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REC-ERC-76-3
Engineering and Research Center
Bureau of Reclamation
March 1976
MS-230 (2•72) Bureau of Reclamation
1. REPORT NO .
R EC-E RC-76-3
TECHNICAL REPORT STANDARD TITLE PAGE
4. TITLE ANO SUBTITLE
Load and Voltage Control Algorithms For Grand Coulee Powerplant
7. AUTHOR(S)
W. B. Gish
9 . PERFORMING ORGANIZATION NAME AND ADDRESS
Engineering and Research Center Bureau of Reclamation Denver, Colorado 80225
12 . SPONSORING AGENCY NAME AND ADDRESS
Same
15. SUPPLEMENTARY NOTES
16. ABSTRACT
3. RECIPIENT'S CATALOG NO.
S. REPORT DATE
March 1976 6 . PERFORMING ORGANIZATION CODE
8. PERFORMING ORGANIZATION REPORT NO.
REC-ERC-76-3
10. WORK UNIT NO .
11. CONTRACT OR GRANT NO.
13 . TYPE OF REPORT ANO PERIOD COVERED
14. SPONSORING AGENCY CODE
A load and voltage controller for managing the power output of 26 generators and the bus voltages for three
high-voltage busses at the Grand Coulee Power Complex is described in detailed flow chart form . The
controller is designed for inclusion in a computer-based supervisory control system. The load control is based
on a closed-loop digital power controller developed especially for hydroelectric installations. Also included is a
unique two-level load allocation system utilizing load-frequency commands from an area automatic generation
controller and features an alternating reactive-power balance and voltage-setpoint algorithm. The load and
voltage controllers use direct analog signals to the electrohydraulic governors and the thyristo r-based
excitation systems.
17. KEY WORDS AND DOCUMENT ANALYSIS
a. DES CR I PTO RS- - I * supervisory control (power)/ *load-frequency control/ * computer applications/
*algorithms/ automatic control/ control systems/ computer programming/ mathematical models/ governors/
voltage regulators/ data transmission/ feedback/ power dispatching/ power system operations/ baseloads/
peak power/ generating capacity/ spinning reserve/ hydroelectric power/ electric generators/ switchyards/
high voltage/ generator-motors
b. IDENTIFIERS~-/ minicomputers/ Grand Coulee Dam/ Columbia_ Basin project, Wash.
c. COSATI Field / Gro up 09 8 COWRR/ 0902 18. DISTRIBUTION STATEMENT
Available from the National Technical Information Service , Operations Division, Springfield, Virginia 22151 .
19 . SECURITY CLASS 21. NO . OF PAGE (THIS REPORT)
UNCLASSIFIED 87 20 . SECURITY CLASS 22 . PRICE
(THIS PAGE)
UNCLASSIFIED
...
REC-ERC-76-3
LOAD AND VOLTAGE CONTROL ALGORITHMS
FOR GRAND COULEE POWERPLANT
by W.B. Gish
March 1976
Electric Power Branch Division of General Research Engineering and Research Center Denver, Colorado
UNITED STATES DEPARTMENT OF THE INTERIOR * BUREAU OF RECLAMATION
Introduction Conclusions Application Algorithm flow charts Master station load control Master station voltage control RTU load and voltage control Load control concepts
"Off" mode ·"Pit" mode "Bpa" mode "Step" mode "Ramp" mode "R le" mode "Age" mode
Load control subroutine summary
Routine 1: Head calculation Routine 2: AGC data substitution Routine 3: Generator modes . Routine 4: Capacity calculation Routine 5: Capacity check Routine 6: BPA signals . . Routine 7: Water constraints Routine 8: Plant mode Routine 9: Mode display Routine 10: Generator ramp driver Routine 11: Plant ramp driver Routine 12: Ric adjust allocator
CONTENTS
Routines 13, 14, 15, and 16: The al I ocator Routine 17: Generator RTU reference
Voltage control concepts
"Off" mode "M bo" mode "Bvc" mode "Sch" mode "Step" mode "Ave" mode
Voltage control subroutine summary
Routine 20: Generator mode control Routine 21: Plant mode control Routine 22: AVC calculation Routine 23: AVC control Routines 24 and 25: The drivers
Page
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4 4 4 4 4 4 4
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5 5 5 5 5 5 5 5 5 5 5 5 5 6
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6 6 6 6 6 7
7
7 7 7 7 7
CONTENTS-Continued
RTU control concepts
Starting and stopping sequences Load control Voltage control Output driver Input systems Calibration system Simulations
Future development
Table 1 Acronyms, abbreviations, and symbols defined
Figure
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4 5 6 7 8 9
10
11
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13 14 15 16
17
18 19 20 21 22 23 24
FIGURES
Flow chart definitions . . . . . . . . . . . . . . Master Station load control-Interface definition . . . . Master Station load control-Head calculation and AGC data
substitution Master Station load control-Generator mode determination Master Station load control-Capacity and reserve calculations Master Station load control-BPA signal checks Master Station load control-Water constraint algorithm Master Station load control-Plant mode selection Master Station load control-Generator mode display and ramp
driver . . . . . . . . . . . . . . . . . . . Master Station load control-Plant ramp drive and reserve load
control adjuster . . . . . . . . . . . . . . Master Station load control-Automatic generation control
allocator . . . . . . . . . . . . . . . . . Master Station load control-Emergency allocator and RTU
reference driver . . . . . . . . . . . . . . Mater Station load control-Variable definitions (three sheets) Master Station load control-Generation summary-CRT format Master Station load control-Generation summary-CRT control tree Master Station load control-Generation substitution-CRT
format . . . . . . . . . . . . . . . . . . Master Station load control-Generation substitution-CRT
control tree . . . . . . . . . . . . . . . . Master Station load control-Load-head-CRT format . . Master Station load control-Load-head-CRT control tree Master Station load control-Load control-CRT format . Master Station load control-CRT control trees (two sheets) Master Station voltage control-Interface definition Master Station voltage control-Generator mode determination Master Station voltage control-Plant mode control
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7 7 7 7 8 8 8
8
8
9 11
13 15 17 19 21 23
25
27
29
31 33 39 41
43
45 47 49 51 53 57 59 61
Figure
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26 27 28 29 30 31 32 33 34 35
CONTENTS-Continued
Master Station voltage control-AVC calculation, Mvar driver, and volt driver . . . . . . . . . . . . . . .
Master Station voltage control-A VC control (two sheets) Master Station voltage control-Variable definitions Master Station voltage control-Voltage control-CRT format Master Station voltage control-Voltage control-CRT control tree RTU load and voltage control-Interface definition RTU load and voltage control-Clock logic sequence RTU load and voltage control-Load controller (two sheets) RTU load and voltage control-Voltage controller RTU load and voltage control-Output driver . . . RTU load and voltage controller-Variable definitions
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Page
63 65 69 71 73 75 77 79 83 85 87
INTRODUCTION
The Grand Coulee PMSC (Programmable Master Supervisory Control) will be a computer-based supervisory and control system for the Grand Coulee Power Complex. 1 Utilizing a redundant master computer and 34 remote minicomputers, the plant operations staff will be able to monitor and control through color CRT (cathode-ray tube) displays the 18 generators (G1 to G18) in the Right and Left Powerplants; the 6 generators (G19 to G24) in the Third Powerplant; the 6 pumps (P1 to P6) and 2 pump/generators (P/G 7 and 8) in the pumping plant; the 115-, 230-, and 500-kV switchyards; station-service equipment; and the various outlet gates and spillway gates of the dam. Provisions for six additional generators in the Third Powerplant, four additional pump/generators in the pumping plant, and an additional high-voltage switchyard have been made.
As part of the Grand Coulee PMSC Computer Complex, load and voltage controllers are required to allow versatile operation of the plant. These controllers must be adapted to the variety of generation characteristics found among the 26 generators under control and to the voltage characteristics of the three main busses connected to the power system.
The control algorithms proposed for Grand Coulee Powerplant utilize the information obtained during development and application of the CTIC (Coulee Third Interim Controller). Thus, the basic concepts of the systems have been tested and proven. However, the total system has not been modeled because of the reliance on the particular PMSC computer system display techniques and communication concepts.
The control algorithms are presented as a series of mathematical operations, computer manipulations, and decisions in flow chart form. These charts are not written in a computer language such as FORTRAN or assembler, but they may readily be adapted to the desired language of the programmer. The algorithms are complete with all inputs, outputs, timing, and communication defined. The implementation on the specific PMSC computer may require altering the mechanics of input, output, timing, and communication, but should not change the algorithm concepts.
CONCLUSIONS
The load-control algorithm proposed for the Grand Coulee Powerplant allows fast and flexible plant
operation, base-loading capability, rapid peak loading, and minimal governor activity. The design embodies closed-loop power-setpoint concepts which feature extensive error detection and adaptive gain correction.
The voltage control algorithm allows independent voltage control of the 115-, 230-, and 500-kV busses with monitoring of their interconnections. Also included is megavar balancing among the generators.
These algorithms are designed to utilize the capabilities of the very responsive governor and excitation systems at Grand Coulee Powerplant. All governors and excitation systems are controlled by direct analog inputs without the usual speed-level and voltage-adjust motors.
APPLICATION
The controllers described in this report are directly applicable only to Grand Coulee Powerplant. However, the concepts used in these controllers will be directly applied to other Bureau powerplants including Yellowtail Powerplant. The algorithm concepts will be used as the basis for the Automatic Generation Control system presently being designed for the Watertown Operations Office. The general concepts can be used at almost any hydroelectric generating plant where plant control computers are available. Minor modifications would allow the system to be applied to fossil-fuel plants.
The use of the algorithms at other plants would usually be less complex than this report presents for Grand Coulee Powerplant. Thus, the report presents the many operating modes available and elimination or modification of the modes for other applications is possible.
ALGORITHM FLOW CHARTS
The flow charts provide a description of the load- and voltage-control algorithms. The charts make use of decision procedures using equivalence (=). greater than (>), less than (<), set (=1), or clear (=0). Logical operators of "inclusive or" (OR) and "and" (AND) are also used. The mathematical formulas use the replacement concept where a variable (a storage location) is replaced or substituted for the result of the mathematics. The replacement is indicated by an arrow (+-) and is equivalent to the FORTRAN "equals" operation. Thus in the expression A+- B, the value in B would be put into the variable or location A. The
1 Grand Coulee Complex Programmable Master Supervisory Control, Solicitation No. DS-7049, two volumes, U.S. Department of the Interior, Bureau of Reclamation, 1974.
mathematical operations included addition (+), subtraction (-), multiplication (*), division (/), and squaring ( 2 ). To allow reduction of flow chart complexity, certain summations are indicated by:
P/G 8
RLC MW~~ GEN MW ]MLM = rlc
G1
This example shows that the variable RLC MW is replaced by the sum of all the values of the GEN MW array (measured power) from G1 through G24 and then PIG 7 and 8 where the generator variable MLM is equivalent to "rlc" (reserve load control). Thus R LC MW contains the total measured power of all generators in the "rlc" mode. Figure 1 shows a summary of the various symbols used in the flow charts and defines the logic constants.
The flow charts form essentially a complete control system with all the inputs, outputs, and constants defined. To allow easy adaption to a computer system, the buffer concept is used. Since a real-time computing system may interrupt the execution of any of these programs, all data used by the program is read from the various input and data base sources to a buffer at the start of the program. The program then uses only data from the buffer so that other activity in the computer will not alter these data. When the program is finished, the new data in the buffer generated by the program are now used to update the data base and output channels. This poses the problem of having an operator enter data and interrupt the algorithm. The data would then be changed back to the original by the update after the algorithm has been completed. This could be solved by several methods such as disabling CRT entries during program execution. However, if program execution is very quick, an occasional occurrence of the problem may not require a solution.
Alarms are also generated on a buffer concept. All alarms for these programs should be cleared at computer power-up, then the actual alarms are never set or cleared by any other program except the control programs. The control program first clears a temporary alarm buffer and then sets the required alarms in the temporary buffer as the program progresses. When the program is finished, all the alarms in the temporary buffer are used to both set and clear the actual alarms, and time tags are added. Thus, alarms that are set each time the algorithm is called do not change for the operator.
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Initializing on computer power-up can be treated in several ways. However, the algorithm design assumes that if the power-down/power-up sequence occurred in less than 2 seconds and no data are lost, the Master Station control algorithms would not have to have the Master Station initialize flags set. (The flag for load control is separate from the flag for voltage control.) If the computer has been down for longer than 2 seconds, the control should be initialized. Since the operator must change all of the plant and generator modes, and many setpoints, initialization should not be allowed to occur often. In the RTU (remote terminal unit), the in'tialization should always take place on any power-down/power-up sequence since the computer-failure contacts may have opened.
The variables used in each control algorithm are defined with each algorithm. For the Master Station controllers, the variables have the subroutines that reference them defined by the "Subroutine Reference Number." The headings of the columns are described in figure 1. For the RTU, the variables are also described by size and accuracy to allow the programmer to efficiently utilize the RTU memory.
The flow charts are divided into three general groups. The Master Station Load Control is shown in figures 2 through 21. The Master Station Voltage Control is shown in figures 30 through 35. In all flow charts, the generators processed are G1 through G24 and P/G 7 and 8. However, the data base and programs should allow for G25 through G30 and P/G 9 through P/G 12.
MASTER STATION LOAD CONTROL
The first figure of the group (fig. 2) shows the interface requirements for the Master Station Load Control algorithm. The variables required for the input and output from various devices and data bases are shown.
The algorithm does not require precise timing of the input data and will react properly if the data have been updated any time since the last pass of the algorithm. Updating only the changing data from CRT's or RTU's is permissible if the CRT's or RTU's are scanning the information at least once every 2 seconds.
The algorithm should be executed every 2 seconds, but is written to be independent of call timing. Thus, the calling time can average 2 seconds with a maximum of 4 seconds and a minimum of 1 second. The 4-second maximum is derived from the necessity to control
devices that have time constants as low as 12 seconds. This allows three control passes to be executed for the minimum time constant.
Figures 3 through 12 describe the mathematical and decision processes of the load-control algorithm. The operational description is given in a later section of this report. Figure 13 describes the variables and the subroutines where they are utilized. Figures 14 through 21 show the CRT display formats and control trees utilized by the load control.
MASTER STATION VOLTAGE CONTROL
Figure 22 shows the interface requirements for the various buffers. The algorithm requires no precise timing of the data input or output. If the data have been updated or scanned by an RTU within 2 seconds previous to the "voltage control" call, the routine will perform well. The routine can be called on the average of every 6 seconds, with a maximum call rate of once a second and a minimum rate of once every 10 seconds. The maximum time (minimum rate) must be limited to keep the incremental gain of the algorithm to a reasonable value.
Figures 23 through 26 describe the mathematical and decision process of the voltage control algorithm. Figure 27 defines the variables used and figures 28 and 29 show the voltage control CRT format and control tree.
RTU LOAD AND VOLTAGE CONTROL
Figure 30 shows the interface of the load and voltage controllers. The program must have data which have been scanned within the 2 seconds previous to the call. Three-second analog filters are required for the power, voltage, and megavar inputs. The gate position and gate limit inputs may have any desired filtering up to 3 seconds. The data for the master can be read or sent on an exception basis provided the RTU can determine if the master is operational.
The algorithms are not time dependent and can be called as often as 0.01 second to as little as every 0.5 second if the generator is in the "local automatic" mode, or wl1en synchronizing G19 through G24. Otherwise, the program may be called every 0.01 seco!lrl tc nvery 4.9 seconds with the average being 2 seconds. Wher. synchronizing G1 through G18 and P/G 7 and 8, the algorithm need not be called at all.
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However, the "output driver" subrouti;1e shou Id be called by the synchronizer to allow the synchronizer to control speed and voltage.
Figure 31 defines the "clock logic" for the RTU load and voltage control. The necessary interlocks to the automatic start and stop logic are shown. The synchronizer enable flag must remain up until the breaker is closed (unless the synchronizer aborts) or the speed and voltage-adjust positions will be set to no-load values. The load control will not become effective until all starting sequences are finished and the starting flag is cleared.
Figures 32, 33, and 34 define the control subroutines. Figure 34 also has several notes on algorithm operation. Figure 35 defines the variables used.
LOAD CONTROL CONCEPTS
The load controller for Grand Coulee Powerplant was designed to provide the following concepts. The load control I er should:
1. Maintain flexible control of the 26 generating units which have a wide range of ratings.
2. Allow SPA (Bonneville Power Administration) to use the plant for peak loading as well as base loading.
3. Allow water constraints to modify the loading of generators.
4. Maintain critically damped governor response with a minimum of governor activity or gate movement.
5. Maintain the normal power system damping provided by governor systems.
The load controller will use to advantage certain characteristics of the plant which include:
1. Very responsive governors with availability of direct analog signal control.
2. Versatile CRT displays which allow rapid changes in generation scheduling among individual generators.
These controls attempt to overcome plant disadvantages of various water-starting times which limit loading response. Also, the vast size of the powerplant creates delays in data collection and
transmission, and poses timing problems for real-time control.
The control algorithms use four modes of control for loading any generator. These modes are "step" for manual ramping, "ramp" for automatic ramping, "rlc" for reserve load control, and "age" for automatic generation control. Each of these modes function under three plant modes: "off" for no control, "pit" for plant setpoint control, and "bpa" for automatic generation control from BPA's Dittmer Center RODS (Real-time Operations, Dispatch, and Scheduling) computer. A detailed discussion of the plant modes precede the discussions of the generator modes.
"Off" Mode.-The "off" mode turns all control on the plant to the manual "step" mode. This mode is used as an "emergency stop" for load control, and thus stops all control and allows all generators to remain at their present loads. After the "off" mode is set, generators may be returned to any other mode such as "age," "rlc," or "ramp." However, only the "step" and "ramp" mode will function. The generators on "age" or "rlc" will remain at their present loads.
"Pit" Mode.-When the "pit" mode is selected, the plant allocator will use generators on "age" and "rlc" as needed to maintain a plant setpoint entered by the operator. The plant may be ramped to a new setpoint at a rate entered by the operator. If some generators are in the "ramp" mode, the allocators will counter-ramp "age" and "rlc" generators to maintain the plant setpoint. If generator loads are changed by "step" inputs or manual adjustments at the unit control boards, the allocators will maintain the plant setpoint by changing the "age" or "rlc" generators by following their power variations.
"Bpa" Mode.-The "bpa" mode is the same as "pit" mode except that BPA's Dittmer Center supplies the plant setpoint from the RODS computer rather than a Grand Coulee operator determining the setpoint. All counter ramping and adjustments for manual changes are the same as for the "pit" mode.
When changing from "pit" to "bpa" modes, the plant will be ramped until the plant setpoint corresponds to the BPA setpoint. Then control will be given to BPA. When changing from "bpa" mode to "pit" mode, the last BPA setpoint entered becomes the plant setpoint until an operator enters a new setpoint.
"Step" Mode.-The "step" mode allows the operator to change the load of any individual generator similar to a raise-lower switch. The operator may enter a
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desired number of steps which are positive for raise and negative for lower. Each step represents approximately 1 percent of generator rating but will vary from 0.5 to 2 percent depending on generator load and head. Thus, the operator will judge from experience the number of steps required to load a generator a given amount. When the steps are actually being used by the RTU to change the load, the number entered by the operator will clear on the CRT format. The steps will be executed at a rate of approximately 1 percent every 2 seconds.
"Ramp" Mode.-The "ramp" mode allows a power setpoint to be entered for the individual generator along with a ramp rate. The generator will then ramp to the new setpoint and maintain that setpoint. When the ramp is finished, a zero rate will be displayed. All ramps will be counter ramped by the "age" or "rlc" generators if the plant is not in the "off" mode. If the generator passes through a turbine rough zone (as calculated from head), a special high ramp rate is used. Normally, generators would be started or stopped with the "ramp" mode.
"Ric" Mode.-The "rlc" or reserve load control mode allows the operator to set an individual generator to a setpoint. However, the generator does not ramp to that setpoint, but moves toward the setpoint as needed to satisfy the plant setpoint. When the generator reaches setpoint load, it will remain there unless the normal "age" generators cannot satisfy the plant setpoint. Then an "rlc" generator will be used to satisfy the plant setpoint, but will return to its individual setpoint as soon as the plant setpoint no longer needs the generator.
"Age" Mode.-The "age" or automatic generation contro! mode uses the generator to satisfy the plant setpoint (either operator entered in "pit" mode or supplied by BPA). The operator cannot enter a setpoint or a ramp rate for the generator. The generator can operate anywhere between its normal capability (or gate limit) and the upper edge of the rough zone (or O MW if there is no rough zone). All generators on "age" will operate at nearly the same percent of loading. If the plant is generating below setpoint, the generators with the lowest percentage loading will be used to raise the generation output. Likewise, the generators that have the highest percentage loading will be used should plant generation be above plant setpoint. No generators will be stepped less than 1 percent of their rating to satisfy the plant setpoint. The generators will be limited in their speed of change 'to normal maximum ramping rate by a rate-limiting filter system.
The RTU algorithm is responsible for using the reference power developed by the ramp generators and allocators, and forcing the actual generated power to comply .with that reference. Thus the RTU has no internal ramp generators or information concerning the operation of other units (except for the ramp generator used in "step" and "local-automatic" modes). This creates a minimum of communications between the Master Station and the RTU, and also allows the two programs to operate asynchronously. The RTU algorithm theory is described in a companion research report.
LOAD CONTROL SUBROUTINE SUMMARY
Routine 1: Head Calculation.-The head at the plant is used to calculate the expected turbine rough zone locations, the generator normal and emergency capabilities, the expected point of maximum turbine efficiency, and the gate limit power. The last is used in Routine 17 for frequency bias calculations. The data for the calculations are determined emperically at the plant and will be defined when the data are available.
Routine 2: AGC Data Substitution.-The condition of the RTU's is checked and appropriate substitutions can be made by the operatars for power or head not monitored by an RTU.
Routine 3: Generator Modes.-The modes of the individual generators are determined by the CRT inputs or the RTU. If changes are required, proper initialization is provided. If changes in mode require repositioning of load (such as from "ramp" to "age"), appropriate adjustment ramps are also initialized. The "step" mode of a generator is processed in this routine.
Routine 4: Capacity Calculation.-The various capacity, reserve, and margin calculations are made for both the allocators, and the PDAS (Powerhouse Data Acquisition System) utilized by BPA. However, not all points of PDAS are provided in this routine. The remaining points should be calculated in other PMSC system programs.
Routine 5: Capacity Check.-The setpoints for the capacities, reserves, and margins are checked. These alarms are for operator convenience and do not affect the load controllers or automatically start or stop generators.
Routine 6: BPA Signals.-The signals from BPA are processed to determined validity. System frequency is monitored to insure the power system has not
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segmented during a major disturbance. The 500-kV bus is monitored in this program as system frequency. The 230-kV bus is monitored to provide a check frequency. If the two do not agree, neither is used.
Some of the colors used in the CRT displays are determined here, but because of data processed later, may be changed in unusual circumstances.
Routine 7: Water Constraints.-This is a very simple routine designed to provide a minimal constraint. As research on groundwater measurements continues and more emperical data are collected, this algorithm may be modified to include other constraint requirements.
Routine 8: Plant Mode.-The plant mode is determined from operator interaction or constraint conditions. If the mode is changed, proper initializing is performed.
Routine 9: Mode Display.-The colors are determined for the various generator data displays according to the generator mode. Also, initializing the allocator for a generator mode change is accomplished.
Routine 10: Generator Ramp Driver.-The "ramp" mode for a generator is processed and the necessary reference changes are made along with derivative calculations. The derivatives are not added to the references until Routine 17. Also calculated is the ramping information required by the allocators.
Routine 11: Plant Ramp Driver.-lf the plant 1s in
"pit" mode, ramps between changes in setpoints are generated. Plant derivatives are calculated and data are prepared for the al locators. The allocators actually change the various generator references in response to the plant ramp driver.
Routine 12: Ric Adjust Allocator.-Since the "rlc" generation is used only in emergency conditions, the "rlc" generators are returned to setpoint as quickly as the plant control error will allow. This is done before the normai "age" generators would be allocated. A maximum ra·ce of 6 percent load per minute is used.
Routines 13, 14, 15, and 16: The Allocator.-These routines function together to form the allocator. Routine 13 determines the error to be allocated and does the actual allocation. Routine 14 searches for the correct generator to al locate. Routine 15 is the "rlc" or emergency allocator if Routine 14 could find no "age" generator, but an error still exists. The emergency allocator uses all "age" and "rlc" generators and removes rough zone and normal capability limitations. Routine 16 searches for the appropriate "age" or "rlc" generator for allocation.
Routine 17: Generator RTU Reference.-The RTU references for load control are calculated including frequency bias. Normal power system damping is assured by this process.
VOLTAGE CONTROL CONCEPTS
The voltage controller concepts for Grand Coulee Powerplant were designed to provide the following concepts. The voltage controller should:
1. Maintain reasonable megavar balance between the various generators supplying the three major high-voltage busses.
2. Allow independent control of the voltage on the three major high-voltage busses within megavar limitations.
3. Allow BPA to schedule the bus voltages through the Powerhouse Data Acquisition System if Grand Coulee operations desires.
4. Allow all normal activities of the voltage regulators and excitation systems for power system disturbances.
The voltage controller will use to advantage certain characteristics which include:
1. Very responsive regulators with availability of direct analog signal control.
2. Versatile CRT displays which allow rapid voltage level changes between busses.
The voltage controller is based on the "sheepherder" principle. The object is not to perform tight control of the excitation system.s, but rather to slowly move all excitation system references together to maintain both a reasonable megavar balance and bus voltage level. The excitation systems have response time constants from 0.1 to 2 seconds and therefore the PMSC would not be able to scan often enough to allow tight control or predictive control techniques. The 3-second analog filter in the RTU thus becomes very important in preventing aliasing.
The algorithm operates two independent controls alternately every 6 seconds. The first control algorithm balances megavar between the generators on a given voltage bus in proportion to their various megavolt-ampere ratings. An average megavar level is found for all generators on a bus and then voltage references are increased or decreased slightly to
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attempt to move all generators to within plus or minus 3 percent of equal per unit megavars. Then, 6 seconds later, the voltage algorithm moves the voltage of all generators on a bus up or down slightly to satisfy the bus setpoint. The system is very low gain.
Megavar setpoint is not used in any algorithm since such control would have to be modified by the apparent power factor of the entire bus to assure the proper negative feedback for both inductive and capacitive loads. Also such megavar setpoint control would have to be biased by apparent system voltage to maintain system voltage stability. This is similar to biasing power setpoint control with frequency to insure the apparent system damping is not weakened.
"Off" Mode.-The "off" mode removes all voltage control from the individual bus. All generators are returned to the "step" mode and voltage remains at previous levels. Voltage and megavars can be changed only by entering step counts. If a generator is placed in "ave" mode, no change of voltage or megavar may be made from the PMSC console until the voltage controller is changed to "mbo," "bvc," or "sch."
The control of all three busses may be stopped simultaneously by using the EMERGENCY STOP CONTROL poke point on the voltage control or load control CRT formats.
"Mbo" Mode.-The "mbo" or "megavar balance only" mode allows the generators (with "ave" mode) of the desired bus to have their megavar levels balanced every 12 seconds. Bus voltage level is not controlled. The bus voltage may be raised or lowered by entering a number into the megavar step CRT location, and all generators will respond in unison.
"Bvc" Mode.-The "bvc" or "bus voltage control" mode uses the alternating megavar balance and bus voltage algorithms to maintain the voltage setpoints of an individual bus as entered by an operator. The action is not excessively strong or fast, but the bus voltage will move to a new setpoint in about 2 minutes.
"Sch" Mode.-The "sch" or "schedule" mode is identical to "bvc" mode except the setpoint is obtained from BPA through the PDAS communication channel. The operator at Grand Coulee cannot control the voltage of the bus.
"Step" Mode.-Each individual generator may be placed in the "step" mode. The operator may then change voltage similar to the voltage-adjust raise-lower switch. The operator may enter a desired number of steps which are positive for raise and negative for
lower. Each step represents a megavar change of 1 percent of the megavolt-ampere rating or 0.1 percent of rated voltage. The exact amount of megavar change will vary as system voltage and loading change. The steps will be executed at a rate of approximately 0.1 percent voltage every 2 seconds.
"Ave" Mode.-The "automatic voltage control" or "ave" mode allows the voltage controller to use an individual generator for megavar balancing and bus voltage adjustment. The operator cannot enter individual generator setpoints for voltage or megavars.
The RTU algorithm is responsible for moving the generator voltage to correspond to the setpoint, to detect failure to respond, and to detect maximum operation for megavar levels based on the generator thermal capacity.
The RTU is separated from the master using the voltage setpoint and thus a minimum of communications is required. Also, the algorithms of the master and RTU may operate asynchronously.
VOLTAGE CONTROL SUBROUTINE SUMMARY
Routine 20: Generator Mode Control.-The mode of the individual generators is determined by the CRT and RTU inputs. If changes are required, appropriate initializing is done. The "step" mode is handled in this routine.
Routine 21: Plant Mode Control.-The mode for each bus is handled by this routine. Also, checks of megavar interchange between busses are made. If mode changes are required, initializing is done.
Routine 22: AVC Calculation.-The totals required by the voltage controller are calculated. No data for PDAS are calculated.
Routine 23: AVC Control.-The routine is divided into two sections, the megavar balance and the bus voltage control. Each section is then divided into 115-, 230-, and 500-kV bus controls. It is physically possible for G 1 to be connected to either the 115-kV bus or the 230-kV bus, or both. Exact operating procedures for the 115-kV bus are not yet defined.
Routines 24 and 25: The Drivers.-The megavar and voltage drive subroutines for individual generators provide the deadbands and control inhibit flags from the RTU. Megavar unloading is also handled. The unloading process is difficult to define since a
7
generator may not be able to have its megavars reduced to zero, particularly if it is tied directly to a long transmission line.
RTU CONTROL CONCEPTS
The RTU algorithms are based on closed-loop setpoint control. The setpoint approach was chosen to allow a minimum of communications between the master and the RTU and also to allow the RTU to operate asynchronously with the master. Should the master fail, the RTU will hold the last setpoint.
Starting and Stopping Sequences.-The normal start/stop logic is assumed to operate asynchronously with the load control. During a sequence, the control algorithm initializes the governor and excitation systems and then bypasses any remaining control. Special conditions such as synchronous condenser operation or pumping must be flagged continuously.
Synchronizing causes most of the routines to be bypassed with the exception of G19 through G24 which are synchronized in the 500-kV yard. The raise-lower signals for speed and voltage are sent by microwave communications.
Load Control.-The load controller handles the "step" mode and also the power algorithm. The "step" function ramps are generated by counters and the power algorithm is implemented by using a pole-cancellation or model prediction concept. Checks for gate limit, loss of response, and excessive error are made. An adaptive gain system is also included.
Voltage Control.-The voltage controller handles the "step" mode and the voltage algorithm. The "step" function ramps are generated and the voltage algorithm is implemented by a low-gain, closed-loop system with response checking. A circle diagram of thermal capacity of the generator is calculated.
Output Driver.-The most important outputs of the RTU are the speed level and voltage level. If these fail in an arbitrary way, excessive load or excessive voltage may be applied to the generator, or a load rejection or out-of-step condition may occur. In all cases, the consequences are serious. Thus, the D/A converter and computer failure detection must be fail-safe. All possible failure modes of hardware, software, or communication must be studied to insure the governor and excitation system do not respond improperly. The output followers will follow the RTU outputs with approximately a 10-second filter.
Table 1.-Acronyms, aqbreviations, and symbols defined
A/D "age" 11avc" BPA "bpa" "bvc" CRT CTIC D/A G GL GP "mbo" PDAS P/G
Analog to digital "Automatic generation control" mode "Automatic voltage control" mode Bonneville Power Administration "Age" from BPA's RODS computer mode "Bus voltage control" mode Cathode-ray tube Coulee Third Interim Controller Digital to analog Generator Gate limit Gate position "Megavar balance only" mode Powerhouse Data Acquisition System Pump/generator
Input Systems.-The A/D converters and multiplexers for generator power, megavar, and voltage must include 3-second filters to prevent aliasing. Other data may have up to 3-second filters. Switch inputs should be isolated and guarded against transients. All data for the control algorithms must be sampled within 2 seconds from program execution.
Calibration System.-A calibration system is required to allow data to be obtained for calculation of constants used in the control algorithms. These constants must be reevaluated after each governor and excitation system maintenance procedure. Also, the various variables of the control system should be available for a strip-chart recorder display (through D/A converters) with a convenient selection, scaling, and offset procedure for each variable. An eight-channel analog recorder with two channels of event information will be connected to the DIA and logic outputs to allow adjustment and debugging of the rather complex control systems.
Simulations.-As an aid to computer system checkout, simple simulations of the governors ca.n be made by programming a simple time constant between Sn (the speed-level output i.n percent megavolt-amperes) and Pl (generator power input in percent megavolt-amperes). The GP (gate position) should be equal to Pl in percent and GL (gate limit) should be set to 100 percent. The time constant should be TG (the governor time constant) in seconds. The same model also may be implemented in hardware if desired. This model does not check out the algorithm operation for water-starting time, error analysis, or gain control, but rather provides a tool to allow the load algorithms to operate while other computer system details are checked and calibrated.
The voltage control system is more complicated to simulate since the various RTU algorithms must
8
Pl
"pit" PMSC "rlc" RODS
"sch" TG vn VI
Generator power input (percent megavolt-amperes)
"Plant setpoint control" mode Programmable Master Supervisory Control "Reserve load control" mode Real-time Operations, Dispatch, and Scheduling
Remote terminal unit Speed-level output (percent
megavolt-amperes) "Schedule" mode Governor time constant Voltage adjust (percent kV) Generator voltage (percent kV)
interact. One very simple approach is to assume the megavar of the generators are always zero and never need balancing. Then a direct software link between V n (voltage adjust in percent kilovolts) and VI (generator voltage in percent kilovolts) will satisfy the RTU algorithm closed loop. At the master, the voltage from each generator [(GEN VOLTAGE)/(GEN VOLT RATING) in percent kilovolts] should be multiplied by 10 and substituted for generator megavar (replacing the O Mvar from the RTU) where the generator megavar is in percent megavolt-amperes (GEN MVAR +- GEN MVA RATING * GEN VOLTAGE * 10/GEN VOLT RATING). Then the voltage of the generators tied to the individual busses should be averaged to form a bus voltage. This will assume the megavar flow -between busses is always zero, but the megavar balance and bus voltage control will function.
FUTURE DEVELOPMENT
A general control system concept proposed for the Grand Coulee Power Complex has been presented utilizing the latest concepts and data available. However, as the concepts are adapted to a specific computer and communications system, several changes in details of computer interaction will be made. Also, as more data are obtained from the CTIC system presently in operation, the algorithms will be slightly modified to provide better control. As the system becomes operational, some additional changes will be required in the operator interface as it is difficult to visualize operator manipulation of the control until it has been experienced. Thus the load and voltage control is presented as a proposed concept which will be refined by experience.
DRAWING SYMBOLS
0 0
START OF
SUBROUTINE
DATA INPUT AND OUTPUT
CALL NAME
SUBROUTINE CALL
(SUaROUTINE REFERENCE NLMlER
IS N}
SUBROUTINE RETURN OR EXIT
INDICATES AN ALAl!M MUST BE SET
D <>
OPERATION MUST TAKE PLACE
DECISION MUST BE MADE
0 SUBROUTINE FLOW IS
CONTINUED ELSE WHERE WI TH AN
I OENTI CAL LETTER
POKE POINT FOR LIGHT PEN + CONTROL Of CRT DI SPLAYS
INDICATES DEFINED VARIASLE ON FORMAT ANO CONTROL TREE
DRAWi NGS
MATPEMATICAL SYMBOLS
ADDITION
SUBTP.ACT!ON
* MULTIPLICATION
DIVISION
( } 2 SQUARE
.,._ REPLACEMENT
SET REPLACE WITH
CLEAR REPLACE WITH D
NAMEn ~~~U~p.~F p~~:~~; PASS
NAME VALUE OF "NA~E" n-1FRDM THE PREV 1rus PASS
SUMMI.TION CF T~E VARIABLE FOR GENERATO~S GI Te G~
DtC If I ON SYMBGIJ_
EQUIVALENT
> GREA HR TH AN
<: LESS THAN
> GREATER THAN - OR EQUAL
5 LESS TPAN OR EQUAL
;. NOT EQUAL
+ POSI Tl VE
- NEGATIVE
I ABSOLUTE
SET VARI ABLE
VALUE
EQUAL TD
CLEAR VARIABLE EQUAL TO 0
OR LOGICAL INCL US I VE DR
AND LOGICAL AND
LOG I CAL CONSTANTS AUTDMATICGENEPATIDN CONTROL MOOE
age FCR INDIVIDUAL GENERATOR LOAD CCNTROL
ave AUTOMATIC VOLTAGE CONTROL MODE 'CR INDIVIDUAL GENERATOR VOLTAGE CONTROL
bpa BONNEVILLE POWER ADMINISTRATION ~ODE FOR MASTER LOAD CONTROL. BPA IS SENDING THE CCNTROL SIGNAL.
bvc BUS VOLTAGE CONTROL MOOE FOR MASTER VOLT AGE CONTROL A SET PD I NT IS USED AS BUS VOLTAGE REFERtNCF..
mbo ~EGAVAR BALANCE ONLY MODF FOR MASTER VOLTAGE CONTROL
off OFF MODE (NO CONTROL I a) MASTER LOAD CONTROL -NO
LOAD CONTROL ANYWHERE. , l MASTER VOLTAGE CONTROL NO
VOLTAGE DR MVAR CONTROL o, A GIVEN BUS. I NOi VI DUAL LOAD CDNTROLUN IT BREAKER IS OPFN
ct I I ND IV I DUAL VOLTAGE CDN TROI. -UN IT BREAKER IS OPEN
el FORMSLMB AND MSVMB, 1NDICATES SYSTEM IS NORMAL
romp RAMP TO A SETPOINT AND MAINTAIN SETPOl~JT
FOR INDIVIDUAL GENERATOR LOAD CONTRCL ( PREYIOUSL Y CALLEO INDIY. MODE I
rl C RESERVE LOAD CONTROL MODE FDR MASTER LOAD CONTROL. UNIT MAINTAINS SETPOINT UNLESS EMERGENCY C,ONDI TIONS REOUI RE A CHANGE. \PREYIOUSlY CALLED NET NOOl'I
sch SCHEDULE MODE FOR MASTER VOL TAGt CONTROL BUS VOLTAGE REFERENCE IS SCHEDULE FROM BPA.
start STARTING RAMP MODE FOR INDIVIDUAL GENERATOR LOAD CONTROL
step STEP MOOE FOR I HD IV I DUAL GEN ER ATOR LOAO DR VOLTAGE CONTROL. GENERATOR HAS NO AUTOMATIC LOAD DR VOLTAGE CONTROL AND MUST BE RAISED OR LCWEREO
BY ENTER I NG DESI RED NUMBER Of "STEPS'' INTO CRT DI SPLAYS.
stop STOPPING RAMP MODE FOR INDIVIDUAL GENERATOR LOAD CONTROL.
zero ZERO MVAR STOPPING MODE FOR INDIVIDUAL VOLTAGE CONTROL
HEADING DESCRIPTIONS FOR VARIABLE DEFINITIONS
··suil FIRST REQUIRING SOURCE FROM RTU, CRT, FILES"
lHE NUMBER LI STEC IS THE SUSROUTINE REFERENCE NUMSER WHERE
THE DATA IS FIRST USED THE BIJfFER SUPPLYINC- me DATA IS
FROM THE RTU, THE CRT FORMATS OR THE PERMANENT Fi LES.
"SUB DETERt-llfllNG DESTINATION TORTU, CRT''
TPE SCBROUTIKE REFERENCE NU~BER INDICATES TPE SUBROUTINE
THAT IS LAST TD OETER~INE THE DATA TO BE SENT TO THE RTU
BUFFER OR THE CRT FORVAT BUFFERS.
''SUBS REQUIRING STORAGE PREV, PRES, PREV - PRES''
THE SUBROUTINE REFERENCE NUMBER INDICATES THE SUBROUTINES
THAT REQUIRE DATA TO BE STORED BETWEEN PASSES. THE SUBROUTINE
WHICH UPDATES THE PAST WITH THE PRESENT IS SHOWN. IF THE PAST
ANO PRESEtH ARE NEEDED TOGETHER, TWO VARIABLES ARE DEFINED
WITP THE PAST VARIABLE CALLED "OLD"
"USED IN SUBS" ALL THE REFERENCE NUMBERS OF THE SUBROUTINES THAT USE THE VARIABLE
ARE GIVEN.
"INITIALIZING, INITIAL LCADING, POWER-UP, IN SUB"
INITIAL LCAOING OF THE DATA CAN BE OCNE FR0M MAG TAPE OR DISK AND
IMPLIES THE LOADING TAKE PLAC, WHEN THE SYSTEM IS INITIALLY
STARTED. DATA FDR THE VARIABLES WILL BE SUPPLIED BY THE GOVERNMENT.
POWER-UP LOADING INDICATES VARIARLE MUST BE GIVEN A VALUE AT
POWER-UP. IN SUB GIVES THE SUBROUTINE REFERENCE NUMBER \iPERE
THE VARIABLE IS INITIALIZED.
"ARRAY SIZE'' THE SIZE OR NUMHR OF ELEMENTS IN THE VARIABLE ARRAY ARE GIVEN.
'"CRT FORMAT, OUTPUT, INPUT, CONTROL"
THE NAME OR A8BijEVIATION OF THE CRT FORMAT WHrnE THE VARIABLE
IS DISPLAYED IS GIVEN. IF IT IS OISPLAYEO FOR THE OPERATOR, IT IS LISTED IN THE OUTPUT. IF
IT IS DATA ENTERED BY TPE OPERATOR, IT IS LISTED 1H INPUT. IF
~ i s~io" I~ L~~N~:otONTROL COM'lAND ENTERED BY THE OPERATOR' IT Is
1222-PS-400
Figure 1. Flow chart definitions.
9
COIMUNICATION TO RTU MASTER STATION
RTIJ 1-2ij, 26, 27
MASTER STATION LOAD MOOE ltep, off}
INHIBIT AGC UP i; =- nor~. I ., inhibit
INHIBIT AGC DOWN 0 = nor111. I= inhibit)
CLUR STEPS 0 = norm. I = clear
I
MSLMB
FSU
FSO
FCS
UNIT POWER I GEM MO MO,
UN IT BREAKER "* BREAKER (0 = OPEN, I CLOSED) ST TUS NORMAL STOP STOP (0 = OFF, 1 = STOP IN PROGRESS I SIGNAL
RTU 25 (STATION SERVICE GEN)
LS I POWER (MW
LS2 POWl'R MW
LS3 POWER
RTU 28 ( II S KV YARD)
RTIJ 29 (230 KV YARD)
RTU 30 (500 KV YARO)
500 KV BUS FRE ENCY (HZ)
liTU 31 (XLS)
I [
I."' I MW
K&LS
USBR I I
500 KY II MW
500 KV ,! #2 MW
FRE 500
CANAL ELEV FOREIIAY
i
BUFFER FOR
DATA FROM RTU 1 S
CALL EVERY
2 SECOIIOS -~ // LOAO \\
d ~~-0
CALL HEAD CALCULATI D1i
---® CALL GEN RAMP ORI VE
READ READ BUFFER BUFFERS FROM FROM RTU CRT
G) CALL AGC DATA SUI
® CALL CALL PLANT RAMP RLC ADJUST DRIVE ALLOC
READ READ BUFFER BUFFER FROM FROM Fl LES I PPA AOC
G) CALL CALL CAPACITY CAPAC I TY CALCULATE CHECK
@ CALL AGC ALLOCATE
@ ® GEN GEN ALLOC ALLOC AGC EMERG
OUTPUT OITA TO RTU
OUTPUT TO
/ OUTPUT ' TD
I OUTPUT I TO
CRT BUFFERS
A!8!!.i. ALARMS GENERATED IN THE LOAO CONTROL Pf!OGRAM ARE SET 1• A PREVIOUSLY CLEAR TEMPORARY BUFFER, AT THE PROGRAM COMPLETION, THIS BUFFER SHOULD SET OR CLEAR EACH ALARM, THE ALARMS SHOULD NOT BE CLEAREO BY ANY OTHER PROCESS EXCEPT POWER-UP, TH IS ALLOWS THE Al ARM TO BE SET UNTIL TliE PROGRAM MO LONG€! DETECTS THE ALARM CONDITION. THE ALARM SHOULD BE TIME TAGGED AT THE COMPLETION OF THE PROGRAM.
IPA AGC PDAS BUFFER BUFFER
AGC MARGIN INAOEQIJATE AGC UNABLE TO MEET LOAD SCHEDULE AGC UNABLE TO MEET FUTIJRE LOAD SCHEDULE AVAILABLE LOAD CAPACITY INADEQUATE BPA RATE TOO LARGE BPA SIGNAL FAlLURE BPA SIGNAL NOT FOLLOWING RATE BPA SIGNAL TOO LARGE FREQUENCY SOURCE our OF SERVICE FREQUENCY OUT OF LIMITS LOAD CONTROL AT MAl'llUM EMERGENCY RATE WATE! CONSTRAIIT ON LOAD NOT MONITORED LOAD CONTROL IN EMEP.GENCY MODE LOAD CONTROL USING El!ERGENCY CAPABILITY
2 SECOND CLOCK
ELEV TAI LBAY r------- ---,
I
RTU 33 (l3S)
Kl28 POWER MW
1178 POWER MW)
I L V 1
Kl28 MW
I Kl78 MO
REAO DATA EVERY I 1 SECONOS OR LESS I L_ ____ __J
M 619-2~ REQUIRE MONITORING 2 BREAKERS (0 • ll92 AID 1196 OPEW, I • U92 OR ll96 CLOSED)
MASTER STATION LOAO MODE (step, ramp, rlc, age) POWER SETPO INT
PERCENT RATED MYA POWER STEP (NO, Of 1i STEPS)
MSLMA BUFFER
PS FOR
DATA
GEN POWER TO
RTU 1 S STE
SEMO DATA EVERY 2 SECONDS OR LESS
SIGNALS Flll)ll MASTER STAT! ON EXE CUTI VE
2 SECOND CLOCK RTU BAD SIGNALS MASTER STATION INITIALIZE TIME iPA AGC CHAMNEl OK GEN TAGS
~· I I READ / CLEAR y BUFFER H BIIFFfR I TEMPORARY , FRO!< FROM / ALARM f,POAS ~~ BUFFER
G) (j) Ci) CALL CALL /'"CALL BPA f'LAHi ~DE SIGNALS MOOE DI SPLAY
G::rm~ Ri~ t E IN VARIABLE UEFINITIONS
DAU TO LOAD CONTROL FORMAT
SPA RATE * BPA SIGNAL fliEQ 500 GEM CRT RATE GEN CRT STPT * GEN MW GEN NORM CAP MSLMO NET GEN PLANT MODE CRT PLANT RATE ''"
GEN POWER STEP '' PLANT STPT * TOT GEN SUB
DATA TO GENEUTIOM .StJM4ARY FOR'M4T
1 AGC MARG DECREASE I, AOC MARG INCREASE ' CAP AVAIL
CAP INC EMER OVLD ' CAP OFF LINE AVAi L.
CAP OM LINE RESERVE CAP WITHOUT EMER OVLD EMER RESERVE CAP NET GEN
CALL GEN RTU TH£ BUFFERS
PREDICTED AOC FOR RAMPS RLC MW
REF
@
OUTPUT TEMPORARY ALARM /---{?) l!UFFER TO ALARMS
ALA81! BUFFER
I
LOAD CONTROL USING ROUGH ZONE CAPABILITY
MO GENERATION ON AGC SPINNING RESERVE INADEQUATE TAI LBAY DROP CAUSED AGC TO STOP
OVERRIDE POSS l BLE TAILBAY DROPPING TOO RAPIDLY CHECK SUBSTITUTION GENERATION
BEFORE US ING LOAD CONTROL PLANT RE~VED FROM BPA CONTROL
OITA TD ANO FRO!! BPA AOC CHANNEL
BPA SIGNAL 8PA RATE
BPA STATUS NET GEN
S <NCE THE LOAD CONTROL PROGRAM MAY BE INTERRUPTED TO PROCESS OTHER TASKS, ALL DATA USED BY THE PROGUM SHOULD BE READ FROM THE "DATA BASE" TO A BUFFER USED OMLY IY THE LOAD COMTROL. THE DATA CAN THEN IE USED WITHOUT CHAMGES TO THE DATA FROM OTHER TASKS. lO!lEH THE LOAD CONTROL IS COMPLETrn, THE DATA GENERATED IN THE PROGRAM CAN BE USED TO UPDATE THE "DATA BASE."
DATA TO POWERHOUSE DATA ACQUISITION (PDAS)
SPINNING RESERVE STEP MW
l TOTAL GEfil MW · TOTAL SS MW
AOC TOTAL MW RAMP MW
DATA TO GENERATION SUBSTITIJTION FORMAT
RTU BAD SIGNALS " SUB GROSS HEAD SUB PUMP HEAD
DATA TO LOAD • HEAD FORMAT
GEN EMER CAP GEN LOWER RZ MW GEN MAX EFF GEN MAX NORM RATE GEN MW GEN NORM CAP GEN RZ RATE GEN UPPER RZ MW GROSS HEAD PUMP NEAD TA I LBAV DROP RATE
DATA TO LOA~ SCHEDULE FORMAT
2~ HOUR LOAD SCl!EOULE AGC MARG DECREASE AGC MARG I NCR EASE NET GEN
UATA FROM PDAS
MASTER STAT! ON
TOT GEN l!W TOT SS MW 2• HOUR
--+-CAP WITHOUT EMER OVLO CAP I NC EMER OVLD
CAP ON LINE RESERVE I LOAD SCHEDULE CAP OH LINE AVAIL '
BPA RATE
(MW/~111)
BPA STATIJS C oo P off
NET GEN
(MW)
BPA COll4\JNICATION
CHANNELS
POINT POINT POINT l'OlNT POI NT PO !NT 2 12 13 lij 15
* INDICATES COLOR CONTROL
POINT 25
DATA SUFFERS
DATA FROM LOAO CONTROL FORMAT
GEN CRT RATE· GEN CRT STPi GEfll POWER STEP MSLMO PLANT HOOE CRT PLANT RATE PLANT STPT
STOP AGC CONT OVERRIDE WATER CONSTRAINT
DATA FROM GENERATION SUll!ARY FORMAT
AOC MARG DECREASE STPT AGC HARO INCREASE STPT CAP AVAi L. STPT MAX PLANT LOAD RATE MU PLANT UNLOAD RATE SPINNING RESERVE STPT
DATA FROM GENERATION SUBSTITUTION FORMAT
SUS GEN MW SUB GROSS NEAO SUS LOAD SUB P/G MW SUB l'IJMP HEAD SUB SS GEN
DATA FROM LOAO - HEAD FORHAT
GEN NORH RATE MU TA I LBAY DROP RATE
DATA FROM VOLTAGE CONTROL FORMAT
STOP AGC CONT
OITA FROM PERHANENT F! LES
FMAX Fl41M GEM A GEN B GEH C GEN GOV TIME GEIi MAX NORM RATE GEN MVA RAT! MGS GEN RZ RATE
1222-PS-401
Figure 2. Master Station load control-Interface definition.
11
SUBRDUTINE REFERENCE NO,
CALLED FROM "LOAD COIITRDL"
SUBROUTINE UFERENCE NO
CALLED FROM "LOAD CONTROL"
4--355' SUB PUMP HEAD 4--362'
MSLMA 4--ttep MSLMD ,..__ atep
for al I bad
RTU'S
IOI) GEN 1111 OLD TD SUB GEN MW for each RTU
chan ed to bad
"CHECK SUBSTI TUTI OIi GENERATION BEFORE USING LOAD COIITROL •
NOTE: Initializing tho SUB GEN 1111, SUB LOAD, SUB P/G 1111, SUB SS GEN
Then values should be initialized to zero when c0111puter sy1tM1 is initially loaded, They should not be inittalize<I to a new value on p°'"er .. up but 1hould retain the val11e used before the p01i1er-down.
GROSS HEADSUB GROSS HEAD PUMP HEAP,..__ SUB PUMP HEAil fil1.lAl SUB GROS! HEAD SUB PUMP HEAil
IN RED
SUB GROSS HEAD 4--GROSS HEAD SUB PU14P HEAD ,._PUMP HEAD .illWl'.. SUB GROSS HEAD SUB PUMP HEAD
IN GREEN
CALCULATE FOR Gl-2~*and P/G 7,-a''(FOR ALL STATUS ANO ALL MODES)
GEN LOWER RZ 1111 GEN UPPER RZ MW GEN MAX EFF GEN NORM CAP GEN EMER, CAP GEN GATE CAP
The forfflula for a H 6 cues above it
FOR GI •2ij: MW -liGEN A) ' (GROSS HEAD)]• (GEN 8)
o, 1111 -(GEN C) WHICH EVER IS SMALLER
FOR P/G 7.5: 'IW....:-.{(GEN A) ' (~P HEAD)]• (GEN 8)
or MW-(GEN C) WHICH EVER I S SMALLER
GROSS HEAD..-- (fORE8AY ELEVATION - TAILBAY ELEYATION) IN FF.ET PUMP HEAD - (CANAL ELEVATION - FOKEBAV ELEYATION) IN FEET
GEN A, GEN B, GEN C WI LL BE SUPPL I ED BY THE GOY' T FOR ALL CASES AS SOON AS FI ELD DATA IS AVAILABLE.
NllfE: IF ND ROUGH ZONE EXISTS, GEN I, GEN BAND GEN C IRE O FOR GEN LOWER RZ 1111, ANO GEN UPPER RZ 1111.
for e4ch RTU changed to good
'"* frOlli P/G indicatH generator It pumping.
MDTE: When an RTU wu cOffllunicating properly (GOOD) during the lut pau of thfs routine, b1.,1t cannot now con,111.micate (BAD) during this pa.u, the RTU has CHAJtGED BAD. Likewise a BAD RTU during the ia1t pass which has recovered and has tent the UMIT POWER (GEM*) to the 11uter previous. to thi & pan. the RTU has CHlNG£0 GOOD. RTU*S bed at master Uation powerup cannot change bad unless they first recover to CHA*iED GOOD and vlsa-veru.
SUM LSI 1111 DLD • LS211110LD• LS3 1111 OLD
AND PUT INTO SUB SS GEN
AOO ( 500 KV.¥ I 1111 OLD
•500 KY#2 1111 OLD •kALS 1111 OLD •!BLS MW OLD •USBR ,i 1111 OLD)
TO SUB LOAD
SUBTRACT (500 KV'! MW • 500 KV#2 filtf +
ULS MW • KBLS MW + USBR ~I 1111)
FROM SUB LOAD
MOTE: If a bad RTU alarm ls not pro1/l-ded by other programs, the alarm ihould be included here to alum when the RTU CHANGED BAD.
* ALLOW FOR FUTURE GENERATORS G25-30 ANO PIG 9-12 tN THE DATA BASE ANO PROGRAMMING.
M.X HEAD
GRuSS HEAD lN FEET
for any bad RTU
RTU 25 bad LSI 1111 ...... 0
LS2 1111,......D LS3 1111 ,......0
0
bad •I filtf4---0
500 KY '2 1111•-0 KALS 1111 .,.___O KBLS 1111 .---o USBR ¥1 1111 .,._ 0
RTU 33 bad Kl2B 1111.,.__0
Kl781111.,.__0
: ROUGH ZONE
' I I I
I ,
PDNER IN MW
ACTUAL CURVE -- CALCUU TED CURVE
MO
RTU 25 good LSI 1111 OLD- LSI 1111 LS2 1111 OLD+-- LS2 1111 LS3 1111 OLD- LS3 1111
tllLZll. good SOO KY II MW OLD,..__
500 KV II MW 500 KY 12 1111 OLD-
500 KV 12 MW KALS 1111 0 LD--.-
KALS 1111 KBLS 1111 OLo--.-
KBLS 1111 USBR 'I 1111 OLD.---
USBR ,1 1111
RTU 33 good -rifli MW DL.O.,.__Kl2B 1111
Kl7B 1111 OL.0.,.__Kl7B 1111
RATED
TOT GEN SUB -SUB GEN 1111 , SUB P/G 1111
1222-0-402
Figure 3. Master Station load control-Head calculation and AGC data substitution.
13
00 fCR Gl-2ij* AN~P/678
MUMA.,...-- step MSLMO - step MLM step CLEAR FCS CLEAR GEN
POWER STEP CLEAR CHANGE
PLANT MOOE CLEAR MCS
MSLMA- rlc MSLMA- ram9 GEN STPT
GEN MAX EFF GEN UTE
GEN NORM ,ATE
SET MCS
•en, THE STEP MOOE SEQUENCE IS SHOWN ON "MASTER STATION VOLTAGE CONTROL"' "GENERATOR MOOE DETtl!l41NATION".
NOTE: * ALLOW FOR EXPANSION OF THE DATA SASE ANO PROGRAMMING AND FUTURE GENERATORS G25-30AN0 PIG 9 -12.
GE!i l'OWFR STEP
GEM POWER STEP
NO
ASSUME MSI...HD -= ramp
YES
CLEAR GEN
POWER STEP
MUI -MSLMA -MSUI)
YES
rafl'lp ..soo-- ramp SET MCS
MSLMA- ramp
MLM ........,.__._ s.top GEM STPT- 0 GEM RATEGEN NORM RATE SET MCS
MSOO MSLMO
MUI MSUID SfT MCS
MS!.* - age
Mli-1- start GEN STPT
GEN OPPER RZ MW
HM RATE..--. GEM NORM
RATE SET MCS kSLMA -- ramp
ML~ - age SET MSC HS!...'U- age
1222-PS-403
Figure 4. Master Station load control-Generator mode determination.
15
SUBROUTINE REFERENCE NO.
CALLEO FROM "LOAD CONTROL"
SUBROUTINE REFERENCE NO.
CALCULATE
TOT GEN MW (PDAS POINT IA) - G~La GEN MW + SUB GEN MW + LS I MW + LS2 MW + LS3 MW + SUB SS GEN + [Pis GEN MW] + SUB P /G MW GI PG7 ,JG STATUS = GENERATE
TOT SS MW (POAS POINT 2A) +--- LSI MW+ LS2 MW+ LS3 MW+ SUB SS GEN+ Kl2B MW+ Kl7B MW+ 500 KV Ill MW+ SOOKV 1;2 MW+ KALS MW+ KBLS MW+ USBR /II MW+ SUB LOAD
NET GEN (TO BPA AGC) -- TOT GEN MW - TOT SS MW m m P~
Gr GEN MW] ML.M =step+ G~ GEN MW] MLM = off + PrG7 GEN MW] (MLM = step o, off AND P/G STATUS= •eae,ate) + SUB GEN MW+ SUB P/G MW STEP MW --
CALCULATE P/GB
AGC TOTAL MW - :::; GEN MW] GI MLM = age
NO. OF AGC GEN --P/GB G~ (generator count)] MLM = age
RLC MW - P~B GEN,..] GI MLM = rlc
RAMP MW - P~B GEN MW] + P~B GEN ... ] GI MLM = ramp GI
CAP WITHOUT EMER OVLO (POAS POINT 12)-- P~B GEN NORM CAP] GI
+ P~B GEN MW] MLM = stop GI MLM = start
+ RLC MW + RAMP MW + STEP MW MLM = age
CAP INC EMER OVLD (POAS POINT 13)-- P~B GEN EMER CAP] + RAMP MW+ STEP MW GI MLM = age or rlc
CAP ON LI NE RESERVE ( POAS POI NT I~) ,-
CAP OFF LINE AVAIL (POAS POINT 15)-P(;B GI
P1:;B GEN EME• CAP] - RAMP MW - STEP MW GI (MLM = ramp or start or stop or step)
GEN NORM CAP] BREAKER STATUS = OPEN . and. RTU BAO = GOOD . and. GEN TAGS = OK
CAP INC EMER OVLO - NET GEN EMER RESERVE CAP (RI) -
SPINNING RESERVE (R2)-
CAP AVAIL (R3)---
EMER RESERVE CAP + CAP ON LI NE RESERVE
SPINNING RESERVE+ CAP OFF LINE AVAIL
P/GB AGC MARG INCREASE (R~) -- :::; GEN NORM CAP] - AGC TOTAL MW
GI Ml.M = age
AGC MARG DECREASE-- AGC TOT MW - P~GB GEN UPPER RZ MW] GI MLM = age
SCHEO CHANGE - SCHED LOAD] THIS HOUR ~ NET GEN
ADVANCE SCHED CHANGE-- SCHED LOAD] - NET GEN NEXT HOUR
P/GB PREDICTED AGC FOR RAMPS~ :::; (-GEN STPT)] + RAMP MW
GI Ml.M = ramp or start or stop
"SPINNING RESERVE I NADEqUATE"
NO
"AVAILABLE LOAD CAPACITY INADE(IUATE"
AGC MARG INCREASE
< AGC MARG I NC
STPT
YES
"AGC MA,GIN INAOEqlJATE"
YES
"AGC UNABLE TO MEET LOAD SCH EDU LE"
YES YES
"AGC UNABLE TO MEET FUTURE LOAD SCHEDULE"
NO
1222-PS-404
Figure 5. Master Station load control-Capacity and reserve calculations.
17
CALLEO FROM "LOAO CONTROL''
PLANT MOOE --
CLEAR CHANGt PLANT MODE
off
PLANT MOOE CRT - off CLEAR STOP AGC
CONT DISPLAY ~IGNAL ANO
BPA RATE IN GREEN
"llf'A RATE TOO LARGE"
FILTERED FRFQ
MO
"FRE11!JENCY SOURCE OUT OF SERVI CE"
BPA SIGNAL OLD - BP• SIIJNAL
PRIMARY FREQ -FREQ 500
PLANT MOOE -- plt
SET CHANGE PlAMT MODE
"BPA SIGUL FAILURE~
"PLAMT REMOVED FROM lll'A CONTROL"
~
PLANT MODE - plt
SET CHANGE PLANT MODE
~
"PLANT REMOiED FROM BPA CONTROL"
SPA S l GNAL ANO BPA RATE IN GREEM
BPA SIGNAL AND BPA RATE IN YELLOW
Dl SPLAY
BPA SIGNAL AND BPA RATE IN GREEM
•
1222-PS-405
Figure 6. Master Station load control-BPA signal checks.
19
SUBROUTINE REFERENCE NO.
CALLED FROM "LOAD CONTROL"
NOTE
CLEAR:
STOP ALLOC DOWN,
STOP ALLOC UP,
OVERRIDE WATER CONSTRAINT
"WATER CONSTRAINT A ON LOAD NOT NON I TORED"
THIS SIMPLE WATER CONSTRAINT ALGORITHM CAN IE EXPANDED TO INCLUDE NORE COMPLEX MONITORING SUCH AS GROUND WATER DAU, OR WATER FLOW AT A LATER DATE. THE CONTROL OF THE LOAD ALLOCATION IS AS FOLLOWS:
I. STOP ALLOCATION DOWN - THIS FLAG STOPS ALL ALLOCATION DOWN BUT NOT UP. IT MUST BE SET OR CLEARED BY TH IS SUBROUTINE. -
2. STOP ALLOCATION UP - THIS FLAG STOPS ALL ALLOCATION UP BUT NOT DOWN. IT MUST BE SET OR CLEARED BY THIS SUBROUTINE. --
3. CHANGE PLANT NODE - If PLANT NODE~- pit AND CIIANGE PUNT NODE IS SH, THEN IPA CONTROL IS REMOVED FROM THE PLANT.
UILBAY ELEV OLD ~ TAILBAY ELEV
CLEAR OVERRIDE WATER CONSTRAINT
TAILOAY DROP RATE --
NO (TAILBAY ELEV OLD - TAILBAY ELEV) ;r-~-.----+t TIME SINCE LAST 15 MIN UPDATE
A DROP IS POSITIVE
TAILOAY ELEV
SET
STOP ALLOCATION DOWN
"UIUAY DROP CAUSED AGC TO STOP - OVERR I OE POSS I ILE"
CLEAR
STOP ALLOCATION DOWN
CLEAR:
STOP ALLDCATIOII DOIM
OVERRIDE WATER CONSTRAINT
CLEAR:
STOP ALLOCATION
UP
1222-PS-406
Figure 7. Master Station load control-Water constraint algorithm.
21
SUBAOOTINE 0 REFERENCE NO B
PLANT IC>OE
CALLEO FROM "LOAD CON TAO L"
PLANT REF ---NET GEN
* ALLOW FOR EXPANSION OF THE DATA BASE AND PROGRAMMING
FOR 02.5-30 AND P/69-12.
PLANT
~~Of
PLANT NOOE ,....__ bpa
ASSUME CHANGE WAS FROM ERROR DETECTION
PLANT STPT ,....__ BPA SIGNAL PLANT' RATE ,....__ BPA RATE PLANT MOOE CAT +-- bpa COM PLT REF+---- BPA SIGNAL
DISPLAY BPA SIGNAL, BPA RATE
IN YELLOW PLANT STPT, PLANT RATE
Ill GREEN
bpa
YES
NO
PLANT STPT 4------ 8PA SIGNAL
NO
SET MCS
GI- ~
FOR P G 7
PLANT RATE+----------
MAX PLANT LOAD RATE
PLANT RATE 4-----
MAX PLANT UNLOAD RATE
NO
YES
PL.A.NT STPT,.____ PLANT REF
SET: MCS FOR ALL
G 1-2~ P G 7 B *
PLANT t«>OE +--- p It PLANT t«>OE CAT+---- bpa
DISPLAY ~ G NA L , BP A A ATE
IN RED PLANT STPT, PLANT
RATE IN RED
YES
PL.A.NT MOOE
pit
NO
PLANT t«>DE +-- p I t PLANT STPT +-
PLANT REF PLANT RATE +-- 0
PLANT t«)OE CRT...-pl t
DISPLAY PLANT STPT, PLANT RATE IN YELLOW
off
PLANT MOOE
pit
NO
YES
PLANT t«>OE 4--------------- off PLANT REF 4------ NET GEN PLANT STPT 4------ NET GEN PLANT RATE +---- 0 PLANT t«)OE CRT .,___ off
DISPLAY ~T STPT, PLANT
RATE IN GREEN
NO
<:LEAR CHANGE PLANT t«>DE PLANT STPT 4-------------- PLANT REF PLANT RATE+--------------0
01 SPLAY PLANT STPT PLANT RATE
IN YELLOW
DlSPUY
PLANT STPT PLANT RATE
IN YELLCllt
1222- PS-407
Figure 8. Master Station load control-Plant mode selection.
23
SUBROUTINE 0 REFERENCE NO.
CALLED FROM "LDAO CONTROL'
SUBROUTINE Q REFERENCE MO. V
CALLED FRON "LOAD CONTROL"
START 111TH GI
00 fOR GI-II, P/G 7-8*
STAAT WITH GI TOT RAMP REF .,_0 1-------,..c TOT RAMP RATE ... O
00 NEXT GEM.
P/G6 PROCESSED
YES YES
CLEAR MCS GEN REF - GEN MW GEN REF OLD- GEN MW GEM OERIV+-- 0 GEN RATE 3 - 0
* ll,LOW FOIi EXPApttS!ON IN TH£ DATE BASE ANO PROGRAMMING FOR G 2~ - 30 ANO P/G 9-12
MLM
off
YES YES
GEN STPT-0 GEN STPT ,..__ 0 GEN RATE-0 GEN RATE,.__ 0
.!fil!Af_ GEN STPT GEN RATE
IN GRE€N GEN POWER
STEP IN YELLON
DI SPLAY Gi:iis'TPT
RATE 4--IGEN RATE I
GEM RATE GEN POWER
STEP IN GREEN
GEN REF OLD --- GEN REF TOT RAMP REf 4-- TOT RAMP REF
+ GEN REF
T01 RAMP RATE -- TOT RAMP RATE • RATE
VES VES
DISPLAY DI SPLAY
GEN STPT GE, STPT GEN RATE GEM RATE
IN RED IN YELLOli G€N POWER GEN POWER
STEP STEP IN IN GREEN GREEN
YES
GEN STPT IN YELLOW
GEN RATE GEN POWER
STEP IN GREEN
GEN RATE..-O GEN STPT
...... -GEN REF
INREO GEN RATE GEN POWER
STEP IN GREEM
G€N REF +-- GEN REF • (RATE • Ttl<E) GEN DERIY,.__ RATE • GEN GGY TIME
TIME TIME SINCE U.ST PASS OF THE LOAD CONTROL ALGORITHM. IF TIME > • SEC, SET TIME.,_
• SEC.
GEN REF.,.___ GEN REF- (RATE • TIME) GEN DERIY+---RATE ' GEN GOV TINE
Figure 9. Master Station load control-Generator mode display and ramp driver.
25
SUBROUTINE REFERENCE NO.
CALLEO FROM "LOAD CONTROL"
CALLEO FROM "LOAD CONTROL"
NOTE'
~------------AVE PLT fG 4-------
P/G~ 2,GEN GOV T IMU
GI MU4=agc
COM PLf REF +-- NET GEN
DISPLAY ~ S TPT
IN RED PLANT RArE
R EN
RATE+--IPLANT RATE I
~------------------~* POWER ALLOC ___JCOM PLf REF
P/68 ~-[
-:5: GEN RE~-'7 ---... (MU4 = rMp or start or
stop) -STEP MW
P/G8 -~ GEN REij }
GI ----(MLM a rlc or age) ALLOCATOR DERIV +-- ror RAMP RATE • AVE PLf Tl.
NO
*
NOTE: MINUS SIGN FOR COUNTER RAMP
ERROR ALLOCATED 4--
POWER ALLOC - ALLOCATOR DER IV
* ALLOW EXPANSION OF fHE DATA BASE AND PROGRAMMING FOR G2~- 30 ANO P/G 9.12
NO
DD Gl-2• AND P/G7-8*
START 111TH GI
DO NEXT
GF.NERATDR
PLANT REF 4----- PLANT REF
• (RATE ' TIME)
PLANT OERIV ,..__.._ RATE '
AVE PLT TG
TIME rs TIME SINCE LAST PASS OF LOAD CONTROL ALGORITHM IF TIME > LI SEC,
SET TI ME ,...__ LI SEC.
PLANT REF 4----- PLANT REF
- I RATE • TIME)
PLANT DER IV +-- .RATE AVE PLT TG
ND
GEN REF --- GEN REF
• 1% • GEN MVA RATING
POWER ALLOC ---POWER ALLOC -
1% ' GEN MVA RATING
YES
PLANT REF -PLANT STPT
NO
YES
YES
NO
GEN REF ,.....__ GEN REF
-11, ' GEN MVA RATING
POWER ALLOC ,.....__ POWER ALLOr. -+-
I% ' GEN MVA RATING
PLANT OERIV +--0
PLANT RATE
4---0
COM PLT RU
..._ PLANT REF
+ PLANT DERlV
1222-PS-409
Figure 10. Master Station load control-Plant ramp drive and reserve load control adjuster.
27
CALLE!) FROM ·LOAD CONTROL'
SUBROUTINE REFERENCE MO.
CALLEO FROM 'AOC ALLOCATE'
(NO. 13)
SMALL GEM OM AGC -THE SIIALLEST 'GEM M'IA RATING"
WITH 141.M &9c
URGE GEM OM AGC -THE LARGEST ·GEN M'IA RAT I MG'
WITH MLM •9<
00 FOR Gl,2ij ANO P/G 1-11*
LOWEST GEM ALLOC -- I~ HIGHEST GEM ALLOC-- -60% CLEAR ALLOCATE FLAG START W 1TH GI
* ALLOW FOR EXPANSION OF THE DATA 8ASE AND PROGRAMMING FOR G2 5 -30 AND P/G9-12
CALCULATE FOR All GENERATORS WI TH MI.M , age:
GEN REF OIFF-GEJI REF GEJI REF OLD
GEM RATE I - GEM REF DIFF /TIME
GEM RATE 2 - GEM RATE a .fGEM RATE I-GEM RATE 3l ' TIME 8
(00 NOT UPOATE GEM REF OLD OR GEN RATE 3)
TIME , TIME SINCE UST PASS OF LOAD CDMTROL ALGORITHM. IF TIMf > ij SECONDS
RETURN TO 'AGC ALLOCATE' (MO, 13)
YES
SET TIME - ij SECONDS
MO
GEM REF OLD 4-- GEM REF AND
GEM RATE 3 --- GEN RATE 2 FOR All GEMERA)l)RS ,OTH MLM a9e or r1c:
CALL GEN ALLOC UC
"LDAO CONTROL 1 M EMERG MODE,.
GEJI REF ...,____ GEM REF • 1% • GEM M'IA RATING FOR "GEN MO. TO ALLOCATE"
ERROR ALLOCATED -ERROR ALLOCATED· I{ ' GEM MVA RATING
FOR "GD NO. TO ALLOCATE"
GEM REF - GEN REF ,It ' GEN MVA RATING FOR "GEN MO. TO AllGCATE"
ERROR ALLOCATED ...-ERROR ALLOCATED , 1% • GEN MVA RATING
FOR 'GEM NO. TO ALLOCATE"
YES
YES
LOWEST GEM ALLGC -[GEN REF 7 LiEM MVA RAT1i!lJ
SET ALLOCATE FUG GEN NO. TO ALLOCATE -
GENERATOR NUMBER
HIGHEST GEJI ALLOC -f":GEM R!:F 7 [g"'ifiii'TATI ~
SET A LlOCATE FLAG GEN NO. TO ALLOCATE -
GENERATOR NUMBER
1222-PS-410
Figure 11. Master Station load control-Automatic generation control allocator.
29
CALLED FROM "AGC ALLOCATE"
(MO. 13)
CALLED FROM "Elft'RG ALLOCATE"
CALLED FRON "LOAO CONTROL"
~--------------~* SMALL GEM D1i /.GC RLC ,..__
THE SMALLEST ''GU MYA RAT I fllG"
WITH MLM age or rlc
LARGE GEM ON AGC • RLC ...,__
THE LARGEST "GEN MVA RATIMG" WITH MIJf = age or rlc
CALCULATE FDR ALL GENERATORS WITH MLM age or rlc
GEN REF DIFF ..,.__._ GEM REF - GEN REF OLD
GEN RATE I ,..__ .. (GEN REF DIFF)/TIME
GEM RATE 2 •-- GEM RATE 3 + (GEN RATE I - GEN RATE 3) * TIME
TIME~ TIME SIMCE LAST PASS Of LOAD CONTROL ALGORITHM IF TIME:>14 SEC, SET TIME•- ij SEC.
DO FDR Gl-2~, P/G 7-6 *
LOWEST GEN ALLDC .,._ __ 150:( HIGHEST GEN ALLOC .,..__ -50%
Cl.EAR ALLOCATE FLAG START WITH G l
FILTERED FREQ+-·PR IMARY FREQ
CLEAR MASTER ST4TION INITIALIZE
OD
NEXT
GENERATOR
FILTERED FREQ ----··-- FI LTEREO FREQ
+ PR IMART FREQ * TIME 300 SECDMOS
OELTA FREQ ----FI LTEREO FREQ
HME = TIME SINCE UST PASS OF LOAD CONTROL. IF TIME>' SEC, SET TIME 4--ijSEC.
START
WITH
GI
DO FDR Gl-2'* P/G 7-6
DO
NOT
GENERATOR
YES
GEN BIAS --
DELTA FREQ * GEM GATE CAP 20 * 60 HZ
FrQJfl 5% droop
'I< ALLOW FOi! EXPANSION OF DATA BASE ANO PROGRAMMING FOR G2 5-30 AND P/G 9-12
"a
RETUR" TD "AGC ALLOCATE"
(NO. 13)
CALL GEN ALLOC
EMERG
GEM OERIV.,.__ 0
GEN REF --- GEN REF + 1% * GEN MVA RAT JNG FDJI <!GEN ND. TO ALLOCA.TE 11
,RROR ALLOCATED ---ERROR ALLOCATED
Ii, * GEM M'IA RAT! NG FOR "GU MO. TO ALLOCATE~
GEN REF "4------ GEN REF ti * GEM MVA RATING FOR "GEN NO. TD ALLOCATE"
ERROR ALLOCATED -ERROR ALLOCATED +
1% * GEN MVA RATIMG FOR "GEN NO. TO ALLOCATE"
PS - GEM REF + GEN BIAS+ GEN DER!¥ GEM MVA RATING
LOWEST GEN ALLOC .,.....__ GEN REF
GE" MVA RATl"G
SET ALLOCATE FLAG GEN NO, TO ALLOCATE -
GENERATOR NUMBER
HIGHEST GEN ALLOC --GEN REF
GEN MVA RAT ING
SE1 ALLOCATE FLAG GEN NO. TO ALLOCATE -
GENERATOR NIMBER
1222-PS-411
Figure 12. Master Station load control-Emergency allocator and RTU reference driver.
31
SUB FIRST SUB SUBS * REQUIRING OCTERMINING REQUIRING SIDRAGE INITIALIZING
IARRAi NAME DESCRIPTION SOURCE FROM DESTINATION USED IN SUBS SIZE CRT FORMAT
TO PREV ir,ff!AL POWER IN RTU CRT FILE'. RTU CRT PREV PRES PRES 1 " 111'1NG UP SUB 0JTPUT INPUT rtWTRn
ADVANCE
SUB FIRST SUB SUBS * REQUIRING DETERMININC REQUIRING STORACE INITIALIZING WlRAY NAME DESCRIPTION SOURCE FROM DESTINATION USED IN SUBS CRT FORMAT
TO ~ ~ITIAL POWER IN SIZE
RTU CRT FILES RTU CRT PREV PRES PRES •™nlNG UP SUB OOTPUT INPUT ccwmot
SCHED REQUIRED SHIFT IN MW TO MEET NEXT HOUR SCHEDULE CHANGE
5 ,.5 I FCS FLAG TO CLEAR STEPS FROM RTU FOR EACH GENERATOR 3 3 3 26
"' AGC MARG THE AVAILABLE MARGIN FOR DECREASING AGC COMMANDS " 5 ,.5 I ~ DECREASE
Fl LTERED FILTERED FREQUENCY TO PROVIDE RESET FUNCTI0HS IN HZ 6, 17 6. 17 I FREQ
AGC MARG X I GEN
DEC STPT SETP0INT FOR AVAILABLE MARGIN FOR DECREASING AGC C0~AN0S 5 5 SUMM FMAX, MAXIMUM AND MINIMUM FREQUEIICIES FOR AGC OPERATION IN HZ
6 6 X 2 FMIN (SET BY PR06RAM CONSOLE) m
AGC MARG THE AVAILABLE MARGIN FDR INCREASING AGC COMMANDS " 5 ,.5 I -l1!"l1, INCREASE SCHEO
FORE BAY ELEVATION OF DAM F0REBAY IN FT I I I I I X I ELEVATION (RTU 31, PO INT 18)
AGC MARG SETP0INT FOR AVAILABLE MARGIN FOR INCREASING AGC CD14!ANDS 5 s X I GEN lNC STPT SUMM
FREQ 230 SYSTEM FREQUtNO Ml:.ASURED ON THE 230 KV BUS I (RTU 29, POINT ) IN HZ 6 6
AGC TOTAL TOTAL ACTUAL PLANT POWER UNDER AGC CONTROL
" " " " " I GEN MW (4- sec calculat1on) SUMM
FREQ 500 SYSTEM FREQUENO J.IEASURED ON THE 50D KV BUS 6 6 6 I LOAD (RTU 30, POINT 106) IN HZ CONT
ALLOCATE FLAG INDICATING A GENERATOR IS AVAILABLE FOR ALLOCATION 13,15 13, I 4-, 15, 16 14-,10 I FLAG
FSU, FSD INHIBIT SPEED FLAG - STOP ALLOCATION UP FOR A ID, 12, 14-,16 GI VEN GENERATOR 52
ALLOCATOR RAMP DERIVATIVES TO BE ALLOCATED 12 I
DERIVATIVE
AVC PLT AVERAGE PLANT GOVERNOR TIME CONSTANT FOR GENERATORS 12 11. 12 I TG DN AGC
GEil A, GEil B. C0NSTAIHS FOR CALCULATING CAPABILITIES FROM HEAD DATA I I X 78 GEN C
GEN FLAG FOR GENCRATOR AVAILABILITY, NO TAGS, NO SPECIAL " I ::i~R~~I TAGS 26 AVAILABlITY CDIIDITIONS (0: NOT AVAILABLE, I : AVAILABLE)
BPA AGC SIGNAL FROM INTERFACE DETECTIN-G FAILURE OF CARRIER, ETC 6
(FROM AGC I CHANNEL ( I : BAD, 0 : GDDD) PORT)
GEN BIAS BIAS POWER FROM FREQUENCY IN MW 17 26
BPA RATE RATE OF CHAN-GE OF BPA LOAD SI-GNAL 6 6 6 6 6,B (FRDl1 AGC 6 I ~~~~ I\ PORT)
GEN CRT RATE FOR RAMPING GENERATOR FROM CRT LOAD LOAD /CDLDR RATE IN MW/HIN 9 9 9, 10 26 CONT CONT
FROM MODE
BPA 6, B ( FROM AGC 2 LOAD N SIGhAL, BPA LOAD S l GNAL 1 N MW 6
PORT\ CNTL DLD
BPA STATUS Of THE SPA AGC SIGNAL 6 6 (FROM AGC I LOAD I/DETER ~INES STATUS (C - GDDD, P : DO NDT USE) PORT\ CNTL COLOR
GEN CRT LOAD LOAD CDLDI STPT SETPOINT FOR RAMPING GENERATOR FROM CRT IN MW 9 9 9, 10 26 CONT CONT FROM
'/4DDE GEN DERIVATIVE FOR EACH GENERATOR IN MW 9, 10, 17 9 26 DERIV
BREAKER STATUS OF EACH GENERATOR BREAKER (OR BREAKERS) 3 3 26
STATUS ( I : ON LINE, D : OFF LINE) GEN CAPACITY OF GENERATOR AT GATE LIMIT OR I ILlX.
I " I '·" LOAD
EMER CAP WHICHEVER IS LESS, IN MW(! hr data) I 26 HEAD
GEN CAPACITY OF GENERATOR AT GATE LIMIT lN tiW ( I hr data) 17 GATE CAP I I, 17 I 26
CANAL ELEVATION OF CANAL TO BANKS LAKE 1N FT I I I I I X I
ELEV {RTU 31, point 21) GEN GENERATOR GOVERNOR TIME CONSTAtH \ 1 IN SEC.
10 10, 11 X 26 GOV TIME (THROUGH PRDGRA!I CONSOLE)
CAP AVAILABLE CAPACITY OF PLANT IN MW
" ,,5 " I GEN
" ,. 5 4-.5 AVAIL ( I m1 n calculation) SUMM
GEN LOAD LOWER BOTTOM BOUN0RY OF THE ROUGH Z0PlE I tl •!W ( I llr data) I 10 I I, 10 I 26 HEAD RZ tiW
CAP I
GEN AVAi L AVAILABLE CAPAC I TY SETPO I NT FOR THE PLANT IN MW 5 5 X SUMM STPT
GEN MAX MAXIMUM TURBINE EFFICIENCY LOA0 IN MW {I hr data) I 3 I 1,3 LOAD
EFF I 26 HEAD
CAP INC CAPACITY Of THE PLANT INCLUDING EMERGENCY OVERLOAD
" " " " " (SEND TO " I GEN EMER 0VLD IN MIi (5 SEC) (PDAS PDIHT 13)
PDASl SUMM GEN MAX MAXIMU•1 NORMAL RA~1PING RATE FDR LOADING A GENERATOR
13 13 LOAD
NDRH RATE (THROUGH PRDGRAH CONSOLE) 13 26 HE.AD CAP
CAPACITY OF THE PLANT OFF LINE ANO AVAILABLE " I ;~:~/D " I GEN OFF LINE " " " " AVAi L (5 SEC) (PDAS POINT 15) ( IN M•) SUMM
CAP CAPACITY OF THE PLANT ON LINE AND 1N RESERVE " " " " " (SEND TO " I GEN
ON LINE (5 SEC) (PDAS POINT '") ( IN MIi) PDAS) SUMM "'''""'
GEN MVA GENERATOR MVA RATING IN •4VA (THROUGH PROGRAt1 CONSOLE) 3 3, 12, 13, J 5, 17 26 RATING
CAP CAPACITY Of THE PLANT WITHOUT EMERGENCY OVERLOAD " " " " " (SEND TO " I GEN WITHOUT (5 SEC) (PDAS POINT 12) ( IN M•) PDAS) SUMM EMER OVLD
GEN l~W 3.,
LOAD GEN MW, POWER OF EACH GENERATOR IN MW FROM RTU 2 9 2 2 2,3. ,,9, 10 2 52
HUD OLD 9, 10 I~~~
CHANGE FLAG TD INDICATE THE PLANT MODE HAS CHANGED 3,6.B 3 I PLANT
MODE (D : ND CHANGE, I : CHANGE)
GEN LOAD LOAD POWER STEPS FDR CONTROL OF THE GENERATOR IN THE. STEP MOOE 3 3 9 3,9 3 26 CONT CONT STEP
COM PLT COMPOS I TE PLANT REFERENCE IN M'W 8, 11, 12 I REF
DELTA CHANGE IN SYSTEM FREQUENCY IN HZ 17 17 I FREQ
EMER EMERGENCY RESERVE CAPAC I TY OF THE PLANT IN MW
" I GEN RESERVE " " " " 4
CAP ( J min cal cul at ion) SUMM
ERROR THE ERROR THAT MUST BE ALLOCATED TD THE GENERATORS IN MW 12, 13. 14-,15,16 12 I ALLOCATED
NOTE: COLUMN HEADINGS ARE DESCRIBED ON THE "GENERAL LOAD AND VOLTAGE CONTROL" SHEET
* ARRAY Sli!E DOES NOT INCLUDE G25-30 OR P/G 9-12
1222 - PS - 412
Figure 13. Master Station load control-Variable definitions (sheet 1 of 3)
33
SUB FIRST SUB SUBS REQUIRING OCTERUNING ~ STrnAGE INITIALIZING Aff/A\ NAME OESCRI PTION SOURCE FROM tBTINATION
PRFV Pfi£S ~ USED IN SUBS SIZE CRT FORMAT
RTIJ CRT Fl LE! TO INITIAL POWER IN * RTU CRT - UP SUB OUTPUT N'IJT :xwTRCI
SUB FIRST SUB SUBS REQUIRING OCTE!M-llNG llEQUIRING STORt,GE INITIALIZING
~ NAME DESCRIPTION SOURCE FROM OCSTINATION USED IN SUBS CRT FORMAT TO 00 IIITIAL POWER '" RTU CRT FILES RTU CRT PREV PRES PRES LOllllNl UP sue * MPUT INPUT l"1'lrmn
GEN NORM "°RMAL GUO ATOR CAPACITY IN MW ( i HOUR OITA) I q I I, q, 1q, 16 I 26 LOll!
CAP fffl- MCS GENERATOR lllDE CHANGE STATUS O • "° CHANGE !•CHANGE 3, 8, 9 3 26
GEN NORM "°RMIL 6UERATOR START-STOP RAMP RATE IN MW/MIN 3 3 X 26 LOAD
RATE HEAD M4STER LOAD MOOE (step, raap, rlc, age. ste.rt,
3 3,q,9,10,11,12,
3 26 MLM stop, off) 3 13. lij, 15. 16, 17
GEN NUl4BER THE GENERATOR NUMBER FOR NEXT ILLOCITION 13. (ij, 15, 16 I TO ALLOC
IISU4A MASTER STATION LOAD MOOE(A-,TO RTU. B-+FROM RTU,O - LOIO LOAD IISLMB 2 3 3 3 2, 3 78 CONT CONT MSOO DISPLi\V (step, ramp, rlc, age) (I( (s-t1p,offl
GEN RUE LOADING RATE CALCULATED FOR LOAD RIMPS IN '4W/MIN 9 3 9 26 LOAD CONT
GEN RUE RATE LIMITING CALCUlATIONS FOR ALLOCATION IN NW/MIN 1.2,3,ij 13. ,q_ ,s. 16 ,oq NET GEN TOTU PLANT NET GENERHION IN MW NOT INCLUDING STATION ij ~.B, ll(TO SPA AGC 1 I
SERVICE LOAD
GU REF. 9.10
GENERATOR REFERENCE POWER IN MW 9, ,o 12, 13, 10 9.10. 12,13, I q, 15, 52 OLD 14, 15. 9 16: 17 16, 17
"°· OF NUMBER OF GENERATORS ON IGC ij, 6, II I IGC GEN
GEN REF GEN REFERENCE DIFFERENCE (PRESUT & PREV IRE BOTH NEEDED) OIFF, OLO 9.13 13, 15 IN NW
13 9. 13. 1; 9 52
GEN RZ GENERATOR ROUGH ZONE RUE IN MW/MIN (THROUGH PROGRAM 10 10 10 X 26 LOAD RITE CO>ISOI..E)
HEAD v•wHHt FLAG TO OVERRIDE WATER CONSTRAINTS 1 7 7 I ~"r ONSTRAINT
GEN STPT GENERATOR SETPOINT IN MW 9 3. 9, 10, 12 3,9 26
GEN TAGS TAG CONDITION OF EICH GENERATOR (i. SPECIIL CONDITION q f FROM MASTER 26 EXISTS. 0 • 01) STATION EXEC l
rLINT PLIMT RAMP OERIYITIVE IN MW " II II II I OERli
GEN UPPER GENERA TOR UPPER l!Ol!OH ZONE LIMIT IN MW (i HO\IR OITA l I, 3, I. 3. I I, 3, q, 10, I q 26
lOIO
RZ MW I ij, ID ij, 10 I HEID
PLANT MO!)[ MOOE OF TifE PLANT ALLOCITDR (off. olt, bi:;al 6 6 6 6, B, II, 12 2 6 I
LOAD GROSS HEAD GROSS HEID ON THE MAIN GENERATORS IN FT (I HOUR DATA) I I ' HEID
PLANT MOOE MODE Of THE PLANT ALLOCATOR DI SPLAYED ON THE CRT LOAD LOAD
CRT 6 6.8 6, B I CONT CONT (off, plt. bpa} <:OLOR :O,,T .. I
LOAD LOAD PLANT RATE PLANT RAMP RATE IN MW/MIN II II B. 11 8 I CONT CONT
(CllLOII: COITftO
HIOHEST HIGHEST GENERATOR REFERENCE (IN PERCENT) OF GENERATORS OM GEN ALLOC, 1q_ 16 I
IGC
PLANT R!F, POWER REFERENCE FOR THE PllMT JN * {orev ious date rtN;t.]
LOAD OLD II 8, II B, II II 6, 11 8 2 CONT
I.OolD LOAD PLANT STPT PLANT SETPOI NT IN MW 8 II 6, II I COMT CONT
>M••• ••mo
PO"l:R ALLOC POWER ALLOCATED CALCULUEO FOR THE ALLOCATOR IN Ill 12 I
PS POWER SETPOINT IN PERCENT RATED MVA ITO RTU) 17 17 17 17 17 26 UL$ !ti PO"l:R FROM XlAS ILBS STATION SERVICE FEED IN NW (Flllil! RTU 0 ULS MW 01.0 2 2 2. ij 2 2 q q !!P ~~ ... 28}. ALSO FROM LAST PASS. 0
PREDICTED FREDICTEO AGC REQUIREMENT FOR RAMPS IN PROGRESS IN GEN AGC FOR IN MW (I MIN DITA) q q, 5 I SUII! RAMPS
K12B MW POWER FROM K12B, kl7B STATION SERVICE FEEP IN MW 0
kl7B MW (FROM RTU 33) 2 2 2. ij 2 2. q 0 2
PRIMARY I REQUENCY OF THE 500 KV BUS IFTER CHECKS IN HZ
LOAD FREO 6 6, 17 I CONT
Kl28 Kw OLD POWER FROM 1128, 1178 STATION SERVICE FEED IN NW FROM 1178 MW OLD LAST PASS 2 2 2 2 2 P/G STATUS
PUMP/GENERATE STATUS OF P/6 7,8 (FROM MAST ER 2 f? ~ ~~il (FROM M4STER STl11JS om) 2, ij OITA)
LARGE GEN LARGEST GENERATOR RATING ON AGC IN MVA 13 I ON AGC
PUMP HEAD \ROSS PUMPING HEAD IN FT LOAD I I I HEAD
LARGE GEN LARGEST GENERATOR RATING ON EITHER AGC OR RLC IN MVA is I ON AGC-RLC
LOWEST GEN LOWEST GENERATOR REFERENCE {IN PERCEMT\ THU CIN BE Allot, jij, 16 ALLOC
LSI MW PONER FROM STITION SERVICE GENERATORS IN MW (FROM RTU 25) 2 2 2 2. ij 2 2, q 0 LOAD LS2 MW
LS3 MW ~ 3 CONT
LSI MW OLD POWER FROM STATION $ERV ICE GENERATORS IN MW RECORDED IN LS2 Kw OLD IN THE PREVIOUS PASS 2 2 2 2 3 1 s, MW ALO
MASTER FLAG INOICITING11iH!; 11H~rR STATION HIS POWERED UP FROM MASTER
STATION STATION 3,6,7.17 SET I ••m '" i I , POWER UP\ MAX PLANT MAXIMUM PLANT LOADING RATE IN MW/MIN 6 6, 8 X I GEN LOAD RATE SUMM
MAX PLANT MAXI- PLANT UNLOADING RATE IN MW/MIN 6 6, B X I Utft
UNLOAD RITE SUMM
MAX TAILBA MAXll«JM TAILHY DROP RATE IN FT /Ml N 7 1 X I LOAD DROP RATE HEAD
NOTE: COLUMN HEADINGS ARE DESCRIBES ON THE "GENERAL LOIO ANO VOLTAGE CONTROL" SHEET
* ARRAY Sl!E DOES NOT INCLUDE: GZ5-30 OR PIG 9-12.
Figure 13. Master Station load control-Variable definitions (sheet 2 of 3).
35
SUB Fl RST SUB REQUIRING [i;ERMNNG NAME DESCRIPTON SOURCE FROM TINATION
TO RTU CRT Fl••' IRTU CRT
TOTAL POWER ON RAMP CONTROL INCIUOING STOP ANO START RAMP MW ' MODES I~ MW
RA TE TEMPORARY RATE STORAGE FOR RAMP GENERATORS I TOTAL POWER IN THE PLANT •lTH RLC ( RESERVE LOAD COHTIOL)
I 4 RLC MW IN MW
RTU FLAG ro INDICATE WHEN .. RfU CAHN~! CO>t!UNICATE i I 2 ts I 2 6 BAD (0-0K, l=BAO) (RTU'; 1-31 .,. 33/
SCHED THE CHANGE IN nAHT POWER TO MEET THE PRESENT HOUR
I CHANGE SCHEDULE IN MW
SCH ED THE LOAO SCHEDULED FOR 24 HOURS IN MW LOAD {PDAS POINT 25)
SMALL GEN ON AGC SMALLEST GENERATOR MVA RATING ON AGC MOOE
SMALL GEN SMALLEST GENERATOR MYA RATING ON EITHER AGC OR RLC MODE ON AGC-RLC
SPINNING SPINNING RESERVE OF THE PLANT IN MW (I
RESERVE mfn data) 4
SPINNING SET POINT FOR SPINNING RESERVE IN ~., 5 I l!ESERVE
STPT
STEP "" TOTAL GENERATION OF ALL GENERATORS IN THE STEP UR OFF MOOE ' STOP AGC FLAG ro REMCVE THE PLANT FRO!! Alt LOAD CONTROL
i !
CONT (PLANT MOOE = OFF) 3 I
STOP ALLOC FLAG TD STOP ALLOCATION OF THE PLANT EITHER DOWN OR UP DOWN UP {O=OK, l=STDP)
STOP ST!lf" Fl.AG FR(l.4 R1U TO INOICATE A GENERATOR SHOULD UNLOAD 3 SIGNAL (O=OK, l=STOP)
SUB GEN MW SUBSTITUTE GENERATOR POWER FOR Gl-24 IN"" 2
SUB GROSS HEAO SUBS! ITUTE GROSS HEAD IN FT I I
SUB LOAD ~UBSTI run LOAD FRO~ STATION SERVICE IN !,fl>' 2
SUB P/G SUBSTITUTE PUMP/GEN POWER FOR PG 7/8 IN GEN MODE MW IN MW I
2
SUB PUMP SUBSTITUTE PUMPING HEAD IN FT I I I HE.AD ···-------~ ·-~ ... ~-.~ --~UB SS
pUBSTITUTE STATION SERVICE GENERATION i ~EN FOR LS-I 2 3 lh MW 2
TAI LBAY ! DROP TAI LBAY DROP RATE IN FT/~R 7 OAT<
TAI LBAY ELEV ELEVATION OF TttE fAILBAY IN FT (RfU 31 POINT 19) I I OLD -------
TIME TIME AND TIME DIFFERENCES CALCULATED FOR VARIOIJS P~!JGRAM TIME DtFF TIMING
TOTAL GEN 1-'W GROSS GENERATED POWER FROM THE PLANT !Pl MW ' TOTAL GEN SUB
TOTAL GENERATION SUBSTITUTION IN MW i
2
~OT TOTAL OF ALL RAMP RATES OF ALL GENERATORS IN l'!AMP RAU MW/MIN I
~OTAL TOTAL OF ALL RAMP REFERENCES OF ALL GENERATORS !N ~AMP REF MW
TOTAL SS TOTAL STATIOH SERVICE MW I • MW -----
I -------· USH <1! MW OIi USBR HO. I FEEDER ( RTU 2B) AND FROM
2 I MW OLD LAST PASS
500 l(y 500- KV STATION S£RV!C£ FEEOERS HO I AND NO. 2 IN MW (RfU 28) 2 l 'I '•2 MW
500 KV 500 KV STATION SERVICE FEEDERS NO. I ANO 110. 2 !H MW , I. ,2 MW,OL( FROM 1"E LAST PASS I
SUBJ I NI Tl ALIZING '1EQUIAING TO!OO USED IN SUBS
~ N!TIAI.. POWU IN
I PR> V PRF'- "'~"" UP sue
' 10
I : 4
I, 2,6,7 ,3
4, 5
4
13 !
15
' 4 ' 4,5 ! 4 l
i 5
I 4, 12
i I ti, 3
7 II 10 12 7
3
2 4 0
I X
2,4 u
2' ~ 0 i
I X _., ..
2,4 0
I ! 7 i
I ,7 I 1,7 I 1,7 X i I I
I FROM MASTER) 0, 5 1 I 0, 11, 12, I 3,
15 7 I X
' TO POAS POINT IA
I 2
' I 10 12 J 10 i
... TO POAS ! • f>OHH 2A i
2 2 2 2 4 ·-r+ 2 2 2 2 •
i
2 2 2 2 I
* (ARRAY
SIZE
I
I
I
32
I
24
I
I
I
I
I
I
2
26
I
I
I
I
I
I
I
2
?
I
I
I
I
l
2
2
2
CRT FORMAT
OUTPUT ltf~T CON'f"ftOI
GE, SUMM
~EN
SUIOI
GEN SUB
·-··- ~-
24 HRI
I SCHEO/
I I
GEN
SUMM
GEN SUMM
CEN SU>t!
\.OU
~
GEN ,.,,. GEN GEN SUB SUB I
GEN I SUB ,
GEH SUB
GEN GEN SUB 1 SOB
i GEN I SOB
LOAD ~EAD
!
GEN SUMM i LOAD
CUNT
I
I i
GEN SUMM
--
! --t- ......
I -
I
NOTE: COLUMN HEADINGS ARE DESCRIBED ON THE 'GENERAL LOAD ANO VOLTAGE CONTROL" SHEET
,;, ARRAY SIZE DOES NOT INCLUDE 625-30 AND PIG 9-12
1222-PS-414
Figure 13, Master Station load control-Variable definitions (sheet 3 of 3).
37
09/15/72 11:2~:18 • INVALID REQUEST
GENERATION TOTALS
TOTAL GEN "" = XXXXX TOTAL SS "" XXX
NET GEN "" = xxxxx xxxx xxxx xxxx xxxx
AGC l«JOE MW RLC MODE "" RAMP l«JOE "" = STEP MOOE MW =
RESERVES
EMERGENCY RESERVE SP INNING RESERVE CAPACITY AVAi LABLE
MARG INS
XXXXXtitl XXXXMW
xxxxx""
AGC FOR INCREASE = xxxx"" AGC FOR DECREASE = XXXXMW
PREn I CT IONS
PREnlCTEO AGC TOTAL FOR RAMPS = XXXMW
PLANT RATES
• MAX PLANT LOAOI NG RATE XXX ""/Ml M
• MAX PLANT UNLOAD I NG RATE = XXX MW/Ml N
GENERATION SUMMARY PAGE XX
CAPACITY TOTALS
CAPACITY WITHOUT EMER OVERLOAD= XXXXXMW CAPACITY INCLUO EMER OVERLOAD = xxxxx"" CAPACITY DN LINE RESERVE = XXXXXMW CAPACITY OFF LINE AVAi LABLE = XXXXMW
• SPINNING RESERVE SETPOINT = XXXXMW • CAPACITY AVAIL SETPOINT = XXXXMW
• SETPOI NT = xxxx"" • SETPDINT = xxxx""
CONTROL TREES
• ALARM XX • LIMIT XX
GENE RAT I ON TOTALS PREDICTIONS
VALUES SHALL BE TOTALS DF OUTPUT MEGAWATTS FROM EACH BUS AS
CALCULATED BY THE CPU,
(SEE NDTE I)
NOTES
GENERATION SUMMARY
CAPACITY TOTALS
"EMERGENCY RESERVE = MW", "AGC FDR INCREASE = """ ANO "SPINNING RESERVE= """ ANO KAGC FDR DECREASE = MW~ VALUES "CAPACITY AVAi LAB LE= MW" SHALL BE AS CALCULATED BY THE CPU,
VALUES SHALL BE AS CALCULATED BY THE CPU,
TO CHANGE THE SETPOINT, SELECT THE INDIVIDUAL POKE POINT OF
THE QUANTITY DESIRED,
GENERATION SUMMARY CONTROL TREE SHALL APPEAR
(SEE NOTE I)
PLANT RATES
TO ENTER A NEW RATE SELECT POKE POINT DF DESIRED PLANT RATE
I. DATA FOR THE DISPLAY IS AS FOLLOWS:
QUANTITY DISPLAYED
TOTAL GEN MW TOTAL SS I« NET GEN I« AGC l«JDE MW RLC l«JOE "" RAMP l«JDE "" STEP MOOE ""
CAPAC I TY WITHOUT EMER DVERLDAO CAPACITY INCLUDING EMER OVERLOAD CAPACITY ON LINE RESERVE CAPACITY OFF LINE AVAILABLE PREDICTED AGC TOTAL FOR RAMPS
EMERGENCY RESERVE SP I MN ING RESERVE CAPACITY AVAILABLE AGC FDR INCREASE AGC FOR DECREASE
VARIABLE
(TOTAL GEN MW) (TOTAL SS "") (NET GEN) (AGC TOTAL MW) (RLC MW) (RAMP "'1) (STEP MW) (CAP WITHOUT EMER OVLD) (CAP INC EMER OVLO) (CAP DN LINE RESERVE) (CAP DFF LINE AVAIL) (PREDICTED AGC FOR P.AMPS) ( EMER RESERVE CAP) (SPINNING RESERVE) (CAP AVAi L) (AGC MARG INCREASE) ( AGC MAP.G DECREASE)
1222-PS-431
Figure 14. Master Station load control-Generation summary-CRT format.
39
SELECTION OF POtE POINT OM
GENFRmON SUMMARY FORMAT
! SELECTED PO I NT
SHALL FLASH IN ITS MORMAL COLOR
TIME DELAY I I Tl ME DELAY I I ! SttALL I I( 10-60 SEC] I -1 START
GENERITll)!I SUMMARY
• ENTER STPT
r\ I I I I I • LOAD RATE SELECT DESl RED PRESS VALUE VIA "ENTER"' u I NUMERIC kEYS I I I I
• UNLOAD RATE
FORMAT POKE POIMT
• SPINN I NG RESERVE STPT • CAPAC !TY AVAILABLE STPT
AGC FOR INCREASE • SETPOINT AGC FOR DECREASE • SETPOINT
.MAX PLANT LOADING RATE
.MU PLANT UNLOADING RATE
If ACTION IS NOT TAKEN WITHIN
I TIME DELAY OE¥! CE SELECT I ON SHALL CANCEL ANO CONTROL TREE SHALL DELETE FROM FORMAT
PRESENT VALUE SHALL BE REPLACED I I POI NT SELE CTI OM SHALL CANCEL
I wl TH ENTERED VALUE AND CHANGE ANO CONTROL TREE SHALL DELETE SHALL BE OBSERVED ON GENERATION FROM FORMAT
SUMMAR'!' \:OR MAT I I {SEE NOTE I)
NOTES
I. THE VARIABLES REPLACED BY THE CONTROL TREE ARE:
VARI ABLE UNITS
(SPINN<NG RESERVE STPT) MW ( CAP AVAi L STPT) MW (AGC MARGIN INCREASE STPT) MW (AGC MARGIN DECREASE STPT) n (MU PLANT LOAD RATE) MW/MIN (MAX PLANT UNLOAD RATE) MW/MIN
1222-PS-432
Figure 15. Master Station load control-Generation summary-CRT control tree.
41
09/12/72 12:22: 1•
• INVALID REQUEST
MONITORED UNITS
LSI LS2 LS3 GI G2 G3 G• GS G6 G7 GB G9 GIO GI I 612 613 GIO 615 616 617 GIB 619 620 621 622 623 G2• PG7 PGB
MOH I TORED SS LOADS
500 KV SS I 500 KV SS 2 500 KV SS 3
KALS KBLS USBR NO I Kl7A Kl78
MON I TOREO Ht:.AD:i
PLANT GROSS HEAD PUMPI HG GROSS HEAD
GENERATION SUBSTITUTION FOR LOAD CONTROL
PAGE
SUBSTITUTE GENERATION
• G 1-2• TOTAL SUBSTITUTE MW = XXXX
• P/G7-B TOTAL SUBSTITUTE MW = XXX
• LS 1-3 TOTAL SUBSTITUTE MW = XX
SUBSTITUTE LOAD
• TOTAL STA SER SUBSTITUTE MW = XXX
SUBSTITUTE HEADS
• PLANT GROSS HEAD = XY.X FT
• PUMPING GROSS HEAD= XXX FT
CONTROL TREES
MONITORED HEADS
HE WORDS "PLANT GROSS HEAD" AND "PUMPING
GROSS HEAD" I H GREEN IF RTU IS BAD·
THE WO ROS IN RED IF RTU GOOO
(RTU BAD) RTU N0.31
MOH I TO RED UH I TS
UN IT HUMBER IN GREEN IF RTU BAD. UNIT HUMBER
IN RED IF RTU GOOD
(RTU BAO) RTU NO· 1-27
MONITORED SS LOADS
DESIGNATION IH GREEN IF RTU BAD. DESIGHATIDH IN
RED IF RTU GOOD
(RTU BAD) RTU HO· 28 AND 33
GENERATION SUBSTITUTION FORMAT
SUBSTITUTE GENERATION
TO CHANGE THE VALUE OF A PARTICULAR ITEM, SELEr.T
". G1-2, TOTAL SUBSTITUTE MW • ,. ". P/G7-B
TOTAL SUBSTITUTE MW= " OR ". LSl-3 TOTAi. SUBSTITUTE MW = ,. TO
ENTER HEW VALUE.
(SUB GEN MW) rsue P/G MWI rsue ss GENI
SUBSTITUTE LOAD
SELECT ". TOTAL STATION SERVICE SUBSTITUTE NII=
" TO ENTER NEW VALUE.
GENERATION SUBSTITUTION rORMAT CONTROL TREE SHALL APPEAR·
SUBSTITUTE HEADS
TO CHANGE THE VALUE OF A PARTICUI..AR ITEII, SELECT
". PLANT GROSS HEAD = FT" OR "• PUMPING GROSS HEAD=
FT" TO ENTER NEW VALUE·
(SUB GROSS HEAD) (SUB PUMP HEAD) THE HEADS ARE COLOR CONTROLLED BY "LOAD CONTROL"
1222-PS-427
Figure 16. Master Station load control-Generation substitution-CRT format.
43
SELECTION OF POKE PO I NT ON
GENERATION SUBSTITUTION
FORMAT
1 I
SELECTED PO I NT
I SHALL FLASH IN I TS NORMAL COLOR
rlTIME DELAY I !TIME DELAY I l SHALL I T ID-6D SEC) I START
GENERATION SUBSTI TUT I DH ....__
• ENTER VALUE
I I I SELECT DES I RED PRESS
I VALUE VIA
I I "ENTER" I NUMERIC KEYS
I IF ACTION IS NOT TAKEN WITHIN TIME I DELAY, DEVICE SELECTION SHALL I CANCEL AND CONTROL TREE SHALL
DELETE FROM FORMAT
I PRESENT VALUE SHALl BE REPLACED LJ I POI NT SELECTION SHHL CANCEL
I WI TH ENTERED VALUE AND CHANGE SHAL AND CONTROL TREE SHALL DELETE l BE OBSERVED ON GENERATION SUBSTI- I
I FROM CRT FORMAT
TION FORMAT
(SEE NOTE I)
I. THE VARIABLES USED FDR ENTRY ARE,
FDRMAT POKE PDINT VARIABLE UNITS
• Gl-2• TOTAL SUBSTITUTE MW isue GEN MW) MW • P/G 7-8 TOTAL SUBSTITUTE MW sue P/G MWl MW • LSl-3 TOTAL SUBSTITUTE MW isue ss GEN MW • TOTAL STA SER SUBSTITUTE MW SUB LOAD) MW • PLANT GROSS HEAD ( sue GROSS HEAD) FT • PUMP I NG GROSS HEAD ( SUB PUMP HEAD) FT
1222-PS-428
Figure 17. Master Station load control-Generation substitution-CRT control tree.
45
NOTES
I. T E "LOAD-CONTROL" PROGRAM CALr:ULATES:
FORMAT I.IEAOING VARlABLF. UNITS
LOWER RZ (GEN L17'1ER RZ MW) MW UPPER RZ (GEN UPPER RZMW) MW MAX EFF (GEN MAX EFF) MW
NORM CAPABILITY (GEN NORM CAP) MW EMER CAPAS IL ITY ( GEN EMER CAP) MW MAX NORM RATE (GEN MAX NORM RATE) MW/MIN RZ RATE (GEN RZ RAH) MW/MIN
TAILBAY OROP RATE (TAILBAY OROP RATE) FT /HR
THE TELEMETERED QUANTITIES ARE:
09/15/72 11,2ij,IB LOAD-HEAD CAP AB I Lill ES PAGE i ALARM XX • IHVALIO REQUEST LIMIT XX LOAD-HEAD CAPABILITIES
GROSS HEAD (GROSS HEAO) FT PUMPING HEAO (PUMP HEAD) FT
GROSS HEAD = XXX .UMPING HEAD= XXX HOURLY DATA
NORM ALL NORM EMER MAX START-STOP
UNIT MW GEN LOWER RZ UPPER RZ MAX EFF CAPABILITY NORM RATE RZ RATE RATE
• GI XXX xx, XXX xx, '" '" XXX XXX XXX
I G2 G3 Gij GS G6
t { SELECT "•:ALL" TO DISPLAY THE "GROSS HEAD", "PUMPING HEAD"
EVEr.Y UNIT QUANTITY SELECT INDIVIIXJAL UNIT POKE AHO "MW GEN" ARE TELEMETERED POINT TO DISPLAY ONLY AN QUANTITIES. ALL OTHER
INDIVIDUAL LINE OF DATA VALUES SHAI.L BE CALCULATED BY THE CPU· (SEE NOTE I)
MW GEN ( GEN MW) MW
2· THE LIMIT FORl~AT WILL REPLACE:
(MAX TAILBAY DROP RATE) WITH ENTRY TO THE UPPER LIMIT. THF. LOWER LIMIT IS NOT USED BY "LOAD CONTROL" ANO MAY HAVE A VALUE OF 0·
• G7 GB G9 GIO GIi Gl2
r ( Gl3 GI ij GIS Gl6 Gl7
SELF.c:T " • MAX TAI LBAY OROP SELECT ". LOAD CONTROL" TD TO CliANGE THE "NORM START-RATE = FT/ TO CALL UP LOAO CONTROL
STOP RATE II I SELECT THE
MIN" TO ENTER A HEW RATE POKE POINT OF H£
FORMAT DESIRED UNIT. GIB Gl9 G20 G21 G22 G2, l l 1 G2ij ,A PG7
x,\ x:~ x,\ PGB x,x "' ,,x "x "'
TRENDS, LIMITS, DATE AND LOAD CONTROL FORMAT TIME FORMAT SHALL APPEAR "LOAD-HEAD CAPABILITIES
IN PLACE OF THE LOAO-HEAO SHALL REPLACE LOAO-HEAO CDHTROL" CDHTROL TREE SHALL APPEAR
CAPABILITIES FORMAT CAPABILITIES FORMAT
( SEE NOTE 2 l
TAILBAY DROP RATE= XX·X FT/MIN • MAX TAILBAY DROP RATE= XX·X FT/MIN • LOAO CONTROL
CONTROL TRCE
12 2 2-PS-42 9
Figure 18. Master Station load control-Load-head-CRT format.
47
SELECT ION Of NORM START -STOP RATE POK£
POI NT ON LOAD-HEAD
CAPABI Cl TI ES ' FORMAT i
l I SELECT£0 POINT SHALL I
FLASH IM1~ NORMAL If ACTION IS MOT TAKEN WITHIN TIME
IME OHAY I _I TIME OELAY ~ 1
DELAY, POINT SELECTION SHALL CANCEL
SHALL ANO CONTROL TREE SHALL DELETE FROM
START I I( !0-60 SEC) FORMAT
LOAD-HEAD CAPABI LI Tl ES
! PRESENT IIORM START-STOP RATE SHALL SELECT START-STOP RATE VALUE V lA
H ~ POIHT SELECTION SHALL CANCEL AND
HUMERlC KEYS. START-STOP RATE CANNOT PRESS BE REPLACED WITH ENTERED VALUE. CONTROL TREE SHALL DELETE FROM CRT f----,,,
• NORM STARt..STOP l BE MORE THAN 'MAX NORM RATE" OR LESS "ENTER" CHANGE WI LL BE OBSERVED ON LOAO-HEAO FORMAT
THAN I MW/MIH CAPABILITlES FORMAT.
(6EN NORM RATE)
12 22- PS-430
Figure 19. Master Station load control-Load-head-CRT control tree.
49
09/15/72 11:2~:18 • INVALID REt)UEST
.ALL
UNIT
.LSI
.LS2
.LS3
.GI
.G2
.G3 ·G~ i ~~
G7 :~ I::.~
Gi2 Gl3
i~t.i Gi6 Gi7 GIB
iGi9 G20 G21 G22
.G23 .G2~
.PG7
.PGB
CONT MODE
STEP STEP STEP
STEP RAMP
RLC A C
STEP RAMP
RLC
STEP RAMP
MW LOAD MW CAP
!XX xx !XX xx !XX xx !XXX XXX
!XXX XXX
!XXX XXX
j l !XXX XXX
!XX xx !XX xx
• OVERRIDE WATER CONSTRAINTS
MW STPT LOAD RATE
XXX XXX
XXX XXX
XXX XXX
j I XXX XXX
xx xx xx xx
LOAD CONTROL
STEP
XXX XXX XXX
XXX
XXX
XXX
I XXX
xx xx
CONTROL TREES
NOTES
""'-n SYSTEM
• SYSTEM FREQ = XX· XX
NET GEN TO BPA
• ACTUAL = XXXXXMW
REQUEST
BPA------- ---- XXXX XMW
PROJECT--- • XXXXXMW
• PLANT MODE = XXX
RE LATED FORMATS
• GENERATION SUMMARY
• LOAD-HEAD CAPABILITIES
• GEN SUBSTITUTION FOR LOAD SUBSTITUTION MW= XXXXX
• SCHEDULE GENERATION
CONTROL
• AGC LOAD CONTROL OFF
• AVC VOLT CONTROL OFF
• TREND
I, DISPLAYED VARIABLES ARE:
FORMAT VARIABLE UNITS COLOR
CONT MODE (MSLMDI step, ramp, rlc, age YELLOW MW LOAD (GEN MWI MW YELLOW MW CAP ( GEN NORM CAP I MW YELLOW MW STPT (GEN CRT STPTI MW PROGRAM CONTROLLED LOAD RATE (GEN CRT RATEi MW/MIN PROGRAM CONTROLLED STEP (GEN POWER STEP} NONE PR06RAM CONTROLLED
l AUllJ.f ,x LIMIT XX
RATE
XXXMW/MI N
• XXXMW/MIN
• LIMIT
SELECT ". OVERRIDE WATER CDNSTAI NTS" TD ENABLE LOAD CONTROL
DURING LOW TAILBAY ELEVATION ALARMS
UNITS SELECT ". ALL" TO DISPLAY ALL QUANTITIES ON THE FORMAT
"UNIT LOAD CONTROL" CONTROL TREE SHALL APPEAR
SELECT INOIVIDIJAL UNIT POKE POINT TD DISPLAY ONLY AN IN
DIVIDUAL LINE OF QUANTITIES
ALL INDIVIDUAL QUANTITIES ALONG THE HOR I ZONTAL LI NE OF THE
SELECT I ON SHALL BE DI SPLA YEO
(SEE NOTE I}
"UN IT LOAD CONTROL" CONTROL TREE SHALL APPEAR
IF TRENDING OR LIMIT SETTING OF "SYSTEM FREQ" IS REQUIRED
SELECT POKE POINT AND ". TRENO" DR ... LIMIT"
(FREQ 500I
TREND, LIMIT, DATE, AND TIME FORMAT SHALL APPEAR
IF TRENDING OR LIMIT SETTING OF "NET GEN TO BPA" IS REQUIRED
ELECT POKE POINT OF ". ACTUAL" & ... TRENO OR ... LIMIT"
(NET GEMi
SYSTEM
BPA QUANTITIES SHALL BE AS
CAcm~T~Rof' p~~Rf:u-BPA SIBNALI
(BPA RATEi
CONTROL
SELECT POKE POI NT TO CHANGE LOAD CONTROL FR(lol AUTOillTI C TO MANUAL
"SYSTEM LOAD CONTROL" CONTROL TREE SHALL APPEAR
RELATED FORMATS
SELECT POKE MINT OF FORMAT DESI RED
SELECTED FORMAT SHALL IMMEDIATELY REPLACE LOAD
CONTROL FORMAT
"SUBSTITUTION MW= " VALUES SHALL BE AS CALCULATED BY THE CPU
SELECT POKE POINT OF PROJECT QUANTITIES TD ENTER NEW VALUES,
COLOR FROM PROGRAM
( PLANT STPTI (PLANT RATE I
( TOT GEN SUB I
SELECT ". PLANT MODE" TO ENTER A NEW MODE DISPLAY MODE IN YELLOW
1222-PS-422
Figure 20. Master Station load control-Load control-CRT format.
51
SELECTION OF SYSTEM FORMAT OR CONTROL POKE POINT OM
LOAD CONTROL FORMAT
SELECTED POINT SHALL FLASH IN ITS MDRMAL COLOR
SYSTEM LOAD CONTROL
• OVERRIDE WATR
• AGC LOAD OFF
• AVC VOLT OFF
• PLANT MOOE
• PROJECT STPT
IME DEU.Y SHALL START
tlME DEU.Y SHALL
RESTART
PRESS "EXECUTE" ;....-------1,;
SELECT DESIRED MOOE VIA ALPHA
NUMERIC KEYS
ENTER DES I RED STPT VIA NUMERIC
KEYS
ACT 1 OM SHALL BE INITIATED •
(SEE NOTE!)
PRESS ~ENTER''
PRESENT MOOE SHALL BE REPLACED WITH ;....---------ENTERED MOOE AND CHANGE SHALL BE
OBSERVED ON LOAD CONTROL FORMAT
PRESS ~ENTER"
, DO MOT CHANGE DATA ON FORMAT BUT SAVE FOR NEXT
ENTRY
SYSTEM RATE
• ENTER RATE
POI HT SELECTED SHALL CANCEL NO CONTROL TREE SHALL DELETE FROM CRTI
FORMAT
ENTER DESIRED R4TE VIA NUMERIC
KEYS
PRESS "ENTER"
REPLACE BOTH STPT ANO RATE OM THE LOAD CONTROL
FORMAT
(PLANT STPTJ (PLANT RATE)
NOTES
I. "ACTION" SHALL BE SETTING THE FOLLOWING VARIABLES.
FORMAT
• OV!RRI OF. WATR • AGC LOAD OFF • AVC \/llL T OFF
VARI 18LE
(OVERRIDE WATER CONSTRAINT) (STOP AGC CONT,) (SToP AVC CONT. J
1222-PS-423
Figure 21. Master Station load control-CRT control trees (sheet 1 of 2}.
53
SELECTION OF A UNITS POKE POI MT OM
LOAD CONTROL FORMAT
r SELECTED POINT SHALL FLASH I N I TS NORMAL
~""""'I COLOR Ir I ME DELAY I 1 :~:~ I ,(10-60 SEC)!
UN IT LOAD CONTROL ~ l
SELECT DESI RED VALUE I I PRESS I • u
i'"'" '" "' " " •• ~ / l VIA NUMERIC KEYS I / I "ENTER" I STEP
• CONTROL l400E
• MW SETPOINT (OIITROL 1400E. IF YES GO
' TD RAMP CONTROL
(SEE NOTE 2)
' ,I
( TIME DELAY SHALL
RESTART
RAMP CONTROL _/
I SELECT DESIRED VALUE I I PRESS I • ENTER SETPO I NT 7 VI A NUMERIC KEYS I I "ENTER" I
{SEE NOTE 2)
~ACTION IS NOT TAKEN WITHIN Tl OE LAY, OEV ICE SELECTION SHALL CANOEL & CONTROL TREE SMALL DELETE
FR~ FORMAT
PRESENT VALUE SHALL BE REPLACED WIT~ ENTERED VALUE & CHANGE SHALL
POINT SELECTION SHALL CANCEL ANO
BE UBSERVEO OIi CRT R>RMAT CONTROL TREE SHALL OHETE FR~ CR FORMAT
:~EE NOTE ll
'-
) RATE CONTROL
PRESENT VALUE SHALL BE REPLACED WITH ENTERED VALUE ANO CHANGE SHALL __/ • ENTER RATE _/ ,or BE OBSERVED OIi CRT um L RATE • 10 MW/MIN CONTROL VALUE HAS BEEM ENTERED.
~ • 30 MW/Ml N
• 60 MW/MIN J {SEE NOTES I & 2)
'
"'
,
• • • • •
NOTES
1- "lO, 30 ANO 60 MW/MIN" VALUES ARE "COMMONLY USED" VALUES ANO MAY BE CHANGED BY THE PROGRAMMER,
2, VAR I ABLES TO BE REPLACED ARE:
FORMAT VARIABLE UNITS
STEP (GEN POWER STEP) NOME
CONTROL l400E (MSLMO) step, ramp,
MW SETPOINT ( GEM CRT STPT) MW
ENTER SETPOINT ( GEN CRT STPT) MW
ENTER RATE (GEM CRT RAT!:) MW/MlN
rlc, a9t
1222-PS-424
Figure 21. Master Station load control-CRT control trees (sheet 2 of 21.
55
COll4UNICATION ~ MASTE'\,STATION
RTU 1-2~, 26, 27
MASTER ST AT I ON VOLT AGE MODE MSVMB (step, off )
IMMIR IT AU(' IIP fVII
(0 = NORM I= INHIBIT) INMIAIT AVr. nnw• FVD (0 = NORM I = INHIBIT) rtcJ.o STfPS FCS (0 = NORM I = CLEAR) ""'" vn1 TA'-E GEN
(KV) VOLTAGE IINIT uu,o GEN
(MVAR)
** MVAR
IINIT 00<0.co BREAKER (0 = OPEN I = CLOSED) STATUS ""°"" OTM
(0 = OFF I = STOP IN PROGF•SS)
RTU 28 ( 115 KV YARD)
CABLE 8 MVAR
(MVAR) 11 < KV RUS VOLTAGE
(KV)
RTU 29 (230 KV YARD)
KX29A AUTO TRANS MVAR (MVAR)
n:n ICU RIIS uni TAGf
(KV)
RTU 30 (500 KV YARD)
<00 KV BUS VOLTAGE (KV)
RTU 1-2~. 26, 27
MASTER STATION VOLTAGE MOOE (step, ave)
vn•TA•E SETPOINT (PERCENT RATED KV)
VOIT Ar., ST<PS
(NO. OF 0. 11, STEPS)
MSVMA
vs
GEN VOLT STEPS
BUFFER
FOR
OATA
FPOM
RTU'S
T READ DATA EVERY
6 SECONDS OR LESS
SEND DATA EVERY 2 SECONDS OR LESS
l BUFFER
FOR OATA
TO RTU' S
NOTE• IF THE RTU OR MASTER HAVE OTHER METHODS OF DETERMININ6 LOSS OF CO~NICATION THAN TO CHECK FOR A DATA UPDATE, THE DATA TO AND FROM THE RTU CAN BE TRANSMITTED ON AN EXCEPTION BASIS OR WHEN CHANGES ARE PRESENT.
* * G 19-2~ REQO I RE MON I TOR ING 2 BREAKERS (0 = XX92 AND XX96 OPEN, I = XX92 OR XX96 CLOSED)
(~~ 1
CALL EVERY READ 6 SEC. BUFFER
\, CONTROL ) FROM
~ RTU
USED FOR REFERENCE IN VARIABLE DEF IN IT I DNS
THE BUFFERS
-{ CALL
AVC GEN MOOE
~ OUTPUT
TO RTU
BUFFER
SINCE THE VOLTAGE CONTROL PROGRAM MAY BE INTERRUPTED TO PROCESS OTHER TASKS, ALL DATA USEC BY THE PROGRAM SHOULD BE READ FROM THE "DATA BASE" TU A BUFFER USED ONLY BY THE VOLTAGE CONTROL. THE DATA CAN THEN BE USED WITHOUT CHANGES TO THE DATA FROM OTHER TASKS. WHEN THE VOLTAGE CONTROL IS COMPLETED, THE DATA GENERATED IN THE PROGRAM CAN BE USED TD UPDATE THE "DATA BASE. "
ALARMS ALARMS GENERATED IN THE VOLTAGE CONTROL PROGRAM SHOULD BE SET IN A PREVIOUSLY CLEAR TEMPORARY BUFFER. AT THE PROGRAM COMPLETION, THIS BUFFER SHOULD SET OR CLEAR EACH ALARM. THE ALARMS SHOULD NOT BE CLEARED BY ANY OTHER PROCESS EXCEPT POWER-UP THIS ALLOWS THE ALARM TO BE SET UNTIL THE PROGRAM NO LONGER DETECTS THE ALARM CONDITION. THE ALARMS SHOULD BE. TIME TAGGED AT THE CIJMPLETION OF THE PROGRAM
I READ
BUFFER FROM CRT
CALL AVC PLANT
MOOE
OUTPUT TO
CRT BUFFER
I
f READ
BUFFER FROM Fl LES
CALL AVC CALC
[ ( READ
READ f- CLEAR BUFFER BUFFER TEMPORARY
FROM FROM ALARM PDAS EXECUTIVE BUFFER
_____ )5~,
( vo~~L~R I VE )
1 (23'
( CALL
MVAR DRl VE
_.-'------<_<~
/ CALL f-------- AVC CONTROL
OUTPUT TEMPORARY
ALARM BUFFER TO ALARMS
CLOCK
I I
SIGNALS FROM MASTE.R STATION EXECUTIVE
6 SECOND CLOCK RTU BAD SIGNALS MASTER STATION INITIALIZE PDAS BAD SIGNAL TIME
I
~
DATA FROM POWE.RHDUSE DATA ACQUISITION
SYSTEM (POAS)
115 SCHE.D 23D SCHED 500 SCHED
+---+---+--- - -
PRESENT HOUR SCHEDULES
PDAS FROM BPA
DATA BUFFERS
DATA FROM LOAD CONTROL FORMAT
STOP AVC CONT
DATA TO VOLTAGE CONTROL FORMAT
GEN MVAR 115 DAVC MSVMD 230 DAVC 5D0 DAVC CABLE B MVAR GEN VO:.. TAGE 115 KVOLT 23D KVOLT
115 SCHED* 23D SCHED* 500 SCHED., 115 STPT* 230 STPT* 500 STPT*
500 KVOLT KX26A MVAR 230 MVAR STEPS*
GEN VOLT STEPS* 115 MVAR STEPS* 500 MVAR STEPS*
* COLOR CONTROL
DATA FROM VOLTAGE CONTROL FORMAT
115 DAVC 230 DAVC 500 DAVC CABLE B MVAR
115 MVAR STEP 230 MVAR STEP 500 MVAR STEP MSVMD
MAX, MIN KX26A MVAR
MAX, MIN STOP AVC CONT GEN VOLT STEPS
115 STPT 230 STPT 500 STPT
DATA FROM PERMANENT FI LES
r-,_~-------<~ I ~~: ~~~T::~l:~TING KVK MVARK Bl.IS VOLTAGE RATINGS MVARS
DATA TD ALARM FORMATS
MVAR BETWEEN 115 AND 230 YARDS NOT MDN I TO RED
MVAR BETWEEN 23D AND 5DO YARDS NOT MONITORED
MVAR BETWEEN 115 AND 230 YARDS HIGH
MVAR BETWEEN 115 AND 230 YARDS LOW
MVAR BETWEEN 230 AND 50D YARDS HIGH
MVAR BETWEEN 230 AND 50D YARDS LOW
l 15 KV BUS AWAY FROM SCHEDULE 23D KV BUS AWAY FROM SCHEDULE 50D KV BUS AWAY FROM SCHEDULE
1222-PS-415
Figure 22. Master Station voltage control-Interface definition.
57
SUSROUT I NE REFERENCE NO,
CALLED FROM "VOLTAGE CONTROL"
GEN VOLT SETPOINT FCS AT MASTER FCS AT RTU
DD FDR Gl-2~ AND P/G 7,8*
START WITH GI
DO NEXT GENERATOR
POWER-UP IN Ill 4.LI ZE
MSVMD4---step
RTU CDl+4UNICATIDN LOSS
MVM +-- step
CLEAR FCS
SEQUENCE CHART FOR STEP MOOE
TABLE SHOWING THE SEQUENCE OF CHANGES IN THE PROGRAM VARIABLES
CRT
STEPS GI 0 G2 0
NOR!i4AL FORMAT FOR CRT
0 + 10 + 10 0 0 0 O O 0
CRT / ~ STEPS
GI + 10 G2 0
OPERATOR ENTRY THROUGH POKE POINTS AND CONTROL TREE (CRT DOES NOT CHANGE AGAIN UNTIL LAST STEP)
VOLTAGE CONTkOL
AVC GE, MODE
DATA IS PROUSSED
BY PROGNAli4
MASTER RTU ~
DATA IS TRANSMITTED TO RTU
EXCITATIDN SYSTEM
DATA IS PROCESSED
BY RTU
STEP MODE
IN
AVC >«!OE UI ITIALI ZE
(RTU CLEARS FCS)
RTU- MODE CHECK
MSVMD•-step CLEAR GEN VOLT
STEPS CLEAR FCS
RTU MASTER ~
RAMP STARTED I COUNT / 2 SECONDS WHERE I COUNT C
0, 1% VOLTAGE CHANGE
VOLT.AGE CONTROL
AVC GEN
~ODE
DATA ACKNOWLEDGE IS PROCESSED BV
PROGRAM
.I~
!+-20-.1 SECONDS
DATA ACKNOWLEDGE IS TRANS~I TTED TO MASTER AS GENERAToR BEGINS TO RESPDND
ND
_QjjfilY__
BREAKER CHECK
,s-------1 GEN VDLTAGEl l_GEN VOLT RATIN~
GEN VOLT STEPS IN GREEN
CRT
CRT FORMAT RETURNS TO
NORMAL
STOP CHECK AVC t,()DE CHECK
MiM
YES
MSlilVA - ave GEN PMVAR --
GE~INGJ CLEAR GEN VDLT
STEPS CLEAR FCS
* ALLOW FOR EXPANSION IN THE DATA BAH ANO PROGRAl,l~IW<i FOR G25-30 ANO P/G9-12
1222-PS-416
Figure 23. Master Station voltage control-Generator mode determination.
59
SUBROUTINE REFERENCEMO. 0
CALLED FROM "VOLTAGE CONTROL"
5D0 "4AVC -- off FOR Gl9 - 2•
MSVM.A --- step MSVMO -- step
CLE.AR GEN VOLT STEPS
MVM step
POWER UP INITIALIZE
115 MAVC off 230 MAVC off 500 MAVC off 115 STPT - l 15 KVOLT 230 STPT -- 230 KV!IL T 500 STPT -- 500 KVOLT
DI SPLAY 115 STPT, 2JOS TPT, 500 STPT,
111 SCHED, 230 SCHEO SOO SCHEO IN GREEN
ITERATION CONTROL - MVAR CLEAR MASTER STATION
INITI.HIZE CLEAR STOP AVC CONT 115 DAVC off 230 DAVC off 500 DAVC off
EMERGENCY OFF
500 KV BUS CONTROL MO DE
RTU 30 BAD
YES
CLEU 115 INHIIIIT UISE 115 INHIBIT LOWER 230 INHIBIT U!SE 230 INHIBIT LOW[R 50(') INl1191T UISE 500 1Jrll1181T LOWER
l 15 MAVC --- off FOR GI ANO G9 •lSVMA --- step flSVMO --- step CLEAR GEN
VOLT STEPS MV!l --- step
"MVAR BETWEEN I JS AND 230
115 KV BUS CONTROL MOOE
115STPT-115KVOLT
DISPLAY _1_1_5-STPT
115 SCHfD IN GREEN
YARDS NOT MON: TORE:D''
NOTE: IF NO OTHER PROGRAM ALARMS FOR PDAS BAD. AN ALARM SHOULD BE GENERATED HERE.
.ASSUME 500 OAVC = sch
500 MAVC b11c 500 MAVC --- sch ?00 ~TPT -- 500 3CHED DISPLAY
DISPLAY 500 STPT IN YELLOW 500 SCHEO IN GREEN 500 STPT. 500 SCH ED
IN YELLOW
NO
500 PKV - 500 KVDLT 50D RATINC
500 PSTPT --- 500 STPT SOC --RATi°N G
CLEAR 500 MVAR STEPS DI SPLAY 500 MVAR STEPS
IN GREEN
NOTE: + MVAR IS TO 115 KV YARD.
115 OAVC --- 115 MAVC rY_E_S _______ ...,~--230 OAVC --- 230 MAVC
500 OAVC --- 500 MAVC
ASSUME I I 5 DAVC :: ~ch
NO
115 MAVC b11c DISPLAY ~PT!NYELLOW
115 SCH ED IN GREEN
115PKV---
115 PSTPT--
115MAVC- sch 115 STPT--115 SCHED DISPLAY llSSTPT. I 15 SCH ED
IN YELLOW
115 KVOLT l 15 RATING
115 STPT Jl5 RATING
CLE.AR 115 tJVAR STEPS
NO
CI SPLAY 115 "4VAR STEPS 7lfcln.EN
" 1,4VAR BETWEEN 115 AND 230 YARDS LOW"
230 MAVC-+-- off FOR G2-8. GID-1B
AND P/G 7-8 t~SV~.A ----- step MSVMD -- step CLEAR GEN
VOLT STEPS UVM step
"MVAR BEH-1EEN A THE 230 AND 500 YARDS NDT MON ITDRED"
230 KV BUS CONTROL MOOE
I NH I Bl T LOWER INHIBIT RAISE
"MVAR BETWEEN 230 AND 500 YARDS HIGH''
ASSUME. 230 DAV(,::: sch
NO
230 MAVC b11c 230 MAVC --- sch
DISPLAY 2JOSTPT IN YELLOW
230 SCH ED IN GREEN
23D STPT -·-23D SCHEO DISPLAY 2JOSTPT. 230 SCHEO
IN YELLOW
INH I Bl T RA I SE INH I Bl T LOWER
"MVAR BETWEEN 23D AND IDO YARDS LOW"
23D <VDL T 23D PKV ---- 230ifAfiNG
230 PSTPT- ;;~ ~i¼G
CLEAR 230 MVAR STEPS
0 I SPLAY 230 1~VAR "fITPS I ti GREEN
NOTE: + MVAR IS TD 23D KV YARD.
12 2 2- PS-4 I 7
Figure 24. Master Station voltage control-Plant mode control.
61
SUBROUTINE REFERENCE NU "0 CALLED FROl4 CALC /
"VOLTAGE CONTROL"
SUBROUTINE 8 REFERENCE NO. @ -E
O.LLED FROl4 "AVC CONTROL'"
SUBROUTINE REFERENCE NO. @ CALLEO FROl4 '"AVC CONTROL'"
CALCULATf THE FOLLl.1,,ING:
NO. GEN.
NO. GEN.
NO. GEN.
NO. GEN.
NO. GEN.
NO. GEN.
115 AVAIL. +---The total
230 AVAIL.+--- fhe totai
500 AVAIL. +---The total
115 AVC UP+--- The tota 1
115 AVC DN +--- fhe tota 1
230 AVC UP+--- The tota 1
number of generators on the 115KY bus (GI and G9) with th~ir RTU Qood anci their unit breaker closed.*
number of generators on the 230 KV t-us (G2-8 GI0-18, P/G 7-8) with their RTU good and their unit breaker closed.
number of generators on the 500 KV t-us (G19-24,) ·,dth their RTU QOOO a~d their unit breoker closed.
number of generators on the 115 KV tius (GI and G9) with their ~VM = UC and FVU clear. * number of generators on the 115 KV bus (Gt arid G9) with their MVM = AVC and FVD clear, * number of generators on the 230 KV bus (G2-8. GI0-18, P/G 7-8) with their MVM-= AVC ano FVU clear.
NO. GEN. 230 AVC DN,.___ fhe total number of qenerators on the 230 KY bus (G2-8 GIO-ld P/G 7-8) with their MVM - AVC and FVD clear.
NO. GEN. 500 AVC UP,.___The total number of generators on the 500 KV bus (G19-211) with their MVM = AVC and FVU clear.
ND. GEN. 500 AVC DN,.___The total number of generators on the 500 KY bus (Gl9-211) with their MVM ~ AVC and FVD clear.
Sll4 PMVAR 115 UP .,...____The sum of Gen PMVAR for all generators on the 115 KV bus (GI and G9) with their MVM = AVC and their FVU clear. * SUM PMVAR 115 DN ,.___The sum of Gen PMVAR for all generators on the 115KV bus (GI and G9) with their MVM - AVC and their FVD clear, * SUM PMVAR 23D UP +----The sum of GEN PMVAR for all generators on the 230 KV bus (G2-8 Gt0-18 P/G 7-8) with their MVM c_ AVC and f:he,r FVU clear,
SUM PMVAR 230 DN .--- The sum of GEN PMVAR for all generators on the 230 KV bus (G2-b GI0-18 P/G 7-8) with their MVM-= AVC and their FVD clear.
SUM PMVAR 500 UP +----The sum of GEN PMVAR for all generators on the 500 KV bus (G19-211,) with their ~VM-= AYC and their FVU clear.
SUM PMVAR 500 DN +----The sum of GEJII PMVAR for all generators on the 500 KV bus (G19-211) with their MVM-= AVC and their FVD clear.
AVC
NO
GEN MVAR DIFF+---(- GEN PMVAR)
MK ---- M\IARS
YES
GEN MVAR DI Ff4--MVAR REF-
GEN PMVAR MK+--- MVARK
YES
VOLT CHANGE
NO
INHI Bl T RAISE .OR.
FVU SET
NO
NO
I NH I 8lT LOWER .OR
FVD SET
NO
y s
YES
UtHIBIT YES RAISE OR
FVU SET
NO
vs.__ vs +
GEN MVAR DI FF ' MK ' TIME
NO
INHIBIT LOWER OR YES
FVD SET
YES
vs 4---- vs +
VOLT CHANGE KVK TIME
NOTE: TIME-= TIME SINCE THE LAST PASS OF THE VOLTAGE CONTROL. IF TIME IS GREATER THAN 10 SECONDS, SET TIME -4--- 10 SECONDS.
NOTE ON GI OPERATION:
* OPERATION OF GI ON EITHER THE 1151<V OR 230KV BUS IS POSSIBLE. PREFERRED OPERAT10N MOOE JS NOT YET AVAILABLE JT IS POSSIBLE THAT SWITCHING GI FOR USE ON THE 1151<V OR 2301<V BUS MAY BE DESIRABLE.
1222-PS-418
Figure 25. Master Station voltage control-AVC calculation, Mvar driver, and volt driver.
63
SUBROUTINE REFERENCE ND.
CALLED FROM "VOLT CONTROL"
VOLTAGE OR MVAR
CHECK
TD MEXT SHEET
ITERA·TI DN CONTROL -
VOLT
115 KV BUS MVAR BALANCE
MVAR REF
(SUM PMVAR 115 UP ) + ND. GEN 115 AVC UP 115 MVAR STEPS
MVAR REF.
(SUM PMVAR 115 DN) • MO GEM 115 AVC DN
115 MVAR STEPS
500 KV BUS MVAR BALANCE
MVAR REF
(SUM eM~AR 500 UP ; NO. GEM SOD AVC UP.
500 MVAR STEPS
MVAR REF -(SU~ PMVAR ~QQ Dtt ) NO. GEN 500 AVC DN 500 MVAR STEPS
500
YES
INHIBIT RAISE -115 INHIBIT RAISE INHIBIT LOWER--115 INHIBIT LDWF.R
YES
YES
ND
CALL MVAR ORI VE
GI and G9 ONLY
SEE NOTE ON
GI OPERATION
ON 122-PS-418
INHI Bl T RAISE --500 INHIBIT RAISE
CALL INHIBIT LD-,.'ER+-- MVAR DRIVE
500 INHIBIT LDWfR Gl9-2ij OMLY
NO
YES MVAR STEPS
:'.': 0
CLEAR
YES
230 MAVC
OFF
I! 5 MVAR STEPS
CLEAR
500 MVAR STEPS
NO
230 KV BUS MVAR BALANCE
MVAR REF -
(SUM PMVAR 230 DN \ NO. GEN 230 AVC Dttf 230 MVAR STEPS
YES
INHIBIT RAISE -230 INHIBIT RAISE
INHIBIT LOWER ---230 INH t Bl T LOWER
CALL MVAR DRIVE
~--------' 62-8, GID-18 P/G 7-8
DNLY
NO
230 MVAR STEPS
$ 0
YES
CLEAR
230 MVAR STEPS
I222-PS-419
Figure 26. Master Station voltage control-AVC control (sheet 1 of 2).
65
FROM PREVIOUS SHEET
M..,__·-tiO. GEN 115 AVC UP
N.,._.IIO, GEM 115 AVC Ill!
N-MO, GEN 230 AVC UP
N-NO. GEN 500 AVC UP
M ,.__NO. GEN 500 AVC ON
115KV BUS VOLTAGE CONTROLLER
23OKV BUS VOLTAGE CONTROLLER
YES MO
NO
5OOKV BUS VOLTAGE CONTROLLER
YES •o
VOLT CHAMGE -( 115PSTPT-I I SPKV)
• KVGA!M INHIBIT RAISE -
115 IMHIBIT RAIS[ INHIBIT LOW~R ...,__
115 INHIBIT LOWER
YOU CHANGc{230 PSTPT-230 PKV)"
KVGAIM INHIBIT RAISE -
230 IMHIBFT RAISE INHIBIT LOWER -
230 JijHIBIT LOWER
VOLT CHANGE --(500 PSTPT •500 Prv)'
KVGAIM INHIBIT RAISE -
500 INHIBIT RAISE INHIBIT LOWER-
500 INHl!IT LOWER
CALL VOLT DRIVE
GI and G9 only
SE£ NOTE ON GI OPERATION ON 1222- PS- 4~8
CALL VOLT ORIVE
G2•B, GI0-18 P/G 7-8 only
CALL VOLT DRIVE
G!9-24- only
1222-PS-420
Figure 26. Master Station voltage control-AVC control (sheet 2 of 2l.
67
SUB FIRST SUB SUBS
~ REQUIRING DETERMINING ~RING~ INITIALIZING NAME DESCRIPTION SOURCE FRCM C6TINATION
PREV USED IN SUBS CRT FORMAT
TO .. Tljj_ PO\lfER IN RTU CRT FILE! RTU CRT PREV PRES~ ,-, UP SUS OUTPUT INPUT 'l>mWII
sue FIRST sue Sl.85 • DESCRIPTION
REQUIRING OCTERMINING REDUIRING S10Rti.iE INITIALIZING AfflAY NAME SOURCE FROM ll:STINATION USED IN sues CRT FORMAT TO
PREV PRES~ INITIAL Fl'.)ltER IN
SIZE RTU CRT FILES f!TU CRT ·""'"' uP SIil !llJTM~- _.,
8l!EUER STATUS DF T~E UNIT ~REAUP. Df &REA!£RS ( 0-0FF LI NE )
STATUS !-=Oft llME 20 20. 22 26 llS Mll'UUtttt , vnn no wv•• nos I% STEPS Df MVAR FOR CHANG I NO BUS VOLTAGE WHEN ON Meo 21 21 .23 3 I CONT $00 MVA. lffllJ
CABLE 8 INTERCHANGE FDR CABLE 8 (RTU 28) 21 21
VOLT MVAR ~VAR 21 I CDHT MVARS GAIN FOR NVAR CONTRU'. ~URING NORMAL STOP (NOIIMALL' !.O) 2q I 2ij X I
CABLE 8
nx~RMIN MVAR INTERCHANGE LIMITS FD~ CABLE 8 IN !!VAR 21
VOLT 21 2 CONT
MVM MASTER VOLTAGE MODE (step stq:1 ,ve off) 20 20 20 20 21 22 2q 2~ 20 26
ua me VOLT .VOLT AVC MODE FOR CRT DISPLAY OF 8US VOLTAGE(DFF M80. 8VC SCH 21 21 21 OFF 3 CDHT
1CONT 5-00 OAVC
N INTER~fDlATE NUMBER •N BUS VOLTAGE CONTROL 23 I
FVU FLAGS TD INH<BIT UP Oil INHIBIT DOIi!! FROM EACH RTU 22 22 2q 25 52 FVD (D=OK, l=INHIBIT)
MQ 60 I !Ii irflll MUNIER Df GENERATORS ON THE 115 230 Git 500 KV BUS tw&HHl>Mll ON-Ll NE 22 23 3 110 UM SOOMll
GEN It/A RAT ING RATING OF THE GENERATOR IN !!VA 20 20 X 26
NOtt:N11$~ NUMMR Of GENrRATDRS ON THE 115 230 OR 5-00 kV BUS ON ttGiUUOMC 11 AVC WITII CAPABILITY Of UP OR DOWN OPERATION i 22 23 6 NO G(M, $00
GEN MYAR GENERATOR MVAR OUTPUT 2D I 20 2q 26 VOLT CONT wm PERCENT VOLTAGE DH TIIE 8USES ! 21 23 3
GEN MVAR l 2q DIFF GEN NVAR DIFFERENCE FDR CONTROL I wnm PERCE!IT VOLTAGE SETPOI NT FOR THE IIUSSES 21 23 3
GEN PMVAR GENERATOR MVAR OUTPUT lN PERCENT 20,22 H 26
STATUS OF POWER SYSTEM STABLIZER OF EACH GENERATDR MASTEi ~ASTE! """Ttl' MASTER LOG! C VOLT VOLT
GEN PSS (llll.DFF) LOGIC OGIC LOGIC 26 CONT CONT I IS RATING
l~ Wl~! RATING Df TNE BUS VOLTAGES IN KV 21 21 X 3
GEN GENUATDR TERMINAL VOLTAGE IN KV 20 2P 20 26 26
VOLT VOLTAGE CONT
RTU BAO FLAG FDR LOSS OF COIMINICATIOI WITH THE RTU 20 20 29 ( D=Ok 1=8AO) RTU'• I .2q 26. ·30
GEN YDLT RATING RATING Of GENERATOR TERMINAL VOLTAGE INKV(l3Bor ISKV 20 ! 20 X ' 26
' GEN VOLT NUMBER DF STEPS TO CHANGE VOLTAGE FDR STEP MOOE STEPS (+raise_ --lower) 20 20 D 26
I 15 SCHED SCHEll!JLEO VOLTAGES FOR THE Ill$ FOR THE PRESENT HOUR VOLT
230 SCHED 21 21 (FROM PDAS) 3 CONT ""'""'" IN KV (FRCl4 PDAS)
' 115 STPT VOLT VOLT 230 STPT SETPOl NT FDR THE SUSSES IN kV 21 21 21 21 3 CONT CONT 500 STPT
INHIBIT INHl8!T RAISE DR LDWER FOR USE IN DRIVER SU8ROUTIMES f~ffi· (O=DK, l=INHl81T)
23 2q 25 23 2 STOP MVAR FLAG TO CAUSE l!YAR TO 00 TO D FOR UNLOAD ING n~~MYi.,)
20 :
20 26 i
IIS !IIHIIIT ltA1$E FlAG TO lllllCATE RAISE IN BUS VlllTNE SIOJU) NOT BE ALLIM!l 2:10 IM118l'T RAISE (il'>O«. i=INHl81T) 21.23 21 3 ~ 00!'81! ltAISE
STOP AVC YOLT FLAG TO CAUSE ALL VOLTAGE ANDl!YAR CONTROL TO SToP 21 21 I CGMT
CONT ~!t~ IISl!ffffBITUIW(ll FLAG TO lNlllCAT£ LOWER IN 8US VOLTAGE SHOULD NOT BE lOIMHtflf U)IIEI ALLDWEO (O=OI( !•INHIBIT) 21 23 21 3 I
,oo tf!:,oan lbfi1t
SI.MIPVVARfl$;~ SUM Of ALL PfRCEOT NVAR FROM CENERATDRS ON Ave FM $tlll'IIW.lUO EACH !!US 22 23 3 SUNNN!OO
ITERATlllH ITERATION CONTROL Tq CHOO$E BEr.EEN MVAR BALANCE ANO 21 23 23 21 23 CONTROL BUS VOLTAGE CONTROL 21 I
'!ME, TIME DIFFS TINE DIFFERENCES FRON MASTER STATION SYSTEl4 ( FROM MASTER)
AVC ALGOR I THN !
KVGAIN GON ON THE 8US FOR A VOLTAGE CHANGE 23 3 i KVK GAIN DF VOLTAGE SIGNAL FOR VOLTAGE CHAIIGES llt % PEfot
SECDHO 25 25 X I VAOJ RAISE RAISE AHD LOWER SIC.•ALS TO CHANGE VOLTAGE ON GENERATORS FROM FROM MASTER
S2 VQLT
VAOJ LOWER WITH R'L MODE (SIGNALS MUST HAVE CLOSE TIME) ~ASTE! LOGIC CONT
I 15 KVDLl V DL TAG ES DN THE I 15 230 and 500KV SUSSES IN KV 21 21 21 23 3 VOLT
ii 118H CONT VOLT CHANGE PERCENT VOLTAGE CHANGE NECESSARY TO CORRECT Ill$ VULTAGE 23. 2S 3
KX26A MVAR fLl)W ACROSS THE 230-500 KV AUTOTRANSFORMER 21 21 21 VOLT
MVAR I CONT
2q vs VOLTAGE SHPDINT IN PERCENT 25 20 2q 25 26
~UA LIMITS FOR MVAR FLOW ACROSS THE 200-SOOKV AUTOTRANSFORMll 21 21 2 VOLT
MAX.MIN CONT :
MASTER FLAG TD INDICATE A POWER-UP OF THE MASTER STAT! ON '
1mmm (DIFFERENT,,_ LOAD CONTROL) (IFOU~POWER UP) 20 21 X I
!!~=m MODE CONTROL FOR THE VOLTAGE 8USSES(DFF MBD.BVC SCH) 21 23 3 MAYC
NOTE:
MK INTERNEO!ATE MVAR BALANCE GAIN IN t PER SECDHD 23 I : COLUMN HEADINGS ARE OESCRl8£0 ON THE ~GENERAL LOAO AND VOLTAGE CONTROL" SHEET,
*•RRAY SIZE 00£S NOT IMCLUO£ G2,- 30 ANO PIG 9-12, MSVMA
ave) : 20 20 VOLT VOLT
~:118 MASTER STATION VOLTAGE MODE (dep :o 20 20 20 20 20 20 21 26 CONT CONT
NVARK GAIN Df MVAR SIGNAL FOR MVAR CHANGES (NORMALLY O, 5) 2q 2q X I i i i
MVAR PERCENTAGE REFERENCE MVAR FOR EACH BUS 2a 2q 3 I REF I
1222-PS-421
Figure 27. Master Station voltage control-Variable definitions.
69
UNIT VOLTAGE
UNIT MVAR KV MAN STEP MODE PSS i LSI :tX.l X. X !Xl STEP OFF
LS2 tX.X X. l !:XX STEP OFF LS3 tl.X X .X tu STEP OFF
- --' 61 tU xx.x tXX STEP AYC ON
62 63
~ Gij GS G6
' G7 G8
' 09 010 GIi
• 012 Gi3 GI~ 615 016 Gl7
__!!!_ !:XX xx.x ±XX AVC ON "!ffl n:Y !ff Sl"EP WI" r 620
.L J J 1 J 621 622 G23 G2~ -- -
i PG7 ±XX u.x '!XX AVC ON PG8 ±XX xx.x .tXX AYC ON
PAGE 31
8US VOLTAGE
• IIS • 230 • 500 llUS BUS llUS
SCHEOOLED XXX XXX XXX
• SETPOINT XXX XU XXX
• ACTUAL XXX XXX XXX
• MOOE MBO 8VC SCH
• llUS MVARS :!:.UJX !UXX :tx:xxx
• MVAR STEPS :xx !XX !XX
MYAR INTERCHANGE
MVHS UPPER LIMIT LOWER LIMIT
• 500 TO 230 YARD txlXX +XXU -XXXX
• 230 TO 115-YARD ±XXXX +XXU -XXXX
• EMERDENCY CONTROL STOP
• TREND • LIMIT
CONTROL TREES
SELECT •+ALL" TO DISPLAY EVERY UNIT QUANTITY, STATUS,
ETC.
MVAR ANO KV VALUES SHALL APPEAR AS TELEMETERED QUANTITIES
( GEN MVAR!,{GEN VOLTAGE)
"STEP" IN YELLOW OR "AVC" IN >ELLOW SHALL INDICATE PRESENT STATUS OF MOOE FEATURES (SU8ROUTINE)
(MSVMD)
VOLTAGE CONTROL
SELECT INDIVIDUAL UNIT POKE POIN TO DISPLAY ONLY AN INDIVIDUAL
LINE OF DATA
"VOLTAGE CONTROL" CONTROL TREE SHALL APPEAR
( KX26A MYARSJ AND THE (CA8LE 8 MVARS) SHALL APPEAR AS TELEMETERE
QUANTITIES
"ON" IN RED OR "OFF" IN GREEN SHALL INDICATE PRESENT STATUS OF POWER SYSTEMS STlBILIZER FEATUJ<E
(SUPPL CONT. J
"ACTUAL' VALUES SHALL APPEAR AS TELEMETERED QUANTITIES, ( H5K VOLT (230 K VOLT), (500 K VOLT)
"BUS MVUS" VALUES SHALL BE TOTALS OF OUTPUT MEGAVARS FROM EACH eus AS CALCULATED BY. TNE CPU. CALCULATION SHALL BE AS DESCRIBED IN THE SPECIFICATIONS PARAGRAPH THAT OESCR I BES THE VOLTAGE
CONTROL FORMAT
"SCHEDULED" VALUES SHALL 8E 01 S· PLAYED IN COLOR PROVIDED BY VOLTAGE CONTROL, ( 115 SCNED) (230 SCHEDI ( 500 SCNEO)
SELECT THE BUS ESI RED VIA THE POKE POINTS
"+ MODES" YALUES MAY 6E CHUGED BY SELECTED POKE POINT,
(115 OAVC) (230 OAVC
(500 DAYCJ
"+ MVAR STEPS" VALUES MAY BE CHUGEO IN THE MBO MOOE 0/ILY (COLOR
CONTROL)
"VOLTAGE CONTROL" COIHROL TREE SHALL APPEAR
( II 5 MVAR STEPS) (230 MVAR STEPS) ( 500 MVAR STEPS J
LIMIT SETTING SHALL 8E ACTIVATED 8Y SELECTlON Of DESI RED POKE POINT,'+ 500 TO 230 YARD' OR
" • 230 TO 115 YARD'
TRENDS, LIMITS, DATE, AND TIME FORMAT SHALL REPLACF. VOLTAGE
CONTROL FORMAT,
DATA ENTERED ON LIMIT FORMAT SHALL 8~ PLACED INTO:
( KX26A MVAR MAX J (KX26A MVAR Ml NJ (CABLE 8 MVAR MAX) (CABLE 8 MVAR MIN)
1222-D-425
Figure 28. Master Station voltage control-Voltage control-CRT format.
71
SELECTION OF UNIT BR BUS POKE POINT
N VOLTAGE CONTROL FORMAT
SELECTED UN IT OR BUS DESIGNATION SHALL FLASH
IN ITS NORMAL COLOR
VOL TA6E CONTROL
•sus STPT
.BUS VOLT MODE
•aus MVAR STEP
.UNIT VOLT MODE
.UN IT VOLT STEP
.STOP LOAD CD!lT
• STOP VOLT CONT
(SEE NOTE 2)
Tl~H~~~y ,_ ___________________ ___,.T( :~~~E~~) ,_ __ __,,. START
IF ACT!OH IS NOT TAKEN WITHIN TIME DELAY, POINT SELECTION SHALL CANCEL AHO CONTROL TREE SHALL D ET FROM FORMAT
PRESS
"ENTER"
PRESENT VALUE SHALL BE REPLACED WITH t------i.,..NTERED SfTPOI NT, CHANGE WI LL BE
BSERVED OH VOLTAGE CONTROL FORMAT
PRESS ; ACT! ON SHALL BE "EXECUTE" .------------..i INITIATED (SEE
NOTE l
(SEE NOTE 3)
POINT SELECT! OH SHALL CANCEL >-----~-& CONTROL TREE SHALL DELETE
FROM CRT FORMAT
NOTES I. "ACTION" SHALL BE THE SETTING OF THE FOLLOWING VARIABLE (STOP
AVC CONT) OR ( STOP AGC CONT). WE LOAD OR VOLTAGE CONTROL WILL CLEAR THE VARIABLES,
2. WHEN A "BUS" POKE POINT IS SELECTED ON THE VOLTAGE CONTROL FORMAT, DIILY ... BUS STPT" ANO " • SUS VOLT MOOE' SHALL APPEAR ON THE CONTROL TREE, BUT IF THE MODE IS'M80' THEN •• aus MVAR STEP' SHALL ALSO APPEAR ON THE CONTROL TRff
THE FEATURES SHALL BE INOEPENOENTLY SELECTABLE FOR EACH UNIT
3. VARIABLE SUBSTITUTED ARE: POKE POINTS VARIABLE UNITS
• l 15 KY BUS, • BUS STPT ( II S STPT) KV
• BUS VOLT MOOE ( 115 OAYC) off, mbo, bvc, sch
• BUS MVAR STEP ( I 15 M'IAR STEPS) NONE
• 230 KV SUS, • BUS STPT (?30 STPT) KV
• BUS VOLT MOOE (230 DAVC) off, mbo, bvc, seh
• BUS MYAR STEP ( 230 MVAR STEPS) IIONE
• 500 KV BUS, • BUS STPT (500 STPT) KV
• BUS VOLT MOOE (500 DAVC) off, •bo, bve, ,eh
• BUS MVAR STEP (500 MVAR STEPS) NONE
• GU DR P/GX, • UNIT YDLT MODE (MSYMD) step, ave
• UNIT VOLT STEP (GEM VOLT STEP) NONE
1222-PS-426
Figure 29. Master Station voltage control-Voltage control-CRT control tree.
73
GOVERNMET FURNISHED PDWERPLANT EQUl PMENT RTU EQUIPMENT ---
T~
: NET UNI
MIi
PERC ENT SVNCHRD GATE CONVERT POSI TION
PERC ENT SYNCHRD GATE CONVERT LIMI T
UNIT TRANS-VOLT AGE DUCER KV
NET TRANS-UNIT OUCER MVAR
' '
* _;U:;;N_IT;,_:_BR.;;E;_A.;;KE;_R__.l 1-----1---
UN I T MODE 3 POSIT IONS :
SELECTOR SWI TCHI
EL.[ .......... .. SPEED LDWER
" VOLTAGE RAISE
VOLTAGE LOWER I SIGNALS [ FROM RTU 3(\ SY~£!!011 I ZE ( 500 •v C()w,wl)l -
RECEIVERS 1--SP ... EE_D-..--M
VOLTAGE I RECEIVERS I---~--
YARD)
3 SEC
Fl LTER
FILTER
FILTER
3 SE Fl L TER
3 SEC Fl LTER
COUPLERS
ANO
FILTERS
H .......... .......... -.......... .......... ..........
Pl - PD•ER INPUT ,__ HARDWARE A-0
(PERCENT RATED MYA)
MULTIPLEX SOFTWUE GP GA TE PDS ITI OIi
AND I---,, SCALI NG (PERCENT GATE POSITION)
A-0 AMO
CONYERS I DN STORAGE (PERCENT GATE Ll~IT)
VI - VOLTAGE INPUT
(PERCENT RATED KV)
(PERCENT RATED MVA)
r r DUA ACQUISITION EVERY 2 SECONDS
DATA ACQU IS I Tl ON IS REQU I R<D BY OTHER SYSTEMS (2 SEC MAXIMUM)
! ! ' UN IT BREAKER HARDWARE tj SOFTWIRE
MULTIPLEX STORAGE (OaOPEN !•CLOSED)
MODE SELECT
*
(LOCAL MANUIL, LOCAL AUTD,5L>' SPEED RAISE
t---"i IIFMORM !•RAISE) I SOFTWARE SPEED LOWER HARDWARE ,._.....
( IFNDRM !•LOWER) STORAGE MULTIPLEX ,._..... VOLTAGE RAISE
( D•N~: uGt~:;.:: 1 i ,._..... I {O•NORH JaLo\iERj
SYNC. SPEED CHANGE ,._..... (RIISE, LONER, OFF) ,._..... SYNC, VOLT, CHANGE
(RAISE, LOWER, OFF) I I
DATA ACQUI SITl !)fl EVERY D. I SECDflDS AS CALLED BY CLOCK LOGIC
• 619-2~
G19-2!
ANAL DO DATA
TO CONTROL __, PROGRAMS
CALLEO SY
CL~CN
LOAD ANO VOLTAGE
CLOCK LOGIC
OUTPUT VOLT ORI VER CONTROL
J t PROGRAM ~+--+-----------_,, '*--- USES TIIE : OUTPUT DRIVER
s!:~~s _L., TD
CONTROL PRDGRli<S
r-so~WARE- 7 in!EN ENABLED
I SYNCHRONIZER I I Gl-18, PG 718 I I ONLY I L -- __j
CLOCK - 0.1 SECOND
{
INITIALIZE FLAG FLAG (0°NORH !•POWER UP)
"-- DATA __ ___;,;A..,;-D;..,;;;HA:;,:Sc.:;,;BE:.::E'"N ..;R;;:;E;;:AD'----1 TO SINCE LAST CONTROL PAS$
MASTER COMM. FAILURE CONTROL l; ---"""-=..;.;.....;;.._;.;,,;...,;;..__.
PIDORAMS (NO sm~1~i>Mii:o:Ih':Rio SEC)I
. ( DITA FROM 500 KV YARD NOT
EXECUTIVE
SYST!M
RTU
LOAD CONTROL
MASTER STAT! ON
DATA TO
CONTROL PR'lGRAMS
MASTER STA Ti ON
DATA :S--- FROM
CONTROL PROGRAMS
}
MASTER '--+-- srm OIi
DATA FR™
}
RTU '-------t--... FOR MASTER
}
CONTROL ,--+---- PROGRAMS
STATION
r
Rl\l
MSLMA
MSVMA COl44
PS INPUT
vs SOFTWARE
SSTEP
VS TEP
f RECEIVE DR SEND EVERY
2 SECONDS DR LESS
l MSOO
MSVMB
FSU Clllt4
FSD OUTPUT
FVU SOFTWARE
FVO
FCS
(dear after tranSl!ltssion
"
--
CO'MJNICATIDN TD MASTER STATION -MASTER STATION LOAD MOOE (St•p, romp, .f'lc, age}
MASTER STATION VOLTAGE MOOE (Step, ave1 POWER SETPOI NT (PERCENT RATED MVA) VOLTAGE SETPDINT
1 [PERCENT RATEO KV) • POWER STEP
( no. of 1% steps) VOLTAGE STEP {no. of O. It steps)
MASTER STATION LOAD MOOE
: ( step, of{) ; MASTER STATION VOLTAllE MOU<
( step, off') INHl81T AGC UP
, (0 , NORM !•INHIBIT) ' IHHIS!T AGC OOW!I
(O,NDRM l•INHIBIT) INHIBIT IVC UP (O••v•" I• I NHI Bl fj
INHI 81T AVC UOW!I (O•NO!!M '•INHIBIT)
I CLEAR STEPS "[ (O•NORM !•CLEAR)
f
UNIT POWER , (MW) i UNIT VOLTAGE
' ( •vi 1 UNIT MVAR
(MVAR) UN IT BREAKER '
(O•OPEN l•CLOSEO) NORMAL STOP
·iO•OFF l•STDP IN PROGRESS) UMPING (P/G 7-8)
f (O•GENERATE l•PUMP) i
NO LOAD CONTROL RESPONSE
NO VOLTAGE CONTROL RESPOIISE
lOCIL MANUAL
SPEED CHANGE OITA OUTPUT WHEN "OUTPUT DR I VER' IS CALLED
AVAILABLE - G19-2ij) I'
{ TIME DATA
r---- "'(piil"Nsl,c~w•u~,1---L ___ ---:;====::::__U--!------_)
SYNCHRONIZER ENABLE >l<>I< _______ ,_ r ___ _
MASTER }
ALARMS FROM
ALIRM BUFFER
; MVA EXCEEDS CAPACITY
GOVERNOR
5 SECOND TIME DELAY
DROPOUT i,,..IELAY
HARDWARE DRIVERS
~ OEENERGI ZE / ON FAILURE
-
1 D-A
SDFTWIRE
DRIVERS
SLR SPEED LEVEL REGISTER
CONTROL
OUTPUT FA>LURE
(0 FAIL,• PULSE O NO FAIL) FAILURE IF NOT PULSED EVERY 5 SECONDS OR IMMEOIHELY ON PO•ER FAILURE.
'
OUTPUTS FROM
CONTROL PRO GR IMS
EXCITATION SYSTEM
LOCAL MA NUAL G FOLLOWER ANO
MEMORY
/ ll-l (RTU COMPUTER FAILURE) VAR
.... ~--... ~, CONVERT DET~E-C-TO_R_::::_:V:.:LEA:::R:::;0:;:R ________ vOL_TA~G-E_A_D_Ju_s_T_R_E_._,s_T_;ER===--".C:...=----
DUTPUT NZ PERCE VOLTAGE VllLTS VOLT
AT - +IOY H.S •10~
EXCITATION SYSTEM
SPEED GITE OOTl'UT Gl-18, P/G 7-8 G19·2• LEVEL POSITION >OLTS VOLT LEVEL VOLT LEVEL •7.5~ 150% +!OY 15, 2KV 16.5KV
7 VDlTAGE CHANGE INTERFIICE OV 61.5 oi -1oi •IOV 58.5
+2.5'.( 50% ov 13,8KV 15.0KV -2. 5~ -50~ -IOV 12. !KV 13,SKV
>I< G-19-2• REQUIRE MONITORING 2 6REAlERS (D • XX92 AND XX96 OPEN, I a XX92 OR XX96 CLOSED)
FLAG DATA
\.._ TO CONTROL
PROGRli<S
(O•GFF !•START IN PROGRESS) NORMAL STOP
'(OoOFF l•UNLOIO FOR STOP) Al!NORMIL START
'(O•OFF l•START IN PROGRESS) SHUTDOWN ( G19-2•)
(O•OFF l•STOP IN PROGRESS) CONDENSING (G19-2ij)
(O•GENERATE l 0 CONDENSEJ PUMPING (P/G 7,8)
>I< >I<" G19-2q SYNCHRONIZE ENABLE MUST RE 08TA1"EO FROM RTU 30 IN THE SOOKV YlRJ.
UNIT
STARTING,
STOPP! NO
AND
STATUS
LOGIC
,. · { \.._ DAU TO
CO~TJ!OL PROGRIMS
'"" { '-- OAU TO
RTU
CAL 1 B '--om -} RTU
TL
XL
TV
xv
SELECT ,. CHANGE SELECT CHANGE
IN Pl
VI
FURN•SHtD N SYSTEM RTU EQUIPMENT -r------,,
CALIBRATION! I",___ +-,;;;;,;.,.;,"!!",!<;::,,..._~_
INPUT
SOFTWARE
• CALI UATIO! ----
SELECT OVTPVT SOFTW~!£
1222·PS·300
Figure 30. RTU load and volt.ige control-Interface definition.
75
CALLED FROM CLOCK EXE CUTI V EVERY 0. I SEC.
RTU POWER-UP INITIALIZE
NO
YES
LOCAL MANUAL MOOE
,---1 619-2~ ONLY
I I I I
SYNCHRONIZER CHECK
I I
I
I
I I
I I 1~-- I
I I L _____ _J
L Data cannot be obtained I 1, ... RTU 3(\,
I Loca~o~:~0
M n al or
I must be
LOCAL AUTO MOOE
Sn and Vn are being controlled by
the synchronizer using the output driver.
r--_j
I
I I I used
I "M"S°'"LM"'B,..._~-07 F"'F:--, ....,=,.,,.~-=-:----, I I
SUBSCRIPTED VARIABLES The subscript n indicates the present value of a variable. The subscript n-1 indicates the value used in the, previous pass.
ALARM BUFFER
The alarms sent to the master do not need accurate time tags, but they must not be repeated every 2 seconds. Thus, an alar111 buffer is used. The alarms required by the control routines should not be c-leared or set by any other routine except the Output Driver. Before the Output Driver is called, an alarm buffer is cleared. Theri the alarms set by the control programs are set in the buffer only. The Output Driver then sets and clears the alarms as necP,ssary.
I
L, I I I I
l_j
I
OFF
L_ - - --
I I I I L---,
I
I I I
NORMAL STOP FLAG
SET
NO
L _____ _
YES
----,
I I I I I I I I I
_J
UNIT BREAKER CHECK
619-2~ ONLY
~SLMB-Step MSVMB-Step CLEAR ALARM
BUFFER
I t
CONTROL PROGRAM Tl MING
MASTER STATION CHECK
STARTING INTERLOCK
STOP FOR STEP MOOE
Time: Time po111d 1lnce last past af this polnt1
'111111 time > O,S uc. 1 tl'ltn time - 0,5 ate,
- -, I
I I
I _____ _J
----,-~~--* .. ~--~---*'-, vn-- vn- l - 'HBt
' _ _£Q_NDENSI~ __
619-2~ O!ILY
MSLMB - Step LEAR ALARM BUFFER
CLEAR FVU
CLEAR FVO
Gl•IB ONLY
,-- ai 9.-; m 7 I CONOENSINO I I BELOW I
CONTROL PIIOOFIAMS
CLEAR ALARM BUFFER
>---------------CLEAR FSU
: P/6 7-B SEE I am rw
~U~I N~ '!::O~ _j CLEAR FYO
I
I I
_J
*Time= Time since last time algorithm was coiled, If time > 0.5 sec., set time .... 0,5 sec.
L_ - - - - - - - - - - - - - _J
I Z 2 2-PS-301
Figure 31. RTU load and voltage control-Clock logic sequence.
77
CALLED FROl4 "LOAO ANO VOLTAGE CLOCK LOGIC"
OBTAIN DATA
STEP AND CALIBRATE MODES
LCNTn-- 0
NOTE: VOLT CONTROL ROUTINE ~UST FOLLOW THIS ROUTINE TO ALLOW .FSU, FSD, ANO FCS TO BE SET OR CL EAREO IN THE COMM. OUTPUT SOFTliARE.
MODE CHANGE INITIALIZATION
LH - ogc
PS -- Pl PRn-1
PMn-1
PEn-1
CTn-1
OBn-1
ECTn-l CLEAR ECS CCn-1 -SET
CTSn-l -R~n-1 -Tos,_ 1 CLEAR CLEAR
Pl
0
FGL 2'TG 0 FJS 0 0 TIME-2 FSUA FSOA
YES
PROGRAM INITIALIZATION MAXIMUM POWER CHECK
GATE LIMIT CHECK
OLT - TIME -TOSn- I
TOSn - TIME
HSLMB- OFF
LCNTn - 0 LSTn -- 0 CLEAR FSG GPA -- GP+
(PM,_ 1 ' G,_ 1) SET
"HVA EXCEEDS CAPACITY"
NO
FSUA
ccn-1- 0 ECS - 2'TG SET FGL SET FSOA
SET CONTROL INTERVALS AND DEADBANDS
INTEGRATE MODELS
OHO -- DEA CTSn - CTT
A - PH,_ 1-(PM,. 1 ' OTL/TG)
1------------~REn - PRn_ 1-Pt-P~in-J
CALCULATE REFERENCE CHANGE
EXTREME ERROR CHECK
CHECK REFERENCE DEADBAND
RESET STOP FLAGS AND ERROR TIMING FOR SMALL ERROR
NO
D - PE,. 1-(PE,_ 1 ' DTL/TG)
ASSUME LM= romp or rlc
DEAD -DB,
CTS - TG
SET "NO LOAD CONTROL
RESPONSE"
NO
YES
ECS - 2'TG
TO NEXT SHEET
1222-P -302
Figure 32. RTU load and voltage control-Load controller (sheet 1 of 2).
79
NO RESPONSE ERROR CHECK
CTA-CTn-l
DTL
SEE NDTE DN PRECEDING PAGE.
DETERMINE CONTROL INTERVAL
PEn-- D
CTn-- CTA SE -- 0
Gn -- Gn-1
nn--o EA ..;,,_ RE-PEn-l
SR -- 0 PMn -- PMn-1
PRn -- PRn- I
CONTROL DEADBAND CHECK
SR-PC • Gn PMn-- A + PC
PRn-- PRn-l +PC
SEE NOTE ON PRECEDING PAGE
CALCULATE REFERENCE OUT PUT
GAIN STOP FLAG CHECK
UPDATE MODE LS
CALCULATE OUTPUT
CALCULATE NEW GAIN
NO
<O >O <O
GAIN LIMIT CHECK AND CALCULATE CONTROL ERROR
1222-PS-303
Figure 32. RTU load and voltage control-Load controller (sheet 2 of 2).
81
OBTAIN DATA STEP AND TEST MODES
Vn -- Vn .. 1 VCMT n ..... VCNT 11
SET OR CLEAR FSU, fSO, fVU. fVO. AND
FCS FOR COMM OUTPUT SOFT•ARE
MODE CHANGE INITIALIZE
NO
VCMT 0 ,.._ 0
NOTE-
ASSUME YM ave
Divide by 2 seconds
YCHT0 .,_
VST 0 ,...
OTV TIME -TOVn-1 TOYn - TIME
\1$T 11 - xv
Time_;' Time co!cuioted in the ''LOAD ANO VOLTAGE CLOCI< LOGIC11
VCNT0-0
FCS MUST BE CLEARED AFTER IT IS TRANS· MJTTED TO THE MASTER STATION BY THE COMM OUTPUT SOFTWARE.
VOLTAGE LIMIT CHECK
YES
CALCULATE CIRCLE DIAGRAM MVA CAPACITY
MVARC MVARL Ml'ARLL EXCC EXCL EXCLL
(MI/Vl) 2
(MVAL/Vl\ 2- (Pl/VI)' (MVALL/Vl) 2- {Pl/VI)'
I (Ml - MVO) /VI)' (E<R/Vl) 2• (PI/Vl) 2 (EXRL/'1)2. (Pl/VI)'
VOLTAGE CHANGE
VR 11 -
(VS • VI)"' V!
CHANGE UMI T
SET "MVA EXCEEDS CAPACITY'
SET • MVA EXCEEDS CAPACITY "
SMALL ERROR CHECK
IVR,,I) O, Jo/. YES
NO
VECn --Vn --.. Vn-1
VTn - VT0 _j
MSVMS -- OFF
VM - STEP
MSVM8 - STEP Vn Yn-1
SET
SET OR CLEAR fSU. FSO, FiU,
FVD, AMO fCL FOR COMM OUTPUT
"NO VOLTAGE CONTROL RESPON
SOFT'WARE
SET fSU ;ET fVU
SET FSU
SET fVO
NO RESPONSE CHECK
CALCULATE CONTROL
~n- Vn-1 +VR11
YT0 - Vl
MSVMS - OFF
1222·PS·304
Figure 33, RTU load and voltage control-Voltage controller.
83
CALLED FROM "LOAD AND VOLTAGE CLOCK LOGIC"
NOTES: I.
!NTERFACE FAO .. l~E CHECKS
SPEED LEVEL OUTPUT
sx-sM
>----oil-~s';.";-(sx11<Ksl '-------'
SX- SL
SENO SLR TO 0-A 1---------<:
CONVERTER
VX- YH
vx-- v,.
VX - YL
1/0L TAGE LEI/EL OUTPUT
VAR(YX* KY}+- OV
SENO VAR TO 0-A
CONVERTER
SENO M!ILM8 ANO MSLM8
TO COM OUTPUT
SOFTWARE
Output control foi ture relay contact 1hovld be a hordwore device w_ith o), inatontoneaus p\ck.up, b) 5 second time delay dropout. c) _ instcmtoneous dropout on computer or interface power f0Hur• 1
d) and equlvotent OPST contoctl closed when the device 11 enero:ized, The dev1ce "'' H drive 2 optic a I copier leads with po•er 1uppti es or1g1not1ng 10 the ~vernor ond the 11e1tat1on system. (RTU OOMPUTER FAILURE DETECTOR on binary outpot lists)
2
3.
4.
5.
6.
7.
8.
!1.
10.
If the control foi1ure relay d1-ener;ize1, the interface follower mechanism will maintain the ,;overnor and regulotor at the lost 1etpa1nt given by the RTU,oftero!Osecondfilter,onctcanbe
controlled by LOCAl.-MANUAL controla.
&efor• coHin~ the output driv•r. the following must be satitft•d. A) Sn and Vn 1 ooded w, th current ,eu i n91,
8) Alarm buffer cl•ored (before control algorithmt- thete o1;onthms moy set alarms). C) MSI..Mllond MSWII lood•d with current st0te1. O) The INITALIZE FLAG be set from power up routines if o power up hos occurred.
ALARM BUFFER ii exp!oi ned on the "LOAO ANO \IOLTAGE CLOCK LOGIC" drawing.
SLR and VAR (and the di9itol-onolog outputs) mu1t never be gllawed to "rol 1 over" or Jump from maximum positive to moilimum ne9otive. These outputs are the mo1t tmportont outputs of the RTUond must be correct regardless of input failures or errors, software errors, hordwore failures or errors,
or on y other computer prob I em. Thus the hardware and so ftwore driven must be core ful I y dest 9ned, and the CONTROL OUTPUT FA1LURE relay. must be fail-safe ,,for every pasaible hordwore or ioftwore condition
Doto from the A-D, COMM IN!'IJT, and CALIBRATE !N!'l,JT softwore should not I>• chon90d durino LOAD AND VOLTAGE CONTROi. operation. If the doto " ploced in a buffer for program vse when the proorom is called. scans moy be made during program execution without disturbing doto.
Doto for COMM OUTPUT ond 0-A software should be stored in o boffer until the program 1s completed execution. Then 1f transmissions to the master station ore mode white the program is in proQresa, 1nvolid doto will not be transmitted,
Doto to ond from the moster station for the proorom moy be transmitted on on exception basis (or when a change occurs) provided o CONTROL TRANSMISSION FAILURE check for data every 10 seconds or lea• con be mode.
The proorammay be called as often os 0.01 seconda, If process.or overload occurs 1 the program can be delayed for 0.5 seconds with the generotor
in the LOCAL-AUTO mode. or for 4.9 seconds if the generator it in the REMOTE mode.
The colibration inputs ond outputs thould 0110w ~ey vono~les to be displayed m o trend or strip-chert mode or recording (eight voriobltu ot o time, and two logic stotes). ond allow key constants to be ehong1d while the RTU 11 ,n operat,on.
11. If the RTU i1 operational in the_ LOCAL-MANUA.L generator m~mu1oted governor ~nd regulator cou~d be designed to all.ow algorithm checkout
The governor would hove the follow1no choracter1atics: s"--., ~ t-*"'Pl The exc1tot1on system wouid be \/14--Vn + 100°1 •. The s1mulot1ons could
use rectangular inteoration and be called every pots ~-'-'=-"-'· of the confrol programs. P! should be 1nio11zed to O and VI to 100•1. on power-up. SLR, VAR, and the D-A converter, could be active 1f the CONTROL OUTPUT ~!LURE relay is de-energized.
1222-PS-30!)
Figure 34. RTU load and voltage control-Output driver.
85
NAME
A cc, ccs CT, CTA
CTSn CTT D
DB, DEA
DEAD DEi DTL OTV E
EA ECS ECT n
EXCC EXCL
EXCLL EXR FCS FGL FJS
FSD FSOA FSG FSU FSUA
FVO FVU G, GA GH
GL GM GP GPA GS
KS KV LCNTn LM LSTn
Ml MSLMA MSLMB MSVMA MSVMB
MVAL MYALL MVARC MVARL MVARLL
MVO OS DV PC PCA
PE, Pl PM, PR, PS
TY PE * INITIALIZED BY
store constant store
store constant
store constant
constant
constant store
constant flag store store
flag store flag flag store
flag flag store
constant
a - d constant
a - d )
constant
constant constant
store store store
a - d
constant constant
constant constant constant
store a - d store
store
load
load
load
load
load
load
load
load
load
load load
load load
load load load
CALIBRATION
% MVA seconds
seconds seconds
seconds
seconds
seconds % MVA
seconds
% MVA
% MVA % MVA
seconds seconds
% MVA
% MVA seconds seconds
(% current) 2
(% cur-rent)2
(% current )2
% current
% ~
%
% % % % %
volts/% volts/% count
count
% MVA
% MVA % MVA (% current) 2
(% current)2 (% current) 2
% MVA vol ts volts
% MVA % MVA
% MVA % MVA % MVA
% MVA % MVA
MINIMUM ACCURACY
0. I % 0. I sec 0. l sec D. I sec O. I sec
O. I sec O. I sec 0. I % 0. I sec
0.1 %
0.1 % 0.1 % 0.1 sec 0. I sec 0, I %
0. I % O. I sec D. I sec
(0. I %) 2
(0.1 1')2
(0.1 %) 2
0. I %
I % I % I %
0.1 % I %
0.1 % O. I %
I %
D. 05v /0 .05% 0,05v/0.05%
I count
I count
0.1 %
0. I % 0.1 %
(0.1 %)2 (0. I %)2 (0.1 %)2
O. I % 0.05v 0.05v 0.1 % 0. I %
O. I % 0.1 % 0.1 % 0. I % O. I %
MAXIMUM SIZE
! 150 % + 30, -0 sec
+ 30, -0 sec +500, -0 sec
+500. -0 sec
+500 -0 sec
+500, -0 sec ! 150 %
+500, -0 sec
+5%,-0%
+10%, -0 'I +10%. -0 % +5,-0sec + 5 , -0 UC
! 150 %
! 150 % +500, -0 sec +500 -0 sec
( 1~0%)2
( 150%)2
( 150%) 2
+200%, -0 %
+200%, +20% +200%, +20% +200%, +20%
+100%. - 0% +200%. +20% +100%. - 01, +120%. -20% + 10%. - 0%
999, -999
999, -999
! 200 %
+ 1501,, - 0% +1501,, - 0%
(!150%)2 (!150%)2 (!150%)2
!250% :!: IOv + IOv !150% !150%
!150% !150% !150% !150% !I 501,
CALIBRATION I/0
change
change
change
change
change trend
trend
change
change
change
change change
trend
trend trend
trend trend
* TYPES: A constant does not change during normal program execution but may be adjusted for best operation. Store indicates the variable must be stored from one program pass to another.
NOTES
reference model integration change control counter
change control setpoint - norm 10 sec, control interval counter intermediate control interval counter
control interval counter setpoint
control i nterva 1 setpo int norm 6 sec error model integration deadband counter
age control deadband - norm 1%
cont ro 1 dead band hold or indiv control deadband - norm 3% time difference for load control ti me difference for vo 1 t control error model error
intermediate error mode I error error counter setpoint for load - norm 20 sec 1 cad error counter
circle diagram variable - excitation circle diagram variable - 115% excitation
circle diagram variable - 105% excitation circle diagram excitation radius - no norm clear step flag to master station gate limit flag just start Ing flag
stop al location down to master station flag local stop load down flag stop gain movement flag stop allocation up to master station flag local stop load up flag
stop voltage change down to master station flag stop voltage change up to master station flag gain intermediate gain 111aximum gain - norm 170%
gate 1 imi t minimum gain - norm LW% gate position predicted gate position gain change step - norm 2%
speed level multiplier - no norm voltage level multiplier - no norm 1 oad step counter
1 cad irode of RTU (step. ramp, rlc, age) load step storage
generator MVAR - 3 second filter master station 1 cad mode to RTU ( step ramp, r1c, age) master station load mode from RTU (step off) master station volt mode to RTU (step, ave) master station volt mode from RTU (step, off)
circle diagram MVA maximu111 - norm 115% circle diagram MVA maximum - norm 105o/c circle diagram variable circle diagram vai-iable for 115¼ limit circle diagram variable for 105%
circle diagram MVAR offset - no norm speed 1 eve 1 off set - no norm voltage level offset - no norm power reference change intermediate power reference change
error model output
generator power - 3 second filter reference model output
old reference power setpoint from master station
NAME
RE, s, sco SE SL
SLR SM
SNL SPU SR
sso SSTEP
SSTP sx TG
TIME TL TDSn TOVn TV
v, VAR VCNTn VECn VH
VI VK VL VM VNL
VR, vs VSC VST n VSTEP
VSTP
VT" vx XL xv
* TYPE INITIALIZED
store store
constant
constant
constant
constant constant
constant
constant
constant
store store
store
store store
constant
a - d constant constant store
constant
store
constant store
constant store
BY
load
load
load
load load
load
load
load
load
load load
load
load
load
CALIBRATION
% MVA % MVA % MVA % MVA % MVA
vol ts
% MVA % MVA % MVA % MVA
% MVA/sec count
% MVA/sec % MVA seconds
seconds
seconds seconds
% KV vo1 ts count
seconds % KV
% KV %
% KV
% KV
% KV % KV
f, kV/sec count count
% kV/sec % KV % KV % MVA % KV
MINIMUM ACCURACY
0. I % 0.001% 0. I % 0. I < O. I %
0.05v
0. I i, 0. I % 0. I % 0. I %
0.001% /0. I sec I count
0.001% /O. I sec O. I % 0. I sec
0. I sec
O. I sec O. I sec
0.0001% 0.05v
I count 0. I sec 0.01%
0.01% 1%
0.01%
0.01%
0.01% 0.0ti,
0.0001% /0. I sec I count I count
0.0001'1", /0. I sec 0.01% 0.01% 0. 1% 0.01%
MAXIMUM SIZE
!150% :!:1507
!150% !150% !150%
:!: IOv
!150% !150% !150% !150%
+ I -0% /sec 999, -999
+ I -0% /sec !150%
+500, -0 sec
+600. -0 sec
+600, -0 sec +600, -0 sec
! 15% :!: IOv
999 -999 +500, -0 sec
! 50%
+150%. -0% +200%, -0%
:!: 501,
! 50%
! 50% +150%, -Olo + I, -01 /sec
999. -999 999, -999
+ I, -0% /sec +1501,, -0%
! 50% ! 20% ! 2%
CALIBRATION I/0
trend trend change
change
change
change change
change
change
change
input
input
trend
trend change
trend change change
change
trend trend change
change
input input
reference error speed level output
NOTES
speed for sync. condenser operation - norm - LW% error speed level lower speed level limit - norm - 501
speed level register to d-a output
upper speed level limit - norm +150% speed no 1 cad setting - norm +5% speed for pump operation - norm +100% reference speed level
power step for stopping - norm 0.016% /0.1 sec load step count from master station power step for manual loading - norm 0. 1% /0. I sec intermediate speed l eve 1 output governor time constant - no norm
RTU time - must never reset but be continuous with rollover flag to indicate load calibration test time in TIME of last pass of load control time in TIME of last pass of volt control flag to indicate volt calibration test
voltage level output where O = 100% voltage adjust register to d-a output voltage step counter voltage error counter voltage adjust upper 1 imit where O = 100% - norm 10%
generator voltage - 3 second f i 1 ter voltage gain - norm 50% voltage adjust lower limit where O = 100% - norm 10% RTU voltage mode (step, ave) no-load voltage where O = 100% - norm 0%
voltage change voltage setpoint from master station voltage step for stopping - norm 0.005% /O. I sec voltage step storage voltage step from master station
voltage step for manual loading - norm 0.01% /0.1 sec generator voltage storage intermediate voltage adjust where O = 100% test step for load calibration test step for volt calibration
1222-PS-306
Figure 35. RTU load and voltage controller-Variable definitions.
87
7-1750 (12-74) Bureau of Reclamation
CONVERSION FACTORS-BRITISH TO METRIC UNITS OF MEASUREMENT
The following conversion factors adopted by the Bureau of Reclamation are those published by the ·American Society for Testing and Materials (ASTM Metric Practice Guide, E 380-72) except that additional factors (•) commonly used in the Bureau have been added. Further discussion of definitions of quantities and units is given in the ASTM Metric Practice Guide.
The metric units and conversion factors adopted by the ASTM are based on the "International System of Units" (designated SI for Systeme International d'Unites). fixed by the International Committee for Weights and Measures; this system is also known as the Giorgi or MKSA (meter-kilogram (mass)-second-ampere) system. This system has been adopted by the International Organization for Standardization in ISO Recommendation R-31.
The metric technical unit of force is the kilogram-force; this is the force which, when applied to a body having a mass of 1 kg, gives it an acceleration of 9.80665 m/sec/sec, the standard acceleration of free fall toward the earth's center for sea level at 45 deg latitude. The metric unit of force in SI units is the newton (N), which is defined as that force which, when applied to a body having a mass of 1 kg, it gives it an acceleration of 1 m/sec/sec. These units must be distinguished from the (inconstant) local weight of a body having a mass of 1 kg, that is, the weight of a body is that force with which a body is attracted to the earth and is equal to the mass of a body multiplied by the acceleration due to gravity. However, because it is general practice to use "pound" rather than the technically correct term "pound-force," the term "kilogram" (or derived mass unit) has been used in this guide instead of "kilogram-force" in expressing the conversion factors for forces. The newton unit of force will find increasing use, and is essential in SI units.
Where approximate or nominal English units are used to express a value or range of values, the converted metric units in parentheses are also approximpte or nominal. Where precise English units are used, the converted metric units are expressed as equally significant values.
Multiply
Mil .•....................... Inches (in) .................. . Inches ...................... . Feet (ft) .................... . Feet ....................... . Feet ....................... . Yards (yd) ......•............ Miles (statute) (mi) •..•......... Miles ....•.........•.........
Square inches (in2) ............ . Square feet (ft2) .............. . Square feet .........•......••. Square yards (yd2) ......•...... Acres ..................... .. Acres ..................... .. Acres ...................... . Square miles (mi2) ............ .
Cubic inches (in3) ....•.•...•.. Cubic feet (ft3) .............. . Cubic yards (yd3) .•............
Fluid ounces (U.S.) (oz) ........ . Fluid ounces (U.S.) ......•..... Liquid pints (U.S.) (pt) ........ . Liquid pints (U.S.) ............ . Quarts (U.S.) ( qt) ............. . Quarts (U.S.) ........•...••... Gallons (U.S.) (gal) .........•... Gallons (U.S.) ......•...•..•.•. Gallons (U.S.) ••..••....•...... Gallons (U.S.) •••...........•.. Gallons (U.K.) ........•.••.... Gallons (U.K.) ..........•..•.• Cubic feet (ft3) •...•....•....• Cubic yards (yd3) •.•. , ...•..... Acre-feet ••..••.•.......... , . Acre-feet ..........•...•.....
Table 1
QUANTITIES ANO UNITS OF SPACE
By To obtain
LENGTH
25.4 (exactly) . . . . . . . . . . . . . . . . . . . . . . . . . . Micron (µ) 25.4 (exactly) . . . . . . . . . . . . . . . . . . . . . Millimeters (mm)
2.54 (exactly)• . . . . . . . . . . . . . . . . . . . Centimeters (cm) 30.48 (exactly) . . . . . . . . . . . . . . . . . . . . . . . . Centimeters
0.3048 (exactly)• . . . . . . . . . . . . . . . . . . . . . . Meters (m) 0.0003048 (exactly)• ............... Kilometers (km) 0.9144 (exactly) . . . . . . . . . . . . . . . . . . . . . . . Meters (m)
1,609.344 (exactly)• . . . . . . . . . . . . . . . . . . . . . . . . . . Meters 1.609344 (exactly) ................. Kilometers (km)
AREA
6.4516 (exactly) ............ Square centimeters (cm2) •929.03 . . . . . . . . . . . . . . . . . . . . . . . . . . . Square centimeters
0.092903 . . . . . . . . . . . . . . . . . . . . . . Square meters (m2) 0.836127 ................•.......... Square meters
*0.40469 . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hectares (ha) • 4,046.9 . . . . . . • . • . . . . • . . . . . . . . . . . . . Square meters (m2)
*0.0040469 . . . . . . . . . . . . . . . . . Square kilometers (km2) 2.58999 ......................... Square kilometers
VOLUME
16.3871 . . . . . . . . . . . . . . . . . . . . Cubic centimeters (cm3) 0.0283168 . . . . . . . . . . . . . . . . . . . . . . Cubic meters (m3) 0. 764555 . . . . . . . . . . . . . . . . . . . . . . . Cubic meters (m3)
CAPACITY
29.5737 . . . . . . . . . . . . . . . . . . . . Cubic centimeters (cm3) 29.5729 . . . . • . . . . . . . . . . . . . . . . . . . . . . . Milliliters (ml)
0.473179 •.................. Cubic decimeters (dm3) 0.473166 ............................... Liters (I)
*946.358 . . . . . . . . . . . . . . . . . . . . . Cubic centimeters (cm3) *0.946331 ............................... Liters (I)
*3,785.43 . . . . . . . . . . . . . . . . . . . . . . Cubic centimeters (cm3) 3. 78543 . . . . . . • . . . . . . . . . . . . . Cubic decimeters (dm3) 3. 78533 . . . . . . . • . . . . . . . . . . . . . . . . . . . . . . . . Liters (I)
*0.00378543 . . . . . . . . . . . . • . • . . . . . . Cubic meters (m3) 4.54609 . . . • • . . . • . . . . . . . . . . . Cubic decimeters (dm3) 4.54596 • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liters (I)
28.3160 . • . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liters *764.55 . • . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liters
• 1,233.5 . . . • • . . . . . . . . . . . . . . • • . . • . . • . Cubic meters (m3) *1,233,500 •...........••......................... Liters
Table II
QUANTITIES AND UNITS OF MECHANICS
Multiply
Grains (1/7,000 lb) (gr) ...... . Troy ounces (480 grains) Ounces (avdp) (oz) Pounds (avdp) (lb) ....... . Short tons (2,000 lb) ...... . Short tons (2,000 lb) ........ . Long tons (2,240 lb) ......... .
Pounds per square inch (lb/in2) ....... . Pounds per square inch ....... . Pounds per square foot (lb/tt2J ..... . Pounds per square foot ..... .
Ounces per cubic inch (oz/in3) . Pounds per cubic foot (lb/ft3J .. Pounds per cubic foot Tons (long) per cubic yard ....
Ounces per gallon (U.S.) (oz/gal) Ounces per gallon (U.K.I ....... . Pounds per gallon (U.S.) (lb/gal) Pounds per gallon (U.K.) ..... .
By To obtain
MASS
64. 79891 (exactly) 31.1035 ....... . 28.3495 ........ .
0.45359237 (exactly) 907.185 ............ .
0.907185 ............ . 1,016.05 ..................... .
FORCE/AREA
Milligrams (mg) Grams (gl
Grams . . . Kilograms (kg)
. ......... Kilograms Metric tons
. . . Kilograms (kg)
0.070307 ......... Kilograms per square centimeter (kg/cm 2) 6B94.76 ....... Pascals (Pa), or Newtons per square meter (N/m2J
4.88243 . . . . . . . . . . . . . . Kilograms per square meter (kg/m2J 47.8803 ..... Pascals (Pa). or Newtons per square meter (N/m2)
MASS/VOLUME (DENSITY)
1. 72999 ......... , Grams per cubic centimeter (g/cm3) 16.0185 , ........... , .. Kilograms per cubic meter (kg/m3) 0.0160185 ............ Grams per cubic centimeter (g/cm3) 1.32894 Grams per cubic centimeter
MASS/CAPACITY
7.4893 ........................... . 6.2362 .................. .
119.829 ......................... . 99.779 ....................... .
Grams per liter (g/I) Grams per liter Grams per liter Grams per liter
BENDING MOMENT OR TORQUE
Inch-pounds (in-lb) ......... . Inch-pounds ... Foot-pounds (ft-lb) Foot-pounds Foot-pounds per inch (ft-lb/in) Ounce-inches (oz-in)
Feet per second lft/s) ..... . Feet per second ................... . Feet per year (ft/yr) ............... . Miles per hour (mi/h) ............... . Miles per hour ................... .
Feet per second2 (11/,2) ............ .
Cubic feet per second (second-feet) (ft3/s)
Cubic feet per minute (ft3/m) Gallons (U.S.) per minute (gal/mini .....
Pounds (lb) ...................... . Pounds .......................... . Pounds ........................ - ..
0.011521 . . . . . . . . . . . . . . . . . . . . . . . Meter-kilograms (m-kg) 1.12985 x 106 Centimeter-dynes (crn-dyn) 0.138255 . . . . . . . . . . . . . . . . . . . . . . Meter-kilograms Im-kg) 1.35582 x 107 . . . . . . . . . . . . Centimeter-dynes 5.4431 ...... Centimeter-kilograms per centimeter (cm-kg/cm)
72.008 . . . . . . . . . . . . . . Gram-centimeters (g-cm)
VELOCITY
30.48 (exactly) Centimeters per second (cm/s) 0.3048 (exactly)• . . . . . . . . Meters per second (m/s)
*0.965873 x 10-6 . . . . . . . . . . . . . . . . . Centimeters per second 1.609344 (exactly) . . . . . . . . . Kilometers per hour (km/hr) 0.44 704 (exactly) ................. Meters per second
ACCELERATION'
·o.3048 ............... . Meters per second2 (m/s2)
FLOW
*0.028317 . . . . . . . . . . . Cubic meters per second (m3/s) 0.4719 . . . . . . . . . . . . . . . . . . Liters persecond 11/s) 0.06309 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Liters per second
FORCE•
•0.453592 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Kilograms (kg) •4.4482 .................................. Newtons (NI • 4.4482 x 1 as . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Dynes (dyn)
'Vlultiply
British thermal units (Btu) ........... . British thermal units (Btu) ........... . Btu per pound Foot-pounds (ft-lb)
Horsepower (hp) ........... . Btu per hour (Btu/hr) .............. . Foot-pounds per second (ft-lb/sec) .... .
Btu in./hr 112 degree F (k, thermal conductivity) .....
Btu in./hr ft 2 degree F (k, thermal conductivity) .
Btu ft/hr 112 degree F .. Btu/hr tt2 degree F IC,
thermal conductance) Btu/hr 112 degree F (C,
thermal conductance) . . . ........ . Degree F hr 112/Btu IR,
thermal resistance) ..... . Btu/lb degree F (c, heat capacity) Btu/lb degree F ........ . Ft2/hr (thermal diffusivity) . Ft2/hr (thermal diffusivity) .
Table II-Continued
By To obtain
WORK AND ENERGY•
·o.252 .................... Kilogram calories (kg-call 1,055.06 . . . . . . . . . . . . . . . . . . . . . . . . Joules (JI
2.326 (exactly) . . . . . . . . . . . . . . . . Jooles per gram (J/g) • 1 .35582 . . Joules (JI
POWER
745.700 .................. . Watts (w) Watts Watts
0.293071 ............. . 1.35582 ....... .
HEAT TRANSFER
1.442 . . .......... Milliwatts/cm degree C
0.1240 . . . . . . . . . . . . . . . . . . . . . . . Kg cal/hr ';l degree C • 1.4880 . . . . . . . . . . . . . . . . . . . . Kg cal m/hr m degree C
0.568
4.882
............... Milliwatts/cm2 degree C
. . Kg cal/hr m2 degree C
1.761 . . . . . . . . . . . . . . . . . Degree C cm2/milliwatt 4.1868 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . J/g degree C
• 1.000 . . . . . . . . . . . . . . . Cal/gram degree C 0.2581 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . cm 2/sec
·o.09290 . . . . . . . . . . . . . M2/hr
WATER VAPOR TRANSMISSION
Grains/hr ft2 (water vapor) transmission) .......... . 16.7 .............................. Grams/24 hr m2
Perms (permeance) ................ . 0.659 . . . . . . . . . . . . . . . . . . . . . . . . Metric perms Perm-inches (permeability) 1.67 . . . .. , , , , ...... , .... , Metric perm-centimeters
Table Ill
OTHER QUANTITIES AND UNITS
Multiply By To obtain
Cubic feet per square foot per day (seepage) ... *304.8 . . . . . . . . . . . . Liters per square meter per day
Pound-seconds per square foot (viscosity)..... *4.8824 ... Kilogram second per square meter
Square feet per second (viscosity) . . . . . . . . . . . *0.092903 ............ , ..... Square meters per second Fahrenheit degrees (change)* .. · ... , ...... ,. 5/9, then subtract 17.78 ....... Celsius or Kelvin degrees
Volts per mil . . . . . . . . . . . . . . . . . . . . . . . . 0.03937 .... , , . . . . . . . . . . . . . . Kilovolts per millimeter Lumens per square foot (foot-candles) . . . . 10.764 ...... , ........... , .. Lumens per square meter
Ohm-circular mils per foot . . . . . . . . . . . . . . . . 0.001662 ........... Ohm-square millimeters per meter Millicuries per cubic foot ................. *35.3147 ................... Millicuries per cubic meter Milliamps per square foot . . . . . . . . . . . . . . . . . * 10. 7639 ................... Milliamps per square meter
Gallons per square yard................... *4.527219 .................... Liters per square meter
Pounds per inch . . . . . . . . . . . . . . . . . . . . . . . . *0.17858 ................... Kilograms per centimeter
GPO 834-767
•••...•..•.•......•..........•...•.•.•.•..•...•......• , ..................................•...•.•.........•••..................•.•..........•...•.•••••.....•.••..•••..•.
ABSTRACT
A load and voltage controller for managing the power output of 26 generators and the bus voltages for three high-voltage busses at the Grand Coulee Power Complex is described in detailed flow chart form. The controller is designed for inclusion in a computer-based supervisory control system. The load control is based on a closed-loop digital power controller developed especially for hydroelectric installations. Also included is a unique two-level load allocation system utilizing load-frequency commands from an area automatic generation controller and features an alternating reactive-power balance and voltage-setpoint algorithm. The load and voltage controllers use direct analog signals to the electrohydraulic governors and the thyristor-based exci.tation systems.
ABSTRACT
A load and voltage controller for managing the power output of 26 generators and the bus voltages for three high-voltage busses at the Grand Coulee Power Complex is described in detailed flow chart form. The controller is designed for inclusion in a computer-based supervisory control system. The load control is based on a closed-loop digital power controller developed especially for hydroelectric installations. Also included is a unique two-level load allocation system utilizing load-frequency commands from an area automatic generation controller and features an alternating reactive-power balance and voltage-setpoint algorithm. The load and voltage controllers use direct analog signals to the electrohydraulic governors and the thyristor-based excitation systems.
•••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••o•••••
ABSTRACT
A load and voltage controller for managing the power output of 26 generators and the bus voltages for three high-voltage busses at the Grand Coulee Power Complex is described in detailed flow chart form. The controller is designed for inclusion in a computer-based supervisory control system. The load control is based on a closed-loop digital power controller developed especially for hydroelectric installations. Also included is a unique two-level load allocation system utilizing load-frequency commands from an area automatic generation controller and features an alternating reactive-power balance and voltage-setpoint algorithm. The load and voltage controllers use direct analog signals to the electrohydraulic governors and the thyristor-based excitation systems.
ABSTRACT
A load and voltage controller for managing the power output of 26 generators and the bus voltages for three high-voltage busses at the Grand Coulee Power Complex is described in detailed flow chart form. The controller is designed for inclusion in a computer-based supervisory control system. The load control is based on a closed-loop digital power controller developed especially for hydroelectric installations. Also included is a unique two-level load allocation system utilizing load-frequency commands from an area automatic generation controller and features an alternating reactive-power balance and voltage-setpoint algorithm. The load and voltage controllers use direct analog signals to the electrohydraul ic governors and the thyristor-based excitation systems.
REC-ERC-76-3 Gish, W B LOAD AND VOLTAGE CONTROL ALGORITHMS FOR GRAND COULEE POWERPLANT Bur Reclam Rep REC-ERC-76-3, Div Gen Res, March 1976, Bureau of Reclamation, Denver, 87 p, 35 fig, 1 tab
DESCRIPTORS-/ *supervisory control (power)/ *load-frequency control/ *computer applications/ *algorithms/ automatic control/ control systems/ computer programming/ mathematical models/ governors/ voltage regulators/ data transmission/ feedback/ power dispatching/ power system operations/ baseloads/ peak power/ generating capacity/ spinning reserve/ hydroelectric power/ electric generators/ switchyards/ high voltage/ generator-motors I DENTI Fl ERS-/ minicomputers/ Grand Coulee Dam/ Columbia Basin project, Wash.
REC-ERC-76-3 Gish, W B LOAD AND VOLTAGE CONTROL ALGORITHMS FOR GRAND COULEE POWE RP LANT Bur Reclam Rep REC-ERC-76-3, Div Gen Res, March 1976, Bureau of Reclamation, Denver, 87 p, 35 fig, 1 tab
DESCRIPTORS-/ *supervisory control (power)/ *load-frequency control/ *computer applications/ *algorithms/ automatic control/ control systems/ computer programming/ mathematical models/ governors/ voltage regulators/ data transmission/ feedback/ power dispatching/ power system operations/ baseloads/ peak power/ generating capacity/ spinning reserve/ hydroelectric power/ electric generators/ switchyards/ high voltage/ generator-motors IDENTIFIERS-/ minicomputers/ Grand Coulee Dam/ Columbia Basin project, Wash.
REC-ERC-76-3 Gish, W B LOAD AND VOLTAGE CONTROL ALGORITHMS FOR GRAND COULEE POWERPlANT Bur Reclam Rep REC-ERC-76-3, Div Gen I Res, March 1976, Bureau of Reclamation, Denver, 87 p, 35 fig, 1 tab
DESCRIPTORS-/ *supervisory control (power)/ *load-frequency control/ *computer applications/ *algorithms/ automatic control/ control systems/ computer programming/ mathematical models/ governors/ voltage regulators/ data transmission/ feedback/ power dispatching/ power system operations/ baseloads/ peak power/ generating capacity/ spinning reserve/ hydroelectric power/ electric generators/ switchyards/ high voltage/ generator-motors IDENTIFIERS-/ minicomputers/ Grand Coulee Dam/ Columbia Basin project, Wash.
REC-ERC-76-3 Gish, W B LOAD AND VOLTAGE CONTROL ALGORITHMS FOR GRAND COULEE POWERPLANT Bur Reclam Rep REC-ERC-76-3, Div Gen Res, March 1976, Bureau of Reclamation, Denver, 87 p, 35 fig, 1 tab
DESCRIPTORS-/ *supervisory control (power)/ *load-frequency control/ *computer applications/ *algorithms/ automatic control/ control systems/ computer programming/ mathematical models/ governors/ voltage regulators/ data transmission/ feedback/ power dispatching/ power system operations/ baseloads/ peak power/ generating capacity/ spinning reserve/ hydroelectric power/ electric generators/ switchyards/ high voltage/ generator-motors I DENTI Fl ERS-/ minicomputers/ Grand Coulee Dam/ Columbia Basin project, Wash.
