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UNITED STATES AGENCY FOR INTERNATIONAL DEVELOPMENT
TWEP
TRANSBOUNDARY WATER AND ENERGY PROGRAM
NARYN SYRDARYA PLANNING INSTRUMENT
NASPI
USER MANUAL
INTRODUCTION
THIS MANUAL IS A COMPLEMENT TO THE ONE WEEK NASPI
USERS COURSE.
THE MANUAL IS NOT ENTIRELY SELF EXPLANATORY BECAUSE
MANY CONCEPTS AND FEATURES OF THE NASPI MODEL CAN
ONLY BE EXPLAINED IN THROUGH EXAMPLES AND EXCERCISES
THAT WILL BE PERFORMED DURING THE COURSE.
HOWEVER, IT IS EXPECTED THAT PARTICIPANTS OF THE COURSE
WILL FIND THIS AS A USEFUL REFERENCE TO FOLLOW THE LOGIC
OF NASPI AND UNDERSTAND THE MANY DETAILED COMMENTS
AVAILABLE DURING EXECUTION OF THE MODEL.
OVERVIEW
OBJECTIVE, CONCEPT AND EXPECTATION
The objective of NASPI is to serve as a flexible and accurate representation
of the Syr Darya river system to help planners test and develop procedures for
the management of water storage based on a full understanding of their short
and long term consequences.
The NASPI concept revolves around the following key needs:
1. NASPI must be fully transparent to all users both in its logic and its data
2. NASPI must not determine how the system is to be managed. It must only
test different management procedures and let the users decide which to use.
3. NASPI must be flexible to accommodate future changes in both system
configuration and logic
4. NASPI must be easy to use without extensive knowledge of complex
programming languages
5. User organizations must be capable of modifying NASPI to meet changing
needs
It is the expectation of USAID that NASPI will serve as a common technical
language to help the countries sharing the Syr Darya river to negotiate the use
of its transboundary waters on rational and fair terms
WHAT NASPI IS NOT
NASPI IS NOT AN OPTIMIZATION MODEL
NASPI is a simulation model and not an optimization model. As such, NASPI does not make
any decisions about how the reservoirs are to be operated. NASPI merely follows rules provided by the
user in the form of a set of controls.
However, it is not entirely practical to develop a simulation model that does not make any
decision whatsoever because then the user would need to interact with the model during the simulation.
While following the rules sometimes NASPI must make a decision about how to meet a certain water
requirement when there is more than one source from which to chose, such as a branch of the river
leading to two upstream reservoirs.
The criterion used for this purpose is simple as will be explained in this document but the
user must be aware that this is not the only criterion and it can be modified eventually if a different
criterion proves more suitable.
NASPI IS NOT A HYDRAULIC SIMULATION MODEL
NASPI simulates the operation of the river system based on a daily balance of flows.
NASPI is not a hydraulic simulation model because it does not take into account the detailed
physical characteristics of the river, namely the slope, profile and rugosity of the river bed to determine
the velocity and elevation of the water at every point.
As such, NASPI cannot be used to determine flooded areas except when these areas are
treated as reservoirs. Similarly NASPI cannot be used to manage the short term operation of a cascade if
that operation requires decisions based on travel time of water.
NASPI STRUCTURE 1
NASPI (excel)
NASPI (fortran)
System Controls
input
Data Input
(Physical Environment)
Daily
Simulation
of the
Syr Darya
River
Output
Output
Output
Results
Results
Results
output
System
for up to
100 years
HYDROPOWER
CONCEPTS
KEY HYDROELECTRIC POWER CONCEPTS 1
KEY HYDROELECTRIC POWER CONCEPTS 1
HYDROELECTRIC POWER FORMULA:
P = 9.81 * E * H * Q
Where:
P = power output in kilowatts (kW)
9.81 = acceleration of gravity in meters per second square (m/s2)
E = power plant overall efficiency (includes hydraulic, mechanical and electrical efficiencies)
H = head = difference in elevation upstream and downstream of turbine, in meters (m)
Q = flow through the turbine in cubic meters per second (m3/s)
When reservoirs are used for multiple objectives that include power generation the monthly
pattern of water use affects not only the flow Q that goes through the turbine but also the
head H that depends on the elevation of the reservoir. It also affects the efficiency E because
some aspects of E are related to both H and Q.
Since the electricity demand and the inflow of water into the reservoir also change according
to a monthly pattern then the problem of optimizing the use of a reservoir for hydropower is
complex. When other important uses of water are also present the problem becomes even
more complex.
KEY HYDROELECTRIC POWER CONCEPTS 2
KEY HYDROELECTRIC POWER CONCEPTS 2
Hydroelectric generation is different every year due to variation in hydrologic
conditions. Therefore, to measure the production of a hydroelectric plant it is
necessary to use a record of several years of actual production. It is also
possible to simulate the production of the plant using a simulation model
and several years of hydrologic data.
The average annual energy production based on all the years of available
hydrologic data is called “mean annual energy”. The lowest annual energy
poduction of all years is called “firm energy”. Therefore, firm energy, is
the energy production that a hydroelectric plant can guarantee under the
worst hydrologic conditions that may be anticipated. The difference between
mean annual energy and firm energy is called “secondary energy”.
The peaking capacity can also be calculated for every instant of the
operation over the available hydrologic data. The lowest value of peaking
capacity is called the “firm peaking capability” of the plant.
The mean annual energy, the firm annual energy and the firm peaking
capability are the most important parameters to determine the value of a
hydroelectric plant.
KEY HYDROELECTRIC POWER CONCEPTS 3
DEPENDS ON BOTH THE FIRM
ENERGY AND THE PEAKING
CAPABILITY OF THE
HYDROELECTRIC SYSTEM
ELECTRICITY
DEMAND MW
FIRM HYDROELECTRIC ENERGY
CAPACITY
GUARANTEED BY
HYDROELECTRIC
POWER
SECONDARY HYDROELECTRIC ENERGY
THERMAL
CAPACITY
REQUIRED
THERMAL PLANT ELECTRIC ENERGY
ONE YEAR = 8760 HOURS
MW
ELECTRICITY
DEMAND MW
Year 1
Year 2
Year 3
PLANNING THE EXPANSION
OF GENERATING CAPACITY
TOTAL
CAPACITY
REQUIRED
KEY HYDROELECTRIC POWER CONCEPTS 3
A reliable generation system must have enough generation capacity to meet its maximum expected
demand even under the most critical hydrologic conditions. In fact, it should also have some additional
capacity called “reserve capacity” but we shall ignore this detail to make the analysis more clear.
The firm energy and the firm peaking capability of a hydroelectric plant or group of hydroelectric plants
determine the maximum demand that it can cover during critical hydrologic conditions. This maximum
demand that can be covered by the hydroelectric system under critical conditions is called “dependable
hydroelectric capacity”.
The planning of a generation system consists of:
1) Determining the maximum demand for several years into the future
2) Calculating the dependable hydroelectric capacity that will be available
3) Determining the amount of thermal generation capacity required
Notice that the secondary hydroelectric energy does not have any value in terms of replacing thermal
generation capacity. Its only value is in reducing the use of thermal generation capacity and saving fuel
during years where the hydrologic conditions are not critical.
RESERVOIR OPERATION RULE CURVES
DIFFERENT RULE CURVES FOR DIFFERENT OBJECTIVES
RESERVOIR OPERATION RULE CURVES
If a hydroelectric reservoir is operated simply by following the demand it will experience two serious
problems: In years of abundant water the turbines may not be able to pass all the water entering the
reservoir and it can overflow. In years of low hydrology the reservoir may be emptied. This last one is
a very bad situation because the head becomes so low that very little energy can be produced with
the available water.
These problems will lead to a low value of firm energy and peaking capacity and may also affect
adversely the mean annual energy of the plant. These problems are avoided by operating the
reservoir within maximum and minimum levels called “rule curves”. These rule curves are simply a
set of reservoir elevations, usually defined at monthly intervals.
Depending on the relative value of the mean annual energy, the firm energy and the peaking
capability a rule curve will be designed to obtain the maximum power benefit from the reservoir. Rule
curves can also be used to obtain other benefits from the reservoir such as irrigation, flood control
and navigation by sacrificing some of the power benefits.
In this simple example there are only two rule curves. The upper rule curve is used to prevent the
reservoir from rising too fast and spilling water. The lower rule curve is used to keep it from dropping
too fast and running dry.
In practice it is customary to define several lower rule curves, each associated with a specific
instruction to reduce water releases. This provides a gradual reduction in meeting water and power
demands to prevent a sudden disruption of irrigation and electricity supply.
NASPI uses four rule curves and they will be explained later in this presentation.
NASPI STRUCTURE
AND
RIVER SYSTEM
REPRESENTATION
NASPI.XLS STRUCTURE
Data Export pages
DOS Files
SYSTEM CONTROL
INPUT
Graphic Result Pages
Table Result Pages
Data Import Pages
WATER BALANCE PLOTS WATER BALANCE TABLES
RESERVOIR PLOTS
RESERVOIR TABLES
POWERPLANT PLOTS
POWERPLANT TABLES
POWER COST
INPUT.CSV
NASPI.EXE
OU1
NASPI.OU1
OU2
NASPI.OU2
OU3
NASPI.OU3
OU4
NASPI.OU4
OU5
NASPI.OU5
OU6
NASPI.OU6
OU7
NASPI.OU7
NASPI STRUCTURE
NASPI consists of two files: NASPI.EXE and NASPI.XLS.
NASPI.EXE is the executable form of a program written in Fortran language and stored as a file
NASPI.FOR. This program contains the entire logic of NASPI and its structure and design is the
subject of a specific course for NASPI Programmers or support personnel. In this course for NASPI
Users the logic of NASPI.EXE will be described but not the way in which that logic is put in the form
of NASPI.FOR or how to turn NASPI.FOR into NASPI.EXE.
Fortran programs are powerful and efficient in terns of calculation speed and their ability to
represent complex systems by mathematical algorithms. However they operate with very rigid and
simple input and output data files. This makes them difficult to operate and limits the possibility of
graphical outputs in comparison with more user-friendly software such as Excel.
NASPI resolves these limitations by handling all input and output via a single large Excel workbook
with multiple pages. This workbook is the file NASPI.XLS
NASPI.XLS has one page dedicated to the controls that the user may use to guide the operation of
the reservoirs.
Another page is dedicated to all the data on the river system including hydrologic records. This
page is used to provide input data to NASPI.EXE.
Several pages are dedicated to accept different types of output from NASPI.EXE.
Finally, several pages are used to convert the output received from NASPI.EXE into tables and
graphs summarizing the results,
RIVER SYSTEM COMPONENTS
RIVER REACH
CONSTANT HEAD POWERPLANT
INFLOW
DEMAND
SIDE
INFLOWS
RIVER
CONSTANT
HEAD
LOSSES
RIVER
POWERHOUSE
OUTFLOW
RESERVOIR AND VARIABLE HEAD POWERPLANT
SPILLWAY FLOW
MAXIMUM LEVEL (Point 20)
RULE CURVE 1
TURBINE DESIGN LEVEL
RULE CURVE 2
RULE CURVE 3
TURBINE DESIGN HEAD
RESERVOIR
TURBINE INTAKE LEVEL
MINIMUM TURBINE HEAD
TURBINE FLOW
RULE CURVE 4
RIVER
POWERHOUSE
BOTTOM OUTLET INTAKE LEVEL (Point 2)
MINIMUM LEVEL (Point 1)
BOTTOM
OUTLET
FLOW
RIVER SYSTEM COMPONENTS
NASPI is built using three types of river system components as follows:
A River Reach (abbreviated Reach) is a segment of the river. The segment is defined by three
parameters: water demand and water losses defined as monthly constants in cubic meters per
second and independent of hydrologic year. Side inflows defined as a record of monthly flows in cubic
meters per second. NASPI is designed for 20 REACH
A Constant Head Electric Plant (abbreviated CHEP) is a plant that is assumed to have always
the same water elevation upstream and downstream of the plant. The power production is
calculated as: P = 9.81*E*H*Q where P is power in kilowatts and is limited by the capacity C of
the plant; 9.81 is the acceleration of gravity in meters per second square; E is a constant
efficiency; H is the constant head in meters and Q is the flow in cubic meters per second. When Q
> {C/(9.81*E*H*C) then the power P = C and the excess flow is assumed to be spilled. NASPI is
designed for 20 CHEP.
A Reservoir and Variable Head Electric Plant (abbreviated VHEP) is a complex component.
The reservoir is represented by 20 points, each point corresponds to one elevation and its
associated reservoir volume and surface area. The reservoir also has specific physical
characteristics including the elevation of the turbine intake and the elevation of the intake of a
bottom outlet. There are also control elevations known as rule curves which are defined monthly to
control the operation of the reservoirs. The powerplant is represented by the capacity C, the
design head, the minimum head and the efficiency at design head and at minimum head. The
bottom outlet is represented by a maximum flow at the maximum reservoir elevation and is
assumed to follow the formula Q=K*H^0.5 where Q is flow in cubic meters per second, H is the
head on the bottom outlet and K is a constant. NASPI is designed for 10 VHEP.
RIVER SYSTEM CONFIGURATION
RESERVOIR
POWERPLANT
REACH
NARYN CASCADE
VHEP 1 = TOKTOGUL
CONFLUENCE
SPECIAL
CONDITION
VHEP 2 = ANDIJAN
REACH 1 = TOKTOGUL - KURUPSAY
CHEP 1 = KURUPSAY
REACH 2 = KURUPSAY-TASHKUMIR
REACH 14 = OTVODIASCHY CANAL
CHEP 2 = TASHKUMIR
REACH 3 =TASHKUMIR-SHAMALDISAY
REACH 6 = ANDIJAN - NARYN/KARADARYA
CHEP 3 = SHAMALDISAY
REACH 4 = SHAMALDISAY - UCHKURGAN
CHEP 4 = UCHKURGAN
REACH 5 = UCHURGAN - NARYN/KARADARYA
REACH 7 = NARYN/KARADARYA-AKJAR
REACH 13 = AKJAR-KAYRAKKUM
VHEP 3 = KAYRAKKUM
VHEP 4 = CHARVAK
REACH 8 = KAYRAKKUM-FARKHAD
REACH 10 = CHARVAK-CHINAZ
REACH 9 = FARKHAD - CHINAZ
REACH 11 = CHINAZ-CHARDARA
VHEP 5 = CHARDARA
REACH 12 = CHARDARA-ARAL
VHEP 6 = ARNASAY
REACH 15 = KYZYLKUM CANAL
RIVER SYSTEM CONFIGURATION
The Naryn-Syr Darya river system is represented by 15 river reaches (REACH), 4 constant head electric
plants (CHEP) and 6 reservoirs with variable head electric plants (VHEP). Reservoirs are represented
by the green triangles, powerplants by the red circles and river reaches by the yellow rectangles.
The order of the numbers is not important. A new REACH, VHEP or CHEP can be added with new
consecutive numbers, the program logic defines the relation between each component regardless of
their number.
The dark blue squares represent confluences that merit special treatment in the logic. The light blue
squares represent other conditions that merit special treatment in the logic.
.Many other constant head plants exist in the system in addition to those in the Naryn cascade but have
not been included because for the purpose of NASPI only the plants in the Naryn cascade represent an
operational objective. It is very easy to add other CHEP if necessary.
The Arnasay reservoir does not contain a powerplant but it is treated as a VHEP with plant capacity
zero. The flow from Chardara to Arnasay is governed by a special logic that depends on the elevation of
Chardara and on the annual volume transferred from Chardara to Aranasay.
The flow into Kyzylkum canal is treated in a special way because it will affect the elevation of Chardara
and therefore the condition of transfer from Chardara to Arnasay.
NASPI LOGIC
OPTIONS FOR TOKTOGUL RESERVOIR MANAGEMENT
TARGET RELEASE OPTION (MODE 2)
This option is for Toktogul only
DEFINE LONG TERM MONTHLY TARGET RELEASE
FROM EACH RESERVOIR
ANNUALLY ADJUST THE LONG TERM MONTHLY
TARGETS BASED ON RECENT HYDROLOGIC
CONDITIONS
OPERATE THE RESERVOIRS BY
ATTEMPTING TO MEET THE ADJUSTED
MONTHLY RELEASE TARGETS AND
PRODUCE AS MUCH POWER AS POSSIBLE
WITH THOSE RELEASES SUBJECT ONLY TO
PHYSICAL LIMITATIONS:
1. POWER PRODUCTION SUBJECT TO POWER PLANT
CAPACITY AND SUBJECT TO RESERVOIR ELEVATION
ABOVE POWER PLANT INTAKE
2. MAXIMUM WATER RELEASE SUBJECT TO
RESERVOIR ELEVATION RELATIVE TO POWER PLANT
AND BOTTOM OUTLET INTAKES
3. MINIMUM WATER RELEASE SUBJECT TO
RESERVOIR ELEVATION RELATIVE TO MAXIMUM
RESERVOIR ELEVATION
RULE CURVE OPTION (MODE 1)
This is the only option on all other reservoirs
DEFINE LONG TERM MONTHLY RULE CURVES FOR
EACH RESERVOIR
DAILY PROPOSE THE IDEAL RELEASES FROM EACH
RESERVOIR BASED ON WATER AND POWER DEMANDS
AND ON THEIR RELATIVE STORAGE POSITION
OPERATE RESERVOIRS BY ATTEMPTING TO
MEET THE PROPOSED IDEAL RELEASE SUBJECT
TO PHYSICAL AND RULE CURVE LIMITATIONS:
1. POWER PRODUCTION SUBJECT TO POWER PLANT
CAPACITY, SUBJECT TO RESERVOIR ELEVATION ABOVE
POWER PLANT INTAKE AND SUBJECT TO RESERVOIR
ELEVATION RELATIVE TO RULE CURVES
2. MAXIMUM WATER RELEASE SUBJECT TO RESERVOIR
ELEVATION RELATIVE TO POWER PLANT AND BOTTOM
OUTLET INTAKES AND SUBJECT TO RESERVOIR
ELEVATION RELATIUVE TO RULE CURVES 2, 3 AND 4
3. MINIMUM WATER RELEASE SUBJECT TO RESERVOIR
ELEVATION RELATIVE TO MAXIMUM RESERVOIR
ELEVATION AND SUBJECT TO RESERVOIR ELEVATION
RELATIVE TO RULE CURVE 1
SUMMARY OF NASPI LOGIC
YEAR Y
ADJUST TOKTOGUL RELEASE TARGETS
BASED ON HYDROLOGY OF LAST RECENT YEARS
MONTH M
SELECT APPLICABLE MONTHLY TOKTOGUL
RELEASE TARGET AND APPLICABLE MONTHLY
RULE CURVES FOR ALL RESERVOIRS
DAY D
DOWNSTREAM ANALYSIS
(SIMULATION)
1
M ODE
2
UPSTREAM ANALYSIS
(PREPARATION)
CALCULATE PROPOSED RELEASES FOR
ALL RESERVOIRS EXCEPT TOKTOGUL
BASED ON WATER AND POWER DEMAND
1
MODE
2
CALCULATE PROPOSED RELEASE
FOR TOKTOGUL BASED ON DEMAND
OPERATE TOKTOGUL
BASED ON
ADJUSTED TARGET
RELEASE
OPERATE TOKTOGUL
BASED ON PROPOSED
RELEASE AND RULE
CURVES
OPERATE ALL OTHER
RESERVOIRS BASED
ON RULE CURVES
NEXT DAY
SINGLE RESERVOIR LOGIC FOR PROPOSED RELEASES
STEP 4
STEP 3
Proposed Reservoir Release = I(1)
I(1) = Inflow Required to Reach 1 = { I(2) + [ D(1) + L(1) - S(1) ] } > 0
D(1) = Demand on Reach 1
L(1) = Losses on Reach 1
STEP 2
I(2) = Inflow Required to Reach 2 = { I(3) + [ D(2) + L(2) - S(2) ] } > 0
LOGIC
D(1) = Demand on Reach 1
FLOW
L(1) = Losses on Reach 1
DIRECTION
STEP 1
S(1) = Side Inflows to Reach 1
S(2) = Side Inflows to Reach 2
I(3) = Inflow Required to Reach 3 = [ D(3) + L(3) - S(3) ] > 0
D(3) = Demand on Reach 3
L(3) = Losses on Reach 3
S(3) = Side Inflows to Reach 3
RIVER FLOW DIRECTION
MULTIPLE RESERVOIR LOGIC FOR PROPOSED RELEASES
RESERVOIR 1
RESERVOIR 2
P(1) = Proposed Release
P(2) = Proposed Release
P(1) = [ I(1) + I(3)*AF(3,1) ] > 0
P(2) = [ I(2) + I(2)*AF(3,2) ] > 0
SEE WATER
ALLOCATION
LOGIC
REACH 1
REACH 2
I(1) = [ D(1) + L(1) - S(1)
I(2) = [ D(2) + L(2) - S(2)
REACH 3
I(3) = Required Inflow to Reach 3
WATER ALLOCATION LOGIC
DATA
I(1)
= Current inflow to Reservoir 1
I(2)
VP(1) = Storage volume of Reservoir 1
= Current inflow to Reservoir 2
VP(2) = Storage volume of Reservoir 2
at current position
at current position
VR3(1) = Storage volume of Reservoir 1
VR3(2) = Storage volume of Reservoir 2
at Rule Curve 3 Level
at Rule Curve 3 Level
R(1)
= Required release of Reservoir 1 to
R(2)
= Required release of Reservoir 2 to
meet demands that only Reservoir 1
meet demands that only Reservoir 2
can supply
can supply
F = Flow requirement that both Reservoirs 1 and 2 can supply
INTERMEDIATE CALCULATION
D(x) = number of days for reservoir X to arrive at Rule Curve 3 supplying all of F
D(x) = [ VP(x) - VR3(x) ] / { 3600*24)*[ F + R(x) - I(x) ]
RESULT
AF(1) = D(1) / [D(1)+D(2)]
AF(2) = D(2) / [D(1)+D(2)]
TARGET RELEASE OPERATION (MODE 2)
LOGIC FOR ADJUSTING TARGET RELEASES
DATA
TOKTOGUL LONG TERM AVERAGE INFLOW = QLT
TOKTOGUL MONTHLY TARGET RELEASES = T(1), T(2),…T(12)
H = NUMBER OF YEARS OF RECENT HYDROLOGIC HISTORY TO CONSIDER
S = ADJUSTMENT SENSITIVITY (1=FULL SENSITIVITY, 0=NO SENSITIVITY)
OPERATION AT THE BEGINNING OF YEAR K
QST = AVERAGE TOKTOGUL SHORT TERM INFLOW (YEARS K-1, K-2….,K-H)
F = ADJUSTMENT FACTOR = 1 + S *[ (QST-QLT)/QLT]
T’(M) = ADJUSTED MONTHLY TARGET FOR MONTH M OF YEAR K = T(M) * F, M =1,2…12
RESERVOIR OPERATION LOGIC 1
DATA FROM INPUT
DATA FROM MAIN PROGRAM
RESERVOIR PHYSICAL CHARACTERISTICS
INITIAL RESERVOIR ELEVATION
POWER PLANT PHYSICAL CHARACTERISTICS
INFLOW
BOTTOM OUTLET CHARACTERISTICS
PROPOSED RELEASE OR TARGET RELEASE
MONTHLY EVAPORATION
RULE CURVES
RELEASE = PROPOSED RELEASE OR TARGET RELEASE
SEE RULE
CURVE LOGIC
1
MODE
ADJUST RELEASE DEPENDING ON RESERVOIR
ELEVATION RELATIVE TO RULE CURVES
ESTIMATE FINAL ELEVATION BASED ON INITIAL
ELEVATION, RELEASE AND EVAPORATION
A
2
RESERVOIR OPERATION LOGIC 2
A
> TURBINE
INTAKE LEVEL
FINAL
ELEVATION
< TURBINE
INTAKE LEVEL
SEE POWER
PLANT LOGIC
DETERMINE
MAXIMUM
TURBINE FLOW
> BOTTOM OUTLET
INTAKE LEVEL
MAXIMUM
TURBINE FLOW IS
ZERO
FINAL
ELEVATION
< BOTTOM OUTLET
INTAKE LEVEL
SEE BOTTOM
OUTLET LOGIC
DETERMINE
MAXIMUM BOTTOM
OUTLET FLOW
MAXIMUM BOTTOM
OUTLET FLOW IS
ZERO
B
RESERVOIR OPERATION LOGIC 3
B
ASSIGN RELEASE TO TURBINE FLOW
COMPUTE RESIDUAL RELEASE
ASSIGN RESIDUAL RELEASE TO BOTTOM OUTLET FLOW
RECALCULATE FINAL ELEVATION
> MAXIMUM
RESERVOIR
ELEVATION
< MAXIMUM
RESERVOIR
ELEVATION
FINAL
ELEVATION
CALCULATE
SPILLWAY FLOW
SPILLWAY FLOW
IS ZERO
FINAL ELEVATION = MAXIMUM RESERVOIR ELEVATION
CALCULATE MEAN HEAD
AND POWER OUTPUT
END
RULE CURVE LOGIC 1
Water above this level is spilled
RCF-1 > 1
Spill danger above this level
RCF-2 = 1
Release is requested upstream
to maintain reservoir level
RCF-2 < 1
Maximum Level - Point 20
RC-1 Spill Control Level
RC-2 Upstream Request Level
RC-3 Low Level Alert
No releases to supply water to
points served by other
reservoirs
RCF-4 << 1
Critical Level Alert
Essential release only
Bottom Outlet Intake - Point 2
No release below this level
Evaporation losses continue
Zero Volume - Point 1
No evaporation losses
RULE CURVE LOGIC 2
Rule Curve 1 – Spill Control Level
This rule curve (RC-1) is used to reduce spilled water. The effect of RC-1 is to increase the
proposed release before the reservoir is completely full and spill is inevitable. The Rule Curve
Factor (RCF-1) should be always greater than 1.00
Rule Curve 2 – Upstream Request Level
RC-2 is used to maintain the reservoir at a constant elevation by requesting upstream the same
amount of water that is released. The RCF-2 should be 1.00 or less. If it is 1.00 the proposed
release will be met while water is requested upstream.
Rule Curve 3 – Low Reservoir Alert
RC-3 is used for two purposes.
1) If the RCF-3 is less than one it will reduce the proposed release to prevent the reservoir from
drawing down too fast when there is insufficient water upstream.
2) When two reservoirs can be used to deliver water to the same point this RC-3 will control the
proportion that is released from each reservoir. The higher the RC-3 the less the proportion
requested. RCF-3 has no relevance for this objective.
Rule Curve 4 – Critical Reservoir Level
RC-4 is used to signal the elevation at which the supply must be seriously reduced. RCF-4 must
be much lower than 1.00.
POWER PLANT LOGIC 1
HEAD
C
En
Hn
DATA
CAPACITY (KW)
C
TAILWATER LEVEL (M)
T
NOMINAL HEAD (M)
Hn
MINIMUM HEAD (M)
Hm
EFFICIENCY AT NOMINAL HEAD En
EFFICIENCY AT MINIMUM HEAD Em
EFFICIENCY
E
POWER
P
Hm
Em
FLOW
Q
Qmax = C / [9.81*En*Hn]
p = 9,81*E*H*q
P=C
q = ø * H**0.5
Q=C/(9,81*E*H)
POWER PLANT LOGIC 2
R = proposed release
L = reservoir level
H=head
I = intake Level = T + Hm
<I
L
>I
Calculate Qmax
T = tailwater
P=0
Q=0
Calculate E
> Qmax
R
Q = Qmax
< Qmax
Q=R
P = 9.81*E*H*Q
END
BOTTOM OUTLET LOGIC
KEY EQUATION FOR BOTTOM OUTLET (B.O.)
B.O. FLOW = B.O. CONSTANT * (B.O. HEAD)**0.5
DATA
RESERVOIR LEVEL
TAILWATER LEVEL
FULL RESERVOIR LEVEL
BOTTOM OUTLET MAXIMUM FLOW
DETERMINATION OF BOTTOM OUTLET FLOW
B.O. MAXIMUM HEAD = FULL RESERVOIR LEVEL - B.O. INTAKE LEVEL
B.O. CONSTANT = B.O. MAXIMUM FLOW / (B.O. MAXIMUM HEAD)**0.5
B.O. HEAD = RESERVOIR LEVEL - TAILWATER LEVEL
B.O. FLOW = B.O. CONSTANT * (B.O. HEAD)** 0.5
RUNNING NASPI
SCREEN CONTROL = 1
FAST RUN - NO RESULTS SHOWN
SCREEN CONTROL = 2
MONTHLY SUMMARY OF RESULTS
SCREEN CONTROL = 3
DAILY SUMMARY OF RESULTS
SCREEN CONTROL = 4
DETAILED CALCULATION FOLLOW UP
SCREEN CONTROL = 5
FOLLOW UP INCLUDING INTERPOLATION PROCESSES
SCREEN CONTROL = -1
WILL PROMPT FOR YEAR AND MONTH
SETS SCREEN CONTROL = 4 AT THE BEGINNING
OF SELECTED YEAR AND MONTH