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HYDROELECTRIC SYSTEM DESIGN
A Thesis
presented to
the Faculty of California Polytechnic State University,
San Luis Obispo
In Partial Fulfillment
of the Requirements for the Degree
Master of Science in Electrical Engineering
byTimothy McDonnell Brown
December 2010
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© 2010
Timothy McDonnell Brown
ALL RIGHTS RESERVED
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COMMITTEE MEMBERSHIP
TITLE: Hydroelectric System Design
AUTHOR: Timothy McDonnell Brown
DATE SUBMITTED: December 2010
COMMITTEE CHAIR: Dr. Ahmad Nafisi, Professor
COMMITTEE MEMBER: Dr. Taufik, Professor
COMMITTEE MEMBER: Dr. Ali Shaban, Professor
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ABSTRACT
Hydroelectric System Design
Timothy McDonnell Brown
Hydroelectric power generation is not a viable option as a prime
source of electrical energy for the Pico Blanco Boy Scout Camp, as
determined by this thesis. The hydroelectric power system can only
provide a maximum power capacity of 17kW as limited by the available
mechanical energy of the water source. This power capacity is
inadequate to reliably supply power to the electrical loads at the camp
during peak demand periods. The purpose of this thesis was to study the
feasibility of supplying the Boy Scout Camp with a renewable source of
electrical energy through an exploration of various hydroelectric system
design concepts.
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ACKNOWLEDGMENTS
I would like to thank Dr. Stanley Crane for providing me with the
opportunity to develop this study for the Pico Blanco Boy Scout Camp. Dr.
Crane not only created the concept for the thesis, but was also a key
factor in its development. He coordinated the site visit of the Camp, led
the effort to obtain site data, and identified many of the resources used to
develop this thesis. Without him, this thesis would not have been
possible.
I would also like to thank Dr. Nafisi, Dr. Taufik, and Dr. Shaban for
providing me with the technical background in power systems engineering
at California Polytechnic State University, San Luis Obispo.
I would finally like to thank Bill Thoma, for providing me with the
industry experience used to supplement the development of this thesis. It
was during my employment at Thoma Electric, Inc., with the help of Bill
Thoma and many others, that I was able to learn about and perform the
electrical design of commercial distribution systems.
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TABLE OF CONTENTS
Page
LIST OF TABLES ………………………………………………………………….. viii
LIST OF FIGURES ………………………………………………..……………….ix
CHAPTERS
I. Introduction ………………………………………………..………………………1
A. Development of Hydroelectric Power………………………………………2
B. Advantages and Disadvantages of Hydroelectric Power Generation…..3
C. Site History ……………………………………………………………………7
D. Site Topography ……………………………………………………………..12
II. Design Requirements…………………………………………………………….15
III. Site Visit and Survey……………………………………………………………...22
A. Existing Distribution System……………………………………………….22
B. Head Measurements………………………………………………………..28
C. Flow Rate Measurements………………………………………………….31
IV. Civil Design………………………………………………………………………..39
A. Exploitation Scheme Types………………………………………………....39
i. Dam Scheme……………………………………………………….......39
ii. Diversion Scheme………………………………………………….......40
iii. Pumped Storage…………………………………………………….….41
B. Exploitation Scheme Selection…………………………………………..…42
V. Mechanical Design……………………………………………………………......46
A. Hydraulic System Considerations…………………………………………..46i. Water Flow in Pipes……………………………………………………46
ii. Head Losses…………………………………………………..………..53
B. Turbine Types…………………………………………………………………57
i. Reaction Turbine…………………………………………………….…59
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a. Francis Turbine……………………………………………………..59
b. Kaplan and Propeller Turbine……………………………….…….60
ii. Impulse Turbine…………………………………………………………60
a. Pelton Turbine………………………………………………………60
b. Turgo Turbine……………………………………………….………64
c. Crossflow Turbine…………………………………………………..65
C. Turbine Selection……………………………………………………………..66
i. Selection Criteria…………………………………………………….….66
a. Cavitation Problems…………………………………………….….67
b. Net Head…………………………………………………………….68
c. Range of Discharges Through the Turbine……………………..69
VI. Electrical Design…………………………………………………………….…….73
A. Generator Types…………………………………………………………..….73
i. Synchronous Generator………………………………….……………74
ii. Asynchronous Generator…………………………………………...…76
iii. Generator Selection………………………………………………..…..77
B. System Design…………………………………………………………….….81
i. Conductor Sizing and Selection………………………………….…..81
ii. Overcurrent Protection Device Sizing and Selection…………..…..88
iii. Overall System Design………………………………………………..89
iv. Motor Starting Considerations…………………………………….….94
v. Turbine & Generator Control……………………………………….…97
VII. Development and Construction…………………………………………………101
VIII. Economic Analysis……………………………………………………………….105
IX. Conclusion…………………………………………………….……………….….109
BIBLIOGRAPHY ……………………………………………………………………..112
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LIST OF TABLES
Table Page
1. U.S. Energy-Related Carbon Dioxide Emissions by Fossil Fuel………..52. Hydroelectric System Design Requirements……………………………..21
3. Existing Diesel Generator Specifications…………………………………254. Existing Manual Transfer Switch Specifications………………………....265. Existing Main Panel Specifications………………………………………..266. Existing Panel ‘KA’ Specifications……………………………………...….26 7. Existing Refrigerator Compressor Specifications………………………...278. Existing Freezer Compressor Specifications……………………………..279. Gross Head Measurements………………………………………………...3010. Time to Fill Bucket…………………………………………………………...3111. Site 1 Depth and Width Measurements…………………………………...34 12. Site 1 Velocity Measurements…………………………………………...…34 13. Site 2 Depth and Width Measurements……………………………….......35
14. Site 2 Velocity Measurements……………………………………………...35 15. Site 3 Depth and Width Measurements……………………………….......35
16. Site 3 Velocity Measurements…………………………………………...…36 17. Site 4 Depth and Width Measurements…………………………………...36
18. Site 4 Velocity Measurements…………………………………………...…36
19. Site 5 Depth and Width Measurements………………………………...…37
20. Site 5 Velocity Measurements……………………………………………...37 21. Float Method Average Velocity and Volumetric Flow Rate for 5 Sites....3822. Dynamic and Kinematic Viscosity of Water………………………………..5223. Turbine Type and Typical Net Head Range…………………………..…..6824. Acceptable Variations of Flow and Head for Various Turbine Types......71
25. New Hydro Generator Specifications…………………………………...…8026. NEC Ampacity Table……………………………………………………...…8427. NEC Ch.9 Table 9 AC Resistance Table………………………………….8528. Approximate Project Costs………………………………………………....106
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LIST OF FIGURES
Figure Page
1. Aftermath of Lightning Fires at Pico Blanco, CA…………………………...82. Camp Ranger’s Home after the Fires…………………………………….…93. Existing Dam at the Top of the Creek Run………………………………...104. Topographic Overview of Surrounding Areas ………………………….....125. Enlarged Topograph of Boy Scout Camp………………………………….13 6. Waterfall at the Base of the River Run……………………………………..14 7. Boy Scout Camp Mess Hall………………………………………………….168. Freezer Compressor Nameplate………………………………………….....17 9. Refrigerator Compressor Nameplate……………………………………….18 10. Locations of the Compressors…………………………………………….…18 11. Compressor Disconnect Switches………………………………………….19 12. Existing Synchronous Generator Nameplate………………………………22 13. Generator Nameplate & Operator Interface………………………………..22 14. Existing Boy Scout Camp Electrical Distribution System…………………24 15. Manual Transfer Switch………………………………………………………2516. The Head of the River Flow……………………………………………….….2817. Surveyor’s Method…………………………………………………………….2918. Folsom River Dam………………………………………………………….….40 19. Diversion Scheme……………………………………………………………..4120. Racoon Mountain Pumped-Storage Plant……………………………...…..4221. Downhill View of River Run………………………………………………......4322. Pipe Emerging From Dam……………………………………………….……44 23. (a) Laminar Flow and (b) Turbulent Flow in a Closed Pipe ……………....4924. Laminar vs. Turbulent Flow #1…………………………………………….…50
25. Laminar vs. Turbulent Flow #2……………………………………………….5526. Reaction Turbine……………………………………………………………....5827. Impulse Turbine………………………………………………………………..5828. Francis Turbine……………………………………………………………...…59 29. Horizontal Axis Francis Turbine…………………………………………..….5930. Kaplan Runner…………………………………………………………………6031. Cross Section of a Nozzle with Deflector……………………………….…..61 32. View of a Two Nozzle Horizontal Pelton…………………………….……...6233. View of a Two Nozzle Vertical Pelton………………………………….……63 34. Pelton Runner…………………………………………………………………6335. Principle of a Turgo Turbine…………………………………………….……65
36. Principle of a Crossflow Turbine……………………………………….…….6637. Typical Flow Ranges for Various Turbines…………………………………7038. Canyon Hydro Pelton 751-2 Turbine………………………………………..72 39. Graph of Flux Versus Field Current for Synchronous Generator ………..75
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I. Introduction
Boy Scouts of America is a program that aims to develop the
character of our youth through team-building and educational activities.
This large national program not only teaches lifelong values but also helps
to create a future leadership in the United States of America through local
councils and dedicated outdoor camping reserves. In the campsite
setting, the Boy Scouts are able to learn how to live a sustainable life in
which a symbiotic relationship with nature exists. It is only natural then to
exhibit sustainability in as many facets of these campsites as possible.
Camp Pico Blanco, located in Los Padres National Forest along the
central coast of California, is just one of the many outdoor camping
reserves that host the Boy Scouts of America program. A map of the
Camp and the surrounding terrain is illustrated in the figure below.
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Figure 1 Topographic Overview of Surrounding Areas [8]
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Forest fires caused by lightning strikes in this area have damaged
much of the infrastructure and associated systems at the Camp.
Examples of this damage are shown in the photographs below.
Figure 2 Aftermath of Lightning Fires at Pico Blanco, CA
Figure 3 Camp Ranger’s Home after the Fires
One of the systems in need of replacement due to the fires is the
existing diesel generator which serves as the primary electrical power
source for the Boy Scout Camp. Diesel generators emit greenhouse
gases which pollute the atmosphere and thus do not provide a sustainable
solution for the Pico Blanco Boy Scout Camp. The Camp has the
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opportunity to exhibit greater levels of sustainability by replacing the
existing diesel generator with a cleaner source of electrical energy.
A. Development of Hydroelectric Power
The concept of harnessing the energy available in moving water to
perform work has been around for thousands of years. Ancient societies
captured the energy in moving water through various devices in order to
drive pumps, crankshafts, and other various loads. For example, over
2000 years ago, the Greeks were using water wheels to grind wheat into
flour. Many cities also used running water to drive water wheels and to
pump water throughout the city. Hydropower was even used in the 1700’s
in the milling lumber and grain industries to pump irrigation water.
The invention of the DC generator led to the development of
hydroelectric power stations. It wasn’t until the discovery of AC power in
the late 19th
century that hydroelectric power stations began to be widely
employed. Previously, hydroelectric power stations generating DC power
were limited by the short distances the DC power could be transmitted.
AC power can be transmitted much longer distances paving the way for
large, centralized generation plants such as hydroelectric power stations.
The first hydroelectric power station was installed on the Fox River in
Wisconsin in 1882 which delivered approximately 12.5 kW [1]. By 1907
and 1920, hydroelectric power accounted for 15% and 25%, respectively,
of the total electricity generated for the United States [2].
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B. Advantages and Disadvantages of Hydroelectric Power Generation
In 2008, renewable energy electricity production represented 9% of
the total electrical energy generation in the United States [3]. Of this 67%
came from hydropower, 15% from biomass, 14% from wind, 4% from
geothermal, and 0.2% from solar [4]. Hydropower is the largest and the
oldest renewable energy source of electricity generation for utilities in the
United States.
Hydroelectric power generation provides many advantages. If
needed, hydropower can produce electricity at a constant rate given a
steady stream flow and head. The energy can also be stored in reservoirs
through the control of gate valves. The ability that hydropower systems
can control the amount of water flowing through the water turbines makes
hydropower a valuable asset of the spinning reserve. This is especially
true for systems employing a pumped storage exploitation scheme. The
spinning reserve supports the local power grid during power quality
disturbances such as in the events that large step-loads are started across
the line or large generators are taken off-line. The spinning reserve uses
generation units that are already connected to the grid, such as
hydropower stations, to maintain system voltage and frequency during
these power quality disturbances. Hydropower plants also have lower
operating costs compared to other generation sources such as nuclear
power plants that depend upon high cost fuel contracts for their operation.
Another advantage of hydropower plants is that the upstream reservoirs
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created through dams can be used for recreational purposes such as
boating, skiing, fishing, and swimming. One of the most important
advantages of hydropower is that it is an emission free source of
electricity. The major contributor to carbon dioxide emissions are
petroleum, coal, and natural gas based prime movers. However,
hydroelectric power does not produce any carbon dioxide. This classifies
hydro power as a clean source of energy helping to reduce our carbon
footprint on the world. The table below outlines the quantity, in million
metric tons, of carbon dioxide produced by each of these fossil fuels
between the years 1995 and 2002.
Table 1 U.S. Energy-Related Carbon Dioxide Emissions
by Fossil Fuel [5]
For example, coal, with a carbon content of 78%, emits about 205
pounds of carbon dioxide per million Btu when completely burned [4].
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Large amounts of greenhouse gas emissions destroy the Earth’s natural
ozone layer leading to global warming.
Though hydroelectric power does not directly produce any carbon
dioxide, the overall system still has negative environmental impacts
outlined by the following excerpts.
Although electricity generated from water plants is relatively
emissions free, significant amounts of methane are produced from
the decomposition of plants in the flood areas. In addition to
methane, hydropower can have significant environmental effects
such as fish injury and impact on downstream water quality. By
diverting water out of the water bodies for power, dams remove
water needed for healthy in-stream ecosystems thereby disrupting
the natural river flows. Dams also slow down the flow of the river.
Many fish species, such as salmon, depend on steady flows to
flush them down river early in their life and guide them upstream
years later to spawn. Slow reservoir pools disorient migrating fish
and significantly increase the duration of their migration. [6]
To be completely environmentally conscious, it is also necessary to
focus on the negative impacts of hydroelectric systems such as the ones
listed above.
In addition, bacteria present in decaying vegetation can
also change mercury, present in rocks underlying a reservoir, into a
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form that is soluble in water. The mercury accumulates in the
bodies of fish and poses a health hazard to those who depend on
these fish for food. [7]
Another disadvantage of hydropower plants are the high capital
costs associated with system installation. High initial costs result in longer
payback periods and thus reduce the economic feasibility of hydroelectric
power systems. As mentioned earlier, the construction of large reservoirs
results in upstream flooding. Although providing the advantages of
increased recreational use, this also has the negative effect on the
environment as explained above and can cause people living in towns and
villages near the flooded areas to relocate.
II. System Design Requirements
The feasibility of the hydroelectric system proposed will be
determined by comparing the proposed design against the following
conceptual basic design requirements. The hydroelectric power station
source must be able to supply reliable power to the Boy Scout Camp
throughout the year despite varying water levels and other associated
environmental conditions. The rated maximum power capacity must be
greater than the Camp’s current peak energy demands in order to not only
meet existing demands but to also allow for possible future load
expansion. The design will also require that the installation and continual
operation of the power plant exhibit minimal to negligible environmental
impact. Finally, the total project cost to design and build the system must
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be economical and within the Camp’s allotted budget for the diesel
generator replacement. The table below highlights each of these
requirements.
Table 2 Hydroelectric System Design Requirements
Generation Classification RenewableEnvironmental Impact MinimalMinimum Real Power Capacity 23.9kW*Minimum Reactive Power Capacity 7.87kVAR*Maximum Project Cost $50,000**Reliability Must be capable of supplying full
power demand at the Boy Scout Camp
while minimizing power interruptions tothe camp*For calculation of the minimum required real and reactive power capacities refer to Section VI(B)(iii) “OverallSystem Design”
**The maximum project cost was an estimate derived from the insurance money allocated for the generatorreplacement including anticipated donations from patrons of the Pico Blanco Boy Scout Camp
III. Site Visit and Survey
A. Site Description
The Boy Scout Camp is located deep in a valley that is densely
populated with trees. The Little Sur River flows through the Camp with
many smaller creeks feeding into it. There are vast amounts of fish and
other wildlife species that inhabit the Little Sur River. The installation of a
hydroelectric power station on the Little Sur River would disrupt the natural
ecosystem and thus would violate this design requirement. The small
creeks that feed into the Little Sur River, on the other hand, do not harbor
fish or other wildlife. The biggest of these creeks results in a small,
approximately 15’ high waterfall that feeds into the Little Sur River. This
waterfall is displayed in the photograph below.
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Figure 4 Waterfall Feeding Little Sur River
This creek will be the proposed location to install a hydroelectric
power station. The creek first appears aboveground at an existing dam a
few hundred feet upstream of the waterfall. The dam is displayed in the
photograph below.
Figure 5 Existing Creek Dam
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Figure 6 Enlarged Topography of Boy Scout Camp
In the figure above, the proposed creek that will power the hydro
turbine-generator unit is labeled “A”. The location of the existing diesel
generator and main service panel is labeled “B”. The proposed location of
the hydroelectric power station is the point at which the small creek feeds
into the Little Sur River. The distance between this point and the location
of the existing main service panel is approximately 630 feet. This distance
is used in later sections to determine the minimum required conductor
size.
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B. Existing Distribution System and Electrical Loads
An evaluation of the Boy Scout Camp’s existing distribution system
and electrical loads provides insight into and a rough characterization of the
Camp’s electrical loads. The majority of the static loads at the Boy Scout
Camp consist of various plug loads for appliances, computer stations, and
incandescent and fluorescent lighting. The majority of the lighting loads were
resistive, incandescent light sources located in the Mess Hall shown in the
figure below. The remainder of the lighting load consisted of various
fluorescent and incandescent light bulbs located in various offices and
buildings.
Figure 7 Boy Scout Camp Mess Hall
The majority of the rotating loads consisted of two 208V, 3ø, 3 wire
compressors. The compressors are located on small skids in an outdoor
utility room and serve the refrigerator and freezer in the Main Mess Hall. Both
compressors are continually connected to the distribution system and are
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cycled on and off as determined by the system’s temperature controls.
According to the device nameplates, the rated locked rotor amps (LRA) for
the refrigerator and freezer compressors were 31A and 82A, respectively. A
compressor’s LRA is defined as the current drawn by the motor when the
rotor “locks” or completely stops. The rotor windings of a motor produce an
electrical magnetic force (EMF) that is 180° out of phase with the EMF
produced by the stator windings. The “back” EMF produced by the rotor
windings reduce the amount of current that is drawn by the motor. If the rotor
is stopped or “locked”, then there is no back EMF produced and thus the
motor will draw its maximum current.
Photographs of the compressors and their associated disconnects are
displayed in the figures below.
Figure 8 Freezer Compressor Nameplate
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Figure 9 Refrigerator Compressor Nameplate
Figure 10 Locations of the Compressors
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Figure 11 Compressor Disconnect Switches
The existing diesel generator supplying power to the Boy Scout
Camp is rated 75kVA, 208/120V, 3ø, 4 wire. The photographs below
display the generator nameplate and its associated operator interface.
Figure 12 Existing Synchronous Generator Nameplate
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Figure 13 Generator Nameplate & Operator Interface
Contrary to common energy saving practices, the facility managers
at the Boy Scout Camp require the light fixtures remain on at all times.
This rule is imposed on all of the Camp residents to prevent the damage
of the diesel generator. It is common for diesel generators that are lightly
loaded to experience “wet-stacking”. If diesel generators are not loaded to
a minimum level as specified by the manufacturer, then the engine prime
movers will not be able to reach their designed operating temperature
potentially resulting in unburned fuel. If operated under this condition for
extended periods of time, the unburned fuel will begin to deposit on
exhausts, turbo blades, and exhaust valves. These effects cause the
efficiency of the diesel generators to drop and can eventually cause
significant equipment damage if left unattended for long periods of time.
The existing diesel generator is oversized compared to the total electrical
load at the Camp with a maximum power demand utilizing about 25% of
its nominal capacity.
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The following single line diagram represents the Camp’s existing
distribution system as determined through the site survey.
Figure 14 Existing Boy Scout Camp Electrical Distribution System
A photograph of the existing manual transfer switch is shown in the
figure below.
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Figure 15 Manual Transfer Switch
The switch positions are labeled “Backup Gen”, “Off”, and “Main
Gen”. There is currently no backup generator but the intention to
eventually install one is apparent through the switch labels.
The specifications for the existing electrical equipment depicted in
the single line diagram above are listed in the following tables.
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Table 3 Existing Diesel Generator Specifications
Manufacturer Elliot Magnetek PowerSystems
Model Number 70 QLSerial Number BU05J265Apparent Power Rating at3ø
75kVA
Real Power Rating at 3ø 60kWReal Power Rating at 1ø 46kWPower Factor at 3ø 0.8Power Factor at 1ø 1Rated Speed 1800 RPM
Table 4 Existing Manual Transfer Switch Specifications
Manufacturer Square DModel Number E-1Serial Number 82354Voltage Configuration 240V, 3ø, 4WNumber of Poles 3PBus Rating 200ABus Bracing 10kAICNEMA Enclosure 3R
Table 5 Existing Main Panel Specifications
Manufacturer Square DModel Number NQOD442L225Serial Number -Voltage Configuration 240/120V, 3ø, 4WBus Rating 225ABus Bracing 10kAICMain Circuit Breaker
Rating
200A/3P
NEMA Enclosure 3R
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Table 6 Existing Panel ‘KA’ Specifications
Manufacturer Square DModel Number NQOD442M150CUSerial Number -Voltage Configuration 240/120V, 3ø, 4WBus Rating 150ABus Bracing 10kAICMain Circuit BreakerRating
150A/3P
NEMA Enclosure 3R
Table 7 Existing Refrigerator Compressor Specifications
Manufacturer CopelandModel Number REK3-0125-TFC-212Serial Number 98B14819Voltage 208V, 3øRated Horsepower 1.5 HPLocked Rotor Amps 31 APower Factor 0.85
Table 8 Existing Freezer Compressor Specifications
Manufacturer CopelandModel Number CS27K6E-TF5-970Serial Number 04J12761BVoltage 208V, 3øRated Horsepower 3 HPLocked Rotor Amps 82 APower Factor 0.85
The generator operator interface displays the real-time phase
current drawn by each of the phases. The operator interface displays the
current drawn by phase 3 to be 62A at 206.3V. The load currents for
phases 1 and 2 were noted as 48A and 56A at 207V and 210V,
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respectively. The phase currents are unequal and thus the system is
unbalanced resulting in a neutral current. The design will assume a
balanced system with a maximum phase current demand of 70A at the
nominal 208V. These assumptions are necessary to ensure the design of
a reliable system that meets the current peak demand requirements as
well as allows for the future load expansion at the Camp. The apparent
power demand at the Boy Scout Camp is calculated below:
ø √ 3 √ 370208 25.2 (3-1)
This apparent power demand will be used in later sections to
determine if the creek can deliver enough power to the Boy Scout Camp.
C. Head Measurements
Figure 16 The Head of a River Flow [9]
The gross head of a water resource is defined as the absolute
vertical distance between the points of entry of the intake system to the
point at which the water imparts onto the turbine. It is illustratively
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depicted in the figure above. The net head is defined as the gross head
minus all pipe losses due to friction and turbulence and is used to
calculate the available power capacity of the water resource. To
determine the net head, the river’s gross head must be measured and
pipe losses calculated. The pipe losses are calculated using the
dimensions and characteristics of the penstock.
Figure 17 Surveyor’s Method
The gross head was measured at the Boy Scout Camp using the
surveyor’s method. This method is illustratively depicted in the figure
above. At the Boy Scout Camp, the proposed location of the pipeline
intake and the water turbine is at the existing dam and at the top of the
waterfall, respectively. The data collected for the horizontal and vertical
distances measured are recorded in the table below.
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Table 9 Gross Head Measurements (measured in feet)
*THD: Total Horizontal Distance*VD: Vertical Distance
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The total vertical distance measured is the sum of the values in the
vertical distance (VD) columns and is 235.9 feet. With a horizontal
distance of 936 feet and a vertical distance of 235.9 feet, the length of the
associated penstock is calculated as:
√ 936 235.9 965.3 (3-2)
D. Flow Rate Measurements
The flow rate of the creek was first measured using the bucket fill
method. The bucket fill method measures the time it takes to fill a
container of known volume. A 5 gallon plastic bucket was used at the Boy
Scout Camp. The flow rate data measured using this method is recorded
in the table below.
Table 10 Time to Fill Bucket
Trial Bucket Volume(gallons) Time to Fill (s)
1 5 13.22 5 15.13 5 14.34 5 13.7Average 5 14.1
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From this data the average volumetric flow rate of the creek can be
calculated:
. 0.355 (3-3)
or
0.355 1
7.481
0.0474 0.0474
An alternative method to measure flow rate is the float method. In
this method, the time it takes a buoyant object to float along a section of
the creek of known length and depth is measured. The cross sectional
area in this particular section of the creek is calculated using the
measured width and average depth. Five locations along the creek were
used to take these measurements. The data collected from these
measurements is recorded in the tables below. For reference, the first
measurement was taken immediately downstream of the existing dam
(Site 1) and last measurement was taken immediately upstream of the
waterfall (Site 5).
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Table 11 Site 1 Depth and Width Measurements
Width [ft] 3
Depth Measurements [ft] 0.083
0.250.3750.330.160.16
Average Depth [ft] 0.226333
Average Cross SectionalArea [ft2] 0.679
Table 12 Site 1 Velocity Measurements
Time [s] Distance [ft] Velocity [ft/s]8.89 4 0.449944
12.56 4 0.3184719.51 4 0.42061
13.53 4 0.295639Average 0.371166
• Site 1 Average Volumetric Flow Rate: 0.252022 ft3/s
Table 13 Site 2 Depth and Width Measurements
Width [ft] 2
Depth Measurements [ft] 0.0830.1450.2080.2080.083
Average Depth [ft] 0.1454
Average Cross SectionalArea [ft2] 0.2908
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Table 14 Site 2 Velocity Measurements
Time [s] Distance [ft] Velocity [ft/s]3.47 3 0.8645533.78 3 0.793651
3.78 3 0.793651Average 0.817285
• Site 2 Average Volumetric Flow Rate: 0.237666 ft3/s
Table 15 Site 3 Depth and Width Measurements
Width [ft] 6.66
Depth Measurements [ft] 0.166
0.250.479
0.50.25
0.229
Average Depth [ft] 0.312333
Average Cross SectionalArea [ft2] 2.08014
Table 16 Site 3 Velocity Measurements
Time [s] Distance [ft] Velocity [ft/s]3.98 2.5 0.6281413.98 2.5 0.6281413.72 2.5 0.6720433.99 2.5 0.626566
Average 0.638723
• Site 3 Average Volumetric Flow Rate: 1.328633 ft3/s
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Table 17 Site 4 Depth and Width Measurements
Width [ft] 2.5
Depth Measurements [ft] 0.02
0.1660.1660.1250.250.250.250.25
0.333
Average Depth [ft] 0.201111
Average Cross SectionalArea [ft2] 0.502778
Table 18 Site 4 Velocity Measurements
Time [s] Distance [ft] Velocity [ft/s]15.92 9 0.56532712.4 9 0.725806
10.07 9 0.893744
11.22 9 0.8021397.61 1.182654
Average 0.833934
• Site 4 Average Volumetric Flow Rate: 0.419 ft3/s
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Table 19 Site 5 Depth and Width Measurements
Width [ft] 3
Depth Measurements [ft] 0.166
0.250.25
0.3330.3330.2080.125
Average Depth [ft] 0.237857
Average Cross SectionalArea [ft2] 0.713571
Table 20 Site 5 Velocity Measurements
Time [s] Distance [ft] Velocity [ft/s]12.93 8 0.61871613.58 8 0.58910211.42 8 0.70052512.9 8 0.620155
Average 0.632125
• Site 5 Average Volumetric Flow Rate: 0.451 ft3/s
The table below compiles all of the average fluid velocities and
volumetric flow rates for the five different sites.
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Table 21 Float Method Average Velocity and Volumetric Flow Rate
for 5 Sites
Location Fluid Velocity[ft2/s]
CrossSectionalArea [ft2]
Volumetric FlowRate [ft3/s]
Site 1 Average 0.371166 0.679 0.252022Site 2 Average 0.817285 0.2908 0.237666Site 3 Average 0.638723 2.08014 1.328633Site 4 Average 0.833934 0.502778 0.419Site 5 Average 0.632125 0.713571 0.451
Total Average 0.6586466 0.853 0.538
The gross head and flow rate data will be used later to calculate the
maximum power rating of the generator. To summarize, the site offers a
gross head of 235.9 feet and an average volumetric flow rate of Q = 0.538
ft3 /s or 0.01523 m3 /s.
The discrepancies between the data obtained by the bucket
method and the float method can be mainly attributed to the inaccuracies
in performing the bucket method at the Boy Scout Camp. Ideally, when
performing the bucket fill method, a temporary dam is built with a single
outlet pipe that directs the water into a bucket just below the pipe. This
ensures all of the water enters the bucket and minimizes splashes which
can lead to inaccurate results. It was not possible to build this dam
because of the rigid bedrock in the waterfall. Inevitably, portions of the
waterfall managed to miss the bucket leading to inaccurate
measurements. It was also difficult to determine when the bucket was
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IV. Civil Design
A. Exploitation Scheme
One of the first steps in the development of a hydroelectric system
design is to determine the desired water control scheme. The two most
important parameters that influence this decision are the head and flow
rate of the water source. The following are descriptions of common hydro
system water control schemes.
i. Dam Scheme
Dams are hydraulic structures used in many water control
schemes. A dam stores the potential energy of water by concentrating the
hydraulic head in a reservoir. This subsequently increases the water level
of the river upstream of the dam. Upstream flooding could potentially
pose a problem if significant flooding occurs. Flooding can lead to the
destruction of existing wildlife and their habitat.
Figure 18 Folsom River Dam [10]
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ii. Diversion Scheme
A diversion scheme, sometimes called “run-of-the-river” scheme,
employs the use of hydraulic structures to divert a portion of the stream
flow to a remote hydro powerhouse. In this water control scheme, the
potential and kinetic energy of the water are harnessed through the
natural flow and elevation drop of the river. In a typical diversion scheme,
the water resource is diverted through a penstock, a low pressure water
pipe, into the powerhouse which houses the turbine-generator set.
Following the powerhouse, the diverted water is then discharged through
a tailrace downstream of the original water resource. Common hydraulic
structures used in these schemes include but are not limited to weirs,
penstocks, dams, and spillways. Diversion schemes are optimal when
used at a site with a steady, constant flow of water throughout the year.
These schemes do not perform well during the dry months with low water
levels and so it is necessary to evaluate the range of water level
fluctuations throughout the year. It is possible to mitigate this problem
through the installation of a large reservoir. The reservoir can store water
to avoid the impacts of dry seasons and provide energy during peak
demand periods with high energy prices increasing the overall efficiency of
the plant.
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Figure 19 Diversion Scheme [11]
iii. Pumped Storage
A pumped storage facility uses water for potential energy storage
and requires the use of unique bi-directional hydro turbines. The rotating
machines coupled to these bi-directional turbines can be operated as
generators or motors. When reversed, the turbines are used to pump
water from the downstream reservoir at the power station to upstream
reservoir. This water is stored as potential energy and can be dispatched
and used to generate electricity during peak demand periods when energy
prices are the highest. This allows the plant to take advantage of price
arbitrage and increase the entire operating efficiency of the plant.
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Figure 20 Racoon Mountain Pumped-Storage Plant [13]
B. Exploitation Scheme Selection
The water source at the Pico Blanco Boy Scout Camp developed a
gross head of 235.9 feet over 936 feet of horizontal terrain. The average
volumetric flow rate was measured to be 0.538 ft3 /s. Compared to other
systems, this flow rate is low given the head capacity developed over 936
feet. The following photograph depicts a downhill view where the creek
flows toward the waterfall.
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V. Mechanical Design
A. Hydraulic System Considerations
Hydroelectric power systems capture the kinetic and potential
energy of water through the use of hydraulic structures, turbines, and
generators. Hydraulic engineering estimates and calculates the effects of
various hydraulic structures on fluid flow. This knowledge allows the
designer to not only estimate or calculate the total available system
energy, accounting for inherent system losses, but to also optimize the
performance of the hydroelectric system.
i. Water Flow in Closed Pipes
One of the major hydraulic structures used in a diversion scheme is
low pressure penstock used to divert the water resource to the hydro
power station. The penstock plays an important role in developing and
capturing the available potential and kinetic energy of the fluid. It
effectively translates the potential energy of the water at the intake into the
kinetic energy of the flowing fluid. The kinetic energy is then imparted
onto the turbine blades rotating the machine generating electrical energy.
An increase in the velocity or kinetic energy of a fluid occurs
simultaneously with a decrease in the fluid’s pressure or potential energy.
This fundamental principle was developed and published in various
hydrodynamic books in 1738 by Daniel Bernoulli, a Dutch-Swiss
mathematician [14]. Bernoulli’s principle assumes that the fluid is nearly
inviscid and incompressible experiencing a steady flow while exhibiting
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negligible heat transfer. A nearly inviscid fluid is one that is characterized
by low viscosity as is the case with hydropower. In mathematical form his
principle states [15]:
(5-1)
Where:
H 1: the total potential energy head [m]
h 1: the elevation of the point above a reference plane (in the
positive z-direction) [m]
P 1: the pressure at that point [kg/m-s2]
ρ: the density of the fluid at all points throughout the fluid [kg/m3]
g : the gravitational acceleration [m/s2]
ρg : the specific weight of water [kg/m2-s2]
V 1 : the fluid flow rate at a point on the streamline [m/s]
The total energy head H 1 of a fluid is the sum of the fluid’s elevation
h 1, pressure head or potential energy, and velocity head or kinetic
energy . As mentioned earlier, this relationship is only true for closed
pipe systems where the fluid is nearly inviscid and incompressible.
Solving explicitly for the pressure P 1 yields:
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· · (5-2)
According to the equation above, the pressure P 1 approaches zero
as the fluidic velocity V 1 increases. This implies that at some high velocity
the fluid exhibits a pressure P 1 that is negative although the majority of
fluids cannot attain a zero pressure let alone a negative absolute
pressure. This realization highlights the boundaries and limitations of
Bernoulli’s equation. Cavitation, a natural phenomenon, is one of the
reasons that Bernoulli’s equation exhibits these limitations.
The manner in which a fluid flows through a pipe depends on
characteristics of the fluid such as viscosity and velocity as well as
characteristics of the pipe such as internal diameter and the roughness of
the interior surface. Laminar and turbulent flow compose the two main
types of fluid flow. Laminar flow, commonly called streamline flow,
describes fluid flows that are smoother and more predictable. On the
other hand, turbulent flow describes fluid flows that are mainly
unpredictable and chaotic. Illustrations of both types of fluid flows are
depicted in the figure below.
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Figure 23 Laminar vs.Turbulent Flow [17]
Laminar flow is described as parallel flowing fluid “sheets”. The
velocity of each of these “sheets” is different from the adjacent “sheet”. It
is possible to plot the velocity of each of the “sheets” on the same graph to
obtain the velocity distribution profile of the fluid. Laminar fluid flows in
closed pipes exhibit a parabolic velocity distribution profile as illustrated in
the figure below.
Figure 24 (a) Laminar Flow and (b) Turbulent Flow in a Closed Pipe [14]
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Referring to the velocity distribution profile for laminar flow in the
figure above, the maximum velocity occurs at the centerline of the pipe.
The portion of the fluid that is in direct contact with the pipe’s interior
surface will exhibit zero velocity. The velocity distribution profile for
turbulent flow is also illustrated in the figure above. The velocity profile of
the fluid in turbulent flow is illustrated to be approximately constant across
the entire diameter of the pipe. In contrast to laminar flow, the portion of
the fluid that is in direct contact with the pipe’s interior surface exhibits
non-zero velocity.
Fluids characterized by either laminar or turbulent flow will exhibit
different system parameters and associated system performance. Thus it
is necessary for the designer to understand the type of flow the water in
the penstock will be characterized by. The type of fluid flow can be
generally predicted and estimated by calculating a parameter called the
Reynold’s number. Reynold’s number is a ratio that defines the
relationship between inertial forces to viscous forces of a fluid. This
number not only helps predict the type of fluid flow exhibited but will
determine at what point the fluid might change between laminar and
turbulent flow. Generalized for fluid flow in a closed circular pipe, the
equation for Reynold’s number is defined as [14]:
(5-3)
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Where:
ρ: the density of the fluid [kg/m3]
V : the average (mean) fluid velocity [m/s]
D : the inner diameter of the penstock [m]
µ : the dynamic viscosity of the fluid [kg/m-s]
: the kinematic viscosity of the fluid [m2 /s]
This equation can be derived by dividing the fluid’s inertial or drag
forces (
) by the viscous forces (). Inertial or drag forces tend to
produce turbulent, chaotic flow instabilities such as eddy currents and
vortices in fluids. Viscous forces produce predictable, smooth, and
constant fluid motion leading to the parabolic velocity distribution profile of
laminar flow. Evaluating the ratio defining the Reynold’s number shows
that fluids characterized by dominant inertial forces will have a high
Reynold’s number and most likely will exhibit a turbulent flow. Fluids
characterized by dominant viscous forces have a low Reynold’s number
and most likely will exhibit a laminar flow.
The industry accepted transition point between laminar and
turbulent flows in closed circular pipes is identified by a Reynold’s number
R e of approximately 2300. Typically, fluids characterized by a Reynold’s
number above 2300 and below 2300, can be described by turbulent and
laminar flows, respectively. The transition point between the two flow
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types are not precisely predictable and so a Reynold’s number of 2300 is
used as an approximate transition point. In reality, the transition occurs
over a range of Reynold’s numbers depending on fluid and system
parameters.
The average volumetric flow rate of the creek at the Boy Scout
Camp was measured to be Q = 0.538 ft3 /s (0.01523 m3 /s). Hydroelectric
systems with similar head and flow rates use penstocks with an internal
diameter of 6” (0.152 meters). The same internal penstock diameter will
be used in this design. Although it is proposed to couple a 6” penstock to
the existing 2” outlet pipe protruding from the dam, the calculations will be
performed using a 6” pipe as this will constitute over 99% of the entire
length of the penstock. The average fluid flow velocity is calculated as:
0.01523
0.1522 0.839 /
The kinematic and dynamic water viscosity coefficients used to
calculate the Reynold’s number are listed in the table below for varying
ambient temperatures.
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Table 22 Dynamic and Kinematic Viscosity of Water [19]
Temperature
- t -
( o
C)
DynamicViscosity
- µ - (kg/(m∙s)) x 10-3
KinematicViscosity
-
-
(m2 /s) x 10-6
0 1.787 1.787
5 1.519 1.519
10 1.307 1.307
20 1.002 1.004
30 0.798 0.801
40 0.653 0.658
50 0.547 0.553
60 0.467 0.475
70 0.404 0.413
80 0.355 0.365
90 0.315 0.326
100 0.282 0.294
The site’s annual temperature cycles were evaluated using data
from the National Oceanic and Atmospheric Administration (NOAA).
According to this data, the annual average temperature is around 20°C.
Referring to the table above, the kinematic viscosity of water at this
ambient temperature is 1.004 x 10-6 m2 /s. This coefficient is used to
calculate the Reynold’s number:
0.839 0.152
1.004 10 / 1.2710
The high Reynold’s number indicates that our fluid will exhibit a
turbulent flow. This is a typical result as “most engineering air and water
pipe flows are turbulent, not laminar” [14].
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· ·
(5-5)
Where:
f : friction factor [unit less]
L: length of the pipe [m]
D : internal pipe diameter [m]
V : average fluid velocity [m/s]
g: gravitational acceleration [m/s2]
The equation above applies for systems with incompressible fluids
exhibiting a steady flow rate through a closed circular pipe of any cross
section. It is valid for both turbulent and laminar flows.
For fluids exhibiting laminar flow, the friction factor f is calculated
using the following equation [14]:
(5-6)
The friction factor is independent of the penstock’s material
properties, as implied by the equation above. In laminar flows, according
to the above equation, the friction factor is inversely proportional to
viscous energy losses. Thus the system’s head losses can be calculated
by inserting the friction factor f into the Darcy-Weisbach equation defined
above [14]:
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, · ·
·
·
(5-7)
The system’s head losses are proportional to the fluid’s average
velocity V . This is in accordance with Newton’s fundamental kinematic
principles, which as applied here, state that an increase in the fluid’s
impending velocity on the penstock’s interior surface will result in an
increase in friction losses.
For fluids exhibiting turbulent flow, the friction factor f can be
approximated applying the following equation for system’s employing
penstock’s with a smooth interior surface [14]:
2.0log · 0.8 (5-8)
It is interesting to note from the equation above, that the friction
factor f is independent of the penstock’s material properties, specifically
the roughness of the interior surface. The friction factor f can also be
approximated explicitly using the alternative equation defined below [14]:
0.316 4000 10 (5-9)
1.8 log .
The Reynold’s number R e for this particular system at the Boy
Scout Camp was calculated to be 1.27x105. Thus observing the defined
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boundaries for the equations above, the latter equation can be applied to
approximate the friction factor f for this system where the fluid is in
turbulent flow. The friction factor f is calculated below.
1.8 log 1.27106.9 0.01696
The Darcy-Weisbach equation is then evaluated by inserting the
friction factor calculated above applying a pipe diameter D of 0.152
meters, a total penstock length L of 936 ft (285 meters), and an average
velocity V of 0.839 m/s: ,
2 0.01696 285
0.152 0.839/29.81 1.14
The head loss inherent in this system is 1.14 m (3.74 feet). The
head losses are used to calculate the system’s net head:
235.9 3.74 232.2
B. Hydraulic Turbines
A turbine is a mechanical device that converts the kinetic energy in
a moving fluid into the rotational energy of the turbine rotor. The two
major turbine types are the reaction and impulse turbines. A reaction
turbine creates power by directly reacting to the fluid's pressure over its
runner blades. Common reaction turbines include Francis and Kaplan
turbines.
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Figure 25 Reaction Turbine
On the other hand, an impulse turbine first converts the potential energy of
water pressure into kinetic energy through the use of nozzles. It then
imparts this kinetic energy onto the runner blades of the turbine. Common
impulse turbines include Pelton, Turgo, and Cross Flow turbines.
Figure 26 Impulse Turbine
i. Turbine Selection Criteria
Selecting a specific hydraulic turbine type for the system
design is not always “black and white” as it is possible to use various
turbine types in multiple applications. It is important to not only
evaluate the site conditions affecting available output power
throughout the year, but to also consider the customer’s preferences
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and the accompanying loud “bang” noise. If not addressed, over time,
the repetitive action can cause pitting of the runner blades or hub and
will eventually result in cracks and other mechanical failures.
Therefore, careful design measures must be taken to avoid
situations such as these and thus it is necessary to understand the
reasons these cavities form and how to solve these problems. The
system proposed at the Boy Scout Camp does not experience flow
rates and head pressures great enough to experience cavitation
problems but it is still important to be aware of these issues as they
arise in many other systems.
b. Net Head
The gross head of the site’s water resource is defined as the
vertical distance between the location of the upstream intake of the
penstock and the downstream outlet where the water imparts onto
turbine. The gross head alone does not provide an accurate
estimation of the amount of available power from the site’s water
resource as it assumes an ideal system model. In order to accurately
estimate the available power, the designer must take into account
inherent system losses. Thus the net head is defined as the gross
head minus head energy losses. Typical turbine types selected for
various net head ranges are outlined in the table below.
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Table 23 Turbine Type and Typical Net Head Range [14]
Turbine Type Head Range [meters]Kaplan and Propeller 2 < Hn < 40Francis 25 < Hn < 350
Pelton 50< Hn < 1300Crossflow 5 < Hn < 200Turgo 50< Hn < 250
The net head at the Boy Scout Camp was previously calculated to
be 232.2 feet (70.8 meters). According to the table above, Francis,
Pelton, Crossflow, and Turgo turbines are all possible candidates for the
proposed system design given the site’s net head.
c. Range of Discharge Through Turbine
The range of flow rates and discharges of the water resource
throughout the year provide another important parameter helping the
designer to select an appropriate turbine type for the system application.
The varying flow rates affect the site’s net head as system losses may be
altered.
An evaluation of and research into the flow rates of the Boy Scout
Camp throughout the year reveal that the most applicable concern is
having too little flow during the summer and fall season. There is no
concern regarding flow rates that may be too high throughout the year.
The safety factors inherently built into the hydraulic structures and other
system components are more than adequate to handle any high flow rates
the site can experience, if any. Thus it is most important to evaluate the
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Figure 27 Typical Flow Ranges for Various Turbines [15]
The minimum volumetric flow rate of 0.01523 m3 /s and net head of
70.8 meters at the Boy Scout Camp places the system below the lower
region of the Pelton turbine. The diagonal power capacity lines in the
figure above indicate that the lower boundary of the Pelton range is 50kW.
Thus the maximum power capacity at the Boy Scout Camp is below this.
The figure above is intended to be used as a reference guide. Although
the available power at the Camp does not fall directly into one of the
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The use of various turbines for the application at the Boy Scout
Camp was also discussed with hydroelectric turbine manufacturers and
system designers. The general consensus and recommendation was that
a Pelton turbine would be optimal for the Camp which aligns with the
turbine selected above. The proposed turbine is a Canyon Model #751-2
Pelton turbine with a 7.5 inch pitch diameter and double nozzle. A
photograph of the turbine is inserted below.
Figure 28 Canyon Hydro Pelton 751-2 Turbine
ii. Pelton Turbine
As mentioned previously, Pelton turbines are a type of impulse
turbine. In this type of turbine, a circular disk is mounted on the rotating
shaft or rotor. Nozzles are arranged around the periphery of a wheel with
buckets.
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Figure 29 Pelton Runner
The buckets are arranged to receive the water jets exiting the
nozzles and are positioned tangentially to the circumference of the turbine
to maximize the amount of energy translated in the process as illustrated
in the figure above. A needle valve will control the flow of water through
these jets as illustrated in the figure below.
Figure 31 Cross Section of a Nozzle with Deflector
The available water pressure, head, and other operating
requirements will determine the configuration of the nozzles placed around
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the turbine. The nozzle axes are typically placed in the plane of the
turbine runner. Additional control may be added to the nozzles for
emergency stop situations such as a load rejection. Some units are built
with deflectors that can divert the jet of water exiting the nozzles. This
helps to ensure that the turbine will not reach its runaway speed if the
highly pressurized water imparts too much kinetic energy onto the runner
blades. The deflectors provide a second level of control in addition to the
flow rate control provided by the needle valves to the nozzles. If needle
valves close abruptly during transient high flow rate events or transient
load changes, it is possible for the upstream pipeline to experience
instantaneous overpressure surges which can damage the equipment.
Deflectors allow the needle valves to remain open during these types of
events preventing overpressure surges.
Pelton turbines are an optimal solution for sites with high net heads.
A high net head increases the water velocity in the pipe resulting in a high
speed jet stream exiting the nozzles and subsequently striking the turbine
runner blades. The water exiting the nozzles gain a significant increase of
kinetic energy as the fluid moves from the high pressure region of the
penstock to an area of low atmospheric pressure. The kinetic energy of
the water is reduced as it rotates the runner blades. The buckets
surrounding the periphery of the wheel are designed to help maximize the
energy translated from the kinetic energy of the flowing fluid to the
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rotational energy of the turbine runner and minimize the energy lost in this
process.
Pelton turbines can be configured with an orientation in either the
horizontal or vertical axes. A vertical axis Pelton turbine will typically have
three or more nozzles directing the water onto the runner blades. The
maximum number of nozzles integrated into a Pelton turbine is typically
six. Pelton turbines with this many nozzles are usually installed in large
scale hydroelectric systems. The proposed Pelton turbine for the Boy
Scout Camp is configured with two nozzles and oriented in the horizontal
axis. Schematics of double nozzle Pelton turbines oriented in the
horizontal and vertical axes are depicted below.
Figure 31 Two Nozzle Horizontal Pelton Turbine
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If the nozzles are supplied with a constant flow of water, then the
turbine speed will only vary according to changes of the load torque place
on the turbine output shaft. A constant system frequency is required thus
the turbine-generator unit must rotate at a constant speed. The water flow
through the nozzles can be controlled and kept constant in steady state
conditions through the use of the needle valves. The positions of the
needle valves are adjusted by servomotors which react to various load
changes on the rotor shaft.
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VI. Electrical System Design
The Boy Scout Camp’s stand-alone, radial feed power distribution
system is currently supplied by a single 75kVA, 3ø diesel generator. The
Camp cannot be tied to the grid and must operate stand-alone due to long
distance between the site and the nearest electric utility power distribution
lines. An important step when evaluating the feasibility of using a
hydroelectric power plant as the Camp’s primary generator is comparing
the available power supplied by the water resource to the electrical load
demands of the site.
A. Generator Selection
The purpose of an electrical generator is to transform the
mechanical energy supplied by the prime mover into electrical energy. A
generator is simply an electric motor that is rotated via a mechanical input.
An AC generator induces an AC voltage on the stator coils as a result of
the rotating alternating magnetic fields of the rotor coils. The prime mover
can be derived from various mechanical sources such as steam power or
an internal combustion engine fueled by diesel, natural gas, or alternative
fuel types. In a hydroelectric power system the generator’s prime mover is
the hydraulic turbine. The two main types of AC generators are
synchronous and asynchronous generators. Asynchronous generators
are more commonly referred to as induction generators.
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i. Synchronous Generator
In general, a synchronous machine maintains a speed, the
synchronous speed, which matches the frequency of the stator current in
the armature windings under steady state conditions. In voltage source
mode, the electrical frequency will be dictated by the speed of the
generator input shaft driven by the prime mover. The shaft speed, and
thus system frequency, is regulated by a governor which monitors this
shaft speed and compares it to the desired frequency set point. The
electrical frequency is defined as [16]:
(6-1)
Where:
f e : Electrical frequency in Hertz [Hz]
n m : Mechanical speed of the magnetic field in revolutions per
minute [rpm]
P : Number of poles
The equation above simultaneously defines the rotor speed as the
two are approximately equal in a synchronous machine.
The amplitude of the internal generated voltage is proportional to
the frequency and the field current and can be expressed by [16]:
(6-2)
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Where:
K : Constant representing the construction of the machine
φ : Flux in the machine
ω: Speed of the machine
The magnetic flux of the machine increases linearly with increasing
field current until the iron saturates after which the flux characteristics are
non-linear. A graph comparing the flux to the field current for a
synchronous generator is illustrated below:
Figure 33 Graph of Flux Versus Field Current for Synchronous Generator [16]
The internal generated voltage E A is proportional to the flux and
thus will exhibit the same characteristics as illustrated in the graph above
assuming a constant synchronous speed ω. In order to optimally control
the system voltage, the machine must not be saturated. A significant
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consumption and terminal voltage control. External sources supply the
reactive power that magnetizes the machines core. In a grid-tied
application, the external source of reactive power can be the connected
utility which is modeled as an infinite bus. If operating stand-alone, then
the induction generator will require local capacitor banks to supply the
magnetizing current to generate a terminal voltage. The generator
terminal voltage varies with the amount of magnetizing current flowing in
the rotor. Thus the size of the externally connected capacitor banks,
which supply this magnetizing current, will determine the terminal voltage
generated. The reactive current supplied by a capacitor is directly
proportional to voltage applied to it as defined in the equation below [16]:
2 (6-3)
The following equation defines the impedance of a capacitor and
illustrates the linear relationship between voltage and current.
(6-4)
At a constant frequency, the slope of the impedance line increases
with decreasing capacitance. The intersections between the capacitor V-I
graph and the terminal voltage versus no-load armature current graph of
the induction machine, when operated as a motor, will determine the
amount of the magnetizing current from the capacitor needed to generate
a specific terminal voltage.
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Even with externally connected capacitor banks supplying steady
state reactive power to the induction machine, there needs to be some
intermittent source of reactive power in order to start the machine. Thus it
is common to connect and temporarily run a small synchronous generator
to produce the initial magnetizing current needed by the machine.
iii. Generator Selection
The major advantages of an induction generator are an increase in
reliability and a decrease in cost compared to that of a synchronous
machine. The major drawback of an induction generator is the lack of a
field winding which results in starting complications and a reduced ability
to control terminal voltage. The induction generator, operating stand-
alone, must rely upon an externally connected synchronous generator to
aid in initial start-up and externally connected capacitor banks to supply
steady state reactive power. The lack of voltage control is a greater
concern when there are additional reactive loads in the system, such as
the refrigerator and freezer compressors at the Boy Scout Camp. The
transient and steady state control complexities associated with induction
generators require an increased level of operations and maintenance and
also require a facility operator with intimate knowledge of the intricacies of
such a system. The Boy Scout Camp does not currently support this level
of operations and maintenance and thus an induction generator does not
prove to be a viable solution for the hydroelectric system design.
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The proposed generator for this design is a four pole synchronous
generator. A permanent magnet will supply the field windings with a DC
current creating a source of reactive power that will be used to maintain
the generator terminal voltage. The synchronous generator will be
connected to the Pelton turbine output shaft through a flexible coupling.
The synchronous generator’s apparent power rating is calculated
from the creek’s mechanical power capacity. Conceptually, this is
performed by first determining the total kinetic energy available from the
creek and then translating it into electric energy while accounting for the
turbine’s rated efficiency. Inherent system losses are then applied to
determine the system’s actual power capacity. The equation below
defines the mechanical power output of the turbine [21]:
ρ (6-5)
Where:
P m : the mechanical power output of the turbine [W]
ρ: the density of the fluid at all points [kg/m3]
Q: volumetric flow rate of the fluid [m3 /s]
g: gravitational acceleration [m/s2]
H : the net head [m]
ηT : turbine efficiency
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The net head and volumetric flow rate were previously determined
to be 232.2 feet (70.8 meters) and 0.538 ft3 /s (0.01523 m3 /s), respectively.
The turbine selected is rated for an efficiency of 80% and thus the
mechanical power applied to the turbine shaft is calculated as:
1000 9.81
70.8 0.01523 80%
8462.4 · 8.46
The torque applied to the generator rotor, neglecting rotational
losses in the flexible coupling, can be calculated from the mechanical
output determined above. The following equation defines the load torque
as a ratio of the applied mechanical power to the rotor speed [21]:
ω (6-6)
The governor isochronously controls the electrical frequency and
thus shaft speed to 60Hz. As stated previously, the electrical frequency
for a synchronous generator is defined as [16]:
(6-7)
Where n m is the speed of the rotor magnetic field and P is the
number of poles. This particular generator will be constructed with 4 poles
and will operate at a nominal 60Hz. The mechanical speed is calculated
as:
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120 120604 1800
This corresponds to a mechanical speed of:
1800 2 60 188.5 /
The mechanical input torque and thus the minimum torque rating of
the generator shaft is calculated as:
ω
8.46 188.5 / 44.9 ·
The proposed generator power rating is 14kW. Hydro generator
units with this rating are readily available and generally recommended for
systems of this size according to hydroelectric system designers and
installers. This rating is much greater than the available power that can be
supplied by the water resource during the dry season which is about
8.5kW as calculated above. This is intended to ensure that hydroelectric
power system can deliver the full amount of power available throughout
the year. The specifications of the proposed hydro generator selected are
outlined in the table below.
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Table 25 New Hydro Generator Specifications
Manufacturer Marathon ElectricModel Number 283PSL1707Apparent Power Rating at3ø
17.5Kva
Real Power Rating at 3ø 14kWVoltage Configuration 208V, 3ø, 4WPower Factor 0.8Rated Speed 1800 RPMField Winding Source Permanent Magnet
B. System Design
i. Conductor Sizing and Selection
The generator feeder cables must be rated to carry the generator
nominal output current continuously under normal operating conditions.
The generator output current is defined below:
ø, √ ø, (6-8)
As indicated in the specification above, the generator selected is a
MagnaPlus 283PSL1707 with an apparent power rating of 17.5kVA. The
output current supplied by the generator is calculated as:
ø, 17.5 √ 3 208 48.6
The rated minimum ampacity of the conductor selected must be
greater than or equal to the generator rated output current as calculated
above. The size of the conductor will also be selected to minimize voltage
drop during normal operating conditions. The amount of voltage drop
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along a circuit depends on the size of the conductor and thus its
resistance. The resistance of a metal conductor is defined below [22]:
1 (6-9)
In the equation above, R0 is the conductor resistance at T0, α is the
percentage change in resistivity per unit temperature, T is the operating
temperature of the conductor, and T0 is the reference temperature which is
typically room temperature. The equation above mathematically illustrates
the linearly proportional relationship between operating temperature and
resistance. An increase in the conductor operating temperature is
accompanied by an increase in its resistance. Thus as operating
temperatures increase the circuit voltage drop and total system losses will
also increase. This concept is the basis for the cable ampacity derating
factors provided by the National Electric Code.
The hydroelectric generator is anticipated to supply current
continuously throughout the day. There will be additional thermal
contributions to the operating temperature of the conductor due to the fact
that it will carry this current continuously. In conditions where the
conductor continuously carries current for three hours or more, the
National Electric Code requires the designer to select a conductor
ampacity that is greater than or equal to 125% of the nominal current. The
generator maximum continuous output current is calculated to be:
1.25 ø, 1.25 48.6 60.75
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Thus the minimum ampacity of the conductor selected must be
greater than or equal to 60.75A. The National Electric Code provides an
ampacity table that defines the ampacity of a cable with a given insulation,
conductor size, and environmental operating conditions. This table is
inserted below:
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Table 26 NEC Ampacity Table
According to the table above, a #6 AWG THWN has a minimum
ampacity of 65A in an ambient operating temperature of 30°C which is
greater than the calculated current of 60.75A. THWN type insulation is a
commonly used cable insulation system that is rated for exposure to
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moisture and contains flame retardant additives for additional fire
resistance. This cable insulation is not rated for direct burial and thus
must be protected by conduit underground.
The National Electric Code provides an AC resistance table for
various conductor sizes and their respective operating conditions and
application. This table is inserted below.
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Table 27 NEC Ch.9 Table 9 AC Resistance Table
According to the table above, the impedance of a #6 AWG 3ø,
600V copper conductor, with 75°C insulation (THWN) operating at 60Hz
with three single conductors in PVC conduit is:
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0.49 0.051 1000 || 0.492 1000
The total circuit voltage drop must be calculated to ensure minimal
system losses. The design goal is to maintain a total maximum line to line
voltage drop of 2%. A 2% voltage drop is selected as a design goal in
accordance with the recommendations of the National Electric Code for
feeder circuit voltage drops.
The line to neutral voltage drop for a single phase AC circuit is
calculated as follows:
|ø| 2 · · || · || (6-10)
Where L is the length of the circuit, Z is the impedance per unit
length of the conductor selected, and I is the continuous current flowing in
the conductor. The factor of 2 appears in the equation above accounts for
the current flowing in both the line and neutral conductor thus establishing
the total circuit voltage drop.
The output circuit configuration of the hydroelectric generator is 3ø,
4 wire. In this design, it is assumed that the Boy Scout Camp loads are
balanced resulting in negligible neutral current. For 3ø circuits, the
voltage drop between any two phase conductors is 0.866 times the
voltage drop calculated by the preceding formula.
ø, 0.866 · 2 · · || · || (6-11)
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ø, 0.866 · 2 · 630 · 0.000492 ·60.75 32.6
The equations above assume a balanced 3ø load and thus there is
no current flowing in the neutral conductor and the voltage drop between
phases A-B, B-C, and C-A will be identical. According to the calculations
above, the service voltage at the main distribution panel in the proposed
design is:
ø, 208 32.6 175.4
The connected loads at the Camp cannot operate with a supply
voltage of 175.4V. The voltage drop expressed as a percentage of the
nominal circuit voltage is calculated:
ø, % 32.6 208 100 15.7%
This is greater than the design requirement of a maximum 2%
voltage drop. The conductor impedance Z is explicitly defined in order to
determine the maximum conductor resistance that will satisfy the 2%
voltage drop design requirement. The maximum allowable voltage drop
along a nominal 208V circuit is calculated:
2%· 208 4.16
An upper limit for the conductor impedance is defined using the
design voltage drop calculated above:
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|| .··· (6-11)
|| 4.16
0.866 · 2 · 630 · 60.75· 1000 0.0628 1000
The maximum impedance is thus 0.0628 [ per 1000 feet]. Thus a
minimum #300kcmil THWN is required which has a corresponding
impedance of 0.059 [ per 1000 feet].
ii. Overcurrent Protection Device Sizing and Selection
Ungrounded system conductors require overcurrent protection in
order to prevent cable damage during overload and short-circuit events.
Overcurrent protective devices include fuses, circuit breakers, and shunt
circuit breakers. This requirement does not apply to grounded conductors
such as grounding electrode conductors, equipment ground conductors,
and neutral conductors in solidly grounded 4 wire systems.
In AC systems, circuit breaker ratings are selected to be the sum of
the non-continuous load current plus 125% of the continuous load current.
It is acceptable to select the rating as the non-continuous current plus the
continuous current if the overcurrent device and its assembly are listed for
100% duty operation. The circuit breaker protecting the generator feeder
cables will not be bear this listing and thus the rating will be selected as
125% of the generator nominal output current. This value, which was also
calculated previously, is determined to be:
1.25 ø, 1.25 48.6 60.75
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During the site survey it was noted that the Camp electrical loads
were mainly resistive except for the two compressors which operated at
0.85 lagging power factor. The “resistive” component of the connected
loads is assumed to be operating at an aggregate 0.99 lagging power
factor. The ratio of the compressor loads to the total camp load can be
estimated from the circuit breaker ratings indicated in the Camp’s existing
single line diagram. The circuit breakers protecting the compressors are
each rated 30A while the main circuit breaker supplying the entire
distribution system is rated for 200A. Thus the rotating loads comprise
30% (60/200 = 0.3) of the total system load. The overall Camp operating
power factor is then 0.95 lagging (30% x 0.85pf + 70% x 0.99pf = 0.95pf).
The phase angle difference between the operating voltage and current is:
cos 0.95 18.2°
This translates to a maximum real power demand of:
, cos 25.2 0.95 23.9
The maximum reactive power demand is calculated as:
, ·sin 25.2 ·sin18.2° 7.87
If the apparent power rating of the hydroelectric generator is
17.5kVA and the load power factor is 0.95 lagging, then the maximum real
power supplied is:
, · cos · 17.5 · 0.95 16.6
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supply the remainder of the electrical demand. This system operation
minimizes the supplemental generator operating time which reduces fuel
operating costs and greenhouse gas emissions.
The proposed supplemental generator is a diesel generator rated
for 30kVA, 208V, 3ø, 4 wire. Operating at a 0.95 lagging power factor the
real power capacity of the generator is calculated as:
, · cos · 30 · 0.95 28.5
The reactive power capacity is calculated as:
, · sin 30 · sin 18.2° 9.37
The diesel generator output is configured 3ø, 4 wire with a solidly
grounded neutral. The hydroelectric generator output is configured in an
identical fashion. Any line to neutral loads connected to the Boy Scout
Camp distribution system can be supplied by the derived neutral of either
generator. A 4 pole transfer switch is required to transfer between
generation sources. The fourth pole in the transfer switch is needed to
switch the system neutral from either generator. If the neutral pole was
not switched between the two systems and instead kept solidly tied, it
would then be possible for neutral current to flow along the ground circuit
and energize any metal enclosures connected to it. This poses a safety
hazard as these metal enclosures are exposed to the public. The single
line diagram below illustrates the proposed system:
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Figure 35 Existing Distribution System with New Hydro
and Diesel Generator Sources
iv. Motor Starting Considerations
As mentioned previously, there are two compressors connected to
the distribution system at the Boy Scout Camp. The prime movers for the
compressors are 3ø induction motors. The construction of an induction
motor is identical to that of an induction generator. In an induction motor,
the rotor speed is less than the synchronous speed consuming real power.
In comparison, the rotor speed of an induction generator is greater than
the synchronous speed providing real power.
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determined. This conservative approach was used to guarantee a reliable
and robust design. The reactive power supplied by the hydroelectric and
supplemental diesel generator is 5.47 kVAR and 9.37 kVAR, respectively.
This provides a total of 14.8 kVAR of reactive power that can be supplied
by all of the generation sources. This is adequate to supply the Boy Scout
Camp’s maximum reactive power demand of 7.87 kVAR.
v. Turbine & Generator Control for Stand Alone Operation
Grid-tied electrical distribution systems are supplied with a constant
frequency and voltage with a specified tolerance from the local utility grid.
The total amount of generation and load within the distribution system is
much smaller than that of utility source which makes the utility source
appear like an infinite bus to the distribution system. Transient step-loads
within the distribution system will have negligible effect on the system
voltage and frequency because of the inertia associated with the utility
grid. Thus there is no need for the distribution system to actively monitor
service voltage and frequency from the utility.
In a stand-alone system, the on-site generation sources will set the
system voltage and frequency. Stand-alone systems lack the inertia to
passively maintain system voltage and frequency. Large step-loads and
generators going on or off line will have an adverse affect on system
voltage and frequency thus requiring active frequency and voltage control.
The major control devices that maintain the system frequency and voltage
are the governor and automatic voltage regulator (AVR), respectively.
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The system frequency in a stand-alone application is dictated by the rate
of rotation of the generator rotor shaft. Changes in the amount of
generation and load within the system will contribute to system frequency
changes. The role of the governor is to adjust the fuel input to the prime
mover in order to maintain the nominal shaft speed. The Boy Scout Camp
nominal shaft speed was calculated to be 1800 rpm corresponding to a
system frequency of 60Hz. For example, if the fuel supply to the prime
mover increases when a constant load is connected, the rotor will
experience a transient acceleration. This translates into an increased
system frequency. Depending on the governor control algorithm, this
frequency will either remain, as in droop control methods, or be returned
to nominal 60Hz, if isochronous methods are used. The opposite is true
for a decrease in fuel supply with a constant load connected, the system
frequency will drop. For example, if a large electric load is suddenly
connected across the line, then the speed or frequency of the system will
drop to unspecified level if uncontrolled and fuel supply left constant. And
vice versa, if a load is taken off-line then the system frequency will
increase.
The automatic voltage regulator (AVR) performs a similar role in
actively maintaining the system voltage at the generator terminals. The
AVR will increase the DC field current in order to boost the terminal
voltage and vice versa. The amplitude of the generator’s terminal voltage
determines whether the generator is consuming or supplying reactive
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power and the amount of reactive power consumed or supplied. Thus a
synchronous machine is capable of controlling terminal voltage and
reactive power itself through the control of the DC field current.
The two main types of voltage and frequency control methods are
isochronous and droop control. A generator operating in isochronous
mode will maintain a constant nominal frequency and/or voltage
regardless of the real and reactive power demand of the system. The
range of the apparent power demand is finite but within these limits the
AVR and governor maintain a constant system voltage and frequency,
respectively. Generators operating in droop control mode allow the
voltage or frequency to droop or rise as defined by the specific control
algorithm implemented by the AVR and governor. The majority of
generators connected to the utility grid operate in droop control mode.
These generators share system load changes as determined by their
respective droop algorithms. Typical droop algorithms allow the system
voltage or frequency to deviate between 3% and 5% of the system
nominal set points. Droop control methods help to increase system
stability. If multiple parallel connected generators with long time delays
were controlled isochronously there could be large power swings within
the system when trying to maintain a nominal system voltage or
frequency. The long time delays associated with the voltage and
frequency correction of these machines cause the parallel connected
generators to “hunt” thus the system will never achieve stability. Droop
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control allows generators to share the power load between each other as
specified by the droop algorithm and rated power capacity of the
generator.
Stand-alone systems with multiple parallel connected generation
sources will typically operate one generator in isochronous mode and the
other generators in droop mode. The generator operating in isochronous
control mode would be the “leader” between the generator sources
maintaining a nominal 60 Hz cycle speed. The other generator would
operate in droop control mode where it would be able to share load
changes by allowing its frequency to droop. Mutual voltage control by the
generators would be accomplished by cross current regulation. This
method uses current transformers to measure the current flowing in the
generator feeder conductors, compare the two, and adjust the associated
DC field currents of either generator to maintain a constant system voltage
at both of the generator terminals.
The governor proposed for this system design is an electronic load
control governor manufactured by Thomson and Howe Energy Systems.
These governors are widely used in stand-alone small scale hydroelectric
power system applications.
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Figure 42 Thomson & Howe Electronic Load Control Governor
Stand-alone system applications require that the governor be
connected to a small excess of either generation or load at all times. The
governor uses this excess to maintain system frequency. Systems that
have greater generation capacity than load capacity require “waste” loads
to be directly connected to the generator through the governor. These
“waste” loads are resistive and turned on by the governor when generation
becomes excessive. It is optimal to select “waste” loads that can provide
a beneficial use to the site which will help contribute to the overall
efficiency of the system. The following are a list of recommended “waste”
loads [23]:
1. Swimming pool heaters
2. Concrete imbedded heating cables
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3. Hot water heating (with high temperature relief valve
or pump).
4. Soil heating cables or greenhouse heating
5. Snow melting cables in driveways
6. Furnace heating elements (with a backup heat
source)
Currently, the Boy Scout Camp does not have any loads from the
above list or that would qualify as a “waste” load. Thus it will be
necessary to install a “waste” load such as a baseboard heating element
in order for the governor to function properly and perform its intended role.
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VII. Development and Construction
A brief evaluation of what site development and construction is
necessary to construct the hydroelectric power system will provide an
insight into the rough capital costs associated with the proposed system.
The following list highlights the major scope of work items associated with
each subcontractor.
• Civil/Structural
o Preparation and grading of the hillside in order to
facilitate the penstock installation
o Demolition and drilling of waterfall bedrock in order to
facilitate hydro power station concrete pier installation
o Create and set forms and rebar cage for concrete piers
o Pour and cure concrete piers
o Create and set forms and rebar cage for hydropower
station foundation pad
o Pour and cure concrete foundation pad
• Mechanical
o Construct hydropower station enclosure
o Install penstock
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o Install a trash rake on penstock intake
o Install hydro turbine-generator skid
o Install hydro turbine-generator unit
o Install various plumbing fittings and accessories for
complete system installation
• Electrical
o Install control equipment including governor,
communication modules, and current transformers
o Install low voltage electrical equipment including circuit
breakers, junction boxes, and other enclosures
o Install complete steel conduit system and accessories
within the hydrostation powerhouse
o Pull and terminate wire complete control and low voltage
cable system within the hydrostation powerhouse
o Trench between hydropower station and Camp main
electrical service panel
o Install complete PVC Schedule 40 conduit system and
accessories below grade in the trench
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o Backfill trench with sand and native soil and install
warning tape 12” above top of conduit maintaining NEC
required distances (no compaction required)
o Pull and terminate control and low voltage feeder circuit
cables between the hydrostation power house and Camp
main service equipment
The figure below represents a high level system diagram depicting
the major system components.
G
Main Panel
New Manual
Transfer
Switch
New Diesel
Generator
G
New Hydro
Generator
New Pelton
Turbine
New Generator-Turbine
Coupling Shaft
New Penstock
Existing Water
Intake
New Conduit
and Feeders New AVR New Governor
New
Powerhouse
Figure 37 Overall System Diagram
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VIII. Economic Analysis
A design requirement of the proposed system is that project
economics are feasible and aligned with the Camp’s allotted budget. In
order to understand rough material costs of the major system equipment,
vendor quotes were solicited from select hydroelectric system component
manufacturers. The total capital cost to develop and construct this project
not only includes construction material and labor costs, but also includes
licensed professional engineering designs, associated construction
documents, and various construction administration items including
construction permit applications. The table below summarizes the major
project costs.
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The proposed supplemental diesel generator is rated 30kVA and
will also be continuously loaded below 25% of its rated capacity. Thus the
new operating costs are calculated:
1.3 24
365 $11,388
The new annual operating costs will also be dominated by costs
associated with the diesel fuel. The Camp’s fiscal budget must account
for an annual preventive maintenance plan and must also allocate a
budget to address additional maintenance costs associated with any
unforeseen system malfunctions or failures.
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IX. Conclusion
A hydroelectric power plant alone cannot adequately supply
enough power to meet the maximum electrical demand at the Boy Scout
Camp. In order to preserve the installation of a renewable energy source,
it is necessary to install a supplemental diesel generator. The
supplemental diesel generator would supply the remainder of the Camp
energy demand as well as supply the entire Boy Scout Camp electrical
load in the event the hydroelectric system fails or is taken off-line for
maintenance. An additional supplemental generator increases the
proposed system’s capital costs. It also increases system control
requirements and thus increases system complexity which results in a
decrease in system reliability. The proposed project is not economically
feasible with a total estimated project cost of $154,000. The Boy Scout
Camp generator replacement budget does not cover this large of a capital
cost and thus the proposed system cannot be built.
Renewable energy systems are more expensive than systems
powered by fossil fuels. The economics associated with renewable
energy systems become more attractive as various governments begin to
establish tax incentive and rebate programs that help to subsidize high
project costs. The assistance of subsidized programs allows renewable
energy technologies to further improve system efficiencies and decrease
system costs. Continual improvements in the manufacturing process and
construction costs help make renewable energy systems more affordable
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and economically feasible. It is the hope that one day, through these
continuing efforts to improve system designs and reduce project costs,
that there will be grid parity.
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