HomeMy WebLinkAboutMicro hydro Vol 2 1980MICRO HYDRO
VOLUME2
Guidance Manual of Procedures
for Assessment of Micro Hydro Potential
OCTOBER 1980
Crippen Consultants
1605 Hamilton Ave.
North Vancouver, B.C.
V7P 2L9
MICRO HYDRO
SYNOPSIS
VOLUME I: A Survey of Potential Micro Hydro
Developments For Use By Remote
Communities in British Columbia
This Volume presents the estimate of the potential for micro hydro development in
remote communities in British Columbia.
VOLUME 2: Guidance Manual of Procedures F"or
Assessment of Micro Hydro Potential
This Volume presents a step-by-step procedure for the assessment of actual sites
for micro hydro development.
MICRO HYDRO REPORT
TABLE OF CONTENTS
Page
I. GUIDANCE MANUAL STUDY PROCEDURE
1.1 lntroduct ion I -I
1.2 Reconnaissance Study 1-2
1.3 Prefeasibility Level Study I - 3
1.4 Study Procedures 1-4
1.5 Ongoing Studies 1-5
2. BASIC DATA COLLECTION
2.1 Sources of In format ion 2-I
2.2 Topographic Mapping 2-2
2.3 Hydrometric and Climate Data 2-2
2.4 Air Photos 2-3
2.5 Geological 2-3
2.6 Other 2-3
3. CONCEPTUAL PLANNING
3.1 Load Demand 3 -I
3.1.1 Existing Demand 3-I
3.1.2 Load Growth 3-2
3.2 Hydrology 3-4
3.2.1 Firm Flow Determination 3-4
3.2.2 Water Storage for Regu lot ion 3-5
3.2.3 Water Licence 3-6
3.3 Layout Concepts 3-6
3.3.1 Installed Capacity 3-6
3.3.2 Civi I Features 3-7
4. DETAILED PLANNING
4.1 Civi I Features 4-I
4.1.1 Diversion/Intake Structure 4-1
4.1.2 Canal 4-3
- i -
TABLE OF CONTENTS -(Cont'd)
Page
4. DETAILED PLANNING -(Cont'd)
4.1.3 Penstocks 4-5
4.1.4 Powerhouse and T ai I race 4-5
4.2 Mechanical Equipment 4-6
4.2.1 Introduction 4-6
4.2.2 Prime Mover 4-7
4.2.3 Selection of Speed 4-13
4.2.4 Control 4-14
4.2.5 Suppliers 4-15
4.3 Electrical Facilities 4-17
4.3.1 Generators 4-17
4.3.2 Protection and Control 4-19
4.3.3 Transmission Line 4-19
4.3.4 Equipment Suppliers 4-20
5. MICRO HYDRO COST ESTIMA TJNG
5.1 General 5 -I
5.2 Cost Estimating Method 5-2
5.3 Cost Estimating Limitation 5-3
5.4 Basic Approach to Costing Civi I Works 5-3
5.5 Basic Approach to Electrical and
Mechanical Cost Estimating 5-4
5.6 Engineering and Management Fees 5-4
5.7 Contingency 5-5
5.8 Price Escalation 5-5
5.9 Interest During Construction 5-6
5.10 Step by Step Cost Estimating Method 5-6
6. FINANCIAL EVALUATION
6.1 Method 6-1
6.1.1 Introduction 6-1
6.1.2 Life Span 6-2
-ii -
TABLE OF CONTENTS-(Cont'd)
6. FINANCIAL EVALUATION-(Cont'd)
6.2
6.3
6.4
6.5
6.6
6.7
Table4-l -
Table6-l -
Figure 1-1
Figure 4-1
Figure 4-2
Figure 5-1
6.1.3 Treatment of Input Price Variations
6.1.4 Method of Evaluation
6.1.5 Selection of Values of Study Variables
Hydro PI ant Gene rat ion Costs
Alternative Generation Costs
Payback Evaluation
Internal Rate of Return Evaluation
Sensitivity
Sample Financial Evaluation
TABLES
Designers of Standardized Micro Hydro
Turbines
Cash Flows -Hydro Versus Alternative
Study
FIGURES
Guidance Manual Study Procedures
Standardized Micro Hydro Turbines-Selection
of Type
Standardized Micro Hydro Turbines-Selection
of Speed
Generating Unit Categories -Head vs Discharge
-iii -
Page
6-3
6-3
6-6
6-7
6-8
6-9
6-10
6-10
6-10
4-22
6-4
APPENDICES
SITE INVESTIGATION ASSESSMENT
II STEP BY STEP COST ESTIMATING METHOD
Ill SUPPORTING INFORMATION
IV MANUFACTURERS AND SUPPLIERS
V HYDRO ELECTRIC CAPACITY DETERMINATION
(HYDRO PLANT WITH SECONDARY ENERGY GENERATION)
VI DIESEL PLANT CAPITAL COSTS
DIESEL PLANT OPERATING COSTS
HYDRO PLANT OPERATING COSTS
VII FINANCIAL EVALUATION
VIII RAPID FINANCIAL EVALUATION METHOD
IX CASE STUDY -CARPENTER AND CODY CREEKS
-iv-
SECTION I
GUIDANCE MANUAL
STUDY PROCEDURE
I. GUIDANCE MANUAL STUDY PROCEDURE
1.1 INTRODUCTION
This manual has been written to assist in the evaluation of potential
micro hydro sites. The evaluation procedure contained herein is at a
prefeasibility level and when done properly should provide enough
direction as to whether a feasibility level study is warranted.
Although the evaluation procedure is straightforward and eliminates or
minimizes the number of technical decisions to be made, it has to be
stressed that the user should have basic knowledge and understanding of
such hydro developments. Therefore the user should have some
engineering or other relevant training, or at the very least be under the
guidance of an engineer. The evaluation procedure is not intended to be
used directly by a lay person.
The need for such training will become readily apparent when decisions
as to the hydro system component layout and interpretation of hydrol-
ogic data are needed.
The evaluation procedure is for micro hydro sites with potential
capacities of from 10 kW to 200u kW installed capacity. The user is
cautioned that cost data presented in the manual are based on January
1980 prices and project ions, and that, while the procedures are appl ic-
able regardless of the year in which the study is to be done, cost data
should be updated wherever possible to reflect conditions applicable at
a given site.
The user will probably adopt a two-stage approach to the evaluation of
a site.
In the first instance a reconnaissance study will probably be required, in
which the input wi II likely be limited to a one man week, for the
I -I
purpose of establishing whether a site has even a remote chance of
feasible development. Although it is desirable that a site visit be made
during a reconnaissance evaluation, it is not essential provided the user
can ascertain the major micro hydro components from existing hydrol-
ogical, topographic and air photo data.
If the reconnaissance evaluation proves that the proposed project is
potentially viable, the user would then proceed to carry out a more
detailed evaluation. This second stage investigation is defined as a
prefeasibility study which could take up to one man month of input or
less if the user is familiar with hydro study procedures, once the basic
data have been obtained.
This manual contains level of detail appropriate to the prefeasibility
study. It is essential that the user comprehend the prefeasibility level
of detail prior to undertaking a reconnaissance study. A reconnaissance
study must adopt the same procedure as a prefeasibility study with the
major exception that the time spent in defining major construction
components and in preparing capital cost estimate is significantly
lower. It is hoped that the judgment exercised by the user in arriving at
an acceptable project layout and cost estimate for a reconnaissance
study proves to be sufficiently accurate.
Figure 1-1 shows the essential study procedures and relates the
different input areas to the chapters and appendices of this volume.
The reconnaissance level procedures are a "once over lightly" version of
the prefeasibility procedures with rapid determination of basic energy
costs facilitated by supporting data for an abbreviated financial com-
parison as contained in Appendix VIII to this Volume.
1.2 RECONNAISSANCE STUDY
A reconnaissance study must essentially cover all of the ground which
has been described in Subsection 1.3 for a Feasibility Study, with the
exception that less time is spent in the detailed selection of project
I -2
design parameters and less time is spent preparing the capital cost
estimate. The user is cautioned that the accuracy of the capital cost
estimate in a Reconnaissance Study must be maintained at a reasonably
high level if meaningful results are to be obtained.
Appendix VIII contains data which will enable the user to provide a
rapid financial evaluation for a reconnaissance study.
1.3 PREFEASIBILITY LEVEL STUDY
A prefeasibility study must start with the assembly of basic data. As
shown in Figure 1-1, Section 2 of this manual deals with the acquisition
of adequate topographic maps, aerial photographs and data on climate,
geology and hydrology. Appendix I provides additional information
which may be useful for data collection on site visits.
Section 3 describes load forecasting requirements and the determina-
tion of the firm flow available at the site. Having established the firm
flow, the user can determine the flow-head combinations that will
produce the desired design peak load, and then move on to examine the
topographic maps and establish basic design layouts. Conceptual design
is described in Section 3 and Appendix Ill provides supporting informa-
tion for water licencing and firm flow determination.
If the site topography and the available firm flow do not yield the
desired firm peaking capability then the user must consider alternative
means of generation to meet the difference between peak demand and
firm hydro capacity. If the need fer additional energy supply is
established, the hydro plant installed capacity can be raised beyond
firm capacity in order to capture secondary energy benefits. A
procedure for determining an appropriate hydro installed capacity under
such circumstances is given in Appendix V: it is based on a cost
optimization process whereby the benefits of secondary hydro energy
generation are weighed against the cost of providing the incremental
hydro capacity.
I - 3
Although the terms of reference for this study exclude sites within
economic distance of the B.C.H.P.A.* distribution system, the user may
wish to evaluate a site where connection to the grid is possible. This
manual emphasizes diesel generation as the most likely alternative
means of supply, but the methods of optimization and evaluation are
the same regard less of the source.
Having established the conceptual design and installed capacities the
user can move on to determine the major project design parameters for
civil, mechanical and electrical components, and to estimate the
project construction costs. Sections 4 and 5 and Appendices II and IV
deal with design parameter selection, quantities estimates and capital
cost estimates. The user should aim to have a good appreciation of the
design parameters and a competent capital cost estimate by the time
he has reached the end of Sect ion 5.
Section 6, together with Appendices VI and VII, provides the user with a
financial evaluation technique which will enable the determination of
unit energy costs, payback periods and project internal rate of return.
The basis of evaluation calls for comparison between the hydro and the
most attractive alternative method of generation: for remote commun-
ities it is likely that diesel generation (either continuation of existing,
or new plant) will be the most attractive alternative means of genera-
tion. At some sites, connection to the B.C.H.P.A. power grid may be
the most viable alternative. The procedure compares the additional
(incremental) capital cost required for a hydro plant over a diesel (or
other) supply against benefits consisting of operating, maintenance, and
fuel cost savings. Upon completion of the financial evaluation the user .
should have a clear idea as to project viability.
*B.C.H.P .A. -British Columbia Hydro and Power Authority
I -4
1.4 STUDY PROCEDURES
The study procedures described in Subsection 1.2 and 1.3 are summar-
ized in flow chart form in Figure 1-1.
1.5 ONGOING STUDIES
After completion of the prefeasibility study outlined in this volume the
user may wish to proceed with project implementation. Prior to making
a final decision to proceed with the project it is recommended that
additional work be carried out to firm up the development concept and
cost estimates and subsequently review the financial viability of the
project. At this point it would be desirable to employ the services of an
individual or a consultant who has had experience in hydro-electric
projects. The program for these additional studies should encompass
the following points:
I. Brief professional review of hydrologic data, development con-
cept, cost estimate and financial evaluation.
2. T opogrophic survey of site and assessment of local construct ion
materials' sources and foundation conditions.
3. Refine project layout and size major components, takeoff quan-
tities, obtain equipment quotations from suppliers and prepare
detailed cost estimates.
4. Refine financial evaluation.
I -5
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MICRO HYDRO STUDY
GUIDANCE MANUAL
STUDY PROCEDURES
CRIPPEN CONSULTANTS -VANCOUVER, B.C. CANADA FIGURE 1-1
SECTION 2
BASIC OAT A COLLECTION
2. BASIC OAT A COLLECTION
2.1 SOURCES OF INFORMATION
It is assumed that the user has identified a river or several rivers which
have the potential for micro hydro power generation, and that a
concerted effort will be made to obtain as much basic data as possible
concerning the site. The following suggestions are made to assist the
user in assembling such basic data.
Topographic Map Sources
a. Geodetic Survey of Canada.
b. Topographic Survey of Canada.
c. B.C. Surveyor General.
d. Municipal or Regional District Offices.
e. Former landowners may have had topographic surveys carried out.
Hydrometric and Climate Data Sources
a. B.C. Water Rights Branch.
b. Canada and B.C. Departments of Environment.
c. Local sources such as farmers, municipal utilities, etc. may have
useful knowledge of the area.
Air Photos
a. Surveys & Mapping Branch, Ministry of the Environment, B.C.
Geology
a. Geological Survey Canada.
b. If mining companies have been active in the area they may be a
useful source of information.
2-I
Other
a. Department of Indian & Northern Affairs, Ottawa.
b. Ministry of Fisl,eries, Ottawa and Victoria.
c. Ministry of Agriculture, Ottawa and Victoria.
2.2 TOPOGRAPHIC MAPPING
Topographic maps ideally should be to a scale of about I: 15,000 or
larger, however, it is unlikely that for most sites scales better than
1:50,000 will be available. Available mapping will be used for a
reconnaissance study and, based on the findings, a decision must then be
made as to whether more accurate topography is required for the
prefeasibility study.
2.3 HYDROMETRIC AND CLIMATE OAT A
If runoff data are not available for a specific stream or site the user
should try to assemble stream flow data for similar catchment areas
within an 80 to 160 km radius of the site. These data can then be used
to synthesize flow data for the site in question on the basis of relative
drainage areas. Stream gauging records in B.C. are published by Water
Survey of Canada. Additional data may be available from local
authorities, companies or persons.
In British Columbia, the most important climatic consideration aside
from precipitation, is temperature and its influence on operation under
freezing conditions.
For canal design, it must be noted that the coast mountains divide the
province into the interior area (where ice cover must be anticipated)
and into the coastal area (where ice-free operation is probable). This
generalization must, of course, take into account the effect of site
elevation. Water Survey of Canada can provide information about ice
2-2
formation at river gauging sites in the vicinity of a proposed site. This
information can then be used as a guide as to the probability of ice
forming at the intake or on canals.
2.4 AIR PHOTOS
Stereoscopic viewing of air photos can be a valuable source of topo-
graphic and geological information. Photos usually are available in
scales of I :40,000 or I :20,000. If topographic mapping is of too small a
scale, an alternative to doing a large scale ground survey is to obtain
I :20,000 scale air photos together with some spot elevations from a
ground control survey. The large scale air photos can then be analyzed
using a stereoscope with a parallax bar to determine elevations at
salient points in the project area. Some areas even have I: I 0,000 scale
air photos available.
2.5 GEOLOGICAL
Although geological mapping of a site area will likely be to a scale
which is small, valuable information can be obtained from a geological
air photo interpretation if done by a competent geologist. Such
interpretation wi II indicate whether construction is in bedrock, alluvial
or glacial deposits, the magnitude of ground slopes involved, potential
landslide areas, and recommended access routes. Potential sources of
construction materials such as concrete aggregates and canal lining
material can be identified.
Site investigation, even if sub-surface exploration is not possible at the
time, is highly recommended. Excavation of test pits at the sites of
major structures would provide valuable sub-surface information.
2.6 OTHER
The user should establish whether environmental considerations such as
fisheries and agriculture or wildlife are likely to become significant
considerations in the development of the project.
2 - 3
SECTION 3
CONCEPTUAL PLANNING
3. CONCEPTUAL PLANNING
3.1 LOAD DEMAND
3.1.1 Existing Demand
*
**
Electrical demand can be established from records of the existing
generation installation or by surveying domestic and industrial facilities
at the site.
In the absence of any other data, a rule of thumb is to allow an average
load requirement of 1.5 kW per person or 6.75 kW per household. To
arrive at the peak demand, a yearly load factor must be applied and the
figure suggested is 0.75* for industrial communities and 0.5* for
residential communities.
Ontario Hydro in their report No. 303-2** present a generalized
formula to estimate the daily peak power requirements for remote
communities.
"This formula assumes that the peak would occur daily, principally as a
result of residential loads coincidental with 24 hour loads. The
community peak power requirement is estimated to be the sum of the
following:
2 kilowatts per (native) household
3 kilowatts per government resident (i.e. teachers and nurses
residence)
5 kilowatts for nursing station
From analysis of data reported in the Inventory of Diesel Electric Load
Centres in Appendix II of Volume I, and also from information provided by B.
C. Hydro.
See Bibliography, Volume I
3-I
5 kilowatts per store (refrigeration and security lighting}
2 kilowatts for airport
5 kilowatts for telephone system
Additional for government agencies (i.e. weather station,
forestry, etc.)
Summation of the above would equal the community peak power
requirement."
The difference in demand estimates quoted above, indicates the
variation in domestic usage, whether electricity is used for lighting,
cooking and appliances and even space heating or for only some of the
uses listed. Usage is usually influenced by cost, and availability of
electricity.
3.1.2 Load Growth
The potential for load growth must be estimated and allowed for when
determining the size of generating equipment to be installed.
Where historical operot ing records of diesel generation plants ore
available these will provide the user with a good ideo of the post load
growth pattern. It is useful to determine whether the historical load
growth was significantly influenced by any changes of the load
components such as residential, commercial or industrial development.
Load growth projections con be mode on the basis of development
trends within each of the above mentioned load components. It is
important to predict both the peak ioad demand growth and the annual
energy demand growth; the former is required in order to size the plant
capacity and the Iotter is required in order to predict future revenues
and costs.
If no data are available for the load centre, it may be possible to obtain
relevant data for a simi lor community nearby.
3-2
If the load centre hos previously been subjected to load growth
restrictions (for example funds may not hove been available to expond
existing plant) then allowance must be mode for the suppressed demand:
in such a system higher than normal growth rates may be experienced
over the first one or two years of operation.
G. B. Scheer* proposed a formula for the estimation of load growth:
where
log 10 G C -0.15 log 1 0 U
G is annual growth rate in percentage points
U is the usage per person, i.e. demand in kWh/yr
C is a constant derived from:
C (Rate of pop. growth x 0.02) + I .33
Population growth for U is about 2 per cent/annum
c = 1.37
U = 1.5 kW x 0. 7 (load foetor) x 24 x 365 = 9198
soy, 9200 kWh/yr
log 10 c = 1.37-0.15 X 3.964
= 0.775
G = 5.96 per cent/annum
This formula, which has been proven over a number of years and in
many c'ifferent countries, appears to bear out the 6 per cent growth
rote reasonably well. In the absence of other information, a compound
load growth rote of 6 per cent per annum is often used.
It is preferable to extend the capacity demand projection to of least 12
years and, if possible, 24 years from the intended first year of operation
of the project.
*See Bibliography in Volume I.
3-3
3.2 HYDROLOGY
3.2.1 Firm Flow Determination
Since the ability of a hydro plant to meet peak load demand depends on
the availability of the design flow it is important that even during dry
years the required flow is available to enable the plant to meet all
peaks (the annual peak load may not coincide with annual low flow). An
estimate of the firm flow in the river must, therefore, be made prior to
proceeding with the project layout design.
The definition of firm flow will depend on whether the system is
capable of tolerating infrequent capacity limitations. If the community
can accept demand rationing during periods of low river flow, then a
suitable dependability may be achieved by defining firm flow as the
minimum daily flow which is exceeded 95 per cent of the time. Such a
community would then be subject to demand rationing for an average of
18 days a year. Less tolerant communities might insist on an
exceedence of 98 per cent of the time or higher.
The most convenient method by which the firm flow can be determined
is from water survey records for the actual stream being considered. In
most cases, however, flow records will not be available, and it then
becomes necessary to look for gauged catchments nearby which have
similar precipitation and runoff conditions. Similar catchments are
those having similar altitude, size, orientation relative to the major
mountain ranges, and similar prevalent weather patterns. The
existence of lakes in a catchment wi II influence runoff patterns owing
to the effects of natural regulation. Any such effects must be
accounted for when using adjacent catchments to synthesize flow data
by choosing catchments which are similar. Procedures, depending on
the records available for the catchment in question, wi II differ and are
detailed below. Although there are methods for using precipitation,
3-4
temperature and snow pack data to synthesize stream flow data, these
are not included in this manual.
It is recommended that mean monthly flow records be used for the
procedures set out below. For determining firm flow the minimum
mean monthly flow appropriately adjusted for the point of diversion
should be adopted. This assumes a period of water shortage during
approximately half of the month providing however this is considered
acceptable for this stage of study.
Therefore if:
records are available on the stream being considered, adjust the
recorded flows in the ratio of the tributary catchment areas.
no records are available on the stream being considered, identify
a gauged catchment with simi lor characteristics as described
above. Adjust the recorded flows in the ratio of the tributary
catchment areas.
Extension or inti II ing of gaps in records used in the above procedures
can be done by correlation with another gauged catchment if a suitable
correlation can be established. The method is set out in Appendix A
of "Hydrology For Engineers" by Linsley, Kholer and Paulus.
If timing of the field visit can be arranged in the low flow period a spot
discharge measurement should be made to check the flow computed
from the gauged records and the catchment area ratio. If the results
differ by more than 20 per cent, the flow generated using the
catchment area ratio should be adjusted accordingly.
3.2.2 Water Storage For Regulation
Storage can be utilized to regulate the flow into patterns which are
more favourable to the operation of the plant. Methods for increasing
3-5
flow by storage are given in "Water Resources Development", by E.
Kuiper, p. 282 and included in Appendix Ill (C) of this volume.
If storage is being considered to improve firm flows, it is generally only
economical if an existing lake can be regulated or significant volume
can be impounded with a low dam.
Depending on the volume of storage available, it may be possible to
provide significant improvements to the operating characteristics of a
hydro plant. The greatest benefit accrues to storage if it can be used
to regulate daily flows so that daily peak loads can be met without
recourse to alternative means of generation. Larger storage volumes
can be utilized to increase plant output during dry season flow periods,
or possibly to provide over-year storage.
3.2.3 Water Licence
It is important to recognize that the ownership of and the right to use
water is vested in the Crown. The water licence application process
can be long and drawn out and if the project looks feasible on the first
analysis a water licence application for the proposed development
should be made without delay. Appendix Ill (A) -"B.C. Water
Licencing", reviews the basic requirements and application procedures.
3.3 LAYOUT CONCEPTS
3.3.1 Installed Capacity
Having established the load demand and the firm flow the user is in a
position to proceed with project planning. The user must determine
whether topographic conditions allow the development of sufficient
generating capacity to meet load demand forecasts. The basic formula
to be used is as follows:
3-6
P = g x z x Q x H where g = acceleration due to gravity 9.8
m/sec 2
z = overall hydraulic, mechanical
and electrical efficiency (usually
0.7)
Q = firm flow m 3 /sec
H = net head metres
p = capacity kW
Figure 3-1 provides a graphical solution of the above equation for two
of the three variables, P, Q and H. Topographic conditions permitting,
it is preferable to select a head which will provide the required peak
load demand capacity for at least 24 years of the pro.ject life. If head
limitations prevent this, the head available should be maximized
consistent with avoiding expensive construction techniques and a deci-
sion should be made as to whether storage should be investigated as a
means of firming up the project capacity or whether supplementary
power is required.
If load growth rates are high a staged hydro development should be
considered, with the initial installed capacity to be sized for a peak
demand of I. 75 to 2 times the initial year peak demand. Load growth
rates of 3 per cent per annum or more will see a doubling of demand in
24 years. A single stage installation would probably be appropriate
under smaller load growth conditions.
It is recommended the initial capacity be based on projected demand of
not less than 6 years from the study date. Single or staged development
should consider demand over a period of 24 years.
3.3.2 Civi I Features
The primary civil features which must be determined are as follows:
3-7
-River intake
-Canal
-Penstocks
-Powerhouse location
-Tailrace
-Access roads
-Transmission line
Success in choosing the most economical layout depends to a great
extent on the judgment exercised by the user on the selection and sizing
of the main project components. Judicious use of natural site features .
can play a significant part in keeping construction costs down. The
intake should be located in a narrow but accessible part of the river,
preferably on rock foundations. During construction it will be neces-
sary to partially or fully divert the river. Canal routes should avoid
excessively steep valley wall slopes and rocky locations in order to
minimize cost. Penstock routes should be chosen to minimize overall
length, avoid severe undulations, and yet provide reasonable foundation
conditions. The powerhouse site should be accessible and situated
above flood level. The intake should prevent entry of flood waters into
the power canal, and penstocks should be located so as to avoid them
being damaged by flood waters.
Some typical layouts are shown on Figure 11-34 and sample layouts of
mechanical and electrical equipment are given on Figures 11-35 to 11-40.
Having decided on a layout, or possibly several alternative layouts, the
user is in a position to proceed with finalization of design parameters as
described in Section 4 of this manual. If firm hydro capacity is not
sufficient to meet the projected load demand then it is necessary to
consider alternative means of generation for the supplementary energy
required. The hydro plant under these conditions is capable of
generating secondary energy and a separate procedure must be under-
taken to determine the optimum hydro installed capacity. This
optimization procedure is outlined in Appendix V.
3-8
SECTION 4
DETAILED PLANNING
4. DETAILED PLANNING
4.1 CIVIL FEATURES
4.1.1 Diversion/Intake Stn •cture
The diversion/intake structure should preferably be located in a stretch
of the river where the width between river banks is a minimum. The
site should, however, be wide enough to provide adequate access and
also be wide enough for provision of a spillway weir to allow passage of
flood flows down the river.
If the structure is likely to be substantial, a gated intake will be
required in order to control release of water into a canal or directly
into a penstock. If a gated intake is constructed a low level outlet
should be included to drain the pond area behind the structure for
maintenance and inspection. The gate structure deck should be above
flood level.
If the structure is small, diversion can be directly into a canal provided
precautions are taken to prevent ingress of silt and floating debris and
the canal is designed to accept high water levels during flood stages. A
simple diversion structure suitable for small streams is shown in Figure
11...,31 in Appendix II. If a gated inlet is not provided at the diversion
site, a gate wi II be required at the end of the canal where ~ater enters
the penstocks.
Control of the large debris such as floating logs may be a problem
during periods of high river flow. If the intake can be located on the
inside of a natural bend in the river floating debris problems will be
minimized. Otherwise a log boom or rock training berm may be needed.
Control of small debris at the intake is by the use of trashracks. The
gross area of the trashrack should give a design water velocity of not
more than 0.6 mls so that:
4-I
the rack can be readily cleaned without having to reduce the flow
and power output;
the head loss through the rack will not be excessive;
the likelihood of vibration is reduced.
The spacing of the vertical rack bars is gauged to suit the size of debris
that will pass safely through the system and should be as large as
possible to prevent the necessity for excessive attention to screen
cleaning.
The rack should be designed to withstand the load due to it being at
least 50 per cent plugged either by debris or ice. F razil ice is a very
real problem in many areas where low temperatures occur. It may be
advantageous to remove the rack when frazil ice is present but care
should be taken to prevent problems of blockage further downstream in
the system.
The trashrack should be designed to be removable for repair and
maintenance. Where debris is a severe problem, relatively simple
automatic or semi-automatic mechanical rakes may be installed.
Trash racks are usually custom designed and bui It.
The type of gate or valve used for intake closure will depend on the
gate's or valve's size and location. The device must be capable of
operating with maximum potential flow through the system. This
maximum flow must consider the possibility of ruptured penstocks when
they are part of the system or at least the full load flow through the
generating unit.
If the gate or valve is located at the head of the penstocks the
arrangement must include provision for the release of air during
penstock fi II ing and its admission when emptying.
4-2
4.1.2
Gates may be either custom designed and built timber and steel
structures or a purchased "off the shelf" design from a supplier such as
Armco.
Valves are usually ')f the butterfly type and in the smaller sizes (less
than 600 mm) are available from many sources.
Canal
If a canal is to be employed, construction should be in overburden where
possible rather than in rock. Well graded and compacted impermeable
overburden materials provide the cheapest canal construction. Sandy or
gravel foundations will require that the canal be lined with an imper-
meable membrane of either soil, asphalt or concrete. In this manual,
concrete is considered to be used as the lining material. Where lining is
required consideration should be given to the use of corrugated metal
half round flumes such as are manufactured by Armco. For smaller
canals in ice-free conditions metal flumes are likely to be more
economical.
If the project site is west of the coast mountains, or at an elevation
greater than 500 m, ice conditions will likely prevail during winter
operation. Water Survey of Canada experience may, however, indicate
ice-free conditions within the above areas and consequently a check
should be made of their records prior to proceeding with design. Ice
thickness of up to one metre can be expected in many areas and must
be allowed for in the design.
It is good practice in canal design to provide a side spillway at an
elevation below the crest of the embankment in order to prevent
overtopping of the canal berms and consequent failure by erosion.
Water discharged at the canal spillway will be returned to the river.
Typical canal freeboard requirements are 0. 7 to 1.0 metres.
4-3
If the canal inlet is not controlled by a gate the embankment height
must be 0. 7 to 1.0 metres higher than the highest anticipated flood
level.
If the canal inlet is controlled by a gate the canal embankment may be
constructed to the same slope as the canal invert, and the side spi II way
located at the downstream end of the canal. Such an arrangement
requires frequent operator adjustment to the inlet gate and may lead to
wastage of water, particularly if the power plant water demand
fluctuates over a wide range throughout the day. A more satisfactory
design would have the canal embankment constructed horizontally,
allowing operation of the plant throughout its full range without spilling
water during periods of low flow. This may not be practical if the canal
is long, say more than 7.5 km.
Canal side slopes should be made as steep as possible to minimize
construction costs. Typical side slopes and design velocities are as
follows:
Side Slope Velocitt m/sec
Vert:Horiz
Soft Clay I :3 0.75
Silt 1:2 0.75
Till I : I I
Rock Vertical 1-2
In this manual, canal side slopes of IV:I.5H are used.
Canals may have to cross streams that are flowing into the main river
from which water has been directed. If such streams are small they
may be taken under the canal in a culvert.
A good appreciation of the maximum side slopes which can be tolerated
can be gained by observing natural slopes in river banks or creek banks
in the area.
4-4
4.1.3 Penstocks
Typical penstock diameters are given in Figure 11-22 Appendix II.
Recommended discharge velocities are between 1.7 and 3 metres per
second. The user may determine an appropriate diameter by entering
the graph with a design flow necessary to meet the peak demand for the
available head.
For most installations* steel p1pe would be used because of strength
requirements, construction ease, cost, and availability. For these
reasons and for the sake of simplifying the costing procedure only steel
penstocks are considered in this manual. As well, two types of
installations are considered: above ground or buried depending on the
slope and ground material.
The user is referred to Appendix II for cost estimating data pertaining
to penstocks.
4 .I .4 Powerhouse and T a i I race
The powerhouse will be located adjacent to the river at an elevation
which is sufficient to avoid damage from flood waters and to provide
the correct setting for the turbines with respect to the minimum
tailrace level. The powerhouse substructure must be designed to
withstand the thrusts introduced by the incoming penstock, and the
operating loads of the turbine. For smaller power plants slab or grade
construction will most likely be employed.
The powerhouse superstructure can be constructed of lumber, concrete
block or prefabricated metal frames and cladding. The latter forms are
recommended where vandalism may be a problem.
* At an early stage of the investigation AC (asbestos cement), PVC (polyvinyl
chloride) and other plastic type pipes were eliminated for these reasons.
4-5
Tailrace design within the building will depend on the type of turbine
units selected. Outside of the building perimeter a simple canal section
will be employed. Riprap lining may be required if either the tai I race
discharge or the river flows are likely to produce scour conditions.
4.2 MECHANICAL EQUIPMENT
4.2 .I lntroduct ion
The equipment for an isolated micro hydro electric power installation is
required to perform the following functions:
a. prevent the passage of harmful debris into the hydraulic system;
b. provide protection against damage in the event of a penstock
failure, to drain the penstock when necessary and to perform
emergency shutdown of the power generation equipment;
c. provide a prime mover with control to drive the electric power
generator at a constant speed;
d. protect the generator and to control and distribute its output.
The type of gate or valve provided for intake closure will depend on its
size and location. The device must be capable of operating with
maximum potential flow through the system. This maximum flow must
consider the possibility of ruptured penstocks when they are part of the
system or at least the full load flow through the generating unit.
The gate or valve arrangement must include provision for the release of
air during penstock filling and its admission when emptying.
Valves are usually of the butterfly type and in the smaller sizes (less
than 600 mm) are available from many sources.
4-6
4.2.2 Prime Mover
Selection of Type
The prime mover is a water turbine selected from several basic types
which are presently being produced from standard designs to suit the
range of micro hydro development under consideration.
The type of turbine being considered for micro hydro developments are
as follows:
~ Head Output
kW
Pelton Over 100m 50-2000
Turgo 15-200 m 50-2000
Francis 15-200m 500 -2000
Banki 2-170m 50-1000
Propeller 2 -15m 500-2000
Typical arrangements and outline dimensions for some of the different
types of units are shown in Figures 11-35 to 11-40 inclusive. A brief
description of each of these types is as follows:
a. Pelton Impulse Turbine
The Pelton turbine is essentially a high head turbine with one or
more free jets driving the runner though for outputs of I 0 kW or
less it may be used under a head of 15 m. The available pressure
head is transformed into velocity head at the jet(s) to allow the
discharge from the wheel to fall freely into the tailrace. The
turbine runner must be set well above the maximum tai I race level
and the available head must be discounted by the elevation of the
jet above the tai I race.
4-7
A horizontal arrangement for runners with one or two jets is
suitable but for runners with three or more jets, a vertical shaft
must be used.
Regulation can be either by jet deflection or nozzle control
(single regulation) or a combination of the two (double regulation).
Jet deflection provides rapid reduction of power input without
change of flow and provides satisfactory regulation under other-
wise difficult hydraulic conditions. Use of jet deflection without
nozzle control eliminates the advantage of the impulse turbine's
relatively flat efficiency/output characteristic.
Impulse turbines may be subject to cavitation both in the buckets,
due to incorrect shape or surface roughness and on the back of the
buckets due to impingement of the jet during its transition from
one bucket to the next.
Integrally cast runners are now favoured by all turbine manufac-
turers of long standing owing to the expense and difficulty of
achieving a connection between individual buckets and a central
disc which will prevent the buckets from working loose under the
operating conditions. Fatigue failure must be carefully con-
sidered due to the extremely high frequency of stress oscillations
which occur at the bucket connection.
b. Turgo Impulse Turbines
The T urgo Impulse turbine is a medium head turbine in which one
'
or two jets drive the runner. The side entry arrangement for the
jet allows a large jet diameter for a relatively small wheel
diameter (as compared to a Pelton turbine) resulting in a very
high specific speed for a single jet impulse turbine. This side entry
jet arrangement of T urgo runners means however, that axial thrust
must be designed for.
4-8
The 'Turgo' can be governed in a similar manner to the Pelton
turbine. The number of jets has been limited to two due to the
high drop-off in efficiency with three or more jets which will not
allow adequate drainage of the buckets. Extra power or higher
speed under low head can be achieved by installing two runners,
each with single or double jets.
Fig. 11-37 shows an arrangement of a small twin jet Turgo
generator unit.
c. Banki Turbine
The Banki turbine (also referred to as a "crossflow" or Ossberger
turbine after the principal manufacturer) is a low to medium head
turbine which is a transition type between an impulse and a
reaction turbine. The rectangular water jet enters the runner
radially on one side and leaves radially at the other side after
turning through about 90°. There is no axial flow and hence no
axial thrust. The shaft arrangement is always horizontal.
Single regulation and shutoff is provided by rectangular pivotted
vanes immediately upstream of the jet.
The full available head can be utilized by the installation of a
draft tube.
Fig. 11-38 shows a typical arrangement of a medium head Banki
generator unit.
d. Francis Reaction Turbine
The Francis turbine is a medium head turbine in which the flow
enters radially with respect to the axis of rotation and is
discharged axially. Both horizontal and vertical shaft arrange-
ments are possible. Provision must be made to accommodate
4-9
axial hydraul !c thrust. The water may be ducted to the guide
vanes leading to the runner entry through:
-an open concrete flume,
- a drum as shown on Fig. 11-39 or
- a spiral casing as shown on Fig. 11-40
and discharged through a draft tube allowing utilization of the full
available heads.
Single regulation is normally provided by a ring of adjustable
guide vanes or wicket gates controlled by servo-motors.
Francis turbines may be relatively small high speed units with
high velocities through the runner. Care must be taken to ensure
adequate margins against cavitation and subsequent damage to
the runner.
The mechanism of a Francis turbine is also prone to wear when
the water is contaminated by chemicals or solids which could
destroy the fine running clearances required for efficient perfor-
mance.
e. Propeller Reaction Turbine
The propeller turbine is a low head turbine which may have either
fixed or adjustable blades. The latter type is the 'Kaplan' turbine.
The direction and the control of flow is similar to a Francis
turbine except that double regulation is required for a Kaplan
turbine to keep the runner blades and wicket gates in correct
relationship for optimum efficiency. If the applied head varies
significantly the blade/wicket gate relationship can be adjusted to
maintain optimum efficiency over the operating load and head
range.
4-10
Both horizontal and vertical shaft arrangements may be used.
The former are called Tubular of Bulb turbines. Provision must be
made to accommodate axial hydraulic thrust.
Sufficient margins against cavitation must be allowed to prevent
damage to the runner and its envelope which may result from
excessive water velocities and low pressures an the downstream
side.
An outline of the range of head and flows suitable for each type
of standard design of turbine is shown on Fig. 4-1 and it will be
seen that for a large range of heads and outputs the choice can be
one of five different types, each type having its own limitations
and advantages depending on the type of operation required.
If the water supply is abundant, there is no need for its efficient
use as would be the case if diesel generation were required to
supply make-up power. Hence turbine efficiency is less important
when evaluating capital cost in the former case. In the latter
case both the peak efficiency and the rate of change of efficiency
with load must be considered. The smaller the physical size of
the turbine the lower the efficiency which varies approximately
as 1-k o-I/S where Dis the characteristic runner diameter.
The Banki, Turgo and Pelton turbines all have relatively flat
efficiency load curves. The extent of the flatness of a Kaplan
turbine efficiency curve depends on the amount of angular move-
ment of the blades towards the closing direction but the smallest
angles of closure give the highest value of runaway speed which
is a disadvantage.
The efficiency and performance of any runner is dependent on the
quality and accuracy of its manufacture. To maximize efficiency
on a small runner, the surface finish must be fine. A Pelton
4-II
runner efficiency is very sensitive to the fineness of the splitter
edge on the buckets which should be as sharp as is practical.
An approximation of full load efficiency, peak efficiency and
range of efficiP.nt operation for a SOO mm runner is as follows:
Minimum
Full Load Peak Percentage of
Efficiency% Efficiency % Full Load*
Tubular
Fixed Pitch Propeller 86 88 so
Variable Pitch Kaplan 86 87 20
I or 2 cell Banki 80 84 10
Francis 87 90 40
Turgo 82 84 IS
Pelton 86 87 IS
*For operation at efficiencies greater than 70 per cent.
For any given speed and runner stze the efficiency is head
sensitive and if the unit has been correctly selected for an
average head, an increase or decrease in head will cause a drop in
operating efficiency. The Kaplan turbine is most suited to
accommodate head variations while the Pelton is most sensitive
and for medium head installations relatively small deviations from
the optimum head can have significant influence on the turbine
efficiency over the whole load range.
In addition to the selection of turbine designs shown in Figures
II-3S to 11-40 inclusive, consideration should also be given to the
use of an axial, mixed flow or centrifugal pump running in reverse
as a turbine for units with outputs up to about ISO kW. Such units
will have to be equipped with external means of regulating the
flow or be arranged to work at constant output by providing a
4-12
suitable variable load up to full capacity of the unit. The head
and output for turbine operation for best efficiency will exceed
the equivalent values for best efficiency point operation of the
pump.
4.2.3 Selection of Speed
Reference to Fig. 4-2 will provide an indication of the speed at which
each different type may operate with a horizontal shaft arrangement to
allow the turbine to be set above the level of the water being
discharged from it.
The optimum speed of the turbine in rpm is given by:
n =
where n = specific speed from Fig. 4-2 s
P = turbine output (kW) from Fig. 4-1
and H net head (m)
The speed of a 60 Hz generator is given by
n = 3600 rpm
p
where p is a whole number. If the turbine and generator are
direct connected, then the generator speed must be selected to either
equal or be below the optimum turbine speed.
The economic minimum turbine speed for direct drive will vary with the
output but will generally be 600 rpm. Belt, chain or gear transmissions
are suitable for increasing the input speed to the generator which may
be as high as 1800 rpm for low outputs but will normally be either 900
or 1200 rpm.
4-13
4.2.4 Control
If a single generating unit is to be installed, the provision of a local
turbine inlet valve will not be necessary if the penstock is short and has
a reliable guard valve at the intake. Where two or more units are
operated from a single penstock it is desirable to be able to dismantle
one unit for maintenance without interrupting the availability of the
other unit(s) for power generation. The installation of turbine inlet
valves will provide this facility.
The type of load which the generating unit is required to supply and the
availability of water determines the method and degree of precision for
maintaining the speed constant for a 60 Hz output. The turbine speed
must be sensed and governed either by regulating the flow through the
turbine or by maintaining the load constant using an energy sink such as
a resistive water-cooled load or a brake. The flow through the impulse
or Banki turbine must be regulated or diverted at the input while the
flow through reaction turbines and reverse running pumps may be
regulated at either the inlet or outlet.
Where two units are required to operate in parallel, the governing
equipment should be slightly more sophisticated to provide for varying
the speed droop characteristic and allow orderly load sharing between
the units.
The rate of control of the flow must be limited to prevent excessive
pressure rise or drop in the water supply system. A too rapid rate of
movement of the turbine flow control gear can cause water hammer
which may lead to failure of the penstock. The balance between rate of
flow control with satisfactory speed regulation and pressure rise is a
function of closing and opening time, length of the penstock, velocity tn
the penstock and the inertia of the machine and the system if it
comprises more than a single unit. The following relationship gives an
indication of the necessity for pressure rise protection:
4-14
LX v ~ t
3Fi
where L = penstock length (meters)
V = Velocity of flow in penstock (meters/sec)
t Full stroke closing or deflecting time (sees)
H = Static Head (meters)
When the economics of the penstock size require that the velocity in it
is maintained at a level where 't' is greater than about 3 seconds
satisfactory speed control may be attained by increasing the inertia of
the rotating parts of the unit by the addition of a suitable flywheel.
The subject of pressure rise, pressure drop and speed regulation will not
be covered in this report but should always be checked to ensure
security of the system.
4.2.5 Suppliers
a. Offshore
The majority of manufacturers of established lines of standard
micro hydro units are offshore companies. There is a growing
number of small companies who provide a service to assemble
micro hydro generating unit packages using established turbine
designs or rehabilitated used equipment.
Some European turbine builders, appreciating the need to keep
equipment prices to a competitive level, have realized that mkro
hydro equipment design and manufacturing costs cannot carry the
high overhead structure of a plant capable of producing the
largest turbines being built today. To achieve this, the following
typical liaisons have been made:
4-15
Escher Wyss Bell (Switzerland)
Kvaerner Brug Sorum sand (Norway)
Voest-Aipine Kossler (Austria)
Tampella Leffel (Finland/USA)
Neyrpic Worthington (F ranee /USA)
A list of the turbine manufacturers known to be marketing
standard designs for micro hydro equipment is given in Table 4-1.
A complete list of turbine manufacturers is given in Appendix IV
together with the names of the offshore manufacturers' North
American representatives. As well, Appendix IV also contains the
names of some suppliers/installers of micro hydro equipment.
b. Canadian
There are three established turbine manufacturers in Canada:
Dominion Engineering Works Ltd., Montreal, P .Q.
ii Marine Industries Ltd., Sorel, P.Q.
iii Barber Hydraulic Turbine Ltd., Port Colborne, Ont.
Dominion Engineering Works have the capability to design
and build a complete range of water turbines. They have no
developed range of equipment designed specifically for
micro hydro and have not suggested that they are working
on such a project.
Marine Industries build turbines to the designs of Neyrpic,
Grenoble, France and have the capability of manufacturing
a complete range of water turbines. They have not ex-
pressed interest in producing the standard Right Angle Bulb
turbines being developed by Neyrpic, who have recently
entered into an agreement with Worthington U.S. on the
marketing of this equipment in the U.S.A.
4-16
Barber Hydraulic Turbine have the capability both for
designing and manufacturing micro hydro equipment and for
rehabilitating older plants. This company has recently been
acquired by Marsh Engineering.
A newcomer to the list of Canadian manufacturers is Dominion
Bridge Sulzer, Montreal, P.O. who wi II be manufacturing to
Escher-Wyss designs. The extent of their involvement in micro
hydro work is not known.
In addition to the manufacturers there are smaller companies
supplying micro hydro packages. These companies will assemble
the equipment using either rehabilitated plant or procuring new
equipment of established design. These companies are listed in
Appendix IV.
4.3 ELECTRICAL FACILITIES
4.3.1 Generators
a. Select ion of Type
This report deals with the development of isolated micro hydro
and is concerned only with synchronous AC generators.
Direct current generators may also be used for isolated systems
but normally they would be higher cost both initially and to
maintain and furthermore a DC system is not as safe to use as
A C.
If the micro hydro unit were to be connected to a larger
synchronous system an asynchronous generator should be con-
sidered since it would be less costly than a synchronous unit and
would be simpler to control.
4-17
Synchronous generators should be of rugged construction, mini-
mum class B insulated 60°C rise and complete with a bui It-in
rotating type static excitation system and automatic voltage
regulator.
The generator frequency should be 60 Hz so as to be compatible
with normal appliances and equipment available in Canada.
The selection of generator voltage will be dependent on several
factors such as size, characteristics of the load and whether a
transmission line is required. Up to approximately 500 kW the
most economical voltage rating is 120 to 600 volts. Beyond this
rating and up to 2000 kW a generator voltage rating of 2400 volts
may provide a lower total cost when the distribution equipment
and transmission system are considered.
If the generator is close to the load the generator voltage will
probably be the same as the load voltage. If the load is mainly
lighting the generator voltage could be 120/208 volt, however, if
mostly industrial the voltage could be 600 volt. If a transmission
line is required, which also involves transformation, then the
generator voltage is independent of the load voltage.
The selection of power factor will be dependent on the load and
the transmission line requirements.
b. Selection of Speed
The economics of indirect drive with a speed increaser for the
generator depend on turbine speed and output; they should be
investigated when the turbine speed is less than 600 rpm espec-
ially for units having outputs greater than 500 kW. In general, for
indirect drive, economics wi II predict that the generator speed
wi II be either 1200 rpm for outputs between 500 and 1250 kW or
900 rpm for outputs in excess of 1250 kW.
4-18
When making the evaluation, it must be recognized that the
inclusion of a speed increaser with the possibility of oil pumps and
heat exchangers, will require additional maintenance, will in-
crease the noise level and will reduce the overall unit efficiency
by about I -I /2 percentage points.
The generator must be capable of running for at least 2 hours at
the highest overspeed capability of the turbine without excessive
vibration, bearing damage or exceeding about 75 per cent of the
yield strength of the material in the rotating parts. The first
critical speed of the rotating elements should be at least 20 per
cent above the maximum overspeed which will be of the order of
1.8 to 2 times normal synchronous speed for Francis, Banki and
Impulse turbine prime movers. For propeller turbines, it may be
as high as 2.8 times normal speed.
4.3.2 Protection and Control
4.3.3
Protection and control must be provided for the turbine generator unit
in the form of failure and overload detection devices, relays, disconnec-
ting means and shutdown facility. The functional requirements will be
basically the same for all units considered, however, more sophisticated
equipment may be utilized for the larger sized units.
If two or more turbine generator units are to be installed provision must
be made for parallel operation. Synchronizing equipment will be
required and the units must be able to share the load.
Transmission Line
If the load is not adjacent to the power generating equipment a
transmission line will be required. Basically it will consist of an
overhead conductor system of sufficient capacity to deliver the load at
rated voltage and within specified voltage variation from no load to full
load.
4-19
Open type bare conductors on wood pole construction is normally the
most economical type of line. The size of conductor and line voltage
selected are dependent on the length of line and the total load
requirements.
Transmission line voltage for the shortest lines may be the same as the
generator voltage but normally transformation wi II be required at both
the generation and the load ends. For the loads and distance considered
in this study the line voltage should not exceed 13,200 volts.
4.3.4 Equipment Suppliers
a. Turbine Generator Units
For the micro hydro developments considered the turbine manu-
facturer wi II put together a standard package including the
turbine and the generator complete with excitation and automatic
voltage regulation. They will also include, if requested, the
protection and control equipment. This report and the supplier
lists included are made on this basis, however, it is also possible
to purchase the prime mover, the generator and the protect ion
and control separately from individual manufacturers.
b. Protection and Control
In order to assure that electrical equipment meets CSA standards
requirements and also that it can be readily maintained and
repaired it is preferable that the protection and control equip-
ment be obtained from a North American manufacturer. Some
representative manufacturers are included in the manufacturers'
list, Table 4-1 and others may be found in Appendix IV of this
volume.
4-20
c. Transmission Lines
Electrical Contractors local to the area will supply and install all
equipment associated with the transmission line system. Trans-
formation equipment can also be supplied by the Contractor or
can be obtained separately from the equipment suppliers refer-
enced in Appendix IV.
4-21
1.
2.
3.
4.
,::.. 5.
IV 6.
IV
7.
8.
9.
10.
ll.
12.
13.
14.
T.ABLE 4-1
DISIGJERS OP srANDA.~IZED MICRO HYOID TURBINES
Manufacturer Country
Allis-chal.Jrers USA
fu.rber Hydraulic Turbine Ltd. Canada
Eell Switzerland
Eofors-Nohab SwEden
Gilbert, Gilkes & Gordon England
Jyoti Limited India
~r..v Sweden
Kassler Austria
Leroy Scrner France
Neyrpic France
Ossberger Gern'kmy
ST\311 Hydro-electric Systems
& Equ i r:rnen t USA
Son.unsand-Verksted Norway
Tampella Finland
~~-
Types
Tubular Right
or Angle Banki Francis
Bulb 'lubular
X
X
X
X
X
X*
X
X
X
X
--~-. --
x Standard designs available
X* Coupled to asynchronous generators
(X) Standard under developuent
X
(X)
X
X
X
X
X
Turgo Pelton
(X)
X X
X X
X
(X)
-~~
_...._.
~
£:
"-...,.
~
<;:)
lt
5(}
40
30
10
9
8
7
6
5
4
2
1.0
0.9
0.8
0. 7 ~-
0.6
0.5
04
03
0.2
:
0./ -
.09-
.08 ~
.07 ~
.06
.05
.04
.03
.02
I 3
STANDARDIZED MICRO HYDRO TURBINES
SELECTION OF TYPE
i
i !
j-
!
I
j I --1
I
I
I ;
' i
l 1 I
-i
4 5 G 7 8910 20 30 4l] 50 70 90
1(;.,0 80 /(}(]
MET HEAD (metres)
(-) CRIPPEN CONSULTANTS
1 ' -~/v1 40:7 6D..J BX! !COO
-..vv 6!XJ 70tJ Joo
FIG. I
------------
FIG. 4-2
~=-CRIPPEN CONSULTANTS
SECTION 5
MICRO HYDRO
COST ESTIMATING
5. MICRO HYDRO COST ESTIMATING
5.1 GENERAL
A cost estimating method presented in Appendix II has been developed
to be used for micro hydro plants with heads ranging from 5 m to over
200m, and outputs from 10 kW to 2000 kW.
The objective of this cost estimating method was, given limited site
information and design criteria, to arrive at realistic order of magni-
tude capital cost estimates for prefeasibility studies.
The cost estimating method is essentially a step by step approach which
guides the user through costing each component of a considered micro
hydro project to arrive at a capital cost estimate which will in turn be
used as part of the prefeasibi!ity study.
The following components have been considered as being standard for
most micro hydro projects.
Access roads
Power Canal
Heaworks (intake structure, retaining dyke/overflow weir)
Penstock
Powerhouse (including mechanical & electrical equipment)
Transmission facilities
Dams to provide storage for flaw regulation purposes are normally too
expensive to be considered for micro hydro developments. Stream
diversions to reverse the flow at the power plant are also normally too
expensive for micro hydro projects.
Other project costs which have been considered in order to arrive at a
capital cost estimate include:
5-1
Engineering, management and construction supervision
Contingencies
Escalation from the base date of the cost estimating method to
the base date of the user's estimate
Escalation during construction
Interest during construction
No calculation of head loss is required for use in this manual as
hydraulic efficiency is included in the overall efficiency.
5.2 COST ESTIMATING METHOD
The cost estimating method is presented in Appendix II and is divided
into four distinct Sections:
A. General Comments.
B. Step by Step Approach.
This Section guides the user through the costing of each compon-
ent and of other project costs (as described above) to arrive at a
capital cost estimate.
C. Cost Estimating Procedure and Summary.
This Section contains tables which are to be filled in by the user
as he follows through the step by step approach in Section Busing
the graphs in Section D.
D. Cost Curve Assumptions, Graphs and Sketches.
Quantities and/or costs for components have been presented
graphically.
Graphs have been constructed for:
Quantities in terms of design parameters
Costs in terms of Quantity parameters (basic unit costs)
5-2
Adjustment curves for both quantities and costs whenever
applicable.
5.3 COST ESTIMATING LIMITATION
Even though micro hydro plant components are fairly standard, their
design and scope vary widely from site to site.
In order to keep the present method simple, certain assumptions had to
be made which are deemed adequate for order of magnitude estimates.
The accuracy to be expected from such estimates is in the order of.±. 40
per cent.
The accuracy range, however, could be decreased or increased depend-
ing upon the following factors:
The degree of information the user has on hand at the time of
preparation of his capital cost estimate.
The similarity of actual site characteristics to those assumed m
the cost estimating procedure.
The judgment of the user in evaluating site characteristics.
The user's assessment of other project costs, as described at the
end of Section 5.1, which are quite important in the overall
capital cost.
The degree of care taken in using the cost estimating method.
5.4 BASIC APPROACH TO COSTING CIVIL WORKS
Quantity take off, basic unit prices and adjustment factors have been
developed to generate the graphs and data necessary for the user to
prepare a capital cost estimate.
The assumptions used for construction material and component sizing
are set out in Appendix II Section D.
5-3
The various sketches presented in this Section form the basis for the
ca leu Ia ted quantities.
Basic unit cost curves have been developed by simulation of mid-range
project components. Adjustments thereafter have been made to
consider a lower and higher range in order to have at least three points
to plot a curve.
Adjustment curves have been developed to modify, whenever necessary,
the basic quantities or the basic unit cost curves. They take into
consideration different design parameters for quantity estimates and
different lengths and widths, etc. of given components for basic unit
cost estimates.
The civil works cost estimate has been divided into contractor's direct
and indirect costs and the total amount of contractor's direct costs is
necessary to assess the cost of contractor's indirect costs.
5.5 BASIC APPROACH TO ELECTRICAL AND MECHANICAL COST ESTI-
MATING
Cost estimates for electrical and mechanical equipment have been
developed from statistical data and in-house experience. They include
a provision for spare parts whenever applicable.
5.6 ENGINEERI~~G AND MANAGEMENT FEES
These usually vary between I 0 to IS per cent of the project cost
depending upon the size of the project and the scope of engineering and
management works. The user should select a fee percentage in
accordance with his own judgement.
5-4
5. 7 CONTINGENCY
This item is always quite difficult to assess and varies widely with the
degree of information avai !able at the time of the estimate.
If the characteristics of a considered micro hydro project fall reason-
ably within the scope of the cost estimating method, the following
contingencies should be used to arrive at a project budget cost.
Civi I Works 20%
Electrical & Mechanical 15%
Transmission Facilities 20%
Engineering & Management 10%
Should it be otherwise, the user should increase or decrease contingen-
cies in relation to his knowledge of the above items.
5.8 PRICE ESCALATION
The costs expressed in the cost estimating method are in January 1980
Canadian dollars.
Once the project cost is estimated in January 1980 Canadian dollars, it
m\JSt be adjusted to reflect:
the project cost for the user's base date and,
the cost of escalation thereafter up to the end of the construct ion
period.
Proper data for price escalation updating are often difficult to obtain in
a "ready to use" manner, even more so when dealing with order of
magnitude estimates which, by definition, are not precise enough to
isolate readily each element of the site.
5-5
It is suggested that the United States -Water and Power Resources
Services* indices for construction costs, published regularly in "Engin-
eering News Record", be used to estimate the rate of price escalations.
Using the appropriate indices, rates of price escalations can be obtained
and applied directly to individual component costs or to the total
project cost.
It can be assumed that the following time periods give an adequate
basis to determine price escalations.
Engineering study
Construction period
6 months to a year
6 months to a year
Indices based on current projects, to be used during the construction
period should be evaluated at the time of the estimate by a person
familiar with escalation trends. A rate of I 0 per cent per annum can be
assumed for an approximate assessment of escalation.
5.9 INTEREST DURING CONSTRUCTION
This should be calculated in terms of available interest rate at the time
of study and is left to the discretion of the user.
5.10 STEP BY STEP COST ESTIMATING METHOD
The user should now proceed to Appendix I! to carry out a complete
cost estimate of the proposed micro hydro site.
Appendix IX presents an actual site investigation using the procedures
outlined in this manual.
*Formally U.S. Bureau of Reclamation
5-6
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t.tb.'fl·----f-.o---pr>c">H Wlilpvf.-V ·---~-----pi!?<;~~-; M07 -----
Sr::?.Jf."?fy // /:'17•~11
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SECTION 6
FINANCIAL EVALUATION
6. FINANCIAL EVALUATION
6.1 METHOD
6.1.1 lntroduct ion
The intention of this section is to provide a method of financial
evaluation which will enable the user to assess the cost of micro hydro
generation and to compare the micro hydro project against alternative
means of meeting load demand. While diesel generation is emphasized
as the most likely alternative means of generation, the underlying
principles are valid for alternatives such as connection to a power grid.
The user is, therefore, at liberty to adjust the approach to suit his own
particular situation.
Three fundamental conditions must be met 1n order to produce a
competent financial evaluation:
a. The user must select an appropriate life span over which the
project w iII function.
b. Adequate allowance must be made for input price variations
throughout the project life span.
c. The costs of producing energy by hydro must be compared with
the cost of producing energy by the most attractive alternative
rr;eans over the common life span.
Each of these fundamental conditions is examined in turn in the ensuing
sub-sections.
6 -I
6.1.2 Life Span
In order to effect a fair comparison between alternative means of
generation it is necessary to adopt a common project life span and take
into account the costs associated with production during the entire
period. Whereas the life span of a hydro plant may be 30 years or
longer, the life span of individual diesel generator sets meticulously
maintained is not likely to exceed 20 years. External conditions may
dictate the selection of a life span less than 20 years if, for example,
power is required for a mining foci lity having a shorter life span. The
user should determine an appropriate life span bearing in mind the
above factors.
For the purposes of this manual, the evaluation calculation sheets have
been prepared on the basis of a 24 year life span. This life span,
although it may appear to be beyond the horizon of most investors, is
nevertheless consistent with the production of electricity on a continu-
ous basis. It allows a reasonable life span for hydro facilities and
equipment and at the same time offers convenience in computing costs
an the basis of two full life cycles for diesel generator equipment. The
user may, however, choose to depart from the above mentioned 24 year
life span according to his own particular situation.
While in practice individual diesel unit life spans could vary from the 12
year life cycle assumed in this manual, to a certain extent the effect of
the variations would be self-compensating in the analysis. If a shorter
life span of diesel units were anticipated, mare frequent capital
replace,nent costs would be offset by lower incurred major overhaul
costs. The reverse would hold true for longer life spans. If a longer
overall project life span were adopted in view of the expected better
performance of hydro plant, I itt le change in the outcome of the
financial analysis would result owing to the prevailing high discount and
interest rates.
6-2
6.1.3 Treatment of Input Price Variations
6.1.4
An acceptable method of handling different rates of inflation must be
used if a fair financial evaluation of a project is to be made.
In some studies, ongoing inputs such as fuel, labour and parts costs are
inflated throughout the project life using different anticipated inflation
rates for each project component. This method is cumbersome and
potentially confusing when it comes to the comparison of costs in
different years.
A more widely used and acceptable method is to value ongoing inputs
using dollar values appropriate to the beginning of the first year of
operation of the project, and to escalate only those prices which are
expected to differ from the general rate of inflation. Cost streams are
then valued in monetary units of constant purchasing power and the
user can relate costs in different project years without having to adjust
for inflation.
The input most likely to be subject to price escalation which will be
different to the general level of inflation is fuel costs. Current values
of the real price escalation of diesel fuel are discussed in Subsection
6.1.5.
Method of Evaluation
As stated in Subsection 6.1.1, the financial evaluation of a micro hydro
project requires that the costs of producing energy by hydro must be
compared with the costs of producing energy by the most attractive
alternate means. For remote communities in B.C. the realistic
alternatives are either diesel generation (by continuation of an existing
plant or installation of a new plant) or connection by the B.C.H.P.A.
system grid.
6 - 3
Year
0
2
3
Yy
Yz
The starting paint for a financial evaluation is the assembly of capital
and operating cost streams for both the proposed hydro project and the
alternative supply source. The difference in capital costs (incremental
cost of hydro over the alternative) is then examined in relation to the
anticipated operating cost savings (hydro operating costs are expected
to be lower than the alternative operating costs). A simplified picture
of 1he cash flows involved is given below.
TABLE 6-1
CASH FLOWS -HYDRO VERSUS ALTERNATIVE STUDY
2 3 4 5 6
Capital Operating Capital Fuel and Increment Operating
Cost Cost Cost Operating Capital Cost
Hydro Hydro Alternate Alternate Cost Savings
CH CD CH-CD
OH 1 ODI oD 1-oH 1
OH 2 OD2 OD 2 -0H2
OH3 OD3 OD3 -0H3
OH CD OD -CD OD -OH y y y y y y
OH OD OD -OH z z z z
A hydro project would be viable if the expenditure on the incremental
capital costs (Col. 5) are justified qy the operating cost savings stream
{Col. 6).
The evaluation recommended herein uses the above cost stream data to
compute three criteria for evaluation:
I. Capital and Operating Costs Streams for the hydro project
(Columns I and 2) and the alternative means of supply (Columns 3
6-4
and 4) enable the computation of unit energy costs for each year
of the project life. Unit energy costs so calculated can be
compared. Usually, hydro unit energy costs decrease over the life
of the project whereas diesel plant unit energy costs increase over
the life of the project, so a direct comparison of unit energy costs
alone is not sufficient for a financial evaluation.
2. Payback periods can be computed from the incremental cost
streams (Columns 5 and 6). This can be done on a before tax basis
or an after tax basis using current or anticipated capital cost
{depreciation) allowances. Although payback criteria are widely
used in industry, they do not take into account the time value of
money.
3. The internal rate of return on incremental investment can be
calculated from the incremental cost streams (Column 5 and 6).
This method provides the user with the most valuable criterion by
which to justify the additional capital expenditures required in a
micro hydro project.
The following Sections describe in more detail the procedure required.
Since a diesel plant is likely to be the most attractive alternative
means of supply in remote B.C. communities, the evaluation sheets and
cost data given in this Section and in Appendices VI and VII have been
prepared accordingly. The user is assumed to have calculated the
capital cost of the hydro project (Column I in Table 6-1) prior to
undertaking the financial evaluation. Appendix VI contains capital cost
data and operating and maintenance cost data which will t;>e useful for
determination of diesel plant capital costs and hydro and diesel plant
operating and maintenance costs required for the evaluation (Columns
2, 3 and 4 in the above cash flow table).
Appendix VII contains computation sheets to assist the user in compiling
the cost data and calculating the above described three evaluation
6-5
criteria. It is recommended that the user familiarize himself with the
computation sheets in Appendix VII prior to proceeding.
6.1.5 Select ion of Values of Study Variables
a. Interest Rate for Calculating Unit Energy Costs
In the determination of unit energy costs an appropriate interest
rate must be established to calculate the annual cost equivalent
of capital investment required for each alternative. In the case
where capital is obtained from borrowing, the interest rate is used
to determine annual debt servicing costs. Where capital is
obtained from within the owner's corporate structure, the interest
rate is used to determine the annual return on equity. The value
to be used can be either the current long term interest rate on
borrowed capital ( 1979/1980 values are around I 0-14 per cent) or
if there are competing demands for capital within the owner's
corporate structure, the opportunity cost of capital may be
employed.
b. Fuel Costs
Current 1980 prices for diesel fuel at supply sources within B.C.
are around 18 cents/litre. To this price should be added the cost
of delivery, which for a round tanker trip of 300 kilometres would
add another 2 cents/litre to the price.
c. Real Price Escalation of Fuel
In order to account for the fact that diesel fuel prices are
currently increasing at a rate greater than the general inflation
rate it is necessary to escalate fuel prices in the project evalua-
tion. Currently real price escalations for diesel fuel of 5-10 per
cent above the general inflation rate are being experienced;
however, long term real price escalations are not expected to be
6-6
so high. Recent studies have used long term real price escalation
values of around I-1/2 per cent per annum. It is recommended
that a compound rate of 1-1/2 per cent per annum be used if more
accurate data is unava i lab I e.
d. Capital Cost Allowance
The user should determine the depreciation allowance appropriate
to his particular application. The computation sheets contained in
Appendix VII have been prepared for two depreciation cases.
Case 2 as shown in the sheets refers to the pre 1980 depreciation
rules where hydro and diesel plants were depreciated at 6 per cent
per annum on declining balance. Case 3 as shown in the sheets
reflects the two year write-off provision for micro hydro plants
which was recently enacted by the Federal Government. In Case
3, diesel plants, whether for the alternate supply or for a hydro
plant with supplementary diesel, is still depreciated at 6 per cent
per annum on declining balance. The user may wish to neglect
Case 2 in view of its historical perspective.
e. Tax Rate
The user should determine the anticipated tax rate applicable to
his proposed project. The computation sheets contained in
Appendix VII have been prepared on the assumption of a 50 per
cent tax rate.
6.2 HYDRO PLANT GENERATION COSTS
The user is referred to Figure VII-I in Appendix VII for calculation of
the hydro-plant Generation Costs. The computation sheet provides two
alternative means of calculation -one for the case where hydro
capacity alone is sufficient to meet demand, and the other where
supplementary diesel energy is required. Notes covering the correct
approach to computing each cost stream are provided as follows:
6-7
a. Capitol Costs-Columns 2 and 3 or 10
Capitol costs must be entered in the year in which they ore
incurred, starting with plant on-line at the end of year zero.
Capital costs estimates for supplementary diesel plant capacity
con be obtained from Appendix VI.
b. Debt Retirement Costs -Columns 4 and 5 or II
Debt retirement costs (otherwise referred to as amortization
costs, or capital recovery costs) are the annual cost equivalent of
the capital cost. In the tables, short term debt retirement refers
to diesel generators only which have a life cycle less than the
assumed project life.
c. Fuel and Operating and Maintenance Costs (Columns 6 and 7 or
m
Fuel costs in Column 6 refer to the fuel needed to provide the
supplementary energy in the case where hydro alone cannot meet
the demand. Operating and Maintenance Costs estimating data is
contained in Appendix VI.
d~ Unit Energy Costs -Columns 9 or 14
Unit energy costs are obtained by dividing total annual costs
(Column 8 or Column 13) by the energy demand.
6.3 ALTERNATIVE GENERATION COSTS
The user is referred to Figure Vll-2 in Appendix VII for calculation of
the alternative generation costs. Although the most attractive alterna-
tive means of power supply at some locations could be by connection to
the B.C.H.P .A. grid, the computation sheets were prepared on the basis
6-8
of diesel generation. Notes covering the correct approach to computing
each cost stream are provided as follows:
a. Capital Costs -Columns IS and 16
The user is referred to Appendix VI.
b. Debt Retirement Costs -Columns 17 and 18
Debt retirement costs (otherwise referred to as amortization
costs or capital recovery costs) are the annual cost equivalent of
capital costs. Column 17 refers to debt retirement over the
assumed project life span, while Column 18 refers to debt
retirement over the life cycle of the diesel-generator units.
c. Fuel and Operating and Maintenance Costs -Columns 19 and 20
The user is referred to Appendix VI for fuel and operating and
maintenance cost estimating data.
d. Unit Energy Costs -Column 22
Unit energy costs are obtained by dividing total annual costs
(Column 21) by the energy demands listed in Fig. VII-I.
Unit energy costs obtained for the hydro system and for the alternative
(diesel only) system may be plotted on the graph given in Fig. Vll-2 for
comparison purposes.
6.4 PAYBACK EVALUATION
The user is referred to Fig. Vll-3 in Appendix VII for calculation of the
payback periods. The figure is self explanatory. The user should
establish his own current capital cost allowance rates and tax rates for
use in the tables.
6-9
6.5 INTERNAL RATE OF RETURN EVALUATION
The user is referred to Fig. Vll-4 in Appendix VII for calculation of
internal rates of return. The data for use in this table is obtained from
Figure Vll-3. Calculation of internal rates of return is accomplished by
discounting the incremental capital cost stream for different trial
discount rates, and plotting a curve of present value against discount
rate. Annual cost saving streams are then discounted and similarly
plotted. The internal rate of return is the discount rate at which the
present value of incremental capital costs is equal to the present value
of the annual cost savings.
6.6 SENSITIVITY
Having completed the financial evaluation for a proposed project the
user should investigate the sensitivity of the outcome (unit energy
costs, payback periods, internal rate of return) to variations in the
major study inputs. Sensitivity calculations should be carried out for
the following:
a. Capital cost increase of Hydro of 25 per cent.
b. Diesel fuel starting price and real price increase variations.
c. Variations in the assumed energy demand project ions.
d. Variations in the assessed water supply.
6.7 SAMPLE FINANCIAL EVALUATION
A sample financial evaluation is presented in Appendix IX in order to
demonstrate the evaluation techniqu'e.
6-10
APPENDIX I
SITE INVESTIGATION ASSESSMENT
A Genera I Data
8 Water Availability
c Construction Materials
D Site Selection
E Equipment Selection Data
F Power Avai !able
APPENDIX I
MICRO HYDRO STUDY
SITE INVESTIGATION ASSESSMENT
A. GENERAL DATA
I . Location Latitude
Longitude
District Lot No. or other references
2. Elevation (m)
above MSL
3. Winter Conditions-Total snowfall (m)
Months of heavy snow
Degree days October-March incl. (°C-days)
Mean Daily Minimum Temperature (°C)
4. Population
5. Number of houses
6. Types of industry and numbers employed
7. Anticipated Load
8. Present Load
Average
Peak
Average
Peak
I-I
kW ----
kW ----
____ kW
____ kW
APPENDIX I
9. Access to Site (bridge capacities, underpass heights, airfields,
road standard, possibility for sea or lake access).
10. Availability of labour (classification and source/town).
II. Availability of contour mapping, aerial photography, geological
mapping. List maps used in the study.
I - 2
APPENDIX I
B. WATER AVAILABILITY
CATCHMENT AREA
I. Period of streamflow records in catchment and Gauge No.
Period of streamflow records in nearby catchment and Gauge No.
2. Period of prec ip it at ion records in catchment.
3.
Period of precipitation records in nearby catchment.
Data for flow durot ion Curve: Generated YES NO
(Use method set out in "Water Resources Development11 by E. Kuiper,
P. 30)
% OF TIME EQ. OR EXCEED.
100% (Firm)
95%
50%
4. Spot measured flow.
5.
6.
m 3 /sec Proposed diversion point measured flow
Date of measurement
--------
------------------
Is regu lot ion to be used? YES NO
Will an existing structure (dam) be used YES NO
Estimate of storage m3
Firm flow (using regulation) m 3!s
Eyewitness accounts:
maximum flood levels Dates
minimum water levels Dates
ice formation,
thickness and extent Dates
1-3
APPENDIX I
7. Existence and value of fish in the stream.
8. Notes from field inspection.
Water quality:
wastes, chemicals (is there industry dumping effluent
upstream)
sea water contamination
sand/silt content (turbidity at time of inspection)
debris
air temperature (°C)
I-4
APPENDIX I
C. CONSTRUCTION MATERIALS
I. Availability of aggregate (sources).
2. Gradation and petrographic analysis results of aggregates
(gravel and sand).
3. Availability of lumber
(source)
i)
ii)
green or fresh cut
seasoned
iii) dried
4. Availability of cement (source).
5. Is there a concrete plant (source)?
Does it have a precasting yard?
I - 5
APPENDIX I
D. SITE SELECTION
I. Diversion weir and intake:
a. Length of weir
b. Maximum height
c. Foundation conditions soil
rock
d. Site description
e. Access
2. Power Canal:
a. Length
b. Conditions soil
rock
c. Site Description
d. Access
3. Penstock:
a. Length
b. Conditions soil
rock
c. Site description
d. Access
4. Transmission Line:
G. Length
b. Conditions soil
rock
c. Site description
d. Access
1-6
D. 5.
6.
APPENDIX I
Powerhouse:
a. Foundation conditions
b. Area for Switchyard
c. Site Description
d. Access
Tailrace:
a. Length
b. Conditions soil
rock
c. Site description
I - 7
soil
rock
APPENDIX I
E. EQUIPMENT SELECTION DATA
I. General Measurements:
a. Tailwater elevation (above sea level) ______ m
b. Headwater elevation (FSL) (above sea level) ______ m
c. Gross head (vertical distance between headwater level
(FSL) and tai (water level) ______ m
2. Water Level Variations:
a.
b.
Tailwater elevation from
Headwater elevation (FSL)
from
3. Mode of Operation:
m to ---___ m
m to ---___ m
Will plant operate on an isolated power grid? YES NO
If no, state: Frequency Hz
Tension V
Type of existing system isolated Diesel-Electric
isolated Hydro-Electric
Capacity of existing system kW
1-8
APPENDIX I
F. POWER AVAILABLE
Design discharge
Gross head
Power (P)
m 3 /s (from 8.3 or 8.5) -------
_______ m (from I)
= design discharge (Q) x gross head (H) x specific
weight of water x efficiency
-specific weight of water = 9.8 kN/m 3
let specific weight of water x efficiency= 7
(this will assume an efficiency of 0.71 for the
entire system, i.e. all losses lumped together)
P = 7QH (in kW}
p = 7x x --- ---
= ___ kW
I-9
APPENDIX II
STEP BY STEP COST ESTIMATING METHOD
A General
B Step By Step Approach
C Micro Hydro Cost Estimating Procedure and Summary
D Cost Curve Assumptions
FIGURES
11-1 Access Roads-Overburden Excavation -Basic Unit Cost
11-2 Access Roads-Overburden Excavation -Cost Adjustment Factor For
Road Width
11-3 Access Roads -Overburden Excavation -Cost Adjustment Factor For
Road Length
11-4 Access Roads -Rock Excavation -Basic Unit Cost
11-5 Access Roads-Rock Excavation-Cost Adjustment Factor For Road
Width
11-6 Access Roads-Rock Excavation -Cost Adjustment Factor For Road
Length
11-7 Unlined Power Canal -No Ice Cover -Basic Excavated Unit Volume
11-8 Unlined Power Canal -Ice Cover -Basic Excavated Unit Volume
11-9 Unlined Power Canal -Adjusted Excavated Volumes
11-10 Lined Power Canal -No Ice Cover-Basic Excavated Unit Volume
11-11 Lined Power Canal-lee Cover-Basic Excavated Unit Volume
11-12 Lined Power Canal-Adjusted Excavated Volumes
11-13 Lined or Unlined Power Canal -Basic Unit Excavation Cost
-I -
11-14 Lined or Unlined Power Canal -Excavation Cost Adjustment Factor
For Length
11-15 Lined Power Canal -No Ice Cover -Concrete Lining Volume
11-16 Lined Power Canal -lee Cover -Concrete lining Volume
11-17 Lined Power Canal -Basic Unit Concrete lining Cost
11-18 Lined Power Canal-Concrete Lining Cost-Adjustment Factor For
Length
11-19 Headworks-Gabion Weir-Basic Unit Cost
11-20 Headworks-Gabion Weir -Cost Adjustment Factor For Crest Length
11-21 Headworks -Intake Structure -Installed Cost
11-22 Penstocks -Discharge vs Inside Pipe Diameter
11-23 Penstocks -Basic Unit Cost
11-24 Penstocks-Cost Adjustment Factor For Length
11-25 Penstocks-Cost Adjustment Factor For Slope
11-26 Powerhouse -Civil Works Direct Costs
11-27 Power Unit -Installed Electrical and Mechanical Costs
11-28 Transmission Line-Installed Unit Cost
11-29 Contractor's Indirect Costs -As a Percent of Direct Civil Works Cost
11-30 Access Road and Unlined Canal Sections
II-31 Lined Can a I Sect ions, Penstock Trench and Excavation Sect ions
11-32 Headworks -Gabion Weir
11-33 Headworks -Intake Structure
11-34 Line Diagram of Typical Layouts
11-35 Low Head-Low/High Output Type-Tubular Turbine
11-36 Low Head-Medium Output Type-Right Angle Bulb Turbine
11-37 Low & Medium Head -Low Output Type-Two Jet Hydec Turbine
11-38 Low & Medium Head-Low & Medium Output Type-Banki Turbine
11-39 Low & Medium Head-Medium Output Type-Horizontal Francis in
Drum
11-40 Medium Head-High Output Type-Horizontal Francis in Spiral
-ii -
APPENDIX II
MICRO HYDRO STUDY
STEP BY STEP COST ESTIMATING METHOD
A. GENERAL
Prior to going through this method, the user should be familiar with the
project under consideration and be in a position to assign values to the
various parameters necessary for performing the capital cost estimate.
The accuracy of the capital cost estimate will depend on the accuracy
of the user's input.
Section B guides the user through this method and indicates the proper
procedure for costing of each component of the project. Reference is
made to the graphs necessary to obtain the desired information.
Section C contains procedure sheets which are to be filled in by the
user as he follows through the step by step approach in Section B. Also,
in Section C is a cost estimating summary sheet which can be filled in
by the user once the procedure sheets are completed.
Section D contains assumptions, graphs and sketches used in the cost
estimating procedure.
This method, if carefully used, will provide an acceptable accuracy for
prefeasibi lity studies.
II -I
APPENDIX II
B. STEP BY STEP APPROACH
B.l Access Roads
Basic Assumptions: Light traffic roads, gravel type.
Section A in Fig. 11-30 for cut through overburden material
Section B in Fig. ll-30 for cut through rock
Cost includes -clearing & grubbing
cut & fi II & compact
gravel surfacing
minimum provision for drainage
ii Basic Data Required From the User:
-length of road in metres
-per cent of length in overburden and rock material
-evaluation of average ground cross slopes for each
materia I or length
iii Road Requiring Overburden Excavation
Basic Unit Cost: See Fig. Il-l
Basis:
-I 000 m long road
-3m wide road
-variable ground cross slope
Adjust Unit Cost to Reflect Different Basis for:
-road width Se~ Fi~. 11-2
-road length See Fig. 11-3
iv Road Requiring Rock Excavation
Basic Unit Cost: See Fig. 11-4
Basis:
-I 000 m long road
-3m wide road
-variable ground cross slope
II - 2
APPENDIX II
B. STEP BY STEP APPROACH-(Cont'd)
B. I Access Roads -(Cont'd)
Adjust Unit Cost to Reflect Different Basis for:
road width See Fig. 11-5
road length See Fig. 11-6
B.2 Unlined Canal
Basic Assumption: Excavation through overburden material.
Basic quantities and cost based on:
Section C of Fig. 11-30 for canal excavation with a I: I side cut slope
(a IH:5V side cut slope shown in Section D of Fig. 11-30 is treated as
a quantity variation below).
Cost includes: clearing & grubbing
cut & fi II & compact as required
excavated material considered reused
as fi II or disposed of within 750 m
excavation in the dry
ii Basic Data Required From the User:
II - 3
length of unlined canal in metres
basic cross-section or Section D of
Fig. 11-30 (if different from basic
assumption)
discharge in m 3 Is
evaluation of average ground cross
slope
APPENDIX II
B. STEP BY STEP APPROACH-(Cont'd)
B.2 Unlined Canal -(Cont'd)
iii Preliminary Steps Prior to Costing
iv
Establish the excavated volume per linear metre of canal for a given
discharge, an estimated average ground cross slope, and a side cut
slope of I: I. Select appropriate graph for a case with or without ice
cover.
no ice cover case:
ice cover case:
See Fig. 11-7
See Fig. 11-8
Adjust excavated volume per metre of canal if selected canal
cross-section is the same as Section D of Fig. 11-30 instead of
Section C in Fig. 11-30, using Fig. 11-9.
Basic Unit Cost: See Fig. 11-13
Basis: I 000 m long can a I
v Adjust Unit Cost to Reflect Different Basis For:
canal length See Fig. 11-4
B.3 Lined Canal
Basic Assumptions: Excavation through overburden material.
Concrete lined canal.
Basic quantities and cost based on:
Section A in Fig. 11-31 for canal excavation with a l:lside cut slope
(a I H:SV side cut slope shown in Section B of Fig. 11-31 is treated as
a quantity variation below).
Cost is broken down into excavation and concrete lining and
includes:
11-4
APPENDIX II
B. STEP BY STEP APPROACH -(Cont'd)
B.3 Lined Canal -(Cont'd)
Excavation
Concrete Lining
clearing & grubbing
cut & fi II & compact as required
excavated material considered reused
as fill or disposed of within 750 m
excavation in the dry
levelling and compacting of ground
interface surface
I 0 em thick concrete slab
waterproofing of construction joints
ii Basic Data Required From the User:
length of lined canal
basic cross-section or Section B of Fig. 11-31 (if different from
basic assumption)
discharge in m3 Is
evaluation of average ground cross slope.
iii Preliminary Steps Prior to Costing
Establish the excavated volume per linear metre of canal for a given
discharge, an estimated average ground cross slope, and a side cut
slope at I: I. Select appropriate graph for a case with or without ice
cover.
no ice cover case:
ice cover case:
SeeFig.ll-12
See Fig. 11-13
Adjust excavated volume per metre of canal if selected canal
cross-section is the same as Section B of Fig. 11-31 instead of
Section A of Fig. 11-31, using Fig. 11-12.
to find out the concrete lining costs, establish required con-
crete volume per metre of canal for a given discharge and
select appropriate curve for a case with or without ice cover.
II -5
APPENDIX II
B. STEP BY STEP APPROACH (Cont'd)
8.3 Lined Canal -(Cont'd)
no ice cover case
ice cover case
See Fig. 11-15
See Fig. 11-16
iv Basic Unit Costs:
Basis:
for excavation cost See Fig. 11-13
for concrete cost See Fig. 11-17
I 000 m long can a I
v Adjust Unit Costs to Reflect Different Assumption For:
Canal length:
for excavation
for concrete lining
B.4 Headwork Structure
See Fig. 11-14
See Fig. 11-18
B.4.1 Retaining Dyke/Overflow (Gabion) Weir Structure
Basic Assumptions: The cross-section shown in Fig. 11-32 has been
selected for the purpose of cost estimating.
The cost includes:
foundation preparation
supply and install gabions
supply and place fill materials (considered to be found within
500 m)
supply and install impermeable membrane with protective
riprap layer
supply and place protective concrete slab on the crest
II - 6
APPENDIX II
B.4.1 Retaining Dyke/Overflow (Gabion Weir Structure)-(Cont'd)
ii Data Required From the User:
iii
average height of dyke
average crest length of dyke
Basic Unit Cost: See Fig. 11-19
Basis:
crest 25 metres long
iv Adjust Unit Cost to Reflect Different Assumption For:
crest length See Fig. 11-20
8.4.2 Intake Structure
Basic Assumptions: Referring to Fig. 11-33
the intake is designed to be a free standing structure
a single intake is considered usable up to I 0 m 3!s discharge
the intake is considered to have a manually controlled gate
a trashrack is provided as are slots for stop logs.
for safety, this intake is to be fenced in
ii Data Required by the User:
discharge in m 3/s.
iii Installed Cost of the Complete Structure: See Fig. 11-21
II - 7
APPENDIX II
B. STEP BY STEP APPROACH-(Cont'd)
B.S Penstock
Basic Assumptions:
steel conduits have been selected as the basis for cost
estimating. They are considered butt welded and buried in a
trench (see Section C of Figure 11-31) for penstocks with
slopes less than 30% or installed above ground for penstocks
having a slope equal or greater than 30%.
In all cases, handling stresses and corrosion provisions have
been the predominant factors in calculating pipe wall thick-
nesses.
Cost items for penstock with slope measured along the penstock
of less than 30%;
Excavation
Steel conduit
clearing, grubbing and stripping
trench excavation
backfill
supply and install
Cost items for penstock with slope measured along the penstock
equal or greater than 30%;
as above whenever applicable
Concrete pedestals and anchoring systems for steel conduit
supplied and installed.
ii Basic Data Required by the User:
discharge in m 3 Is
length of penstock for slope less than 30%
length of penstock for slope equal or greater than 30%
II - 8 '
APPENDIX II
B. STEP BY STEP APPROACH-(Cont'd)
B.S Penstock -(Cont'd)
iii Penstock Inside Diameter:
Figure 11-22 gives an approximate penstock diameter in relation
to the design discharge. This curve is provided in the manual for
information purposes only.
iv Basic Unit Costs
See Figure 11-23
Basis: I 000 m long penstock and 30% average slope
v Adjust Unit Cost to Reflect Different Basis For:
penstock length
penstock slope(s)
B.6 Powerhouse
Basic Assumptions:
See Figure 11-24
See Figure 11-25
Given a head and an installed power output in kW,
Civil works quantities and costs are based on Fig. 11-35 to
11-40 and include: excavation works
substructure works
superstructure works
yard and fencing
Mechanical cost includes:
II - 9
valves, turbine, regulation and
control
APPENDIX II
B. STEP BY STEP APPROACH-(Cont'd)
8.6 Powerhouse-(Cont'd)
Electrical cost includes:
ii Data Required From the User:
gross head in metres
discharge in m 3 /s
generator, excitation, and AVR
(Automatic Voltage Regulation)
generator protection and control
generator cabling
station service
sending and receiving end trans-
formers
installed plant capacity in kW
iii Plant Cost:
Civil works
Electrical and Mechanical
B.7 Transmission Line
Basic Assumptions:
See Fig. 11-26
See Fig. 11-27
Given a distance in kilometres and total power cielivered m
kilowatts, the transmission line cost includes:
wooden poles (class 2, butt treated)
wooden cross arms
II -10
APPENDIX II
B. STEP BY STEP APPROACH -(Cont'd)
B.7 Transmission Line-(Cont'd)
NOTE:
galvanized steel hardware
insulators and ACSR (Aluminum Cable Steel Reinforced)
conductors
installation
ii Data Required From the User:
total power to be transmitted in kW
total length of line in km
iii Basic Unit Cost:
multiply power (kW) by length (km)
apply this product to Fig. 11-28, reading horizontally to
select the lowest cost vs line voltage
select the nearest ACSR conductor size equal to or greater
than that size appearing opposite the selected cost. Use the
corresponding cost figure as the Basic Unit Cost.
AT THIS STAGE IT IS POSSIBLE TO SUMMARIZE ITEMS B.l TO B.7
JUST COSTED ONTO THE SUMMARY SHEETS C.2 USING INFORMA-
TION FROM THE PROCEDURE SHEETS C. I.
II -I I
APPENDIX II
B. STEP BY STEP APPROACH -(Cont'd)
B.8 Contractor's Indirect Costs (Civil Works Only)
Basic Assumptions:
Indirect costs comprise the following items:
Site Indirect Costs
site supervision and administration
handling on site
mobilization and demobilization cost
transportation of personnel during construction.
It is considered that the site would be within 50 km of a
town and therefore camps would not be necessary. This
item covers daily cost of transportation to the site
including travelling time.
bonds and insurance
contractor's fixed fees, including taxes on profit
cost of working capital
Note: provincial and federal sales taxes are included in the
unit costs whenever applicable.
ii Preliminary Steps Prior to Costing:
determine total direct cost of civil works by summanz1ng
the cost of all civil work components (items 1.1 to 6.1 on
sheet C.2}.
iii Determine Contractor's Indirect Cost Percentage: See Fig. 11-29
use this percentage to calculate contractor's indirect costs
(on sheet C.2}.
II-12
APPENDIX II
B. STEP BY STEP APPROACH-(Cont'd)
B.9 Price Escalation
Price Escalation to Date:
The estimate generated using the cost curves presented herein
will produce a cost estimate in January 1980 Canadian dollars.
Since escalation has been significant in the recent past, it is
necessary to update the result given by these curves to reflect
today's cost.
For the purpose of order of magnitude estimates, it is suggested
that price escalation be calculated using the United States Dept.
of Interior, Water and Power Resources Services* (WPRS) con-
struction cost index published regularly in the Engineering News
Records. It is felt that even though the indices shown represent
the U.S. trend, it is a reasonable representation of the Canadian
market as well.
The price escalation may be arrived at by using the composite
index or the indices for types of works or structures within the
project. Should the user choose to calculate price escalation by
structures, it is suggested that the estimate be broken down into
the following components listed in the USBR indices:
Access Roads
Canal -earthworks
Dam -structures (for headworks)
Stee I penstocks
Power plants, hydro -buildings and equipment
Transmission lines, wood poles
*Formerly United States Bureau of Reclamation (USBR)
II -13
APPENDIX II
B. STEP BY STEP APPROACH-(Cont'd)
B.9 Price Escalation-(Cont'd)
Engineering and Management should be included in the above
items proportionally.
ii Price Escalation During the Construction Period
It is assumed that most micro hydro projects under consideration
would be constructed within a year. Therefore, half of the
anticipated price escalation for that year should be applied to the
project cost.
Should the construction period be different, then adjust accord-
ingly.
II -14
APPENDIX II
C. MICRO HYDRO COST ESTIMATING PROCEDURE AND SUMMARY
C.l COST ESTIMATING PROCEDURE (Working Sheet Ill)
BASIC DATA
Micro Hydro Site Name:
Available Head (m):
Design Discharge (m 3 /s):
Installed Power Plant Capacity (kW):
Access Roads -Length (m):
Width (m):
Type of Material: Overburden
(As % of Total Length)
Rock
Average Ground Cross Slope (%): In 0/B
(%): In Rock
Power Can a I -Total Length (m):
Average Ground Cross Slope(%):
Type of Materia I & % of Total Length
%Lined %Unlined
Ice Cover No Ice Cover
Gabion Weir -Average Height (m):
Crest Length (m):
Penstock -Length (m):
Length @ less than 30% slope
Length@ more than 30% slope
Transmission Line -Length (km):
II -IS
C. I COST ESTIMATING PROCEDURE (Cont'd) Working Sheet 112
Item Figure
Number Cost Component Desrription Number Unit Value
CIVIL WORKS COST ESTIMATING PROCEDURE
1.0 ACCESS ROADS
I. I EXCAVATION IN OVERBURDEN
a Basic Unit Cost II -I $/m
b Adjustment for Width II - 2 Factor
c Adjustment for Length II - 3 Factor
d Adjusted Unit Cost 1.1 (a x b x c) $/m
1.2 EXCAVATION IN ROCK
a Basic Unit Cost II - 4 $/m
b Adjustment for Width II - 5 Factor
c Adjustment for Length II - 6 Factor
d Adjusted Unit Cost 1.2 (a x b x c) $/m
2.0 UNLINED CANAL
a Basic Excavated Volume 11-7orll-8 m 3 /m
b Adjusted Excavated Volume II - 9
3 m /m
c Basic Unit Cost of Excavation II-13 $/m
d Adjustment for Length II -14 Factor
e Adjusted Unit Cost 2.0 (c x d) $/m
3.0 LINED CANAL
a Basic Excavated Volume 11-10 or II 3 m /m
b Adjusted Excavated Volume II-12 3 m /m
c Basic Unit Cost of Excavation II-13 $/m
d Adjustment for Length If -14 Factor
e Adj. Excavation Unit Cost (c x d) $/m
II-16
C. I COST ESTIMATING PROCEDURE (Cont'd) Working Sheet 113
Item f-igure
Number Cost Component Description Number Unit Value
CIVIL WORKS COST ESTIMATING PROCEDURE (CONT'D)
3.0 LINED CANAL (Cont'd)
f Concrete Lining Volume 11-15 or 16 m 3 /m
g Basic Concrete Lining Cost II-17 $/m
h Adjustment for Length II-18 Factor
i Adjusted Lining Unit Cost (g X h) $/m
j Adjusted Unit Cost 3.0 (e + i) $/m
4.0 HEAD WORKS
4.1 GABION WEIR
a Basic Unit Cost II-19 $/m
b Adjustment for Length II -20 Factor
c Adjusted Unit Cost 4.1 (a x b) $/m
4.2 INTAKE STRUCTURE
a Total Cost 4.2 II -21 LS
5.0 PENSTOCK
a Required Inside Pipe Diameter II -22 mm
b Basic Unit Cost II -23 $/m
c Adjust for Length II -24 Factor
d Adjust for Slope II -25 Factor
e Adjusted Unit Cost 5.0 (b XC X d) $/m
6.0 POWERHOUSE
6.1 POWERHOUSE (CIVIL WORKS)
a Total Cost 6.1 II -26 LS
II -17
C.l COST ESTIMATING PROCEDURE (CONT'D) Working Sheet 114
Item figure
Number Cost Component Description Number Unit Value
CIVIL WORKS COST ESTIMATING PROCEDURE (Cont'd)
6.0 POWERHOUSE (Cont'd)
ELECTRICAL AND MECHANICAL COST
ESTIMATING PROCEDURE
6.2 POWERHOUSE (ELECT & MECH}
a T ota! Cost 6.2 II -27 LS
7.0 TRANSMISSION LINE
a Total Cost 7.0 II -28 $/km
II -18
C.2 COST ESTIMATING SUMMARY (User Sheets)
·Item Unit
Number Cost Component Description Unit Quantity Cost Cost
I .I Access Road Through Overburden m
1.2 Access Road Through Rock m
2. Unlined Canal m
3. Lined Canal m
4.1 Gabion Weir m
4.2 Intake Structure LS
5. Penstocks
-Slope <30% m
-Slope? 30% m
6.1 Powerhouse Civi I Works LS
Sub Total Civil Works Direct Costs
Contractor's Indirect Costs* %
TOTAL CIVIL WORKS COSTS
6.2 Powerhouse (Elect. and Mech.) LS
7. Transmission Line km
TOTAL (ITEMS I TO 7)
8. Engineering and Management % 10
(%of Total (Items I to 7))
9. Contingencies:
Civil Works % 20
(% of Total Civi I Works Costs)
Powerhouse (Elect. and Mech.) % IS
(%of Item 6.2)
Transmission Line % 20
(%of Item 7)
Engineering and Management
(%of Item 8) % 10
*Using Graph 29
II-19
C.2 COST ESTIMATING SUMMARY (Cont'd)
Item Unit
Number Cost Component Description Unit Quantity Cost Cost
I 0. PROJECT COST IN JANUARY 1980 CANADIAN DOLLARS I l
Price Escalation to Start of Construction Date
Cost of Interest During Construction
Price Escalation During Construction (E.D.C.)
Cost of Interest on E.D.C.
II. TOTAL CAPITAL COST: I I
II -20
APPENDIX II
D. COST CURVE ASSUMPTIONS
D.l Road Cut Excavation Design
The road cut excavations are shown in Figure 11-30. They are
simi lor except that the exposed cut has different values, I: I to
represent most types of overburden soil, and I H:5V to represent
more competent overburden materials (e.g. gravel) or rock exca-
vations.
The cross-sections have varying values of ground cross-slope.
The width of the cut B, is also considered to be the width of the
road, although the road is seated on both the excavation and the
fill section (as shown in the figures) to make allowance for a ditch
approximately 1.0 metres wide.
The road will have a gravel base 0.30 metres thick.
The fill section will be compacted and the slope will be set by the
natural angle of repose of the fi II material.
D.2 Unlined Canal Design
General Considerations
designed using an average velocity for a canal cross-section.
The velocity chosen was that considered to be an upper limit
non-scouring velocity for erodible material and was set at
V = 0.67 m/s.
Canal side slopes were set at 1.5 horizontal to 2.0 vertical
(i.e. 1.5: I). This is an average side slope for canals
excavated in a fairly competent material.
II -21
APPENDIX II -(Cont'd)
D.
D.2 Unlined Canal Design-(Cont'd)
The minimum allowable bottom width bt was 2.0 metres to
allow ease of construction using mechanized equipment.
Otherwise b Sd where d is the depth of flow.
The bed slope of the canal did not enter into calculations of
sizing the canalt but will have to be considered in later
design phases.
The unlined canal excavation cross-sections are shown in
Figure 11-30. The canals were considered to be excavated
into the side of a hill with varying cross-slopes. Provision is
made for a bench between the exposed cut and the canal.
This bench is to provide drainage as well as to catch
material falling from the hill above, which might otherwise
accumulate in the canal. The exposed cut above the bench
has two values for slope, I: I to represent most types of
overburden materials (e.g. gravel) or I H:SV for material
which will stand steeply such as dense till or loess.
An allowance for freeboard on the canals has been provided
for the various discharges.
ii Ice Covered Canal (unlined)
The criterion for sizing an unlined ice covered canal was to
allow a maximum velocity of V 0.30 m/s. This low velo-
city would prevent frazil ice from forming by minimizing
turbulence, while at the same time allowing a sheet of ice
to form over the canal. Once a sheet of ice had formedt
(0.90 metres was chosen as a thickness to be expected in
II -22
APPENDIX II
D. COST CURVE ASSUMPTIONS-(Cont'd)
D.2 Unlined Canal Design-(Cont'd)
B.C.) the section was then checked to see that the velocity
in the restricted area under the ice did not exceed the
maximum allowable non-scouring velocity of V 0.67 m/s.
A velocity of 0.67 m/s would also be low enough to prevent
rippling of the underside of the ice surface which would
result in excessive head losses.
0.3 Lined Canal Design
General Considerations
Designed using an average velocity of 1.0 m/s. The velocity
was limited to 1.0 m/s so that head losses are not excessive.
Canal side slopes were set at 1.5 horizontal to 1.0 vertical
(i.e. 1.5: I), and the canal designed as the most efficient
cross-section with this slope.
There was no specified minimum bottom width for lined
canals (as there was for unlined canals) because the extra
expense for the concrete bottom slab would be more than
the savings resulting from being able to excavate a canal
with a wider bottom using machines.
The bed slope of the canal did not enter into calculations of
sizing the canal, but will have to be considered in later
design phases.
II -23
APPENDIX II
D. COST CURVE ASSUMPTIONS-(Cont'd)
D.3 Lined Canal Design -(Cont'd)
The lined canal excavation cross-sections are shown in
Figures 11-31. Details of these sections are similar to those
for unlined canals which have already been discussed.
Standard allowance for freeboard which varies with dis-
charge is included. As well there was a fixed amount of
freeboard of 0.30 metres between the water surface and the
top of the concrete lining.
The lining was assumed to be 0.10 metres thick.
ii Ice Covered Canal (lined)
The criterion for sizing a lined ice covered canal was the
same as that for an unlined ice covered canal. A maximum
ice thickness of 0.9 m was assumed. With this cover the
velocity was maintained less than 1.0 m/s, so that the tee
water interface is kept smooth and head loss is kept
reasonably low.
D.4 Intake Structure Design
The intake structure is shown in Figure 11-33.
The intake diameter is the same as the required penstock dia-
meter to carry the same flow, at the allowable velocity.
Freeboard requirements are the same as those for a canal with
the same discharge.
II -24
APPENDIX II
D. COST CURVE ASSUMPTIONS -(Cont'd)
D.4 Intake Structure De~ign -(Cont'd)
A submergence depth S, of the intake is required to prevent
formation of a vortex. In "Vortices at Intakes" by J.L. Gordon
Water Power, April 1970, a suggested minimum submergence Sis
given by
s = o.54 v/D in metric units
where V =velocity in intake penstock (m/s)
and D = intake penstock diameter (m)
The wingwalls of the intake are flared at 4: I to provide a
streamlined flow transition, which wi II reduce head loss in the
structure.
The end floor sill is at a 4:1 slope. This sloping end sill is
necessary since a drop is required between the canal bed and the
inlet to the intake to maintain the submergence depth S.
The intake structure has provisions for a control gate and also for
stop-logs. There is allowance for working space behind the
stop-logs. Positioning of the stop-log opening and control gate
also minimizes the size and consequently the construction cost.
The trashrack is positioned along the inclined face of the intake
structure. Having the trash rack inclined allows debris to ride up
it and helps maintain a free flow area. The troshrock area is such
that the velocity across it is less than 0.60 m/s, which 1s
considered an upper limit for a non-self cleaning troshrack.
Cleaning of the trashrack is done from the walking slob/floor
covering the top of the structure. As well, this floor serves the
II -25
APPENDIX II
D. COST CURVE ASSUMPTIONS-(Cont'd)
D.4 Intake Structure De~l9.!:! -( Cont'd)
purpose of providing an area from which to operate the stop-log .
and control gate. In conjunction with the trashrack, the floor also
effectively seals off the intake and provides a degree of safety
against someone falling into the intake.
The excavation for the intake structure is to a depth equal to the
height of the structure. It is assumed it is overexcavated by 1.0
metres at the bottom and has I: I side slopes.
D.5 Penstock
Steel pipes were selected as a basis for the penstock design criteria.
D.5.1 Sizing of the Steel Pipes
a. Inside Diameter
Inside diameter was chosen to maintain the following velocity
requirements to minimize head losses:
V = I. 7 m/s for Q ~ 1.0 m 3 /s
V = 2.0 m/s for 1.0 m 3 /s < Q ::S 4.0 m/3 /s
V = 3.0 m/s for 4.0 m3 /s < Q ~I 0.0 m 3 /s
b. Pipe Wall Thickness
Wall thickness was chosen to meet two criteria, one a minimum
thickness for handling, the other a stress requirement with a 2.0
mm allowance for corrosion.
II -26
APPENDIX II
D. COST CURVE ASSUMPTIONS-(Cont'd)
D.S Penstock -(Cont'd)
The required handling thickness governed in the cases calculated.
USBR Handling Formula handling T = D 4+0 g08
gives T in mm for D in mm
Where D = ins ide diameter of the penstock.
D.5.2 Installation of Penstock
a. Buried Penstock
Typical penstock excavation is shown in Figure 11-31. The
penstock would be buried to a depth of 0.30 metres above the
crown so that penstock excavation costs can be kept minimal. If
this amount of cover is not enough to provide freezing protection
then additional material will have to be piled over the pipe.
Clearance distances B, are acceptable values which are needed to
allow slinging, aligning and joining of the pipe in the trench.
Side slopes of I: l are used to prevent the excavation sides from
slumping.
The trench will be backfilled with the excavated material.
b. Above Ground Penstock
It has been assumed that an above ground penstock on supports is
used where the penstock slope is greater than 30%.
II -27
D.
D.6
D.6.1
APPENDIX II
COST CURVE ASSUMPTIONS-(Cont'd)
Powerhouse
Powerhouse Structure
The simplest powerhouse structure is found in higher head plants where
Pelton wheels or similar turbines are employed. The machine is placed
on a floor slab and water discharges through an opening in the floor to a
well below the slab and thence to a tailrace channel. No buyoancy
forces are encountered so that "light" concrete substructure design is
employed. The well and tailrace wi II be formed of 175 mm concrete
slabs and walls and the ground level slabs would be of similar thickness.
In heavier installations a concrete thrust block may be required to
resist penstock hydrau I ic loadings.
In lower head plants, where reaction or propeller turbines are required,
considerably more concrete is required in the substructure to accommo-
date the irregular shapes of the turbine and hydraulic passages and in
some cases to resist uplift forces. Powerhouses for this type of
machinery require larger excavation volumes, and generally result in a
more complex construct ian arrangement.
For both types of powerhouse the superstructure can be of timber,
concrete block or steel frame and cladding construction. An opening is
required in the roof for mobile crane access to the machinery.
Cost estimates presented in Figure 11-26 are based on typical machine
sizes and types appropriate to the capacity and head available.
II -28
D.
0.6.2
APPENDIX II
COST CURVE ASSUMPTIONS -(Cont'd)
Powerhouse -Turbines and Generators
a. General
The turbine estimating price for any specific head and output is
dependent on the following variables, many of which are inter-
related:
Type
ii Speed
iii Setting of the runner relative to the tailwater level
iv Governor type and system
v Inertia requirements
vi Manufacturers
The estimating price for the asociated generator is dependent on
the following:
Speed
ii Voltage
iii Runaway speed due to the turbine
iv Bearing loading due to the turbine
v Manufacturer
The majority of these variables are site or load specific and can
entail substantial unit size variations.
b. Generator
Generator costs for any given output are fairly readily predictable
with a parabolic relationship between cost and speed. Reducing
the speed to half the optimum value can double the generator
cost.
II -29
APPENDIX II
D. COST CURVE ASSUMPTIONS -(Cont'd)
D.6 Powerhouse
Considering generators running at their economic speeds, cost is
approximately proportional to output.
The economic generating voltage is dependent on the location of
the load centre and for the lower outputs, say below 750 kW, an
increase in voltage from 600 V to 4160 V can increase the cost of
a generator running at economic speed by 50 per cent. This cost
increase may be significantly less for generators running at speeds
below their optimum speed.
Cost data are based on the assumption that the generators will
hove a horizontal shaft configuration and will only be suitable for
indoor operation with open circuit air cooling.
c. Turbine and Governor
Turbine prices are based on units with horizontal shaft arrange-
ments set at an elevation to give positive suction head but having
a speed and size to prevent cavitation damage to the turbine
runner. Prices are based on January 1980 Canadian dollars, and
consider minimum supply and installation costs without provision
for spare parts and without evaluation of efficiency at either full
or port load ope rat ion.
II -30
n y
n
" "'0
"'0 m z
n
0 z
(/) c ,...
-1
l> z
-1
(/)
32
31
30
v
0
0 29 ct
6
QJ 28
" ....
)
::;_
' 27 ..
'.,)
·\ ' ~ 2G
... -.
....
'1
Q ?5
\j'"'
...
~ '-' 24
?-~;l
22
0 10 20 30 -"rO 50
Ground Cro.ss Slope In 'ro
GO
BAStS'V/OOOrn al' R.ood
2):3.0 m Wide. roo</
J)~::o,·-,o,-c r.:: ~r..f.:n eJ.(.CWrJ fion .
4;/·t Side ctJr slope
6)Ciec;,r 5 9rut. included.
MICRO HYDRO STUDY
ACCESS ROADS
OVERBURDEN EXCAVATION
BASIC UNIT COST
FIGURE n ·I
A v
n ;o
"'CC
"'CC ,
z
n
0 z
rJ) c: ,... ....
l> z ....
rJ)
/. 7 <
l /.f. 0
"" \)
0
1.\.
~
/.5.
c ...
£ .... /.4 .. ,
:::.
')
")
~ /.3
l..
vl
()
\j
1.2
"' ....
"' )
~ /./
a
() !.C 0 ,..
"
0.3
05
2.0
~-·--~
:3.0 4-.0 5.0
Rood Widt-h In Merres
'"!
I
~:
MICRO HYDRO STUDY
ACCESS ROADS
OVERBURDEN EXCAVATION
COST ADJUSTMENT FACTOR
FOR ROAD WIDTH
FIGURE !! -2
B v
0
~
"'CC
"'CC m z
0
0 z
(/')
c: r-
-f
)>
z
-1
(/')
t
Q
/.04'
/.02
~ 1.00.
,:)
"'-
~
cD-:lo
J
.,._
:?0.96
:::
' "0-34 ,r,
')
'J
;:: 0 92 ....
0\
c:
':!
10.90
'0
0
') .. ,
"0.38
0.8.;;;
0
i j
i
2 3 4 5 G 7 8 ..9 10 II 12 13 14 15
Road Len9th rn X 1000
MICRO HYDRO STUDY
ACCESS ROADS
OVERBURDEN EXCAVATION
COST ADJUSTMENT FACTOR
FOR ROAD LENGTH
FIGURE !I-3
G
n
~
"'0
"'0 m z
n
0 z
(f) () c c r-0 -4 Q: l> z ....
-1 C)
(f)
1;.,
~ .;._
(l.l
~
l..
\)
Q
~
c: .....
~
"' 0 u
4... ·,
'::
::J
I i ' I I ' ' I i . I I ! ' ' I ; I l I i ' ......___., ___ _j_ --1-----. I ' I . ' i_j I . I I I ' . I
I i · i' 1 · rT -,-:-1-~t~ 1 ~r+i!-i !-:_:_t_J _j_j : : ' ; : . I : '. • I -H~l---H·+ -f-:_4-:_l ' ~_._
,._ I : I _-·. I ''_ I --:-n--_ I . rl -~l--t -j~:_-_-~. II +-h-·. -t-~-__ -1-J:_ ~~--+--~ I ' I I I . _ _J_:: L I i 1 ' I 1-I
I . li. _1 : j . I : "I'. I ' 1 I i +r . ,-I l,.l_. ~·. -t+f-+-" ' -+--' ___J "o~TEI.1i~ ~*-1
-r-i. . -'--h-T--+-r#:-H-t~
I j_~_-L~ I · 1 ~~ 1~--i_--i~+-·_--~-~_J __ ·_--1 _ _::· __ ~-.,+_--~~ll+:_L
100
~·--~+-f : · H--~--. ~ -r
1
Tt-'-+-t+: 1 '+ !· :~_t-~-t-·_ f~-~:-. +. _ : .. L_.L~_11 _--+ J .--~ -. 1-~-;[--:-l .-"~---t--t---_-t_! __ ,l __ i:--:
! I . . I I --I ------r-------t--+ . I . ' - . ··;
90 ~--~--' I I . I I 1 . tl . I ~---1-t------; ---:-t _; __ : . I 1 . -. -T-:-r-~r-+--, --_-----~-+---1~__::__, __ :...1 · 1· _ 1 ; -: 1--~--..L.--1---+--~ . 1 . 1 • t-· 1 : 1 . r---~--, -~ -I
•. I •. !. I.,.: .---1-r-_____ j _I __ _) _____ [ , . J .I ~J.
80 r·-----+--_ J. I I I ' I · ' I · 1
. ) •
1
I -;l" ·--:---l-~! -~-i~_-1-T-~I-J-:--·'-tl-~:_ :i··:-1~~-. i ~ -_l~--:-+-~-+:-~~---l-:._t_J' ___ I
' . ; . ! I : l I ~ ---+-+-. _ ___j I j . I . . . 70~ .--1 _ __j__ I i I I . . I ' . T 1----:-_·i+---t---:··--___ c_ __ . .L
• . I r--,--1 ---. --+· I ; I I I ' ' I I [ ; j__ I I . I . II I . I I ~ . r--j -r ----,...---~--t··-. t
1
-I
·-I -· ..L. I ' I I ' I . I I '--:., ;--~~-~--J---1----.l --·--~--L---·, ·:. 1
GO L-~--1-~-~-_; _ _;_ -i -: . 1 . ! .-_1,-~-~ ~r:-;·--r· -r-~+"'---
,: ·1 I · i -i l ~-~---: -r-+-:--·-i·---l-1 ~-~_ .. _J_ i ~·
• ---~ --------~ I ' I I .. ' I ' . i I . I I I ~· . ~~-. 1 --·r·-·i-----~ _ l __ f __ 1 __ 1 ' !. _1 • I . 1 -·~
' I I . I I ' I I -I .. _J . --. I -+ f I '
5o ; ---~--rr-:--1 ~-' ~-~~ + t: • l l----LI __ Hi~~il_=--c: __ H,~ (~:---_-. JLJ-· --~ J I • I HI J . ' --·-, . :--~---:-----r--·-r------t--I ~-_ 1 · i ·· · 1
· • , I :
• ' ' ' ~I =-r I T]""' . I I . I
4-0 --~--: _~----;--t--~-~_1. I' I_· _ ·
1
. · --~-~-]-~·-+-!~--~--
; I . ' . i . ' I I I' I ' I ..... , --r------....!..-....... . I
,--. ___ , _____ ;_--I--I _,_ : . I . I . ! . I • f I ' ' I" I -~-.
30 ~-j.: 1 ~ ~ TT~r-J-:tt-r-rtr:.L.-1 1
~..:.t __ f~J--~~r-~~-t-:-r--~~-r_-~ t• J. ~-+_.__·--~-~--~ -~~-rr· ~-~
1 -: ; . 1 r-: t· ~ ~1 --;-+ --~--:-~-~-:-I ~-~...:... ~~-· _ t· -: ·1 !
20 · , 1 , , · I · 1 • I • I , -· 1-' 1 . 1---1· :-r~ ,------:--:
I I I -' ' ' ' . :--1 :____:___I -:
20 30 ..;o 50 rao 60 70
Ground Cross Slnpe 'Yo
BASIS:
I) tOOOm or Rvocl
ZJ3.0m W1de ro~u::l
.3) 100 Y. Overburclo:n e..-.::-A"--"'! .';
4)1.'/ S/de cut ~lope
SJ Clear &: qrub /nc.lude:cl
MICRO HYDRO STUDY
ACCESS ROADS -ROCK EXCAVATION
BASIC UNIT COST
FIGURE li-4
L\ v
n
:::0 ., .,
m z
n
0 z
(f) c r-
-1
:P z
-;
C/'1
2.4 -
2.2
l
0
' lj
·) 2.0
1....
i..
~ /.8
t
'·
·I
~
·_;:, I. G
-~ .
....
'·' 0 /.4
•.j
,.
'
""" b 1.2
~
~ 1.0
I) cr
08
0.~
20
1
;_
-l -~--·------!
3.0 4.0 5.0
Rood Widt-h In Merre s
I
I
MICRO HYDRO STUDY
ACCESS ROADS· ROCK EXCAV..! TIO~
COST ADJUSTMENT FACTOR
FOR ROAD WIDTH
FIGURE II-5
Jl. w
n
:::0
"'C
"'C m z
n
0 z
(/') c: r--;
)>
z
-;
(/')
1... ,....
" iJ
...
"
/.04
/.02.
1.00
..... 0.98 ,,
J ·;:;
";::
t. 0:9G
0 <-
')
~
;, 0.94
CJ
'J
.t:·
' ~·092
1J _,
t;,
0
l) < 0.90
088
08G
0
j
+·
2 3 4 5 <:;;. 7 8 .9 10 II 12 13 14 15
Roocl Lenoth rn X 1000
MfCRO HYDRO STUDY
ACCESS ROADS -ROCK EXCAV~TJ:~
COST ADJUSTMENT FACTOR
FOR ROAD LENGTH
FIGURE :rr-6
A v
n
:;tJ
""0
""0 m z
n
0 z
(/)
c:
r-....
:t> z ....
(/)
~----, TL···~·· .,., 4' ''1_:_!-t' I ~_JJ_:_ __ ~.:___j.__~~ 100, --~ ,-r~--~' 1 _]--l-+ ----+---•---~-f 1, --~=t r------T---------;--•--:·; _ _J__ I ---+----!--;---------1.; rl --------~-----;----·-1 I
1 f.-P+ .l.....:__J__ ---__ ,.L__ . [ I-i _
L----·---~-~: :~n~:-;--~-t:=L·+··-j=L·i-~-~~--;-~1 ~~
50: i : 1 ~t: ·
1
-ljJJ_· _:~i--LL ~-H-}-· I :
' -1--:--r---:-+-I . ' I ' 1 ' . I . I I I I -I . . I ---r-1 ' I "-HI' .. j 'I : ; I' I I' I
t . I I I I I ' _!_L_'--+---f-l·-ttl--
1
------:-:-r 1-------t-,---:-;-::--rr I _j_1--~--~::r .. ! _;_ I I ~I I:---. r---'~:-!
---! --,--! -I II j I i : I ' l' : I J /(Jl 4,,~!."'.!..:3' ......,<-A
" : . : . i 1 i : Jn-~~~~~0~~
0
r-vt<?J7 . 1 . J:
. ---r----~--;,-r--r ~1 , rr--·: --r-: i I ·yy 1 i ·
! · : 1 1 i 1 ,
1
·_ --k-,·-~--~------r----·--.---r-l I I -----,.-~r/' ,/ .,/ ~ . . ~ -·-1 10---L_ _____ ~---+-~--,--~· -----1 /-;I . .~-, . , ----+L.-~~ ~-:._-===--·--,--L~----~-t: __ ::~~-·-·_; y::li.-H--T" -· ' -----·----.-;--T ~__[_ _____ r--!l -'·/---./--1. r ------r;-!
..... i ~I ; : 'I !7'7: 1-V+-----1----r-~----~ ~ • ---:-:==~; ~: ~ ;-::-;:;-=~~ « ; -+11 + ! • :+-: --~:1 ~ :-~----Li Hf'F!f~ r ' :_~-tu_--:~riJ
'J --------__ :__ -----:-: t-i -tjrz: -' -----. . r 1 1 : I • :
'·" . I : ' ' ' ' ' : I I I I --: I
1.. • ; --. -:-• : I ; : j I : i I D ' I I ~ . ' i i I i ' . ' : I I I I I -t ·---1 ~ • I , 1 ,_' ---• ---------·--.-r-.--~-+--------1 1 10----------------,---+--1 I · . ... -j--· -·-+-' l" i ( ' -+--~ 6 . : ~ ~:--..:. ~ ~~-1 _ : ~~ F: : ~ ::'~ ~j lrc-:---:-~-'
c._--, ___ ·----:--~I .1 I • __L __ J._J---! .LI'i+----t-;g 0.5'----------~-'----l---:~~-·;-.--. -----· -: i I ; l I I I_ -~-
' ' ' I ' ~---,----r--~-,__ ·tl -----, I
r-----;-----·-';j·-1 ~~.-7t' ---~[:-· i---r--i : -: I l ! i ·-I~J ~~-~ , -_t1u·rl ~ ~ fT~ r1~-frw~ ~~ ~~ 1 , ~
: /_lj i/J 1 i-1~J ---_:---J---~-i-~ 1--1 -~r -~----;----·:---1
I l i ! ; t I· + I ; I ' ! l Jjj_'. l ; .... : : : : · :l_l I · I 1 • • • • I ·1 · 1 ~ L
1
oo 5oo 0.1, 5 10
Excavated Volurne rn3/m
BASts: t);:; Side cut :slo~e.
2)Cross slc;:·c cl o,..iginol
9rour;e1 :sno,·.--n on
curves.
MICRO HYDRO STUDY
UNLINED POWER CANAL
NO ICE COVER
BASIC EXCAVATED UNIT VOLUME
FIGURE II.-7
f\ y
n
:::0 ., .,
I"T'1 z
0
0 z
(,f) c r-
-1
l> z
-1
(,f)
u
4J
il)
~
E
()
{; ·:-,
l
iJ -c:
\.)
'1)
CJ
£xcc:rvated Volum(!ii!' rn .!3fm
BASt.S·t)J:JS/.7~ cv.' '!J/ape
2)Crc:.:::; sJ::pe. .;;~ original
yround cs snc•·,r; oli
c(..Jrvcs
MICRO HYDRO STUDY
UNLINED POWER CANAL
ICE COVER
BASIC EXCAVATED UNIT VOLur.~E
FIGURE II-8
G
n ;o ., .,
m z
n
0 z
E CJ'J
~ c:
~ r-
-1
v )>
Q z
rJ -1
CJ'J in
4..
) u
"J ':l
·~
J)
....
'
•[I v
t
)
' r,
""
~ .J
<-..
() ,
0
v ...
l..J
Aaju::,ted £xcovafed Volvmes IH:5V 5/cie Cut :Slope rn 'Vm
NOT/!!:
1.) Cro.s~ .stop& of' origir>o/
qround a:, shorvrJ Or1
curves.
MICRO HYDRO STUDY
UNLINED POWE~ CANAL
ADJUSTED EXCAVATED VOLU~.~ES
FIGURE li-9
J:\
\J'
(")
:::0 -., .,
m z
(")
0 z
(/) c: r-
~
l> z
~
(/)
B
VJ '~ ~
c
x
' u
.:_!
Cl
ExcovoTc.d Volutne m·'/17>
8ASIS:I)t·t 5iae. cut-:s;cpe.
C:)Cro::;5 '!:;:c,.-::::: ;;of' original
grovnd c:, shown on
curves
MICRO HYDRO STUDY
LINED POWER CANAL
NO ICE COVER
BASIC EXCAVATED UNIT VOLUME
FIGURE n.-10
1;\ y
n
:::0
'"'0
'"'0 m z
("')
0 z
(/)
c: r-
-f
l> z
-f
(/) u v
Ill
~
t
0
0
f}.
c
' 'J
4:: u
·'
Cl
E.xcovore::t. VoiL.Jnle. rn3/tn
BASIS 1) 1:1 St::ie. cut .slope
2) Cro~-;;, slope of or:gina/
9round as :shown en
cur .res.
MICRO HYDRO STUDY
LINED POWER CANAL-ICE COVER
BASIC EXCAVATED UNIT VOLU~.:E
FIGURE ll-11
n
\:1
n
::0
"'0
"'0
m z
n
0 z
Cfl c r-
~
l> z
-t
Cfl
1000, ,-,,-n.-·,--r---:---•~r·-r•l;_+~-=I_:_r~·T-·-•· l'j 'j I'ITTT'-'IT--+-------::2 ~~-_ ~--E:_~t-~;=r~~i:r-__ _j_~~t-~~~'i:-~~::~~~=tE:~E~-~ +---~-==~
~-+-~--~~-:--c+--i~;--+--; _, -~:.. t'-~-t-+----: -:-i+t--· -· -+-i
500: . -. ' : I ~ • 1 1 1 . . _:_ ___ '----,-----+-~ • I , · : i ________.
. I I I ':! .. l '. I . I I II 'I' ' :2 I
I •• 1 •. ~-'I'
t-------7--r---t . ~-------· ' ! I i-T I : · ·_-:t•··~~Ju! ~r '~t:t t1 :~:_w~~1::-1
t . ' . ' ' I I I I I ' . ' I I I : '. /1 '
I ' ' I ' I ' • ' I 1 I 1 ;-;;. r :··:--:-: Av!iri:.~i' 'cor/ei:J(on Cur~e' i ,.( / ·•I -·1
r . 1 1 Jcc. Co,er (;no Ice Cover · /.' ' : . ' I I : ' : : I ' ' . . : I
' ; ' : i. i ! ··~ I ! • / ' : : : I : ' ' -------~-----T-iTiTT17-/ ---r---r ,-i -! ,. ~..,I -----r----,
."' \. I I I I ,., • I I ! -~ I ' :: '/' / ' I I
~ : ! / / I I I! '
l ':~~=~ >j,~Xc~·~~z=!••••~ ••• r:~1 •ti.~J••~ ~~~ •; ~~-~
l.j ·-//---·--:' !---·--1 I i'! It:,-· ·i. I ----/ / /-----1---~--: !1----~ ---t-··-T---~--·-, ·ti tr"'~, -r-:--j ·LZ/, ~ :!:: ~---f--++i -~~~~~~,-------i~ :-~ ' / 'i I ' L ' 'I' l I ·--r·------~ ----· --1 -~-r ··--<
/.: : ; i ! i! j' I I I I I, 'I I'
• . ' ' ' I ' ' I I ' --·----:------·----•----1---1. I. •-~-•-----·• I -I ~~~~11 -r·-_]-
I I ' I I ' ' I ' I I I I I . I ' I I I ' • I ' I I ' I
; I I I I l I ' ' I' I I I I 'j ' ' I ! I I I -., ... I • I ' ' I I I JJ ' I I ·--'-___.L__j____L ~--....____L_-l_L-.J__ -----'
I 5 10 50 100 200
Adjusted E;<co•/ofed Vo/urnes /H:5V Side Cut Slope rn 3/rn
NOTE:
1.) Cro.ss slope or or/g/na/
qroun cl os :5hown on
curveS-
C.J Corroct;on
to So:c f,on
or Section 8
A F;gii-3/
MICRO HYDRO STUDY
LINED POWER CANAL
ADJUSTED EXCAVATED VOLUMES
FIGURE n-12
£\ v
n
A:) , ,
m z
n
0 z
(/) c: ,...
-f
::t> z
-f
(/)
~
'1'):
..... ... ,
<3
t
·~
"'-
'l :::.
<'I
0
~
~
r.::
\;
{J
l 'J ~
\)
Q..
! ;oo -~-·--
i 1-
100 -~.
8A:SIS"I)IOO)m LC"Yn9 canol
2)!0U%0>'"erburcten excavo1iM
7!)1:/ s,cJe cut slcpe
4)C~ecr !'S grub inc/vde.d
MICRO HYDRO STUDY
LINED OR UNLINED POWER CA~i-"L
BASIC UNIT EXCAVATION COST
FIGURE .I!-I 3
.A v
n ::c
"'0
"'0
rT'I z
n
0 z
(/')
c r-
-f
l> z
-f
(/')
tO::J o!::Jo
i
50 ooo .
10
"l
GJ
I.. ......
~
~
..(: ..._
1)
~
-....
' \l c:
?')
f.j
...
CJ t
<;)
Q
tOO
so -t--. . I
·-~-· ..
j,
f-o,ver Cono I Exccvor ;on Cos 1" Adjvs trnenr Foe-tor
MICRO HYDRO STUDY
LINED OR UNLINED POWER CANt.L
EXCAVATION COST ADJUSTMENT
FACTOR FOR LENGTH
FIGURE I!-! 4
A ·o
n
::tl -"0 .,
m z
(')
0 z
(J)
c: ,....
ti ...;
l> ~
¥) z ~ ...;
(J) t
0
r.,
~ ~ .....
\j
II) ·,
(J
!5 -<--
1.0
1
I
----------··
Concrete Linin9 Volurne rn 3/rn
BASJ.S:0./0 m Th1ck lining
MICRO HYDRO STUDY
LINED POWER CANAL
NO ICE COVER
CONCRETE LINING VOLUME
FIGURE .It-15
I} y
n
::0 , , ,.,.,
z
n
0 z
(/) c
~
)> z
-f
(/)
I <.IV
\)
'.;
~~r
0
·' ....
(; 10
'J
?" ...
() ,.
\)
.1)
Q 5
:-------'--------;-----
l ~ -' '
~---··~--~
~ !
.---___ ,.. ~·. >-----._ .. ~ ------··
i
j
'-'' i
I
i
~-=,-;::-------..-,.~;:------, 2:f --/.?fo----~~75
Concre.Te Lint'nq Volume
I
'
--~--<--
' -'
.I ' ''
~-·
--z:oo·----z:2_5 ___ 2:'5o
rn]/m
BAS/S.'0./0 rn Tnic.k tmln9
MICRO HYDRO STUDY
LINED POWER CANAL -ICE COVER
CONCRETE LINING VOLUI.:E
FIGURE ::l-!6
1\ v
n :;a ., .,
m z
n
0 z
C/) c r-
~
l> z
~
C/)
300
230
280
270 . ---
2t:;O
c5D
:: 240
):..:.?30
"' ... 220 ---
II)
0-0 ',J ..:' /.
?• .?OD
~
~ 19()
..._J
\) 160
<
<), 170 ~
'J
;-:!GO
(j
\)150
.....
0140 c:
0 U/.30
120
/10
100
90
80 . --·-
0 0/
'>····-··
-L
r
I
-I
I I
-!··
------------.. ..:. ----~-
0.2 0'3 04 05 OG 0.7 0.0 0.~
Ccnol Concrete J..,"n/ng
I
j
' '
·! 1 ..
' -.L
'
/.0 I./ /. 2 /. 3 1.4 /.5 /.6 /. 7
Volume rn -1,.-~'n?
BAS/5."/000 1?1 Lonr:; cone. I
MICRO HYDRO STUDY
LINED POWER CANAL
BASIC UNIT CONCRETE LINING COST
FIGURE n -17
A v
0
:::0 -., .,
m z
n
0 z
(/)
c: r-
-f
l> z
-f
(/)
I"""' J V~J\.11
SO CIOO
10 000 -=±====--=:-=t~
II)
t
1... ....
(J ....
<.
..c -~
\:
'iJ
..J
......
.j c:
~
\)
l ~
;.::
&
Focror
MICRO HYDRO STUDY
LINED POWER CANAL
CONCRETE LINING COST
ADJUSTMENT FACTOR FOR LENGit-
FIGURE II-18
n v
n
~
"'0
"'0 m z
n
0 z
(f)
c: r-
-!
l> z
-!
(f)
BOO
700
'"'\
-t .....
\!'
t:::
'() .......
" 600 ~
't~
'-
......
'/)
\)
l,j
l 500
QJ
~
r:::
()
.()
(l
I() 400
300
:woo 1.0
! !
L --~·t·--:.. _L .... -
j !
'
--l
' ' -.; --------+-
2.0
.. ,
I
I
! .. !
!-leiqhl P oF Gab/on
_;
'I
3.0
Weir (m)
:
4.0
MICRO HYDRO STUDY
HEADWORKS-GABION WEIR
BASIC UNIT COST
FIGURE :::!.-19
G
n
:0
""0
""0 m z
n
0 z
(/') c:
r-
-(
l> z r..
0 ..... -(
(/') IJ
/) . ..__
.... ,..
~ /./
' ' ....
"' ) !.0 " 1:
.....
0~ l•1
G v
\..
'J 0.8 ~
~
'-()
0.7 ~
()
lj
:--· _j
·t -l-
·r· I -i
. l
; -.)
! --· I
i
l
I
. .
~---~~-__ j ____ ~----
0 10 20 30 -40 50 '0 70 ~0 .90 100 1/0 120 130 140 150 /60 170
Crest-Lengt-h of Goo.:on We;r (m)
MICRO HYDRO STUDY
HEADWORKS-GAB ION y,'EIR
COST ADJUSTMENT FACTOR
FOR CREST LENGTH
FIGURE n-20
0
n
::0
"tt
"tt m z
n
0 z
U'l c: r-
-4
l> z
-i
(/)
5
'J
v
~ 0.5
~
~
' " ' ' u
.;
(J
0.1
0.0~
.i
'
·--j.
11?1-::.l<.e Structure /I?Sia!lec:l Cosf x
MICRO HYDRO STUDY
HEADWORKS -INTAKE STRUCTURE
INSTALLED COST
FIGURE JI-21
1:\
Y'
n
~ ., .,
m z
n
0 z
Cfl c
r-
-4
l> z
-i
C/l IJ
'<!
·-1
"" "l
::::
()-
~)
:-;-,
' ·' J
---\.)
I)
(j
5
1.0.
0.5-
C. I
0.05·
0.01 100
:
I r-____ J __ _ I
~--~[ -~.] -j
j
I
-I
.. I
' I j 1-~--·-i· -~-··j-·i--t-+~-:---·· -·---~-~ -:--,
I . i . 1 , t 1' ' • I · 1--·l I I ' ' • I ' I ! I ~ I ! /; i ~: ~-i rr· ---~-~t-TI~-~-L~~T-
1
1 I 1 I 1 I J i l ' ' -'--1--r--~ i--j--r-r'l· ~-~-·r r-: 1
. -1 I -1-l ~ ' '-f -: -_j -I --I -~
I I I I I I : : ' I
I il. I I ! i I I l I i I
-------~-----·t
-~ ---------·---" .. " -r -------------1
,.1 ~••: :--1::~r:-1r~
'.
-~
1 ,II.
-r----~ --<-_J I ---r --:-
;·
I 1 i
' I I ; I ; -.
I I
-·~·--·
!
·-· 1 I
I
I -r-
-~-~--rj·-~-T-1 1"'---j--~~
--·--t-~; --r---~-~f-~+---~---~--
-1 ·--~-; _J __ L ~ _; ___ j _ _j __ lJ ___ 11 _j_
' ' I : I ' I 1 I I I I ' i ! ·-. : --: -. J.__ . , _ _, _, ; __ L_ ----_ L-j __ , __
I I I I ,. I I . i I' '· : . I • ' · · · 1 I t ·; · i -r ~ -~
l __ tJ -~-LL-~-! .. ,_l __ , __ :_ L-~-L---i I I I : I : I I I I I
I : i i I +: i l i : i-! I
I i I I ! ! I :
" f_j , : i . j -~L~ ;t! :1 1: ··~~··~····:•. !·~·.-,·~~··•·t"l
' I ' ' 1 I i I I I I I 1 ' , I , ·c-·:-·:·-"-T :_:_r_, __ l I;---: ~--l--~ :~~:~r'·-;--__j-~--
---l. -~
i I I i ·-j
, ' ' I I ~ I I I ' i I ' ' I I . . --! .. -I_ . ---!-_j ~-·-! -· I -j----· ----·---,---1-,--j--,--: 'T
• I I I i I I I I ' ' ! ! ; I I )1 I j : ' I
• -; I I I' . I ' j-1
I_ ; I .. I :. 1 -,_--I I I-+·-,--.---; -~ ---,
I ' I~ I I I I j I I I ; I . I J I I I ' I ' I : I I I I : ___:___I --' I ___ . --~-' ------------------~---~-----1-----f--··t-----+_--.--r---~ t-1 ]----+ r--T"'1 I r • I I ' I ' I I ' F I I I I ! I I . :
' l I ! I ! ! J_[ I-: ! .: ··-... ; . Jj_J_-)_11_[_1---L-~J-
1
' I I . . I I I I I I I I I.
I
I
500
I I I ! !. i . ' I ! I I I
I I ! : I i I ' I I I : I I I I I L ~ i L I j l_ L_l__J Ll I I I I I I I I I :
1000 1500 ~---
Ins/de Pipe D/ameter mm
NOT~:
Sol,-ct line qives .suqqesled
values
Dashed line qlves mcoo'urn
and m/ninurn values
MICRO HYDRO STUDY
PENSTOCKS
DISCHARGE VS INSIDE PIPE DIA~~ETER
FIGURE li-22
A 0
n ::a
~
~
m z
n
0 z
c.n c: r-
-1
l> z
-1
U'l
10.0 ... L .... ·t-.; . . +·---j-·--r--··: ----r· ~---t ··-· ··: ·:· ---~----:
, ..
. --7---~----· . t~ ---:----r---
::~ ~~~~~~~-~:-~---~~:-; _t! U : ~1--:_·_-: -~J: ~-=c:~-~-rL~=~--~L-~-~
! j I' I . I ., I t I i.: .• j
. i i ; :: .. ! J : I : 1 : i . ! j
3 ·0 :-· --.----;---. --:----:-·-;-··:-t·trr---,---;--·-;--;---r··j--r-;-r----1 ----r
~
(\)
-~ !:'
2.0
1.0
0.5
0.4
-~ 0.3
~
())
l 0.2
~
-t
\) ,,
cS
0.1
0.05
0.04
0.03
0.02
. I : t --: l . j : l i ~ j
! ; : ~ f : I ! i I l : I '
~---------~~------·--------~ ------·--->.. ·r------... ----------.,---• --T
' 0 ' 1 ! j · • <! I I ! I : i I l
' I ...
.... -------------------:-----+--------r: -.
I .,
----!
I I I
' ..
1-:
-;.
~ ~-= J
I "1
.. '
--I
! I
0 I '
_.,
... 1
..... -1
l....-.....:._ ----~
' !
. --+----~
: 11.
1 I (' f
I j I I 'I I
.. ,
'
---1
i
:--j
I ! I
I • I
0.01. ·-----------. ' . ···-·. ---·~~ --· -~--I i I 1 ; I I ,
... __ ~..l_.,.__j_~---------= ~-·
10 20 30 40 50 100 200 300 400 1000
Unit cost in $per rnefr? of' penstock
BASIS -1000 rn of' penstock
-30% average penslock :slope
MICRO HYDRO STUDY
PENSTOCKS
BASIC UNIT COST
FIGURE n-23
~) CRIPPEN CONSULTANTS
0
2
a:
0 .....
0
ct
Lt..
>-..... 0
::::> z ..... w
(/) :E
0 1---::c
(/) ..... a: (I)::;C> 0
>-:x:oz
::t: Octi.IJ
0 ...J
0 ~ ..... a: :Z(I)O:: 0
~ woo
Q.OI.t..
(.
t~-~··----1 2 .P
\)
~
i..
tO ~
E
..(.,
l/)
J . ._,
'tJ
"{
'!...
VI
I)
\J
c: -0 .\::
0
~
0
'!...
II> <11
d .S'
--d
0
'f
N
I
r:-:1
w cr:
:J
'-!)
ii:
n v
n
:0
"'C
"'C m z
n
0 z
C/'l c:
~
l> z
~
C/'l
~
() .....
\j
10.0
~50
!
t 4.0 -..
'v
~ :!1.0 ··-·
.....
~ c
\j 1.0
~ -
.....
;:-' 0 5.
~ 04
0.:!1
0.2
0 I ·-·--------·--·-
-·i·
2 :!> 4 5 10 20 30 40 50 100
Average penstock slope /n 7.
MICRO HYDRO STUDY
PENSTOCKS
COST ADJUSTMENT FACTOR
FOR SLOPE
FIG:JRE II-2.5
G
n
~
"tt
"tt m z
n
0 z
(/)
c:
r-
~
)>
z
~
(/)
2'J:l0
te:;o
l£00
!
~ i4C:. -...
" ~ !2~J
( j
--:coo --~ -.-,
~ -OJ'~
€:x>
4CO
~:x>
0 20
f
121
(j --(j ~I~~
::t -~
-1 -
I -; -; _____ t -·--;----;--: -·-·--I I I
--! --1-
! I
l
··-·
r-
!
----~-
~ ~ ~ ro
I ' I
i 1--
--1-
l---···
I
!--
··:-· L ··-~--i--·
I
l.
.L -r-
70
Powerhouse C/v/1 Works Dir~cl Cosl:s X It 1000
80
MICRO HYDRO STUDY
POWERHOUSE
CIVIL WORKS DIRECT COSTS
FIGURE n-26
n \J'
n
Cl :::0 -"0 C; , ::)
m ....
-"': z ~
n "' '-0 "l
·~ z
'J (f)
c: ......
r-·:)
\j ~ ., l> z ~
-! \j
(f) :.:..}
-----'
-~
......
·~
.·~
....
~
~
"t1
~J
r~ ..... . ,
-S
:"-,-: ::s
1000 ·------,-~-~~---r-1
500
. ---·--r-----~--
1 ---------t---------.
-------1-
. -------l
100 ----
50-·-·------
i i --i
-_,
I
I
I I
i -;. i
I
I
i
• I
I
I
----~ _L I I -------------.--·j I
I
1 · i 1--I ; i ' ' ' I I-
II I ; : I 1 I I! I i. • ;. I I I I I I i i i
10----------~~-~-_L ___ l _'" ___ L_ ___ ~I _______ , __ ~ ___ t_j __ ---~-!-~ ____ ------~]
I 5 10 50 100
I I I t·-__ J __ · I
' I -~-. ..__
I '
-! .
i
!-lead-Metres
'
1
-~-
1
i ! ; .\J
' ' -,. -~ ~
! I I 1 •.
i : i
----' . I __ ,__
I ' I I I
; : I
Hi
i _li 1 l
I I I I I • J____j_ ~-: •
500 1000
Nor£.
Where nydro fo hydro or
hydro to diesel units ore
to be ~ync.hron/r.ed add fiJe
Fol/c-,\'-tfi') costs:
a) When Z 1.mlfs odd I 300.0
b) For CC/CfJ ,,JfitJc.·,,,: onif
above two odd .; 2000
MICRO HYDRO STUDY
UNIT
INSTALLED ELECTRICAL AND
MECHANICAL COSTS
FIGURE n-27
A v
n
::0
"'0
"'0 m z
n
0 z
(f)
c r-
-1
)>
z
-1
(f)
.. j
'..!
..:.:
s
IJ
"--'<
"':
"
'-.,.
.j
t
~
:-:::-
·<
~C%
100:':.
50::
iOCO
5'-~~
10:
50
10 --
15
I
1.
I
. ---j ----~ -: . : r --_J
. I , . -j ____ ,_ '
I I • I --
! l ! • I ·I
J
• j
---;
. -·-c----1---;-:-,·'-:-j
I ' -·--··1 ; __
I J : : I .,
. ;
2 110 210 310 4/u 26G.8 336 477 636 795
L___l___ L__L ' __ !_________j___ _____ t I
A luminu!Tl Coote Steel IZ:.:inForced ( AC5R) Conductor Size
--! I -.
. ' ' . I
_L ____ , _ _j__~j__~_L_ __ ~I --I
20 25 30 35
lnsfa/led Transmission Line Cost .$ x 1000 per kilometre
BASIS:
Includes poles, insulators.
conductors, and hardware
installed .
A5sumes 5"' losses
MICRO HYDRO STUDY
TRANSMISSION LINE
INSTALLED UNIT COST
FIGURE Ir-28
ea. v
n ::a , ,
m z
n
0 z en c: r-
-f
)> z
-i
(/}
""' ~
'-
.....
I')
i3
......
tJ
-~
cS
VJ
l.
';:) .....
\j
t .....
S 000 0()() r"'---'--' --o _ _;_:_
I 000 000
t 500000
()
\J
' '
-! -
----------. --·--· -
. ;
I . -~-----~ ""~ '
'. '
100 OOO,.f;,.--~ "TG____ "18 ts-o----------.. ~.-----
Controc.tor's lndire.c.t
I , I I
.I
.. ·-~ 1----·---.
..,. ______ _
MICRO HYDRO STUDY
CONTRACTOR'S INDIRECT COSTS
AS A FUNCTION OF DIRECT
CIVIL WORKS COST
FIGURE li-29
n
\8
n
~
"'0
"'C m z
n
0 z
(/) c r-
-4
l> z
-4
(/)
fJ_E,><covafecl area.
;:-........_ -~
I .. ...,.J~ I~
I ........... Grovel bose ..
Dlfc r---''~-+-~ ~5
(Approx. I 0.-n) I
I. I B .I
Embonf<.ment (of nof'ura I
angle of repose}
=B
Ori9/nol 9r-ound
surPoce
SeCTION A
ROAD CUT EX'CAVATION
WITH 1:1 SID£ CUT SLOP£
'
=B
Embankment (ot natural
angle of repose)
Orig/nol 9rounc1
,5urf'oce
SECTION B
ROAD CUT e:.XCA.VATION
WITH IH'5V SID£ CUT SLOP£
I
£xcovored oreQ
o bo ve co no I.
r ----..._ -·~ -,1-;,-------LSpoil E.om.! ~+ .::=:::.::::::::....,_ ,
-Wof'~r or tee
surl"oce 't)
Canal excavated area.
SECTION C
CANAL EXCAVATION (UNLINED)
WITH 1:1 SIDE CUT SLOPE
~
E.xcovated oreo
above canol.
SECTION D
Conal exco.,.of'ed area.
CANAL EXCAVATION (UNLINED)
WITH IH·'5V SIDE CUT SLOPE
MICRO HYDRO STUDY
ACCESS ROAD AND UNLINED
CANAL SECTIONS
FIGURE n-30
0
n
~
'"'C .,
m z
n
0 z
(/') c: r-
-1
l> z
-1
(/')
Excavated area
above. canol.
SE:CT/ON A
CANAL EXCAVATION (L/N£'D)
WITH 1:1 SID£ CUT SLOP£
Original 9round
surf"oce.
Canol excavated area.
Concrete area
(Concrete lining thicf.<ness tr 0.10 m)
Orl9inal ground
surf"oce.
Conal excavated oreo.
Concrete area.
(Concrete /:n/n9 1-hicimess f:20.!0rn)
SECTION 8
CANAL £XCAVATION(L!N£DJ
WITH fH:5v SIDE CUT SL.OP£
I~
I 0
E>, D E>,
I
5E:.CTION C
/
~
("')
C)
/ ......
..,
t
Cl
" V/T
!3,=0.23 r
B =10.::?0 I
r D~.:::J.~I rn
r O.~I!E-O~C 3/n-
8,=0.313 m For D>0.9t m
PENSTOCK TRENCH EXCAVATION
(See Nole 2)
NOT£5
/. Only f"/xed dimensions
assumed /n the calculalion
or lhe 'Jlh:A'nhhes ~re
shown.
2. Penstock. shown in trench
adopted ror .:5/opes less
than 30 f/, fOr sk·~per
slopes penstock. abOve
ground on .supports h<:>s
been adopled.
MICRO HYDRO STUDY
LINED CANAL SECTIONS,
PENSTOCK TRENCH AND
EXCAVATION SECTIONS
FIGURE n-31
£?\
~
("')
AI
'"0
'"0 m z
("')
0 z
(/)
c:
r-
-i
l> z
-i
U'l
Flow ....
2.!5 p
R/prop prorectt'on
over impermeable.
membrane
3.0rn For
road cn::>sstn9
me...n?brone
SECT/ON
Q roilworer
Downsrreo,.. .;..
Gob/on blonket'J
;;:rn:fl!IT?E ,
MICRO HYDRO STUDY
HEADWORKS-GABION WEIR
FIGURE II-32
A 'g
n
:::0
"tl .,
m z
n
0 z
til c: r-
-4
)>
z
-4
(/)
l
AI t -rnJJ..-r:-T!L p.,....----(.'!~--{ -,
I
I
1·-·rvr-!.).1 +v I I
r-_ill
rt>B
r Lf> B
-----_
Flow ~ftt' -::.-s:T
~R;prop
SECTION A
Ft:nce.
Control go>'e slot
Srop lo9 slot
PLAN
2.0 m .1
o~ pen.sfock.
Bockr/11 to original
ground SIJrl'ace.
SE:.CTION B
MICRO HYDRO STUDY
HEADWORKS -INTAKE STRUCTURE
FIGURE Jr-33
G
0
:::0
"'0
"'0 rn
2
0
0
2
(/')
c: ,... ....
l>
2 ....
(/')
Conrrol
strvcrure
Conlrol
structure
Weir
lnrok.e.
w~ir
lntoke.
River
Pen-stocA
River
Penstock
R/ver
Pensfe>ck
R./ver
Pensroc.K.
Powerhov:Je.
1..z::.an.:smission 1/ne
Po~erhovse
\:[::ansmlssion 1/ne
Powerhouse
1..:[:-c::uu::r miss t'tPn line
Powerhouse
'{-ansmis:slon 1/ne
Toilrc:u;;e.
Toilroce
MICRO HYDRO STUDY
LINE DIAGRAM OF TYPICAL LAYOUTS
FIGURE li-34
A 0
n
:::0
i:'l
i:'l rn z
n
0 z
(/') c: r--c
l> z
-i
(/')
Sp«e.d ir>er.eas.u· Locar/on cl' 'l'"(y#'lll>~.et
II' l"c-qut'rt:d
=-,1,7~-;~ TYPICAl. DIMt:IVSIOA.I:J /""OR. ::$00 kW UIVIT
l~L I "'] ~ ~ ~®J'
H'!J
m.
5 -
6 1'00 -
12
PLAN
lnt'okc gat• and cpe.rofor
A
B c
!II· ...::J Mif1. T.W.L
I!)
1..
·~: . . . ..
SECTION MICRO HYDRO STUDY
LOW HEAD-LOW I HIGH OUTPUT
TYPE • TUBULAR TURBINE
FIGURE 11·35
\.
R!qhf on9,~ tn::m!!;m;ss;on\
{:>p.::ecl tncrc-os::r lr i"lii:<fUtrt!C{)
PLAA..I
,'c
SeCTION
-----
1
--I -----..L
MICRO HYDRO STUDY
LOW HEAD -MEDIUM OU'7P:.JT
TYPE-RIGHT ANGLE BULB TURS:::E
FIGURE !! -3 5
n y
(')
::0
"'C
"'C m z
(')
0 z
(/') c r-
~
l> z
~
(/')
~E· Ftorv ;tl I_ -~ ·-·
·i_ ! !-~-~-
1400 ,--------l
(____!____ ,_ ... ~-r-_ ~ --, ~~~~-.
I
I
[__ ___ ~
SlOE ELEVATIOA.I
----,
()lr:: a ·-
!OJ ~
()
(IJ
10
()
~
TYPICAL O!MeAJStONS FOR 25/tOOkN UNtr
H~od lOvtpvfl
"'· ;,.v I
10 25 i
20 ~0
.50 !00
G~en:>~r
I I t MICRO HYDRO STUDY
'----------LOW a MED. HEAD -LOW OUTPUT
TYPE-TWO JET HYDEC TURBINE
EA.ID ELEVATION·
FIGURE I I-37
fii._ v
(')
:::0 , ,
m z
(')
0 z
(/) c
~
l> z
-i
VI
Ill
5pc<:d
in<:.rtll!~Gr
PLAN
L~
SECTION
; .. ·
-:.;
... •t> .4'
H$
max.
MICRO HYDRO STUDY
LOW a MED. HEAD· LOW a MED. OUTPUT
TYPE· BANKI TURBINE
FIGURE I I • 38
£\ v
n
::0
"'0
"'0 m z
n
0 z
(/')
c:
I"'"
-4
l> z
-4
(/')
locahon of" f'lywh.rc/ a,cf
sp•ecl ,nc~.:!T•,. II' nequJr<!C/.
-+~~--~-1-
PLAN
A a,
SIDe eLEVATION
I
'
82.
I I
,_L_
I
I
I I I ~ -±· -,: I. 1.:__ --
1
I .,.. L ____ _
TYPICAL DIMEA.JStOA.IS FOR 250 I< VII UA.Itr
H«KK A B, 82 c m.
12 1800 1500 2.500 1200
20 1750 1200 1800 900 --4!:> 1700 1000 1.500 600
c--·
60 1700 900 /100 500
l
END ELeVATION
D E F G ~,. s,.....,
MOA r.p.l'n
<'000 .?X>O 1.200 1000 5=oc ~00
1600 /GOO IDOO 750 ~co::; 514
1100 1100 800 =o5CCO 9:/0
1000 1000 700 4=F 900
MICRO HYDRO STUDY
LOW S. MED. HEAD -MEO. OUTPUT
TYPE-HORIZONTAL FRANCIS IN DRUM
FIGURE 1 I-39
~
~
n
::u
""0
""0 m z
n
0 z
(J')
c
r
-1
l> z
-1
(J') l .i .. Gc.nc,..,:r _.,~ 8 t --
'
n ' l i
-1--
r------"'
SIDE ELt:VATION
,, -
I('
I -I
I
Q
Oral"f l'r.tl>lll
bend
~I ,Jr-T II /1 I
I\ 1 I u r 1--+ , I I \ T ~II j : I_J,..,~ :: t t=~-~--:]
L------
TYPICAL DIME/1../.SIOJVS FOR !OOOkW W.J!T
~
XC!
720
MICRO HYDRO STUDY
MED. HEAD -HIGH OUTPUT
TY?E-HORIZONTAL FRANCIS IN SPIRAL
C:ND ELEVATION
FIGURE II-40
APPENDIX Ill
SUPPORTING INFORMATION
A B.C. Water Licencing Information
B Flow Duration Curve Calculation
C Storage Requirement Using Mass
Curve Analysis
APPEND I X Ill
SUPPORTING INFORMATION
A. B.C. WATER LICENCING INFORMATION
In general, the ownership of water in B.C. and the right to use water is
vested in the Crown in the right of the Province. No right to divert or
use water can be acquired by prescription. Thus any person who uses
water without a licence has no rights to that water and the water could
be taken away from him without recourse if a I icence for its use is
issued to another party.
A licence entitles the holder to beneficially use water for the purpose
for which the licence is issued and in accord with the conditions of the
licence. The holder is also entitled to construct, maintain and operate
works which makes the use of the water possible. A water licence may
be issued to any owner of land, owner of a mine, holder of a certificate
of public convenience and necessity, municipality, improvement
district, Minister of the Crown, or any board, corporation or person
having charge of administration of any land. Where there is more than
one licence holder on a stream, the precedence for use is in accord with
the respective priorities of dates of issue. In other words, the earliest
issued licence has first right of use if water is in short supply.
A water licence is made appurtenant to the land or mine where it is
used and shall pass with any conveyance of the land or mine just as if it
was part of that property.
The B.C. Water Act is administered by the Comptroller of Water Rights
of the Ministry of the Environment.
Annual water licence rental fees are nominal and are based on the
capacity of the hydroelectric plant and on the energy produced. If
Ill (A)-I
storage is developed in conjunction with the plant an additional fee is
charged based on the quantity of water stored and used.
Attached are the following sample forms:
I. Information Regarding Applications for Water Licences
2. Application Forms for a Water Licence
3. Form of Conditional Water Licence
4. Form of Final Water Licence
Initially, a conditional water licence is issued stating the conditions
that have to be met with regard to the use of the water. In theory, a
final licence is issued when all conditions have been met, but because of
the very large backlog of licence applications, a final licence may not
be issued for many years. This backlog of applications presents a
problem as far as getting even a conditional licence in a short time is
concerned unless a priority for processing the application can be
established. Applications can also suffer long delays if there are
serious objections to the proposed project that makes it necessary to
carry out further studies or if hearings require to be held. However,
this latter concern should not be a problem in most cases as far as
micro hydro is concerned.
If a micro hydro project is developed by a small, unorganized commun-
ity there should be some organization formed for financing it and to be
responsible for its operation and maintenance. This organization could
be an Improvement District, which can be formed under the Water Act.
It would have elected trustees to take care of any day to day affairs.
The purposes for which it is formed are required to be set out in Letters
Patent.
Thus once established the Improvement District is a legal entity which
can borrow money and set rates for the sale of power.
Ill (A) - 2
MINISTRY OF TilE ENVIRONMENT
Water Right~ Branch, l'arli~ment Buildings, Victoria, B.C. V8V IX5
INFOHJ\IATJON HEGAHDING Al•PLJCATIONS FOR WATEH LICENCES
In order to help you fill in a water application correctly, a few suggestions are set out below:
.Application forlllj' must be complrtcd in full. It is particularly important that the quaruity of
waur rcquirt'd is shown.
Domestic purpose: "Means the use of water for household requirements, sanitation, and fire prevention, the
watering of domestic animals and poultry, and the irrigation of a garden not exceeding one quarter of ao
acrt adjoining and occupied with any dwelling-house."
The normal requirement for one household, including the irrigation of a small garden, is 500 gallons a day.
However, if the watcrine of poultry and domestic animals other than pets is included, water requirements
may be 1,000 gallons a day.
Irrigation purpose: "Means the bcnefJcial use of water on cultivated land and hay meadows for nourishing
crops."
The quantity needed should be stJted in acre-feet per annum. An acre-foot of water is the quantity which
will cover I acre, I foot in depth.
As quantities required for irrigation vary depending on local climate and conditions, the following general
guide should be used:
Climate Quantity ltl!'quirW
Wet or roo] ___ , .. ~-~--------------------acre-foot per acre
Semidry or worm .. -·-~-----·----------------2-3 acre-feet per acre
Dry or hoL__ ..... ---·---~----·---.. 3-4 ·acre-feet per acre
Thus, if you live in a dry or hot area and wish to irrigate 10 acres you should apply for 40 acre-feet.
Any advice you need regarding water applications can be obtained from the Water Rights Branch offices
in the Provincial Government Buildings, at Victoria, Kaml>~ops, Nelson, and at 1905 Kent Road, Kelowna,
B.C.; 313 Sixth Street, New Westminster, B.C.; and 1488 Fourth Avenue, Prince George, B.C. Advice may
also be obtained from any of the Water Recorders listed below.
Tdephone
Alberni.___ 4515 Eliz.ab<cth Strtet, Port Alb<crni V9Y 6U ----723-3501
Ashcroft .Box 70, C'inton VOK 1 KQ _____ _ -----453-2412
Allin_. __________ !lox 100, At! in VOW lAO----·-·--371
Cariboo _________ 540 Hnrland S<reet. Williams Lake V2G IR8 .... --------392-6261
CranbrooL ______ 100-lltb Avenue Sou:h. Cranbrook VIC2P2.._ .. _____ 426·8431
Fernie_____ llo> 340, Fernie VOB t MO ....... ___ 423-6845
·Golden_ .. ________ Rox 39, Golden VOl\ 1110 ............. -----------·-.. --344-6817
Grond Forls_ .... _____ lle>< 850. Grnnd For•< VOH 1110... ... _ 442-8642
Hazelton __________ .. Bo< 340, Smithers VOJ 2NO. 847-4411
Kamloops __________ 7 West &;ymour Street. Kamloops V2C JES .......... _ .... _ 372·5233
Kaslo_.. Box 580, Kaslo VOG l~lO ..... _ ........ _........... .. 353-2338
Liard_____ 1201-103 "'venue, Dowson Creek V!G 412 ....... -------786.5721
Nanaimo .Courthouse, Nanaimo V9R SJ L ................... ________ 754-2111
Ncl><>n ·--------.. ____ .... Bnx 730. Nchon VIL SRS ............ -----------·--352-2211
New Westminster ___ ...... 10(}-.403 Si>tb Street, New Westminster V3L 3B L....... 525-037 5
Nicola Dox 339, Merrill VOK 2BO ..................... ------.. -·--378-9944
Peace Riv<'--·---· .. .120!-103 "'venue, Dawson Creek VIG 412_.... 786-5721
Pcnticlon .... Courthouse, Pcntic!On V21\ 51\5 ...... -----·-·---·--·---.... 492·2782
Prince George _____ .. ___ 1600 Third "'venue, Prince Gcor~e V2L 3G6____ 562-2111
Prince Ru~rl-------Courth•>Ust, Prince R11pert V8J 1!17 ........ _________ 624-2121
Princeton.......__. ___ ........... Box 9. Princeton VOX 1 WO. . .......... ----------295·6151
Quesnd ________ , __ I02-)50 Barlow "'''<nHc, Quesnel V2J 2CJ.. ______ , ___ 992·5591
Rcvebtokc_. _________ Dox :180. Rcvchtokc \'OE :so ........ ---------------·--937-3122
Vancou,·cr ...... ,_._, ____ 635 Burrard Street, Vancouv<r V6C 2L4-..... ---------684-9111
Vernon ....... -......... ______ courthou..:, Vtrnon VIT 4\1/S.-... -------------545·2387
Victoria_. _________ Parlbmcnt Buildings, Victoria VSV IX5 .... -.. ---------387-)41)
Rt!aion:al Enginrcr
Victoria
Kamloops
Prince Georte
Kamloops
Nelson
Nelson
Nelson
Kt'Iowna
Prince George
Kamloops
Nelson
Prince George
Victoria
Nelson
New We!.lmin~..ter
Kamloops
Prince George
Kdowna
Prince Gcor~e
Prinu: George
Kelowna
Prin<:<: George
Kclowna
New We.otmimter
Kclowna
Victoria
If your application is not correctly completed you may be required to make out a oew application at a
later date.
W.l\8,1-o
Ill (A) -3
Application for a W atcr Licence
WATER ACT
(Section 8)
(f\lll n.amc ar no.rnM. it l~ond owned joint:y .}
JOR WAll.R. RI£0RUl H. ~lAl..H'
of ·--··-····--······ ·······-······-··········--·······-·······-···-······-·· ........................... ··············--··-····-··················
CMailini addrns}
hereby apply to the Comptroller of Water Rights for a licence to ~divert and usc lf water out of
l store
----···----------··········-····-···---················ ............. which flows . ············-············
(Name of ucck, We. or •prior.} (Direction of ftow.)
aod discharges into . ·····-·····------··--·----·--·-·····and give notice of my application
to all persons afiectcd.
~~;:;~~eo~ a: version} will be located at·--·· ·-·((;;~~·.;;;;~~;;·~~:;.;;,;;;;~~;~·~;;,-,:;;;;~·;~-~;~;.;·~;k:",;~~ pmnr.)
The quantity of water to be diverted or stored is. ·-·-····-··· .
(CubK: tnt per IU:cond, , .. uons per diY, or 4liCfc-fect pn annum.)
The purpose for which the water will be used is .
The land or mine on which the water will be used is Lot
A copy of this application was posted on the
(Day,) (Month.)
... , 19 ....
at the proposed point of diversion or site of the dam and on the land or mine where the water is to be used
and two copies will be filed in the office of the Water Recorder aL ..... ---------------------------
British Columbia.
Objections to this application may oc filed with the said Water Recorder or with the Comptroller of Water
Rights, Parliament Buildings, Victoria, B.C. V8V I X5, wah in thirty days of the serving of a signed copy o(
the application.
Applicant.
By·----····--···· --------·-····----·--·····-------------
Ag~nl.
A gtn(s addrtll.
IMPORTAST
Every applicant mu't do the following:
(1) Post 1hr opp};'(·mion on rl1c ~:ruund; that is, in conspicuous places at or ntar the proposed point of diversion. site
o( the dam (if any), and ptoce o[ use.
(2) Fill' two copirs k·ith tire W4ifn Rrcordrr in whose dhlrict the point o{ diversion Will be-. within~ days of th~
po$tinc on the (:round.
(3) \\'lthin nindv tL•)·s of the JX1Jting of the :lpplic:nion on the r:round, strve ~lgncJ copic~ on all owner-s of JanJ or
mining property thJt "ill be alkch:d phy!-.ical!)' hy the propo'\cd wod .. s or by the opera! ion or uttl•zation the-reof.
and on 01!1 hccn~cc!t or prior appliCants whose po1nts of (IJvcr::.ion are at or below 1he Jpphcant's prupo~J point
of diversion.
All ropie, must ht slf:ntJ and compk!C'd by filling in the bbnl'{, in the above form, and, in adJition, the two cop1es fikd
with the" \Vater Rcc.:o1 ~!a mu'>l cont•tin a sl..ctch ~ho\.\ in~ the applic.lnt's l:1nJ, the locatwn •A !he potnt of ~.hvcnion and the
dam (if any). and alt l.wJ touched or cro~'-<'d hy 1he worl~. and the adJit~onal informatiun indicated on the other siJc
of thi' form.
Both !'oiJes of the lwo copin filed with the Wilttr Recorder must be fully and correctly complcteJ or the application may
have to bC' returned,
It iii ih.l¥i~ott>k to f.l~,· the ;lpf'llK.1ti~m 'lll'ith the W.tter Ke<:ordt'"r M ~n a'\ f"N.l'\ih!e ahcr fl'tlll!ng it on the ground bt't:JUM"
the d.1tc of fi11ng \.\ill, in ntO'>il-;t"''· J~.:ternunc the pram!y ot 1hc hccn\.'c lh.tt nLl'f he tHucJ.
Ill (A) - 4
Non.-TI•is 5hcl'l need only be completed on the two copies of the application filed with the Water
Recorder.
1'o the Comptroller of Water Rights:
In support of my ;~pplication for a water licence I submit the following information:-
(J) My title to the place of use is ~-------~~-··------···------·--·---··-···----------·-··-····------------··--·---·-·-·-··---·-·-
(Wh«Lhc:t ttJislned owou. a&rnment holder. pu-cmptor, ~Cc.)
(2) The proposed works will be ............ ----------------------------------... «--------------------------------------·------·-··-·
{Giw JftU:ral devtiption--pump. pipt~ d1tch, etc.)
(3) The dam to be constructed will be -------------------------------------·-----·-------------·-------·-·------•u~'"• and
will be ________________________ feet in height, and ____________________ Ject in length.
(4) The maximum area of the reservoir will bc~--------------·-···-----acres.
(5) The depth of storage at the dam, from boHom of sluice-pipe to crest of the spillway, will be -----~·--·-----.feet.
(6) The head of wotcr to be used will be .. _____ ---···---------------~-------------feet.
(For J>O'lllet and hydraulic .aii.n.lna ob.ly.)
(7) The area of land to be irrigated will be .. ~~~~-·---------·------------acres.
(8) (a) The works will be entirely on my own property, or
(b) The works will a!Icct physically the property of the following owners:-
Name or Owna. Uaal Ductiption of l.and lndudi.n.& Che Crown
Au.a R.t:Quircd tor Works
L<nath Brudlh
Sketch, showing applicant's land and all other land touched by the works or flooded, also the location of
the point of diversion and other works, including buildings to be served with water, if applicable, and the lengths
of all dit.::hes, flumes, and pipes.
-···-·--·-·-··-----·-<.-H••·--------Applicanl,
W.IUI. <I-0
Ill (A) - 5
J.ANP AND WATf."k MANACFMFNT
WATEk kJGIITS hHANCJI
------·-------l J.11NI~TH.Y OF THt',
LNVIHONMY-NT
TilE PROVJ:-.ICE OF flRlTlSJI COLU~IBIA-WATER ACT
CONDITIONAL \VATER LICENCE
is/arc hcr~by authorized to water as follows:-
(a) The source(s) of the water-supply is/arc
(b) The point(s) of is/are located as shown on the attached plan.
(c) The date from which this licence shall h:~vc precedence is
(d) The purpose for which the w:~ter is to be used is
(e) The maximum qu:~ntity of w:~tcr which may be
and such additional quantity
as the Engineer may from time to time determine should be allowed for losses ..
(f) The period of the year during which the water may be
(g) The land upon which the water is to be used and to which this licence is appurtenant is
(h) The works authorized to be constructed are
which shall be located approximately as shown on the attached plan.
(i) The construction of the said works
Comprrollu of Waur Rights.
File No. Date issued: Conditional Licence No.
0
III(A)-6
(){ t"Akl Mf Nl Of
LNVIM.UN~H P.. T
THE PROVJNCE OF BRITISH COLUMBIA-WATER ACf
FINAL \VATER LICENCE
is/arc hereby authorized to water as follows:-.
(a) The sourcc(s) of the water-supply is/are
(b) The point(s) of is/are located as shown on the attached plan.
(c) The date from which this licence shall have precedence is
(d) The purpose for which the water is to be used is
(e) The maximum quantity o! water which may be
and such additional quantity
as the Engineer may from time to time determine should be allowed for losses.
(/) The period of the year during which the water may be
(g) The land upon which the water is to be used and to which this licence is appurtenant is
(h) The works authorized hereunder are
located as shown on the attached plan.
(i) This licence is issued in substitution of Conditional Water Licence No.
Comptroller of Water Rights.
File No. Date issued: Final Licence No.
0
Ill (A) -7
B.
APPENDIX Ill
FLOW DURATION CURVE CALCULATION*
A rough appraisal of a stream flow record can be obtained by listing the
minimum, the average, and the maximum flow. However, for detailed
studies, it should be known more precisely how often low flows or high
flows occurred during the period of record. This can be accomplished
by preparing a duration curve in which magnitude of discharge is
plotted against the percentage of time that discharge is exceeded. A
duration curve can be prepared for any period of time. One can prepare
a duration curve of daily flows, mean monthly flows, or mean annual
flows.
One way to prepare a duration curve is as follows. The total range of
discharge, say from 0-! 00,000 cusec, is divided into 20 compartments
of 5,000 cusec. One starts scanning through the selected period of
record, day by day for a duration curve of daily flows (which is a
tremendous amount of work), or month by month (for a duration curve
of mean monthly flows). For this micro hydro study, a monthly basis is
recommended. For every item in the record, a mark is made in the
appropriate compartment. When all items are entered, one could plot
the results as shown in Figure III(B)-1 (a), which shows the so-called
frequency distribution of the sample. The compartment with the
largest number of items is called the mode of the sample.
When the frequency curve of Figure III(B)-1 (a) is accumulated, com-
partment by compartment, starting with the low value, the total
frequency curve, or duration of Figure III(B)-1 (b), is obtained. The
vertical ordinate still shows the discharge, the horizontal ordinate
represents the total number of items, or, more conveniently, the per
cent of the time. In plotting the points of the duration curve, one must
*Reference -Water Resource Development by E. Kuiper.
Ill (B) -I
realize that the total number of items in, say, the first four compart-
ments (0-20,000 cusec) must be plotted right on the 20,000 cusec value.
After all 20 points are plotted, a smooth line can be drawn through the
points. With this duration curve we can now select any discharge and
find the per cent of time this discharge is exceeded. The stream flow
value that is exceeded 50 per cent of the time is called the median
flow. The average value of all items is called the mean flow. Since
nearly all natural stream flows have an asymmetrical distribution (the
high values deviate much more from the average than the low values) it
follows that the median flow and the mean flow are usually not the
same, as may be seen in Figure III(B)-1 (b). The median flow can be read
directly from the curve. The mean flow can be found by drawing a
horizontal line, such that the two shaded areas are equal in size, or by
computing the arithmetic average of the sample.
Ill (B) -2
B.) F.LOW DURATION CURVE CALCULATION. (Cont.)
0 .,
"' ' ...
E
1.1
01 ...
0 .r:;;
0
"' 0
100
80
60
40
20
u
C)
"'
80
;;-60
E
1.1
01 ...
0
.r:;; 40 u
"' ·-0
80
Number of items
(a)
FREQUENCY CURVE
Percent of time exceeded
60 40 20 0
I
I
I
' I
I
I
I
I
I
I
0~------------------------------------~
(b)
DURATION CURVE
FIGURE m (B) -I
c.
APPENDIX Ill
STORAGE REQUIREMENT USING MASS CURVES ANALYSIS
The mass curve is a graphical tool, to review long-term trends in the
river f!ow. It is also a convenient device to estimate storage
requirements that are needed to produce a certain dependable flow
from a reservoir. To illustrate the technique of doing this, a hydro-
graph of river flow is shown in Figure I (a). It is assumed that the
recorded flows show the two years 1930 and 1931 as the lowest
cumulative flow period on record. The problem is to find the storage
capacity required to increase the minimum natural flow of 2 m 3 Is to a
dependable flow of 20 m 3 Is. In this simple example, this problem can
easily be solved without resorting to a mass curve. All we have to do,
is to draw a horizontal line at the ordinate of 20 m 3 Is in Figure I (a),
planimeter the shaded area, apply a conversion and find the required
storage capacity. Let us now solve the same problem by using the mass
curve shown in Figure I (a).
The mass curve is the summation of the hydrograph. The abscissae are
in the same units of time as the hydrograph. The ordinates represent
the total volume of water that has passed from zero time up to that
point. The slope of the mass curve at any point represents change of
volume per change of time; in other words the rate of flow at that
moment. Hence the mass curve is steep when the river flow is large,
and flat when the flow is low. A small key diagram showing the value
of slope in terms of cubic meters per sec0nd is convenient in appraising
a mass curve. The slope of a line joining any two points of the curve
represents the uniform rate of discharge that would have yielded the
same total incremental volume in the same period. For instance, in
Figure I (b), going from A to C along the mass curve, represents the
same volume of water as going from A to C along the straight line.
This feature of the mass curve enables ready determination of the
amount of required storage capacity. Assume that adequate, but yet
unknown, storage capacity is avai !able at Point A (where the 20 m 3 Is
Ill (C)-I
slope is tangent to the mass curve). From that moment on the release
from the reservoir is 20 m 3 Is, but the inflow into the reservoir is less
and therefore the reservoir level goes down. At any time between A
and C, the length of the ordinate intercepted between the straight line
AC and the mass curve measures directly the total amount by which the
reservoir capacity has been reduced. The maximum ordinate is reached
at point B, and measures 90,000 m 3 on the vertical scale. In other
words, if the reservoir capacity had been 90,000 m 3 to start with, a
flow of 20 m 3 Is could have been maintained from A to B. After B, the
inflow to the reservoir is greater than 20 m3 1s. If we would still
release no more than 20 m 3 Is, the reservoir would gradually be fi lied
and would be full again at C. It is interesting to note the corresponding
features in Figures I (a) and I (b).
.
Cl.>
~
0
.s::;
u "' .~ 0
'0 -
><
'0 "' Cl.> E
u
Cl.>
~ 80
"' E 60
~1,0
~
1 20
u
(a)
~ o~~~-L~~~~~~~~~~~~~
0 J F M A M I J A S 0 N 0 IfF M A M I I A S 0 N 0
1930 I I 11931 :
500
1,00
300
: Required : :
storage 1 1 I capac1ty c
I
I
0 200
::J
E
::J
u u
<l:
100 (b)
OL-~~~-L~~~~~~-L~~~
IFMAMIIASONDJFMAMIIASONO
1930 1331
FIGURE
Ill (C)-2
If the energy that can be generated by a hydro plant from a steady
stream flow equals the average weekly load demand, one may think that
the plant will have no difficulty in meeting the load. However, the
stream flow provides a steady supply of energy, whereas the system
load is continuously fluctuating. The only possibility to let the steady
supply meet the fluctuating demand is to store water in the reservoir
above the plant whenever there is less demand than supply. If a hydro
plant is able to do this over weekly periods, it is said to have sufficient
pondage capacity. The fluctuation of the pondage reservoir may look
G.>
"0
"0
nl I I .3 I M 'T w T • : i SFull ouppl-IMI
F 5
FIGURE 2. PONDAGE OPERATION
s
somewhat as shown m Figure 2. It may be seen from this figure that
due to the pondage operation, the average reservoir level is less than
the full supply level. This is a disadvantage since it means that the
plant operates at a less than maximum head and therefore produces less
energy than possible.
For preliminary estimates for small B.C. communities with small
amounts of industrial load and where the available streamflow is only
just equal to that required to meet the average load, 25 per cent of
average daily energy consumption is required from pondage. This figure
should be used if local information is unavai !able.
Ill (C)-3
APPENDIX IV
MANUFACTURERS Af\JD SUPPLIERS
A Off Shore
B United States of America
C Canada
A.
APPENDIX IV
MANUFACTURERS AND SUPPLIERS
OFF SHORE
Ateliers des Charmilles SA, (1, 3)
I 09 Rue De Lyon
CH-1211 Geneva 13
Switzerland (022 458821)
Ateliers de Constructions Mecanique (I ,3)
de Vevey
CH-1800 Vevey
Switzerland
Bell Maschinen F abrik A. G. (I ,3)
6010 Kriens
Lucerne
Switzerland
A.B. Bofors-Nohab (I, 3)
S-46101
T rollhattan
Sweden
Boving & Company Ltd. (I)
Villiers House
41-47 Strand
London WC2N5LB
England
Electro GmbH (I)
St. Gallerstrasse 27
Winterthur
Switzerland
IV-I
NORTH AMERICAN REPRESENTATIVES
Charmilles
Euro-USA Company
779 Barbara Avenue
Solana Beach, CA 92075
U.S.A.
None
Same as Escher-Wyss Ltd.
None
None
None
Escher-Wyss, Ltd. (I, 3)
Hardstrasse 319
CH8023 Zurich
Switzerland (01246 2211)
Fuji Electric Ca. Ltd.(!, 2, 3)
12-1 Yurakucho 1-Chow
Chiyoda-ku
Tokyo, I 00 Japan
Gilbert Gilkes & Gordon Ltd. (1, 4)
Kendal
Cumbria LA9 7BZ
England
Hitachi Ltd. (I, 2, 3)
New Maru Bui !ding
Maranouchi
Chiyoda-ku
Tokyo, Japan
Hydroart S.p.A. (I, 3)
20144 Milan
Via Standhal 34
Italy (479104)
Jyoti Ltd. (I, 3, 4)
lnterr.ational Division
Bombay Shopping Centre
R.C. Dutt Road
Vadodara 390 005
India
AB Karlstads Mekaniska Werkstad
S-681-01
Kristenehamn I
Sweden
(46) 550 152 00
Kassler Ges. m.b.H Maschinenfabrik
A-3151 St. Po !ten St. Georgen
Austria
IV-2
Sulzer Bros. Canada Ltd.
Nissho-lwai Canada Ltd.
Electric Power Equipment Ltd.
1285 Homer Street
Vancouver, B.C.
V6B 2Z2
(604) 682-4221
C. ltoh & Co. (Canada) Ltd.
None
None
Axel-Johnson Corp.
I Market Plaza
San Francisco, Co 941 05
U.S.A.
Same as Voest-Aipine AG
Kvaerner Brug A/S (I, 3)
Box 3610, Kvaernerveien I 0
Oslo, I
Norway
Maschinenfabrik B. Maier
4812 Brackwede
Brockhagner Strasse 14/20
Postfach 320
West Germany
Mitsubishi Heavy Industries Ltd. (I ,2,3)
5-1 Maranouchi, 2-Chome
Chiyoda-ku
Tokyo 100
Japan
Neyrpic Department Turbines (1, 3, 4)
Rue General Mangin
38100 Grenoble
France
(7 6) 96.48.30
Ossberger T urbinenfabrik
D-8832 Weissenburg in Bayern
P.O. Box 425
Weissenburg, Germany
(0 91 41) 4091
Sorumsand Verksted A/S (I, 3)
N-1920 Sorumsand
Norway
OY T ampella AB (I, 4)
P.O. Box 267
SF -33 I 0 I T ampere I 0
Finland (931-32400)
Titovi Zavodi Litostroj (I)
61000 Ljubljana
Djakoviceva 36
P.O. Box 308-VI
Yugoslavia
IV-3
Kvaerner-Moss Inc.
31st Floor 800 Third Avenue
New York, N.Y. 10022
U.S.A.
None
Mitsubishi Canada Ltd.
Marine lndustrie Limitee
Division Hydroelectrique
Sorel (Tracy) Quebec
J3P SPS
Canada (514) 743-3351
F. W .E. Stapenhorst Inc.
285 Labrosse Avenue
Point Claire, Quebec
H9RIA3
Canada
(514) 695-2044
Madden Paper & Paper Board
Service Corp
9 Rockefeller Plaza
New York N.Y. 10020
U.S.A.
None
None
Tokyo Shibaura Electric Co. Ltd. (1,2,3)
<Toshiba)
Producer Goods Export Division
1-Chome, Ushisaiwaicho
Chiyoda-ku, Tokyo
100 Japan
Voest-Aipine AG (I, 3)
Muldenstrasse 5, P.O. Box 2
A-4010 Linz
Austria (0732 585 8083)
J. M. Voith, G.m.b.H (I, 3)
Postfach I 940
D-7920 Heidenheim
West Germany
(0 73 21) 32 21
Westward Mouldings Limited
Green hi II Works
Delaware Road
Gunnislake, Cornwall
England
B. UNITED STATES OF AMERICA
Alaska Wind and Water Power
Box G
Chugiak, Alaska 99566
Allis-Chalmers (I)
Hydro-Turbine Division
East Berlin Road
Box 712
York, PA 17405
(717) 792-3511
American Ligurian Company
IS Ralsey Road South
P .0. Box I 005
Stamford, CT 06902
IV-4
None
Industrial Process Heat Engineering
Ltd.
680 Raymur Street
Vancouver, B.C.
V6A 2RI
Canada
(604) 254-0461
None
None
Arbanas lndustr ies
24 Hi II Street
Xenia, OH 45385
(513) 372-1884
Border Electric Company
Route I
Blaine, WA 98230
(206) 332-5545
Cascade Patterns
1309 Glenwood Drive
Mount Vernon, WA 98273
(206) 856-6608
Davis Constructors and Engineers, Inc.
P. 0. Box 4-2360
Anchorage, AK 99509
Electric Machinery Manufacturing Co. (2)
A Division of T urbodyne Corp.
800 Central Avenue
Minneapolis, MN 55413
General Electric Company (2)
One River Road
Schenectady, NY 12345
(518) 385-5444
Hannon Electric Company
1605 Waynesburg Drive S.E.
Canton, OH 44707
(216) 456-4728
Hydrotool Corporation
2640 Industry Way
Lynwood, CA 90262
(213) 639-4402
Kato Engineering (2)
P.O. Box 47
Mankato
Minnesota 5600 I
(507) 625-40 II
IV-5
The James Leffel Company (I)
426 East Street
Springfield, OH 4550 I
Lima Electric Company (2)
200 E. Chapman Road
Box 918
Lima, OH 45802
(419) 227-7327
National Tank & Pipe Company
P.O. Box 7
I 0037 S.E. Mather Road
Clackamas, OR 97105
Attention: Steve Mclaughlin, Sales
(503) 656-1991
Pumps, Pipe and Power
Kingston Village
Autin, Nevada 89310
Short Stoppers Electric
Route 4 Box 247
Coos Bay, OR 97420
(503) 267-3559
Small Hydroelectric Systems (I, 4)
and Equipment
Box 124
Custer, W A 98240
(206) 366-7 696
Westinghouse Electric Corp. (2)
700 Braddock Avenue
East Pittsburgh, PA 15112
Wind and Water Power
P.O. Box 49
Harrisville, NH 03450
(603) 827-3367
Woodward Governor Company (3)
500 I North Second Street
Rockford, Illinois 61101
(815) 877-7441
IV-6
C. CANADA
Barber Hydraulic Turbine, Ltd. (1, 4)
Barber Point, Box 340
Port Colborne, Ontario
(416) 363-4929
Brown Boveri Canada Limited (2)
160 St. Joseph Blvd.
Lachine, Quebec
H8S 2L5
(514) 637-5531
Dependable Turbines Ltd. (4)
1244 Boundary Road
Vancouver, B.C.
V5K 4T6
(604) 299-2626
Dominion Bridge-Sulzer Inc. (I)
295 Hymus Blvd.
Point Claire, Quebec
H9R 4N9
Ingersoll-Rand Canada Inc. (5)
1695 Main Street
Vancouver, B.C.
Leroy-Somer Company of Canada Ltd. (I ,2,4)
337 Deslauriers
Montreal, Quebec
H4NIW2
(514) 332-1880
Marine lndustrie Limitee
Division Hydroelectrique
Sorel (Tracy) Quebec
J3P 5P5
(514) 743-3351
National Energy Systems Ltd. (4)
7759 Edmonds Street
Burnaby, B.C.
V3N 189
(604) 524-0817
IV-7
Niagara Water Wheels Ltd. (5)
706 East Main Street
We II and, Ontario
L3B 3Y4
Small Hydro-Eiectrics Canada Ltd. (4)
Box 54
Silverton, B.C.
(604) 358-2406
Thomson and Howe Energy Systems
Box 2
Kimberly, B.C.
VIA 2Y3
Water Wheels Canada (5)
8555 Cornish Street
Vancouver, B. C.
V6P SB7
Water Wheel Erectors Limited (4)
P.O. Box 487
Port Colborne, Ontario
L3K SX7
(416) 835-5402
Suffices:
(I) Turbine designers and manufacturers
(2) Generator designers and manufacturers
(3) Governor designers and manufacturers
(4) Package Units
(5) Supplier and/or installer of electrical or mechanical equipment
IV-8
APPENDIX V
HYDRO-ELECTRIC CAPACITY DETERMINATION
(Hydro Plant With Secondary Energy Generation}
A. lntroduct ion
B. Method
I. Flow Duration Relationship
2. Load Duration
3. Diesel Fuel Cost Calculation
4. Incremental Benefit/Cost Analysis
5. Final Step
FIGURES
V-I Hydro Capacity Determination With Secondary
Energy
V -2 Hydro-Electric Capacity Determination -
Benefit Comparison -Sheet I
V-3 Hydro-Electric Capacity Determination-
Benefit Comparison -Sheet 2
APPENDIX V
HYDRO-ELECTRIC CAPACITY DETERMINATION
(Hydro Plant With Secondary Energy Generation)
A. INTRODUCTION
B.
The method set out uses an economic analysis to determine the
optimum hydro capacity in a situation where hydro is installed to
provide primary and secondary energy with diesel standby to operate in
times of water shortage.
METHOD
The method uses flow and load duration curves to estimate the amount
of energy that must be provided by diesel standby. From this the cost
of fuel is computed.
The capital cost of at least three alternative hydro installations with
increasing capacities must be estimated. Guidelines are given on Fig.
V-I for the choice of hydro capacity of the alternatives, however,
experience will enable a user to use judgment in this choice.
The capital cost of the diesel standby is also estimated. Hence three
alternatives are casted using standard costing procedures as set out in
the main section of this manual. The details of the method are set out
below.
B.l Flow Duration
In run of the river projects minimum flows are considered for the supply
of firm power. There is the potential in these projects to generate
secondary energy, particularly if the proposed scheme will displace an
existing diesel plant which can be maintained as standby.
V-1
For analysis of schemes utilizing higher than firm flow, a duration
curve is required. The method is set out in "Water Resources
Development" by Kuiper, page 30, copied in Appendix Ill B. For this
study the curve should be constructed from mean monthly flow records
adjusted for the proposed diversion point in the ratio of the tributary
catchment areas.
The site capacity duration curve is derived from the flow duration
curve by multiplying the flow ordinates by 7 x H where H is the gross
head available at the site.
8.2 Load Duration
The demand for power is represented by the load growth curve and the
load duration curve. Annual load duration is considered since the
analysis is done on an annual basis. The load duration curve is
developed as set out on Figure V-I, if data are unavai !able for the site
being studied.
Annual load duration curves move up the vertical axis as the load grows
(assuming the load factor remains constant). The Oth, 12th and 24th
year load duration curves are used to determine the growth in energy
demand during the project I if e.
8.3 Diesel Fuel Cost Calculation
Diesel fuel costs are computed from the annual energy provided by the
standby. This cost is computed by superLnposing the load duration and
capacity duration curves, and measuring the area, under the load
duration curve and above the site capacity curve. This is done for the
Oth, 12th and 24th years. The annual energy is then computed
graphically as shown on Figure V-1. Diesel fuel costs are computed
using the conversion factor and are entered in Figure V -2.
Superposition of load and capacity duration curves is possible as load is
essentially a daily fluctuation and flow has a much longer time base.
V-2
B.4 Incremental Benefit/Cost Analysis
Operating and maintenance costs are calculated using the cost curves in
the main section of the manual and are entered in Figure V-2.
Incremental capital costs and depreciation allowance (at the approp-
riate rate) are entered on Figure V -3.
B.S Final Step
The present value of the incremental cost and aftertax savings streams
and incremental benefit cost ratios are calculated on Figure V-3. The
alternative with the highest hydro capacity and an incremental benefit
cost ratio greater than unity is adopted for comparison with an all
diesel alternative as outlined on Figure VI-I. If the highest capacity
considered has a B/C ratio much greater than unity, a two-unit
alternative with higher capacity should be analyzed.
V-3
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(j) S~.<.;t;!;l•m•hiOfJ
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$1./J•Utl.lAY CQ9IIC4t~ C•
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FIGURE ::!Z.-
A y
(")
" "'0
"'0 m z
n
0 z
(/'l c: r
-1
)> z
-1
(/'l
ENO
OF
YEAR
COL I
0
I
2
3
4
~
6
7
&
9
10
II
12
ll
14
I~
16
17
16
19
20
21
22
23
24
I
TOTAL
ENERGY
6
kWh 1 10
COL, 2
-········-~·-
PROJECT NAME
RIVER/STREAM
LOCATION
DATE
CAPITAL a OPERATING COSTS -HYDRO/DIESEL SYSTEM
HYDRO CAPACITY c, HYDRO CAPACITY
CAP:TAL OBM FUEL ANNUAL CAPITAL I 0 & .. FUEL
COST HYDRO S OPERATING COST HYDRO &
DIESEL & DltSE\.. COSTS DIESEL 6 Qif.SEL
HYDRO $/YR, $/YR $/YR, HYDRO $/YR,
COL,~ ca. 4 I COL. ~ I COL, 6 CO,, 7 COL. 8 I COl, 9 I
l I COL.4 ... COL~ I
c2 HYDRO CAPACITY CJ
' ANNUAL CAPITAL O&M fUEL ~ A..,•wA:.
OPERATING COST H'f8AO & I CP(q,r;~(.
COSTS
$/YR,
COc
DIESEL&. 01£ SEL C.'>lS I HYORO $/YR f/YR *-yq
10 COL, II COL 12 j COL I) c c~ 1• I
I
I
I
I
I
I
I
I I
•
foL 12 + CJL '
MICRO HYDRO STUDY
HYDROELECTRIC CAPACITY
DETERMINA Tl ON
BENEFIT COMPARISON
SHEET I
FIGURE 12:-2
ft u
("')
;o
"0
"'0 m z
("')
0 z
{.f) c r-
-i
l> z
-i
{.f)
£NO
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0
I
2
3
" 5
6
1
8
9
IC
" 12
ll
14
15
16
17
18
19
20
2
22
2l
24
PR:£ SC ~T
v:. .... :...E
DIESEL-HYDRO/DIESEL INCREMENTAL BENEFIT COMPARISON $xl000
PROJECT NAME
RIVER/STREAM
LOCATION
DATE
INCREMENTAL CAPITAL COSTS S ANNUAL SAVINGS AFTER DEPRECIATION ALLOWANCE S TAXES
HYDRO CAPAC! TY c 2 WITH S TANOBY
OVER HYDRO CAPACITY C1 WITH STANDBY
INCREMENTAL CCPR I ANNJAL AFTER TAX
ALLC'\<IJ't..!'"iCE St.\/ lNG ANNUAL COST
COST * TAX SAVING
CCL. 7 COL.l CCL 10-COL 6
COL 15 COL. 16 ! COL 17 CCL. 18
PV COST SA.V~_IN--~:_:5:_ ____ _
PV 1NCREMUoTkL CAPITAL COSlS
PV COL. 18
~
* Jl'{Jffi CA?IT"L CDS!' c:a-ll'CM."i'l' IS DE?Rl'X:LI\Trn OVER
2 '!L.l-.'<5, 50 l P'"c:R YEAR.
SL??:Z.:I~:rhm.' DLSS£0.. CAPIT!\.L COST o::Mi'CN".::m' IS
Dr:Pr:.:x:~::D 0\!'i':R ProJECT LIFE AT 6\ PEl\ YEAR 00
D!X::L.I.K!:n:; !'J\IR~.
INCREMENTAl.
HYDRO CAPACITY C3 WITH STANDBY
OVER HYDRO CAPACITY C 2 WITH STANDBY
INCREMENTAL OEPR .4NNUAL AFTER TAX
CAPITAL ALLOWANCE St<V!NG ANNUAL COST
COST *
COL. ll-COL. 7
COL 19 COL 20
PV COST SAVIN OS
PV INCREMENTAL CAPITAL COSTS
TAX SAVtNG
COL 14-CCL 10 COL 20+COL.21
COL. 21 COL
PV COL 22
PV COL. I~ -c=-1
2
z 2
NOTE
I. USE 10% DISCOUNT RATE UNLESS
BETTER INFORMATION IS AVAILABLE
FOR CALCULATING PRESENT VALUE.
2. USE CURRENT DEPRECIATION ALLOW.l.NC!
RULES IF DIFFERENT FROM
ASSUMPTIONS OF COLUMNS 16 8 20.
MICRO HYDRO STUDY
HYDROELECTRIC CAPACITY
DETERMINATION
BENEFIT COMPARISON
SHEET 2
FIGURE 'lr-3
APPENDIX VI
DIESEL PLANT CAPITAL COSTS
DIESEL PLANT OPERATING COSTS
HYDRO PLANT OPERATING COSTS
A. Introduction
B. Grid Supply Alternative to Diesel Supply
C. New Diesel Plant
D. Continuation of Existing Diesel Plant
E. Hydro Operating and Maintenance Costs
F. Price Escalation
I. Diesel Plant Construction Cost Escalation
2. Diesel and Hydro Plant Operating and
Maintenance Cost Escalation
FIGURES
VI-I Diesel Plant Capital Cost Data
Vl-2 Diesel Plant Operating Cost Data -Hydro
Plant Operating Cost Data
APPENDIX VI
DIESEL PLANT CAPITAL COSTS
DIESEL PLANT OPERATING AND MAINTENANCE COSTS
HYDRO PLANT OPERATING AND MAINTENANCE COSTS
A. INTRODUCTION
The financial evaluation of a micro hydro site requires that the costs of
generating electricity from the micro hydro source be compared with
the costs of generation by the least expensive alternative. The user
must determine the least expensive alternative method of generation
and develop generation costs for use in the evaluation. The three most
likely alternative means of generation in British Columbia are as
follows:
I. Connection to B.C.H.P.A. grid.
2. If the existing diesel plant is obsolete, or if the load centre has
not previously been supplied with power, then a new diesel plant
must be considered as a potential alternative means of
gene rat ion.
3. If an existing diesel plant provides power to the load centre, then
continuation of operation of the existing plant (including replace-
ment of motor/generator sets as they wear out) must be consid-
ered as a potential alternative 'means of supply.
For a particular site it should be readily apparent which of the above
three alternatives will be the best "challenger" of a micro hydro site.
As described in Section 6, the capital costs, and the operating and
maintenance costs of the best alternative means of supply must be
estimated for use in the evaluation computation sheets in Appendix VII.
VI-I
B.
The following cost data are presented to assist the user in assembling
capital and operating costs if more accurate estimates are not avail-
able.
GRID SUPPLY ALTERNATIVE TO DIESEL SUPPLY
I. Capital Costs
It is recommended that the user approach B.C.H.P.A. to obtain a
capital cost estimate for extension of the power grid to the
project load centre.
2. Operating Costs
Regional rates for demand and unit energy tariffs are available
from B.C.H.P .A.
C. NEW DIESEL PLANT
I. Capital Costs -Diesel Plant
Figure VI-I contains a three-step procedure for estimating the
cost of a diesel plant.
Step I consists of determining the total installed capacity needed
throughout an assumed 24 year project evaluation period in order
to meet the peak load demand. The curves show plant capacity
increasing in two stages over the 24 year evaluation period. If
high load growth rates are anticipated some modification to the
staged approach may be desirable. Three or possibly four stages
of capacity growth may be considered. The procedure for higher
growth rates will, however, remain unchanged.
Step 2 consists of choosing appropriate motor/generator unit
configurations which wi II be satisfactory for the first and latter
half of the project evaluation period. At the end of Step 2 the
VI-2
user should have a clear picture of the number and type of units
and the total installed capacity which would be required of a
diesel plant to allow satisfactory operation over the 24 year
project evaluation period.
Step 3 consists of selecting plant costs from cost curves. Plant
costs have been broken down into two parts shown in Figure VI-I.
Curve A reflects the cost of the diesel generator units, and
includes radiator cooling system, breakers, alarm shutdown, and
controls.
Curve B reflects all plant costs except the costs shown in Curve
A.
If an existing plant is capable of accommodating the required
additional diesel generator units, only an estimated portion of
cost B should be considered.
The cost curve A has been based on typical unit configuration
described in Figure Vl-l Step 2.
It is now necessary to bring the diesel alternative plant cost to
the same base date as that of the micro hydro pI ant cost.
Therefore, using information in Section F of this Appendix, the
appropriate escalation factors should be applied to Figure VI-I.
Having obtained the capital costs for an alternative diesel plant,
the user should enter the data into the computation sheets given
in Appendix VII Figure Vll-2.
2. Operating Costs -Diesel Plant
Operating costs for the alternative diesel plant must be esti-
mated, to include fuel supplies and non-fuel components such as
labour, transportation, lubricating oils, overheads and administra
VI-3
tion. Computation procedures and cost curves are given in Figure
Vl-2.
D. CONTINUATION OF EXISTING DIESEL PLANT
E.
F.
If an existing plant is capable of being maintained in service for the 24
year project evaluation period, then capital and operating costs asso-
ciated with this alternate means of supply must be obtained for
comparison with hydro generation costs. Capital costs may be esti-
mated using the procedures outlined in Section C of Appendix VI and
Figure Vl-1, taking into account the age and condition of existing
facilities and equipment. Capital costs should be entered in the
financial computation sheet in Appendix VII appropriate to the years in
which capital expenditures are anticipated. Operating costs can
likewise be estimated using Figure Vl-2 and entered in the appropriate
Appendix VII computation sheet.
HYDRO OPERATING AND MAINTENANCE COSTS
Figure Vl-2 contains an estimate of hydro plant operating costs. The
cost curve was estimated on the basis of labour, transportation,
lubricating oils, maintenance costs and overhead and administration.
PRICE ESCALATION
I. Diesel Plant Construction Cost Escalation
Price Escalation to Beginning of Year 0
The estimate generated via the cost curves presented in
Figure VI-I and Vl-2 will produce a cost estimate in January
1980 Canadian dollars.
Since escalation has been significant over the past, it is
necessary to update the result given by these curves to
obtain the actual cost when the plant is constructed.
VI-4
For the purpose of order of magnitude estimates, it is
suggested that price esc a lot ion be co leu fated using the
Water and Power Resources Services (WPRS) construct ion
cost index published regularly in the Engineering News
Records. It is felt that even though the indices shown
represent the U.S. trend, it is a reasonable representation of
the Canadian market as well.
The price escalation may be arrived at by using the Pumping
Plants section within the USBR cost indexes for construc-
tion work. For the costs derived from Curve B use the
"Structure and Improvement" component and for Curve A
the "Equipment" component.
ii Price Escalation During the Construction Period (EDC)
It is assumed that a diesel plant installation would require a
construction period of one year. Therefore, half of the
anticipated price escalation for that year would be applied
to the project cost.
Should the construction period be different, then adjust
accordingly.
2. Diesel and Hydro Plant Operating and Maintenance Cost Escalation
Price Escalation to End of Year 0
The source of escalation ·indices to be used for operating and
maintenance cost estimates is left to the discretion of the
user.
For the hydro plant the cost breakdown for 0 and M is
estimated to be as follows:
VI-5
Labour
Construct ion
Equipment
Construct ion
Materials
70 per cent
5 per cent
25 per cent
For the diesel plant the cost breakdown for 0 and M
(excluding the cost of fuel) is estimated to be:
Labour
Spare Parts and
Materials
Lubricating Oi Is
64 per cent
25 per cent
II per cent
The above breakdowns of 0 and M inputs should be utilized
to arrive at overall escalation factors for diesel and hydro
plants.
VI-6
A v
n
:::0 -"0
"0 ,.,
z
n
0 z
(f) c: r-
-4
l> z
-4
(f)
CAPir/•t. CO!:T E:STII<IAT£-Dif.SF:L ~TERNATI!
:STV I St ... ~CT Wli'T'All~.O CAPACITY STAGE$ ,APPROPRJATI! TO
PRCVECTLD ~~~ GROWTH
!
~
~
~
~
" .
C~t• TotQI mtnimt.1m ,.,.,~d
t:ap«;:Jty~IZ
.,.~ .. Y-~~1: ~Pnd
CM• Tctol mmlrrw'" h'ti~IJed
Copcu:;Jty !:l,.<>r' 24
•J.J" ~or 24 d•'"IIHNI
~ . .. ,, ,. Z<
CNt:> C'>F YEAII!f
!ITCPZ· $.!'J..E.C":' CI£$/!L. G£hi£RATOR UNIT CONFIGt.IRATIOAI$•
TI"'Pie;.t. MOTCR/G£N£RAT:JR UNIT CCNJI-"IGVRATION3
FIA~£. CF tf\6i.ALL.t:D !NITI.AJ. IN5TALL.ATI()N REP.i-AC.EM£NT AT
CAPACITY fGOCD f'l.) CN:;) Y£,1.R IZ' ~ND YEAR 12
bQH Wt"'lf ,....,..,,,~ cap9CIIy • C12 ,,,.,,,. c.o,pt>c;Jt11•cz4
»-Jao.-W
.'d'(Jir"dt:lsl urut I "'"lf.;;O~>tKJfy •OZ. $ Ct,f -
.:X.u ~~" l' "n'"'""'-'"•• j-•c,z I ""''J C~ITf11-t:2ttl-7'
.Jc.o~J<XXJ•tll
Ptcq/lr ''"' j ;.......,t,c.o.;~:g..:t¥ • f Jf C11 -
"o,. 1o~llll' t VI'II1'S~~~u;,.::d¥ &~h t,;:l :.:;;::c,,ll} •cZA-E~!L
~z:xx:;,.,,
vnd-j-JI C1<1;
,.::W,oA' l.ln•f lunlf,£:.c;z.oordy•j «Ctz -
o,~~:~~ 9'l""';I"Q''on i.N''''~-
"""•"~~~•d (.f:.p.DC.•':J o/" .,_,.,f'# t:tl' Jn,f-al lrt'Jiallof/On~------AW
I:'J!Ir~I'Cd C4:J;:>.X.tftf o;' 4'"ld:J qf r•PI«•I'P'>41'>f y!t<::t,. /Z -~-·---A 'Ill
• It' •.n•''~"'~l pl•nt #'I .$1/'W., 1'/'Nvt ~vv•! ,..plac~m•,' ~nf~l~ 1'0 •4ul' r4n'N~ktt.,_,
td•"Arllrt ~ •111af>,"'!i "'"0,.... ~rtfii"'QI'pr urt1"-
~
~
~ ..
...
8 ...
~
0:
~
'MV...:t-;;:1 !0\AI.lt,
RIVtR /STR[AIA
I..O~ATION
DATE
~T~P !': oa-:AJN COSY' ()~ DIC$£L PLANT FROM GR,~~>,Pff V.'I-1 AND E.SCA:...A rE C0$'T$. ACD IN7'Cl~£:sr C ... :"f"•"""':S
CON5TRVC'r'ION TO ,ARRIVE. ,AT CJir.PIT,~i>,L COST CNt:J OF Yt:.a.~ 0
.._-,~,,. ol /"l'fef'"'l'!3f .:~..,r/"'9
c..on~tru<:t•D-"1
CvRvE IJ
$1TE D/!.Vt::LOP!r.#l::l\7
ICU~II~ A
1
/Nif/.I<L IN$TALJ.....ATIO/\I
$ENE.RJ.fCR UIYrTS
Cl./l?vE A
lt<:':P-A..;O,.,~,._~,A..."".,..':'",~
::;e_,.,t::;A'!'.:;:~ _.-.::rs
~~----+------------r----------~------------
lnfc'"C'li"Crl t!:OC
Tctol capdol co:sf
•R~of•~ncl-Apj>~~nd•Jt '1.!7 S•.::flon Jll
8:::0 1000
TOTAL c.-P,ACffY kW
,zoo "'DO
s: COST ·o, O'E~El p·_.,
EXCLU~;~G CCSt CF"
CUR>E A
'""" '""" ;;no
MICRO HYDRO STUDY
DIESEL PLANT CAPITAL COST DATA
FIGURE "!ZZ-1
fi u
()
::0
-o -o m z
()
0 z
I,Jl c
r-
-i
l> z
-;
I,Jl
ALTERNATIVE DIESEL PLANT
PROJECT NAME
RIVER/STREAM
LOCATION
DATE . ..
FlJEL COSTS= kWh/YEAR x CONSUMPTION FACTOR x FUEL PRICE YEAR 01 REAL PRICE ESCALATION FACTOR
(NO OF YEAR >W~/YEAR • 106 CONS>JM!'TION FACTOR 1 ftJEL Pfi!C£ ESCALATED
~ "" -...
V> w c::
t:
--·-
..J 0
tr
0 ....
'-' 0
<! ....
z
0
I-
C.. ::;
:;;, ., 5 026
u
-
CE~TS/L!TRE
--···----
fi=t FOR CAPACJTY>500 kW
---USE 0. 3 LIT RES/ kWh
.
100 ;:~o 300 4CO 500 6(X) 700
INSTALLED CAPACITY kW
• ':"':(?,.:~ 20 cr-r:'S~
~ P?.:':E ~7:CN y; .• .':-:t)R !S THE ~'tl Ph'!i: IN 1oim(lj Dll'SEL Ftn. CX'.'8l'S
>..-.:tS ~ :V E::::<.::LE:) ~ 11.1~ AA7'E OF tNF"..A....-:ICN.
';7 ~-:.3i FJ.....-:cF: • R ~ rt:...l:l. FRIO: ~ • IN:fU'COO Ml"J +R~
T<?:O.:. taG 1UK = ~ ~ M'Z l!,\ P.A. L.\5 CiF J1>.N l9SO),
ANNUAL FUEL COST
$ •1000
Cleael only O:.te.rn.at.!.vo
~'
OPERATING S MAINTENANCE COSTS EXCLUDING FUEL(JAN. 1980 CAN.$)
z
<!
.3
I-
"' 0 u
..J
<! :;;, z z ..:
DIESEL PLANT
HYDRO PLANT
200 400 600 BOO IOC') !200 1400 IWO 1800 20C()
INSTALLED CAPACITY kW
St.M-?.R'i ~ 0 ' H COS":'S
o:ESt;.;-CA;•;,.:r;y ""' .As 1960 O':iti ll"i:A!:A':'5 c:iS': I
(SYL K~ 4!
l YR. 0-12 YR. 12·24 ~~ 0-12 YR. !'r-14 ¥?.. C:~~ 11!
1
:::. l..e-:• 'hi. e:~ .,-_r~. !J ... .,(J
IM'.JO CV/ICl':'i l6<
I 1<>1 kl< )6; 1<>1
)0; )0;
l. OJS7'S HClL'DE -l.AOCL'R, ::tWl!?r\JR""...A':ICl-l, tL'BRICA..."'"'!:l't; OILS, M!~t)R N::l w.....:;c,R ~rlJJ'...S. O.'t'R{L'..O kl,D ~"!S:Ww""'!~
2. FCR DI~ P!A'"I' LS!:.n TO F'fO/l:".E St ... "P?U~·':'A~ f:>."EJG\' PRJ-U~ 'IUE a:sT OlJ'TI.,'"'rt::~ ~'tn< K'.iDRJ: 1 O::m;:. ~
':'0 ':'l:S I•:-c:•Jl{'l'l(!Z CF A.~-...:..\L :c;:-_.:g s·..;p;:>:..::r.:J BY £.\...jJ,
l. I..A.:':l':X,'il c:.s:'S f'C~ ~~ p:;;.:rr .\SS:.M: PAIC' 'i:'~ C?SiioA........,..Jl. IS ;..·.~ }.S ~.
•· m=:cr APP=IX vr =-::::m T •
MICRO HYDRO STUDY
DIESEL PLANT OPERATING COST DATA
HYDRO PLANT OPERATING COST DATA
FIGURE "lZZ-2
APPENDIX VII
FINANCIAL EVALUATION
FIGURES
VII-I Financial Evaluation Computation Sheet -
Hydro With/Without Supplementary Diesel
Vll-2 Financial Evaluation Computation Sheet -
Alternative (Diesel Only) System
Vll-3 Financial Evaluation Computation Sheet -
Payback Computations
Vll-4 Financial Evaluation Computation Sheet -
Internal Rate of Return
A
"fJ
n
::0
"'0
"'0 m z
n
0 z
IJ) c r-
-1
l> z
-i
IJ)
COMPUTATION OF TOTAL ANNUAL COSTS AND UNIT ENERGY COSTS $xl000
(HYDRO ONLY SYSTEM OR HYDRO SYSTEM WITH SUPPLEMENTARY DIESEL)
PROJECT NAME
RIVER/ STREAM
LOCATION
DATE
USE THIS TABLE WHEN HYDRO FIRM CAPACITY < PEAK DEMAND USE THIS TABLE WHEN HYDRO FlRM CAPACITY >PEAK DEIAAND
I r.,:J TOTAL
' •.Jf 'ENER\;V
I YEt.R
COL. I
LCNG TER .. SI-1CRT TERM LO'G TER .. SHORT TER" fUEL 08 .. I TOTAL VNIT
CAPITAL CAPITAL CEOT OE BT COMBINED ANNUAL ENER3Y
EXP'EN~!Tt.:RE · £xpr•;:::HTURE PETIREMENT RETIREMENT HYORO/DI!:SQ. COSTS COST
CENTS/kW"
COL 2 COL. 3 COL. 4 COL. ~ COL 6 COL 7 COL. 8 COL. 9
0
I
2
3
• I ~
6
7
8
9
10
II
IZ
13
14
I~
16
17
18
19
n
Z1
22
23
-':.; I ---··-
llYDOO SY~ F~'RAL DATA Sl..li-MAm'
~-~ ~2-~ ~:::.H 1 c;__-
=::_:·.~! ~:.::.:::J y-~ 1
:..;:_·.:; ;: . ...:::--:::·2::1.
kW
kWh
:-.:__:_-_-:::..::; ~:.-.:::-.. -:;~ R.;':E __ % PER AN.~UM
:0.-~~:.:::_"f :::.S~L FL'E:L (IF RLQ'D)
:::_ . .: _: ..:_-..-~ .::::J. (.--.::~,_,.--<..
ls:.. '.:..-:.=-_'0.. C::J.5:..2·:?':l:CN
ls:. ·:..-=..;_-, ?"_-~ ?lt:CL
1s: ::::..:.« r~:::.. c::6T
,;s.:;..~·::.:l = R:AL PRia: E.SCALATirn
LITRES(K\m
LI':K:S
C::':'S(LITRE
$ X 1000
% PI:R A. '~·.'UM
CAPITAL COST DATA
r..::t;G ':I:P: 1 CAPITAL COSTS -HYDRO PIA'<"!'
DU:Sl.L SI1E DEVIL.
(IF REQ'D)
SriORT Till'l GJ'ITAL COS§ -DIESEL l-'NITS (IF REQ'D)
Th'TCRI"ST M'FC Gl CAPITliL
DEB'i' ICI'IJ1Y:r. IT FN:'IORS @ Th'I'EREST
u:m; 'I'ER.'l CAP. cosr x
SllORT TEFH CAP. COST X
12%
0.129
0.161
%
CAPITAL
COST
COL, 10
$ X 1000
$ X 1000
$ X 1000
%
DEBT 0&1.1 TOTAL
RETIREMENT ANNUAL
COSTS
COL. II COL. 12 COL 13
MICRO HYDRO STUDY
FINANCIAL EVALUATION
COMPUTATION SHEET
HYDRO WITH/ WITHOUT
SUPPLEMENTARY DIESEL
U~IT
E ... .::RGY
CCST
CUHS/kWII
C 0 L 14
FIGURE im-1
L\ v
n
::tJ
"0
"'0 m z
n
0 z
(/') c: r-
-i
l> z
-i
(/')
l::IT!:l:. SYSTI:1 FliC'ItiAL t:M\'::1'. SW'!oMI.RY
tr;.:J s,.·\TA
l-.5 ?':."'l. FIG. \'II;-1
Dr:S~~ P~TL DA~~
CO -~-~·?'riai Fl..croR
lst. ·IL\R ca~st:~·?:'ICN
lst lU:..t~ FL"EL rRia.:
1st YL~·.R ?.... TI .. cx:s:'
;.:._s_--:.:=J Rc\':"E P.i.;I. PRICE ESC.AI.AT!CN
G:?I":l!-CC6':' C.\':'A
L(l;G ':::R·l Ch?ITAL COS'i'S -SI'l'E DEVEI.(I'MENI'
LITFES/kWh
LITFES
CD.'TS/LrrnE
$ X 1000
% Pr:R A.\lirJM
SEC:<~ =-~ C..P?'u,l. CXlSTS -D:::ESI:L CE-'ERATOR u:li'IS YEAR 0
YEAR 12
:L.-:scsr RAT: Cll CAPITAL
car.' m:: I r::::·'E:r.' FACTORS @ Th'IEREST RA 'IE OF 12%
LOiG 'r!:.R-1 CAPITAL COST X 0.129
SEORI' TI:R-1 CN' ITAL ca; T X 0. 161
UNIT ENERGY COST COMPARISON
.c.
~
~
1-:z
..J u @IIIII
$ X 1000
$ X 1000
$ X 1000
%
%
~
Vl
0 u
)-
'-' C<:
'-' z
I
I
I
I .I
I I
i
. __ :::q
I I 1
PLOT VALUES fROM COL. 22 AND I
FIGURE 'Z:!-1 COL. 9 OR 14 HERE
1-z
;;J
I
i
I
4
I 1
I I
I I
I I I
8 12 16 20 24
YEAR
END
OF
YEAR
0
I
2
3
4
~
6
1
8
9
10
II
12
13
14
I~
16
17
18
19
20
21
22
23
24
PROJECT NAME
RIVER/STREAM
LOCATION
DATE
COMPUTATION OF TOTAL ANNUAL COSTS AND UNIT ENERGY COSTS $ X 1000
(DIESEL ONLY SYSTEM)
LONG TER'-1 SHORT TERI.I LONG TER!ol SHORT TER'-1
CAPITAL CAPITAL CEBT DEBT
EXPENDITLRE EXPENDITURE RETIRE'-IENT RETIREMENT
COL. I~ COL. 16 COL. 17 COL. IS
-·
FUEL o a 11 TOTAL UNIT
A~\'JAL ENE~VY
COSTS CCS!S
CE'-'7S/II'tll'h
COL. 19 COL 20 COL 21 I c ~l 2 2
MICRO HYDRO STUDY
FINANCIAL EVALUATION
COMPUTATION SHEET
ALTERNATIVE (DIESEL ONLY)
SYSTEM
FIGURE 1m-2
j
I
I
l
I
I
fi
\.1
("')
:0
"'0
"'0 m z
n
0 z
(f) c:
r-
-f
l> z
-f
(/'1
PAYBACK COMPUTATIONS $xl000
PROJECT N AV.E
RIVER/STREAM
LOCATION
E~O
o•
YEAR
0
I
2
3
•
~
6
1
e
9
10
II
12
13
I<
·~ 16
11
18
11)
20
21
22
23
2•
CASE I
BEFORE TAXES
TOTAL CAP"A~ TOTAL CAPITAL INCREMEN1'AL
COS'S j COSTS CAPITAL COST
H"'':)tfQ SYST! C'ESEL SYSTE!f. HYORO·OIESEL
CCL 23 COL 2 4 COL 2~
COL 2 +COL.3
OR COL t5+COLI6 COL 23-COL24
COL 10
!D!'E:
BEFORE TAX INCREMENTAL
ANNUAL COST COST "'"US
SAVINGS ACCUMULATED
SAVINGS
COL. 26 COL 21
COL!9+COL20 -COL 25
MINUS + 1COL.26
El !HER COL 12
1aR(CCX-6+COL
l. PAY&'\0< PER!CO • YEAR IN 'nl!IOl ~;J., CXlST MINUS
1\0:::tMJI.ATID &wm::;s
2. lSE 2 YE.'IR lo!'!UTD:lFF FOR HYDR:l AT 50% PER YE.'IR.
t::'E 6\ Ds::!..IKING !l.'J..I\:'l:E FOR SUPPLE:·~"':ARY DIESEL
r:y .. ::r~~,Pf ..
DATE ----
CASE 3 CASE 2
AFTER TAXES
FORMER Of.:PRECIATION RULES
AFTER TAXES
ACCELERATED HYOR:J DEPRECIATION RULES
INCREMENTAL ~I AFTER TAX INCREMENTAL
CAP' I TAL COST ,C,~*a:AL COST COST Mlf.JUS
ALLOWANCE 6Ji SAVINGS ACCUMULATEC
CECL. eAtA~~£~ S!'.Vi!'I!GS
HYDRO CAPITAL
COST
ALLOWAr-<CE.
COL 28 I COL.29 I COL. 30 COL. 31
6% OECL. -COL 25 SH NOTE 2
ON +ICOL.29 BASED ON
COL. 25 COL 23
SLWJ\RY:
1. PAYBACK BO'OR£ TAXES -CASE l -----'YEARS
2. PAYBACK AFTI:R TJ\XES -CASE 2 ____ YEARS
3. PAYBt\CK AFTER TAXES -CASE 3 ____ Y>'..ARS
DiESEL :ttCPE 'IA~'tT:.L
C0ST CC.S"" v ~ •• <;
t.c.:~'lA.l.;:::
CECl B•u".C( SA. \~S
COL .12 COL 33 I CCL 34 C S: L :!5
6 %D~Cl.. !!AL. COL 26 .. COL~J-~Cl...l!l
ON coL 31-cou~ 2 < CCC~34 COL 24
MICRO HYDRO STUDY
FINANCIAL EVALUATION
COMPUTATION SHEET
PAYBACK COMPUTATIONS
FIGURE 1m-3
6 v
n
;o ., .,
m z
n
0 z
(.f) c r-
-1
l> z
-1
(.f)
I j T~.~L
~ c s:.c..,xr
lUTES
EO()
vF
YEAR
0
4
~ •
7
8
9
10
II
12
13
14
~
16
17
l8
19
20
~I
22
23
~·
CASE I CASE 2 CASE~
INC"E"ENTAL BEFORE TAX AFTER TAX AfTER TAX
Ct.PIUL COST t.NNUAL COST ANNUAL COST ANNUAL COST
HYO~O-OiESEL SAVINGS SAVINGS SAVINGS
(COL.25) {COL. 26) (COL.29) {COL. 34)
$'lOCO $. 1000 $. 1000 $• lOCO
PRESENT VALUES
DODD
0
0
2
"' .....
.....
;:l
.J
<(
> ,_
z
"' "' ....
0:: a.
SUM-lt\R'l:
P.'lOJECT NAME
RIVER/STREAM
LOCATION
DATE
CASE l IRR
Ci\SE 2 IRR
CI\SE 3 IRR •
DISCOUNT RATE
\
\
\
!UI'E: lm'ER:-l,'IL M'IE OF RS"Jt:R>l IS DISCU.''::IT MTE
AT 1-.'HIQI PRt-:s:E:\'I' VAUJE OF rn:Rl~2>'TAL
CAPITAL CXSTS IS meAL 'ID PRJ:Sl:';T \'ALL'E
Ci' !'JN;"lJAL a:6T SA VD:GS.
MICRO HYDRO STUDY
FINANCIAL EVALUATION
COMPUTATION SHEET
INTERNAL RATE OF RETURN
FIGURE lZ!I-4
APPENDIX VIII
RAPID FINANCIAL EVALUATION METHOD
A Introduction
B Method
TABLES
VIII-I Hydro and Diesel Generation Unit Energy
Cost Comparison
FIGURES
VIII-I Hydro Plant Unit Energy Cost Data-
Interest I 0%
Vlll-2
Vill-3
Vlll-4
Diesel Plant Unit Energy Cost Data -
Fuel 20 Cents/Litre -Interest I 0%
Diesel Plant Unit Energy Cost Data -
Fuel 30 Cents/Litre -Interest I 0%
Capital Cost vs Installed Capacity
APPENDIX VIII
RAPID FINANCIAL EVALUATION METHOD
A. INTRODUCTION
This Appendix has been prepared in order to assist the user in providing
a rapid financial evaluation of a hydro project consistent with the level
of accuracy which would be expected of a reconnaissance level study.
The user should bear in mind the limitations of the method presented in
this Appendix since certain basic assumptions have had to be made in
order to simplify the evaluation. The method does, however, give the
user an "order of magnitude" evaluation procedure which will be useful
in screening projects for ongoing investigation.
B. METHOD
B.l User Inputs
It is assumed that the user has compiled the following basic information
pi'ior to proceeding:
I. Peak load and the energy demand forecast for as many years as
desired.
2. The installed capacity and capi'tal cost of the hydro project.
3. The installed capacity of the first stage of an alternate diesel
generation plant.
4. The price of diesel fuel at the beginning of the first year of
operation, and the real price escalation rate for diesel fuel (that
VIII -I
is, actual long term fuel price escalation rate minus the average
nationwide inflation rate).
5. An appropriate cost escalation factor covering the period from
January, 1980 to the beginning of the first year of operation.
B.2 Description
Figures VIII-I, 2, 3 and 4 and Table VIll-I have been prepared to assist
the user in the rapid determination of unit energy costs from the
proposed hydro project and from an alternative new diesel generating
plant. It allows the user to decide whether the cost of energy
generation in the initial years of the project by a hydro or by a diesel
generating plant is going to be competitive. The assumptions made m
preparing the cost curves in the figures are as follows:
I. Construction costs are financed at an interest rate of 14% p.a.
2. Long term debt retirement is over a period of 24 years. Short
term debt retirement of diesel equipment is over a period of I 2
years.
3. No allowance is made for staged development.
4. The capital cost of the diesel installation, and the hydro and
diesel plant operation and maintenance are based on January 1980
cost estimates which are included in Appendix VI.
5. The capital cost of the hydro installation is based on site
investigations of this study as well as studies carried out in
Newfoundland and Labrador*.
*Study of Small Scale hydro for Newfoundland and Labrador.
VIII -2
6. Part-time plant operators for smaller installations and full-time
operators for larger installations are available at the site.
The procedure consists of determining the unit energy costs for the
hydro and diesel generating plants during the first 12 years of the
project, and comparing the values so obtained. No account is made of
capital and operating costs or salvage values which will be incurred
beyond the 12-year period; the user is referred to Section 6 for detailed
financial evaluation procedures which include such costs.
Figure VIll-I is used to determine the unit energy costs of the hydro
plant. The cost curves include debt retirement payments as well as
annual operation and maintenance costs. The hydro unit energy cost so
obtained must be adjusted for operation and maintenance cost escala-
tion between January, 1980 and the beginning of the first year of
operation.
The user is referred to Table VIll-I which shows the required adjust-
ment. Typical 1980 fuel cost components for diesel generation are
shown on the graphs in Figure VIll-I to indicate the level at which a
hydro plant can be justified on the basis of diesel fuel displacement
alone.
Figures Vlll-2 and 3 are used to determine the unit energy cost of a
diese I pI ant. Although, in fact, only one of these curves is necessary
for a rapid evaluation, Figure Vlll-3 has been included to show the
sensitivity of diesel generation costs to the price of fuel. The cost
curves include debt retirement payments as well as annual operation,
maintenance and fuel costs. Diesel generation unit energy costs so
obtained must be adjusted for price escalations between January, 1980
and the beginning of the first year of operation, and account must be
made for continued real escalation of fuel costs during the first twelve
years of operation. The user is referred to Table VIll-I for the
adjustment calculations.
VIII - 3
Figure Vlll-4 is used for an "order of magnitude" estimate of the hydro
plant capital cost based on an assumed installed capacity. This graph is
presented mainly for the novice who has had no experience in estima-
ting hydro electric costs. The user is cautioned that the use of this
graph should only be for the purpose of obtaining a range of capital
costs (based on the upper and lower limits) in order to compare with the
diesel costs as presented in this quick evaluation method.
8.3 Evaluation
Having obtained the unit energy costs for years l, 6 and 12 of the
proposed project using the figures and Table VIII-!, the user can
determine whether his hydro project is competitive with a new diesel
plant installation. If the cost of generating energy by hydro exceeds
that of diesel by less than 50%, it is recommended the user proceed
with a full financial evaluation in accordance with Section 6 of this
manual. Although hydro may appear to be uneconomic on the basis of
this abbreviated analysis, the long term benefits of hydro could be
substantial enough to reverse the outcome.
VIII - 4
TABLE VIll-I
HYDRO AND DIESEL GENERATION UNIT ENERGY COST COMPARISON
Installed Capacity kW ------
Cost Escalation Factor (Jan 1980 to Year I) ---
(Cost Index beginning Year I)
(Cost Index Jan 1980)
Price of Diesel Fuel at Beginning of Year I cents/litre ----
Real Price Escalation ofF uel % per Annum ----
Hydro Installation Capital Cost Upper Limit $ -----
Energy Demand kWh X I o6
Diesel Generation Unit Energy Cost
I. Jan 1980 Unit Energy Cost (Fuel @ 20¢/1)
(No real escalation assumed)
2. Fuel only cost component (Fuel @ 20¢/1)
3. Difference = Capital & 0 & M Cost
Component (Line I -line 2)
4. Escalated value of Capital & 0 & M
Component Jan 1980 to Year I
(Line 3 x escalation factor)
5. Fuel only cost component Year
(Pro-rate line 2 -without fuel escalation)
6. Fuel only cost component, subsequent
years (Escalate according to real
fuel price escalation)
7. Unit Energy Cost, (Beginning year !-dollars)
(Line 4 + line 5 or 6)
VIII-5
Lower Limit$ -----
YEAR
6 12
Hydro Generation Unit Energy Cost
8. Jan 1980 Unit Energy Cost (Fig VIll-I)
9. Add 0 & M Escalation Component
= 4.2 x I 0 6 x (Cost Escal. factor -I)
Annua I Energy
I 0. Unit Energy Costs, (Beginning year I -
dollars) (Line 8 + Line 9)
Upper
Compare Diesel Energy Costs (Line 7) with
Hydro Unit Energy Costs (Line I 0)
VIII - 6
Limits Lower
~ 0 w -5
() -10 ::0 -'"'0
'"'0 /JC
m z
() 9~
0 z
(fJ ....
c ;: 80
r-~
---1 " l> .:::: z ~ 70 ---1 \J (fJ .._
·.;
:--g
~-~·--t or•---;---· ----,--·---·, ----~-,-~-~--r
KWH/YEAR .•. ___;,;;;;; I I I i J f j I
.f)"!.~ /:,;;:r~
/ ~01'-Unil enerqy co.sf
reduct/on r;_.,,-small
capacity Hydro
ins lolled /ons I GRAPH B] ( 8a5cr/ on lower
operolt'ng co sf}
NOTE: For :smo/1 capacify hydro
insfalkdlons a,~-ply reduc:f/ons
io these curves as per above
Hydro plant
copito/ cos!
~X 1000
D/e•sel 9.-::nerat-/on
/·uel cost af
30 cc·nts/ldre
20 cPnls/ 1/fre
·:~.
!;J t:){)
'--c-L-:--'----c-'·-c--·'----c·"·",.---'--...J.c-·-L--~:=---'---,-J-o--'-~~----J
6 /. 6
~ ~
'0 {'
~
\J
' ~
--r-:·-, -.--,-..,: ---r~------
I (;f:iAPW X I
NOT£ : For Hydro plan! capila/1
coJ:f <: $I mill/on u::e
c;raph 8 J
I -- -· 1
1 Hy.c/ro pl.2rr L
l cc.rp!/7/c:;~s;L 1 !
_! x . .:_oo:J 1 l
..--::-·---• I D/esef generar,or: I I
rue/ cos! al I
30cenl:;/h"tre . . 2o'~~" \ "\ ,~/Iii'~ I l
t%?~~~'. ,·vee••. •• ., ,•·. ~;::' IOf= ._, , ry_,__.,.,. ._. /.'-'"""·--,·"-.... -. , ~·"_.:._:_: ;;~~ ~;:;:·~~~~c~~ ~::~ ;~;:=·:':-~~ ..... ·~ ~~~~
0 ~//c I ~-U(.,~-'-~--'-l.....~.-J......i--t-.J.~I-.J.,..---~----,! o 1 ::: 3 4 !i o 7 e
Annual e-~rwrgy generated KW!t /YE/.R" ;ot>
N!JTc: Ur?fl eru::>r;~y cosl
Ji.•,_:/u~...l::::s :;;(_.J,u/t.:...J/ cusf
r:i/ /:./ c;
rt)(;/r;/,·: . .:-tJc:.;/;C'!!:: cosfs
MICRO HYDRO STUDY
HYDRO PLANT UNIT ENERGY COST DATA
INTEREST 10%
FIGURE 1llll:-1
n v
n
" -, ,
m z
n
0 z
(./) c ,....
.....
l> z .....
(./)
100
90~
t r --,
80,
r
70!--
~ I "( 60r--, I
~ I
r:: l
~ ' \.) 50;-
1
' I
~
\.; -'10 ,_
~· i :::-, '
~; '
IC: l
:, .!:?~-
?
'J ~ I .:.0-:-l '
' t-
10 L
' [•/ /.
/ /
[GRAPH Aj
'....,_ ___ .
!' ---
~--r··
.i.".
I •.
;·
NOT£:ror smaller pkmr capacl//(';;>s
us~ qre?Ph 8
lJ /esc=! plan!'
inslal/cd
2000 kW
·>>:··.<~<~< ',·-. ~<< ~<·>:·>>:<<->>>>>~
4
Annual ener9y 91Jinera/'ect xWh/ycar"' 10 5 ,
100
90
~ 70l
·.~ 601 I~ ..... ..
'~50~
I ...__ I
~ ll ~40
-~:;,
l.
QJ
~ :
I
. ~ 30l.
• 2ol. .
JGRAPJ.I Bl
c::sl
-. '/0 . · · · L · "'" ' f -'r • •
t
' '-' v '' ' ' • .,_' .; . ' • , '·;. • ' ' ' . "' • . '-"'-' ' ' ' • '· ' ' ' , . • . . ' . . . . r . ""-'-''-,_•., v"-\.~~'~ "~"'·"""-""·"·'---"'-,._·,.,.'~·~·. "·~~·'• • ·'"'..,'~'-.. '· .. ·.·.,_.·,".,-.".~.· .'.',
•. 'I
. . •. -.l..-....1 .. ___!__ .. J. _ _j_---..L__.!. .. ---L.-.....L...-· ·--' -·-· .. ---"
0./ 0.2 0-3 0.4 05 0.6 0.7 o.s 0.910 1./ 121.31415 !6
Annual energy generated AWh/yr::ar J< !0 6
NCTt:.: Vni! energy costs inc/vcte copfla! cosT(new plant)
0 6: M cos!s c:NJd lve/ costs f Ja/7 1930 prices)
MICRO HYDRO STUDY
-·
DIESEL PLANT UNIT ENERGY COST DATA
FUEL 20 CENTS/LITRE
INTEREST 10.% FIGURE .'JZ!ll-2
~~ r~o
v .
L 90
()
:::u -""0
""0 reo
m z
()
0 70
z
(f)
c ~ r-60
'""" l> :<
z ~
'"""
::: ,_,-50
(f) \.!.
~ ;-:.
·} \). 40
~ ,·' >-
:::: 3?
\ J
.'---
' r--·
~-
f 20
I
'-10
/
·"
NoTe :For smaller plonT capac/lies
u:;e '2raph B
Diesel p/or,T
1175/ol/ec/ copoc/ly
6 7 .
A nnua/ energy q~I?C:'raf~d k. Wh/yeor >r 10 6
,V:JTC.· Cln;/ c..r;\?rqy costs /nc/vcte ca,or:-:.:-1 cosf(new plant)
0 c. M CCI5/:s and l'u-5'/ cosJ:-c; I Jan 1!.730 pr/ces)
"-..
tj
(1
::,..
~40 s
~
i':: 30 '-S
20
10
..
Ra179e of rue:/ only co~t
C1'> 30 Ccn!s/L/Ire.
' :,') ~ ,'/
'YJ!ikYI
:~~~~~=-~~~~~~~~~~~~~ o.; o.z o.s ().4 0-5 o.6 o.7 o.r:, o.g 1.0 u 12 1.:; 1.4 1.5 IG
Annualenerqy generated kWh/yE>Qr >< 10 15
--j_
MICRO HYDRO STUDY
DIESEL PLANT UNIT ENERGY COST DATA
FUEL 30 CENTS /LITRE
: .INTEREST .. lO% .. _ FIGURE 1m!-3
fi v
(")
;:c
"'C
"'C m z
("")
0 z
{/) c:
r-
-i
l> z
-i
{/) .0,000----
,...._, ~.v.:.ro_
?:: ::£. "CP:>O-~-·-~-
"-' ~ ].Q,.JOO+--
(f)
f-· 2'0,D'X.i_l
(f)
0 u
_J
<t !0'):.0_. 1-
J')I)O ~i c.. l,lJC~-<t
1,':.Y.:l .. l u
6,:.0;).) ___
~,OJV~
<IQ-)0-
LOW{',-
!
•poo-! r ··---------__._..,
K) lO 40 50
r
"'
" 8
HYDRO INSTALLED CAPACITY (KW)
NOT£
Do not use as a 91.11de {or
economic f"e-c;sib!!ily .
LEGEND
6 ---Lobrad.:;'!r Study
0 ---N(:wfouna~'and Study
0---Brih:Sh Colurnb/a Study
MICRO HYDRO STUDY
CAPITAL COSTS PER KW
vs
HYDRO INSTALLED CAPACITY
FIGURE 11[-4
APPENDIX IX
CASE STUDY
CARPENTER AND CODY CREEKS
APPENDIX IX
SITE INVESTIGATION -CARPENTER AND CODY CREEKS
TABLE OF CONTENTS
Page
A. GENERAL LOCATION IX-I
B. SITE DESCRIPTION IX-I
c. HYDROLOGY
D. POWER DEMAND AND SUPPLY IX-3
D. I Present Power Demand IX-3
D.2 Expected Power Demand and Supply IX-3
E. STRUCTURES IX-4
E. I Access IX-4
E.2 Intake IX-4
E.3 Penstock IX-5
E.4 Powerhouse IX-5
E.S Turbine/Generator IX-5
E.6 Transmission Line IX-6
F. ECONOMICS
F.l Rapid Financial Evaluation IX-6
F.2 Financial Evaluation Study IX-7
F.3 Summary IX-7
G. CONCLUSION IX-8
IX-i
ADDENDUM I
ADDENDUM II -
TABLE IX-I
TABLE VIll-I
LIST OF ADDENDA
SITE INVESTIGATION ASSESSMENT
COST ESTIMATING PROCEDURE AND SUMMARY
(ALTERNATIVES C I' c2 , and C3)
LIST OF TABLES
FLOW DURATION DATA
HYDRO AND DIESEL GENERATION, UNIT ENERGY
COST COMPARISON
IX -ii
Figure 9-1
Figure 9-2
Figure 9-3
Figure 9-4
Figure 9-4
Figure V-I
Figure V -2
Figure V-3
Figure VI-I
Figure Vl-2
Figure VII-I
Figure Vll-2
Figure Vll-3
Figure Vll-4
Figure VIII-I
Figure Vlll-2 -
Figure Vlll-4 -
LIST OF FIGURES
Location Map
Carpenter Creek Flow Duration Curve
Cody Creek Flow Duration Curve
Combined Flow Duration Curve
Superposition of Load Duration Curves
On Site Capacity Duration Curves
Hydro Capacity Determination With Secondary Energy
Hydro-electric Capacity Determination, Benefit Comparison
Sheet I
Hydro-electric Benefit Comparison Sheet 2
Diesel Plant Capital Cost Data
Diesel Plant Operating Cost Data and
Hydro Plant Operating Cost Data
Financial Evaluation Computation Sheet
Hydro With/Without Supplementary Diesel
Financial Evaluation Computation Sheet
Alternative (Diesel Only) System
Financial Evaluation Computation Sheet
Payback Computations
Financial Evaluation Computation Sheet
Internal Rate of Return
Hydro Plant Unit Energy Cost Data -Interest I 0%
Diesel Plant Unit Energy Cost Data
Fuel 20 cents/litre, Interest I 0%
Capital Cost per kW vs Hydro Installed Capacity
IX-iii
APPENDIX IX
SITE INVESTIGATION -CARPENTER AND CODY CREEKS
A. GENERAL LOCATION
The proposed micro hydro development is at Sandon, British Columbia
which is approximately IS kilometres from New Denver in the South
Central port of the province.
There ore several streams within a 3 kilometre radius of Sandon which
have potential for micro hydro development. An existing small hydro
station which utilizes flow from Carpenter and Cody Creeks is pres-
ently supplying some of the power required by the Silvana Mine
operation in Sandon. The existing plant equipment is very old and has
reached the end of its useful life.
This study will look at the possibility of using the combined flows from
Carpenter and Cody Creeks to develop a new micro hydro plant to
supply electricity to the Silvana Mine operation in Sandon.
B. SITE DESCRIPTION
Carpenter and Cody Creeks are located in the Kootenay range of the
Selkirk Mountains. The town of Sandon is at an elevation of approxi-
mately II 00 metres above sea level as is the powerhouse located near
Sandon. The intake structures on both Carpenter and Cody Creeks
would be at an approximate elevation of 1400 metres above sea level
and located near the existing intake structures. Cody Creek joins
Carpenter Creek at an approximate elevation of 1220 metres.
The creek bed is filled with boulders and gravel is exposed on both
banks of the two creeks. Access is good to both intake sites by existing
roods.
IX-I
The proposed location of the powerhouse would be near the existing
powerhouse at Sandon.
The penstock would be located on or near the right-of-way of the
existing penstock.
C. HYDROLOGY
Generation of streamflow data was necessary to produce flow duration
curves for creeks in the Sandon area. This is because there is no
streamflow data for Sandon Creek and only partial records for both
Carpenter Creek and Cody Creek.
Data to produce flow duration curves was generated using streamflow
data for Redfish Creek at Gauging Station 08NJ061. Redfish Creek is
located south of Sandon and has a small drainage area similar in size to
the drainage areas for Carpenter, Cody and Sandon Creeks.
This similarity of drainage area size is a necessary characteristic to
obtain reliable generated streamflow data. Correlation of known
streamflow data for Red fish Creek to that generated for Carpenter,
Cody and Sandon Creeks was based on using their respective drainage
area ratios. The drainage area for Carpenter Creek at a point just
upstream from the confluence of Cody Creek was found to be 19.0
square kilometres. The drainage area for Cody Creek just upstream
from its confluence with Carpenter Creek was 16.4 square kilometres.
Sandon Creek has a drainage area of 4.1 square kilometres at a point
just upstream from the confluence of White Creek.
The accompanying flow duration curves and Table IX-I indicate that
the finn flow for Carpenter Creek is 0.060 m 3 Is, for Cody Creek, 0.051
m 3 Is, and for Sandon Creek, 0.0 13 m 3 Is.
IX-2
D. POWER DEMAND AND SUPPLY
D. I Present Power Demand
Presently the Silvana Mine at Sandon is serviced by diesel-electric
generator sets with an installed capacity of approximately 800 kilo-
watts. The installed capacity represents a peak load at the mine.
Presently the mine operates on a 16 hour basis with an average load
requirement of 450 kilowatts.
The combined firm flow of Carpenter and Cody Creeks is 0.11 m 3/s.
With an available head of 152 metres, firm power of I 18 kW can be
produced. Combined firm flow from Carpenter, Cody and Sandon Creek
of 0.12 m 3/s will make 130 kW of firm power available. This small
additional gain in power makes development of Sandon Creek imprac-
tical, since for any time of the year flow from Sandon Creek will only
increase the total power by I 0 per cent.
D.2 Expected Power Demand and Supply
Silvana Mines has indicated that the initial future peak load for the
mine will be 1200 kilowatts when the compressors used in the mining
operation are converted to using hydro-electric power. Therefore, an
electrical supply system should be developed considering an initial peak
load requirement of 1200 kilowatts with a load factor of 0.6. A load
growth rate of 1.5 per cent per annum has been assumed to account for
increased mining production over the years.
Because the power demand is more than can be provided by firm flow
alone, it is necessary to use supplementary diesel power generation.
Hydro can only provide 118 kW of firm capacity yet the load peak
demands will vary from 1200 kW in year 0 up to 1715 kW in year 24.
Three arbitrary hydro capacities were selected for use in the prelim-
inary optimization of plant capacity as outlined in Appendix V. Figures
IX-3
V-I, V -2 and V -3 show that the larger hy.dro capacity should be viable
and hence the hydro system is evaluated on the basis of a hydro
installed capacity of 1463 kW together with supplementary diesel
capacity sufficient to meet the difference between hydro firm capacity
and peak demands. The system demands and capacities are summarized
as follows:
Year 0 Year 12 Year 24
Demand kW 1200 1435 1715
Minimum Capacity ( 1.1 x Demand) 1320 1579 1887
Firm Hydro kW 118 118 118
Net Supplementary Diesel kW 1460 1769
In view of the fact that supplementary diesel supplies only a minor
portion of the total energy for the selected hydro installation, it is not
necessary to replace the diesel units in Year 12. Therefore 3 units will
be installed in Year I to last 24 years: one 486 kW unit and two 640 kW
units.
E. STRUCTURES
E.l Access
The access to the micro hydro site would be by existing logging road to
the intake areas and also to the powerhouse. The road from the
powerhouse to the intake areas would probably have to be upgraded for
access of construction equipment. The excavation for the access road
would be in granular material.
E.2 Intake
The proposed intake structure foundations do not appear to be a
problem as they will be on dense granular material. As stated in the
previous paragraph, access to this site would require some improvement
of the existing roads. The locations of the two intake structures (on
IX-4
Carpenter and Cody Creeks) are at the locations on the creeks stated in
Section C for which the drainage areas were calculated.
E.3 Penstock
A penstock approximately 2000 metres long will be required to run from
the Carpenter Creek intake to a point approximately 350 metres up the
hill from the powerhouse location. The penstock from Cody Creek
intake to a junction with the Carpenter Creek penstock would be
approximately 200 metres long. A high pressure penstock approxi-
mately 350 metres long will be required for the last section leading
down to the powerhouse, giving a total of 2550 metres of penstock.
If flow from Sandon Creek was to be used, an additional 700 metres of
penstock would have been required to connect to the intake on Sandon
Creek. As already stated, development of Sandon Creek would not be
practical, mainly because of this great length of additional penstock
required.
E.4 Powerhouse
The powerhouse will be located near the site of the present powerhouse.
This site has good foundation conditions and will only require minimal
clearing of trees.
E.5 Turbine/Generator
As determined from Figure V -3, the installed capacity of the hydro
portion of the hydro-diesel system is 1463 kW. This will operate under
a head of 152 metres (net head of 144 m) with a discharge of 1.38 m 3 /s.
From Figure 4-1 of Volume 2 it is apparent that a Francis, Turgo or
Pelton turbine would be suitable.
Based on Section 5 and Figure 4-2 of Volume 2, the following specifics
have been tabulated:
IX-5
I.
2.
3.
4.
5.
6.
Turbine
Type
Francis
Turgo
Turgo
Pelton
Pelton
Pelton
No. of
Jets
2
4
2
I
Specific
Speed
100
60
45
55
40
28
RPM
1200
750
550
675
490
340
Of these alternatives, the 2 jet Turgo or 4 jet Pelton would most likely
be the best choices since they can be directly coupled to the generator
and also provide better efficiency as a result of the multiple jets.
E.6 Transmission Line
The location of the transmission line has been shown on Fig. 9.1.
Approximately one kilometre of transmission line would be required to
the lower adit while an additional 0.6 kilometres of transmission line
would be required to the upper adit of the mine.
F. ECONOMICS
F.l Rapid Financial Evaluation
A rapid financial evaluation was done according to the procedure in
Appendix VIII, Volume 2 of this study. As shown in the accompanying
Table VIll-I, the unit energy costs for both the upper and lower limit
hydro capital costs are very favorable when compared to the unit
energy costs for the diesel alternative. A prefeasibility level study
should be done to compare hydro costs to diesel alternative costs.
IX-6
F .2 Financial Evaluation Study
As discussed in Section D.2 the hydro installation will require supple-
mentary diesel capacity to meet the load demand. The optimization
procedure used to determine the hydro installed capacity resulted in the
selection of a 1463 kW hydro capacity. The capital costs of the
optimized hydro/diesel plant ore summarized in Addendum 11-C. Oper-
ating costs are obtained from Figure Vl-2. The Hydro/Supplementary
diesel system capital and operation and maintenance costs are entered
into the financia I evaluation sheet, Figure VII-I.
The mixed Hydro/Diesel system costs must be compared with an
alternative Diesel Only system in the financial analysis. The Diesel
Only system capital and operation and maintenance costs are calculated
using Figures VI-I and Vl-2. The results are entered into financial
evaluation sheet, Figure Vll-2.
Unit energy costs are evaluated in Figures VII-I and Vll-2. Payback
periods are evaluated in Figure Vll-3. Internal rates of return are
evaluated in Figure Vll-4.
F.3 Summary
I. TOTAL CAPITAL COST ($xI 000)
2. UNIT ENERGY COST: Year I
(¢/kWh) Year 24
IX-7
Hydro
2823.6
9.34
8.86
Diesel
1378
10.60
12.07
3. PAYBACK PERIODS (YEARS)
a.
b.
c.
Before Taxes (Case I)
After Taxes (Case 2)
After Taxes (Case 3)
4. INTERNAL RATE OF RETURN (IRR)
a.
b.
c.
G. CONCLUSION
Before Taxes (Case I)
After Taxes (Case 2)
After Taxes (Case 3)
6
9
6
24.5%
14.0%
22.0%
The preceding summary data indicates that Carpenter and Cody Creeks
are viable sites for micro hydro development. A feasibility level
investigation is warranted.
IX-8
Redfish Creek
near Harrop
Stn. No. 08NJ061
Stn. No. 08NJ021
DA = 26.16 km
....... Q (m 3 /s)
X
0.082 (Feb)
1.0 0.161 (Jan)
0.167 (Mar)
0.218 (Dec)
0.289 (Nov)
0.306 (Oct)
0.326 (Sep)
0.385 (Apr)
0.411 (Aug)
1.838 (Jul)
2.246 (May)
4.231 (Jun)
TABLE IX-I
MICRO HYDRO STUDY -CARPENTER, CODY AND SANDON CREEKS
FLOW DURATION DATA
Carpenter Creek Cody Creek Sandon Creek
near Confluence near Confluence of near Confluence
of Cody Cree~
DA:: 19.0km
Carpenter Cr1ek
DA = 16.4 km
of White Crezk
DA = 4.1 km
Q (m 3 /s) Q (m 3 /s) Q (m 3 /s)
0.060 0.051 0.013
0.117 0.10 I 0.025
0.121 0.105 0.026
0.158 0.137 0.034
0.210 0.181 0.045
0.222 0.192 0.048
0.237 0.204 0.051
0.280 0.241 0.060
0.299 0.258 0.064
1.335 1.152 0.288
1.631 1.408 0.352
3.073 2.652 0.663
%of Time
Equal or
Exceeded
100
91.67
83.33
75.00
66.67
58.33
50.00
41.67
33.33
25.00
16.67
8.33
ADDENDUM I
MICRO HYDRO STUDY
SITE INVESTIGATION ASSESSMENT
A. GENERALDATA
I. Latitude 49° 59'
tl ' Longitude Ill ll
Location
District Lot No. or other references
2. Elevation (m)
above MSL 1100
3. Winter Conditions -Total snowfall (m) 4.1
Months of heavy snow NOV. MP.f' ..
4. Population N /A
5. Number of houses N /A
Degree days October-March incl. (°C-days)
Mean Daily Minimum Temperature (°C)
6. Types of industry and numbers employed rv'i!NI~&) UNKNOvJN
7. Anticipated Load Average 120 kW 1 lNI11 P)L LY
Peak kW ' 1200 j
8. Present Load Average 450 kW
Peak ~JJO kW
II
9. Access to Site (bridge capacities, underpass heights, airfields,
road standard, possibility for sea or lake access).
L066-1N6-ROAD FROM FROM NEW DENVER, B.C.
10. Availability of labour (classification and source/town).
UJNSIRUCTIOI'I-NELS01\l 1 B.G.
OPERfr\ ION t MA!NTENtiiCE. -AT flllt--IE
II. Availability of contour mapping, aerial photography, geological
mapping. List maps used in the study.
j·.SO,COO SCf\Lc TOP06RAPH!CAL SURVEY
B. WATER AVAILABILITY
CATCHMENT AREA
1. Period of streamflow records in catchment and Gauge No. M 11-J W]/1 L
Period of streamflow records in nearby catchment and Gauge No. 12@ Ot N :r Dfo I
2. Period of precipitation records in catchment. 30 YEARS
Period of precipitation records in nearby catchment. UNKNOWN
3. Data for flow duration Curve: Generated YES ____1_ NO
(Use method set out in "Water Resources Development" by E. Kuiper,
P. 30)
% OF TIME EQ. OR EXCEED.
100% (Firm)
95%
50%
FLOW (m3 /sec)
Q. II I (1\ p ;, E } R +
0.22 \COD'{ (F[E:.KS
0.44 j COME.:/11[ D
4. Spot measured flow. ~!ONE
Proposed diversion point measured flow
Date of measurement ------------------
5. Is regulation to be used? YES ---
Wi II an existing structure (dam) be used
3 ____ m Estimate of storage
Firm flow (using regulation)
6. Eyewitness accounts:
NOHE. maximum flood levels
NONE·
NO~l E •
minimum water levels
ice formation,
thickness and extent
NO __ _
YES __
Dates
Dates
Dates
NO ---
7. Existence and value of fish in the stream.
UNKNOWN
8. Notes from field inspection.
Water quality:
NOtiE •
NONE •
LOW
NONE..
wastes, chemicals (is there industry dumping effluent
upstream)
sea water contamination
sand/silt content (turbidity at time of inspection)
debris
air temperature (°C)
C. CONSTRUCTION MATERIALS
I. Availability of aggregate (sources).
NEW DENVER, 13.(, Of< ON SlTE
2. Gradation and petrographic analysis results of aggregates
(grave I and sand).
NOI 1\YAILAE,LE
3. Availability of lumber
(source)
i) green or fresh cut
ii) seasoned
iii) dried
4. Availability of cement (source).
HAS TC 8t rr''i'JijHl JJ'.J (NELSOt·l .3.G.)
5. Is there a concrete plant (source)? NE-LSON. f3 .(,
Does it have a precasting yard? UNK}!QWN
ON SITE
NE-W DEU 11Sf?)3.G.
NFW C t~ ~i\ir<:; S.(
D. SITE SELECTION
I. Diversion weir and intake:
2.
a. Length of weir _.:::l:...:::O~Y'f\.!....:,_ _____________ _
b. Maximum height __ .... .=:..~..!.:.O~m~-------------
c. Foundation conditions soil
rock
X COAPSE-GR/\YEk
------------------
d. Site description
e. Access &RAVE k POADS UP TO /5/1
: G-RADE
Power Canal:
a. Length N/A
b. Conditions soil
rock
c. Site Description
d. Access
3. Penstock:
4.
a.
b.
c.
Length
Conditions
Site description
d. Access
T ransm iss ion Line:
a. Length
b. Conditions
c. Site description
d. Access
2550 '11
soil X CO/'IPCE (,pf'.'/EL
rock
DEN' E UtJDERBPIJC·H flt,fQ Jl!~~ ::_p
soil f.. GPJ\VEL
rock
D. 5. Powerhouse:
a. Foundation conditions soil X G-RAVEL NEAR 5l2RFACE
rock
b. Area for Switchyard AD5A( ENT To PI H
c. Site Description OE:NS'-,:. I hiDF r; t'J'I)S\1 /1 ~!0 Tlf'/\BER
d. Access G-oOD E yy~:---n : ! (y P ('f) D
6. Tailrace:
a. Length MINI Mill-
b. Conditions soil X G-Pf\V EL-
rock
c. Site description
E. EQUIPMENT SELECTION DATA
I. General Measurements:
a. Tailwater elevation (above sea level)
Headwater elevation (FSL) (above sea level)
_ _:_11-'--o_o __ m
b. -----'--=1 2=-5:=::.~ =2.=---_m
c. Gross head (vertical distance between headwater level
(FSL) and tailwater level) ______ m
2. Water Level Variations:
a. Tailwater elevation from m to ---___ m
b. Headwater elevation (FSL)
from m to ---___ m
3. Mode of Operation:
Will plant operate on an isolated power grid? YES_t_ NO
If no, state: Frequency Hz
Tension
Type of existing system
v -----
isolated Diesel-Electric
isolated Hydro-Electric
Capacity of existing system COOO kW
X
F. POWER AVAILABLE
Design discharge
Gross head
Power (P)
-----'1~......· ~..;;.__::::.tQ __ m 3!s (from 8.3 or 8.5)
152 (from E. I)
design discharge {Q) x gross head {H) x specific
weight of water x efficiency
-specific weight of water = 9.8 kN/m 3
let specific weight of water x efficiency = 7
{this will assume an efficiency of 0. 71 for the
entire system, i.e. all losses lumped together)
P = 7QH On kW)
p = 7 X • 3<0 X 152.
= l4b3 kW
ADDENDUM II-A
C. MICRO HYDRO COST ESTIMATING PROCEDURE AND SUMMARY
C.l COST ESTIMATING PROCEDURE (Working Sheet Ill)
BASIC DATA
Micro Hydro Site Name: (!lRPe.rn:R. AND COD'{ CREEKS (51LV!HJA MINES)
Available Head (m): I --~=-----------3 ( 0.12m 3 /s CARF~Nit:RO<.
Design Discharge (m /s): Q.23ALT. C) 0.11 ~"~'.3/S [OD'{ CK.
Installed Power Plant Capacity (kW): 245 --~~----------
Access Roads -Length (m): USE: EX!S11"'1G= FiJCS
Width (m):
Type of Material: Overburden
(As % of Total Length)
Rock
Average Ground Cross Slope (%): In 0/B
(%): In Rock
Power Canal -Total Length (m): NIA
Average Ground Cross Slope(%):
Type of Material & %of Total Length
%Lined %Unlined
Ice Cover No Ice Cover
Gabion Weir -Average Height (m): __ 2 . ..:...5 __ _
CrestLength (m): '0+!0=15 (2WEIRS)
Penstock-Length (m): 2-C 0 (O ·II vr)fs) ZOOO (0.12 rr)/?) 350 ( Q. 2 3»• :/S)
Length @ less than 30% slope
Length@ more than 30% slope 2550@ bO?o
Transmission Line -Length (km): _.:....l....;;:.b __ _
C. I COST ESTIMATING PROCEDURE (Cont'd) Working Sheet 112
Item Figure
Number Cost Component Description Number Unit Value
CIVIL WORKS COST ESTIMATING PROCEDURE
1.0 ACCESS ROADS
I .I EXCAVATION IN OVERBURDEN
a Basic Unit Cost II -I $1m
b Adjustment for Width I II - 2 Factor NIA I c Adjustment for Length II - 3 Factor
d Adjusted Unit Cost 1.1 (a X b X c) $/m
1.2 EXCAVATION IN ROCK
a Basic Unit Cost II - 4 $/m I b Adjustment for Width II - 5 Factor I N/A I c Adjustment for Length II - 6 Factor i
d Adjusted Unit Cost 1.2 (a x b x c) $/m :
i
2.0 UNLINED CANAL
a Basic Excavated Volume 11-7 OR 11-8 3 m /m
b Adjusted Excavated Volume II - 9 m 3 /m N/A
c Basic Unit Cost of Excavation II-13 $/m
d Adjustment for Length II -14 Factor
e Adjusted Unit Cost 2.0 (c x d) $/m
3.0 LINED CANAL
a Basic Excavated Volume 11-IOORII m3!m
b Adjusted Excavated Volume II-12 3 m /m N/A
c Basic Unit Cost of Excavation II-13 $1m
d Adjustment for Length II -14 Factor
e Adjusted Excavn. Unit Cost (c x d) $/m
C. I COST ESTIMATING PROCEDURE (Cont'd) Working Sheet 113
Item Figure
Number Cost Component Description Number Unit Value
CIVIL WORKS COST ESTIMATING PROCEDURE (CONT'D)
3.0 LINED CANAL (Cont'd)
f Concrete Lining Volume 11-15 OR 16 m 3/m
g Basic Concrete Lining Cost II-17 $/m N /A
h Adjustment for Length II -18 Factor
i Adjusted Lining Unit Cost (g X h) $/m
j Adjusted Unit Cost 3.0 (e + i) $/m
4.0 HEAD WORKS
4.1 GABION WEIR i
Basic Unit Cost II-19 $/m GIO.O I a I I I
b Adjustment for Length II -20 Factor 1. 0
c Adjusted Unit Cost 4.1 (a x b) $/m biO.O
4.2 INTAKE STRUCTURE
I
l
I
a Total Cost 4.2 II -21 LS 14000. I (for-2.)
5.0 PENSTOCK 2.00 m Z.OOOm ~50rr.
a Required Inside Pipe Diameter
I
II -22 mm 2..05. 300. 420.
b Basic Unit Cost II -23 $/m ~4 bb. C03.
c Adjust for Length II -24 Factor
; 0 co_ . '-v
d Adjust for Slope II -25 Factor 1.50 i
e Adjusted Unit Cost 5.0 (b X C X d) $1m "J 0. 0 (ME.l
6.0 POWERHOUSE
6.1 POWERHOUSE (CIVIL WORKS)
a Total Cost 6.1 II -26 LS 3 2000.
C. I COST ESTIMATING PROCEDURE (CONT'D) Working Sheet 114
Item Figure
Number Cost Component Description Number Unit Value
CIVIL WORKS COST ESTIMATING
PROCEDURE (Cont'd)
6.0 POWERHOUSE (Cont'd)
ELECTRICAL AND MECHANICAL COST
ESTIMATING PROCEDURE
6.2 POWERHOUSE (ELECT & MECH) J
l
a Total Cost 6.2 II -27 LS 1~0000
7.0 TRANSMISSION LINE l a Total Cost 7.0 II -28 $/km !lbOO I
C.2 COST ESTIMATING SUMMARY (User Sheets)
Item Unit I Number Cost Component Description Unit Quantity Cost Cost
'
i
l • I Access Road Through Overburden m -I -
1.2 Access Road Through Rock m I -
2. Unlined Canal m --I -
3. Lined Canal m --I
4.1 Gabion Weir m tra biD. 109'60
4.2 Intake Structure LS -14000
5. Penstocks
-Slope< 30% m --
-Slope~ 30% m 2550 90. 2l<::J500
6.1 Powerhouse Civil Works i LS -~2 coo
Sub Total Civi I Works Direct Costs I
2f(J.Sol
2£Cb 460
Contractor's Indirect Costs* I % , 5b 160430
! I
TOTAL CIVIL WORKS COSTS ! I 11 4b'J 10 I i
I
I
6.2 Powerhouse (Elect and Mech) LS -I 100 ooo
I I 2_9 1 b() 7. Transmission Line km 1.6 llbOO I
I
! i (s5'5 07 0 TOTAL (ITEMS I TO 7) j t
I --I
8. Engineering and Management % ' 10 ~5 52.06, I":::-c:: I
I
.... ~ _./ ._/
!
(% of Total (Items I to 7)) I
I
9. Contingencies: '
Civil Works % I 20 44(:,910 COS'360 I
(%of Total Civil Works Costs) ! !
Powerhouse Elect. & Mech. % i 15 100000 Z-1000
(% of Item 6.2)
Transmission Line % 20 2<Qlb0 h'(o' ! _..) :-.)
(%of Item 7) l Engineering and Management
(%of Item 8) % i 10 hsscc G;s s-o
*Using Graph 29
C.2 COST ESTIMATING SUMMARY (Cont'd)
Item Unit
Number Cost Component Description Unit Quantity Cost Cost
PROJECT COST IN JANUARY 1980 CANADIAN DOLLARS I <D49 I 30 I
Price Escalation to Start of Construction Date 0
Cost of Interest During Construction: o.s-x 14 -:::.l% 5<34 00
Price Escalation During Construction (E.D.C.) 5% .q j_Ll 00
Cost of Interest on E.D.C. Q. 5 'i I~ -_o 1 °/o 3000d
TOTAL CAPITAL COST: [ <Jr:;L'. ocol
SLJPPLfrv'IEf.JTARY DiESEL /NSTALLI1TION COSTS
LONG TERM CAP· COSTS (YR 0-24)
-DIESEL PLANT (CURVES) FIG-YI-1) llh9 kvJ
-SING--LE \.)~J\t L'Jt)t> KW
SHORT TERH CAP. COS\S (YR 0-12-)
-IV-IO VN liS 2-'f.-. ~Sb KvJ
S~OR\ TE-RM CAP. COSTS lYR 12-24)
-TwO UN 11S 2-X b40 k\t.J
HYoP-O -surPL. DlESEL sYsiEM cosTs
I 'JAN 19'00 ~ E<SCA L.
· .$ ~ ,ood $ X/OOO
I -'* 21S" I z__c;-2 .<3 :
l~l 167·6-'*,
~34
4--:,o
i
i
i 40~ ,2_ 1
LONG-\E-RM CfiP. COStS (YR 0-llJ)::: CJ54-+ 252.5--t
SHORl TCK'M (f1P. CoSlS (YR 0-12)
SHOR1 TERM (.f\P. COSTS ('{R 12 -2LJ)·
l0T G = 139LJ.4
= 315.2..
::::. 40:S.2
TOTAL
OPERAllON 4 Mfi!NlENANCt (YR 0-12) -1/2.5
(DIESEL ENr R6 Y /T01 ALENE R G-Y::: Q.lO)
0 PER All 0 J-J t M p, 1 NT EN /1 N C E ( '( R \2-2 LJ) =--I '2 b. 3
(DIESEL ENER61' /TOTAL ENERCrY:: 0.15)
COS\ -=2152.B
*~ (ESU1L.I2~.6)
:** ( ESU1L. t3B .9)
~ ESCALAlED IHE SAME AS FOR HYDRO ~DR110N OF sYSTEM (~EE ABOYE)
~ * ESCALf\lED lOYo ( OffvJ IS Pf~ORATED /lLSO)
ADDENDUM II-B
C. MICRO HYDRO COST ESTIMATING PROCEDURE AND SUMMARY
C. I COST ESTIMATING PROCEDURE (Working Sheet Ill)
BASIC DATA
Micro Hydro Site Name: (1\F'PENTER ANJ) CODY CPEE KS ( 'SILV!lNA ~1lii\!FS)
Available Head (m): 152
Design Discharge (m 3/s):
() 30 vn~/S (APP'E:NTfR (K.
0.55 (ALT CzJ 0·25vn'-/5 DY U\
Installed Power Plant Capacity (kW): _.-:5_...8"-'S"'--------
Access Roads -Length (m):
Width (m):
Type of Material: Overburden
(As % of Total Length)
Rock
Average Ground Cross Slope (%): In 0/B
(%): In Rock
Power Canal -Total Length (m): N/A
Average Ground Cross Slope(%):
Type of Material & % Jf Total Length
%Lined %Unlined
Ice Cover No Ice Cover
Gabion Weir -Average Height (m): 2.5
Crest Length (m): '6+ I 0::: 10 ( 2 VI t w::)
Penstock -Length (m): 200 (0.25 m 3/S) ZOOC (o .-:Cr• 3/~) 350 ( Q. 55 vr,3 I~)
Length @ less than 30% slope
Length@ more than 30% slope
T ransm iss ion Line -Length (km): ).b
C. I COST ESTIMATING PROCEDURE (Cont'd) Working Sheet t/2
Item Figure
Number Cost Component Description Number Unit Value
CIVIL WORKS COST EST!MA TING PROCEDURE
1.0 ACCESS ROADS
1.1 EXCAVATION IN OVERBURDEN
a Basic Unit Cost II -I $/m
b Adjustment for Width 11-2 Factor N/A
c Adjustment for Length II - 3
Factor ' I
d Adjusted Unit Cost 1.1 (a X b X c) $/m I
1.2 EXCAVATION IN ROCK
a Basic Unit Cost II - 4 $/m
b Adjustment for Width II - 5 Factor N !A
c Adjustment for Length II - 6 Factor
d Adjusted Unit Cost 1.2 (a x b x c) $/m
2.0 UNLINED CANAL I
a Basic Excavated Volume 11-7 OR 11-8 m 3 /m I
b Adjusted Excavated Volume II - 9 m 3 /m N/A I
c Basic Unit Cost of Excavation II -13 $/m
d Adjustment for Length II -14 Factor
e Adjusted Unit Cost 2.0 (c x d) $/m
I
3.0 LINED CANAL I
a Basic Excavated Volume 11-10 OR II m 3/m I
b Adjusted Excavated Volume II -12 3 m /m N/A
c Basic Unit Cost of Excavation II -13 $/m
d Adjustment for Length II -14 Factor
e Adjusted Excavn. Unit Cost {c x d) $/m
C. I COST ESTIMATif\JG PROCEDURE (Cont'd) Working Sheet 113
Item Figure
Number Cost Component Description Number Unit Value
CIVIL WORKS COST ESTIMATING PROCEDURE (CONT'D)
3.0 LINED CANAL (Cont'd)
f Concrete Lining Volume 11-15 OR 16 m 3 /m
g Basic Concrete Lining Cost II -17 $/m N/A
h Adjustment for Length II -18 Factor
I Adjusted Lining Unit Cost (g X h) $/m
j Adjusted Unit Cost 3.0 (e + i) $/m
4.0 HEADWORK$
4.1 GABION WEIR I a Basic Unit Cost II-19 $/m ~1o.o I .
l-0 i b Adjustment for Length II -20 Factor ! '
(a x b) $/m
I
(o!O·O c Adjusted Unit Cost 4.1
;
I
'
4.2 INTAKE STRUCTURE I
!
I
a Total Cost 4.2 II -21 LS I 15900
(forz.) 1 I
5.0 PENSTOCK 200w. 2000m 350
a Required Inside Pipe Diameter II -22 mm 435 4lS bli5
b Basic Unit Cost II -23 $/m ' 05. '?2.. lib.
c Adjust for Length II -24 Factor o.0o
d Adjust for Slope II -25 Factor !.SO
I l15.0(AYE.) Adjusted Unit Cost 5.0 (b X C X d) $/m I e I
I
I
6.0 POWERHOUSE I
6.1 POWERHOUSE (CIVIL WORKS) I
I
a Total Cost 6.1 II -26 LS L __ ~.'1_~ o o _____ -
C. I COST ESTIMATING PROCEDURE (CONT'D) Working Sheet 114
Item Figure
Number Cost Component Description Number Unit Value
I
CIVIL WORKS COST ESTIMATING I
I
PROCEDURE (Cont'd) i
i
I
6.0 POWERHOUSE (Cont'd) ' I
ELECTRICAL AND MECHANICAL COST
ESTIMATING PROCEDURE
6.2 POWERHOUSE (ELECT & MECH)
a Total Cost 6.2 II -27 LS I 2.. l2000 I
I
7.0 TRANSMISSION LINE I
I
a Total Cost 7.0 II -28 $/km I llGOO I
C.2 COST ESTIMATING SUMMARY (User Sheets)
Item Unit
Number Cost Component Oeser ipt ion Unit Quantity Cost Cost
1.1 Access Road Through Overburden m -
1.2 Access Road Through Rock m -
2. Unlined Canal m -
3. Lined Canal m -
4.1 Gabion Weir m 1<0 ~10. 10960
4.2 Intake Structure LS --15000 I
5. Penstocks
-Slope .( 30% m -' !
-Slope~ 30% m 50 \25. '?oltl50
6.1 Powerhouse Civi I Works LS --3ll500
Sub Total Civi I Works Direct Costs 300 l30
Contractor's Indirect Costs* % 56 3001?.0 2l26l0
TOTAL CIVIL WORKS COSTS 5'3~000 1
6.2 Powerhouse (Elect and Mech) LS 2l'L000
{. Transmission Line km l.b 17&.00 2') JbD
TOTAL (ITEMS I TO 7) 'o'-J ~ cc I
8. Engineering and Management % 10 • f " :.,£.V
(% of Total (Items I to 7)) I
9. Contingencies:
Civil Works % 20 5':33000 110000
(%of Total Civil Works Costs)
Powerhouse Elect. & Mech. % IS ~0000
(% of Item 6.2)
Transmission Line % 20 2.0!b0 5G30
(%of Item 7)
Engineering and Management
(%of Item 8) % 10 C(;;':730
*Using Graph 29
C.2 COST ESTIMATING SUMMARY (Cont'd)
Item Unit
Number Cost Component Description Unit Quantity Cost Cost
PROJECT COST IN JANUARY 1980 CANADIAN DOLLARS
Price Escalation to Start of Construction Date
jl15bt:flto I
0
51000
51~00
4100
Cost of Interest During Construction: 0.5'i-14-7%
Price Escalation During Construction (E.D.C.) 5"/tJ
Cost of Interest on E.D.C. 0. 5 'I-. f 4 7 '/o
TOTAL CAPITAL COST:
SUPPLEfVIEfJTARY OlESEL INSTAlLATION COSTS
LONG TERM CAp. COSTS (YR 0-24)
DIESEL PLANT (CURVE B) F16YJ-I) )7(;9 kvJ
-THREE Ut--JtiS Ll36 KW 1 bLIO KW
SHORT TERri\ GAP. COSIS LYR 0 12-)
-NO VNIIS
St1oKT TERM CAP. COSTS LVR 11-24)
-NO VNI1S
I J?,OOCOQ I
JAN 1900 I E'SCA L. I
.$"~-roo $X/DOD
"* 215" 2C?2 .£
597 6lO.n "*
0 0
0 0
8VOR0 -SUPPL. DIESEL 5\'SIEM COSTS
L0"-1&-IERttl (f,p, COSIS (YR 0-2LJ)
SHOR'llCRM CAP. (OSlS (YR 0-!2)
SHOR11ERM U\P. COSTS (YR 12 2LJ)·
1300-r l52.~r bl().t;) = 2223.6
= 0
-0
TOTAL (OS\ -=2'2.23.b
OPERAliON 4 MfiiN1ENANCE (YR 0-12) ~ 01.£)
(DIESEL ENERGY /TOl/\Lf-NERCrY:::: 0-4L!)
OPE RAllO~ t Mf\ 1 N NANCE (YR 12 2lJ)-102.1
(D!E<:~EL ENER0Y /TOTAL ENERuY-0.53)
** (ESC/I L. 9b.6)
:%* (ESU1L. 1!3.0)
-if ESCALA1E.D THE Sflti\E AS FOf~ HYDRO PORliDN Of sYSTEM (SEE f\EOYE)
7 * E5CP.LAlED 10% ( Otfvl IS Pf~ORATED f\LSO)
ADDENDUM II-C
C. MICRO HYDRO COST ESTIMATING PROCEDURE AND SUMMARY
C. I COST ESTIMATING PROCEDURE (Working Sheet ill)
BASIC DATA
Micro Hydro Site Name:
Available Head (m):
CARPE-NIE& f)ND CCDY (REEKS (51LVAMA ~J11UES)
152
Design Discharge (m3 /s):
Installed Power Plant Capacity (kW): _ _._I4,_L.;. {:_:::::..,., 3::;__ ____ _
Access Roads -Length (m):
Width (m):
Type of Material: Overburden
(As % of Total Length)
Rock
Average Ground Cross Slope (%): In 0/B
(%): In Rock
Power Canal -Total Length (m): N /A
Average Ground Cross Slope(%}:
Type of Material & % 'Jf Total Length
%Lined %Unlined
Ice Cover No Ice Cover
Gabion Weir -Average Height (m):
Crest Length (m): B i I C :-j ( 1/.': ! ? ~,)
Penstock -Length(m): 2-oo(O(r,~'""·:;<J) 20ro (o15h:b) ~,50(1. 'rT~/~)
Length @ less than 30% slope
Length@ more than 30% slope
Transmission Line-Length (km): j.b
C. I COST ESTIMATING PROCEDURE (Cont'd) Working Sheet 112
Item Figure
Number Cost Component Description Number Unit Value
CIVIL WORKS COST ESTIMATING PROCEDURE
1.0 ACCESS ROADS
I. I EXCAVATION IN OVERBURDEN
a Basic Unit Cost I
I II -I $/m
b Adjustment for Width ' II -2 Factor NIA I
c Adjustment for Length ! II -3 Factor
d Adjusted Unit Cost 1.1 I (a x b x c) $/m I
1.2 EXCAVATION IN ROCK I
a Basic Unit Cost I II -4 $/m
b Adjustment for Width I II - 5 Factor NIA
Adjustment for Length i II - 6 Factor c I
d Adjusted Unit Cost 1.2 I (ax b x c) $/m I i
I !
I
'
:
2.0 UNLINED CANAL '
3 ' I i a Basic Excavated Volume i 11-7 OR 11-8 m /m I
I 3 b Adjusted Excavated Volume I II - 9 m /m N/A I
c Basic Unit Cost of Excavation I II-13 $/m I
I d Adjustment for Length ' II -14 Factor I
I
e AdJusted Un1t Cost 2.0 i (c x d)
I
$/m
3.0 LINED CANAL
a Basic Excavated Volume 11-10 OR II 3 m /m
b Adjusted Excavated Volume II-12 m 3/m N/A
c Basic Unit Cost of Excavation II-13 $/m
d Adjustment for Length II -14 Factor
e Adjusted Excavn. Unit Cost (c x d) $/m
C. I COST ESTIMATING PHOCEDURE (Cont'd) Working Sheet 113
Item Figure
Number Cost Component Description Number Unit Value
CIVIL WORKS COST ESTIMATING PROCEDURE (CONT'D)
3.0 LINED CAhJAL (Cont'd)
f Concrete Lining Volume 11-15 OR 16 3 m /m
g Basic Concrete Lining Cost II-17 $/m NIA
h Adjustment for Length II -18 Factor
i Adjusted Lining Unit Cost (g X h) $/m
J Adjusted Unit Cost 3.0 (e + i) $/m
4.0 HEADWORKS
4.1 GABION WEIR
a Basic Unit Cost II-19 $/m biO.O
b Adjustment for Length II -20 Factor !.C
c Adjusted Unit Cost 4.1 (a x b) $/m (:/C. 0 I
4.2 INTAKE STRUCTURE I
a Total Cost 4.2 II -21 LS
5.0 PENSTOCK 200r. L-CCC't'• ·; ,,1
a Required Inside Pipe Diameter II -22 mm f l50 c;;LO I
b Basic Unit Cost II -23 $/m /l2A. ) ~;3. ll
c Adjust for Length II -24 Factor l 0/?:S
d Ad just for Slope II -25 Factor j.')O
I
102.0 (A'I::.) e Adjusted Unit Cost 5.0 (b X C X d) $/m !
i I
6.0 POWERHOUSE I
j
6.1 POWERHOUSE (CIVIL WORKS)
a Total Cost 6.1 II -26 LS 7 go,OO _, ' ~_..
C. I COST ESTIMATING PROCEDURE (CONT'D) Working Sheet tJ4
Item Figure
Number Cost Component Description Number Unit Value
CIVIL WORKS COST !MATING
PROCEDURE (Cont'd)
6.0 POWERHOUSE (Cont'd)
ELECTRICAL AND MECHANICAL COST
ESTIMATING PROCEDURE
6.2 POWERHOUSE (ELECT & MECH)
a Total Cost 6.2 II -27 LS 450000
7.0 TRANSMISSION LINE I
I
I i
a Total Cost 7.0 II -28 $/km I 11600
C.2 COST ESTIMA Tlt'-JG SUMMARY (User Sheets)
Item Unit
Number Cost Component Description Unit Quantity Cost Cost
I. I Access Road Through Overburden m ----
1.2 Access Road Through Rock m ---
2. Unlined Canal m ----
3. Lined Canal m --~----
4.1 Gabion Weir m I~ biO. \0900
4.2 Intake Structure LS --2C1(00
5. Penstocks
-Slope <30% m ----
-Slope~ 30% m 2550 \<OZ. f}(;L: \00
6.1 Powerhouse Civi I Works LS --?>CJ<:?OO
Sub Total Civi I Works Direct Costs --S'35(o<20 I
Contractor's Indirect Costs* % 55 535Grt0 2"/6~?.0 '
TOTAL CIVIL WORKS COSTS <(':'").,o >,no _) • ,_I
6.2 Powerhouse (Elect and Mech) LS 450 000 !
7. Transmission Line km 1-b llGOO 2£1GC i
'
TOTAL (ITEMS I TO 7) I j 01(\L: 60
8. Engineering and Management % 10 \:, 00SO
(% of Total (Items I to 7))
9. Contingencies:
Civil Works % 20 030?JO l(o(JOGO I
(%of Total Civi I Works Costs)
Powerhouse Elect. & Mech. % IS Gl500
(%of Item 6.2)
Transmission Line % 20 201b0 5( /~0
(%of Item 7)
Engineering and Management
(%of Item 8) % 10 1~0'30
*Using Graph 29
C.2 COST ESTIMATING SUMMARY (Cont'd)
Item Unit
Number Cost Component Description Unit Quantity Cost
PROJECT COST 11'-l JANUARY 1980 CAt'-lADIAN DOLLARS
Price Escalation to Start of Construction Date
Cost of Interest During Construction: 0. 5 'Z 14-:::: I%
Price Escalation During Construction (E.D.C.) 5%
Cost of Interest on E. D. C. 0 5 'I-14-=--('Ia
TOTAL CAPITAL COST:
SUPPU':f-"lEIJTilRY DIESEL INSTALLATION COSTS
LONG-TERM CAp. COSTS (YR 0-24)
-DIESEL PLANT (CURVE B) f\6':ll-1) llb9 kW
-TI-H\EE l>~tiS 4t\GKW) 2'/-C:JLJOKW
SHORT TERM CAP. (06\S LYR 0-!Z-)
-NO VNrTS
SHoRt TE-RM CAP. COSTS LYR 11-24)
-NO VN!1S
-::fAN 1900
.$ "!000
216
597
0
0
Cost
I I (')Sl 590 I
0
li9LJIO
2Ll560
4130
f-lt_"::?_oo oon J j
E<SC.f\ L. I
$ '1../000 I
"* Z-62 .'3
6lO.~-'*
0
0
HYDRO -SUPPL. DIESEL SYSTEM COSTS
LONG-TE-RM C/IP.COSTS (YR0-2"1)-\Soot
~HOf?TlU~fVI Ci1P. LOSlS (Yf~ 0-12)
SHOR11ERM (f\P. Co s (\"R 12 2/J)
.'(li (Jl0.0 = 2C023.b
::: 0
ToTAL COS1
OPERAltON-+ MAINlENf\NCt (YR 0 12) -13. b
(DIESEL ENERGY /101ALENERG-Y-0.29)
0 PERin 10}-.,1 + Mf\ l N TE NANCE ( YR 12 -1LJ):: CC33.5'
(DIEC..,EL ENER6Y /10TAL ENERCrY-0.35)
(ESCAL. 1()0
:'!¥* (fSUlL. 9l.CO)
-if ESCALA1ED IHE SAME AS FOR HYDRO P0R110N OF sYSTEM (SEE f\E~OYE)
~, * ESCALAIED IO% ( 0ffvj IS PRORATED /\LSO)
TABLE VIII-I
HYDRO AND DIESEL GENERATION UNIT ENERGY COST COMPARISON
Installed Capacity l4-b3 kW
Cost Escalation Factor (Jan 1980 to Year I) ). ; + (Cost Index beginning Year I)
(Cost Index Jan 1980)
Price of Diesel Fuel at Beginning of Year I --=2=0"'---cents/litre
Real Price Escalation of Fuel 1. 5 % per Annum/
Hydro Installation Capital Cost Upper Limit $ ).g IJ'i)LLI/I~Lower Limit$ 15 {'111LLIQ~{
YEAR
6 12
Energy Demand kWh x I 0 6 (~W LOA 0 GRO 'NTH ~
CO~l01DERSD 1 L.F-:::.-O.lO
8.9ll 9. 9l/ o.~~-u
Diesel Generation Unit Energz Cost
I • Jan 1980 Unit Energy Cost (Fuel @ 20¢/1)
(No real escalation assumed) 9.5 9.5 9.5
2. Fuel only cost component (Fuel@ 20¢/1) ~.o (,.() b.O
3. Difference = Capital & 0 & M Cost
Component (Line I -line 2) 3.s-'3.:) 3.5
4. Escalated value of Capital & 0 & M
Component Jan 1980 to Year I 4·0 LL.o 4.0 (line 3 x escalation factor)
5. Fuel only cost component Year I b.o (Pro-rate line 2)(without fuel escalation) b.O b.o
6. Fuel only cost component, subsequent
years (escalate according to real b,O (c;c 1.) fuel price escalation) •,)
7. Unit Energy Cost, (beginning year I dollars) ID. o (Line 4 + line 5 or 6) 10·5 II ·I
Hz:dro Generation Unit Energz: Cost U1212er
8.
9.
I 0.
Jan 1980 Unit Energy Cost (Fig VIll-I) b.O
Add 0 & M Escalation Component
= 4.2 x 10 6 x (Cost Escal. factor -I) 0.07
Annual Energy
Unit Energy Costs, (beginning year l 0, l dollars) (Line 8 + Line 9)
Compare Diesel Energy Costs (Line 7) with
Hydro Unit Energy Costs (Line I 0)
Limits Lower
0 ()7
5.[
fl. v
n
;:lj
"'0
"'0
m z
n
0 z
(J')
c
I
-l
l> z
-l
(J')
N
1 .J•L
~~:-
' 6
(S
-o ..of:.....::: ~.<z...o~ .... \
c:::>C> ~.,-s
-::."--.
('>_..
\...... ---------
"" ~'\ ~ \\
\\
Upperm/ne
oO'//
r
Carpt?n7er Creek.
ln!ok..e
!Present and proposed)
I
(!~Present Intake /onk.S
1' -~lnraA:e
\ (Presentcmd prop:;osed)
\
0 c
"Q
LEGEND
----,.<;ccess Roads
-----Penstock
----" ---Transmission Line
MICRO HYDRO STUDY
CARPENTER AND CODY CREEKS
DEVELOPMENT
LOCATION MAP
FIGURE 9-1
~ ·v
(")
:::l:i
"'C
"'C m z
(")
0 z
IJ)
c: r ....;
l> z
....;
IJ)
2.0
18 !----1-'---'--' -.-+---r-----t--+-
1.6 -,-t--,.-
~
\) 1.2
~
(j
-l:::
\l
-~
()
100 90 130 70 60 50 40 30
PercenT or time eqva//ec:t or exceeded
MICRO HYDRO STUDY
CARPENTER CREEK
FLOW DURATION CURVE
FIGURE 9-2
fl 'f.1
n
::0
2.2 -"'0
"'0
m z
2.0 n
0 z
/.!3 IJI c
r-_,
/.G l>
(J z ~ _,
~ /.4 IJI ..,
t
\J /. 2 ~ t
-..1:::
\j
/.0 -~
G
0.8
0.6
0-4
0-2
T --r~-~f=-~ .r-;~T-F=:1:=-~r··:~r :i~~F---P=T~'--;---:~-EfJ l
'-I '-I' ·1 ·_·•cl·i·l, L;··-1 --l_-r·'. I: 1_ 1 • ·: 1-,-1 .·1 H=--:--.. j : :--'--f-l-l : I , . : : • ; I 1 , : I
I ;~J-· l··· i. : i .. .. : I ~--1--+--;-h-+-i
. J .. J i )-,----r-1--:t -j~ j .. j.:.~(_ ;.L:--.J _ _:_~-~-1--~---11
I I ' ' : ' ' I . I ' ; I .
1 -' : '" r • 1 1
-
1 ; + -· I I · ! i 1 ~ : -· ·
1 • -: -: i--·-: : --! --l f-.---'-~-+~-~---------r------L~-r r-~--·~---+--~ ·: ---;---·-----~-----~
U =f~-1 -~=t-~ 1.~-l _:j ~=L~~-
1 I I j t I I I -1 I I . -1 ·j I : . j . ~ l ' I 1 1 i ' . i I -----r-+--+----:--~ '--\-"--------4-~ ~--~· --~-~~ ---r-1 ---! -r --1 ·-1 --1 • l··J ---J.-. 1-' : --1---: -' .1 --L--t -1--
bjl _ 1 _
1
. i . 1-H. . 1 : __ 1 _ 1 !~ __ :--r=·-~--:-~~H _ : . _. __
1 ----+----r--:--r~ ---+-'_.).1 ---\--Y--1--f -tl -----j-~;---~ --1 ~ -j-J ---t: .•. I -; I . I . j . . ' I . I i I : u ' I . I . I .. I If~ H-__ ·r-~r--1-:1 -~-~-11~_,-::-T·--~~-! ··!--+~~~~ I I I I ' I ' I I I I ' ' ~----;--l---~-t--;-, ~--;---1-,--~--~-----~---_J __ i
t I 1 • • • I --1 u l . I ---j 1 -. • I . • ·--1 -·-I -I l~ I I I I I I I t I -I I I ' ·-·-1-I I
' I I I I l . I I ' -r-' ' I I I ! ' I I .; . ' ' u • •• i i u I 1 u i j • u 1 u i .. I f---r........,.--~ I . .l-·-----r--·-;--+-:-·+-~~--,--'----L---i ··-,._ ;-~--·-~ ~ . I . I ; l . • 1 1 I . I : ! ; . i . I . ! . • l . J. . I . . I ~-i I I ' i ~ 1 --'i I I . ~1~-. ---~~-~-_L_ ________ ~--c·+ 7 1-1 : 1 -~ -· ~ I . J _:__ i : ~ . 1-·-:-~ i : : .. : . i :-i --· ;.............;-~--;.· --'-~---------___ , ---T----'----'-·--·--1
1 ---t·· :_II···: ll.; l ·;-h ~I ~--! .. Jl i-i ' i . l . j : I .. ; . 1 . i : j .. : . i
--. : ; . : I ~~~-~--~~-~~-;~~. --+-------r-~~--+-~~ r.l-r ! , ~ u. ~ ;_ .. L "-) -~-. -l ~--j . :._· . I ._ ~--._ ; _ .. _ i. _ .• : . I .. i _____ i ···--_-
1
>---:-. : -~-r~--l---f---1-~· -. 1 . , 1 • 1 1 1 : ---·----·--,-.-, :· . ~ . ! ... t ; I C j -r I d-. l --I ·-1 . ~ ·-; . 1 I .. ! . + . j ; . l . '
. 1 L.....~: -,-~~-~-:··~---~-~~-;--:----r--1 -:·--+-1···:----r-1
• u : i ·-I ! -· ! : i -I u: I "I . ! . i i : . ! i . ! . I ! i -~
:-:--; --l --i --~--ki~_t_l ~l ~j ..::_L~.L :~ -1~ --~r-~J~j
; 1 I I I : ! I : 1 • I , . . . I L : ++' : : -;-[·rf _1_· -~ -~J=~t~:i_~~-;~:.J~~-,..i ~~ l
I . l I ' i I l . ' I i ! ! ' i : ! : j . I . ! I i L:_~-1
· r ~j-~_::L~~~~---J_'_,~~_-1 1 .. , -c-+ · 1 -~ --1
MICRO HYDRO STUDY
CODY CREEK
FLOW DURATION CURVE
IO.:J 30 80 70 60 50 40 30 20 10 0
Percent o;f !/me e9u.:?//ect or exceeded
FIGURE 9-3
17\i u
("')
::0
"'0
"'0 m z
("')
0 z
(/') c r--;
l> z
-1
(/')
Ill
i:'
tl
" v
·'2
(;)
Percenf of time equalled or e-xceeded
MICRO HYDRO STUDY
CARPENTER AND CODY CREEKS
COMBINED
FLOW DURATION CUR\IE
FIGURE 9-4
fi u
("')
::a -"0
"0 m z
("')
0 z
(f) c r-
-1
l> z
-1
(f) .. J '"'
~
e'
l:l
-.(:
u
.'_2
Cl
Percenf of' lime. equalled or exceeded
' .. ~-6
~
-x
c
).. ..._
.,
1.> 851.2 l:l
Q.
l:l
'-.1
...__,,,~ ...... I l ,_ ,_ ... ,-,~-~.'.:JI/~_;;;'/,::::·.~::;_':~
LoQd 0%
Lood ~6
Fnd of
Peak = 1200kW
Fnd of year 12:
P:;:a k d:2rnor.d = 143 5 k ;~·
End of' Yt'ar 24:
Peak demand= 1715 kli
I em Z 466032 A Wh
MICRO HYDRO STUDY
CARPENTER AND CODY CREEKS
COMBir\ED
FLOW DURATION OJRVE
FIGURE S-4
~ ·o
("')
::0
'"0
'"0 m z
("')
0 z
(/1 c
r-
-i
l> z
-i
(/1
-~-,-.--~-w--:~-E~=~~-----------,
nJr.!rl. o_,..,,~.,.,,.....JIILi'C:J:Sr.::. ln'Y!WII
f.'.N'l7...._ uz.-n .., I'C"ovuo a ~
111'1'".JIIt.-l'N:,"t:J.;ULOIII'fi(T'Y"l..
J:l,.!S-rc...t~
a-re-.:.:..ov-~._, a-.-.. 1 ~ ("''W;J Ul(.l'1'l
1 IJol:'lll.."t~~CU;.,._c;£:",,• ir""":ft~_;!;'..t.;._y-{m:-.»C.'l:-~,)lm:.
,.,....:"l,.:"<..o• ""'). a:J,. ~ ~ ''
Doc-~"'~w...,.,:;,.-... .o.......o..!.......c1
r~..r:"'" I, 01. a ~ ;Ki.
:1 ~--"'1-01<-"""·-~>C::, LV:-!.>' p,;R' V.\. ('tl... lJ ...:l l.l
~ __ •.::;;,-""-•I t • I" CL= "''l· :,..~.:~ N':"'.ll 'Dol..
.... 'J". ····: ,..--,_~ 1'1.J.T.:' ;.. =~ ,,_~L:~
Jo.o.;•-: .o,_,;"'!M-'\~.....,. a~ M-""':::> I'"~ tt.·_IC_-.,.,..R, o.I-IOC'Tf'L
'tl*>~-::1~
rn r
WEl.KlY LOAD CURVl:.
,.. Qr ,,,..,.,
Y£,AR 0
"'" = 0
.,, .:.">f 1.~ rzc•lt'dcd
WLE"Kl. Y LOAD
DURATION .C.:UR\1£
~
~
100 "0 % cr ,,,_.
Y£AGl IZ (..AP.ACITY 0/...IRA(ION
D~.-,.,1!'0 ;,;p,...., rJ.t>w
<c*'-'(-''<;11"7 \ .~, ~_;'::!; ~!~";;!::!'!. r '<2"! __ !::?.:__.
SUioiMARY
(ncr~y (Arec vrtdf'r lccd Du•OhOI"' C,.,,.,)
[r>trtjy{A.•eo u•Hitr Stt<' Copcc•l:t ond lt>O~ Dutot.of'l Cur•••)
D•tltl [l'"t9l" tG) -® • Shod•.:! 01•!! for coyat•'J Cs.)
r.,d I (f'lt:HJJ a Cnn"lf's'o"' h1tt:t/kWn)
_,--~--
~~ ····· .. -1l-~£,/ ~-~ 7/
~~:~·--·--tz~· ----~-~ ___ _ .....
1R l_~
NXJ ..• . ""-"" ~.."'r ~-~
Lo,.ao
CUI'....'vE
""'/ ... Pr f1,.,.
Y~,AR ;?<II
Co"' s fr'v<: I L·.• ·""£~' I ~r~
co ..!!t> .. .,t,..:;r ...,.~:.-, ,.., .....
}, or !,1'1"J;e fl!'~<.:ll'rd•d
LOAD
v~
f"'fa'C fOr'"
;:,.,..,-,..,.// p. c :!.1('1/.~-,,.~ "f
J
----·---
----
~ :----r ------
\; ...--M,n ~ trtll #-f •QI 3\_j-~a-~~~~~:-<-'f
a 12
YII!IIPI'
LCAD GROWTH
C~~~I !:2::___E-'::~ ~1' !!2.~~--C_I_J_~y_~ _ __J
MICRO HYDRO STUDY
HYDRO CAPACITY
DETERMINATION WITH
SECONDARY ENERGY
,,
'Jca.s
b .~46
3
l '.i
FIGURE .,..
fl
\:1
n
:::0
"'C
"'C m z
("')
0 z
(f)
c
;-
-l
~ z
-l
(f)
END
OF
"''EAR
COL I
~ 0.
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
1 t.
12.
13.
14.
15.
16.
17.
1S.
19.
20.
21.
22.
23.
24.
L----
TOTAL
ENERGY
5
II.WI'\ I 10
COL. 2
6. 402
6.498
6.595
6.694
6.795
6.897
7. 000
7. 105
7. 212
7. 320
7.430
7. 541
7. 654
?. 769
7.335
3. 004
s. 124
3.246
S.369
-S. 4?5
8. 622
8. 752
3. 833
9. 016
PROJECT N A~E _Sjt,_V~J..il\~"llN.ES __ _
RIVER ISTRE A'-4 _(.8RJ'£J'D E.fl_(QQI ..CREEKS
LOCATION _.q'l•5_::t___II.J~L-
DATE _1'!1AK_CJ:ij_9a_g __ _
CAPITAL a OPERATING COSTS -HYDRO/DIESEL SYSTEM
HYDRO CAPACITY cl HYDRO CAPACITY Cz HYDRO CAPACITY cl
CAPITAL 0 s .. FUEL ANNUAL CAP1TAL 0 s .. F U(L -ANNUAL CAPITAL 0 " .. FUEL AN,..UAL COST HYDRO 6 OPERATING COST HYDRO ~ OPERATING COST HYDRO a. OPERATING DIESEL llo DIESEL COSTS DIESEL e. OIESE L
HYDRO $/YR. $/YR. $/YR. HYDRO $/YR.
f----·
COL. 3 CQ. o4 COL~ COL. 5 COL.7 cOL. a COL.'
1769. 60 222j. 60
tz3:so 259:--34 383:"!4 96:""60 15"()."01 123.80 269.50 393.30 96. 60 158.53 123.80 279. 90 403. 70 96. 60 167.27 123.80 2'30. 56 ;j 14. 36 96.60 176.23 123.80 301. 4 7 425.· 27 96.60 1S5 .. 43 123.80 312. 65 436.45 96:60 194 .. 87
123. 80 324. 0'3 447.89 '36. 60 2C~.54
123.801335.81 459. 61 96.60 214. 4 7 123.80 347.80 4 71. 60 '36. 60 2 2 ·\. 6·1 12'3. 81]' 360.03 483.88 96. 60 2:C5.07 123. 80 372.65 ·1%. 45 96. 60 245.77
483.20 123. so 385. 51 509. 31 o.oo 96. 60 226.73 13:3. 30 -100. 15 539.05 113. 00 2E3. 43 1 :n. 9o ~ 15. 13 554. 03 113. 00 2t2.45 138. 90 430. 42-569.38 113. 00 2':5.31 13:3. 90 446. 19 535.09 113.00 3( 9. 50 138. S'O 462.27 601. 17 113. co 323.53 138. 90 478.74 617. 64 113. 00 3:07 •. 92 138. 90 495.60 634.50 113. 00 3~2.67 138. 90 512. 86 65 t. 76 113. 00 3f?. 78 138. 'JO 5.30.52 663.42 113. 00 383.26 13:3. 90 54:3. 5'3 687.49 113. 00 3':C"'J. 13 138. '30 567.09 705. 99 113. 00 415. 3'3 138. 90 586. 03 724.93 113. 00 432.05
*FOR .ALTE:.R.r·H111VE:S C'-(1-{D C.3 , INI\i11L SUPPLE.ME.NIAR'{
DIESE.L 1NSTI1LL£D (.MAC.I11E:S ARE. SUFFIC.IEtJI FOR
LOADS 10 YEAR 24 NO PEPLACEME.N\ I'S ~E:EDED IN
~Et'IR \2 SlfH.E. DIESEL LOf\0 IS A SMALL PROP0\?1101-j
Or 1"0\AL LOAD
COSTS 01[ SEL ~ DIESEL COSTS
$/YR. HYDRO $/YR $/YR. $/YR.
COL. 10 COL. II COL. 12 COL. 13 COL I 4
~8.Z3. 6C
'24"b. b"t eo: ··.HJ !C"4:24 I ES: 14
225. 13 80.'90 103.43 190. 33
263.8? E0.90 114. 76 1 '05. 66
272. 83 E0.90 1ZJ. 22 2G l. 12
282.03 60.90 1£:5.82 2C s. 72
2':1.4? 60.90 13!. 56 212. 46
301. 14 £0.90 1:; 7. 4 :s 21 s. 35
311. 07 EO.. 30 14 3. 49 22 4. 38
321. 24 E0.90 14'1. 66 2::0 .. 56
331. 6 7 50.90 155. '39 2:2 6. 89
342. 37 50.90 1 E 2. 49 24 ). 39
3~3. 33 o.oo E0.90 169. 14 2~0. 04
3:02. 43 91. 80 1 ;:..;.-13 26 9. 9 3
3C:::J.45 5'1. 80 157. 36 273. 16
4('3.81 91. 30 1 ':?"i. 82 2E 3. 62
422.50 91.80 2(6. 52 2SS. 32
426. 53 S I. 30 216. 4 7 3C 3. 27
4~0.92 s I. 80 226.63 313. 48
4 f 5. 6 7 S I. 80 2:; ?. 14 32:3. 94
480. 78 91. so 247.8S 3::9. 66
4':'6. 26 <:1.80 2~'3.85 3:C0.65
51.?.13 91 •. so 271). 12 3E 1. 92 5£::3 .. 39 S' !. so 281.66,373.46 545.05 91.80 2'=3.49 3E5.29
MICRO HYDRO STUDY
HYDROELECTRIC CAPACITY
DETERMINATION
BENEFIT COMPARISON
SHEET I
·-
2 .. COLI~
--------'
FIGURE "'2:-2
a ·-r WI
n
:2J
"0
"0 m z
n
0 z
(/')
c ,...
-1
l> z
-1
(/')
[NO
OF
YEAR
0.
!.
2.
3.
4. s.
6.
7.
8.
9.
10.
1!.
12.
13.
14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
PRESENT
VALUE.
PROJECT NAME 5tL'UI~8_/1.1Nf:.!> __ _
RIVER/STREAM _CAS ~~.It..R.. C.OD'L CREEK';>
LOCATION _49~5-:L _jfl~L--DIESEL-HYDRO/DIESEL INCREMENTAL BENEFIT COMPARISON $"I 000
r---------------------------------------------------------------------------------------~~OATE ~~KUct ~~BQ __ _
INCREMENTAL CAPITAL COSTS B ANNUAL SAVINGS APTER DEPRECIATION ALLOWANCE B TAXES
INCREtrr.o1fNT A L
CAPITAL
COST
COL 7-COL.3
COL. I~
4:54.00
-4E3.20
3:53. 71
HYDRO CAPACITY c 2 WITH STANDBY
OVER HYDRO CAPACITY C1 WITH STANDBY
INCHE ... ENTAL DEPR.l ANNUAL COST AFTER TAX
ALLOw'ANC( SAYING BEFOHE ANNUAL COST
• TAX SAYING
COL 16 • COL.I7
COL 10-COL 6 -------2
COL. 16 COL. 17 COL I 8
17'9.43 136.53 158. OL
179. 09 128. I? 1:58.63
:5.73 139. 84 72. 7':1
:5.38 141.53 73.46
5.06 143. 24 74. IS
4. 76 144. 98 74.8?
4.47 146.75 75. 61
4.20 148.54 76. 37
3.95 1 :o. 36 77. !6
J. 71 1:2. 21 77.96
3. 4'1 154. 08 78.79
3. 28 1 :s. 99 79.64
-25. 91 1:6. 62 65.36
-2 4. 35 1:3.58 67 0 12
-22. 90 IE 0. 57 E8. 84
-2 [. 52 162. 59 70. 54
-2 0. 23 164. 6.J. 72. 21
-19. 02 1£6. 72 73. 8:5
-!? 0 87 lt 8. 83 75.48
-16. 80 170. 93 77. 09
-1 s. 79 173. !5 78. 68
-14. 84 175. 36 80.26
-13. '36 17?. 61 81. 33
-13. 12 179.88. 63. 38
738. 16
PV COST SAVINGS. PV COL. 16 I I ~[~ENTAL CAPITAL COSfS ::::: -p--y(oll5 = z 'Q'j
• HYDI<l CAPITAL CDS!' cx:MPCNENf IS Dt:PR!'.X:IATED CNER
2 YEARS, 50% Prn YEAR.
SUPPU~J-NTARY DIESEL CAPITAL Cl:'6T CXMPCNlNf IS
D£P HEX:I.ATlll ()V} R P fDJ E:CT LIFE Nf 6% PEH Y !:'.P.R Cl'l
DI:JJ.H/ltJ:.; BAIP.tU.
INCREMENTAL
CAPITAL
COST
COL 11-COL 7
COL 19
6CO.OO:
0.00
6CO. OG
HYDRO CAPACITY C:5 WITH STANDBY
OVER HYDRO CAPACITY c 2 WITH STANDBY
INCRE~ENTAL DEPR.
ALLOWANCE
*
COL 20
300.00
300.00
o.oo
o. 00 o.oo
0.00
o.oo
0.00
0.00
0.00
0. 00
0.00
o. 00
0.00
0.00
0.00
0.00
o.oo
0.00 o. 00
0.00
0.00
0.00
0.00
ANNUAL COST
S AIJI N G BEFORE
TA<
COL.I4-COL 10
COL 21
t>r:'47
64.79
68.21
71. 71
75.31
79. 01
62.80
£6.69
5-0. 68
'34. 78
5-8.98
1C3.29
112. 50
11 E,. 30
!:CO. 19
124. 17
1 ":' 0 ") ~
L..W•Lb
132. 44
1:06.73
141.12'
14 5. 61
1 :so. 21
1::-L 93
1:5 9. 75
AFTER TAX
ANNUAL COST
SAVING
COL 20 "+COL 21
2
COL 2 2
180.74
182.40
34. 11
35.86
37.66
39. 51
4 t'. 40
43.35
45. 34
47.39
49. 49
51. 65
56.25
58. 15
60. 10
62.09
64. 13
66.22
68.37
70.56
72.81
75. 11
77. 4 7
79.83
612.45
NOTe: In 1Hi? Si AGE. H'<0RO SYSTEM
(.':> WAS CHOSEN AU0~01iJCr
lo !HE. STiPULf\TIOf.JS ON
FiGURE. 'I-1
NOTE
I. USE 10% DISCOUNT RATE UNLESS
BETTER INFORMATION IS AVAILABLE
FOR CALCULATING PRESENT VALUE.
2. USE CURRENT DEPRECIATION ALLOWANC!
RULES IF DIFFERENT FROM
ASSUMPTIONS OF COLUMNS 16 a 20.
PV COST. SAVINGS =~COL. 2_~ =I 0 I
PV INCREME.NTAL CAPITAL COSTS PV COL. I 9 1. 2_
MICRO HYDRO STUDY
HYDROELECTRIC CAPACITY
DETERMINATION
BENEFIT COMPARISON
SHEET 2
FIGURE 1l-3
ff\ v
(")
;:o
"'0
"'0 m z
(")
0 z
(/)
c r-
-1
l> z
-1
(/)
CAPITAL CO'ST ~!STIMATI!:-DII!:Sa -"LTERNJ'.TE
5Tl!.P 1. 'SL'L£CT INS'Y.ALL£0 CAP,.CITY ST.AG£3 A.PP;;fOPRJA.1'~ TO
PROJt.CTED LOAD GROWTH
Crz• 1'otcl l"nlnirnurtt uutatl•d
CO~tfy !Ji,e.a,.. FZ
•U•~or,q d<=a-
• _j:;._1;;;>_ ---
C;u"' 70 tel tnd">!!Tiu,... In i ra/l~d
Co;:><:Kd!.f ytror 24
~or l. 4 d<t,...,and ___ l'0£37
:JT~PZ" :5EL!:CT cn:SeL Gt::N£RATOR UNIT CONFtCJ'URA.TIONS•
TYPIC.A.t. !-#OTO!it/6ENEF<IA.T0.q i,.,'Nii CONF•6URAT'K'>N.S
-~---·-----,--.. ~----
"'T
CAPACITY
50-.JOO /tiW
~·IO<-"'XJ•w
~~.} ;:;;:;cdy} '"C~-~2.
;ooo-UXX>.t: w
or~~u yencrar;oi"Y .,.,,,,-
1519 .... J.n•l'olf«d CC;;>OC.•'!J" oF Vnt!;,. 6, lnd~/ Jn~toll!::,r',on
ln~f.ollt:d CO~ II !I ol' '-'nd;j oY r«t::>-'?tr<l/""~nf !I>'"' or f1' __ ttC~J-*""
• ff' ~""•'"~~ p/•nf o' :s'nr. ~r.n oJ.;'-••~' r"<<t:,;;>·~C~-,.~~nr ,ntr./-.-ui:J to .5....,11' ~117-'""'.)
llrtt5AD'"" o/ .-~.,."1,...,9 IT'>Or<:;:::>r' g•nttrarvr ur>1f$
~
t
~
~
....
§
" ~
0:
~
IT
OJECT NAYE
rvE'liSTREAU
OCATION
ATE
..-------------------------------~-----~---·---
:!JT~P ~,' OOT~!N CO$T OF DlrSt::L PLANT FPC;.411 GRAPH "il::r-1 AND ESC,io,LAT£ CO$TS • .AOD tNTC.R;t.:JT [)U~:IV(;
CCJNSTRUCTION TV "'Rf?f'¥1: .i4.T CAPITAl.. COST CND OF YI!!:AR 0
TOTAL C.~JP:f..CITY .\W
MICRO HYDRO STUDY
DIESEL PLANT CAPITAL COST DATA
FIGURE llJ-l
fi u
(')
~
"'0
"'0 m z
(')
0 z
(/') c
r-
-1
l> z
-1
(/')
ALTERNATIVE DIESEL PLANT
PROJECT NAME
RIVER/STREAM
LOCATION
DATE
,-· _ _j ----
11 ElS CJi _L<;;'2'{2 ..
FUEL COSTS= kWh/YEAR • CONSUMPTION FACTOR x FUEL PRICE YEAR 0 x REAL PRICE ESCALATION FACTOR
~ ...,.
"' w
"' t:
.J
z
0
>-
0.. ::;,
:::>
"' ~
(.)
[NO OF' YEAR kWh/YEAR • 106 CONSJf.F'T ION FACTOR Fl£L PRICE ESCALATED
I (, -'102-o.-~o
I
t v
ll 1541
'
J
{ I y ZA 901&
'---···-·-----·-
100 200 300 400 ~00 €00 700
INS TAL LED CAPACITY kW
Ttl' IOI.U.:r 20 Clm'S/Lrrn!:
y
CENTS/LITRE
u;.oo
I ~
135b
I I ~
1'Q.fl
CAPACITY> 500 kW
0. 3 LITRES/ kWh
~ f'RlCE ~TlGI FN..~ 1..S TH:£ CJ.:l-'J:u.H:> AAtt 9'Y "*illf CJn'SEt.. nlEL OlSl'S
AM: ~ ro ~ 7'H£ A\/DV..::L AA!'e cr INnA'TlCii~
IT ~a.l f'JrrCI'OR • R ~ !U:l. PRIO::: n~ • mnA.."'""ftl'l 'PA...,~ +Jl.
TYPIDJ.. l..CtG ~ """'-'l...J:S f"<.:R RAn:. l&,\ PA~ ().5 Cl? .:r>tH l!:'BO).
ANNUAl. FUf:l COST
$ 11000
-~04.11
I
{
532 .9l
I v
161169
tm"!:~:
OPERATING 8 MAINTENANCE COSTS EXCLUDING FUEL(JAN. 1980 CAN_ $1
" ~I
0 .,
"'
z
<1: -,
1-
(J)
0
(.)
.J
<1:
::>
2 z
<1:
S<._H~'"'trt (lf' 0 ' H a.:STS
HYtro r;;;;.-;.;c;v-;;;:;---;c;"''~--;,,."--~ ... ..-."·~---,~
\4b3Jo< jll(:,3"" llbb lo< l-Ib(, "' 13 G
--15-l9~ 1%1 ):>< 141.0
PLANT
ffiS .;>ra
\ .. / ~' --"' <:: ~ .~
15~-0
l. a:xJ1"S lN:::!lJ'CE-I.AEO.JR, ":'RA.tGT~TI.c!'l, lL"RRIC'A..""'JN'.; OTIS, ¥.1~ l'nJ ~ OJE:?.!WJl.S. ~i.'D\0 NoD ~},"'.S'TRA.."'"1Ctl
l~ 1'U\ or:r:;;r:r.. Pl.A.vr U::.:::o ro P~oc SL"PI:"l...!~..AR:t n.:::::R..~ );>FO-AAI'£ TH£ ca;r o~_::cr ~ HY'DR:) " o~ ~
ro 'fHE P!UGC"~ (F ~JIJ... L~ SU'F"....!E!) BY EJ'Oi.
3.. IAl.'C:UR OJS":'S fOR~ PT..JI...."l!' ~ PAJC" ~ ('F~~ IS AV"'-rv.Il!.E 1-.5 N:EI:f$.:~ ..
.c. ~ A.."""P'E:'~I.X VI S..~Qi 1'.
MICRO HYDRO STUDY
DIESEL PLANT OPERATING COST DATA
HYDRO PLANT OPERATING COST DATA
FIGURE 1Z!-2
A u
n
::0
"'0
"'0 m z
n
0 z
(/')
c
r-
-f
l> z
-f
(f)
_ ' ... '1. l-f'-1 \Jo.-/ '--.._,.
COMPUTATION OF TOTAL ANNUAL COSTS AND UNIT ENERGY COSTS $xl000
PROJECT NAME
RIVER/ STREAM
LOCATION
SU .. i'flsP~ /o':sE .,-.,B-
-_cM<.rcc.,,l<,._ 0 (I''\' ("~"~r'',
_t-3'.5'7_ 117'17'_ ..
Etl:>
GF
YEAR
lOT .:.L
ENERGY
(HYDRO ONLY SYSTEM OR HYDRO SYSTEM WITH SUPPLEMENTARY DIESEL)
USE THIS TABLE WHEN HYDRO FIRM CAPACITY< PEAK DEMAND
LONG TERM
CAPITAL
EX ?EN~ITUA E
Sr<ORT T[RM ILC~~G TERM
CAPI~AL DEBT
(XPU<~•ITURE Rf_ r IREM [NT
ShORT TERM
CE BT
RETIRE~ENT
FUEL 0 8 M
COVBI~EO
HYDRO/O.[SQ
TOTAL
ANNUAL
COSTS
UNIT
ENERGY
COST
DATE ___ f\Vi\(r/ l9Zu ___ •
USE THIS TABLE WHEN HYDRO FIRM CAPACITY >PEAK DEMAN:)
---------
CAPITAL DEBT o a" TCTAL LJf-.I.T COST RET 1REMC:NT t.r. •, .. .'AL ( •, ~ R ;::.y
C031S CC'~ T
CENTS/kWh C~~TS/.Yit.
COL. I COL 2
·=1. .:::.::_: :::. c.1:1 .. ~
C•
':.
o. '='•
c.
..;, '· .
~ ·'· ':.
'=·· '=··
...... ',-,::::
:1.
~: .....
': ~
:: :S
! ~. :. ~
·:·. .. : ..
·=·
·:. -. ::-::•
2!. :·. r_ ..:...:..
~~ :·
·=·
..:.. , . .:, ·~· 1 6
COL. 3 I COL. 4
0. C:1:1
o.oo
"t ~ ~; • ~ i I ~ 1 ~·. ! '~I
-1 ;. ~;. 1•=1
~ 1 ~:. 1•:1
...l 1 ~. . i I= I
~ ~ ~· • ' .-!
_-,. ~ (I
~ l ~ . i =i
.__; l : , ~ 1:!
"t. -'-'
~ 1 1
.:1 1
4 1 . 1
11=1
~ 1 ~·. i ._:
4: .. : ,:,
...; : ~:. l•=l
4 ~ j ,-,
~ ·-·
~: ~:. l ::I
.., : ~ •=I
.., --'• t::l
COL 5
r: .. ,_:,_r
C1.
·=1. ·=I=·
i=i. 1_•,_
1=1. 1=·=1
u. ·=·1=1 o.
(1.
1=1·
1=1.
c~. ·=· ._: o. c~::
1=1.
C•. ·=I ·=I
1=1. 1=1·=1
C1. e:·:1
ci. c:.:l
1:1. C =f
c1. c~~=~
·=1. i::::l
I=·· (1,=1
o. i=ll=l
1=1. 1=10
·='· (1 .~1
COL. 6
~c. ·t. ~-
1·_ .... ....,
1 ~ ...; ' ':: : :..o .
• -.c ,-,-
: ~: ~ .
: -''. '-t-'
1":. ~:
~ ~·.
·=-....
-· -t-:. .. '-~, . ~
1' =·· i
1 ~ t ..
:..· 1~1 ~-.
._lO: .._:.-
.~: .. 1"'
::.r::-
2~'1=1.
.:: :: 1' ",:.
~-_:,, ~ '?
COL 1
'-'· ·:.·-
·: C1.
:::::1. ·~ ,-1
.:;. •:r • ~ •:•
·:..,-r
·::r=•. ·:.,-
·:.•:1,
:• _: • : ~I
~-1 .
OJ.
:-1.
•0 1 '
-~ ~
·~ 1.
::.:1
:.1. :::1_,
·~ ~ • ::, :=!
1.
1.
1.
COL 8
c, ~· • ...:.' ~
_:., ~
~. i= ·::.
'' ',.
-:. 1 0. := •.
-= I:""~·
r:: ;, ._,::-
~-'-I o -•
t .: ~-. '::· -
'-• 1=:=·
'=' -=·. -1 ?
':.· ~--1 .:.
t~ __ ., I __ ,
~ ~-. ::._·
;'r:· 1. ~~
l:. 42
~ .c 1.
_1.
I ... ...:_,
c ·, ,,
~
_,..:_, ':•
~' o I _I
1_,._:-_
~,._:
--. ~~ ::!
COL. 9
--~
--=.
~ 1 ::
?. 12
·~ ,-1 ......
•:•.
·=·
·=· ·:.1
=-:-1
:-.
:: .
.:_ .• ·-=·
·:·t::·
.--c
•:•, ,-I
·:-. ·:':•
HY:)fD SYSTI:M FACI'JRAL or,y,'\ Sc:·•·:tRf
LQ.':..:J [.;'J..,
rz-:::~-u ~--~ '!''"£~":.>.
c:c::=>.:;y := ~:-;:.J \TA'< 1
u:....~-.:J C ;.,:_~. r:__?..
l.SS~--: -:.:._~ G?.J..~::~ R-~-.TE
llJ3. kW
_l.;_'-_2 kWh >106
!.L0
.L'i_ % PER ACJ.'IUM
5'.~;:;.:: ::·.:-;-;"-o-i rJ:~_cc:L FC'EL (IF fSQ' D)
CJ: . .:::~:<:,"=-~J, ? .. :...::_"~....::-\
ls~ ;::;._'-. m::::·_-:-·:7'7ICI~
lst Y"":-.:.:_~ !"""l.-.:::., J_l?JC:::
ls~ Y:: .. -..?, r...,:-~ c:::s:-
ASs ... ::·=:J K.;.ti: FS;L PiUCZ E.SC.AI..rU'::!:CN
0 ?.0 LIT~S/ki'J1 T ~>]J LITilES
_2Q_ G:'(TS/LITRE
tf-.5,::_4 $ X 1000
__!3_ c;, Pc.R h.~•'L':ol
CIIPI'~l\L COST fV1'r.'l
iliTG 'J1...:K·l C:.l\Jll1~\:C COSTS -lil'Bffi PLrii:l'
nn:sLL sr·1 r ur:vc:r...
(IF EDJ'D)
SHORT TlR~~ CAPITAL COS?S-D:ESEL Lr.~I'lS (IF REXJ 1 D)
n-nLf€.57 R<"" .. Tr: a~ CAr./IT.-"U...
Dr:::H":' R.:;l'I~-::__;:r FA.:_....-lDR.S @ D-:'fi.R::.ST
W ~G T,_:_j\.:~ CJ-.2. CDS'I' X
S! iO:-G 'l'l_:.F\.'1 CI..P. CDST X
12%
0.129
0.161
-~% 0./Ll.,
_D.,j]]
I ---COL. 10 COL. II COL. 12 CCL 13 COL 14
I
DEBT RETIREMENT
FACTOR:
(CAPllAL RECOVeRy)
WHERE
ISoo s x 1ooo
~ 13.6 $ X 1000
- $ X 1000
-).:.. %
A ;(;.,;)n
p= (/,<i)n-1
A:: ANNUAL PAYMENT
P = PRESENT SVI,.f OF MCNEY
(CAPITAL COST)
n, NUMBER OF YEARS
i • INTEREST RATE
(AS A DECIMAL)
LJ
MICRO HYDRO STUDY
FINANCIAL EVALUATION
COMPUTATIO~ SHE:ET
HYDF\0 WITH I WITH OUT
SUPPLEMENTARY DIESEL
FIGURE llll-1
fi v
("')
::0
"'0
"'0 m z
("')
0 z
(j')
c r-
-1
l> z
-1
(j')
DIESEL SYSTIJ-1 FJ\C'illAL na.TJI. S1J!-Mr\RY
IDI-!:J DATA
;s ?ER FIG_ VII=l
DEC,c:L f'~l::L DATA ---------
a_]..._S:_Y~~IQJ FACTOR
lst. ¥t:~R CU~S.::·:?Tia.l
ls'::. YL-".......q Fl.:EL ?RICE
1st YL\R FLLL =r
ASS<.::-:F.IJ RA7E REAL PRICE ESCAlATICN
GPITAL o:sT DATA
0 "'.0 LITRES/kl-.'h
I 'J2! Lr:'P.F..S Y.!Ob
2. 'J _ CD. ":'5/LITRE
'3011 $x1000
__1_2_ % Prn ,'\:;;;t,'M
IJllG T!::P.'-1 G\PlT.;.L C:O:,'"TS SITE DEVEIL'P~'DIT
S!iCF~r T"JZ'I CAPl'rAL COSTS -DIEST'.L ~!COR WITS YEAR 0
4!A.O $ X 1000
4C4.4-$ x 1000
YEAR 12 5 G9 b_ $ x 1000
~.~=r RY!L CN CAPITAL
DEBT RE.'IIRL'l!Xf FAcrcRS @ INfEREST RATE OF 12%
LCNG TElM CAPITAL CDST X 0.129
SHORT TElM CAPITAL CDST X 0.161
UNIT ENERGY COST COMPARISON
13,----T ---,----T
.c
~
~ ;;,
~ z w II u
~%
14 %
_Q./_1.6_
_QJlL
~
V) PLOT VALUES FROM COL. 22 AND
0
u FIGURE llll-I ,.. ,_.,
0: w z w
~ z
::0
B 12 16 20 24
YEAR
PROJECT NAME
RIVER/STREAM
LOCATION
DATE
_? .!_LYANJL 1'1lNE. s_ __
_CPRPENTEI<, COO'( CREE:KS
_A·z:.s.'7'_JIJ·n· _ --~
__!llflR(,H_ .1 3 '130_ ----
COMPUTATION OF TOTAL ANNUAL COSTS AND UNIT ENERGY COSTS $ X 1000
(DIESEL ONLY SYSTEM}
E~O I LONG TERM I SHORT TERM I LO~G TERM I SHORT TER'-4
OF CAPITAL CAPITAL DEBT DEBT
YEAR EXPENDITURE EXPENDITURE RETIREMENT RETIREMENT
~ ~ .J. 1-: :~! 1 .! ·=; 4 • ..: ::1
~ 1. 45
-;-' lo 45
:---1. 45
;-'1. 45
;-'1. 45
; 1 • ..15
71. 45
..., 1. 45 -. -~ 5
:---~ . -! c-,
:--:. 45
so:-. ~.o :'1 . ..:s
=.-, '=! ~:
i=J.
~J. :=· .::
·::.i=J. 3
·~ :=1.
~(IT
::,1-1 -,
:-''_i,
:. 1~1 •
~I~' o
~ :_).
:..-,
FUEL
---19
': 4. 1
~: ·~ ':
41=17'. :3
4~1=10 (t . -,-, .... ~·..:. 0 .,
'.c ~ .......... _,,
4:: "· c;
4 ;-::. -
-!:;".
_ .. _..:._. '=·
c::. ~ -;'. ~
-'-~·
':-!.
C ,.. 5o
-' ~ ....:. .
~.I=:_,, 0
~· ~ ·:: 0 ..\
':•_.
~0 ~ ~ T ,
-:-·~· ..\
':·:-'':·
'' ..
~
--:.:. "
0 8 ..
COL 20
1~
15 :
15 1 ., 1 ! _,
1~ 1
15 1
1S : 1:. l ., 1 ·= 1
1 =o:. l
• c:_-c-1
1,-,-
1<.
'
=
lo:.
! ~ :::
1 c =.
1 c =.
TOTAL
AN~UAL
COSTS
.: ~ ::. ':4
~. ~·=1 • 1 5
_•...:. •.. l
~' . . . ......... _.
I ....:. o ~ ....:.
~: ~I: ~ ~~:
~~-. :.:.
·---=·· c::.
·=:1:. ;--;-
: .=::---. ~I=!
=,=]
: ':-< : • ~ ~
-.. :----.
=·
: :. -J
-'
1 : .. c 5
~ ":: I
1 ·=:. ~.-)
1 :=:. -
~ ~-,
l I= ~ I =I
t·=··
1 .::. 0'
1:. -1-.l
ll ...... :
~ =·
1:.
-~ ' ~ . ~ '
.:_-. . .. .. . ...
'-~. "::· : l. : :=)
j =: .~; ~ ~ : ·~-~:
':"::. ~'S 12. ·= ·=1
: ::·. : ·=, : .=.. +=' ~
<. ~:u· !~: :.~ c-; ,
·--'-L_____
MICRO HYDRO STUDY
FINANCIAL EVALUATION
COMPUTATION SHEET
ALTERNATIVE (DIESEL ONLY)
SYSTEM
FIGURE 'W-2
~
'\1
0
::0
"'0
"'0 m z
(')
0 z
(/) c
r-
-1
l> z
-!
(/)
PAYBACK COMPUTATIONS $ xiOOO
PROJECT NAME
RIVER/STREAM
LOCATION
[NO
()I'
YEAR
o.
I.
2.
3.
4.
"' -'· &.
7.
8.
9.
1 o.
11.
12.
13.
14.
15.
16.
17.
18.
19.
20.
21.
22. ...........
.::.~.
24.
CASE 1
BEFORE TAXES
TOTAL CAPITAj TOTAL CAPITAj INCREMENYAL I BEfORE TAX !INCREMENTAL
tOSTS COSTS CAPITAL COST I ANNUAt. COST COST MINUS
~YORO SYS1'E DfESEL SYSTE HYDRO-DllS(L SA\/l~CS ACCUMULAT(D
2823 .. 60
0. 00
COL2+COL.3
OR
COL 10
CCL Z 4 COL. 2 ~
8 f.8. 40 I 1
509. 60 I -509. GO
CCL I!>+COL16I CCL.Z3-COL24
COL 26
54.07 t:.o. 48
t,?. 12
3,.3.~S
1. 07
41
3 . oo
4 • f:5
4 . cq
4 C•7 ,. -·'
4 "o:.
4 • [14
4 • 45
4:.:4 .. 82
41S?.46
470. 37
4 7~:. :~e.
4~:;-, 06
4
" -·
"' c: '"• • ....).::.""!.
.534. ;"'
544.89
SAV lNG S
~87:.:.:. 53
-4'?'j. 55
11 [:. 48
2r:.9. '?3
f~.s. 93
or:.9. 713
4:::1. 75
9(12. 12 ::nt. 1 ;·
lt,'?:.?D
~~~ -.-~~.::. oLb
418 .08
464 .54
5 11 . <q
5~9 .47
607
6:;75.
7(1 o. 6
7~1 4. s
t: 1 9. I
8t.53. :;::::
9198.__??
COL 19+COL20 -C;;-;.~25
MtNUS +I COL 26
COL 12
& t COL
N:JI'E:
1. PA Yl3AC1C PERl CD = YEAR IN W!U 0! IN:RlrlENTAL CJ:l'>'T MINUS
J\CClM:JlA TED SI\VIN-iS
2. USE 2 Y.E7\.R W!UTI:DFF FOR HYDRO AT 50% Pl'J' YEAR.
lEE 6\ DfD-.INING BI\.LI\l'I:E FOR SUPI'LL"'J:)"n::ARY DIESEL
EJ;)UlPMINT.
CASE 2
AFTER TAXES
fORMER DEPRECIATION RULES
6°/o DECL
ON
COL 25
Stl!-r-11\HY:
INCREMENTAL
COL ~0
1 ?. 5
-l 4 ~ !
-l ~: ~ 7 4
1 ::;. o:::
~;;~: ~g
--3 o. '<:
-1 .. 02
(1. 7 2
4. 51
0 .. 6::::
·~-::~ 4
1 : .• .:::o
1 4 .. 5 ~::
2 e .. ':4r:·
2 .?. 64
2 1. 7f:
:: -+ .. 57
31 :.t. .21
3 .. :;:·?
::;: .~ .• DO
3 <· .. 15
4 0 .. 13
4 ·~:. So?
DATE MAf\Ctl l%0 __ _
CASE 3
AFT[R TAXES
ACCELERATED HYDRO DEPRECIATION RULES -----.---------.----
-COL 2 5 St::E NOTE 216 °/0 0tCL 8AL.
BASfO ON ON
COL 23 COl 24
COL31-COL-37 COL 34
1. PAYBIIC:K llEF'CRE 'l'AXES -CASE 1 __ 6__YEARS
MICRO HYDRO STUDY
FINANCIAL EVALUATION
COMPUTATION SHEET
PAYBACK COMPUTATIONS
2. P AYBliCK AF'I'ER 'J'AXF.S CASE 2 9 Y'.::ARS
3. PAYEI\CK JI.F'l'ER TAXES -CASE 3
FIGURE 1ITI-3
A \I
0
:::0
"'0
"'0 m z
0
0 z
(/')
c
r-
"""i
J> z
"""i
(/')
TRfAL
DISCOUNT
RATES
EI'O
OF
YEA<!
2 ..
..; ...
" ...
·5 ..
·::.
·::..
1 'J.
1 1.
12 ..
.:. ,: ...
'' . ~.
' .
1 ·:·.
i. ·~-
~.
CASE I CASE 2 CASE :3
PRESENT VALUES
"' '")
_J
<! >
>-z
w
t/)
w
<r
0.
SL'M'.AHY:
PROJECT NAME
RIVER/STREAM
LOCATION
DATE
CASE 1 !RR
t.1'liE'5_
_c.t\~ PfN1ER,_(lDU:.J\EEKS
_4~ 59' __ m~n' _
_M __ ,Af:C.JL t'?OO. __
ZA5%
CI\EiE 2 IRR = i4.0%
c-.sE 3 IRR = L2.Dt
N:JI'E: It:TI.J·~~\L Rt{;'E OF l"'.U~; IS DISCO:.,~rr RAT£
AT h1!ICH !?HES:.::·.''T \'ful:£ OF TI,X:R.L:'-~lf.l\L
C)\PITAL l\:f)T'S IS L.()C:\L TO F?l:.SI::Z::'r VALL'E
OF ;..,;~:t:.!\.L CC!)T S/\\.'I~:r.::s.
MICRO HYDRO STUDY
FINANCIAL EVALUATION
COMPUTATION SHEET
INTERNAL RATE OF RETURN
FIGURE lZ!I-4
~ ·u
(")
" '"'0
'"'0 m z
(")
0 z
(}') c
r-
-{
l> z
-{
(J)
CARPENTER AND (COY CREEK~
~ ' CAP. CO~T:: 3.'0 X IG", lilliT ENEI/6-Y CC5T-::.
(U?PER LlMi1')
(1\f>. C. OS 1 ·=.·!-!. 5 '( UI..!IT E;\!ERCrY C.OST L ").0¢'/kT<.'',.,
L~'~\E~ L-:;~r:)
8.
\.1
(")
::0
-o -o m z
(")
0 z
(,f) c
I
-1
l> z
-1
(,f)
-----"""' -~
-:-::.
CARFtN1E~ A~D CCDY LkEEKS
140":. 'KVJ IUS\ALLE:D CMA(rf'{ 13 91l J:10 6 Kwh /YR
\01AL. Utm Sr-!E:RG-'< (OS\ = 9-5¢-/kWh
LoST (OMPO!\Jf.'\lr ~ (;,. 0
~ ;~'
'--,-.-
Jri!l''
-!
0.7 ().3' (4_!.5 /6_
t.~ HY DF:O STUDY
2
17\ ·u
n
:::lj
"'C
"'C m z
n
0 z
(/) c r-
-i
l> z
-i
Cfl
AND (OD'{
140'3> KW INSTAL.LED
i01f\l.-UN\1 ENER(r'{ (OS\::
FiJEl.-ONt.. Y COST CDM?Cl\i:Xt::
I .e:. /V ....
COST DATA'
A lZJ
n
::tT
""0
""0 m z
n
0 z
{/)
c: r-
-1
l> z
-1
{/)
lO'iiSR.
..J
<!:
1-
a_
.::::
(.)
HYDRO INSTALLED CAPACITY (KW)
UPPER LiMiT C/li'iTI1L (OS1-.:: 'zu:-ofi\W x Jll;J3 kv!
•'~ Ill 10,'!
LOWER LIM\1 U\P:1AL (OS\::. .II 30/"'W ~ it.(-'3 /..\':
[o"] LL!J.~ J
NOT£
Do not use os a guide ror
economic reosib/lity .
LEGEND
8 ---L.obrad::;r Sludy
0 ---N~wf'ound/ond Study
[J---Bril/sh Columb/o Study
MICRO HYDRO STUDY
CAPITAL COSTS PER KW
VS
HYDRO INSTALLED CAPACITY
FIGURE :Z:::-4