus bars)
Rate of
interest:-
EQUITY 30% 156.87
Loan @ 10.00% 70% 366.04
Discounting factor 12.00% Total 522.91
Annexure 13.3
H
a
l
f-
Y
e Phasing of
NPV of
a Escalated Equity LOAN loan Op.
Int fin. From Int fin. From
Total Discountin NPV of Esclated
r Hard Cost 30% 70% Bal. Interest on loan. Eq.30% Loan.70% Total Loan Equity g Factor IDC Cost
2 3 4 5 6 7 8 9 10
19.34 5.80 13.54 0 0.34 0.10 0.24 13.77 5.90 1.00 0.34 19.34
22.74 6.82 15.92 13.77 1.09 0.33 0.76 16.68 7.15 0.94 1.03 21.46
35.82 10.74 25.07 30.46 2.15 0.64 1.50 26.58 11.39 0.89 1.91 31.88
35.82 10.74 25.07 57.03 3.48 1.04 2.43 27.51 11.79 0.84 2.92 30.07
71.63 21.49 50.14 84.54 5.48 1.64 3.84 53.98 23.13 0.79 4.34 56.74
81.84 24.55 57.29 138.51 8.36 2.51 5.85 63.14 27.06 0.75 6.25 61.16
94.91 28.47 66.44 201.65 11.74 3.52 8.22 74.66 32.00 0.70 8.28 66.91
94.91 28.47 66.44 276.31 15.48 4.64 10.83 77.27 33.12 0.67 10.29 63.12
65.90 19.77 46.13 353.58 14.12 4.24 9.89 56.02 24.01 0.63 8.86 41.35
T 522.91 156.87 366.04 62.24 18.67 43.56 409.60 175.54 44.22 392.02
Original Cost 522.91
Esc. 0.00
Hard Escalated 522.91 89.36% 89.36% Loan 409.60 70.00%
IDC = 62.24 10.64% 10.64% Equity 175.54 30.00%
Total = 585.15 100% 100.00% Total 585.15

COST OF THE PROJECT INCLUDING IDC. (At purchase center)
Switch 2
Rate of
interest:-
EQUITY 30.00% 159.41
Loan @ 10.00% 70.00% 371.95
Discounting factor 12.00% Total 531.36
Annexure 13.3 (b)
H
a
l
f-
Y
e Phasing of
NPV of
a Escalated Equity LOAN loan Op.
Int fin. From Int fin. From
Total Discountin NPV of Esclated
r Hard Cost 30% 70% Bal. Interest on loan. Eq.30% Loan.70% Total Loan Equity g Factor IDC Cost
2 3 4 5 6 7 8 9 10
19.34 5.80 13.54 0 0.34 0.10 0.24 13.77 5.90 1.00 0.34 19.34
22.74 6.82 15.92 13.77 1.09 0.33 0.76 16.68 7.15 0.94 1.03 21.46
36.24 10.87 25.37 30.46 2.16 0.65 1.51 26.88 11.52 0.89 1.92 32.25
36.24 10.87 25.37 57.33 3.50 1.05 2.45 27.82 11.92 0.84 2.94 30.43
72.48 21.74 50.73 85.15 5.53 1.66 3.87 54.60 23.40 0.79 4.38 57.41
83.11 24.93 58.17 139.75 8.44 2.53 5.91 64.08 27.46 0.75 6.31 62.10
96.81 29.04 67.77 203.83 11.89 3.57 8.32 76.09 32.61 0.70 8.38 68.25
96.81 29.04 67.77 279.92 15.69 4.71 10.98 78.75 33.75 0.67 10.43 64.39
67.59 20.28 47.31 358.67 14.34 4.30 10.04 57.35 24.58 0.63 9.00 42.41
T 531.36 159.41 371.95 62.96 18.89 44.07 416.03 178.30 44.72 398.03
Original Cost 531.36
Esc. 0.00
Hard Escalated 531.36 89.41% 89.41% Loan 416.03 70.00%
IDC = 62.96 10.59% 10.59% Equity 178.30 30.00%
Total = 594.32 ###### 100.00% Total 594.32

Annexure -13.4
DETAIL OF DEPRECIATION
Life in % Rate Cost (Rs.in Dep. (Rs.
years of Dep. Lac.) in Lac.)
I-CIVIL WORKS
Diversion Barrage 50 1.95 9,243.19 180.24
Intake Structure 50 1.95 337.34 6.58
Desanding Chamber 50 1.95 5,968.28 116.38
Head Race Tunnel &
Tail Race
50 1.95 6,415.56 125.10
Surge Shaft 35 3.4 862.58 29.33
Pressure Shaft 35 3.4 2,899.73 98.59
P/ House 35 3.4 2,236.82 76.05
Buildings. 50 3.02 233.34 7.05
R-Communication 50 3.02 757.00 22.86
Total 28,953.82 662.18
II-ELECTRICAL WORKS
Generating Plant and Equi 35 3.4 5500 187.00
Transformers 25 7.84 390 30.58
Switchgears etc. 25 7.84 20 1.57
Communication equipeme 15 12.77 180 22.99
Batteries and DC equipts. 5 33.44 45 15.05
Air conditioning and venti 15 12.77 50 6.39
Bus ducts 50 1.95 150 2.93
Plant handling equipts. 5 33.44 800 267.52
Total 10294.96 534.01
G. Total 39,248.78 1196.19
Rate of Depreciation-
Say
3.05
3%

Calculations for Levelised Tariff For Chhatru Hydro Electric Project (AT POWER HOUSE BUS BARS)
Assumtions
( without free power)
Cost Of Project Rs. 522.91 Crores
IDC Rs. 62.24 Crores
Total Cost 585.15 Crores
Loan
70%
Equity
30% Return on Equity (Post Tax) 16.0%
Loan amount
409.60 Crores Income Tax @ 35% + 10% Surcharge 38.5%
Design Energy 455.72 Million Units Assumed Sale Rate :
Rs. 2.75 per unit
Free Power
0%
Available Energy
Interest Rate
455.72
10.0%
Million Units
Working Capital: 1 month O&M Charges including spares + Actual recievables for 2 months
Repayment Period
12 Years Rs. 21.37 Crores
O&M Charges
1.5%
Depreciation(yearly)
3.00% (Straight Line Method up 90% of the value)
Aux. Consumption
0.7% Dep. Amount 90% of the total cost 526.63 Lac.
Transformation Losses
0.5% Dep. Amount recovered 526.63 Lac.
Interest on Working Captial
9.75%
Discount Rate
12.00%
Transmission Losses 0.00%
Year 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18
Capacity Charges
1 Interest on debt Rs. Crores 39.25 35.84 32.43 29.01 25.60 22.19 18.77 15.36 11.95 8.53 5.12 1.71 0.00 0.00 0.00 0.00 0.00 0.00
2 Depreciation @ 3.00% Rs. Crores 17.55 17.55 17.55 17.55 17.55 17.55 17.55 17.55 17.55 17.55 17.55 17.55
a AAD 1/12 of loan minus dep. Rs. Crores 16.58 16.58 16.58 16.58 16.58 16.58 16.58 16.58 16.58 16.58 16.58 16.58
b Total Depriciation Rs. Crores 34.13 34.13 34.13 34.13 34.13 34.13 34.13 34.13 34.13 34.13 34.13 34.13 5.09 5.09 5.09 5.09 5.09 5.09
3 Return on Equity Rs. Crores 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09
4 O&M Charges Rs. Crores 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78
5 Interest on W.C Rs. Crores 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08
6 Income Tax on ROE Rs. Crores 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58
7 Total
129.92 126.50 123.09 119.68 116.26 112.85 109.44 106.02 102.61 99.20 95.78 92.37 61.62 61.62 61.62 61.62 61.62 61.62
8 Equated energy Sent Out Rs/Kwh 2.89 2.81 2.73 2.66 2.58 2.51 2.43 2.35 2.28 2.20 2.13 2.05 1.37 1.37 1.37 1.37 1.37 1.37
9 Discounted Calculations
10 Rate
12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00%
11 Discounting Factor
1.00 0.89 0.80 0.71 0.64 0.57 0.51 0.45 0.40 0.36 0.32 0.29 0.26 0.23 0.20 0.18 0.16 0.15
12 Discounted Equated Charge Rs/Kwh 2.89 2.51 2.18 1.89 1.64 1.42 1.23 1.07 0.92 0.79 0.68 0.59 0.35 0.31 0.28 0.25 0.22 0.20
Levelised Tariff(Discounted) Rs/Kwh
Annexure 13.5
2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28

Annexure 13.5 Contd.
19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
5.09 5.09 5.09 5.09 5.09 5.09 5.09 5.09 5.09 5.09 5.09 5.09 5.09 5.09 5.09 5.09 5.09
28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09 28.09
8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78 8.78
2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08 2.08
17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58 17.58
61.62 61.62 61.62 61.62 61.62 61.62 61.62 61.62 61.62 61.62 61.62 61.62 61.62 61.62 61.62 61.62 61.62
1.37 1.37 1.37 1.37 1.37 1.37 1.37 1.37 1.37 1.37 1.37 1.37 1.37 1.37 1.37 1.37 1.37
12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00% 12.00%
0.13 0.12 0.10 0.09 0.08 0.07 0.07 0.06 0.05 0.05 0.04 0.04 0.03 0.03 0.03 0.02 0.02
0.18 0.16 0.14 0.13 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
2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28 2.28

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
MAIN ABSTRACT OF COST OF TRANSMISSION
Sr.No. Description Amount ( in Lacs)
1 Preliminary Works ( Annex. 1) 5.10
2 Detailed Surveying ( Annex. 2) 1.74
3 Compensation for land, Trees,
Crops, Tree cutting and afforestation
( Annex. 3)
13.20
4 Transmission Line ( Annex. 4) 626.00
5 Terminal Equipment at Tandi (LILO
of one ckt. of Khoksar-Tandi
220Kv D/C line)
0.00
6 PLCC Equipment at Tandi 69.6
7 Buildings 15
8 Vehicles and Workshop machinery
( Annex. 13)
34
Sub Total-I 764.64
9 Contingency @ 3% on Item 1 to 8 22.94
Sub Total-II 787.58
10 Establishment charges @ 4%, Tools
and Plants @ 1%, Losses on stock
@ 0.25%, Maintenance during
construction @ 1%, Audit and
accounts charges @ 1%
57.10
GRAND TOTAL 844.68
Say Rs. 845 LACS

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
COST OF PRELIMINARY WORKS
Annexure-1
Sr.No Description Qty Amount in Lacs
1 Cost of Temporary Sheds and
camping requirement ( Annex.- 1.1)
2.5
2 Cost of Reconnaisance and
Preliminary survey ( Annex.- 1.2)
0.60
3 PTCC Clearance LS 2
TOTAL
Sheet 2
5.10

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
Annexure-1.1
ABSTRACT OF COST FOR TEMPORARY SHEDS AT EACH
CAMPING SITE
Sr. No Description Qty Rate Unit Amount in Rs
1 Temporary Sheds of CGI
Sheets on sides and top with
wooden ballies posts and
Wooden Rafters
100 700 Sq.Mtr 70000
2 One Swiss Engineer Cottage,
Engineer tent ( 3.65 x 3.65)
1 5500 No 5500
3 Four Labour tents for
Chowkidars Double Ply
4 5500 Nos 22000
4 Area Fencing with Angle Iron/
wooden Posts and barbed
wire etc.
1 22000 LS 22000
5 Miscellaneous Tools for
setting up Camp
1 5500 LS 5500
6 Total Cost of Each Camp 125000
7 Number of Camps required
for surveying the
Transmission System under
Sorang HEP
2 Nos
8 TOTAL COST OF 2 CAMPS 250000
Sheet 3
Say Rs 2.5
Lacs

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
Annexure-1.2
ABSTRACT OF COST FOR RECONNAISANCE AND
PRELIMINARY SURVEY OF 220 KV D/C LINES.
Sr. No Description
Reconnaisance and
Preliminary survey ( Unit 1
km of length )
Qty Rate Unit Amount in Rs
A SURVEYING PARTY
I) Surveyor (Regular) 1 6000 No 6000
ii) Beldar 6 2250 No 13500
iii) Chowkidar 2 2250 Nos 4500
Sub Total 24000
B Labour for Reconnaisance
and Preliminary survey of 1
km of line
Assuming 4 days for 1 Km
of line and 25 working days
in a month
3840
C Wooden Pegs 16 9 Nos 144
Total (B+C) 3984
Cost of conducting
preliminary Survey per Km
Line length
3984
Cost of conducting
preliminary Survey for 15
Kms Line length
15 Kms. 59760
Say Rs 0.60
Sheet 4
Lacs

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
COST OF DETAILED SURVEYING OF 220 KV D/C LINE.
Sr. No Description Qty Rate Unit Amount in Rs
A SURVEYING PARTY
Assuming 4 days for
conducting of survey of 1
km of line
(I) Surveyor (Regular) 1 6000 No 6000
(ii) Beldar (Daily Wages) 6 2250 Nos 13500
(iii) Chowkidar (Daily Wages) 2 2250 Nos 4500
(iv) Labour for 4 days
( Assuming 4 days for 1 km
and 25 working days in a
month)
3840
(v) Wooden pegs 16 9 Nos 144
Total 3984
B Stacking ( Unit 1 Km of
line)
0
(I) Surveyor (Regular) 1 6000 Nos 6000
(ii) Beldar (Daily Wages) 12 2250 Nos 27000
(iii) Chowkidar (Daily Wages) 2 2250 4500
Sub Total 37500
(iv) Labour for 4 days
( Assuming 4 days for 1 km
and 25 working days in a
month)
6000
(v) Stone Marking Pillars 8 80 Nos 640
Total 6640
C Transportation
Camp Shifting Etc. 1000
Total (A+B+C) 11624
Cost of Detailed survey of
15 Kms of Line
15 kms. 174360
Say Rs 1.74
Sheet 5
Lacs
Annexure-2

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
Annexure-3
COST OF COMPENSATION FOR LAND, TREES, CROPS,
TREE CUTTING AND AFFORESTATION
Sr. No Description Qty Rate Unit Amount in Rs
1 Compensation for tree
cutting and afforestation
15 20000 Kms 300000
2 Compensation for land
falling under the towers and
rent for camping site
15 50000 Kms 750000
3 Compensation to damage to
crops under the line
15 18000 Kms 270000
Total 1320000
Say Rs 13.2
Lacs
Sheet 6

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
ESTIMATE OF COST FOR 220 KV D/C TRANSMISSION LINE FROM
BARDANG TO TANDI 400 KV POOLING-IN STATION.
Sr. No Description Qty Rate Unit Amount in Lacs
1 220 KV D/C line (Snow
Zone) ( Annex. 5)
15 35.40 Kms 531.00
2 Retaining Walls 65
3 Benching of towers 30
TOTAL 626.00
Sheet 7

Annexure-4

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
BREAK UP ESTIMATE FOR 1 KM OF 220 KV D/C LINE.
(SNOW ZONE)
Conductor size= 0.4 Sq. Inch Cu. Eq. "ACSR" ZEBRA
Earth Wire Size= 7/3.18 mm GSS 140 Kgf Quality.
Normal Span= 350 MTS
Annexure-5
Sr. No Description Qty Rate Unit Amount in Rs
1 Steel for towers
(Prefabricated galvanized/
painted) ( Annex. 6)
39.27 31000 MT 1217370.00
2 Nuts and Bolts ( Annex. 6) 1.96 60000 MT 117600
3 Tower Accessories
( Annex. 7)
4 Conductor ( Allowing
1.5% for Sag and wastage)
5 Conductor Accessories
(Annex. 8)
6 Ground Wire ( Allowing
1.5% for Sag and Wastage)
24770
6.09 140000 Kms 852600
16590
1004.18 40 Kg 40167.2
7 Ground Wire Accessories (
Annex. 9)
5760
8 INSULATORS (ANNEX.
10)
I) Suspension 48 350 Nos 16800
ii) Tension 510 400 Nos 204000
9 INSULATOR
HARDWARE (
ANNEX. 12)
I) Suspension 3 1600 Set 4800
ii) Tension 30 2100 Set 63000
10 Foundation Material, Sand,
Bajri and Concrete
(Annex. 7).
55.37 3200 Cu Mt. 177184
Sub Total 2740641.20

Sr. No Description Qty Rate Unit Amount in Rs
11 Transportation @5%,
Insutrance @ 1% and CST
@ 4% ( Total 10% on Item
1 to 10)
274064.12
12 Erection Charges
( Annex. 11)
525741.72
GRAND TOTAL 3540447.04
Say Rs 35.4
Sheet 8 Lacs

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
Annexure-5
BREAK UP ESTIMATE FOR 1 KM OF 220 KV S/C LINE ON D/C TOWERS
(NON SNOW ZONE)
Conductor size= 0.4 Sq. Inch Cu. Eq. "ACSR" ZEBRA
Earth Wire Size= 7/3.18 mm GSS 140 Kgf Quality.
Normal Span= 350 MTS
Sr. No Description Qty Rate Unit Amount in Rs
1 Steel for Towers ( Prefabricated
galvanised/ Painted ) Annex. 8
27.13 31000 MT 841133.33
2 Nuts and bolts ( Annex. 8) 1.36 60000 MT 81600
3 Tower Accessories ( Annex. 9) 24770
4 Conductor ( Allowing 1.5% for
Sag and wastage)
3.045 140000 Km 426300
5 Conductor Accessories (Annex.
10)
8295
6 Ground Wire Allowing (1.5% for
Sag and Wastage)
1004.18 40 Kg 40167.2
7 Ground Wire Accessories (
Annex. 11)
5760
8 INSULATORS (ANNEX. 12)
I) Suspension 22.5 350 Nos 7875
ii) Tension 240 400 Nos 96000
9 INSULATOR HARDWARE
(ANNEX. 12)
I) Suspension 1.5 1600 Set 2400
ii) Tension 15 2100 Set 31500
10 Foundation Material, Sand, Bajri
and concrete (Annex. 8)
25.33 3200 Cu. Mt 81056
Sub Total 1646856.53
11 Transportation @ 5%, Insurance
@ 1% and CST @ 4% ( Total
10% on Item 1 to 10)
164685.65
12 Erection Charges ( Annex. 14) 292049.56
GRAND TOTAL 2103591.7
Say Rs 21.0
Sheet 9 Lacs

Annexure-6
CHHATRU HYDRO-ELECTRIC-PROJECT
1 Span 350 Mtr
2
No. of Towers per 10 Km
TRANSMISSION WORKS - COST ESTIMATES
Type of Tower Normal Tower Tower with
3 mtr extn.
Tower with 6
mtr extn.
Total
W ( 0-2) 3 1 1 5
X ( 2-15) 3 1 1 5
Y ( 15-30) 10 1 1 12
Z ( 30-60) 8 8
Total 24 3 3 30
3 No. of Tower
Foundation / 10
Kms
W-Type X-Type Y-Type Z-Type
Normal Soil 5 5 12 8
4
WEIGHT FOR TOWERS INCLUDING NUTS AND BOLTS
Type of Tower Wt. Of Normal Wt. Of 3 Wt. Of 6 mtr.
Tower mtr. Extn Extn
W(0-2) 6.5x3=19.5 7.3 8.2
X ( 2-15) 3x11.9= 35.7 13.5 14.6
Y ( 15-30) 10x13.9= 139 15.7 17.2
Z ( 30-60) 8x17.7=141.6
Total 335.8 36.5 40
5 TOTAL I/C
NUTS AND
BOLTS
6 WT. OF NUTS
AND BOLTS (
5% OF TOWER
WEIGHT)
7 TOWER STEEL
PER KM
TOWER WEIGHT, CONCRETE FOR FOUNDATION
AND EXCAVATION FOR FOUNDATION
(SNOW ZONE)
412.3 MT
19.60 MT
39.27 MT

8 WT. OF NUTS
AND BOLTS
PER KM
1.96 MT
9 VOLUME OF CONCRETE AND EXCAVATION FOR TOWER FOUNDATION
Type of Tower No. of Tower
Foundations
/10 kms
Volume of
Excavation
( Cu. Mtr.)
Volume of
Concrete (
M^3)
W 5 176.5 17.5
X 5 334 39
Y 12 1393.2 207.6
Z 8 1453.6 289.6
Total 30 3357.3 553.7
10 VOLUME OF
CONCRETE PER
KM
55.37 Cu. Mt
11 VOLUME OF
EXCAVATION
PER KM
335.73 Cu. Mt.
Sheet 10

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
Annexure-8
TOWER WEIGHT, CONCRETE, FOR FOUNDATION
AND EXCAVATION FOR FOUNDATION
(NON SNOW ZONE)
1 Span 350 Mtr
2
No. of Towers per 10 Km
Type of Tower Normal Tower with 3 Tower with 6 Total
Tower mtr extn. mtr extn.
S ( 0-2) 3 1 1 5
T ( 2-15) 3 1 1 5
U ( 15-30) 10 1 1 12
V ( 30-60) 8 8
Total 24 3 3 30
3 No. of Tower
Foundation / 10
Kms
S-Type T-Type U-Type V-Type
4
Normal Soil 5 5 12 8
WEIGHT FOR TOWERS INCLUDING NUTS AND BOLTS
Type of Tower Wt. Of
Normal
Tower
Wt. Of 3 mtr.
Extn
Wt. Of 6 mtr.
Extn
S(0-2) 6x3=18 6.7 7.6
T ( 2-15) 3x7.5=
22.5
8.5 9.7
U ( 15-30) 10x9.2=
92
10.4 11.9
V ( 30-60) 8x12.2=9
7.6
Total 230.1 25.6 29.2
5 TOTAL 284.9 MT
6 WT. OF NUTS
AND BOLTS (
5% OF TOWER
WEIGHT)
13.60 MT
7 TOWER
STEEL PER
KM
27.13 MT

TOWER WEIGHT, CONCRETE, FOR FOUNDATION
AND EXCAVATION FOR FOUNDATION
(NON SNOW ZONE)
8 WT. OF NUTS
AND BOLTS
PER KM
1.36 MT
9
VOLUME OF CONCRETE AND EXCAVATION FOR TOWER
FOUNDATION
Type of Tower No. of
Tower
Foundatio
ns /10
kms
Volume of
Excavation (
Cu. Mtr.)
Volume of
Concrete (
M^3)
S 5 164.55 16
T 5 252.15 26.2
U 12 656.4 71.4
V 8 934.48 139.68
Total 30 2007.58 253.28
10 VOLUME OF
CONCRETE PER
KM
25.33 Cu. Mt
11 VOLUME OF
EXCAVATION
PER KM
Sheet 21
200.76 Cu. Mt.

Annexure-7
CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
TOWER FIXTURE FOR 220 KV D/C LINE.
Sr. No Description Qty Rate Unit Amount in Rs
1 Earthing Sets
I) Counterpoise 25 3000 Nos 75000
ii) Pipe Type 5 1400 NOs 7000
2 Danger Plates 30 300 Nos 9000
3 Number Plates 30 300 Nos 9000
4 Bird Guard 5 540 Sets 2700
5 Phase Plates 60 250 Sets 15000
6 Anti Climbing 30 2500 Nos 75000
7 Barbed wire
Galvanised
1000 40 Kg 40000
8 Circuit Plates 60 250 Nos 15000
Total Cost per 10 Kms 247700
9 Cost per Km 24770
Sheet 11

Annexure-8
CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
CONDUCTOR ACCESSORIES FOR 220 KV D/C LINE.
Sr. No Description Qty Rate Unit Amount in Rs
1 Preformed Armour rods sets
complete with Ferrules for
Suspension Towers ( 2x3x5)
30 550 Nos 16500
2 Stock Bridge vibration
Dampers ( 30x 2 x 3
x2=360)
360 330 Nos 118800
3 Mid Span Compression Joints 52 300 Nos 15600
4 Other Miscellaneous Items
e.g. PG Clamps, Binding
Wire etc.
1 LS 15000
Total Cost per 10 Kms 165900
5 Cost of conductor
Accessories per Km
16590
Sheet 13

Annexure-9
CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
EARTHWIRE ACCESSORIES
Sr. No Description Qty Rate Unit Amount in Rs
1 Mid Span Compression
Joint Assembly
14 100 Nos 1400
2 Suspension Assembly for
GSS Wire 7/3.15 mm
(2x5=10)
10 300 Nos 3000
3 Compression Type
Tension Assembly for
GSS Wire 7/3.15 mm
with Terminal Jumpers
( 25x2x 2=100)
100 400 Nos 40000
4 Flexible grounding Leads
for Earthing GSS Wire
(1x2x5+2x2x25)
110 120 Nos 13200
Total Cost for 10 Kms 57600
Cost for 1 Km
sheet 15
5760

Annexure-10
CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
QUANTITIES OF HARDWARES AND INSULATORS
FOR 220 KV D/C LINE.
Sr. No Description
Qty
Snow Zone
A FOR SUSPENSION TOWERS
I) Number of suspension Insulators Strings
per 10 Kms ( Nos)
30
ii) Number of Discs per Suspension insulators
Strings (Nos)
16
iii) Number of suspension Insulators Discs per
10 Kms ( Nos)
480
iv) Number of suspension Insulators Discs per
Kms ( Nos)
48
v) Number Suspension Hardware per 10 Kms
( Sets)
30
vi) Number Suspension Hardware per Kms
( Sets)
3
B FOR TENSION TOWERS
I) Number of Tension Insulator Strings per 10
Kms ( Nos)
300
ii) Number of Tension Discs per String ( Nos) 17
iii) Number of Tension Discs per 10 Km
( Nos)
5100
iv) Number of Tension Discs per Km ( Nos) 510
v) Number of Tension Hardware per 10 Km
( Sets)
vi) Number of Tension Hardware per Km
( Sets)
Sheet 16
300
30

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
SCHEDULE OF COST ANALYSIS FOR ERECTION
CHARGES OF 220 KV D/C LINE ( SNOW ZONE)
Annexure-11
Sr. No Description Qty Rate Unit Amount in Rs
1 Excavation and Backfill per
Km
335.73 185 Cu Mt 62110.05
2 Concreting I/c Dewatering
etc.
55.37 4500 M^3 249165
3 Erection of Towers 39.27 4000 MT 157066.67
4 Stringing of Conductor 1 50000 Km 50000
5 Stringing of Earth Wire 1 3800 Km 3800
6 Earthing of Towers 3 1000 Nos 3000
7 Fixing of Tower
Accessories
3 200 Nos 600
Total Cost of Erection of
Towers per Km
Sheet 17
525741.72

KHOKSAR HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
Annexure-14
SCHEDULE OF COST ANALYSIS FOR ERECTION
CHARGES OF 220 KV S/C LINE ON D/C TOWERS (NON SNOW ZO
Sr. No Description Qty Rate Unit Amount in Rs
1 Excavation and
Backfill per Km
200.76 185 Cu Mt 37140.23
2 Concreting I/c
Dewatering etc.
25.33 4500 M^3 113976
3 Erection of Towers 27.13 4000 MT 108533.33
4 Stringing of Conductor 1 25000 Km 25000
5 Stringing of Earth
Wire
1 3800 Km 3800
6
3 1000 Nos 3000
Earthing of Towers
7 Fixing of Tower
Accessories
Total Cost of
Erection of Towers
per Km
Sheet 18
3 200 Nos 600
292049.56

ONE)

KHOKSAR HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
SCHEDULE OF COST ANALYSIS FOR TERMINAL
EQUIPMENT AT TANDI
Annexure-12
Sr. No Description Qty Rate Unit Amount in
Lacs
1 220 KV SF6 Out doortype 3
phase Circuit Breaker
complete
2 15 Nos 30
2 220 KV Control and Relay
Panels
2 9.3 Nos 18.6
3 220 KV 3 phase Isolators
without Earth Swicth
4 3.2 Sets 12.8
4 220 KV 3 phase Isolators
with Earth Swicth
2 4.3 Sets 8.6
5 220 KV LAs 6 0.78 Nos 4.68
6 Multi Core Multi Ratio CTs 6 2 Nos 12
7 Structures 60 0.32 MT 19.2
8 Bus Bar Material and
Insulators
Lot LS 14
9 Power and Control Cables
and EI Works etc.
Lot LS 24
Sub Total-I 143.88
10 Transportation @ 5%, Spares
@ 3%, Insurance @ 1%, CST
@ 4%,Civil Works @ 8% (
Total 21% on Sub Total-I)
30.21
12 Erection and commissioning
Charges @ 10% of Sub Total-
I)
14.39
GRAND TOTAL
Sheet 19
188.48

CHHATRU HYDRO-ELECTRIC-PROJECT
TRANSMISSION WORKS - COST ESTIMATES
VEHICLES AND WORKSHOP MACHINERY
Annexure-12
Sr. No Description Qty Rate Unit Amount in Lacs
1 7.5 Tons Trucks 2 8.5 Nos 17
2 Jeep/ Car 2 3.5 Nos 7
3 Maintenance van 1 4.5 Nos 4.5
4 Workshop Equipment such as
Lathe , Welding Sets, Drilling
machines , Power Hacksaw etc.
Lot LS 5.5
TOTAL
Sheet 20
34

CHHATRU HYDRO-ELECTRIC-PROJECT (108 MW)
COST ESTIMATES OF ELECTRO-MECHANICAL WORKS FOR PRE-FEASIBILITY REPORT
Sl.No. Item Qty Rate Amount Excise Duty* Total
Rs.(Lakhs) Rate Amount Amount
(Rs. Lakhs) (Rs. Lakhs)
1 2 3 4 5 6 7 8
1 Generating Unit and 11 KV Bus Duct 36MW,
428.6 RPM with net Head of 160 mtrs.
3 Rs.5600/KW 6048.00 16% 967.68 7015.68
2 Step-up transformer, 11/220KV,15MVA,single
phase
10 Rs.260/KVA 390.00 16% 62.40 452.40
3 Auxiliary Electrical Equipment for Power
Stations (Except transformer) (5% of item 1).
302.40 16% 48.38 350.78
4 Auxiliary Equipment and Services for Power
Stations (5% of item-1)
302.40 16% 48.38 350.78
5 220 KV Switchyard GIS. 6 bays 300 Lacs/bay 1800.00 16% 288.00 2088.00
6 Spares (5% of 1 and 3% of 2-5) 386.24 16% 61.80 448.04
7 Sub-Total-1: 9229.04 10705.68
8 Central Sales Tax ** 4% of item 1 to 6 428.23
9 Transportation & Insurance 6% of item-7 642.34
10 Erection and Commissioning 8% of item-7
(except spares)
820.61
11 Sub-Total-2 : 12596.86
12 Establishment, Contingency, other charges
11% of item-7 (excluding duties)
1015.20
Grand Total :- 13612.06
Say Rs. 13612 Lacs

DISCHARGE IN CUMECS
350.00
300.00
250.00
200.00
150.00
100.00
50.00
TIME IN HOURS
0 1 2 3 4
Effective rain fall in Cm
CHHATRU HEP
DESIGN FLOOD HYDROGRAPH FIG-A-II
Qp = 291.59 Cumecs
0.00
0 2 4 6 8 10 12 14 16 18 20
TIME IN HOURS
Series1

CHHATRU HEP
STANDARD PROJECT FLOOD HYDROGRAPH (SUG)
TIME ORDINATE RAINFALL EXCESS IN CM. SUB TOTAL BASE TOTAL
IN OF SUH DSRO IN FLOW FLOW IN
HOURS IN 0.11 1.52 5.75 0.71 CUMECS IN CUMECS
CUMECS CUMECS
1 2 3 4 5 6 7 8 9 10
1 0 0.00 0.00 2.40 2.40
2 1 0.11 0.00 0.11 2.40 2.51
3 7.5 0.79 1.52 0.00 2.30 2.40 4.70
4 20.28 2.13 11.38 5.75 0.00 19.26 2.40 21.66
5 40.25 4.23 30.76 43.14 0.71 78.83 2.40 81.23
6 27.5 2.89 61.05 116.65 5.33 185.91 2.40 188.31
7 15 1.58 41.71 231.50 14.40 289.19 2.40 291.59 PEAK
8 8 0.84 22.75 158.17 28.58 210.34 2.40 212.74
9 5.2 0.55 12.13 86.28 19.53 118.48 2.40 120.88
10 3.5 0.37 7.89 46.01 10.65 64.92 2.40 67.32
11 2.5 0.26 5.31 29.91 5.68 41.16 2.40 43.56
12 1.55 0.16 3.79 20.13 3.69 27.78 2.40 30.18
13 0.75 0.08 2.35 14.38 2.49 19.29 2.40 21.69
14 0.3 0.03 1.14 8.92 1.78 11.86 2.40 14.26
15 0 0.00 0.46 4.31 1.10 5.87 2.40 8.27
16 0 0.00 0.00 1.73 0.53 2.26 2.40 4.66
17 0.00 0.00 0.21 0.21 2.40 2.61
18 0.00 0.00 0.00 2.40 2.40
19 0.00 0.00 2.40 2.40
20 0.00 2.40 2.40
21 2.40 2.40
22 0.00
Flood for 1 in 100 years can be worked out from Fuller's formula as
Q 100 =
Q 50 (1+0.80 log T 100/1+0.80log T 50)
Annexuure - 2
= 321.38 Cumecs
Snow contribution = = 342.09 Cumecs
(Snow contribution has been taken as the maximum discharge in the flow series during
the 2nd week of July)
Total design flood = 663.468 Cumecs
Say 665 Cumecs
REM-
ARKS

CHHATRU HEP Annexure - 1
Cumputation of Equivalent slope of river Chenab in respect of Chhatru HEP
S.No.
Ruduced
RD In K
Level
m
in m
leanth of
each
segment
Li in Km
Height
above (Di-1+Di) In
Li X (Di-1+Di)
Datum Di m
in m
1 2 3 4 5 6 7
1 0.00 3405.00 0.00 0.00 0.00 0.00
2 0.75 3420.00 0.75 15.00 15.00 11.25
3 2.05 3440.00 1.30 35.00 50.00 65.00
4 2.75 3460.00 0.70 55.00 90.00 63.00
5 3.68 3480.00 0.93 75.00 130.00 120.90
6 4.43 3500.00 0.75 95.00 170.00 127.50
7 4.93 3520.00 0.50 115.00 210.00 105.00
8 5.38 3540.00 0.45 135.00 250.00 112.50
9 6.28 3560.00 0.90 155.00 290.00 261.00
10 6.58 3580.00 0.30 175.00 330.00 99.00
11 7.03 3600.00 0.45 195.00 370.00 166.50
12 7.46 3620.00 0.43 215.00 410.00 176.30
13 8.81 3640.00 1.35 235.00 450.00 607.50
14 9.81 3680.00 1.00 275.00 510.00 510.00
15 11.41 3720.00 1.60 315.00 590.00 944.00
16 12.51 3760.00 1.10 355.00 670.00 737.00
17 14.11 3800.00 1.60 395.00 750.00 1200.00
18 16.11 3840.00 2.00 435.00 830.00 1660.00
19 17.91 3880.00 1.80 475.00 910.00 1638.00
20 23.91 3920.00 6.00 515.00 990.00 5940.00
21 27.91 3960.00 4.00 555.00 1070.00 4280.00
22 31.41 4000.00 3.50 595.00 1150.00 4025.00
Total 22849.45
S = Li X (Di-1+Di)/ L 2 = 23.16
m/Km
Datum = 3405 m I,e R.L. of river bed at point of study.

ESTIMATE OF DESIGN FLOOD FOR CHHATRU HEP
UNIT HYDROGRAPH METHOD
COMPUTATION OF ONE HOUR SYNTHETIC UNIT GRAPH
Ref;- FLOOD ESTIMATION REPORT FOR WESTERN HIMALAYAS - ZONE 7 (CWC)
i) Name of zone Western Himalayas
ii) Name of river Chandra River in Chenab basin
iii) Shape of Catchment Leaf Shaped
iv) Location Lat. 32°-18'-08"
Long. 77°-24'-39"
v) Topography Steep slope
Step -1 Physiographic Parameters
1 Permanent Snow Line 4000 m
2 Total catchment area at diversion site 1583 Sq. Km
(Ref. Drg. No Chhatru-PR-3)
3 Permaqnent snow covered area above EL4000m. 1535 Sq.km.
4. Catchment area contribution to run-off ( Ref.FIG - A) 48 Sq.km.
5. Length of the longest (Stream) ( L ) 31.41 Km
6 Length of the longest (Stream) from a point
apposit to C.G. of catchment to point of study (LC) 11.80 Km
7 Equivalent stream slope (S) 23.16 m/Km
(Refer Annexure-1)
Step -2:1-hr. Synthetic unit graph
I) tp = 2.498(LxLC/S) 0.,156
Annexure V - 1
3.85 hrs
4.00 hr
and taken 0.5 hr. less than the completed value for
highest peak. = 3.50 hrs
ii) qp = 1.048(tp) -0.178
0.84 Cum/SqKm
iii) W50 = 1.954x(LxLC/S) 0.099
2.57 hrs
iv) W75= 0.972x(LxLC/S) 0.124
1.37 hrs
v) Wr50= 0.189x(W50) 1.769
1.00 hrs
vi) Wr75= 0.419x(W75) 1.246
0.62 hrs
vii) TB= 7.845x(tp) 0.453
Taking tp in multiple of 1-0 hr. I.e.
13.84 hrs
viii) Qp = qpxA 40.25 Cumecs
Estimated parameter of unit graph in Step-1 were plotted on a graph paper as shown in
Fig. A-I. The plotted points were joined to draw synthetic unit graph. The discharge
ordinates(Qi) of the unit graph at ti=tr=1 hr. interval were summed up and multiplied by
tr=1 and compared with the volume of 1.00cm direct run-off depth over the catchment
computed from the formula.
Q= Axd/0.36xtr
Where A = Catchment area in Sq.km.
d= 1.0m depth
ti= tr(the unit duration of the UG)=1 hr.
The following limb of the hydrograph is suitably modified without altering the points of
synthetic parameters.
133 Cumecs

Step-3 Estimation of design storms
a) Design storm duration
The design storm duration TD has been adopted as 1,1x1xtp
TD = 1.1xtp
TD = 1.1x3.5 3.85 Say 4 Hrs
b) Estimation of point rain fall and areal rainfall for storm duration
Catchment under study was located on Plate-9, P=-58, showing 50 year 24 hr./ point
rainfal. The point fainfall was found to be = 16 cm.
Coversion factor read from Fig. 3, P-67 to convert 50-yr. 24 hr. point rainfall to
50 yr. 4 hr. point rainfall is = 0.65
Hence 50 year 4 hr, point rainfall is = 10.40 cm.
Areal reduction factor = 0.97 corresp. to the C.A. = 48
Sqkm. For TD = 4 hr. was interpolated from
Annexure-4.2. P-42,for conversion of point rainfall to areal rainfall.
50Year 4 hr. Areal rainfall worked out to be = 10.08 cm.
The 50-yr. 4 hr. areal rainfall spilt in to 1-hr. rainfall increments using time
distribution co-efficient given in Annexure-4.1, P-41.
A design loss rate of 0.20 cm/hr. as recommended in para 3.5,P-15
has been used to get effective rainfall hyetograph.
Duration
Hourly effective rainfall increments Table - 1
Distribution
co-efficient
increment
1 2 3 4 5 6
1 0.62 6.25 6.25 0.50 5.75
2 0.82 8.27 2.02 0.50 1.52
3 0.94 9.48 1.21 0.50 0.71
4 1.00 10.08 0.61 0.50 0.11
Step-4 Estimation of base flow
Taking design base flow of = 0.05 cumecs per Sq.km. as recommended.
in para 3.6 P-15, the base flow as ground water estimated as
2.4 cumecs for 48 Sq.km. catchment area.
Step-5 Estimation of 50 year flood
Storm
rainfall
(cm)
a) Compputaiton of flood peak
Rainfall
increments
(cm)
Loss per
hr. (cm)
Effective rainfall
increments
For estimation of the peak discharge , the effective rainfall increments were
re-arranged against ordinates such that the maximum effective rainfall
is placed against the maximum U.G. oridnate,next lower value of effective
rainfall against next lower value of U.G. ordinate and so on as shown in
column (2) in Table - 2.Sum of the product of U.G. ordinates and effective
rainfall increments gives total direct surface run off to which
base flow is added to get total peak discharge.

50 year Peak flood Table - 2
U.G.
1 hr.
Time hrs.
ordinates
effective
Direct run-off
cumecs
rainfall
1 2 3 4
1 20.28 0.71 14.40
2 40.25 5.75 231.50
3 27.50 1.52 41.71
4 15.00 0.11 1.58
Total 289.19
Base flow 2.40
50 year flood peak 291.59
Say 292 Cumecs
b) Computation of design flood hydrograph
Effective rainfall increments shown in col. 3 of table-2 in step 5. above were
reversed to obtain critical sequence as shown below
( Critical sequence of rain fall )
Time in hrs. Crirital 1-hr. effective rainfall sequence cms.
1 0.11
2 1.52
3 5.75
4 0.71
Table - 3.
For computation of design flood hydrograph, the U.G. ordinates were tabulated in
Col. (2) of Annexure-2. The critical sequence of effective rainfall increments were
entered in col. 3 to 6 horizontally. Direct run of resulting from each of the
effective rainfall increments was obntained by multiplying effective rainfall
depths with the synthetic U.G. ordinates in col. 2 and direct run off
values were entered in columns against each unit with a successive lag of 1 hr.
since the unit duration of S.U.G. is 1 hr. Direct run off values are shown in col. 3 to 6.
Direct run off values were added horizontally and total direct runoffis shown in col. 7. Adding
Adding total base flow of = 2.40 cumecs ( col.8) .
Design flood hydrograph ordinates in col.9 were obtained. Design
flood hydrograph was plotted against time as shown fig. A-II
The peak obtained was = 291.59 cumecs for 1 in 50 years
which talies with the peak shown in Table-2
Flood for 1 in 100 years can be worked out from Fuller's formula
and has been worked out as = 321.38 Cumecs (i)
Snow contribution = = 342.09 Cumecs (ii)
(Snow contribution has been taken as the maximum discharge in flow series during
the 2nd week of July)
The total design flood (i) + (ii) 663.47 cumecs
The design flood has also been worked out by Gumble's flood frequency method
considering top eight flood events of G&D site w.e.f. June 1973 to May 2001 as per data
collected from CWC, Chenab Divn, Jammu vide letter Dt.13/1/04 (copy encl. Annexure. 3)
which is = 1377.59 Cumecs for 1000 years (Annxure-4)
However design flood of 1500 cumecs has been considered for computation
of HFL for designing the diversion stucture of this project

1 HOUR SYNTHETIC UG
ORDINATES
1 HOUR SYNTHETIC
UG PARAMETERS
CA = 48.00 Sq. Km. 0 0
tr = 1.00 Hr 1 1
Qp = 40.25 Cumecs 2 7.5
qp = 0.84 Hrs 3 20.28
tp = 3.50 Hrs 4 40.25
Tm = 4.00 Hrs 5 27.5
TB = 13.84 Hrs 6 15
W50 = 2.57 Hrs 7 8
W75 = 1.37 Hrs 8 5.2
Wr50= 1.00 Hrs 9 3.5
Wr75 = 0.62 Hrs 10 2.5
d = 1.00 Cm 11 1.55
12 0.75
13 0.3
Q = A X d /tr X0,36 14 0
133.33 Cumecs TOTAL 133.33

CHHATRU HEP ANNEXURE-4 ( i )
DESIGN FLOOD - GUMBLE'S FLOOD FREQUENCY ANALYSIS
C.A AT GHOUSAL 2406.25 SqKm
C.A AT CHHATRU 1583 SqKm
C.F. 0.658
Sr. No. Date/ Year Max.Flood Discharge Max.Flood Discharge Max.Flood Discharge Q' - Q (Q ' - Q )^2
in Cumecs at G& D in Cumecs at Q in Cumecs in
Site Ghousal Diversion Site Descending order (Cumecs) (Cumecs)
1 8.8.78 625 411 611 -121.870 14852.40
2 25.7.87 636 418 579 -90.293 8152.77
3 21.7.88 631 415 570 -81.082 6574.37
4 29.7.89 866 570 461 28.124 790.96
5 19.7.91 700 461 445 43.913 1928.34
6 6.7.95 676 445 418 70.228 4931.92
7 8.7.98 928 611 415 73.517 5404.75
8 10.7.99 880 579 411 77.464 6000.70
TOTAL 3909 0 48636
MEAN DISCHARGE Q ' 488.63
TOTAL NO. OF YEARS n 8
Standard deviation d = (Q ' - Q )/n-1
= 83.35
Co-efficient of variation Cv = d / Q'
Cv = 0.1706
For 8 years period
Reduced standard deviation Sn = 0.9496 Refer book Irrigation Engg &
Reduced mean Yn = 0.4952 Hyd. Structure by S.K.Garg
Q max. = Q' (1+Cv*(Y-Yn)/Sn) Page No.441
= 488.63(1+0.1706*(Y-0.4952)/0.9496) 445.16
Q max. = 445.16+87.78Y 87.78

CHHATRU HEP ANNEXURE-4 ( ii )
COMPUTATION OF DESIGN FLOOD
RETURN Xt = REDUCED VARIATE MAX. FLOOD INST. FLOOD PROBABILITY
PERIOD log log( T/T-1) Y= Qmax = 1.15 TIMES OF
T in Years 0.834032 - 2.302585Xt 445.16+87.78Y MAX.FLOOD % AGE
10000 -4.362 10.878 1400.062 1610.07 0.01
5000 -4.061 10.185 1339.213 1540.10 0.02
1000 -3.362 8.575 1197.902 1377.59 0.1
500 -3.061 7.882 1137.013 1307.57 0.2
200 -2.662 6.964 1056.449 1214.92 0.5
100 -2.360 6.268 995.384 1144.69 1
50 -2.057 5.570 934.095 1074.21 2
25 -1.751 4.867 872.350 1003.20 4
10 -1.340 3.918 789.120 907.49 10
Considering Design Flood of 1000 Years Return Period to be SPF
which works Out to be = 1377.59 Cumecs

DISCHARGE (CUMECS)
45
40
35
30
25
20
15
10
5
0
tr
Wr50=1.00
Hrs
Tm=4 hrs CHHATRU HEP
Wr75=0.62
Hrs
1 cm rainfall excess
tp=3,50 HRS
TB =13.84 Hrs
SYNTHETIC UNIT HYDROGRAPH FIG-A-II
Qp=40.25 Cumecs
W 75= 1.37Hrs
W 50 =2.57 Hrs
0 2 4 6 8 10 12 14 16
TIME (HOURS)

COMPUTATION NO- Chhatru HEP -PR-SS chhatru HEP
REF DRG. NO-chhatru-PFR-
CALCULATIONS OF UPSURGE & DOWNSURGE IN SURGE SHAFT
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
BASIC PARAMETERS 1) DIAMETER OF HRT =
2) LENGTH OF HRT =
3) DESIGN DISCHARGE =
4) VELOCITY IN HRT =
5) DIAMETER OF MAIN
PENSTOCK =
6) NO. OF MAIN PENSTOCK
7) DIAMETER OF BRANCH
PENSTOCK =
8) NO.OF BRANCH PENSTOC
9) VELOCITY IN PENSTOCK
10) DIAMETER OF SURGE
SHAFT =
11) SURGE HT. NEGLECTIN
LOSSES = Z* =
12) HEAD LOSS IN ORIFIC
MAXIMUM =
MINIMUM =
AVERAGE =
13) RUGOSITY COEFFICIEN
MAXIMUM =
MINIMUM =
AVERAGE =
14) FRICTION COEFFICIEN
MAXIMUM =
MINIMUM =
AVERAGE =
15) HEAD LOSS IN HRT =h
MAXIMUM =
MINIMUM =
AVERAGE =
16) COEFFICIENT OF HYDR
MAXIMUM =
MINIMUM =
AVERAGE =
17) COEFFICIENT OF RESI
MAXIMUM =
MINIMUM =
AVERAGE =
18) TIME INTERVAL
IN SECONDS =

CASE - I MAXIMUM UPSURGE FOR TOTAL REJECTION ( 100 - 0 )%
AT MAXIMUM RESERVOIR LEVEL & MINIMUM LOSSES IN HRT
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
TIME VELOCITY UPSURGE CHANGE TOTAL V1^2 x
INTERVAL IN HRT Z IN UPSUR- UPSURGE (B+N+1/2g)
dt in V1 IN GE z+dz =Z
sec. M/SEC. dz
1 2 3 4 5 6
0.00 3.64 -9.84 0.00 -9.84 0.00
10.00 3.64 -9.84 4.20 -5.64 37.93
20.00 3.15 -5.64 3.64 -2.00 28.44
30.00 2.75 -2.00 3.18 1.18 21.69
40.00 2.40 1.18 2.78 3.96 16.59
50.00 2.09 3.96 2.42 6.38 12.58
60.00 1.81 6.38 2.09 8.47 9.38
70.00 1.54 8.47 1.78 10.25 6.79
80.00 1.28 10.25 1.48 11.73 4.71
90.00 1.03 11.73 1.19 12.92 3.06
100.00 0.79 12.92 0.92 13.84 1.80
110.00 0.56 13.84 0.64 14.48 0.89
120.00 0.32 14.48 0.37 14.85 0.30
130.00 0.10 14.85 0.11 14.96 0.03
140.00 -0.13 14.96 -0.15 14.81 0.05
150.00 -0.36 14.81 -0.41 14.40 0.36
160.00 -0.58 14.40 -0.67 13.73 0.96
170.00 -0.80 13.73 -0.92 12.81 1.84
180.00 -1.02 12.81 -1.18 11.63 2.99
190.00 -1.24 11.63 -1.44 10.19 4.42
200.00 -1.46 10.19 -1.69 8.50 6.14
210.00 -1.68 8.50 -1.95 6.56 8.13
220.00 -1.90 6.56 -2.20 4.36 10.41

CASE - II MINIMUM DOWNSURGE AT MDDL OF RESERVOIR AT MINIMUM
HEAD LOSSES IN HRT (100-0-33.33)% , V1 = 3.64
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
TIME VELOCITY MAXIMUM
INTERVAL IN HRT Z in DOWN V1^2(-B-N+1/
COMPUTATION NO- chhatru HEP -PR-SS
REF DRG. NO-chhBHR-
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
1 2 3 4 5 6
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
140.00 -0.13 14.96 -0.15 14.81 -0.05
150.00 -0.36 14.81 -0.41 14.40 -0.35
160.00 -0.57 14.40 -0.66 13.75 -0.89
170.00 -0.76 13.75 -0.88 12.87 -1.60
180.00 -0.93 12.87 -1.08 11.79 -2.40
190.00 -1.07 11.79 -1.24 10.55 -3.19
200.00 -1.18 10.55 -1.37 9.18 -3.88
210.00 -1.26 9.18 -1.46 7.72 -4.42
220.00 -1.31 7.72 -1.52 6.20 -4.78
230.00 -1.34 6.20 -1.54 4.66 -4.94
240.00 -1.33 4.66 -1.54 3.12 -4.90
250.00 -1.30 3.12 -1.51 1.61 -4.71
260.00 -1.26 1.61 -1.45 0.16 -4.38
270.00 -1.19 0.16 -1.38 -1.22 -3.94
280.00 -1.12 -1.22 -1.29 -2.51 -3.45
290.00 -1.03 -2.51 -1.19 -3.70 -0.73
300.00 -0.96 -3.70 -1.11 -4.81 -0.64

CASE - II MINIMUM DOWNSURGE AT MDDL OF RESERVOIR AT MINIMUM
Contd. HEAD LOSSES IN HRT . (100-0-33.33
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
TIME VELOCITY MAXIMUM -BV1^2
INTERVAL IN HRT DZ in DOWN -N(V1-V2)^2
dt in V1 IN m Z in m SURGE +1/2G*V1^2
sec. M/SEC. Z+DZ (3+4)
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
1 2 3 4 5 6
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
240.00 -1.33 -3.66 3.12 -0.54 -28.47
250.00 -0.89 -3.15 -0.54 -3.69 -19.91
260.00 -0.54 -2.74 -3.69 -6.43 -14.13
270.00 -0.23 -2.38 -6.43 -8.81 -9.97
280.00 0.06 -2.06 -8.81 -10.87 -6.87
290.00 0.32 -1.75 -10.87 -12.62 -4.56
300.00 0.58 -1.45 -12.62 -14.07 -2.90
310.00 0.84 -1.15 -14.07 -15.22 -1.82
320.00 1.10 -0.85 -15.22 -16.07 -1.29
330.00 1.36 -0.55 -16.07 -16.62 -1.31
340.00 1.63 -0.24 -16.62 -16.86 -1.95
350.00 1.91 0.09 -16.86 -16.77 -3.28
360.00 2.22 0.44 -16.77 -16.33 -5.44
370.00 2.55 0.82 -16.33 -15.51 -8.65
380.00 2.91 1.24 -15.51 -14.27 -13.28
390.00 3.33 1.72 -14.27 -12.55 -19.93
400.00 3.82 2.29 -12.55 -10.26 -29.63

~~~
5.10 METRES
6500.00 METRES
75.00 CUMECS.
3.64 M/Sec.
4.70 METRES
K = 1.00 NOS.
2.70 METRES
CK = 3.00 NOS.
K =
MAIN = 4.33 M/Sec.
BRANCH = 4.37 M/Sec.
15.00 METRES
NG
CE =hor
NT =n
NT =f
hf
31.82 METRES
30.19 METRES
27.42 METRES
29.20 METRES
0.02
0.01
0.01
0.02
0.01
0.01
15.38 METRES
9.84 METRES
13.40 METRES
RAULIC LOSSES IN HRT =B
1.16 CASE-I
0.74
1.01
CASE-II(i)
ISTANCE FOR ORIFICE =N
2.28
2.07 CASE-II(ii)
2.21
10.00

~~~
COL.(5+6) dv=-g/ L dt
*Col.7
7 8
0.00 0.00
32.30 -0.49
26.44 -0.40
22.87 -0.35
20.54 -0.31
18.96 -0.29
17.85 -0.27
17.04 -0.26
16.44 -0.25
15.98 -0.24
15.64 -0.24
15.37 -0.23
15.15 -0.23
14.99 -0.23
14.86 -0.22
14.76 -0.22
14.69 -0.22
14.64 -0.22
14.62 -0.22
14.62 -0.22
14.64 -0.22
14.69 -0.22
14.77 -0.22

m/sec. v2 = 0.00 m/sec.
~~~
dv= -g/l dtx
COL. Col.7
~~~
~~~
7 8
14.86 -0.22
14.05 -0.21
12.85 -0.19
11.26 -0.17
9.39 -0.14
7.36 -0.11
5.30 -0.08
3.30 -0.05
1.42 -0.02
-0.28 0.00
-1.79 0.03
-3.10 0.05
-4.22 0.06
-5.17 0.08
-5.96 0.09
-4.43 0.07
-5.44 0.08

0.00

V1 = 1.34 m/sec. v2 = 1.46 m/sec.
~~~
dv= -g/l dtx
COL. *Col.7
(5+6)
~~~
~~~
7 8
-29.01 0.44
-23.60 0.36
-20.56 0.31
-18.78 0.28
-17.74 0.27
-17.18 0.26
-16.97 0.26
-17.04 0.26
-17.36 0.26
-17.93 0.27
-18.81 0.28
-20.05 0.30
-21.77 0.33
-24.16 0.36
-27.55 0.42
-32.48 0.49
0.00 0.00

(0-33.33)% (0-100)% (100-0)%
V1 = 0.00 0.00
V2 = 4.37 4.33
V1 = 1.34 3.64
V2 = 1.46 0.00
VI 1.63
VII 1.46

COMPUTATION NO-
REF DRG. NO-UHL
CALCULATIONS OF
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
BASIC PARAMETER

CASE - I
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
TIME VELOCITY
INTERVAL IN HRT
dt in V1 IN
sec. M/SEC.
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
1 2
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
0.00 3.05
10.00 3.05
20.00 2.72
30.00 2.44
40.00 2.21
50.00 2.00
60.00 1.81
70.00 1.64
80.00 1.47
90.00 1.32
100.00 1.16
110.00 1.02
120.00 0.88
130.00 0.74
140.00 0.60
150.00 0.46
160.00 0.33
170.00 0.20
180.00 0.07
190.00 -0.06
200.00 -0.19
210.00 -0.32
220.00 -0.45

CASE - II
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
TIME VELOCITY
INTERVAL IN HRT
COMPUTATION NO-
REF DRG. NO-UHL
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
1 2
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
190.00 -0.06
200.00 -0.19
210.00 -0.32
220.00 -0.44
230.00 -0.55
240.00 -0.65
250.00 -0.74
260.00 -0.82
270.00 -0.88
280.00 -0.93
290.00 -0.97
300.00 -0.99
310.00 -1.00
320.00 -1.00
330.00 -0.98
340.00 -0.96
350.00 -0.93

-0.89
-0.89

CASE - II
Contd.
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
TIME VELOCITY
INTERVAL IN HRT
dt in V1 IN
sec. M/SEC.
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
1 2
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
320.00 -1.00
330.00 -0.78
340.00 -0.56
350.00 -0.36
360.00 -0.15
370.00 0.06
380.00 0.26
390.00 0.47
400.00 0.68
410.00 0.90
420.00 1.12
430.00 1.35
440.00 1.59
450.00 1.84
460.00 2.11
470.00 2.40
480.00 2.71

- UHL STAGE-III-PR-SS-
L-PR-15
F UPSURGE & DOWNSURGE IN SURGE SHAFT
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
RS 1) DIAMETER OF HRT =
2) LENGTH OF HRT =
3) DESIGN DISCHARGE =
4) VELOCITY IN HRT =
5) DIAMETER OF MAIN
PENSTOCK =
6) NO. OF MAIN PENSTOCK =
7) DIAMETER OF BRANCH
PENSTOCK =
8) NO.OF BRANCH PENSTOCK =
9) VELOCITY IN PENSTOCK =
10) DIAMETER OF SURGE
SHAFT =
11) SURGE HT. NEGLECTING
LOSSES = Z* =
12) HEAD LOSS IN ORIFICE =hor
MAXIMUM =
MINIMUM =
AVERAGE =
13) RUGOSITY COEFFICIENT =n
MAXIMUM =
MINIMUM =
AVERAGE =
14) FRICTION COEFFICIENT =f
MAXIMUM =
MINIMUM =
AVERAGE =
15) HEAD LOSS IN HRT =hf
MAXIMUM =
MINIMUM =
AVERAGE =
MAIN =
BRANCH =
16) COEFFICIENT OF HYDRAULIC LOSSES IN HRT
MAXIMUM =
MINIMUM =
AVERAGE =
17) COEFFICIENT OF RESISTANCE FOR ORIFICE =
MAXIMUM =
18) TIME INTERVAL
IN SECONDS =
MINIMUM =
AVERAGE =

MAXIMUM UPSURGE FOR TOTAL REJECTION ( 100 - 0 )%
AT MAXIMUM RESERVOIR LEVEL & MINIMUM LOSSES IN HRT
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
UPSURGE CHANGE TOTAL V1^2 x COL.(5+6)
Z IN UPSUR- UPSURGE (B+N+1/2g)
GE z+dz =Z
dz
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
3 4 5 6 7
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
-12.65 0.00 -12.65 0.00 0.00
-12.65 3.11 -9.54 40.33 30.79
-9.54 2.77 -6.77 31.95 25.18
-6.77 2.49 -4.28 25.82 21.54
-4.28 2.25 -2.03 21.10 19.07
-2.03 2.04 0.01 17.31 17.32
0.01 1.85 1.86 14.20 16.05
1.86 1.67 3.52 11.59 15.11
3.52 1.50 5.02 9.37 14.40
5.02 1.34 6.36 7.48 13.85
6.36 1.19 7.55 5.86 13.41
7.55 1.04 8.59 4.48 13.07
8.59 0.89 9.48 3.32 12.80
9.48 0.75 10.23 2.34 12.57
10.23 0.61 10.84 1.55 12.39
10.84 0.47 11.31 0.93 12.24
11.31 0.34 11.65 0.47 12.12
11.65 0.20 11.85 0.17 12.02
11.85 0.07 11.92 0.02 11.94
11.92 -0.06 11.86 0.02 11.87
11.86 -0.20 11.66 0.16 11.82
11.66 -0.33 11.33 0.45 11.78
11.33 -0.46 10.88 0.87 11.75

MINIMUM DOWNSURGE AT MDDL OF RESIRVOIR AT MAXIMUM
HEAD LOSSES IN HRT (100-0-50)% , V1 = 3.05 m/sec. v2 = 0.
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
MAXIMUM
Z in DOWN V1^2(-B-N+1/2G COL.
- UHL STAGE-III-PR-SS-
L-PR-16
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
3 4 5 6 7
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
11.92 -0.06 11.86 -0.01 11.87
11.86 -0.20 11.66 -0.13 11.53
11.66 -0.32 11.34 -0.34 10.99
11.34 -0.45 10.89 -0.65 10.24
10.89 -0.56 10.33 -1.03 9.30
10.33 -0.66 9.67 -1.44 8.23
9.67 -0.75 8.91 -1.86 7.05
8.91 -0.83 8.08 -2.27 5.81
8.08 -0.90 7.18 -2.63 4.55
7.18 -0.95 6.23 -2.94 3.29
6.23 -0.98 5.25 -3.17 2.08
5.25 -1.01 4.24 -3.32 0.92
4.24 -1.02 3.22 -3.39 -0.17
3.22 -1.02 2.21 -3.38 -1.17
2.21 -1.00 1.20 -3.29 -2.09
1.20 -0.98 0.22 -3.14 -2.92
0.22 -0.95 -0.72 -2.94 -3.66

-0.65

MINIMUM DOWNSURGE AT MDDL OF RESERVOIR AT MAXIMUM
HEAD LOSSES IN HRT (100-0-50)% , V1 = 0.92 m/sec. v2 = 2.
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
MAXIMUM -BV1^2
DZ in DOWN -N(V1-V2)^2 COL.
m Z in m SURGE +1/2G*V1^2 (5+6)
Z+DZ (3+4)
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
3 4 5 6 7
~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~
-3.28 3.22 -0.06 -20.21 -20.27
-3.02 -0.06 -3.08 -16.49 -19.57
-2.77 -3.08 -5.85 -13.30 -19.15
-2.53 -5.85 -8.38 -10.55 -18.93
-2.30 -8.38 -10.68 -8.20 -18.88
-2.06 -10.68 -12.74 -6.22 -18.96
-1.82 -12.74 -14.56 -4.59 -19.15
-1.58 -14.56 -16.14 -3.32 -19.46
-1.33 -16.14 -17.47 -2.41 -19.88
-1.08 -17.47 -18.55 -1.88 -20.43
-0.82 -18.55 -19.37 -1.75 -21.12
-0.56 -19.37 -19.93 -2.07 -22.00
-0.28 -19.93 -20.21 -2.88 -23.09
0.01 -20.21 -20.20 -4.26 -24.46
0.32 -20.20 -19.88 -6.32 -26.20
0.65 -19.88 -19.23 -9.19 -28.42
1.01 -19.23 -18.22 -13.10 0.00

4.15 METRES
9000.00 METRES
41.30 CUMECS.
3.05 M/Sec.
3.40 METRES
1.00 NOS.
2.40 METRES
2.00 NOS.
4.55 M/Sec.
4.56 M/Sec.
13.00 METRES
29.52 METRES
30.76 METRES
27.20 METRES
29.49 METRES
0.02
0.01
0.01
0.02
0.01
0.02
19.77 METRES
12.65 METRES
17.22 METRES
=B
2.12 CASE-I V1 =
1.36
1.85
V2 =
CASE-II V1 =
=N V2 =
3.30
2.92
3.16
10.00

dv=-g/ L dt
*Col.7
8 UPSURGE
0.00 0.00
-0.34 0.00
-0.27 0.00
-0.23 0.00
-0.21 0.00
-0.19 0.00
-0.17 0.00
-0.16 0.00
-0.16 0.00
-0.15 0.00
-0.15 0.00
-0.14 0.00
-0.14 0.00
-0.14 0.00
-0.14 0.00
-0.13 0.00
-0.13 0.00
-0.13 0.00
-0.13 11.92
-0.13 11.86
-0.13 11.66
-0.13 11.33
-0.13 10.88

00 m/sec.
dv= -g/l dtx
Col.7
8
-0.13
-0.13
-0.12
-0.11
-0.10
-0.09
-0.08
-0.06
-0.05
-0.04
-0.02
-0.01
0.00
0.01
0.02
0.03
0.04

0.00

28 m/sec.
dv= -g/l dtx
*Col.7
8
0.22
0.21
0.21
0.21
0.21
0.21
0.21
0.21
0.22
0.22
0.23
0.24
0.25
0.27
0.29
0.31
0.00

(0-50)% (0-100)% (100-0)%
0.00 0.00
4.56 4.55
0.96 3.05
2.28 0.00

(0-25)%
V1 = 0.00
V2 = 0.00
V1 =
V2 =

0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00

0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00

(0-50)% (0-100)% (100-0)%
0.00
0.00
0.00
0.00

CHHATRU HYDRO-ELECTRIC PROJECT
TABLE 7.2
COMPUTATIONS FOR DEPENDABLE YEAR ON THE BASIS OF ENERGY
S.No. ANNUAL GENERATION GENERATION IN MU
IN DESCENDING ORDER % DEP. YEAR
YEAR IN MU. YEAR IN MU.
1 1973-74 988.34 1998-99 1302.18 3.57
2 1974-75 635.24 1999-00 1231.36 7.14
3 1975-76 853.23 1987-88 1039.94 10.71
4 1976-77 702.96 1973-74 988.34 14.29
5 1977-78 833.62 1991-92 973.55 17.86
6 1978-79 952.55 1994-95 966.89 21.43
7 1979-80 927.92 1988-89 963.47 25.00
8 1980-81 899.67 1978-79 952.55 28.57
9 1981-82 787.20 1996-97 937.25 32.14
10 1982-83 835.86 1979-80 927.92 35.71
11 1983-84 885.81 1989-90 920.92 39.29
12 1984-85 849.10 1990-91 909.46 42.86
13 1985-86 804.87 1995-96 905.47 46.43
14 1986-87 895.05 1980-81 899.67 50.00 50% mean
15 1987-88 1039.94 1986-87 895.05 53.57 YEAR
16 1988-89 963.47 1983-84 885.81 57.14
17 1989-90 920.92 1975-76 853.23 60.71
18 1990-91 909.46 1984-85 849.10 64.29
19 1991-92 973.55 1982-83 835.86 67.86
20 1992-93 755.22 1977-78 833.62 71.43
21 1993-94 765.29 1997-98 833.35 75.00
22 1994-95 966.89 1985-86 804.87 78.57
23 1995-96 905.47 1981-82 787.20 82.14
24 1996-97 937.25 1993-94 765.29 85.71
25 1997-98 833.35 1992-93 755.22 89.29 90% Dep
26 1998-99 1302.18 1976-77 702.96 92.86 YEAR
27 1999-00 1231.36 1974-75 635.24 96.43

POWER & ENERGY GENERATION IN TABLE 7.4
90% DEPENDABLE YEAR (1992-93)
Net Head = 160.00 mtr
Eff. = 0.92
90% Dep. Un-res. Restricted
YEAR Power Energy Power Energy
1992-93 MW GWH MW GWH
MONTH PERIOD DISCHA. 78
I 59.21 85.50 20.52 78.00 18.72
JUN II 134.86 194.75 46.74 78.00 18.72
III 173.02 249.85 59.96 78.00 18.72
I 132.89 191.90 46.06 78.00 18.72
JUL II 196.70 284.05 68.17 78.00 18.72
III 218.41 315.40 83.26 78.00 20.59
I 162.49 234.65 56.32 78.00 18.72
AUG II 155.26 224.20 53.81 78.00 18.72
III 163.15 235.60 62.20 78.00 20.59
I 139.47 201.40 48.34 78.00 18.72
SEP II 68.42 98.80 23.71 78.00 18.72
III 44.08 63.65 15.28 63.65 15.28
I 39.47 57.00 13.68 57.00 13.68
OCT II 32.24 46.55 11.17 46.55 11.17
III 28.95 41.80 11.04 41.80 11.04
I 22.37 32.30 7.75 32.30 7.75
NOV II 18.42 26.60 6.38 26.60 6.38
III 16.45 23.75 5.70 23.75 5.70
I 15.79 22.80 5.47 22.80 5.47
DEC II 15.13 21.85 5.24 21.85 5.24
III 15.13 21.85 5.77 21.85 5.77
I 13.82 19.95 4.79 19.95 4.79
JAN II 13.16 19.00 4.56 19.00 4.56
III 12.50 18.05 4.77 18.05 4.77
I 11.84 17.10 4.10 17.10 4.10
FEB II 11.18 16.15 3.88 16.15 3.88
III 11.84 17.10 3.28 17.10 3.28
I 11.84 17.10 4.10 17.10 4.10
MAR II 12.50 18.05 4.33 18.05 4.33
III 12.50 18.05 4.77 18.05 4.77
I 13.82 19.95 4.79 19.95 4.79
APR II 15.13 21.85 5.24 21.85 5.24
III 20.39 29.45 7.07 29.45 7.07
I 32.89 47.50 11.40 47.50 11.40
MAY II 29.60 42.75 10.26 42.75 10.26
III 55.92 80.75 21.32 78.00 20.59
TOTAL ENERGY 755.22 395.07
P. L. FACTOR 0.58
INC.INC. IN ENR. 0.00
GWH / MW 5.07
% AGE UTILISN 52.31
PLF (LEAN- P.) 0.25

MONTH PERIOD
I
JUN II
III
I
JUL II
III
I
AUG II
III
I
SEP II
III
I
OCT II
III
I
NOV II
III
I
DEC II
III
I
JAN II
III
I
FEB II
III
I
MAR II
III
I
APR II
III
I
MAY II
III
TOTAL ENERGY
P. L. FACTOR
INC.INC. IN ENR.
GWH / MW
% AGE UTILISN
PLF (LEAN- P.)
POWER & ENERGY GENERATION IN
90% DEPENDABLE YEAR (1992-93)
TABL
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power
MW GWH MW GWH MW
81 84 87
81.00 19.44 84.00 20.16 85.50
81.00 19.44 84.00 20.16 87.00
81.00 19.44 84.00 20.16 87.00
81.00 19.44 84.00 20.16 87.00
81.00 19.44 84.00 20.16 87.00
81.00 21.38 84.00 22.18 87.00
81.00 19.44 84.00 20.16 87.00
81.00 19.44 84.00 20.16 87.00
81.00 21.38 84.00 22.18 87.00
81.00 19.44 84.00 20.16 87.00
81.00 19.44 84.00 20.16 87.00
63.65 15.28 63.65 15.28 63.65
57.00 13.68 57.00 13.68 57.00
46.55 11.17 46.55 11.17 46.55
41.80 11.04 41.80 11.04 41.80
32.30 7.75 32.30 7.75 32.30
26.60 6.38 26.60 6.38 26.60
23.75 5.70 23.75 5.70 23.75
22.80 5.47 22.80 5.47 22.80
21.85 5.24 21.85 5.24 21.85
21.85 5.77 21.85 5.77 21.85
19.95 4.79 19.95 4.79 19.95
19.00 4.56 19.00 4.56 19.00
18.05 4.77 18.05 4.77 18.05
17.10 4.10 17.10 4.10 17.10
16.15 3.88 16.15 3.88 16.15
17.10 3.28 17.10 3.28 17.10
17.10 4.10 17.10 4.10 17.10
18.05 4.33 18.05 4.33 18.05
18.05 4.77 18.05 4.77 18.05
19.95 4.79 19.95 4.79 19.95
21.85 5.24 21.85 5.24 21.85
29.45 7.07 29.45 7.07 29.45
47.50 11.40 47.50 11.40 47.50
42.75 10.26 42.75 10.26 42.75
80.75 21.32 80.75 21.32 80.75
403.86 411.93
0.57 0.56
8.79 8.06
4.99 4.90
53.48 54.54
0.24 0.23

MONTH PERIOD
I
JUN II
III
I
JUL II
III
I
AUG II
III
I
SEP II
III
I
OCT II
III
I
NOV II
III
I
DEC II
III
I
JAN II
III
I
FEB II
III
I
MAR II
III
I
APR II
III
I
MAY II
III
TOTAL ENERGY
P. L. FACTOR
INC.INC. IN ENR.
GWH / MW
% AGE UTILISN
PLF (LEAN- P.)
LE 7.4
Energy
GWH
20.52
20.88
20.88
20.88
20.88
22.97
20.88
20.88
22.97
20.88
20.88
15.28
13.68
11.17
11.04
7.75
6.38
5.70
5.47
5.24
5.77
4.79
4.56
4.77
4.10
3.88
3.28
4.10
4.33
4.77
4.79
5.24
7.07
11.40
10.26
21.32
419.63
0.55
7.70
4.82
55.56
0.22
N

MONTH PERIOD
I
JUN II
III
I
JUL II
III
I
AUG II
III
I
SEP II
III
I
OCT II
III
I
NOV II
III
I
DEC II
III
I
JAN II
III
I
FEB II
III
I
MAR II
III
I
APR II
III
I
MAY II
III
TOTAL ENERGY
P. L. FACTOR
INC.INC. IN ENR.
GWH / MW
% AGE UTILISN
PLF (LEAN- P.)
POWER & ENERGY GENERATION IN
90% DEPENDABLE YEAR (1992-93)
TABLE 7.4
Net Head = 160.00 mtr
Eff. = 0.92
Restric Restricted Restricted
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
90 93 96
85.50 20.52 85.50 20.52 85.50 20.52
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
90.00 23.76 93.00 24.55 96.00 25.34
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
90.00 23.76 93.00 24.55 96.00 25.34
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
63.65 15.28 63.65 15.28 63.65 15.28
57.00 13.68 57.00 13.68 57.00 13.68
46.55 11.17 46.55 11.17 46.55 11.17
41.80 11.04 41.80 11.04 41.80 11.04
32.30 7.75 32.30 7.75 32.30 7.75
26.60 6.38 26.60 6.38 26.60 6.38
23.75 5.70 23.75 5.70 23.75 5.70
22.80 5.47 22.80 5.47 22.80 5.47
21.85 5.24 21.85 5.24 21.85 5.24
21.85 5.77 21.85 5.77 21.85 5.77
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
18.05 4.77 18.05 4.77 18.05 4.77
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
17.10 3.28 17.10 3.28 17.10 3.28
17.10 4.10 17.10 4.10 17.10 4.10
18.05 4.33 18.05 4.33 18.05 4.33
18.05 4.77 18.05 4.77 18.05 4.77
19.95 4.79 19.95 4.79 19.95 4.79
21.85 5.24 21.85 5.24 21.85 5.24
29.45 7.07 29.45 7.07 29.45 7.07
47.50 11.40 47.50 11.40 47.50 11.40
42.75 10.26 42.75 10.26 42.75 10.26
80.75 21.32 80.75 21.32 80.75 21.32
426.98 434.32 441.66
0.54 0.53 0.53
7.34 7.34 7.34
4.74 4.67 4.60
56.54 57.51 58.48
0.22 0.21 0.20

MONTH PERIOD
I
JUN II
III
I
JUL II
III
I
AUG II
III
I
SEP II
III
I
OCT II
III
I
NOV II
III
I
DEC II
III
I
JAN II
III
I
FEB II
III
I
MAR II
III
I
APR II
III
I
MAY II
III
TOTAL ENERGY
P. L. FACTOR
INC.INC. IN ENR.
GWH / MW
% AGE UTILISN
PLF (LEAN- P.)
POWER & ENERGY GENERATION IN
90% DEPENDABLE YEAR (1992-93)
TABLE 7.4
Net Head = 160.00 mtr N
Eff. = 0.92
Restricted Restricted Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
99 102 105
85.50 20.52 85.50 20.52 85.50 20.52
99.00 23.76 102.00 24.48 105.00 25.20
99.00 23.76 102.00 24.48 105.00 25.20
99.00 23.76 102.00 24.48 105.00 25.20
99.00 23.76 102.00 24.48 105.00 25.20
99.00 26.14 102.00 26.93 105.00 27.72
99.00 23.76 102.00 24.48 105.00 25.20
99.00 23.76 102.00 24.48 105.00 25.20
99.00 26.14 102.00 26.93 105.00 27.72
99.00 23.76 102.00 24.48 105.00 25.20
98.80 23.71 98.80 23.71 98.80 23.71
63.65 15.28 63.65 15.28 63.65 15.28
57.00 13.68 57.00 13.68 57.00 13.68
46.55 11.17 46.55 11.17 46.55 11.17
41.80 11.04 41.80 11.04 41.80 11.04
32.30 7.75 32.30 7.75 32.30 7.75
26.60 6.38 26.60 6.38 26.60 6.38
23.75 5.70 23.75 5.70 23.75 5.70
22.80 5.47 22.80 5.47 22.80 5.47
21.85 5.24 21.85 5.24 21.85 5.24
21.85 5.77 21.85 5.77 21.85 5.77
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
18.05 4.77 18.05 4.77 18.05 4.77
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
17.10 3.28 17.10 3.28 17.10 3.28
17.10 4.10 17.10 4.10 17.10 4.10
18.05 4.33 18.05 4.33 18.05 4.33
18.05 4.77 18.05 4.77 18.05 4.77
19.95 4.79 19.95 4.79 19.95 4.79
21.85 5.24 21.85 5.24 21.85 5.24
29.45 7.07 29.45 7.07 29.45 7.07
47.50 11.40 47.50 11.40 47.50 11.40
42.75 10.26 42.75 10.26 42.75 10.26
80.75 21.32 80.75 21.32 80.75 21.32
448.96 455.58 462.21
0.52 0.51 0.50
7.30 6.62 6.62
4.53 4.47 4.40
59.45 60.32 61.20
0.20 0.19 0.18

MONTH PERIOD
I
JUN II
III
I
JUL II
III
I
AUG II
III
I
SEP II
III
I
OCT II
III
I
NOV II
III
I
DEC II
III
I
JAN II
III
I
FEB II
III
I
MAR II
III
I
APR II
III
I
MAY II
III
TOTAL ENERGY
P. L. FACTOR
INC.INC. IN ENR.
GWH / MW
% AGE UTILISN
PLF (LEAN- P.)
POWER & ENERGY GENERATION IN
90% DEPENDABLE YEAR (1992-93)
Net Head 160.00 mtr
TABLE 7.4
Eff. = 0.92
Restrict Restricted Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
108 111 114
85.50 20.52 85.50 20.52 85.50 20.52
108.00 25.92 111.00 26.64 114.00 27.36
108.00 25.92 111.00 26.64 114.00 27.36
108.00 25.92 111.00 26.64 114.00 27.36
108.00 25.92 111.00 26.64 114.00 27.36
108.00 28.51 111.00 29.30 114.00 30.10
108.00 25.92 111.00 26.64 114.00 27.36
108.00 25.92 111.00 26.64 114.00 27.36
108.00 28.51 111.00 29.30 114.00 30.10
108.00 25.92 111.00 26.64 114.00 27.36
98.80 23.71 98.80 23.71 98.80 23.71
63.65 15.28 63.65 15.28 63.65 15.28
57.00 13.68 57.00 13.68 57.00 13.68
46.55 11.17 46.55 11.17 46.55 11.17
41.80 11.04 41.80 11.04 41.80 11.04
32.30 7.75 32.30 7.75 32.30 7.75
26.60 6.38 26.60 6.38 26.60 6.38
23.75 5.70 23.75 5.70 23.75 5.70
22.80 5.47 22.80 5.47 22.80 5.47
21.85 5.24 21.85 5.24 21.85 5.24
21.85 5.77 21.85 5.77 21.85 5.77
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
18.05 4.77 18.05 4.77 18.05 4.77
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
17.10 3.28 17.10 3.28 17.10 3.28
17.10 4.10 17.10 4.10 17.10 4.10
18.05 4.33 18.05 4.33 18.05 4.33
18.05 4.77 18.05 4.77 18.05 4.77
19.95 4.79 19.95 4.79 19.95 4.79
21.85 5.24 21.85 5.24 21.85 5.24
29.45 7.07 29.45 7.07 29.45 7.07
47.50 11.40 47.50 11.40 47.50 11.40
42.75 10.26 42.75 10.26 42.75 10.26
80.75 21.32 80.75 21.32 80.75 21.32
468.83 475.46 482.08
0.50 0.49 0.48
6.62 6.62 6.62
4.34 4.28 4.23
62.08 62.96 63.83
0.18 0.17 0.17

MONTH PERIOD
I
JUN II
III
I
JUL II
III
I
AUG II
III
I
SEP II
III
I
OCT II
III
I
NOV II
III
I
DEC II
III
I
JAN II
III
I
FEB II
III
I
MAR II
III
I
APR II
III
I
MAY II
III
TOTAL ENERGY
P. L. FACTOR
INC.INC. IN ENR.
GWH / MW
% AGE UTILISN
PLF (LEAN- P.)
POWER & ENERGY GENERATION IN
90% DEPENDABLE YEAR (1992-93)
Net Head = 160.00 mtr
TABLE 7.4
Eff. = 0.92
Restricted Restricted Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
117 120 123
85.50 20.52 85.50 20.52 85.50 20.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 30.89 120.00 31.68 123.00 32.47
117.00 28.08 120.00 28.80 123.00 29.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 30.89 120.00 31.68 123.00 32.47
117.00 28.08 120.00 28.80 123.00 29.52
98.80 23.71 98.80 23.71 98.80 23.71
63.65 15.28 63.65 15.28 63.65 15.28
57.00 13.68 57.00 13.68 57.00 13.68
46.55 11.17 46.55 11.17 46.55 11.17
41.80 11.04 41.80 11.04 41.80 11.04
32.30 7.75 32.30 7.75 32.30 7.75
26.60 6.38 26.60 6.38 26.60 6.38
23.75 5.70 23.75 5.70 23.75 5.70
22.80 5.47 22.80 5.47 22.80 5.47
21.85 5.24 21.85 5.24 21.85 5.24
21.85 5.77 21.85 5.77 21.85 5.77
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
18.05 4.77 18.05 4.77 18.05 4.77
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
17.10 3.28 17.10 3.28 17.10 3.28
17.10 4.10 17.10 4.10 17.10 4.10
18.05 4.33 18.05 4.33 18.05 4.33
18.05 4.77 18.05 4.77 18.05 4.77
19.95 4.79 19.95 4.79 19.95 4.79
21.85 5.24 21.85 5.24 21.85 5.24
29.45 7.07 29.45 7.07 29.45 7.07
47.50 11.40 47.50 11.40 47.50 11.40
42.75 10.26 42.75 10.26 42.75 10.26
80.75 21.32 80.75 21.32 80.75 21.32
488.70 495.33 501.95
0.48 0.47 0.47
6.62 6.62 6.62
4.18 4.13 4.08
64.71 65.59 66.46
0.17 0.16 0.16

MONTH PERIOD
I
JUN II
III
I
JUL II
III
I
AUG II
III
I
SEP II
III
I
OCT II
III
I
NOV II
III
I
DEC II
III
I
JAN II
III
I
FEB II
III
I
MAR II
III
I
APR II
III
I
MAY II
III
TOTAL ENERGY
P. L. FACTOR
INC.INC. IN ENR.
GWH / MW
% AGE UTILISN
PLF (LEAN- P.)
POWER & ENERGY GENERATION IN
90% DEPENDABLE YEAR (1992-93)
TABLE 7.4
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
126 129 132
85.50 20.52 85.50 20.52 85.50 20.52
126.00 30.24 129.00 30.96 132.00 31.68
126.00 30.24 129.00 30.96 132.00 31.68
126.00 30.24 129.00 30.96 132.00 31.68
126.00 30.24 129.00 30.96 132.00 31.68
126.00 33.26 129.00 34.06 132.00 34.85
126.00 30.24 129.00 30.96 132.00 31.68
126.00 30.24 129.00 30.96 132.00 31.68
126.00 33.26 129.00 34.06 132.00 34.85
126.00 30.24 129.00 30.96 132.00 31.68
98.80 23.71 98.80 23.71 98.80 23.71
63.65 15.28 63.65 15.28 63.65 15.28
57.00 13.68 57.00 13.68 57.00 13.68
46.55 11.17 46.55 11.17 46.55 11.17
41.80 11.04 41.80 11.04 41.80 11.04
32.30 7.75 32.30 7.75 32.30 7.75
26.60 6.38 26.60 6.38 26.60 6.38
23.75 5.70 23.75 5.70 23.75 5.70
22.80 5.47 22.80 5.47 22.80 5.47
21.85 5.24 21.85 5.24 21.85 5.24
21.85 5.77 21.85 5.77 21.85 5.77
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
18.05 4.77 18.05 4.77 18.05 4.77
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
17.10 3.28 17.10 3.28 17.10 3.28
17.10 4.10 17.10 4.10 17.10 4.10
18.05 4.33 18.05 4.33 18.05 4.33
18.05 4.77 18.05 4.77 18.05 4.77
19.95 4.79 19.95 4.79 19.95 4.79
21.85 5.24 21.85 5.24 21.85 5.24
29.45 7.07 29.45 7.07 29.45 7.07
47.50 11.40 47.50 11.40 47.50 11.40
42.75 10.26 42.75 10.26 42.75 10.26
80.75 21.32 80.75 21.32 80.75 21.32
508.58 515.20 521.82
0.46 0.46 0.45
6.62 6.62 6.62
4.04 3.99 3.95
67.34 68.22 69.10
0.15 0.15 0.15

MONTH PERIOD
I
JUN II
III
I
JUL II
III
I
AUG II
III
I
SEP II
III
I
OCT II
III
I
NOV II
III
I
DEC II
III
I
JAN II
III
I
FEB II
III
I
MAR II
III
I
APR II
III
I
MAY II
III
TOTAL ENERGY
P. L. FACTOR
INC.INC. IN ENR.
GWH / MW
% AGE UTILISN
PLF (LEAN- P.)
POWER & ENERGY GENERATION IN
90% DEPENDABLE YEAR (1992-93)
TABLE 7.4
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
135 138 141
85.50 20.52 85.50 20.52 85.50 20.52
135.00 32.40 138.00 33.12 141.00 33.84
135.00 32.40 138.00 33.12 141.00 33.84
135.00 32.40 138.00 33.12 141.00 33.84
135.00 32.40 138.00 33.12 141.00 33.84
135.00 35.64 138.00 36.43 141.00 37.22
135.00 32.40 138.00 33.12 141.00 33.84
135.00 32.40 138.00 33.12 141.00 33.84
135.00 35.64 138.00 36.43 141.00 37.22
135.00 32.40 138.00 33.12 141.00 33.84
98.80 23.71 98.80 23.71 98.80 23.71
63.65 15.28 63.65 15.28 63.65 15.28
57.00 13.68 57.00 13.68 57.00 13.68
46.55 11.17 46.55 11.17 46.55 11.17
41.80 11.04 41.80 11.04 41.80 11.04
32.30 7.75 32.30 7.75 32.30 7.75
26.60 6.38 26.60 6.38 26.60 6.38
23.75 5.70 23.75 5.70 23.75 5.70
22.80 5.47 22.80 5.47 22.80 5.47
21.85 5.24 21.85 5.24 21.85 5.24
21.85 5.77 21.85 5.77 21.85 5.77
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
18.05 4.77 18.05 4.77 18.05 4.77
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
17.10 3.28 17.10 3.28 17.10 3.28
17.10 4.10 17.10 4.10 17.10 4.10
18.05 4.33 18.05 4.33 18.05 4.33
18.05 4.77 18.05 4.77 18.05 4.77
19.95 4.79 19.95 4.79 19.95 4.79
21.85 5.24 21.85 5.24 21.85 5.24
29.45 7.07 29.45 7.07 29.45 7.07
47.50 11.40 47.50 11.40 47.50 11.40
42.75 10.26 42.75 10.26 42.75 10.26
80.75 21.32 80.75 21.32 80.75 21.32
528.45 535.07 541.70
0.45 0.44 0.44
6.62 6.62 6.62
3.91 3.88 3.84
69.97 70.85 71.73
0.14 0.14 0.14

MONTH PERIOD
I
JUN II
III
I
JUL II
III
I
AUG II
III
I
SEP II
III
I
OCT II
III
I
NOV II
III
I
DEC II
III
I
JAN II
III
I
FEB II
III
I
MAR II
III
I
APR II
III
I
MAY II
III
TOTAL ENERGY
P. L. FACTOR
INC.INC. IN ENR.
GWH / MW
% AGE UTILISN
PLF (LEAN- P.)
POWER & ENERGY GENERATION IN
90% DEPENDABLE YEAR (1992-93)
TABLE 7.4
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
144 147 150
85.50 20.52 85.50 20.52 85.50 20.52
144.00 34.56 147.00 35.28 150.00 36.00
144.00 34.56 147.00 35.28 150.00 36.00
144.00 34.56 147.00 35.28 150.00 36.00
144.00 34.56 147.00 35.28 150.00 36.00
144.00 38.02 147.00 38.81 150.00 39.60
144.00 34.56 147.00 35.28 150.00 36.00
144.00 34.56 147.00 35.28 150.00 36.00
144.00 38.02 147.00 38.81 150.00 39.60
144.00 34.56 147.00 35.28 150.00 36.00
98.80 23.71 98.80 23.71 98.80 23.71
63.65 15.28 63.65 15.28 63.65 15.28
57.00 13.68 57.00 13.68 57.00 13.68
46.55 11.17 46.55 11.17 46.55 11.17
41.80 11.04 41.80 11.04 41.80 11.04
32.30 7.75 32.30 7.75 32.30 7.75
26.60 6.38 26.60 6.38 26.60 6.38
23.75 5.70 23.75 5.70 23.75 5.70
22.80 5.47 22.80 5.47 22.80 5.47
21.85 5.24 21.85 5.24 21.85 5.24
21.85 5.77 21.85 5.77 21.85 5.77
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
18.05 4.77 18.05 4.77 18.05 4.77
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
17.10 3.28 17.10 3.28 17.10 3.28
17.10 4.10 17.10 4.10 17.10 4.10
18.05 4.33 18.05 4.33 18.05 4.33
18.05 4.77 18.05 4.77 18.05 4.77
19.95 4.79 19.95 4.79 19.95 4.79
21.85 5.24 21.85 5.24 21.85 5.24
29.45 7.07 29.45 7.07 29.45 7.07
47.50 11.40 47.50 11.40 47.50 11.40
42.75 10.26 42.75 10.26 42.75 10.26
80.75 21.32 80.75 21.32 80.75 21.32
548.32 554.94 561.57
0.43 0.43 0.43
6.62 6.62 6.62
3.81 3.78 3.74
72.60 73.48 74.36
0.13 0.13 0.13

MONTH PERIOD
I
JUN II
III
I
JUL II
III
I
AUG II
III
I
SEP II
III
I
OCT II
III
I
NOV II
III
I
DEC II
III
I
JAN II
III
I
FEB II
III
I
MAR II
III
I
APR II
III
I
MAY II
III
TOTAL ENERGY
P. L. FACTOR
INC.INC. IN ENR.
GWH / MW
% AGE UTILISN
PLF (LEAN- P.)
POWER & ENERGY GENERATION IN
90% DEPENDABLE YEAR (1992-93)
Net Head = 160.00 mtr
TABLE 7.4
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
153 156 159
85.50 20.52 85.50 20.52 85.50 20.52
153.00 36.72 156.00 37.44 159.00 38.16
153.00 36.72 156.00 37.44 159.00 38.16
153.00 36.72 156.00 37.44 159.00 38.16
153.00 36.72 156.00 37.44 159.00 38.16
153.00 40.39 156.00 41.18 159.00 41.98
153.00 36.72 156.00 37.44 159.00 38.16
153.00 36.72 156.00 37.44 159.00 38.16
153.00 40.39 156.00 41.18 159.00 41.98
153.00 36.72 156.00 37.44 159.00 38.16
98.80 23.71 98.80 23.71 98.80 23.71
63.65 15.28 63.65 15.28 63.65 15.28
57.00 13.68 57.00 13.68 57.00 13.68
46.55 11.17 46.55 11.17 46.55 11.17
41.80 11.04 41.80 11.04 41.80 11.04
32.30 7.75 32.30 7.75 32.30 7.75
26.60 6.38 26.60 6.38 26.60 6.38
23.75 5.70 23.75 5.70 23.75 5.70
22.80 5.47 22.80 5.47 22.80 5.47
21.85 5.24 21.85 5.24 21.85 5.24
21.85 5.77 21.85 5.77 21.85 5.77
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
18.05 4.77 18.05 4.77 18.05 4.77
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
17.10 3.28 17.10 3.28 17.10 3.28
17.10 4.10 17.10 4.10 17.10 4.10
18.05 4.33 18.05 4.33 18.05 4.33
18.05 4.77 18.05 4.77 18.05 4.77
19.95 4.79 19.95 4.79 19.95 4.79
21.85 5.24 21.85 5.24 21.85 5.24
29.45 7.07 29.45 7.07 29.45 7.07
47.50 11.40 47.50 11.40 47.50 11.40
42.75 10.26 42.75 10.26 42.75 10.26
80.75 21.32 80.75 21.32 80.75 21.32
568.19 574.82 581.44
0.42 0.42 0.42
6.62 6.62 6.62
3.71 3.68 3.66
75.24 76.11 76.99
0.13 0.12 0.12

POWER & ENERGY GENERATION IN TABLE 7.6
50% MEAN YEAR (1980-81)
Net Head = 160.00 mtr
Eff. = 0.92
50% Mean. Un-res. Restricted
YEAR Power Energy Power Energy
1980-81 MW GWH MW GWH
MONTH PERIOD DISCHA. 78
I 132.89 191.90 46.06 78.00 18.72
JUN II 154.60 223.25 53.58 78.00 18.72
III 219.73 317.30 76.15 78.00 18.72
I 231.57 334.39 80.25 78.00 18.72
JUL II 223.68 323.00 77.52 78.00 18.72
III 205.91 297.35 78.50 78.00 20.59
I 223.02 322.05 77.29 78.00 18.72
AUG II 146.71 211.85 50.84 78.00 18.72
III 165.13 238.45 62.95 78.00 20.59
I 103.29 149.15 35.80 78.00 18.72
SEP II 65.13 94.05 22.57 78.00 18.72
III 45.39 65.55 15.73 65.55 15.73
I 35.52 51.30 12.31 51.30 12.31
OCT II 23.03 33.25 7.98 33.25 7.98
III 18.42 26.60 7.02 26.60 7.02
I 13.82 19.95 4.79 19.95 4.79
NOV II 13.16 19.00 4.56 19.00 4.56
III 13.16 19.00 4.56 19.00 4.56
I 11.84 17.10 4.10 17.10 4.10
DEC II 11.18 16.15 3.88 16.15 3.88
III 10.53 15.20 4.01 15.20 4.01
I 11.18 16.15 3.88 16.15 3.88
JAN II 10.53 15.20 3.65 15.20 3.65
III 9.87 14.25 3.76 14.25 3.76
I 9.87 14.25 3.42 14.25 3.42
FEB II 10.53 15.20 3.65 15.20 3.65
III 11.84 17.10 3.28 17.10 3.28
I 11.18 16.15 3.88 16.15 3.88
MAR II 11.18 16.15 3.88 16.15 3.88
III 11.84 17.10 4.51 17.10 4.51
I 12.50 18.05 4.33 18.05 4.33
APR II 17.10 24.70 5.93 24.70 5.93
III 24.34 35.15 8.44 35.15 8.44
I 86.18 124.45 29.87 78.00 18.72
MAY II 109.21 157.70 37.85 78.00 18.72
III 128.28 185.25 48.91 78.00 20.59
TOTAL ENERGY 899.67 389.24
P. L. FACTOR 0.57
INC.INC. IN ENR. 0.00
GWH / MW 4.99
% AGE UTILISN 43.26
PLF (LEAN- P.) 0.20

POWER & ENERGY GENERATION IN TABLE 7.6
50% MEAN YEAR (1980-81)
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
81 84 87
81.00 19.44 84.00 20.16 87.00 20.88
81.00 19.44 84.00 20.16 87.00 20.88
81.00 19.44 84.00 20.16 87.00 20.88
81.00 19.44 84.00 20.16 87.00 20.88
81.00 19.44 84.00 20.16 87.00 20.88
81.00 21.38 84.00 22.18 87.00 22.97
81.00 19.44 84.00 20.16 87.00 20.88
81.00 19.44 84.00 20.16 87.00 20.88
81.00 21.38 84.00 22.18 87.00 22.97
81.00 19.44 84.00 20.16 87.00 20.88
81.00 19.44 84.00 20.16 87.00 20.88
65.55 15.73 65.55 15.73 65.55 15.73
51.30 12.31 51.30 12.31 51.30 12.31
33.25 7.98 33.25 7.98 33.25 7.98
26.60 7.02 26.60 7.02 26.60 7.02
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
19.00 4.56 19.00 4.56 19.00 4.56
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
15.20 4.01 15.20 4.01 15.20 4.01
16.15 3.88 16.15 3.88 16.15 3.88
15.20 3.65 15.20 3.65 15.20 3.65
14.25 3.76 14.25 3.76 14.25 3.76
14.25 3.42 14.25 3.42 14.25 3.42
15.20 3.65 15.20 3.65 15.20 3.65
17.10 3.28 17.10 3.28 17.10 3.28
16.15 3.88 16.15 3.88 16.15 3.88
16.15 3.88 16.15 3.88 16.15 3.88
17.10 4.51 17.10 4.51 17.10 4.51
18.05 4.33 18.05 4.33 18.05 4.33
24.70 5.93 24.70 5.93 24.70 5.93
35.15 8.44 35.15 8.44 35.15 8.44
81.00 19.44 84.00 20.16 87.00 20.88
81.00 19.44 84.00 20.16 87.00 20.88
81.00 21.38 84.00 22.18 87.00 22.97
399.54 409.83 420.13
0.56 0.56 0.55
10.30 10.30 10.30
4.93 4.88 4.83
44.41 45.55 46.70
0.19 0.19 0.18

POWER & ENERGY GENERATION IN TABLE 7.6
50% MEAN YEAR (1980-81)
Net Head = 160.00 mtr
Eff. = 0.92
Restric Restricted Restricte
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
90 93 96
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
90.00 23.76 93.00 24.55 96.00 25.34
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
90.00 23.76 93.00 24.55 96.00 25.34
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 94.05 22.57
65.55 15.73 65.55 15.73 65.55 15.73
51.30 12.31 51.30 12.31 51.30 12.31
33.25 7.98 33.25 7.98 33.25 7.98
26.60 7.02 26.60 7.02 26.60 7.02
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
19.00 4.56 19.00 4.56 19.00 4.56
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
15.20 4.01 15.20 4.01 15.20 4.01
16.15 3.88 16.15 3.88 16.15 3.88
15.20 3.65 15.20 3.65 15.20 3.65
14.25 3.76 14.25 3.76 14.25 3.76
14.25 3.42 14.25 3.42 14.25 3.42
15.20 3.65 15.20 3.65 15.20 3.65
17.10 3.28 17.10 3.28 17.10 3.28
16.15 3.88 16.15 3.88 16.15 3.88
16.15 3.88 16.15 3.88 16.15 3.88
17.10 4.51 17.10 4.51 17.10 4.51
18.05 4.33 18.05 4.33 18.05 4.33
24.70 5.93 24.70 5.93 24.70 5.93
35.15 8.44 35.15 8.44 35.15 8.44
90.00 21.60 93.00 22.32 96.00 23.04
90.00 21.60 93.00 22.32 96.00 23.04
90.00 23.76 93.00 24.55 96.00 25.34
430.42 440.72 450.55
0.55 0.54 0.54
10.30 10.30 9.83
4.78 4.74 4.69
47.84 48.99 50.08
0.17 0.17 0.16

POWER & ENERGY GENERATION IN TABLE 7.6
50% MEAN YEAR (1980-81)
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
99 102 105
99.00 23.76 102.00 24.48 105.00 25.20
99.00 23.76 102.00 24.48 105.00 25.20
99.00 23.76 102.00 24.48 105.00 25.20
99.00 23.76 102.00 24.48 105.00 25.20
99.00 23.76 102.00 24.48 105.00 25.20
99.00 26.14 102.00 26.93 105.00 27.72
99.00 23.76 102.00 24.48 105.00 25.20
99.00 23.76 102.00 24.48 105.00 25.20
99.00 26.14 102.00 26.93 105.00 27.72
99.00 23.76 102.00 24.48 105.00 25.20
94.05 22.57 94.05 22.57 94.05 22.57
65.55 15.73 65.55 15.73 65.55 15.73
51.30 12.31 51.30 12.31 51.30 12.31
33.25 7.98 33.25 7.98 33.25 7.98
26.60 7.02 26.60 7.02 26.60 7.02
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
19.00 4.56 19.00 4.56 19.00 4.56
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
15.20 4.01 15.20 4.01 15.20 4.01
16.15 3.88 16.15 3.88 16.15 3.88
15.20 3.65 15.20 3.65 15.20 3.65
14.25 3.76 14.25 3.76 14.25 3.76
14.25 3.42 14.25 3.42 14.25 3.42
15.20 3.65 15.20 3.65 15.20 3.65
17.10 3.28 17.10 3.28 17.10 3.28
16.15 3.88 16.15 3.88 16.15 3.88
16.15 3.88 16.15 3.88 16.15 3.88
17.10 4.51 17.10 4.51 17.10 4.51
18.05 4.33 18.05 4.33 18.05 4.33
24.70 5.93 24.70 5.93 24.70 5.93
35.15 8.44 35.15 8.44 35.15 8.44
99.00 23.76 102.00 24.48 105.00 25.20
99.00 23.76 102.00 24.48 105.00 25.20
99.00 26.14 102.00 26.93 105.00 27.72
460.12 469.70 479.28
0.53 0.53 0.52
9.58 9.58 9.58
4.65 4.60 4.56
51.14 52.21 53.27
0.16 0.15 0.15

POWER & ENERGY GENERATION IN TABLE 7.6
50% MEAN YEAR (1980-81)
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
108 111 114
108.00 25.92 111.00 26.64 114.00 27.36
108.00 25.92 111.00 26.64 114.00 27.36
108.00 25.92 111.00 26.64 114.00 27.36
108.00 25.92 111.00 26.64 114.00 27.36
108.00 25.92 111.00 26.64 114.00 27.36
108.00 28.51 111.00 29.30 114.00 30.10
108.00 25.92 111.00 26.64 114.00 27.36
108.00 25.92 111.00 26.64 114.00 27.36
108.00 28.51 111.00 29.30 114.00 30.10
108.00 25.92 111.00 26.64 114.00 27.36
94.05 22.57 94.05 22.57 94.05 22.57
65.55 15.73 65.55 15.73 65.55 15.73
51.30 12.31 51.30 12.31 51.30 12.31
33.25 7.98 33.25 7.98 33.25 7.98
26.60 7.02 26.60 7.02 26.60 7.02
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
19.00 4.56 19.00 4.56 19.00 4.56
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
15.20 4.01 15.20 4.01 15.20 4.01
16.15 3.88 16.15 3.88 16.15 3.88
15.20 3.65 15.20 3.65 15.20 3.65
14.25 3.76 14.25 3.76 14.25 3.76
14.25 3.42 14.25 3.42 14.25 3.42
15.20 3.65 15.20 3.65 15.20 3.65
17.10 3.28 17.10 3.28 17.10 3.28
16.15 3.88 16.15 3.88 16.15 3.88
16.15 3.88 16.15 3.88 16.15 3.88
17.10 4.51 17.10 4.51 17.10 4.51
18.05 4.33 18.05 4.33 18.05 4.33
24.70 5.93 24.70 5.93 24.70 5.93
35.15 8.44 35.15 8.44 35.15 8.44
108.00 25.92 111.00 26.64 114.00 27.36
108.00 25.92 111.00 26.64 114.00 27.36
108.00 28.51 111.00 29.30 114.00 30.10
488.85 498.43 508.00
0.52 0.51 0.51
9.58 9.58 9.58
4.53 4.49 4.46
54.34 55.40 56.47
0.14 0.14 0.14

POWER & ENERGY GENERATION IN TABLE 7.6
50% MEAN YEAR (1980-81)
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
117 120 123
117.00 28.08 120.00 28.80 123.00 29.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 30.89 120.00 31.68 123.00 32.47
117.00 28.08 120.00 28.80 123.00 29.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 30.89 120.00 31.68 123.00 32.47
117.00 28.08 120.00 28.80 123.00 29.52
94.05 22.57 94.05 22.57 94.05 22.57
65.55 15.73 65.55 15.73 65.55 15.73
51.30 12.31 51.30 12.31 51.30 12.31
33.25 7.98 33.25 7.98 33.25 7.98
26.60 7.02 26.60 7.02 26.60 7.02
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
19.00 4.56 19.00 4.56 19.00 4.56
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
15.20 4.01 15.20 4.01 15.20 4.01
16.15 3.88 16.15 3.88 16.15 3.88
15.20 3.65 15.20 3.65 15.20 3.65
14.25 3.76 14.25 3.76 14.25 3.76
14.25 3.42 14.25 3.42 14.25 3.42
15.20 3.65 15.20 3.65 15.20 3.65
17.10 3.28 17.10 3.28 17.10 3.28
16.15 3.88 16.15 3.88 16.15 3.88
16.15 3.88 16.15 3.88 16.15 3.88
17.10 4.51 17.10 4.51 17.10 4.51
18.05 4.33 18.05 4.33 18.05 4.33
24.70 5.93 24.70 5.93 24.70 5.93
35.15 8.44 35.15 8.44 35.15 8.44
117.00 28.08 120.00 28.80 123.00 29.52
117.00 28.08 120.00 28.80 123.00 29.52
117.00 30.89 120.00 31.68 123.00 32.47
517.58 527.16 536.73
0.50 0.50 0.50
9.58 9.58 9.58
4.42 4.39 4.36
57.53 58.59 59.66
0.13 0.13 0.13

POWER & ENERGY GENERATION IN TABLE 7.6
50% MEAN YEAR (1980-81)
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
126 129 132
126.00 30.24 129.00 30.96 132.00 31.68
126.00 30.24 129.00 30.96 132.00 31.68
126.00 30.24 129.00 30.96 132.00 31.68
126.00 30.24 129.00 30.96 132.00 31.68
126.00 30.24 129.00 30.96 132.00 31.68
126.00 33.26 129.00 34.06 132.00 34.85
126.00 30.24 129.00 30.96 132.00 31.68
126.00 30.24 129.00 30.96 132.00 31.68
126.00 33.26 129.00 34.06 132.00 34.85
126.00 30.24 129.00 30.96 132.00 31.68
94.05 22.57 94.05 22.57 94.05 22.57
65.55 15.73 65.55 15.73 65.55 15.73
51.30 12.31 51.30 12.31 51.30 12.31
33.25 7.98 33.25 7.98 33.25 7.98
26.60 7.02 26.60 7.02 26.60 7.02
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
19.00 4.56 19.00 4.56 19.00 4.56
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
15.20 4.01 15.20 4.01 15.20 4.01
16.15 3.88 16.15 3.88 16.15 3.88
15.20 3.65 15.20 3.65 15.20 3.65
14.25 3.76 14.25 3.76 14.25 3.76
14.25 3.42 14.25 3.42 14.25 3.42
15.20 3.65 15.20 3.65 15.20 3.65
17.10 3.28 17.10 3.28 17.10 3.28
16.15 3.88 16.15 3.88 16.15 3.88
16.15 3.88 16.15 3.88 16.15 3.88
17.10 4.51 17.10 4.51 17.10 4.51
18.05 4.33 18.05 4.33 18.05 4.33
24.70 5.93 24.70 5.93 24.70 5.93
35.15 8.44 35.15 8.44 35.15 8.44
124.45 29.87 124.45 29.87 124.45 29.87
126.00 30.24 129.00 30.96 132.00 31.68
126.00 33.26 129.00 34.06 132.00 34.85
545.94 554.79 563.65
0.49 0.49 0.49
9.20 8.86 8.86
4.33 4.30 4.27
60.68 61.67 62.65
0.12 0.12 0.12

POWER & ENERGY GENERATION IN TABLE 7.6
50% MEAN YEAR (1980-81)
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
135 138 141
135.00 32.40 138.00 33.12 141.00 33.84
135.00 32.40 138.00 33.12 141.00 33.84
135.00 32.40 138.00 33.12 141.00 33.84
135.00 32.40 138.00 33.12 141.00 33.84
135.00 32.40 138.00 33.12 141.00 33.84
135.00 35.64 138.00 36.43 141.00 37.22
135.00 32.40 138.00 33.12 141.00 33.84
135.00 32.40 138.00 33.12 141.00 33.84
135.00 35.64 138.00 36.43 141.00 37.22
135.00 32.40 138.00 33.12 141.00 33.84
94.05 22.57 94.05 22.57 94.05 22.57
65.55 15.73 65.55 15.73 65.55 15.73
51.30 12.31 51.30 12.31 51.30 12.31
33.25 7.98 33.25 7.98 33.25 7.98
26.60 7.02 26.60 7.02 26.60 7.02
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
19.00 4.56 19.00 4.56 19.00 4.56
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
15.20 4.01 15.20 4.01 15.20 4.01
16.15 3.88 16.15 3.88 16.15 3.88
15.20 3.65 15.20 3.65 15.20 3.65
14.25 3.76 14.25 3.76 14.25 3.76
14.25 3.42 14.25 3.42 14.25 3.42
15.20 3.65 15.20 3.65 15.20 3.65
17.10 3.28 17.10 3.28 17.10 3.28
16.15 3.88 16.15 3.88 16.15 3.88
16.15 3.88 16.15 3.88 16.15 3.88
17.10 4.51 17.10 4.51 17.10 4.51
18.05 4.33 18.05 4.33 18.05 4.33
24.70 5.93 24.70 5.93 24.70 5.93
35.15 8.44 35.15 8.44 35.15 8.44
124.45 29.87 124.45 29.87 124.45 29.87
135.00 32.40 138.00 33.12 141.00 33.84
135.00 35.64 138.00 36.43 141.00 37.22
572.50 581.36 590.22
0.48 0.48 0.48
8.86 8.86 8.86
4.24 4.21 4.19
63.63 64.62 65.60
0.12 0.11 0.11

POWER & ENERGY GENERATION IN TABLE 7.6
50% MEAN YEAR (1980-81)
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
144 147 150
144.00 34.56 147.00 35.28 150.00 36.00
144.00 34.56 147.00 35.28 150.00 36.00
144.00 34.56 147.00 35.28 150.00 36.00
144.00 34.56 147.00 35.28 150.00 36.00
144.00 34.56 147.00 35.28 150.00 36.00
144.00 38.02 147.00 38.81 150.00 39.60
144.00 34.56 147.00 35.28 150.00 36.00
144.00 34.56 147.00 35.28 150.00 36.00
144.00 38.02 147.00 38.81 150.00 39.60
144.00 34.56 147.00 35.28 149.15 35.80
94.05 22.57 94.05 22.57 94.05 22.57
65.55 15.73 65.55 15.73 65.55 15.73
51.30 12.31 51.30 12.31 51.30 12.31
33.25 7.98 33.25 7.98 33.25 7.98
26.60 7.02 26.60 7.02 26.60 7.02
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
19.00 4.56 19.00 4.56 19.00 4.56
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
15.20 4.01 15.20 4.01 15.20 4.01
16.15 3.88 16.15 3.88 16.15 3.88
15.20 3.65 15.20 3.65 15.20 3.65
14.25 3.76 14.25 3.76 14.25 3.76
14.25 3.42 14.25 3.42 14.25 3.42
15.20 3.65 15.20 3.65 15.20 3.65
17.10 3.28 17.10 3.28 17.10 3.28
16.15 3.88 16.15 3.88 16.15 3.88
16.15 3.88 16.15 3.88 16.15 3.88
17.10 4.51 17.10 4.51 17.10 4.51
18.05 4.33 18.05 4.33 18.05 4.33
24.70 5.93 24.70 5.93 24.70 5.93
35.15 8.44 35.15 8.44 35.15 8.44
124.45 29.87 124.45 29.87 124.45 29.87
144.00 34.56 147.00 35.28 150.00 36.00
144.00 38.02 147.00 38.81 150.00 39.60
599.07 607.93 616.58
0.47 0.47 0.47
8.86 8.86 8.65
4.16 4.14 4.11
66.59 67.57 68.53
0.11 0.11 0.10

POWER & ENERGY GENERATION IN TABLE 7.6
50% MEAN YEAR (1980-81)
Net Head = 160.00 mtr
Eff. = 0.92
Restricted Restrict Restrict
Power Energy Power Energy Power Energy
MW GWH MW GWH MW GWH
153 156 159
153.00 36.72 156.00 37.44 159.00 38.16
153.00 36.72 156.00 37.44 159.00 38.16
153.00 36.72 156.00 37.44 159.00 38.16
153.00 36.72 156.00 37.44 159.00 38.16
153.00 36.72 156.00 37.44 159.00 38.16
153.00 40.39 156.00 41.18 159.00 41.98
153.00 36.72 156.00 37.44 159.00 38.16
153.00 36.72 156.00 37.44 159.00 38.16
153.00 40.39 156.00 41.18 159.00 41.98
149.15 35.80 149.15 35.80 149.15 35.80
94.05 22.57 94.05 22.57 94.05 22.57
65.55 15.73 65.55 15.73 65.55 15.73
51.30 12.31 51.30 12.31 51.30 12.31
33.25 7.98 33.25 7.98 33.25 7.98
26.60 7.02 26.60 7.02 26.60 7.02
19.95 4.79 19.95 4.79 19.95 4.79
19.00 4.56 19.00 4.56 19.00 4.56
19.00 4.56 19.00 4.56 19.00 4.56
17.10 4.10 17.10 4.10 17.10 4.10
16.15 3.88 16.15 3.88 16.15 3.88
15.20 4.01 15.20 4.01 15.20 4.01
16.15 3.88 16.15 3.88 16.15 3.88
15.20 3.65 15.20 3.65 15.20 3.65
14.25 3.76 14.25 3.76 14.25 3.76
14.25 3.42 14.25 3.42 14.25 3.42
15.20 3.65 15.20 3.65 15.20 3.65
17.10 3.28 17.10 3.28 17.10 3.28
16.15 3.88 16.15 3.88 16.15 3.88
16.15 3.88 16.15 3.88 16.15 3.88
17.10 4.51 17.10 4.51 17.10 4.51
18.05 4.33 18.05 4.33 18.05 4.33
24.70 5.93 24.70 5.93 24.70 5.93
35.15 8.44 35.15 8.44 35.15 8.44
124.45 29.87 124.45 29.87 124.45 29.87
153.00 36.72 156.00 37.44 157.70 37.85
153.00 40.39 156.00 41.18 159.00 41.98
624.72 632.85 640.68
0.47 0.46 0.46
8.14 8.14 7.82
4.08 4.06 4.03
69.44 70.34 71.21
0.10 0.10 0.10

CHHATRU HYDRO- ELECTRIC PROJECT TABLE-7.7
50% Dep. Power Energy Energy
Discharges MW GWH GWH
MONTH PERIOD 1980-81 108 at 95%m/c Availability
I 132.89 108.00 25.92 25.92
JUN II 154.60 108.00 25.92 24.62
III 219.73 108.00 25.92 24.62
I 231.57 108.00 25.92 24.62
JUL II 223.68 108.00 25.92 24.62
III 205.91 108.00 28.51 27.09
I 223.02 108.00 25.92 24.62
AUG II 146.71 108.00 25.92 24.62
III 165.13 108.00 28.51 27.09
I 103.29 108.00 25.92 24.62
SEP II 65.13 94.05 22.57 21.44
III 45.39 65.55 15.73 15.73
I 35.52 51.30 12.31 12.31
OCT II 23.03 33.25 7.98 7.98
III 18.42 26.60 7.02 7.02
I 13.82 19.95 4.79 4.79
NOV II 13.16 19.00 4.56 4.56
III 13.16 19.00 4.56 4.56
I 11.84 17.10 4.10 4.10
DEC II 11.18 16.15 3.88 3.88
III 10.53 15.20 4.01 4.01
I 11.18 16.15 3.88 3.88
JAN II 10.53 15.20 3.65 3.65
III 9.87 14.25 3.76 3.76
I 9.87 14.25 3.42 3.42
FEB II 10.53 15.20 3.65 3.65
III 11.84 17.10 3.28 3.28
I 11.18 16.15 3.88 3.88
MAR II 11.18 16.15 3.88 3.88
III 11.84 17.10 4.51 4.51
I 12.50 18.05 4.33 4.33
APR II 17.10 24.70 5.93 5.93
III 24.34 35.15 8.44 8.44
I 86.18 108.00 25.92 25.92
MAY II 109.21 108.00 25.92 25.92
III 128.28 108.00 28.51 28.51
TOTAL ENERGY= 488.85 475.80
GWH GWH

CHHATRU HYDRO- ELECTRIC PROJECT
SUMMARY TABLE 7.10
50% MEAN YEAR
Installed Cap. Total Energy Inc. Increase Gwh/ Mw PLF PLF
Mw Gwh Gwh Total Year Dec. - Feb.
78 389.24 0.00 4.99 0.57 0.20
81 399.54 10.30 4.93 0.56 0.19
84 409.83 10.30 4.88 0.56 0.19
87 420.13 10.30 4.83 0.55 0.18
90 430.42 10.30 4.78 0.55 0.17
93 440.72 10.30 4.74 0.54 0.17
96 450.55 9.83 4.69 0.54 0.16
99 460.12 9.58 4.65 0.53 0.16
102 469.70 9.58 4.60 0.53 0.15
105 479.28 9.58 4.56 0.52 0.15
108 488.85 9.58 4.53 0.52 0.14
111 498.43 9.58 4.49 0.51 0.14
114 508.00 9.58 4.46 0.51 0.14
117 517.58 9.58 4.42 0.50 0.13
120 527.16 9.58 4.39 0.50 0.13
123 536.73 9.58 4.36 0.50 0.13
126 545.94 9.20 4.33 0.49 0.12
129 554.79 8.86 4.30 0.49 0.12
132 563.65 8.86 4.27 0.49 0.12
135 572.50 8.86 4.24 0.48 0.12
138 581.36 8.86 4.21 0.48 0.11
141 590.22 8.86 4.19 0.48 0.11
144 599.07 8.86 4.16 0.47 0.11
147 607.93 8.86 4.14 0.47 0.11
150 616.58 8.65 4.11 0.47 0.10
153 624.72 8.14 4.08 0.47 0.10
156 632.85 8.14 4.06 0.46 0.10
159 640.68 7.82 4.03 0.46 0.10

DISCH. IN CUMECS
400.00
300.00
200.00
100.00
0.00
0.00
CHHATRU HEP FLOW DURATION CURVE(OVER-ALL)
10.00
20.00
30.00
40.00
50.00
60.00
% OCCURR.
70.00
80.00
90.00
100.00
PLATE 5.1
%Cumm.occ. Disch.(m3/sec)
0.31 300.00
10.49 200.00
19.03 150.00
28.40 100.00
29.53 90.00
31.38 80.00
32.92 70.00
34.88 60.00
37.04 50.00
41.26 40.00
46.50 30.00
51.23 25.00
59.67 20.00
72.53 15.00
91.56 10.00
100.00 5.00
90% Dep. Discharge = 10.41 cumecs
50% Dep. Discharge = 26.30 cumecs
Design discharge of 75 Cumec 32.15 % availability

DISCH.(CUMECS)
40
35
30
25
20
15
10
5
0
0.00
CHHATRU HEP FLOW DURATION CURVE (LEAN SEASON)
10.00
20.00
30.00
40.00
50.00
60.00
% OCCURR.
70.00
80.00
90.00
100.00
PLATE 5.2
Series1
%Cumm.occ. Disch.
2.06 35
2.47 30
4.94 25
13.58 20
32.92 15
74.49 10
100.00 5
90% Dep. Discharge = 6.96 Cumecs
50% Dep. Discharge = 12.95 Cumecs

TEN DAILY AVERAGE DISCHARGE DATA OF RIVER CHANDRA AT GHOUSA
Year Period 1973-74 1974-75 1975-76 1976-77 1977-78 1978-79 1979-80
I 279 98 196 208 135 237 101
June II 464 163 271 163 93 215 205
III 402 110 306 139 281 411 403
I 383 154 228 269 370 443 359
July II 403 289 403 352 347 369 431
III 330 238 278 372 294 360 346
I 323 262 329 262 349 368 386
Aug. II 229 222 357 233 249 289 322
III 266 205 236 184 221 259 236
I 217 136 183 156 189 126 213
Sept. II 198 100 127 84 109 105 112
III 136 66 80 69 71 83 51
I 48 35 61 49 50 56 48
Oct. II 31 27 51 31 34 44 39
III 26 22 33 23 29 38 34
I 22 18 23 21 26 28 31
Nov. II 19 17 20 19 22 25 27
III 18 16 18 17 21 25 26
I 18 15 16 16 20 23 25
Dec. II 17 13 14 14 17 22 23
III 17 14 13 13 15 22 23
I 16 14 12 12 13 22 20
Jan. II 14 14 12 11 15 19 19
III 17 12 11 9 14 18 18
I 14 14 12 13 13 20 23
Feb. II 17 14 8 12 12 18 20
III 15 14 10 12 18 16 22
I 14 11 12 12 12 17 20
March II 15 12 11 12 12 22 22
III 19 16 10 17 15 28 24
I 21 18 10 20 16 31 26
April II 26 25 16 19 26 38 29
III 43 35 40 24 33 63 32
I 66 51 57 24 102 88 66
May II 57 111 88 36 159 77 90
III 64 143 122 88 181 76 122
TEN DAILY AVERAGE DISCHARGE DATA OF RIVER CHENAB AT UDAIPUR
Month Period 1973-74 1974-75 1975-76 1976-77 1977-78 1978-79 1979-80
I 195 361 477 258 456 197
June II 318 558 351 184 424 401
III 203 651 287 633 845 806
I 299 513 574 828 904 736
July II 636 887 721 754 700 927

III 504 618 755 601 700 698
I 524 731 569 724 725 817
Aug. II 430 856 518 501 619 666
III 417 535 381 468 528 437
I 293 718 326 396 253 423
Sept. II 205 288 178 226 221 216
III 144 177 159 151 164 130
I 82 148 118 109 121 127
Oct. II 67 121 70 80 96 108
III 55 79 56 69 79 91
I 46 58 52 57 59 83
Nov. II 40 49 44 49 49 70
III 36 42 37 44 44 65
I 36 39 34 38 40 59
Dec. II 35 33 31 35 38 57
III 35 32 31 33 35 57
I 24 32 33 30 32 41 57
Jan. II 22 31 33 29 33 42 56
III 23 26 32 155 32 40 52
I 21 27 31 33 32 39 58
Feb. II 23 31 25 27 27 38 57
III 21 32 28 26 32 - 54
I 23 30 31 28 31 - 51
March II 23 31 29 29 31 - 51
III 35 31 28 37 36 - 51
I 42 38 34 40 38 - 58
April II 53 54 42 39 66 91 71
III 75 71 101 47 82 144 95
I 137 108 131 50 197 179 155
May II 106 228 189 75 290 163 182
III 125 277 276 168 336 145 240

AL (in cu.M/Sec.) FROM 1973-74 Nov.2000.
1980-81 1981-82 1982-83 1983-84 1984-85 1985-86 1986-87 1987-88 1988-89
202 151 122 133 256 186 95 165 155
235 152 232 148 248 220 228 170 199
334 315 213 219 299 255 391 224 392
352 277 283 269 289 294 331 386 393
340 357 314 224 220 340 382 414 375
313 376 353 337 267 271 417 451 378
339 324 379 397 300 286 374 359 328
223 296 335 358 321 283 338 335 333
251 216 247 354 262 250 228 345 238
157 169 163 288 166 200 207 259 198
99 94 151 202 121 112 105 168 167
69 86 115 108 60 81 80 129 168
54 47 80 76 37 65 49 74 79
35 39 70 51 38 42 37 52 57
28 25 39 33 37 34 27 45 48
21 23 26 27 34 29 23 43 43
20 20 25 25 31 22 23 40 39
20 18 22 23 26 21 20 37 37
18 17 18 20 25 20 19 29 31
17 15 15 19 34 18 19 24 29
16 14 14 18 23 16 18 20 25
17 14 15 19 19 15 19 19 23
16 14 15 19 18 15 19 18 20
15 12 15 18 17 15 20 17 19
15 13 14 17 15 15 19 17 18
16 14 14 17 18 14 18 17 17
18 13 14 16 18 14 17 16 15
17 15 18 16 21 14 18 17 17
17 15 20 18 22 14 17 24 17
18 14 18 19 23 15 17 34 18
19 16 18 20 24 16 18 28 18
26 17 18 20 29 18 19 54 20
37 25 21 26 45 21 44 97 21
131 49 37 45 56 45 64 94 25
166 44 56 74 71 121 55 118 51
195 76 83 125 159 69 74 122 132
(in cu.M/Sec.) FROM Jan.1973-74 May.2001.
1980-81 1981-82 1982-83 1983-84 1984-85 1985-86 1986-87 1987-88 1988-89
395 292 320 264 615 379 207 330 420
481 311 537 310 555 469 499 383 535
696 738 519 555 643 511 810 546 958
731 582 582 497 576 579 685 717 950
762 779 705 350 437 666 797 709 811

635 818 903 725 556 535 819 863 920
750 694 861 903 598 585 697 624 710
423 628 664 686 639 564 648 577 704
473 467 425 697 536 520 482 631 493
301 370 338 597 362 392 424 532 416
213 221 339 406 239 240 197 352 306
165 211 136 195 112 165 181 273 274
150 125 84 142 78 127 109 132 170
116 108 71 99 65 80 78 100 132
95 92 63 62 60 63 64 80 98
84 76 53 50 48 54 53 78 85
77 57 48 48 43 49 49 75 75
72 53 44 44 41 46 45 71 64
68 49 42 42 38 41 40 68 57
67 45 42 39 37 38 37 64 52
65 44 39 36 36 36 34 62 47
65 36 31 35 36 37 34 57 39
62 35 29 35 34 35 33 55 36
65 33 28 32 31 34 32 52 36
59 36 27 30 31 34 31 51 34
64 35 26 28 30 34 36 49 35
64 37 24 22 31 35 38 48 32
61 37 26 33 33 35 42 57 33
60 37 30 33 31 49 52 77 34
65 38 32 36 36 35 54 70 43
70 45 44 42 36 37 65 100 36
100 56 45 51 42 65 82 143 40
149 80 45 69 63 103 102 187 44
304 138 100 128 93 143 110 243 51
321 109 173 180 120 245 111 350 73
405 179 167 353 386 170 156 377 181

1989-90 1990-91 1991-92 1992-93 1993-94 1994-95 1995-96 1996-97 1997-98
292 176 213 90 156 215 156 169 67
215 174 301 205 220 220 328 299 174
257 449 352 263 260 311 273 351 230
240 402 448 202 289 379 415 263 257
356 285 433 299 326 402 365 290 319
456 284 397 332 192 362 262 323 344
209 335 326 247 245 329 254 345 272
290 283 253 236 184 265 256 343 249
266 266 247 248 204 370 237 249 216
133 200 226 212 163 195 263 186 161
126 148 178 104 190 140 181 120 161
106 112 103 67 75 74 117 103 121
64 69 72 60 58 63 78 77 67
43 53 54 49 45 46 59 60 50
37 42 44 44 34 38 45 52 44
33 38 38 34 30 38 36 46 41
30 37 30 28 25 36 32 44 38
27 34 26 25 23 34 31 41 36
28 27 23 24 23 33 32 40 34
26 23 21 23 22 31 25 39 33
24 21 20 23 20 30 25 37 32
24 19 19 21 19 29 25 36 30
23 19 19 20 18 27 25 34 30
23 17 18 19 17 24 26 32 29
22 16 18 18 17 23 22 34 27
23 14 18 17 17 23 23 34 27
22 14 17 18 17 24 21 33 30
23 12 18 18 19 24 23 33 30
25 16 19 19 21 26 23 34 31
26 17 18 19 23 27 27 39 32
26 20 19 21 23 28 27 37 34
28 18 23 23 28 29 27 39 37
33 30 29 31 33 28 29 39 40
62 61 34 50 52 32 33 43 46
140 97 48 45 58 90 31 43 53
184 90 70 85 150 105 74 52 154
1989-90 1990-91 1991-92 1992-93 1993-94 1994-95 1995-96 1996-97 1997-98
497 503 589 490 305 388 409 253 251
445 459 775 700 471 362 831 542 211
530 989 826 909 458 996 589 703 362
501 886 905 825 648 954 776 140 344
694 721 975 864 650 758 837 298 524

992 634 1025 950 451 747 677 312 561
525 820 820 816 496 753 548 216 569
639 582 487 631 398 612 658 182 604
569 590 510 650 469 653 605 163 523
314 424 473 472 356 511 452 407 437
326 215 415 218 246 220 276 366 294
257 125 234 163 200 129 204 295 169
175 88 163 136 130 117 170 187 95
131 72 125 104 108 96 145 158 57
101 64 96 89 80 73 167 132 59
90 58 88 82 77 73 100 85 62
85 43 82 80 80 70 74 69 62
81 31 78 75 74 67 61 62 57
78 39 72 68 68 64 59 67 53
70 37 68 61 67 60 56 64 50
64 38 63 56 56 60 53 62 54
61 34 56 48 50 63 56 60 48
56 29 54 46 48 63 58 57 47
53 29 54 44 44 61 56 57 45
50 38 59 41 46 60 58 60 42
47 28 54 41 45 63 63 59 43
44 30 52 41 53 62 61 67 46
43 31 52 45 44 60 65 85 56
43 45 61 44 53 63 62 106 58
49 69 72 42 64 64 30 96 76
50 98 73 42 68 69 80 67 86
59 136 84 50 69 77 98 64 114
82 162 110 74 88 88 111 72 172
133 178 152 118 115 97 125 78 202
348 220 233 124 134 101 131 54 244
545 246 326 168 194 128 121 109 398

1998-99 1999-2000 2000-01
221 147 130
175 278 187
286 384 245
485 429 236
520 435 248
453 344 292
442 371 278
426 293 248
351 321 263
296 240 200
227 221 135
128 197 92
105 118 58
75 72 53
69 67 50
66 67 51
57 66 45
45 61 41
40 59
38 57
36 57
35 43
34 42
32 41
31 55
30 55
29 46
30 50
30 46
33 43
34 42
40 42
124 45
164 86
193 197
218 187
1998-99 1999-2000 2000-01
466 273 290
333 590 451
717 777 675
968 1032 655
815 908 725

610 712 944
708 881 674
709 588 670
564 591 641
504 470 500
322 427 336
264 319 207
152 202 166
132 121 143
110 109 135
91 96 130
81 85 104
70 72 91
61 66 85
55 63 83
48 61 80
49 53 77
47 49 67
45 49 71
57 48 65
58 46 65
55 48 65
55 47 66
55 47 71
60 52 75
72 69 72
118 97 86
281 117 98
255 193 152
360 411 257
397 430 293

Table-5.3(1)
REGRESSION ANALYSIS BETWEEN DISCHARGES OF TANDI AND GHOUSAL JUNE- JULY
TANDI GHOUSAL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
I 54.28 98.00 1.7346 1.9912 -0.3652 -0.3987 0.1334 0.1456
1974 JUN II 85.59 163.00 1.9324 2.2122 -0.1674 -0.1777 0.0280 0.0298
III 57.44 110.00 1.7592 2.0414 -0.3406 -0.3485 0.1160 0.1187
I 92.61 154.00 1.9667 2.1875 -0.1332 -0.2024 0.0177 0.0270
JUL II 163.53 289.00 2.2136 2.4609 0.1138 0.0710 0.0129 0.0081
III 136.12 238.00 2.1339 2.3766 0.0341 -0.0133 0.0012 -0.0005
I 86.44 196.00 1.9367 2.2923 -0.1631 -0.0977 0.0266 0.0159
1975 JUN II 127.51 271.00 2.1055 2.4330 0.0057 0.0430 0.0000 0.0002
III 162.02 306.00 2.2096 2.4857 0.1098 0.0958 0.0120 0.0105
I 132.00 228.00 2.1206 2.3579 0.0208 -0.0320 0.0004 -0.0007
JUL II 210.91 403.00 2.3241 2.6053 0.2243 0.2154 0.0503 0.0483
III 151.52 278.00 2.1805 2.4440 0.0807 0.0541 0.0065 0.0044
I 109.18 208.00 2.0381 2.3181 -0.0617 -0.0719 0.0038 0.0044
1976 JUN II 84.79 163.00 1.9283 2.2122 -0.1715 -0.1777 0.0294 0.0305
III 63.81 139.00 1.8049 2.1430 -0.2949 -0.2469 0.0870 0.0728
I 146.59 269.00 2.1661 2.4298 0.0663 0.0398 0.0044 0.0026
JUL II 208.80 352.00 2.3197 2.5465 0.2199 0.1566 0.0484 0.0344
III 208.87 372.00 2.3199 2.5705 0.2201 0.1806 0.0484 0.0397
I 61.59 135.00 1.7895 2.1303 -0.3103 -0.2596 0.0963 0.0806
1977 JUN II 48.04 93.00 1.6816 1.9685 -0.4182 -0.4214 0.1749 0.1763
III 155.71 281.00 2.1923 2.4487 0.0925 0.0588 0.0086 0.0054
I 209.09 370.00 2.3203 2.5682 0.2205 0.1783 0.0486 0.0393
JUL II 185.87 347.00 2.2692 2.5403 0.1694 0.1504 0.0287 0.0255
III 156.26 294.00 2.1938 2.4683 0.0940 0.0784 0.0088 0.0074
I 116.06 237.00 2.0647 2.3747 -0.0351 -0.0152 0.0012 0.0005
1978 JUN II 97.95 215.00 1.9910 2.3324 -0.1088 -0.0575 0.0118 0.0063
III 229.03 411.00 2.3599 2.6138 0.2601 0.2239 0.0676 0.0582
I 204.43 443.00 2.3105 2.6464 0.2107 0.2565 0.0444 0.0540
JUL II 171.15 369.00 2.2334 2.5670 0.1336 0.1771 0.0178 0.0237
III 176.99 360.00 2.2479 2.5563 0.1481 0.1664 0.0219 0.0246
I 40.70 101.00 1.6096 2.0043 -0.4902 -0.3856 0.2403 0.1890
1979 JUN II 90.39 205.00 1.9561 2.3118 -0.1437 -0.0782 0.0206 0.0112
III 194.47 403.00 2.2889 2.6053 0.1890 0.2154 0.0357 0.0407
I 182.98 359.00 2.2624 2.5551 0.1626 0.1652 0.0264 0.0269
JUL II 229.97 431.00 2.3617 2.6345 0.2619 0.2446 0.0686 0.0640
III 173.08 346.00 2.2382 2.5391 0.1384 0.1492 0.0192 0.0206
I 99.89 202.00 1.9995 2.3054 -0.1003 -0.0846 0.0101 0.0085
1980 JUN II 121.45 235.00 2.0844 2.3711 -0.0154 -0.0189 0.0002 0.0003
III 173.78 334.00 2.2400 2.5237 0.1402 0.1338 0.0197 0.0188
I 184.27 352.00 2.2655 2.5465 0.1656 0.1566 0.0274 0.0259
JUL II 184.29 340.00 2.2655 2.5315 0.1657 0.1416 0.0275 0.0235
III 161.10 313.00 2.2071 2.4955 0.1073 0.1056 0.0115 0.0113
I 70.07 151.00 1.8455 2.1790 -0.2543 -0.2109 0.0647 0.0536
1981 JUN II 77.57 152.00 1.8897 2.1818 -0.2101 -0.2081 0.0442 0.0437
III 186.01 315.00 2.2695 2.4983 0.1697 0.1084 0.0288 0.0184
I 141.26 277.00 2.1500 2.4425 0.0502 0.0526 0.0025 0.0026
JUL II 169.95 357.00 2.2303 2.5527 0.1305 0.1627 0.0170 0.0212
III 196.92 376.00 2.2943 2.5752 0.1945 0.1853 0.0378 0.0360
I 60.53 122.00 1.7820 2.0864 -0.3178 -0.3036 0.1010 0.0965
1982 JUN II 100.83 232.00 2.0036 2.3655 -0.0962 -0.0244 0.0093 0.0024
III 115.64 213.00 2.0631 2.3284 -0.0367 -0.0615 0.0013 0.0023
I 156.48 283.00 2.1945 2.4518 0.0946 0.0619 0.0090 0.0059
JUL II 150.71 314.00 2.1781 2.4969 0.0783 0.1070 0.0061 0.0084
III 186.55 353.00 2.2708 2.5478 0.1710 0.1579 0.0292 0.0270
I 71.20 133.00 1.8525 2.1239 -0.2473 -0.2661 0.0612 0.0658
1983 JUN II 83.29 148.00 1.9206 2.1703 -0.1792 -0.2197 0.0321 0.0394
III 108.14 219.00 2.0340 2.3404 -0.0658 -0.0495 0.0043 0.0033
I 133.41 269.00 2.1252 2.4298 0.0254 0.0398 0.0006 0.0010
JUL II 89.79 224.00 1.9532 2.3502 -0.1466 -0.0397 0.0215 0.0058
III 201.52 337.00 2.3043 2.5276 0.2045 0.1377 0.0418 0.0282
G.TOTAL 125.99 143.40 0.00 0.00 2.18 2.00
NO. OF PERIOD 60 LOG x' LOG y'
AVERAGE
Co-efficient of Corelation
2.0998 2.3899
b = SIGMA X*Y = 0.9168
SIGMA X^2

REGRESSION ANALYSIS BETWEEN DISCHARGES OF TANDI AND GHOUSAL AUG.- SEPT.
TANDI GHOUSAL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
I 140.96 262.00 2.1491 2.4183 0.1890 0.1610 0.0357 0.0304
1974 AUG II 108.22 222.00 2.0343 2.3464 0.0742 0.0890 0.0055 0.0066
III 106.99 205.00 2.0293 2.3118 0.0693 0.0544 0.0048 0.0038
I 75.23 136.00 1.8764 2.1335 -0.0837 -0.1238 0.0070 0.0104
SEPT II 60.48 100.00 1.7816 2.0000 -0.1785 -0.2573 0.0318 0.0459
III 41.41 66.00 1.6171 1.8195 -0.3430 -0.4378 0.1176 0.1501
I 182.62 329.00 2.2615 2.5172 0.3015 0.2599 0.0909 0.0784
1975 AUG II 218.79 357.00 2.3400 2.5527 0.3800 0.2954 0.1444 0.1122
III 134.86 236.00 2.1299 2.3729 0.1698 0.1156 0.0288 0.0196
I 101.37 183.00 2.0059 2.2625 0.0458 0.0051 0.0021 0.0002
SEPT II 73.70 127.00 1.8675 2.1038 -0.0926 -0.1535 0.0086 0.0142
III 44.74 80.00 1.6507 1.9031 -0.3094 -0.3542 0.0957 0.1096
I 146.32 262.00 2.1653 2.4183 0.2052 0.1610 0.0421 0.0330
1976 AUG II 127.47 233.00 2.1054 2.3674 0.1453 0.1100 0.0211 0.0160
III 98.12 184.00 1.9918 2.2648 0.0317 0.0075 0.0010 0.0002
I 84.73 156.00 1.9280 2.1931 -0.0320 -0.0642 0.0010 0.0021
SEPT II 54.96 84.00 1.7400 1.9243 -0.2200 -0.3330 0.0484 0.0733
III 44.35 69.00 1.6469 1.8388 -0.3132 -0.4185 0.0981 0.1310
I 181.88 349.00 2.2598 2.5428 0.2997 0.2855 0.0898 0.0856
1977 AUG II 119 249.00 2.0755 2.3962 0.1155 0.1389 0.0133 0.0160
III 109.56 221.00 2.0397 2.3444 0.0796 0.0871 0.0063 0.0069
I 92.03 189.00 1.9639 2.2765 0.0039 0.0192 0.0000 0.0001
SEPT II 61.94 109.00 1.7920 2.0374 -0.1681 -0.2199 0.0283 0.0370
III 43.63 71.00 1.6398 1.8513 -0.3203 -0.4061 0.1026 0.1300
I 182.35 368.00 2.2609 2.5658 0.3008 0.3085 0.0905 0.0928
1978 AUG II 146.17 289.00 2.1649 2.4609 0.2048 0.2036 0.0419 0.0417
III 119.00 259.00 2.0755 2.4133 0.1155 0.1560 0.0133 0.0180
I 60.00 126.00 1.7782 2.1004 -0.1819 -0.1569 0.0331 0.0285
SEPT II 37.98 105.00 1.5796 2.0212 -0.3805 -0.2361 0.1448 0.0898
III 53.28 83.00 1.7266 1.9191 -0.2335 -0.3382 0.0545 0.0790
I 188.89 386.00 2.2762 2.5866 0.3161 0.3293 0.0999 0.1041
1979 AUG II 156.29 322.00 2.1939 2.5079 0.2339 0.2505 0.0547 0.0586
III 99.16 236.00 1.9963 2.3729 0.0363 0.1156 0.0013 0.0042
I 98.36 213.00 1.9928 2.3284 0.0328 0.0711 0.0011 0.0023
SEPT II 52.16 112.00 1.7173 2.0492 -0.2427 -0.2081 0.0589 0.0505
III 23.60 51.00 1.3729 1.7076 -0.5872 -0.5497 0.3447 0.3228
I 176.94 339.00 2.2478 2.5302 0.2878 0.2729 0.0828 0.0785
1980 AUG II 95.18 223.00 1.9785 2.3483 0.0185 0.0910 0.0003 0.0017
III 105.30 251.00 2.0224 2.3997 0.0624 0.1424 0.0039 0.0089
I 68.52 157.00 1.8358 2.1959 -0.1242 -0.0614 0.0154 0.0076
SEPT II 45.10 99.00 1.6542 1.9956 -0.3059 -0.2617 0.0936 0.0800
III 30.36 69.00 1.4823 1.8388 -0.4778 -0.4185 0.2283 0.1999
I 163.37 324.00 2.2132 2.5105 0.2531 0.2532 0.0641 0.0641
1981 AUG II 145.32 296.00 2.1623 2.4713 0.2023 0.2140 0.0409 0.0433
III 87.76 216.00 1.9433 2.3345 -0.0168 0.0771 0.0003 -0.0013
I 81.66 169.00 1.9120 2.2279 -0.0481 -0.0294 0.0023 0.0014
SEPT II 47.39 94.00 1.6757 1.9731 -0.2844 -0.2842 0.0809 0.0808
III 39.77 86.00 1.5996 1.9345 -0.3605 -0.3228 0.1300 0.1164
I 199.82 379.00 2.3006 2.5786 0.3406 0.3213 0.1160 0.1094
1982 AUG II 151.72 335.00 2.1810 2.5250 0.2210 0.2677 0.0488 0.0592
III 97.35 247.00 1.9883 2.3927 0.0283 0.1354 0.0008 0.0038
I 88.49 163.00 1.9469 2.2122 -0.0132 -0.0451 0.0002 0.0006
SEPT II 68.20 151.00 1.8338 2.1790 -0.1263 -0.0783 0.0159 0.0099
III 37.19 115.00 1.5704 2.0607 -0.3896 -0.1966 0.1518 0.0766
I 246.85 397.00 2.3924 2.5988 0.4324 0.3415 0.1869 0.1476
1983 AUG II 188.24 358.00 2.2747 2.5539 0.3146 0.2966 0.0990 0.0933
III 185.17 354.00 2.2676 2.5490 0.3075 0.2917 0.0946 0.0897
I 149.26 288.00 2.1739 2.4594 0.2139 0.2021 0.0457 0.0432
SEPT II 97.29 202.00 1.9881 2.3054 0.0280 0.0480 0.0008 0.0013
III 53.98 108.00 1.7322 2.0334 -0.2278 -0.2239 0.0519 0.0510
G.TOTAL 117.60 135.44 0.00 0.00 3.52 3.37
NO. OF PERIOD 60 LOG x' LOG y'
AVERAGE 1.9601 2.2573
Co-efficient of Corelation
b = SIGMA X*Y = 0.9583
SIGMA X^2
Table-5.3(2)

Table-5.3(3)
REGRESSION ANALYSIS BETWEEN DISCHARGES OF TANDI AND GHOUSAL ( NON-MONSOON PERIOD)
TANDI GHOUSAL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
I 24.62 35.00 1.3913 1.5441 0.2877 0.1687 0.0828 0.0485
1974-75 OCT II 21.58 27.00 1.3341 1.4314 0.2305 0.0560 0.0531 0.0129
III 17.31 22.00 1.2383 1.3424 0.1347 -0.0329 0.0181 -0.0044
I 14.92 18.00 1.1738 1.2553 0.0702 -0.1201 0.0049 -0.0084
NOV II 18.83 17.00 1.2749 1.2304 0.1713 -0.1449 0.0293 -0.0248
III 11.45 16.00 1.0588 1.2041 -0.0448 -0.1712 0.0020 0.0077
I 10.69 15.00 1.0290 1.1761 -0.0746 -0.1992 0.0056 0.0149
DEC II 10.43 13.00 1.0183 1.1139 -0.0853 -0.2614 0.0073 0.0223
III 10.42 14.00 1.0179 1.1461 -0.0857 -0.2292 0.0073 0.0196
I 8.38 14.00 0.9232 1.1461 -0.1803 -0.2292 0.0325 0.0413
JAN II 8.07 14.00 0.9069 1.1461 -0.1967 -0.2292 0.0387 0.0451
III 7.60 12.00 0.8808 1.0792 -0.2228 -0.2961 0.0496 0.0660
I 8.19 14.00 0.9133 1.1461 -0.1903 -0.2292 0.0362 0.0436
FEB II 7.59 14.00 0.8802 1.1461 -0.2233 -0.2292 0.0499 0.0512
III 9.12 14.00 0.9600 1.1461 -0.1436 -0.2292 0.0206 0.0329
I 7.30 11.00 0.8633 1.0414 -0.2403 -0.3339 0.0577 0.0802
MAR II 6.43 12.00 0.8082 1.0792 -0.2954 -0.2961 0.0872 0.0875
III 7.26 16.00 0.8609 1.2041 -0.2427 -0.1712 0.0589 0.0415
I 8.42 18.00 0.9253 1.2553 -0.1783 -0.1201 0.0318 0.0214
APR II 10.38 25.00 1.0162 1.3979 -0.0874 0.0226 0.0076 -0.0020
III 13.70 35.00 1.1367 1.5441 0.0331 0.1687 0.0011 0.0056
I 23.16 51.00 1.3647 1.7076 0.2612 0.3322 0.0682 0.0868
MAY II 47.15 111.00 1.6735 2.0453 0.5699 0.6700 0.3248 0.3818
III 62.11 143.00 1.7932 2.1553 0.6896 0.7800 0.4755 0.5379
I 36.47 61.00 1.5619 1.7853 0.4583 0.4100 0.2101 0.1879
1975-76 OCT II 30.99 51.00 1.4912 1.7076 0.3876 0.3322 0.1503 0.1288
III 21.50 33.00 1.3324 1.5185 0.2289 0.1432 0.0524 0.0328
I 16.53 23.00 1.2183 1.3617 0.1147 -0.0136 0.0132 -0.0016
NOV II 14.42 20.00 1.1590 1.3010 0.0554 -0.0743 0.0031 -0.0041
III 13.23 18.00 1.1216 1.2553 0.0180 -0.1201 0.0003 -0.0022
I 13.32 16.00 1.1245 1.2041 0.0209 -0.1712 0.0004 -0.0036
DEC II 12.02 14.00 1.0799 1.1461 -0.0237 -0.2292 0.0006 0.0054
III 11.75 13.00 1.0700 1.1139 -0.0336 -0.2614 0.0011 0.0088
I 12.16 12.00 1.0849 1.0792 -0.0187 -0.2961 0.0003 0.0055
JAN II 11.46 12.00 1.0592 1.0792 -0.0444 -0.2961 0.0020 0.0131
III 10.84 11.00 1.0350 1.0414 -0.0686 -0.3339 0.0047 0.0229
I 10.41 12.00 1.0175 1.0792 -0.0861 -0.2961 0.0074 0.0255
FEB II 10.21 8.00 1.0090 0.9031 -0.0946 -0.4722 0.0089 0.0447
III 10.03 10.00 1.0013 1.0000 -0.1023 -0.3753 0.0105 0.0384
I 10.49 12.00 1.0208 1.0792 -0.0828 -0.2961 0.0069 0.0245
MAR II 10.10 11.00 1.0043 1.0414 -0.0993 -0.3339 0.0099 0.0331
III 10.13 10.00 1.0056 1.0000 -0.0980 -0.3753 0.0096 0.0368
I 10.08 10.00 1.0035 1.0000 -0.1001 -0.3753 0.0100 0.0376
APR II 10.91 16.00 1.0378 1.2041 -0.0658 -0.1712 0.0043 0.0113
III 20.08 40.00 1.3028 1.6021 0.1992 0.2267 0.0397 0.0452
I 26.13 57.00 1.4171 1.7559 0.3136 0.3805 0.0983 0.1193
MAY II 39.74 88.00 1.5992 1.9445 0.4956 0.5692 0.2457 0.2821
III 62.72 122.00 1.7974 2.0864 0.6938 0.7110 0.4814 0.4933
I 31.29 49.00 1.4954 1.6902 0.3918 0.3149 0.1535 0.1234
1976-77 OCT II 20.19 31.00 1.3051 1.4914 0.2015 0.1160 0.0406 0.0234
III 16.71 23.00 1.2230 1.3617 0.1194 -0.0136 0.0143 -0.0016
I 14.45 21.00 1.1599 1.3222 0.0563 -0.0531 0.0032 -0.0030
NOV II 13.17 19.00 1.1196 1.2788 0.0160 -0.0966 0.0003 -0.0015
III 11.95 17.00 1.0774 1.2304 -0.0262 -0.1449 0.0007 0.0038
I 10.40 16.00 1.0170 1.2041 -0.0866 -0.1712 0.0075 0.0148
DEC II 9.24 14.00 0.9657 1.1461 -0.1379 -0.2292 0.0190 0.0316
III 8.93 13.00 0.9509 1.1139 -0.1527 -0.2614 0.0233 0.0399
I 8.07 12.00 0.9069 1.0792 -0.1967 -0.2961 0.0387 0.0583
JAN II 7.97 11.00 0.9015 1.0414 -0.2021 -0.3339 0.0409 0.0675
III 7.18 9.00 0.8561 0.9542 -0.2475 -0.4211 0.0612 0.1042
I 9.47 13.00 0.9763 1.1139 -0.1272 -0.2614 0.0162 0.0333
FEB II 7.22 12.00 0.8585 1.0792 -0.2451 -0.2961 0.0600 0.0726
III 7.26 12.00 0.8609 1.0792 -0.2427 -0.2961 0.0589 0.0719
I 7.12 12.00 0.8525 1.0792 -0.2511 -0.2961 0.0631 0.0744
MAR II 7.33 12.00 0.8651 1.0792 -0.2385 -0.2961 0.0569 0.0706
III 9.05 17.00 0.9566 1.2304 -0.1469 -0.1449 0.0216 0.0213
I 9.91 20.00 0.9961 1.3010 -0.1075 -0.0743 0.0116 0.0080
APR II 9.31 19.00 0.9689 1.2788 -0.1346 -0.0966 0.0181 0.0130
III 10.28 24.00 1.0120 1.3802 -0.0916 0.0049 0.0084 -0.0004
I 11.33 24.00 1.0542 1.3802 -0.0494 0.0049 0.0024 -0.0002
MAY II 15.18 36.00 1.1813 1.5563 0.0777 0.1810 0.0060 0.0141
III 36.42 88.00 1.5613 1.9445 0.4578 0.5692 0.2095 0.2605
I 30.11 50.00 1.4787 1.6990 0.3751 0.3236 0.1407 0.1214
1977-78 OCT II 23.55 34.00 1.3720 1.5315 0.2684 0.1562 0.0720 0.0419

Table-5.3(4)
TANDI GHOUSAL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
III 18.45 29.00 1.2660 1.4624 0.1624 0.0871 0.0264 0.0141
I 15.74 26.00 1.1970 1.4150 0.0934 0.0396 0.0087 0.0037
NOV II 14.3 22.00 1.1553 1.3424 0.0517 -0.0329 0.0027 -0.0017
III 13.85 21.00 1.1414 1.3222 0.0379 -0.0531 0.0014 -0.0020
I 12.17 20.00 1.0853 1.3010 -0.0183 -0.0743 0.0003 0.0014
DEC II 10.86 17.00 1.0358 1.2304 -0.0678 -0.1449 0.0046 0.0098
III 10.35 15.00 1.0149 1.1761 -0.0886 -0.1992 0.0079 0.0177
I 9.94 13.00 0.9974 1.1139 -0.1062 -0.2614 0.0113 0.0278
JAN II 11.57 15.00 1.0633 1.1761 -0.0403 -0.1992 0.0016 0.0080
III 10.35 14.00 1.0149 1.1461 -0.0886 -0.2292 0.0079 0.0203
I 9.16 13.00 0.9619 1.1139 -0.1417 -0.2614 0.0201 0.0370
FEB II 10.57 12.00 1.0241 1.0792 -0.0795 -0.2961 0.0063 0.0235
III 9.02 18.00 0.9552 1.2553 -0.1484 -0.1201 0.0220 0.0178
I 8.6 12.00 0.9345 1.0792 -0.1691 -0.2961 0.0286 0.0501
MAR II 8.1 12.00 0.9085 1.0792 -0.1951 -0.2961 0.0381 0.0578
III 8.41 15.00 0.9248 1.1761 -0.1788 -0.1992 0.0320 0.0356
I 9.1 16.00 0.9590 1.2041 -0.1445 -0.1712 0.0209 0.0247
APR II 14.41 26.00 1.1587 1.4150 0.0551 0.0396 0.0030 0.0022
III 19.48 33.00 1.2896 1.5185 0.1860 0.1432 0.0346 0.0266
I 44.66 102.00 1.6499 2.0086 0.5463 0.6333 0.2985 0.3460
MAY II 70.87 159.00 1.8505 2.2014 0.7469 0.8261 0.5578 0.6170
III 86.93 181.00 1.9392 2.2577 0.8356 0.8824 0.6982 0.7373
I 24.94 56.00 1.3969 1.7482 0.2933 0.3729 0.0860 0.1094
1978-79 OCT II 17.61 44.00 1.2458 1.6435 0.1422 0.2681 0.0202 0.0381
III 21.49 38.00 1.3322 1.5798 0.2286 0.2045 0.0523 0.0467
I 12.26 28.00 1.0885 1.4472 -0.0151 0.0718 0.0002 -0.0011
NOV II 10.70 25.00 1.0294 1.3979 -0.0742 0.0226 0.0055 -0.0017
III 11.17 25.00 1.0481 1.3979 -0.0555 0.0226 0.0031 -0.0013
I 10.02 23.00 1.0009 1.3617 -0.1027 -0.0136 0.0106 0.0014
DEC II 9.29 22.00 0.9680 1.3424 -0.1356 -0.0329 0.0184 0.0045
III 9.17 22.00 0.9624 1.3424 -0.1412 -0.0329 0.0199 0.0046
I 8.52 22.00 0.9304 1.3424 -0.1731 -0.0329 0.0300 0.0057
JAN II 7.92 19.00 0.8987 1.2788 -0.2049 -0.0966 0.0420 0.0198
III 8.07 18.00 0.9069 1.2553 -0.1967 -0.1201 0.0387 0.0236
I 7.86 20.00 0.8954 1.3010 -0.2082 -0.0743 0.0433 0.0155
FEB II 7.12 18.00 0.8525 1.2553 -0.2511 -0.1201 0.0631 0.0301
III 9.41 16.00 0.9736 1.2041 -0.1300 -0.1712 0.0169 0.0223
I 8.35 17.00 0.9217 1.2304 -0.1819 -0.1449 0.0331 0.0264
MAR II 18.35 22.00 1.2636 1.3424 0.1600 -0.0329 0.0256 -0.0053
III 28.50 28.00 1.4548 1.4472 0.3513 0.0718 0.1234 0.0252
I 20.00 31.00 1.3010 1.4914 0.1974 0.1160 0.0390 0.0229
APR II 16.00 38.00 1.2041 1.5798 0.1005 0.2045 0.0101 0.0206
III 25.02 63.00 1.3983 1.7993 0.2947 0.4240 0.0868 0.1250
I 30.02 88.00 1.4774 1.9445 0.3738 0.5692 0.1397 0.2128
MAY II 25.58 77.00 1.4079 1.8865 0.3043 0.5112 0.0926 0.1556
III 24.78 76.00 1.3941 1.8808 0.2905 0.5055 0.0844 0.1469
I 20.72 48.00 1.3164 1.6812 0.2128 0.3059 0.0453 0.0651
1979-80 OCT II 17.94 39.00 1.2538 1.5911 0.1502 0.2157 0.0226 0.0324
III 14.83 34.00 1.1711 1.5315 0.0676 0.1562 0.0046 0.0105
I 13.23 31.00 1.1216 1.4914 0.0180 0.1160 0.0003 0.0021
NOV II 10.74 27.00 1.0310 1.4314 -0.0726 0.0560 0.0053 -0.0041
III 10.24 26.00 1.0103 1.4150 -0.0933 0.0396 0.0087 -0.0037
I 9.74 25.00 0.9886 1.3979 -0.1150 0.0226 0.0132 -0.0026
DEC II 8.93 23.00 0.9509 1.3617 -0.1527 -0.0136 0.0233 0.0021
III 8.86 23.00 0.9474 1.3617 -0.1562 -0.0136 0.0244 0.0021
I 7.68 20.00 0.8854 1.3010 -0.2182 -0.0743 0.0476 0.0162
JAN II 7.76 19.00 0.8899 1.2788 -0.2137 -0.0966 0.0457 0.0206
III 6.08 18.00 0.7839 1.2553 -0.3197 -0.1201 0.1022 0.0384
I 6.54 23.00 0.8156 1.3617 -0.2880 -0.0136 0.0829 0.0039
FEB II 6.83 20.00 0.8344 1.3010 -0.2692 -0.0743 0.0725 0.0200
III 6.79 22.00 0.8319 1.3424 -0.2717 -0.0329 0.0738 0.0089
I 5.5 20.00 0.7404 1.3010 -0.3632 -0.0743 0.1319 0.0270
MAR II 5.55 22.00 0.7443 1.3424 -0.3593 -0.0329 0.1291 0.0118
III 6.63 24.00 0.8215 1.3802 -0.2821 0.0049 0.0796 -0.0014
I 7.9 26.00 0.8976 1.4150 -0.2060 0.0396 0.0424 -0.0082
APR II 9.03 29.00 0.9557 1.4624 -0.1479 0.0871 0.0219 -0.0129
III 10.98 32.00 1.0406 1.5051 -0.0630 0.1298 0.0040 -0.0082
I 25.76 66.00 1.4109 1.8195 0.3074 0.4442 0.0945 0.1365
MAY II 33.09 90.00 1.5197 1.9542 0.4161 0.5789 0.1731 0.2409
III 55.23 122.00 1.7422 2.0864 0.6386 0.7110 0.4078 0.4541

Table-5.3(5)
TANDI GHOUSAL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
I 30.26 54.00 1.4809 1.7324 0.3773 0.3571 0.1423 0.1347
1980-81 OCT II 21.63 35.00 1.3351 1.5441 0.2315 0.1687 0.0536 0.0391
III 17.26 28.00 1.2370 1.4472 0.1335 0.0718 0.0178 0.0096
I 12.35 21.00 1.0917 1.3222 -0.0119 -0.0531 0.0001 0.0006
NOV II 9.02 20.00 0.9552 1.3010 -0.1484 -0.0743 0.0220 0.0110
III 8.62 20.00 0.9355 1.3010 -0.1681 -0.0743 0.0283 0.0125
I 8.16 18.00 0.9117 1.2553 -0.1919 -0.1201 0.0368 0.0230
DEC II 7.82 17.00 0.8932 1.2304 -0.2104 -0.1449 0.0443 0.0305
III 7.64 16.00 0.8831 1.2041 -0.2205 -0.1712 0.0486 0.0378
I 7.71 17.00 0.8871 1.2304 -0.2165 -0.1449 0.0469 0.0314
JAN II 7.35 16.00 0.8663 1.2041 -0.2373 -0.1712 0.0563 0.0406
III 7.36 15.00 0.8669 1.1761 -0.2367 -0.1992 0.0560 0.0472
I 7.46 15.00 0.8727 1.1761 -0.2308 -0.1992 0.0533 0.0460
FEB II 7.07 16.00 0.8494 1.2041 -0.2542 -0.1712 0.0646 0.0435
III 6.76 18.00 0.8299 1.2553 -0.2736 -0.1201 0.0749 0.0329
I 6.76 17.00 0.8299 1.2304 -0.2736 -0.1449 0.0749 0.0396
MAR II 6.60 17.00 0.8195 1.2304 -0.2840 -0.1449 0.0807 0.0412
III 6.80 18.00 0.8325 1.2553 -0.2711 -0.1201 0.0735 0.0325
I 7.44 19.00 0.8716 1.2788 -0.2320 -0.0966 0.0538 0.0224
APR II 9.34 26.00 0.9703 1.4150 -0.1332 0.0396 0.0178 -0.0053
III 33.52 37.00 1.5253 1.5682 0.4217 0.1929 0.1778 0.0813
I 70.93 131.00 1.8508 2.1173 0.7472 0.7419 0.5584 0.5544
MAY II 77.63 166.00 1.8900 2.2201 0.7864 0.8448 0.6185 0.6644
III 92.76 195.00 1.9674 2.2900 0.8638 0.9147 0.7461 0.7901
I 15.05 47.00 1.1775 1.6721 0.0739 0.2968 0.0055 0.0219
1981-82 OCT II 12.80 39.00 1.1072 1.5911 0.0036 0.2157 0.0000 0.0008
III 12.24 25.00 1.0878 1.3979 -0.0158 0.0226 0.0002 -0.0004
I 10.72 23.00 1.0302 1.3617 -0.0734 -0.0136 0.0054 0.0010
NOV II 8.67 20.00 0.9380 1.3010 -0.1656 -0.0743 0.0274 0.0123
III 7.31 18.00 0.8639 1.2553 -0.2397 -0.1201 0.0574 0.0288
I 6.42 17.00 0.8075 1.2304 -0.2961 -0.1449 0.0876 0.0429
DEC II 5.94 15.00 0.7738 1.1761 -0.3298 -0.1992 0.1088 0.0657
III 5.72 14.00 0.7574 1.1461 -0.3462 -0.2292 0.1198 0.0793
I 8.34 14.00 0.9212 1.1461 -0.1824 -0.2292 0.0333 0.0418
JAN II 8.20 14.00 0.9138 1.1461 -0.1898 -0.2292 0.0360 0.0435
III 9.41 12.00 0.9736 1.0792 -0.1300 -0.2961 0.0169 0.0385
I 9.32 13.00 0.9694 1.1139 -0.1342 -0.2614 0.0180 0.0351
FEB II 8.70 14.00 0.9395 1.1461 -0.1641 -0.2292 0.0269 0.0376
III 8.76 13.00 0.9425 1.1139 -0.1611 -0.2614 0.0259 0.0421
I 8.37 15.00 0.9227 1.1761 -0.1809 -0.1992 0.0327 0.0360
MAR II 7.92 15.00 0.8987 1.1761 -0.2049 -0.1992 0.0420 0.0408
III 8.09 14.00 0.9079 1.1461 -0.1956 -0.2292 0.0383 0.0448
I 8.50 16.00 0.9294 1.2041 -0.1742 -0.1712 0.0303 0.0298
APR II 9.13 17.00 0.9605 1.2304 -0.1431 -0.1449 0.0205 0.0207
III 11.40 25.00 1.0569 1.3979 -0.0467 0.0226 0.0022 -0.0011
I 21.96 49.00 1.3416 1.6902 0.2380 0.3149 0.0567 0.0750
MAY II 20.11 44.00 1.3034 1.6435 0.1998 0.2681 0.0399 0.0536
III 30.79 76.00 1.4884 1.8808 0.3848 0.5055 0.1481 0.1945
I 20.84 80.00 1.3189 1.9031 0.2153 0.5278 0.0464 0.1136
1982-83 OCT II 18.58 70.00 1.2690 1.8451 0.1655 0.4698 0.0274 0.0777
III 16.79 39.00 1.2251 1.5911 0.1215 0.2157 0.0148 0.0262
I 15.31 26.00 1.1850 1.4150 0.0814 0.0396 0.0066 0.0032
NOV II 13.77 25.00 1.1389 1.3979 0.0353 0.0226 0.0012 0.0008
III 12.27 22.00 1.0888 1.3424 -0.0147 -0.0329 0.0002 0.0005
I 11.40 18.00 1.0569 1.2553 -0.0467 -0.1201 0.0022 0.0056
DEC II 10.54 15.00 1.0228 1.1761 -0.0807 -0.1992 0.0065 0.0161
III 12.22 14.00 1.0871 1.1461 -0.0165 -0.2292 0.0003 0.0038
I 7.36 15.00 0.8667 1.1761 -0.2369 -0.1992 0.0561 0.0472
JAN II 7.40 15.00 0.8692 1.1761 -0.2344 -0.1992 0.0549 0.0467
III 7.62 15.00 0.8820 1.1761 -0.2216 -0.1992 0.0491 0.0442
I 7.39 14.00 0.8686 1.1461 -0.2349 -0.2292 0.0552 0.0538
FEB II 7.20 14.00 0.8573 1.1461 -0.2463 -0.2292 0.0606 0.0564
III 7.45 14.00 0.8722 1.1461 -0.2314 -0.2292 0.0536 0.0530
I 11.99 18.00 1.0788 1.2553 -0.0248 -0.1201 0.0006 0.0030
MAR II 12.42 20.00 1.0941 1.3010 -0.0095 -0.0743 0.0001 0.0007
III 11.44 18.00 1.0584 1.2553 -0.0452 -0.1201 0.0020 0.0054
I 11.41 18.00 1.0573 1.2553 -0.0463 -0.1201 0.0021 0.0056
APR II 10.28 18.00 1.0120 1.2553 -0.0916 -0.1201 0.0084 0.0110
III 12.42 21.00 1.0941 1.3222 -0.0095 -0.0531 0.0001 0.0005
I 20.45 37.00 1.3107 1.5682 0.2071 0.1929 0.0429 0.0399
MAY II 35.11 56.00 1.5454 1.7482 0.4418 0.3729 0.1952 0.1647
III 56.24 83.00 1.7500 1.9191 0.6465 0.5438 0.4179 0.3515

Table-5.3(6)
TANDI GHOUSAL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
1983-84 I 45.51 76.00 1.6581 1.8808 0.5545 0.5055 0.3075 0.2803
OCT II 27.07 51.00 1.4325 1.7076 0.3289 0.3322 0.1082 0.1093
III 17.04 33.00 1.2315 1.5185 0.1279 0.1432 0.0164 0.0183
I 12.42 27.00 1.0941 1.4314 -0.0095 0.0560 0.0001 -0.0005
NOV II 11.67 25.00 1.0671 1.3979 -0.0365 0.0226 0.0013 -0.0008
III 11.10 23.00 1.0453 1.3617 -0.0583 -0.0136 0.0034 0.0008
I 10.40 20.00 1.0168 1.3010 -0.0868 -0.0743 0.0075 0.0064
DEC II 9.55 19.00 0.9801 1.2788 -0.1234 -0.0966 0.0152 0.0119
III 3.42 18.00 0.5340 1.2553 -0.5696 -0.1201 0.3244 0.0684
I 11.03 19.00 1.0426 1.2788 -0.0610 -0.0966 0.0037 0.0059
JAN II 10.59 19.00 1.0249 1.2788 -0.0787 -0.0966 0.0062 0.0076
III 10.06 18.00 1.0026 1.2553 -0.1010 -0.1201 0.0102 0.0121
I 9.62 17.00 0.9829 1.2304 -0.1206 -0.1449 0.0146 0.0175
FEB II 9.07 17.00 0.9576 1.2304 -0.1460 -0.1449 0.0213 0.0211
III 8.73 16.00 0.9410 1.2041 -0.1626 -0.1712 0.0264 0.0278
I 9.65 16.00 0.9845 1.2041 -0.1191 -0.1712 0.0142 0.0204
MAR II 11.19 18.00 1.0488 1.2553 -0.0548 -0.1201 0.0030 0.0066
III 11.48 19.00 1.0599 1.2788 -0.0436 -0.0966 0.0019 0.0042
I 11.91 20.00 1.0759 1.3010 -0.0277 -0.0743 0.0008 0.0021
APR II 10.85 20.00 1.0354 1.3010 -0.0682 -0.0743 0.0046 0.0051
III 15.00 26.00 1.1761 1.4150 0.0725 0.0396 0.0053 0.0029
I 28.03 45.00 1.4476 1.6532 0.3440 0.2779 0.1184 0.0956
MAY II 33.90 74.00 1.5302 1.8692 0.4266 0.4939 0.1820 0.2107
III 72.58 125.00 1.8608 2.0969 0.7572 0.7216 0.5734 0.5464
G.TOTAL 264.86 330.08 0.00 0.00 15.65 14.99
NO. OF PERIOD 240 LOG x' LOG y'
AVERAGE
Co-efficient of Corelation
1.1036 1.3753
b = SIGMA X*Y = 0.9580
SIGMA X^2

REGRESSION ANALYSIS BETWEEN DISCHARGES OF TANDI PLUS GHOUSAL AND UDAIPUR JUNE- JULY
UDAIPUR TDI.+GSL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
I 195.00 152.28 2.2900 2.1826 -0.4193 -0.3874 0.1758 0.1625
1974 JUN II 318.00 248.59 2.5024 2.3955 -0.2069 -0.1746 0.0428 0.0361
III 203.00 167.44 2.3075 2.2239 -0.4018 -0.3462 0.1615 0.1391
I 299.00 246.61 2.4757 2.3920 -0.2337 -0.1781 0.0546 0.0416
JUL II 636.00 452.53 2.8035 2.6556 0.0941 0.0856 0.0089 0.0081
III 504.00 374.12 2.7024 2.5730 -0.0069 0.0029 0.0000 0.0000
I 361.00 282.44 2.5575 2.4509 -0.1518 -0.1192 0.0231 0.0181
1975 JUN II 558.00 398.51 2.7466 2.6004 0.0373 0.0304 0.0014 0.0011
III 651.00 468.02 2.8136 2.6703 0.1042 0.1002 0.0109 0.0104
I 513.00 360.00 2.7101 2.5563 0.0008 -0.0138 0.0000 0.0000
JUL II 887.00 613.91 2.9479 2.7881 0.2386 0.2180 0.0569 0.0520
III 618.00 429.52 2.7910 2.6330 0.0816 0.0629 0.0067 0.0051
I 477.00 317.18 2.6785 2.5013 -0.0308 -0.0688 0.0010 0.0021
1976 JUN II 351.00 247.79 2.5453 2.3941 -0.1640 -0.1760 0.0269 0.0289
III 287.00 202.81 2.4579 2.3071 -0.2515 -0.2630 0.0632 0.0661
I 574.00 415.59 2.7589 2.6187 0.0496 0.0486 0.0025 0.0024
JUL II 721.00 560.80 2.8579 2.7488 0.1486 0.1787 0.0221 0.0266
III 755.00 580.87 2.8779 2.7641 0.1686 0.1940 0.0284 0.0327
I 258.00 196.59 2.4116 2.2936 -0.2977 -0.2765 0.0886 0.0823
1977 JUN II 184.00 141.04 2.2648 2.1493 -0.4445 -0.4207 0.1976 0.1870
III 633.00 436.71 2.8014 2.6402 0.0921 0.0701 0.0085 0.0065
I 828.00 579.09 2.9180 2.7627 0.2087 0.1927 0.0435 0.0402
JUL II 754.00 532.87 2.8774 2.7266 0.1680 0.1565 0.0282 0.0263
III 601.00 450.26 2.7789 2.6535 0.0695 0.0834 0.0048 0.0058
I 456.00 353.06 2.6590 2.5478 -0.0504 -0.0222 0.0025 0.0011
1978 JUN II 424.00 312.95 2.6274 2.4955 -0.0820 -0.0746 0.0067 0.0061
III 845.00 640.03 2.9269 2.8062 0.2175 0.2361 0.0473 0.0514
I 904.00 647.43 2.9562 2.8112 0.2468 0.2411 0.0609 0.0595
JUL II 700.00 540.15 2.8451 2.7325 0.1358 0.1624 0.0184 0.0221
III 700.00 536.99 2.8451 2.7300 0.1358 0.1599 0.0184 0.0217
I 197.00 141.70 2.2945 2.1514 -0.4149 -0.4187 0.1721 0.1737
1979 JUN II 401.00 295.39 2.6031 2.4704 -0.1062 -0.0997 0.0113 0.0106
III 806.00 597.47 2.9063 2.7763 0.1970 0.2062 0.0388 0.0406
I 736.00 541.98 2.8669 2.7340 0.1575 0.1639 0.0248 0.0258
JUL II 927.00 660.97 2.9671 2.8202 0.2577 0.2501 0.0664 0.0645
III 698.00 519.08 2.8439 2.7152 0.1345 0.1451 0.0181 0.0195
I 395.00 301.89 2.5966 2.4798 -0.1127 -0.0902 0.0127 0.0102
1980 JUN II 481.00 356.45 2.6821 2.5520 -0.0272 -0.0181 0.0007 0.0005
III 696.00 507.78 2.8426 2.7057 0.1333 0.1356 0.0178 0.0181
I 731.00 536.27 2.8639 2.7294 0.1546 0.1593 0.0239 0.0246
JUL II 762.00 524.29 2.8820 2.7196 0.1726 0.1495 0.0298 0.0258
III 635.00 474.10 2.8028 2.6759 0.0934 0.1058 0.0087 0.0099
I 292.00 221.07 2.4654 2.3445 -0.2440 -0.2256 0.0595 0.0550
1981 JUN II 311.00 229.57 2.4928 2.3609 -0.2166 -0.2092 0.0469 0.0453
III 738.00 501.01 2.8681 2.6998 0.1587 0.1298 0.0252 0.0206
I 582.00 418.26 2.7649 2.6214 0.0556 0.0514 0.0031 0.0029
JUL II 779.00 526.95 2.8915 2.7218 0.1822 0.1517 0.0332 0.0276
III 818.00 572.92 2.9128 2.7581 0.2034 0.1880 0.0414 0.0382
I 320.00 182.53 2.5051 2.2613 -0.2042 -0.3088 0.0417 0.0630
1982 JUN II 537.00 332.83 2.7300 2.5222 0.0206 -0.0479 0.0004 -0.0010
III 519.00 328.64 2.7152 2.5167 0.0058 -0.0534 0.0000 -0.0003
I 582.00 439.48 2.7649 2.6429 0.0556 0.0729 0.0031 0.0040
JUL II 705.00 464.71 2.8482 2.6672 0.1388 0.0971 0.0193 0.0135
III 903.00 539.55 2.9557 2.7320 0.2463 0.1619 0.0607 0.0399
I 264.00 204.20 2.4216 2.3101 -0.2877 -0.2600 0.0828 0.0748
1983 JUN II 310.00 231.29 2.4914 2.3642 -0.2180 -0.2059 0.0475 0.0449
III 555.00 327.14 2.7443 2.5147 0.0349 -0.0554 0.0012 -0.0019
I 497.00 402.41 2.6964 2.6047 -0.0130 0.0346 0.0002 -0.0004
JUL II 350.00 313.79 2.5441 2.4966 -0.1653 -0.0734 0.0273 0.0121
III 725.00 538.52 2.8603 2.7312 0.1510 0.1611 0.0228 0.0243
G.TOTAL 162.56 154.21 0.00 0.00 2.15 2.03
NO. OF PERIOD 60 LOG x' LOG y'
AVERAGE 2.7093 2.5701
Co-efficient of Corelation
b = SIGMA X*Y = 0.9422
SIGMA X^2
Table-5.4(1)

REGRESSION ANALYSIS BETWEEN DISCHARGES OF TANDI PLUS GHOUSAL AND UDAIPUR AUG.- SEPT
UDAIPUR TDI.+GSL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
I 524.00 402.96 2.7193 2.6053 0.1394 0.1697 0.0194 0.0237
1974 AUG II 430.00 330.22 2.6335 2.5188 0.0535 0.0832 0.0029 0.0045
III 417.00 311.99 2.6201 2.4941 0.0402 0.0586 0.0016 0.0024
I 293.00 211.23 2.4669 2.3248 -0.1131 -0.1108 0.0128 0.0125
SEPT II 205.00 160.48 2.3118 2.2054 -0.2682 -0.2302 0.0719 0.0617
III 144.00 107.41 2.1584 2.0310 -0.4216 -0.4045 0.1777 0.1705
I 731.00 511.62 2.8639 2.7089 0.2840 0.2734 0.0806 0.0776
1975 AUG II 856.00 575.79 2.9325 2.7603 0.3525 0.3247 0.1243 0.1145
III 535.00 370.86 2.7284 2.5692 0.1484 0.1336 0.0220 0.0198
I 718.00 284.37 2.8561 2.4539 0.2762 0.0183 0.0763 0.0051
SEPT II 288.00 200.70 2.4594 2.3025 -0.1205 -0.1330 0.0145 0.0160
III 177.00 124.74 2.2480 2.0960 -0.3320 -0.3396 0.1102 0.1127
I 569.00 408.32 2.7551 2.6110 0.1752 0.1754 0.0307 0.0307
1976 AUG II 518.00 360.47 2.7143 2.5569 0.1344 0.1213 0.0181 0.0163
III 381.00 282.12 2.5809 2.4504 0.0010 0.0148 0.0000 0.0000
I 326.00 240.73 2.5132 2.3815 -0.0667 -0.0541 0.0045 0.0036
SEPT II 178.00 138.96 2.2504 2.1429 -0.3295 -0.2927 0.1086 0.0964
III 159.00 113.35 2.2014 2.0544 -0.3785 -0.3812 0.1433 0.1443
I 724.00 530.88 2.8597 2.7250 0.2798 0.2894 0.0783 0.0810
1977 AUG II 501.00 368.00 2.6998 2.5658 0.1199 0.1303 0.0144 0.0156
III 468.00 330.56 2.6702 2.5193 0.0903 0.0837 0.0082 0.0076
I 396.00 281.03 2.5977 2.4488 0.0178 0.0132 0.0003 0.0002
SEPT II 226.00 170.94 2.3541 2.2328 -0.2258 -0.2027 0.0510 0.0458
III 151.00 114.63 2.1790 2.0593 -0.4010 -0.3763 0.1608 0.1509
I 725.00 550.35 2.8603 2.7406 0.2804 0.3050 0.0786 0.0855
1978 AUG II 619.00 435.17 2.7917 2.6387 0.2118 0.2031 0.0448 0.0430
III 528.00 378.00 2.7226 2.5775 0.1427 0.1419 0.0204 0.0202
I 253.00 186.00 2.4031 2.2695 -0.1768 -0.1661 0.0313 0.0294
SEPT II 221.00 142.98 2.3444 2.1553 -0.2355 -0.2803 0.0555 0.0660
III 164.00 136.28 2.2148 2.1344 -0.3651 -0.3012 0.1333 0.1100
I 817.00 574.89 2.9122 2.7596 0.3323 0.3240 0.1104 0.1077
1979 AUG II 666.00 478.29 2.8235 2.6797 0.2435 0.2441 0.0593 0.0594
III 437.00 335.16 2.6405 2.5253 0.0605 0.0897 0.0037 0.0054
I 423.00 311.36 2.6263 2.4933 0.0464 0.0577 0.0022 0.0027
SEPT II 216.00 164.16 2.3345 2.2153 -0.2455 -0.2203 0.0603 0.0541
III 130.00 74.60 2.1139 1.8727 -0.4660 -0.5629 0.2172 0.2623
I 750.00 515.94 2.8751 2.7126 0.2951 0.2770 0.0871 0.0818
1980 AUG II 423.00 318.18 2.6263 2.5027 0.0464 0.0671 0.0022 0.0031
III 473.00 356.30 2.6749 2.5518 0.0949 0.1162 0.0090 0.0110
I 301.00 225.52 2.4786 2.3532 -0.1014 -0.0824 0.0103 0.0084
SEPT II 213.00 144.10 2.3284 2.1587 -0.2516 -0.2769 0.0633 0.0697
III 165.00 99.36 2.2175 1.9972 -0.3625 -0.4384 0.1314 0.1589
I 694.00 487.37 2.8414 2.6879 0.2614 0.2523 0.0683 0.0659
1981 AUG II 628.00 441.32 2.7980 2.6448 0.2180 0.2092 0.0475 0.0456
III 467.00 303.76 2.6693 2.4825 0.0894 0.0469 0.0080 0.0042
I 370.00 250.66 2.5682 2.3991 -0.0117 -0.0365 0.0001 0.0004
SEPT II 221.00 141.39 2.3444 2.1504 -0.2355 -0.2852 0.0555 0.0672
III 211.00 125.77 2.3243 2.0996 -0.2557 -0.3360 0.0654 0.0859
I 861.00 578.82 2.9350 2.7625 0.3551 0.3270 0.1261 0.1161
1982 AUG II 664.00 486.72 2.8222 2.6873 0.2422 0.2517 0.0587 0.0610
III 425.00 344.35 2.6284 2.5370 0.0485 0.1014 0.0023 0.0049
I 338.00 251.49 2.5289 2.4005 -0.0510 -0.0351 0.0026 0.0018
SEPT II 339.00 219.20 2.5302 2.3408 -0.0497 -0.0947 0.0025 0.0047
III 136.00 152.19 2.1335 2.1824 -0.4464 -0.2532 0.1993 0.1130
I 903.00 643.85 2.9557 2.8088 0.3757 0.3732 0.1412 0.1402
1983 AUG II 686.00 546.24 2.8363 2.7374 0.2564 0.3018 0.0657 0.0774
III 697.00 539.17 2.8432 2.7317 0.2633 0.2961 0.0693 0.0780
I 597.00 437.26 2.7760 2.6407 0.1960 0.2052 0.0384 0.0402
SEPT II 406.00 299.29 2.6085 2.4761 0.0286 0.0405 0.0008 0.0012
III 195.00 161.98 2.2900 2.2095 -0.2899 -0.2261 0.0840 0.0656
G.TOTAL 154.80 146.14 0.00 0.00 3.49 3.37
NO. OF PERIOD 60 LOG x' LOG y'
AVERAGE 2.5799 2.4356
Co-efficient of Corelation
b = SIGMA X*Y = 0.9648
SIGMA X^2
Table-5.4(2)

REGRESSION ANALYSIS BETWEEN DISCHARGES OF TANDI PLUS GHOUSAL AND UDAIPUR ( N-MON )
UDAIPUR TDI.+GSL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
I 82.00 59.62 1.9138 1.7754 0.1598 0.2095 0.0256 0.0335
1974-75 OCT II 67.00 48.58 1.8261 1.6865 0.0721 0.1206 0.0052 0.0087
III 55.00 39.31 1.7404 1.5945 -0.0136 0.0287 0.0002 -0.0004
I 46.00 32.92 1.6628 1.5175 -0.0912 -0.0484 0.0083 0.0044
NOV II 40.00 35.83 1.6021 1.5542 -0.1519 -0.0116 0.0231 0.0018
III 36.00 27.45 1.5563 1.4385 -0.1977 -0.1273 0.0391 0.0252
I 36.00 25.69 1.5563 1.4098 -0.1977 -0.1561 0.0391 0.0309
DEC II 35.00 23.43 1.5441 1.3698 -0.2099 -0.1961 0.0441 0.0412
III 35.00 24.42 1.5441 1.3877 -0.2099 -0.1781 0.0441 0.0374
I 32.00 22.38 1.5051 1.3499 -0.2488 -0.2160 0.0619 0.0537
JAN II 31.00 22.07 1.4914 1.3438 -0.2626 -0.2220 0.0690 0.0583
III 26.00 19.60 1.4150 1.2923 -0.3390 -0.2736 0.1149 0.0927
I 27.00 22.19 1.4314 1.3462 -0.3226 -0.2197 0.1041 0.0709
FEB II 31.00 21.59 1.4914 1.3343 -0.2626 -0.2316 0.0690 0.0608
III 32.00 23.12 1.5051 1.3640 -0.2488 -0.2019 0.0619 0.0502
I 30.00 18.30 1.4771 1.2625 -0.2768 -0.3034 0.0766 0.0840
MAR II 31.00 18.43 1.4914 1.2655 -0.2626 -0.3003 0.0690 0.0789
III 31.00 23.26 1.4914 1.3666 -0.2626 -0.1992 0.0690 0.0523
I 38.00 26.42 1.5798 1.4219 -0.1742 -0.1439 0.0303 0.0251
APR II 54.00 35.38 1.7324 1.5488 -0.0216 -0.0171 0.0005 0.0004
III 71.00 48.70 1.8513 1.6875 0.0973 0.1217 0.0095 0.0118
I 108.00 74.16 2.0334 1.8702 0.2795 0.3043 0.0781 0.0850
MAY II 228.00 158.15 2.3579 2.1991 0.6040 0.6332 0.3648 0.3824
III 277.00 205.11 2.4425 2.3120 0.6885 0.7461 0.4740 0.5137
I 148.00 97.47 2.1703 1.9889 0.4163 0.4230 0.1733 0.1761
1975-76 OCT II 121.00 81.99 2.0828 1.9138 0.3288 0.3479 0.1081 0.1144
III 79.00 54.50 1.8976 1.7364 0.1437 0.1706 0.0206 0.0245
I 58.00 39.53 1.7634 1.5969 0.0095 0.0311 0.0001 0.0003
NOV II 49.00 34.42 1.6902 1.5368 -0.0638 -0.0290 0.0041 0.0019
III 42.00 31.23 1.6232 1.4946 -0.1307 -0.0713 0.0171 0.0093
I 39.00 29.32 1.5911 1.4672 -0.1629 -0.0987 0.0265 0.0161
DEC II 33.00 26.02 1.5185 1.4153 -0.2355 -0.1505 0.0554 0.0354
III 32.00 24.75 1.5051 1.3936 -0.2488 -0.1723 0.0619 0.0429
I 33.00 24.16 1.5185 1.3831 -0.2355 -0.1827 0.0554 0.0430
JAN II 33.00 23.46 1.5185 1.3703 -0.2355 -0.1955 0.0554 0.0460
III 32.00 21.84 1.5051 1.3393 -0.2488 -0.2266 0.0619 0.0564
I 31.00 22.41 1.4914 1.3504 -0.2626 -0.2154 0.0690 0.0566
FEB II 25.00 18.21 1.3979 1.2603 -0.3560 -0.3055 0.1268 0.1088
III 28.00 20.03 1.4472 1.3017 -0.3068 -0.2642 0.0941 0.0810
I 31.00 22.49 1.4914 1.3520 -0.2626 -0.2139 0.0690 0.0562
MAR II 29.00 21.10 1.4624 1.3243 -0.2916 -0.2416 0.0850 0.0704
III 28.00 20.13 1.4472 1.3038 -0.3068 -0.2620 0.0941 0.0804
I 34.00 20.08 1.5315 1.3028 -0.2225 -0.2631 0.0495 0.0585
APR II 42.00 26.91 1.6232 1.4299 -0.1307 -0.1359 0.0171 0.0178
III 101.00 60.08 2.0043 1.7787 0.2504 0.2129 0.0627 0.0533
I 131.00 83.13 2.1173 1.9198 0.3633 0.3539 0.1320 0.1286
MAY II 189.00 127.74 2.2765 2.1063 0.5225 0.5405 0.2730 0.2824
III 276.00 184.72 2.4409 2.2665 0.6869 0.7007 0.4719 0.4813
I 118.00 80.29 2.0719 1.9047 0.3179 0.3388 0.1011 0.1077
1976-77 OCT II 70.00 51.19 1.8451 1.7092 0.0911 0.1433 0.0083 0.0131
III 56.00 39.71 1.7482 1.5989 -0.0058 0.0331 0.0000 -0.0002
I 52.00 35.45 1.7160 1.5496 -0.0380 -0.0162 0.0014 0.0006
NOV II 44.00 32.17 1.6435 1.5075 -0.1105 -0.0584 0.0122 0.0065
III 37.00 28.95 1.5682 1.4616 -0.1858 -0.1042 0.0345 0.0194
I 34.00 26.40 1.5315 1.4216 -0.2225 -0.1442 0.0495 0.0321
DEC II 31.00 23.24 1.4914 1.3662 -0.2626 -0.1996 0.0690 0.0524
III 31.00 21.93 1.4914 1.3410 -0.2626 -0.2248 0.0690 0.0590
I 30.00 20.07 1.4771 1.3025 -0.2768 -0.2633 0.0766 0.0729
JAN II 29.00 18.97 1.4624 1.2781 -0.2916 -0.2878 0.0850 0.0839
III 155.00 16.18 2.1903 1.2090 0.4364 -0.3569 0.1904 -0.1557
I 33.00 22.47 1.5185 1.3516 -0.2355 -0.2142 0.0554 0.0504
FEB II 27.00 19.22 1.4314 1.2838 -0.3226 -0.2821 0.1041 0.0910
III 26.00 19.26 1.4150 1.2847 -0.3390 -0.2812 0.1149 0.0953
I 28.00 19.12 1.4472 1.2815 -0.3068 -0.2844 0.0941 0.0872
MAR II 29.00 19.33 1.4624 1.2862 -0.2916 -0.2796 0.0850 0.0815
III 37.00 26.05 1.5682 1.4158 -0.1858 -0.1500 0.0345 0.0279
I 40.00 29.91 1.6021 1.4758 -0.1519 -0.0900 0.0231 0.0137
APR II 39.00 28.31 1.5911 1.4519 -0.1629 -0.1139 0.0265 0.0186
III 47.00 34.28 1.6721 1.5350 -0.0819 -0.0308 0.0067 0.0025
I 50.00 35.33 1.6990 1.5481 -0.0550 -0.0177 0.0030 0.0010
MAY II 75.00 51.18 1.8751 1.7091 0.1211 0.1433 0.0147 0.0173
III 168.00 124.42 2.2253 2.0949 0.4713 0.5290 0.2222 0.2494
Table-5.4(3)

UDAIPUR TDI.+GSL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
I 109.00 80.11 2.0374 1.9037 0.2835 0.3378 0.0803 0.0958
1977-78 OCT II 80.00 57.55 1.9031 1.7600 0.1491 0.1942 0.0222 0.0290
III 69.00 47.45 1.8388 1.6762 0.0849 0.1104 0.0072 0.0094
I 57.00 41.74 1.7559 1.6206 0.0019 0.0547 0.0000 0.0001
NOV II 49.00 36.30 1.6902 1.5599 -0.0638 -0.0059 0.0041 0.0004
III 44.00 34.85 1.6435 1.5422 -0.1105 -0.0236 0.0122 0.0026
I 38.00 32.17 1.5798 1.5075 -0.1742 -0.0584 0.0303 0.0102
DEC II 35.00 27.86 1.5441 1.4450 -0.2099 -0.1209 0.0441 0.0254
III 33.00 25.35 1.5185 1.4040 -0.2355 -0.1619 0.0554 0.0381
I 32.00 22.94 1.5051 1.3606 -0.2488 -0.2053 0.0619 0.0511
JAN II 33.00 26.57 1.5185 1.4244 -0.2355 -0.1415 0.0554 0.0333
III 32.00 24.35 1.5051 1.3865 -0.2488 -0.1793 0.0619 0.0446
I 32.00 22.16 1.5051 1.3456 -0.2488 -0.2203 0.0619 0.0548
FEB II 27.00 22.57 1.4314 1.3535 -0.3226 -0.2123 0.1041 0.0685
III 32.00 27.02 1.5051 1.4317 -0.2488 -0.1342 0.0619 0.0334
I 31.00 20.60 1.4914 1.3139 -0.2626 -0.2520 0.0690 0.0662
MAR II 31.00 20.10 1.4914 1.3032 -0.2626 -0.2626 0.0690 0.0690
III 36.00 23.41 1.5563 1.3694 -0.1977 -0.1964 0.0391 0.0388
I 38.00 25.10 1.5798 1.3997 -0.1742 -0.1662 0.0303 0.0289
APR II 66.00 40.41 1.8195 1.6065 0.0656 0.0406 0.0043 0.0027
III 82.00 52.48 1.9138 1.7200 0.1598 0.1541 0.0256 0.0246
I 197.00 146.66 2.2945 2.1663 0.5405 0.6005 0.2921 0.3246
MAY II 290.00 229.87 2.4624 2.3615 0.7084 0.7956 0.5019 0.5637
III 336.00 267.93 2.5263 2.4280 0.7724 0.8622 0.5966 0.6659
I 121.00 80.94 2.0828 1.9082 0.3288 0.3423 0.1081 0.1126
1978-79 OCT II 96.00 61.61 1.9823 1.7897 0.2283 0.2238 0.0521 0.0511
III 79.00 59.49 1.8976 1.7744 0.1437 0.2086 0.0206 0.0300
I 59.00 40.26 1.7709 1.6049 0.0169 0.0390 0.0003 0.0007
NOV II 49.00 35.70 1.6902 1.5527 -0.0638 -0.0132 0.0041 0.0008
III 44.00 36.17 1.6435 1.5583 -0.1105 -0.0075 0.0122 0.0008
I 40.00 33.02 1.6021 1.5188 -0.1519 -0.0471 0.0231 0.0071
DEC II 38.00 31.29 1.5798 1.4954 -0.1742 -0.0704 0.0303 0.0123
III 35.00 31.17 1.5441 1.4937 -0.2099 -0.0721 0.0441 0.0151
I 41.00 30.52 1.6128 1.4846 -0.1412 -0.0813 0.0199 0.0115
JAN II 42.00 26.92 1.6232 1.4301 -0.1307 -0.1358 0.0171 0.0177
III 40.00 26.07 1.6021 1.4161 -0.1519 -0.1497 0.0231 0.0227
I 39.00 27.86 1.5911 1.4450 -0.1629 -0.1209 0.0265 0.0197
FEB II 38.00 25.12 1.5798 1.4000 -0.1742 -0.1658 0.0303 0.0289
III 35.00 25.41 1.5441 1.4050 -0.2099 -0.1608 0.0441 0.0338
I 41.00 25.35 1.6128 1.4040 -0.1412 -0.1619 0.0199 0.0229
MAR II 40.00 40.35 1.6021 1.6058 -0.1519 0.0400 0.0231 -0.0061
III 45.00 56.50 1.6532 1.7520 -0.1008 0.1862 0.0102 -0.0188
I 64.00 51.00 1.8062 1.7076 0.0522 0.1417 0.0027 0.0074
APR II 91.00 54.00 1.9590 1.7324 0.2051 0.1665 0.0421 0.0342
III 144.00 88.02 2.1584 1.9446 0.4044 0.3787 0.1635 0.1532
I 179.00 118.02 2.2529 2.0720 0.4989 0.5061 0.2489 0.2525
MAY II 163.00 102.58 2.2122 2.0111 0.4582 0.4452 0.2100 0.2040
III 145.00 100.78 2.1614 2.0034 0.4074 0.4375 0.1660 0.1783
I 127.00 68.72 2.1038 1.8371 0.3498 0.2712 0.1224 0.0949
1979-80 OCT II 108.00 56.94 2.0334 1.7554 0.2795 0.1896 0.0781 0.0530
III 91.00 48.83 1.9590 1.6887 0.2051 0.1228 0.0421 0.0252
I 83.00 44.23 1.9191 1.6457 0.1651 0.0799 0.0273 0.0132
NOV II 70.00 37.74 1.8451 1.5768 0.0911 0.0110 0.0083 0.0010
III 65.00 36.24 1.8129 1.5592 0.0589 -0.0067 0.0035 -0.0004
I 59.00 34.74 1.7709 1.5408 0.0169 -0.0250 0.0003 -0.0004
DEC II 57.00 31.93 1.7559 1.5042 0.0019 -0.0616 0.0000 -0.0001
III 57.00 31.86 1.7559 1.5032 0.0019 -0.0626 0.0000 -0.0001
I 57.00 27.68 1.7559 1.4422 0.0019 -0.1237 0.0000 -0.0002
JAN II 56.00 26.76 1.7482 1.4275 -0.0058 -0.1384 0.0000 0.0008
III 52.00 24.08 1.7160 1.3817 -0.0380 -0.1842 0.0014 0.0070
I 58.00 29.54 1.7634 1.4704 0.0095 -0.0954 0.0001 -0.0009
FEB II 57.00 26.83 1.7559 1.4286 0.0019 -0.1372 0.0000 -0.0003
III 54.00 28.79 1.7324 1.4592 -0.0216 -0.1066 0.0005 0.0023
I 51.00 25.50 1.7076 1.4065 -0.0464 -0.1593 0.0022 0.0074
MAR II 51.00 27.55 1.7076 1.4401 -0.0464 -0.1257 0.0022 0.0058
III 51.00 30.63 1.7076 1.4861 -0.0464 -0.0797 0.0022 0.0037
I 58.00 33.90 1.7634 1.5302 0.0095 -0.0356 0.0001 -0.0003
APR II 71.00 38.03 1.8513 1.5801 0.0973 0.0143 0.0095 0.0014
III 95.00 42.98 1.9777 1.6333 0.2238 0.0674 0.0501 0.0151
I 155.00 91.76 2.1903 1.9627 0.4364 0.3968 0.1904 0.1732
MAY II 182.00 123.09 2.2601 2.0902 0.5061 0.5244 0.2561 0.2654
III 240.00 177.23 2.3802 2.2485 0.6262 0.6827 0.3922 0.4275
Table-5.4(4)

UDAIPUR TDI.+GSL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
I 150.00 84.26 2.1761 1.9256 0.4221 0.3598 0.1782 0.1519
1980-81 OCT II 116.00 56.63 2.0645 1.7530 0.3105 0.1872 0.0964 0.0581
III 95.00 45.26 1.9777 1.6557 0.2238 0.0899 0.0501 0.0201
I 84.00 33.35 1.9243 1.5231 0.1703 -0.0427 0.0290 -0.0073
NOV II 77.00 29.02 1.8865 1.4627 0.1325 -0.1031 0.0176 -0.0137
III 72.00 28.62 1.8573 1.4567 0.1034 -0.1092 0.0107 -0.0113
I 68.00 26.16 1.8325 1.4176 0.0785 -0.1482 0.0062 -0.0116
DEC II 67.00 24.82 1.8261 1.3948 0.0721 -0.1710 0.0052 -0.0123
III 65.00 23.64 1.8129 1.3736 0.0589 -0.1922 0.0035 -0.0113
I 65.00 24.71 1.8129 1.3929 0.0589 -0.1730 0.0035 -0.0102
JAN II 62.00 23.35 1.7924 1.3683 0.0384 -0.1976 0.0015 -0.0076
III 65.00 22.36 1.8129 1.3495 0.0589 -0.2164 0.0035 -0.0128
I 59.00 22.46 1.7709 1.3514 0.0169 -0.2144 0.0003 -0.0036
FEB II 64.00 23.07 1.8062 1.3630 0.0522 -0.2028 0.0027 -0.0106
III 64.00 24.76 1.8062 1.3938 0.0522 -0.1721 0.0027 -0.0090
I 61.00 23.76 1.7853 1.3758 0.0314 -0.1900 0.0010 -0.0060
MAR II 60.00 23.60 1.7782 1.3729 0.0242 -0.1929 0.0006 -0.0047
III 65.00 24.80 1.8129 1.3945 0.0589 -0.1714 0.0035 -0.0101
I 70.00 26.44 1.8451 1.4223 0.0911 -0.1436 0.0083 -0.0131
APR II 100.00 35.34 2.0000 1.5483 0.2460 -0.0176 0.0605 -0.0043
III 149.00 70.52 2.1732 1.8483 0.4192 0.2825 0.1757 0.1184
I 304.00 201.93 2.4829 2.3052 0.7289 0.7394 0.5313 0.5389
MAY II 321.00 243.63 2.5065 2.3867 0.7525 0.8209 0.5663 0.6177
III 405.00 287.76 2.6075 2.4590 0.8535 0.8932 0.7284 0.7623
I 125.00 62.05 2.0969 1.7927 0.3429 0.2269 0.1176 0.0778
1981-82 OCT II 108.00 51.80 2.0334 1.7143 0.2795 0.1485 0.0781 0.0415
III 92.00 37.24 1.9638 1.5710 0.2098 0.0052 0.0440 0.0011
I 76.00 33.72 1.8808 1.5279 0.1268 -0.0380 0.0161 -0.0048
NOV II 57.00 28.67 1.7559 1.4574 0.0019 -0.1084 0.0000 -0.0002
III 53.00 25.31 1.7243 1.4033 -0.0297 -0.1626 0.0009 0.0048
I 49.00 23.42 1.6902 1.3696 -0.0638 -0.1963 0.0041 0.0125
DEC II 45.00 20.94 1.6532 1.3210 -0.1008 -0.2449 0.0102 0.0247
III 44.00 19.72 1.6435 1.2949 -0.1105 -0.2709 0.0122 0.0299
I 36.00 22.34 1.5563 1.3491 -0.1977 -0.2168 0.0391 0.0428
JAN II 35.00 22.20 1.5441 1.3464 -0.2099 -0.2195 0.0441 0.0461
III 33.00 21.41 1.5185 1.3306 -0.2355 -0.2352 0.0554 0.0554
I 36.00 22.32 1.5563 1.3487 -0.1977 -0.2171 0.0391 0.0429
FEB II 35.00 22.70 1.5441 1.3560 -0.2099 -0.2098 0.0441 0.0440
III 37.00 21.76 1.5682 1.3377 -0.1858 -0.2282 0.0345 0.0424
I 37.00 23.37 1.5682 1.3687 -0.1858 -0.1972 0.0345 0.0366
MAR II 37.00 22.92 1.5682 1.3602 -0.1858 -0.2056 0.0345 0.0382
III 38.00 22.09 1.5798 1.3442 -0.1742 -0.2216 0.0303 0.0386
I 45.00 24.50 1.6532 1.3892 -0.1008 -0.1767 0.0102 0.0178
APR II 56.00 26.13 1.7482 1.4171 -0.0058 -0.1487 0.0000 0.0009
III 80.00 36.40 1.9031 1.5611 0.1491 -0.0047 0.0222 -0.0007
I 138.00 70.96 2.1399 1.8510 0.3859 0.2852 0.1489 0.1101
MAY II 109.00 64.11 2.0374 1.8069 0.2835 0.2411 0.0803 0.0683
III 179.00 106.79 2.2529 2.0285 0.4989 0.4627 0.2489 0.2308
I 84.00 100.84 1.9243 2.0036 0.1703 0.4378 0.0290 0.0746
1982-83 OCT II 71.00 88.58 1.8513 1.9473 0.0973 0.3815 0.0095 0.0371
III 63.00 55.79 1.7993 1.7466 0.0454 0.1807 0.0021 0.0082
I 53.00 41.31 1.7243 1.6161 -0.0297 0.0502 0.0009 -0.0015
NOV II 48.00 38.77 1.6812 1.5885 -0.0727 0.0227 0.0053 -0.0016
III 44.00 34.27 1.6435 1.5349 -0.1105 -0.0309 0.0122 0.0034
I 42.00 29.40 1.6232 1.4683 -0.1307 -0.0975 0.0171 0.0127
DEC II 42.00 25.54 1.6232 1.4072 -0.1307 -0.1586 0.0171 0.0207
III 39.00 26.22 1.5911 1.4186 -0.1629 -0.1472 0.0265 0.0240
I 31.00 22.36 1.4914 1.3494 -0.2626 -0.2164 0.0690 0.0568
JAN II 29.00 22.40 1.4624 1.3502 -0.2916 -0.2156 0.0850 0.0629
III 28.00 22.62 1.4472 1.3545 -0.3068 -0.2114 0.0941 0.0648
I 27.00 21.39 1.4314 1.3302 -0.3226 -0.2356 0.1041 0.0760
FEB II 26.00 21.20 1.4150 1.3263 -0.3390 -0.2395 0.1149 0.0812
III 24.00 21.45 1.3802 1.3314 -0.3738 -0.2344 0.1397 0.0876
I 26.00 29.99 1.4150 1.4770 -0.3390 -0.0889 0.1149 0.0301
MAR II 30.00 32.42 1.4771 1.5108 -0.2768 -0.0550 0.0766 0.0152
III 32.00 29.44 1.5051 1.4689 -0.2488 -0.0969 0.0619 0.0241
I 44.00 29.41 1.6435 1.4685 -0.1105 -0.0973 0.0122 0.0108
APR II 45.00 28.28 1.6532 1.4515 -0.1008 -0.1144 0.0102 0.0115
III 45.00 33.42 1.6532 1.5240 -0.1008 -0.0418 0.0102 0.0042
I 100.00 57.45 2.0000 1.7593 0.2460 0.1934 0.0605 0.0476
MAY II 173.00 91.11 2.2380 1.9596 0.4841 0.3937 0.2343 0.1906
III 167.00 139.24 2.2227 2.1438 0.4687 0.5779 0.2197 0.2709
1983-84 I 142.00 121.51 2.1523 2.0846 0.3983 0.5188 0.1587 0.2066
OCT II 99.00 78.07 1.9956 1.8925 0.2417 0.3266 0.0584 0.0789
III 62.00 50.04 1.7924 1.6993 0.0384 0.1335 0.0015 0.0051
I 50.00 39.42 1.6990 1.5957 -0.0550 0.0299 0.0030 -0.0016
NOV II 48.00 36.67 1.6812 1.5643 -0.0727 -0.0015 0.0053 0.0001
III 44.00 34.10 1.6435 1.5328 -0.1105 -0.0331 0.0122 0.0037
Table-5.4(5)

UDAIPUR TDI.+GSL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
I 42.00 30.40 1.6232 1.4828 -0.1307 -0.0830 0.0171 0.0109
DEC II 39.00 28.55 1.5911 1.4557 -0.1629 -0.1102 0.0265 0.0180
Table-5.4(6)

UDAIPUR TDI.+GSL DEVIATION FROM MEAN
D/SITE D/SITE X Y X^2 X*Y
YEAR MONTH Qx Qy LOG x LOG y LOGx-LOGX' LOGy-LOGy'
(Cumecs) (Cumecs)
III 36.00 21.42 1.5563 1.3308 -0.1977 -0.2350 0.0391 0.0465
I 35.00 30.03 1.5441 1.4776 -0.2099 -0.0883 0.0441 0.0185
JAN II 35.00 29.59 1.5441 1.4711 -0.2099 -0.0947 0.0441 0.0199
III 32.00 28.06 1.5051 1.4481 -0.2488 -0.1178 0.0619 0.0293
I 30.00 26.62 1.4771 1.4251 -0.2768 -0.1407 0.0766 0.0390
FEB II 28.00 26.07 1.4472 1.4161 -0.3068 -0.1497 0.0941 0.0459
III 22.00 24.73 1.3424 1.3932 -0.4115 -0.1726 0.1694 0.0710
I 33.00 25.65 1.5185 1.4091 -0.2355 -0.1568 0.0554 0.0369
MAR II 33.00 29.19 1.5185 1.4652 -0.2355 -0.1006 0.0554 0.0237
III 36.00 30.48 1.5563 1.4840 -0.1977 -0.0818 0.0391 0.0162
I 42.00 31.91 1.6232 1.5039 -0.1307 -0.0619 0.0171 0.0081
APR II 51.00 30.85 1.7076 1.4893 -0.0464 -0.0766 0.0022 0.0036
III 69.00 41.00 1.8388 1.6128 0.0849 0.0469 0.0072 0.0040
I 128.00 73.03 2.1072 1.8635 0.3532 0.2977 0.1248 0.1051
MAY II 180.00 107.90 2.2553 2.0330 0.5013 0.4672 0.2513 0.2342
III 353.00 197.58 2.5478 2.2957 0.7938 0.7299 0.6301 0.5794
G.TOTAL 420.95 375.80 0.00 0.00 17.53 15.36
NO. OF PERIOD 240 LOG x' LOG y'
AVERAGE 1.7540 1.5658
Co-efficient of Corelation
b = SIGMA X*Y = 0.8766
SIGMA X^2
Table-5.4(7)

Discharge in Cumecdays
120000
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Graph showing the trend lines of two series blocks
of annual discharge of river Chenab at Udaipur
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combined s2 s1 Linear (combined) Linear (s2) Linear (s1)
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