Training Materials For Trainee

Note; GAC is arranged near the Generator.
GAC PANEL NO.1
GAC PANEL NO.2
Exciter
Generator Generator Control Panel (GCP)

GAC PANEL NO.3
Note; GCP takes in the measured value and performs the control and protection about a generator. Therefore, GAC has contained the equipment like CT & VT which is only measuring.
GAC and Generator are connected with a bus duct, and a bus duct junction is in the GAC upper part.
(closed the door)
Attachment-6 (1/2)
FRONT VIEW
(the door opening situation)
SIGNAL LAMP (52G OPEN/52G CLOSE)
HANDLE with key
CT
LA
SC VCB PANEL NO. 1 NP1: GENERATOR / BREAKER PANEL NO. 2 NP2: SURGE ABSOBER / VT,SA & LA NG TR PANEL NO. 3 NGR
NP3: NEUTRAL GROUNDING / EQUIPMENT
Attachment-6 (2/2)
REAR VIEW
(the door opening situation) The withdrawal type box which contained VT inside The withdrawal type box which contained EVT inside
PF
CT
PANEL NO. 3 NP3: NEUTRAL GROUNDING / EQUIPMENT
PANEL NO. 2 NP2: SURGE ABSOBER / VT,SA & LA
PANEL NO. 1 NP1: GENERATOR / BREAKER
NATIONAL ELECTRIC POWER AUTHORITY NIGERIA REHABILITATION OF DELTA II&III POWER STATION DELTA-III H-25 CO-GENERATION PLANT
TECHNOLOGICAL TRAINING MATERIALS Gas Turbine Control Panel AVR Cubicle Generator Control Panel
June. 20, AM
Shop tour (Omika works) June. 20, PM
Gas Turbine Control Philosophy Gas Turbine Control Panel AVR Cubicle Generator Control Panel June. 22, AM/PM HMI Operation (GT control) June. 21
June 2005 Hitachi, Ltd.
GTI-DELTA-HMI050527
H25 GAS TURBINE CONTROL SYSTEM
HITACHI, LTD
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Table of Contents
1. 2. 3. 4. 5. 6. 7. 8. 9. General Descriptions Start-up Operation Synchronizing Operation MW Operation Generator Control Operation Stop Operation Cooldown Operation Governor Manual Operation Load Limiter Manual Operation
10. Overspeed Test Operation 11. Diesel Engine Operation 12. FSNL Operation 13. Emergency Shutdown 14. Alarms 15. Start Check Screen 16. Trip Screen 17. BOI (Backup Operator Interface)
In case of Black Start Operation
<HMI> can't be used because there is no AC power supply. Refer to the 17th chapter for Black Start with <BOI>.
Therefore, the turbine unit can start only with <BOI> in this case.
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1 General Descriptions
1. Turn on the computer and log on the windows system. 2. Click the icon set for this project. Simplicity Program starts automatically and following screen will appear it will and access MarkV. Now we will enable to view the graphics and control Gas turbines.
3. The graphic screen will be shown to select functions using Navigation button stratified based on the functions.
LEVEL1 Navigation : Unit select
LEVEL2 Navigation : Functions select
LEVEL3 Navigation : Sub menu for
Functions select
ALARM Viewing Windows
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2 Start-up Operation
2.1 Unit Control Display Display START-UP Screen of the target GTG unit by clicking the following Level 1: target unit No. Level 2: CONTROL Level 3: START-UP
Navigation buttons;
2.3 Start-up Permissive
2.2 Mode Select
2.4 Start Select
2.5 Startup Sequence check
Unit Control Display
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2.2 Auto Mode select mode.
(a) Click Auto button of the Mode Select section to select automatic start
(b) The system confirms again with showing the confirmation box. (c) If it is accepted, the background color turns to orange. (a) (b) (c) Click OK to select.
2.3 Check start-up permissive
(a) Confirm Ready to Start is displayed in the data area of the Startup Status Enumerated Data Group objects.
(b) If it is not shown(Not Ready to Start is displayed), go to the START CHECK Screen and establish the conditions to start permissive. The more detail about START CHECK Screen, refer Section 11. (a)
(b)
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NOTE: 1. 2.
Start check and the Trip signal include the signal of Latch Type. display does not appear.
Click "Master Reset" button for the Latch release when "Ready to Start"
2.4 Start
(b) Click Start button of the Master Control section. Click OK to select.
(c) The system confirms again with showing the confirmation box. (d) If it is accepted, the background color of the button turns orange, then, start-up sequence is started. (a)
(b)
(c)
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2.5 Start-up Sequence Complete
(a) If start-up sequence is completed, Sequence Complete is displayed in the data area of the Start Sequence Enumerated Data Group objects. (a)
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3 Synchronizing Operation
3.1 Synchronizing Screen Navigation buttons; Display Start-up Screen of the target GTG by clicking the following Level 1: target unit No. Level 2: CONTROL Level 3: SYNCHRO
Synchronizing Screen
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3.2 Display Configuration 1.
Display can be divided into 5 different areas as follows: 2. Synchronizing permissives. The Synchroscope.
3.
4. Monitoring
Operator selector control push buttons.
5. Synchronizing data. NOTE: The permissive section consists of two parts - text and an indicator to
show if that permissive is satisfied or not. A red indicator would mean the permissive is not satisfied, a green indicator would mean the permissive is satisfied.
3.2.1 OPERATOR SELECTOR CONTROL PUSH BUTTONS 3.2.1.1 Synch Mode SELECTIONS This area consists of the following:
Off Off
- disables all the MKV synchronizing functions.
Manual - this enables the MKV synchronizing algorithms,and Manual MANUAL mode section for synchronizing.
the BREAKER CLOSE control button shown in the
Monitor Monitor - enables Sync Monitor mode. This allows automatic
speed and voltage matching to take place. Also it will indicate on the Synchroscope where the automatic was selected. synchronizer would have closed the breaker if AUTO
Auto Auto
- Same as MONITOR except in this mode the command to close the breaker would actually be given.
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3.2.1.2 MANUAL MODE FUNCTIONS: Manual Control section

Raise SPD/LD Raise Lower SPD/LD Lower Raise KV/VAR Raise Lower KV/VAR Lower
Turbine speed/load raise.
- Turbine speed/load lower. Generator voltage KV/VAR setpoint raise.
- Generator voltage KV/VAR setpoint lower.
- Generator circuit breaker close. - Generator circuit breaker trip. 3.3 Auto Synchronization:
Auto mode is selected as default setting.
if Auto mode in Synch Mode selection, Auto mode is selected manually after Field Circuit Breaker closed is comfirmed.
NOTE : Confirm AVR control mode is displayed the AVR/FVR Control Mode.
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3.4 Manual Synchronization: (In case of fault in Auto Synchronization) (a) Display Synchronizing Screen after normal start sequence or when NOTE : Confirm AVR control mode is displayed the AVR/FVR Control mode. (b) Change Synch Mode from other modes to Manual. FSNL condition.
(c) Monitor Synchroscope
Monitor Synchroscope to check if the needles red color of the Synchroscope changes to a green color when the synch check function 25X is satisfied (The needle will be within +/- 10 degrees ). check relay.)
(The color of the needle changes depending on the status of the synch NOTE : The needle of the Synchroscope only rotates if the slip frequency is fixed at the 6 oclock position.
slower than 1.0Hz. For slip frequencies greater than this the needle will be
(d) Calibration of Voltage , Frequency & Slip Frequency (Phase Angle) (d-1) Calibration of Voltage Monitor Synch Metering & operate button in Manual Mode function. If Gen. voltage < Bus voltage , then click Raise KV/VAR. If BUS voltage > Gen. voltage , then click Lower KV/VAR. Monitor Synch Monitoring & operate button in Manual Mode function. If Gen. Frequency < Bus Frequency , then click Raise SPD/LD. (d-3) Calibration of Slip Frequency (Phase Angle) If BUS Frequency > Gen. Frequency , then click Lower SPD/LD. Monitor Synchroscope & operate button in Manual Mode function. If the needle rotates anti-clockwise , then click Raise SPD/LD. If the needle rotates clockwise , then click Lower SPD/LD.
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(d-2) Calibration of Frequency
(e) Close Generator Circuit Breaker (52G)
If the needle rotates clockwise in Synchroscope and slip frequency is less standby.
than 0.1 Hz in Synch Meter click BREAKER CLOSE button for close
And if the needle places at approx -20 degrees (before -10 degrees ) , click Breaker Close button for close again.
3.5 Manual Open Generator Circuit Breaker (52G) (a) Click BREAKER TRIP button for open standby. And click Breaker Trip button, then Generator Circuit Breaker open.
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4 MW Operation
Navigation buttons;
4.2.3 Base load select
4.2.1 Inching operation
4.2.2 Input demand target
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4.2 Change output 1) 2) 3)
There are the three following processes to change the demand. inching operation Base load select input the demand target directly
4.2.1 Inching operation (One shot) Raise Lower
Click button of the Speed/Load Ctrl Raise button Section Confirm the demand shown in the Increase data box Check the actual MW is (a) Raise Increase (b) Lower
Lower button Decrease Decrease
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4.2.2 Input demand target
(a) Click the Setpoint button of the Load Control Section. demand to the box and click OK.
(b) Input box will appear as a sub window. Then, input the desired MW (c) Click the PRESEL button of the Load Control Section. OK.
(d) The system confirms again with showing the confirmation box and click (e) If it is accepted, the background color of button turns orange, then, the (f) Confirm the actual MW will be tracking to the demand. (a) (b) GTG Load Control mode is switched to the Preselect mode.
(c)
(d)
(e)
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4.2.3 Base Load select
(a) Click the BASE button of the Load Control Section. OK.
(b) The system confirms again with showing the confirmation box and click (c) If it is accepted, the background color of button turns orange. Then, the (d) Confirm the actual MW will be tracking to the demand. (a) (b) GTG Load Control mode is switched to the Base Load mode.
(c)
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5 Generator Control Operation

5.1 Unit Control Display Display GEN/EXCITER Screen of the target GTG by clicking the following Navigation buttons; Level 1: target unit No. Level 2: CONTROL Level 3: GEN/EXCITER
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5.2
Display Configuration 1. 2. 3. 4.
Display can be divided into 4 different areas as follows: Operator selector control push buttons. Monitoring EX2000 Status & Control. MW Control
5.2.1 OPERATOR SELECTOR CONTROL PUSH BUTTONS 5.2.1.1 Generator Mode SELECTIONS This area consists of the following:
AVR Off FVR Auto
- enables AVR Control Mode.
- enables FVR Control Mode.
This allows automatic terminal voltage control This allows manual field current control.
5.2.1.2
MANUAL MODE FUNCTIONS:
- Gas Turbine Speed/Load setpoint raise - Gas Turbine Speed/Load setpoint lower - AVR Voltage setpoint raise - AVR Voltage setpoint lower - FVR Voltage setpoint raise - FVR Voltage setpoint lower
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5.3 AVR/FVR Control:
Normally until arriving at 52G closing, AVR control is selected as default. selected automatically.
In case of AVR fault like PT failure or normal/black startup, FVR control is If FVR or AVR is selected manually, confirmation PB is popped up.
In FVR mode, Volt is regulated by Raise/Lower PB manually. 5.4 EX2000 fault:
If certain EX2000 fault is issued, Code is identified from EX2000 ERROR CODE window.
Then to confirm what kind of fault, open the file F:ex2000.dat. Each cause can be identified.
To reset the fault code, push RESET PB for PT RESET or SOFT RESET. - EX2000 PT failure reset PB - EX2000 Soft reset PB After pushing, following confirmation PBs are displayed.
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5.5 MW Control:
(a) Confirm that Selected the PRESEL button of the Load Control Section at (b) Click the Setpoint button of the MW Control Section. to the box and click OK. the START-UP screen.
(c) Input box will appear as a sub window. Then, input the desired MW demand (d) Confirm the actual MW will be tracking to the demand. (b) (c)
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6 Stop Operation
Navigation buttons;
6.2 Stop select
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6.2 Stop
(b) The system confirms again with showing the confirmation box. (c) Click OK to select. If it is accepted, the background color of the button turns orange and then,
(a) Click Stop button of the Master Control section.
stop sequence is started. (a)
(b)
(c)
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6.3 Cancellation of STOP sequence
(b) The system confirms again with showing the confirmation box. (c) Click OK to select. If it is accepted, the background color of the button turns orange and then,
(a) Click Start button of the Master Control section.
stop sequence will suspend. speed/load demand is fixed.
Then, Speed/Load Ctrl will change to the manual mode automatically, and
(d) Again, Speed/Load Ctrl will be changed to the automatic mode by clicking on START button of the Master Control section or BASE button of the Load Control section. Each button chooses the following Load Control mode. START button : BASE button : Base Load mode Preselect Load mode BASE PRESEL.
NOTE : This function can be carried out over than operating speed. operating speed (14HS) : 97.5%SPD PU / 94.5%SPD DO (b) (c)
(a)
(d)
or
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7 Cooldown Operation
7.1 Unit Control Display Display START-UP Screen of the target GTG unit by clicking the following Navigation buttons; Level 1: target unit No. Level 2: CONTROL Level 3: START-UP
7.2 Cooldown Operation
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7.2 Cooldown Control ON speed picked up.
After Turbine shuts down, Cooldown Control is automatically turned on at Zero The Lube oil pump(AOP or EOP) and the Ratchet start automatically when Cooldown Control is turning on, and the turbine drives the turning mode.
When you want to turn off Cooldown Control, the undermentioned procedure is executed.
7.2.1.1 Click OFF button of the Cooldown Control section. Click OK to select.
7.2.1.2 The system confirms again with showing the confirmation box. 7.2.1.3 If it is accepted, the background color of the button turns orange and stopped.) (a)
then, Cooldown Control is turned off.(Lube oil pump and Ratchet will be
(b)
(c)
ON OFF
NOTE:
manual when you want to turn off Cooldown Control.
Please execute the operation after confirming the description of a mechanical
Cooldown Control is very important Control for Turbine.
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executed.
When you want to turn on Cooldown Control, the undermentioned procedure is
(a) Click ON button of the Cooldown Control section. Click OK to select.
(b) The system confirms again with showing the confirmation box. (c) If it is accepted, the background color of the button turns orange and then, Cooldown Control is turned off.(Lube oil pump and Ratchet will be started.) (b) (c)
(a)
ON OFF
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8 Governor Manual Operation

Navigation buttons;
8.2 Mode Change
8.3 Change output
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8.2 Change Governing Mode
(a) If the color of LLM button is orange, click Change SW button of the GOV/LLM Changer section to change the governor mode to Governing Mode.
(b) The system confirms again with showing the confirmation box. Click OK to select.
(c) If it is accepted, the background color of the GOV button turns orange, then, the GTG is switched to the Governing mode. (a) (b)
(c)
8.3 Change output (One Shot) Raise Lower
Note: Change SW can be activated only while 52G is closed. Start-up to 52G Close: Governor Mode is selected.
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9 Load Limiter Manual Operation

Navigation buttons;
9.2 Mode Change
9.3 Change output
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9.2 Change Load Limiter Mode
(a) If the color of GOV button is orange, click Change SW button of the Mode.
GOV/LLM Changer section to change the governor mode to Load limiter
(b) The system confirms again with showing the confirmation box. (c) If it is accepted, the background color of the LLM button turns orange, then the GTG is switched to the Governing mode. (a) (b) Click OK to select.
(c)
9.3 Change output (One shot) Raise Lower
Note: Change SW can be activated only while 52G is closed. Start-up to 52G Close: Governor Mode is selected.
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10 Overspeed Test Operation

10.1 Unit Control Display Display OVERSPEED Screen of the target GTG unit by clicking the following Navigation buttons; Level 1: target unit No. Level 2: TESTS
Level 3: OVERSPEED
10.2 Overspeed Test Select
10.3 Main Test Select
10.4 Backup Test Select
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10.2 Overpeed Test Select
(a) Click ENABLE button of the Over Speed Test Select section. (b) The system confirms again with showing the confirmation box. Click OK to select.
(c) If it is accepted, the background color of the button turns orange, then Overspeed Test mode is selected.
(a)
(b)
(c)
NOTE:
ENABLE can be activated only while 52G is open and over than operating speed (14HS).
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10.3 Main Test Select
(a) Click Start button of the Main Overspeed Trip Test section. Click OK to select.
(b) The system confirms again with showing the confirmation box. (c) If it is accepted, the background color of the button turns orange, then Main Overspeed Trip Test mode is selected and Turbine speed rises automatically. (b) (c) (a)
(d) If you want to cancel Overspeed Test Mode, click abort button of the Main Select section.
Overspeed Trip Test section or DISABLE button of the Over Speed Test
(e) The system confirms again with showing the confirmation box. (f) If it is accepted, the background color of the button turns orange, then Overspeed Test mode is canceled and Turbine speed lowers automatically. (e) or (d) Click OK to select.
(f)
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10.4 Backup Test Operation
(a) Click Start button of the Backup Overspeed Trip Test section. (b) The system confirms again with showing the confirmation box. Click OK to select.
(c) If it is accepted, the background color of the button turns orange, then Backup Overspeed Trip Test mode is selected and Turbine speed rises automatically. (b) (c)
(a)
NOTE:
The method of canceling Backup Test is similar to Main Overspeed Trip Test.
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11 Diesel Engine Test Operation

11.1 Display DIESEL ENGINE Display DIESEL ENGINE Screen of the target GTG unit by clicking the following Navigation buttons; Level 1: target unit No. Level 2: TESTS
Level 3: DIESEL ENGINE
11.2 Diesel Engine Test Select
11.3 Diesel Engine Test Start
11.4 Acceleration Test Start
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11.2 Diesel Engine Test Select
(a) Click ENABLED button of the DIESEL TEST PERMISSIVE section. (b) The system confirms again with showing the confirmation box. Click OK to select.
(c) If it is accepted, the background color of the button turns orange, then Diesel engine Test mode is selected. (a)
(b)
(c)
(a) If you want to cancel Diesel engine Test Mode, click DISABLED button of the (b) The system confirms again with showing the confirmation box. (c) If it is accepted, the background color of the button turns orange, then Diesel engine Test mode is canceled. (d) (e) Click OK to select. DIESEL TEST PERMISSIVE section.
(f)
NOTE:
ENABLED can be activated only while Turbine reset (L4) is not TRUE or Turbine sequence complete (L3) is TRUE.
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11.3 Diesel Engine Test Start
(a) Click START button of the DIESEL TEST CONTROL section. (b) The system confirms again with showing the confirmation box. Click OK to select.
(c) If it is accepted, the background color of the button turns orange, then Diesel engine Test mode is selected and Diesel engine rises automatically up to the idling speed. (a)
(b)
(c)
(d) If you want to cancel Diesel engine Test Start, click STOP button of the (e) The system confirms again with showing the confirmation box. (f) If it is accepted, the background color of the button turns orange, then Diesel engine Test is canceled. (d) Click OK to select. DIESEL TEST CONTROL section.
(e)
(f)
NOTE:
Diesel engine test stops automatically after 5 minutes pass from the test start (c). necessary.
After executing the test for 5 minutes, the cooling down interval of 20 minutes is
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11.4 Diesel Engine Test - Acceleration
(a) Click ENABLED button of the DIESEL TEST ACCELERATION section. (b) The system confirms again with showing the confirmation box. Click OK to select.
After completing the warm-up of the diesel engine. (see Section 12.2, 12.3)
(c) If it is accepted, the background color of the button turns orange, then Diesel (d) Click Setpoint button of the DIESEL TEST SPEED REF. Section. (rpm) demand to the box and click OK. engine Test - Acceleration is selected.
(e) Input box will appear as a sub window. Then, input desired Speed reference (f) Confirm the actual speed will be tracking to the demand. (a) (b) (c)
(d)
(e)
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(g) If you want to cancel Diesel engine Test Start, click DISABLE button of the (h) The system confirms again with showing the confirmation box. (i) If it is accepted, the background color of the button turns orange, then Diesel engine Test - Acceleration is canceled. (g) (h) Click OK to select. DIESEL TEST ACCELERATION section.
(i)
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12 FSNL Operation
12.1 Synchronizing Screen Navigation buttons; Display Start-up Screen of the target GTG by clicking the following Level 1: target unit No. Level 2: CONTROL Level 3: SYNCHRO
Synchronizing Screen
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12.2 Open Generator Circuit Breaker
(a) Click BREAKER TRIP button for open standby. And click Breaker Trip button, then Generator Circuit Breaker open.
12.3 Generator Breaker Close
(a) Click Start button of the Master Control of START-UP Screen.
(b) See 3.3 Auto Synchronization when select Auto Synchronization, or see 3.4 Manual Synchronization when select Manual Synchronization.
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13 Emergency Shutdown
The E-Stop (emergency stop) push-button is located below the back up panel on the only and should not be used as a normal turbine stop. right front door. This push-button is used to trip the turbine in an emergency situation
LOW LEVEL SHIELD BUS BAR
CCOM
<S> Core
<R> Core
<C> Core
HIGH LEVEL SHIELD BUS BAR
TB for LVDT/R Servo's etc. Not Used
TB for LVDT/R Servo's etc. Vibration, PR, Vdc etc. TB for Themopcouples LVDT feedback, mA inputs
TB for mA inputs/outputs Not Used
Not Used
TB for Themopcouples TB for RTD
Not Used
Backup Operator Interface <BOI>
<T> Core
 Core
<PD> Core
TB for LVDT/R Servo's etc.
Overspeed, flame Synch & trip
AC & DC power supply inputs
Emergency Stop PB
<D> Core or <QD2> Core or Rectfiers
<QD1> Core
<CD> Core
Contact Input Terminal Board Contact Input Terminal Board Contact Output Terminal Board
Contact Input Terminal Board Contact Input Terminal Board Contact Output Terminal Board Contact Output Terminal Board
LEFT FRONT DOOR
LEFT SIDE WALL
Contact Output Terminal Board
BACK PANEL
RIGHT SIDE WALL
RIGHT FRONT DOOR
Ground Lug
NOTES: 1 - High level wiring on right side of case, low level on left side. 2 - Cable support rails provided on both side walls. 3 - Refer to case outline drawings for additional site specific details.
Figure 1 Functional Layout of a typical SPEEDTRONIC Mark V Cabinet
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14 Alarms
Alarms allow for 4 priority classifications distinguished by the implemented color scheme.
Ack/UnAck
Unacknowledged Unacknowledged Acknowledged Acknowledged
Alarm Alarm
Normal/Alarm
Normal
White/Red Red/White
Text/Background
Black/White
Normal
Auto Reset
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15 Start Check Screen
10.1 Start Check Display
Display START CHECK Screen of the target GTG unit by clicking the following Navigation buttons; Level 1: target unit No. Level 2: AUX
Level 3: START CHECK

1
START CHECK Display

The Start Check Screen provides a list of signals which all must be in the proper state, GREEN, to permit a start. Therefore, a green signal is required to start the unit. When a RED signal is present then the text in the Data Box turns red and the NOT READY When all signals are green then the Data Box displays the READY TO START signal in green. TO START signal is display.
If signals are RED then a start request is inhibited.
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16 Trip Screen
11.1 Trip Diagram Display Display TRIP DIAGRAM Screen of the target GTG unit by clicking the Level 1: target unit No. Level 2: AUX
following Navigation buttons;
Level 3: TRIP DIAGRAM

1
TRIP DIAGRAM Display

The Trip screen provides a list of Protective trips for the GTG. The trips are normally GREEN and turn RED when activated. Some signals are not latched, so the data logger must be the display. checked for an accurate chain of events, leading to any highlighted trips that may appear on
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17 Backup Operator Interface Panel - <BOI>

turbine functions. This ancillary device is known as the Backup Operator Interface or three control processors <R>, <S>, and<T>. The Mark V System also provides a secondary means of monitoring/controlling the
<BOI>. The <BOI> has its own communications link which is directly connected to the
used to start and stop the unit, load or unload it, silence acknowledge alarms, reset process alarms, and monitor unit operation. LCD(Liquid Crystal Display)
An LCD panel with a keypad, this device is mounted on the control panel. It also can be
GE Drive Systems
Control Products
C 2 E 4 R 7 S 8 DZ 0 . 5 T 9 F 6 DELETE E N T E R 3 CLEAR ALARM SIL ALARM ACK ALARM RESET MENU DSP PROC NORMAL ALARMS F11 F1 F16 F6 SCROLL UP SCROLL DOWN F12 F2 F17 F7 PREV DSP NEXT DSP F13 F3 F18 F8 ALLP ESC DEM HELP LOWER RAISE F14 F4 F19 F9 F15 F5 F20 F10 FORCE SET D A 1 B
SHIFT
<
>
The contents to mention here are contents of a setup of <BOI>, unit operation procedure and alarm display. Refer to the following drawings for the details. Application Manual Users Manual - GEH-6195D
Maintenance Manual
- GEH-5980E
- GEH-5979D
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12.1 <BOI> Source File BOI_Q.SRC
Following is description of the BOI_Q.SRC File. All settings about <BOI> are contained in this file. (Only the selection of the unit-scale-data is set up in the CONST_Q.SRC file.)
~~~~~~~~~~~~~~~~~~ Start of BOI_Q.SRC file ~~~~~~~~~~~~~~~~~~~

; ; BOI_Q.SRC - This is the definition of the BOI display. ; ; The scaling used for the BOI display is determined by the ; value of the constant BOI_SCAL_SET where: ; ; 0 = Hardware ; 1 = English ; 2 = Metric ; 3 = Custom ; ; ; This file is essentially a set of tables. The header and END line of each ; section must begin in the first column of the file. The entries in each ; table can not start in column one. (Spaces or tabs can be used to indent ; each line.) ; ; ;-----------------------------------------------------------------------------; ; DEMAND SECTION ; ; This section defines the demand displays (two) that the customer is allowed ; to change from the panel. ; "N" (Normal) type displays are normal displays of up to 4 points, ; "E" (Enumerated) type displays are enumerated point displays. ; ; LIMIT: There must be exactly 2 displays shown here. ; DEMAND ; E DISPLAY NAME ;or ; N DISPLAY NAME ; - -----------------N "DEMAND, PAGE 1 " N "DEMAND, PAGE 2 " END DEMAND SIGNAL_TAG POINT_TAG -----------BLANK_DSPLY BLANK_DSPLY MASK_TAG POINT_TAG -----------BLANK_DSPLY BLANK_DSPLY ENUM_TAG POINT_TAG -----------BLANK_DSPLY BLANK_DSPLY COMMAND_TAG POINT_TAG -----------BLANK_DSPLY BLANK_DSPLY
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;-----------------------------------------------------------------------------; ; DISPLAY SECTION ; ; This section defines each display in terms of POINT_TAGS. ; "N" (Normal) type displays are normal displays of up to 4 points, ; "E" (Enumerated) type displays are enumerated point displays. ; ; LIMIT: 32 displays. ; DISPLAY ; E DISPLAY NAME ;or ; N DISPLAY NAME ; - -----------------E "F1 MODE SEL " N "F2 MASTER RESET " N "F3 BS_MODE_SEL " N "F4 START/STOP " N "F5 EX2000 " E "F6 SYNCH MODE " E "F7 LOAD SEL " N "F8 PRE-SEL LD SP" N "F9 SPEED/LOAD SP" N "F10 MOTOR STAT1 " N "F11 MOTOR STAT2 " N "F12 MOTOR STAT3 " N "F13 START CHECK0" N "F14 START CHECK1" N "F15 START CHECK2" N "F16 START CHECK3" N "F17 START CHECK4" N "F18 START CHECK5" N "F19 NORMAL pg 1 " N "F20 NORMAL pg 2 " N "F21 NORMAL pg 3 " N "F22 NORMAL pg 4 " N "F23 NORMAL pg 5 " N "F24 NORMAL pg 6 " N "F25 CTRL LOC " N "F26 BLACK START1" N "F27 BLACK START2" END DISPLAY NORMAL 20 ; This defines which of the above displays is the NORMAL display. ; This is an index into the above list, 1 means the first display. SIGNAL_TAG POINT_TAG -----------SS43 L86MR1_CPB L43BSON_CPB L1STOP_CPB DVOLT SS43SYNC SS43LOAD L90PSEL_CMD TNH L52HR L52QA L52VG1 L27BN L86MP L43O L86CB L83DT_CMD L43DIAG PN_RPM FSR TNH DWATT TTXSP1 FLAME_A L43BOI2A_CPB L41DC_FB DV_EX MASK_TAG POINT_TAG -----------SK43_MASK STATUS_FLD L43BSOFF_CPB L1START_CPB DAMP SK43SYNC SK43LOAD DWATT TNR T2HR L72QEZ L52FC1 L27BZ L14HR L86HD L4Y L39VD3 L3ACS TNH_RPM FPG2 TTXM DPF CSGV FLAME_B CPD L52GX L52GX ENUM_TAG POINT_TAG -----------Etag_00 SPEED_LVL L83BS_SEL BLANK_DSPLY L90FVRIN_CPB Etag_14 Etag_02 BLANK_DSPLY L70R4R_CPB L52DS L52QV L52FC2 L86TCI L26QN L27DDEC L63FGN L26DW1H L3VOTE_Q FSR STATUS_FLD TTXSP1 DVAR BLANK_DSPLY FLAME_C FSR_CONTROL TNH DA_EX COMMAND_TAG POINT_TAG -----------SC43 BLANK_DSPLY BLANK_DSPLY BLANK_DSPLY L90FVRDE_CPB SC43SYNC SC43LOAD SS43LOAD L70R4L_CPB C48DSX L52BT1 L52FC3 L3IGVFLT L28FDSCK L52GX L4T L3TFLT L4_FB L28FDX SPEED_LVL MAXVIB SS43LOAD BLANK_DSPLY FLAME_D L3 L90AVRACT L27MC1N
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;-----------------------------------------------------------------------------; ; POINT_TAG SECTION ; ; ; This section defines for each point tag a point definition. Each definition ; consists of: ; ; POINT TAG: The point tag used in the display section. ; SIGNAL NAME: The Mark V signal name, must exist in UNITDATA.DAT. ; DISPLAY NAME: The name (6 chars) that is shown on the BOI. ; E/N FLAG: "N" for normal points, "E" for enumerated points. ; SCALE/ETAG: "N" points have the scale name or scale number here. If a ; scale name is used, it must exist in ENGLISH.SCA. The scale ; name or number must resolve to a scale code from 0 to 247. ; Scale codes 248-255 are user programmable via the SCALE_DATA ; section below. ; "E" points have the enumerated tag here. ; ; Since this section is used for the "ALL POINTS" display, it is customary to ; sort this section upon the DISPLAY field so that the ALL POINTS display ; presents the points in sorted order. The exception - BLANK_DISLY must be ; the first point in the list. ; ; LIMIT: 128 points in this list. (BLANK_DSPLY plus 127 others.) ; ; POINT ; POINT_TAG POINTNAME DISPLAY N/E N:SCALE or E:NUM_TAG ; --------------------------------------------------BLANK_DSPLY BLANK_DSPLY "------" N NULL DVOLT DVOLT "GEN_V " N V64K DAMP DAMP "GEN_A " N AM16K L43BSON_CPB L43BSON_CPB "BS_ON " N LOG L43BSOFF_CPB L43BSOFF_CPB "BS_OFF" N LOG L83BS_SEL L83BS_SEL "BSMODE" N LOG FPG2 FPG2 "P2PRES" N PRESS CPD CPD "CPD " N PRESS L3 L3 "L3 " N LOG L90AVRACT L90AVRACT "AVRACT" N LOG L90FVRIN_CPB L90FVRIN_CPB "FVR_IN" N LOG L90FVRDE_CPB L90FVRDE_CPB "FVR_DE" N LOG L43CD_OFFCPB L43CD_OFFCPB "CD_OFF" N LOG L43CD_ON_CPB L43CD_ON_CPB "CD_ON " N LOG FSR_CONTROL FSR_CONTROL "CONTRL" E Etag_03 STATUS_FLD STATUS_FLD "STATUS" E Etag_05 SPEED_LVL SPEED_LVL "SPEED " E Etag_06 DVAR DVAR "DVARS " N MVARS DWATT DWATT "DWATTS" N MWATT SK43F SK43F "FMSK " E Etag_00 FQG FQG "FQG " N LB_S FSR FSR "FSR " N PCT SC43F SC43F "FUEL_C" E Etag_01 SS43F SS43F "FUEL_S" E Etag_01 SC43GEN SC43GEN "GEN_C " E Etag_04 SK43GEN SK43GEN "GEN_K " E Etag_04
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SS43GEN CSGV CSRGV L83WQ_CMD L83SCI_CMD FLAME_A FLAME_B FLAME_C FLAME_D FLAME_E FLAME_F FLAME_G FLAME_H SK43LOAD SC43LOAD SS43LOAD L70R4L_CPB MAXVIB SK43_MASK SC43 SS43 L86MR1_CPB L4EXOFF_CMD L4EX_SS DPF L69PF DRPF_CMD L43FSRS L90PSEL_CMD L70R4R_CPB SFL1 L1START_CPB L1STOP_CPB TNH TNR TNRI_CMD TTXM TTXSP1 TXGVERR DRVAR_CMD L69VC L43BOI2A_CPB SFL2 DF SFL1 SC43SYNC SK43SYNC SS43SYNC L52GX L41DC_FB DV_EX DA_EX L27MC1N
SS43GEN CSGV CSRGV L83WQ_CMD L83SCI_CMD L28FDA L28FDB L28FDC L28FDD L28FDE L28FDF L28FDG L28FDH SK43LOAD SC43LOAD SS43LOAD L70R4L_CPB BB_MAX SK43_MASK SC43 SS43 L86MR1_CPB L4EXOFF_CMD L4EX_SS DPF L69PF DRPF_CMD L43FSRS L90PSEL_CMD L70R4R_CPB SFL1 L1START_CPB L1STOP_CPB TNH TNR TNRI_CMD TTXM TTXSP1 TXGVERR DRVAR_CMD L69VC L43BOI2A_CPB SFL2 DF SFL1 SC43SYNC SK43SYNC SS43SYNC L52GX L41DC_FB DV_EX DA_EX L27MC1N
"GEN_S " "IGVPOS" "IGVREF" "INJ_SL" "ISOCTL" "L28FDA" "L28FDB" "L28FDC" "L28FDD" "L28FDE" "L28FDF" "L28FDG" "L28FDH" "LDMSK " "LOAD_C" "LOAD_S" "LOWER " "MAXVIB" "MDMSK " "MODE_C" "MODE_S" "MRESET" "OFFREQ" "ON_FB " "PF " "PF_ACT" "PF_CMD" "PRESET" "PS_CMD" "RAISE " "SFL " "START " "STOP " "TNH " "TNR " "TNRI " "TX " "TXSPRD" "TX_ERR" "VARCMD" "VC_ACT" "BOI2AL" "SYS_FQ" "GEN_FQ" "SFL " "SYNC_C" "SYNCMK" "SYNC_S" "GENBKR" "FLDBKR" "GNVOLT" "GN AMP" "27MC1N"
E N N N N N N N N N N N N E E E N N E E E N N N N N N N N N N N N N N N N N N N N N N N N E E E N N N N N
Etag_04 ANGLE ANGLE LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG Etag_00 Etag_02 Etag_02 LOG VIBVL Etag_00 Etag_00 Etag_00 LOG LOG LOG PF LOG PF LOG MWATT LOG FREQL LOG LOG PCT PCT PCT TC TCDIF TCDIF MVARS LOG LOG FREQL FREQL FREQL Etag_14 Etag_14 Etag_14 LOG LOG V64K AM16K LOG
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; ;>START CHECK SIGNAL ; L27BN L27BZ L86TCI L3IGVFLT L86MP L14HR L26QN L28FDSCK L43O L86HD L27DDEC L86CB L4Y L63FGN L4T L83DT_CMD L39VD3 L26DW1H L3TFLT L43DIAG L3ACS L3VOTE_Q L4_FB L1X L63QT L52HR T2HR L52DS C48DSX L52QA L72QEZ L52QV L52BT1 L52VG1 L52FC1 L52FC2 L52FC3 TNH_RPM PN_RPM L28FDX END POINT
L27BN L27BZ L86TCI L3IGVFLT L86MP L14HR L26QNX L28FDSCK L43O L86HD L27DDEC L86CB L4Y L63FGN L4T L83DT_CMD L39VD3 L26DW1H L3TFLT L43DIAG L3ACS L3VOTE_Q L4_FB L1X L63QT L52HR T2HR L52DS C48DSX L52QA L72QEZ L52QV L52BT1 L52VG1 L52FC1 L52FC2 L52FC3 TNH_RPM PN_RPM L28FDX
"27BN 1" "27BZ 1" "TCID 0" "IGVF 0" "86MP 0" "14HR 1" "26QN 1" "28FDF1" "OFF_M0" "86HD 0" "DDECP0" "86CB 0" "L4Y 1" "63FGN1" "TRIP " "DE_TST" "39VD 0" "26DW 0" "CPDF 0" "DIAG 0" "3ACS 1" "VOTE 1" "4_FB 1" "1X 1" "63QT 0" "G88HR1" "RCT_TD" "G88DS1" "DE_CNT" "G88QA1" "G88QE1" "G88QV1" "G88BT1" "G88VG1" "G88FC1" "G88FC2" "G88FC3" "TNHRPM" "PN_RPM" "L28FDX"
N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N
LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG LOG MIN64 LOG CNT15 LOG LOG LOG LOG LOG LOG LOG LOG RPM RPM LOG
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;-----------------------------------------------------------------------------; ; ENUMDATA SECTION ; ; This section defines the strings associated with each ENUM_TAG. ; The strings are limited to 8 characters each. The list must end with the ; special END line. ; ; LIMIT: The total number of bytes used for all ENUM_TAGs must be <= 512 bytes. ; There can be no more than 32 enumerated sets defined. ;
ENUM ; Etag_00 "OFF" "COOLDOWN" "CRANK" "FIRE" "MANUAL" "AUTO" ;(N/A) "SERIAL" ;(N/A) "CABLE" ; Etag_01 "GAS" ;(N/A) ;(N/A) ;(N/A) ;(N/A) ;(N/A) ; Etag_02 "LOAD_CAN" "PRESELEC" "BASE" ;(N/A) "PEAK" ;(N/A) "PEAK_R" ;(N/A) "EXT_SP" ; Etag_03 "SHUTDOWN" "MANUAL" "TEMP" "STARTUP" "ACCELH" "ACCELL" "DROOP" "ISOCH"
"MIX" "DIST" "HEAVY" "GAS1" "GAS2"
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; Etag_04 "GEN_OFF" "VAR_CTRL" "PF_CTRL" "ERROR" ; Etag_05 "--------" "FSR_MAN " "NOTREADY" "READY!!!" "STARTING" "CRANKING" "FIRING " "WARMUP " "ACCEL " "FSNL " "SYNCHRO " "SPINNING" "LOADING " "FASTLOAD" "PRE_LOAD" "BASELOAD" "--------" "PARTLOAD" "UNLOAD " "V_MACTH " "ISOCH " "FIRESHUT" "COSAST_D" "COOLDOWN" "STOP!!!!" ; Etag_06 "--------" "14HS_SPD" "14HC_SPD" "14HA_SPD" "14HM_SPD" "14HT_SPD" "14HF_SPD" "14HRZ_SP" ; Etag_14 "OFF" "MANUAL" "MONITOR" "AUTO" "MAN DBUS" ; END ENUM
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;-----------------------------------------------------------------------------; ; SCALE DATA SECTION ; ; This section defines the scale codes for the 8 user programmable scale codes ; that the unit supports. These scale codes are used when the above POINT_TAG ; section defined a point as having a scale code of 248 to 255. (These must ; have been defined by number, not by name, in the POINT_TAG section.) ; ; If not all scale sets are defined for a given scale code, the un-specified ; scale sets will be displayed in the lowest number scale set that was ; specified. ; ; FORMAT IS: ; ; code set gain shift offset resol decimal units ; ; where ; ; CODE: Scale code being defined (248..255) ; SET: Scale set being defined: ; 0 = Hardware ; 1 = English ; 2 = Metric ; 3 = Custom ; GAIN: Gain in decimal counts. ; OFFSET: Offset in decimal counts. ; SHIFT: Shift in decimal. (Can be negative.) ; RESOLUTION: The number of counts to change for each RAISE/LOWER command. ; DECIMALS: The number of places after the decimal point. ; UNITS: The engineering units string (5 chars). ; ; ; LIMIT: 8 scale codes (248..255) with up to 4 scale sets (0..3) per code. ; ; SCALE ; ; CODE SET GAIN SHIFT OFFSET RESOL DEC UNITS ; ---- -------- ---------- ------------; 248 0 16384 1 0 1 1 "cnt15" 249 0 16384 1 0 1 1 "cnt15" END SCALE _
~~~~~~~~~~~~~~~~~~~~~ End of BOI_Q.SRC file ~~~~~~~~~~~~~~~~~~~~~
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12.2 FUNCTION KEY DESCRIPTION The following table shows the contents of indication by pressing FUNCTION KEY.
(FIELD 01) (FIELD 03)
(FIELD 02) (FIELD 04)
GE Drive Systems
Control Products
C 2 3 F 5 6 T 8 9 0 . DELETE E N T E R CLEAR
ALARM SIL ALARM ACK ALARM RESET
MENU DSP PROC NORMAL ALARMS
F11 F1 F16 F6 SCROLL UP SCROLL DOWN
F12 F2 F17 F7 PREV DSP NEXT DSP
F13 F3 F18 F8 ALLP ESC DEM HELP
F14 F4 F19 F9 RAISE LOWER
F15 F5 F20 F10 FORCE SET
A 1 D 4 R 7
B E S DZ
SHIFT
<
>
(FUNCTION KEY)
KEY F1 F2 F3 F4 F5 F6 F7 F8 F9 F10 F11 F12 F13 F14 F15
DISPLAY NAME F1 MODE SEL F2 MASTER RESET F3 BS_MODE_SEL F4 START/STOP F5 EX2000 F6 SYNCH MODE F7 LOAD SEL F8 PRE-SEL LD SP F9 SPEED/LOAD SP F10 MOTOR STAT1 F11 MOTOR STAT2 F12 MOTOR STAT3 F13 START CHECK0 F14 START CHECK1 F15 START CHECK2
FIELD 01
FIELD 02
FIELD 03
FIELD 04
Enumerated Command (Etag_00) MRESET BS_ON STOP GEN_V # # # # (Etag_05) BS_OFF START GEN_A # # # (Etag_06) BSMODE FVR_IN # # FVR_DE #
Enumerated Command (Etag_14) Enumerated Command (Etag_02) PS_CMD TNH G88HR1 G88QA1 G88VG1 27BN 1 86MP 0 OFF_MO # # # # # # # # DWATTS TNR RCT_TD G88QE1 G88FC1 27BZ 1 14HR 1 86HD 0 # # # # # # # # RAISE G88DS1 G88QV1 G88FC2 TCID 0 26QN 1 DDECP0 # # # # # # # (Etag_02) LOWER DE_CNT G88BT1 G88FC3 IGVF 0 28FDF1 GENBKR # # # # # # #
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KEY F16 F17 F18 F19 F20 F21 F22 F23 F24 F25 F26 F27
DISPLAY NAME F16 START CHECK3 F17 START CHECK4 F18 START CHECK5 F19 NORMAL pg 1 F20 NORMAL pg 2 F21 NORMAL pg 3 F22 NORMAL pg 4 F23 NORMAL pg 5 F24 NORMAL pg 6 F25 CTRL LOC F26 BLACK START1 F27 BLACK START2
FIELD 01 86CB 0 DE_TST DIAG 0 PN_RPM FSR TNH DWATTS TXSPRD L28FDA BOI2AL FLDBKR GNVOLT # # # # # # # # # # # #
FIELD 02 L4Y 1 39VD 0 3ACS 1 TNHRPM P2PRES TX PF IGVPOS L28FDB CPD GENBKR GENBKR # # # # # # # # # # # #
FIELD 03 63FGN1 26DW 0 VOTE 1 FSR (Etag_05) TXSPRD DVARS L28FDC (Etag_03) TNH GN AMP # # # # # # # # #
FIELD 04 TRIP CPDF 0 4_FB 1 L28FDX (Etag_06) MAXVIB (Etag_02) L28FDD L3 AVRACT 27MC1N # # # # # # # #
; shows blank display
Etag_nn
; see previous section ENUMDATA SECTION at BOI_Q.SRC file
; shows logic status or process data
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12.3 The explanation of Basic Operation about FUNCTION KEY Command Section ; F1 ~ F9 Monitoring Section ; F10 ~ F27 12.3.1 Command Section 12.3.1.1 Enumerated Command 2) Press a cursor key name.
1) Press function key ( F1, F6, F7 ), and indicate enumerated command.
< or > , and take a sign ">" at the head of the command
3) Press ENTER key to execute the command, and confirm that the sign 4) If an Enumerated Switch Display has more functions than can be shown on a single page, the SCROLL DOWN and SCROLL UP keys can be used to view the additional functions. 12.3.1.2 Normal Command > changed in asterisk " * ".
1) Press function key, and indicate desired command. 2) Press a cursor key name.
The points (command name) which can be selected are prefixed by the symbol " ^ ". < or > , and take a sign ">" at the head of the command
3) Press ENTER key, and confirm that the sign > changed in an asterisk " * ". 4) Press RAISE or LOWER key to execute the command. 12.3.1.3 Analogue Demand Input 2) Press a cursor key name. Points can be deselected by pressing the ESC key.
1) Press function key, and indicate analogue demand.
< or > , and take a sign ">" at the head of the command
3) Press ENTER key, and confirm that the sign > changed in an asterisk " * ". Target value can be deselected and back to the previous value by pressing the ESC key.
4) Press SET key, and Input a target value with 10 key on the right of function key.
5) Press ENTER key to execute the demand.
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12.3.2 Monitoring Section 12.3.2.1 Start Check concluded.
Logic status from F10 to F19 is to be checked when a start permissive condition isn't
( In case of Indication " NOTREADY " in the FIELD02 with F2 key, after Master Reset and Startup Mode Select operation. ) 12.3.2.2 Process Data Check
Function keys from F20 to F26 is used for the process data monitoring.
Normal display can be immediately accessed by pressing the NORMAL key, and that can display the item of F20 that is configured from the DEMAND SECTION of the BOI_Q.SRC source file.
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12.4 Startup/Shutdown Procedure 12.4.1 Normal Startup
1) Press F1 key, and select Startup Mode AUTO with the process mentioned in section 12.3.1.1.
2) Press F2 key, and reset master sequence MRESET with the process mentioned 3) Confirm "READY" status in the FIELD02 with F2 key on LCD. status from F10 to F19. in section 12.3.1.2 .
4) IF not (indicated NOTREADY), check a start permissive condition with command 5) When "READY" is confirmed, press F4 key, and execute turbine start command 6) Turbine is started and reached at Full Speed No Load, and automatically loaded. 12.4.2 Load Control START with the process mentioned in section 12.3.1.2.
1) Press F7 key, and select Load Control Mode BASE or PRESELEC with the 2) PRESELEC (Pre-selected load demand [MW]) 12.3.1.3. process mentioned in section 12.3.1.1.
Press F8 key, and input a target load with the process mentioned in section (a) Initial Load : 2.5 [MW]
3) BASE (Base load control)
(b) Setup range : 2.5 - 28.6 [MW]
up to 28.6 [MW] or FSR Temperature Control . (a) Base load target output : 28.6 [MW]
When BASE command is executed with F7 key , Turbine is automatically loaded
12.4.3 Normal Shutdown section 12.3.1.2. ZERO speed.
1) Press F4 key, and select STOP command with the process mentioned in 2) Turbine is automatically unloaded, shut down fuel at 75% speed and coast down to
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12.4.4 Black Start (for UNIT#9,#10 and #12 only)
1) Before startup operation, all alarms must be acknowledged and reset with the 2) Press F3 key, and select Black Start Mode BS_ON with the process mentioned process mentioned in section 12.5.2 and 12.5.3.
3) Confirm that the status BSMODE in the FIELD03 with F3 key is changed in 1 4) Press F1 key, and select Startup Mode AUTO with the process mentioned in 5) Press F2 key, and reset master sequence MRESET with the process mentioned 6) Confirm "READY" status in the FIELD02 with F2 key on LCD. status from F10 to F19. in section 12.3.1.2. section 12.3.1.1. from 0.
in section 12.3.1.2.
7) IF not (indicated NOTREADY), check a start permissive condition with command 8) When "READY" is confirmed, press F4 key, and execute turbine start command 9) After firing and warm-up (Status F20 FIELD3 changes in ACCEL), select F26 screen and confirm the following items (a) Exciter control status AVRACT changes in 0 from 1 at 44% speed. START with the process mentioned in section 12.3.1.2.
10) Select F27 screen and confirm the following items
(b) Field breaker status FLDBKR changes in 1 from 0 at 97.5% speed.
(a) Generator breaker status GENBKR changes in 1 from 0 at 97.5% speed. (b) Generator current GN AMP doesnt exceed 1492 A (100%). (c) Generator voltage GNVOLT automatically rises to 11.5 kV (100%).
11) Select F26 screen and confirm that exciter control status AVRACT changes in ----------------------------------------- PLANT OPERATION ---------------------------------------------------Aux. Trans. Circuit Breaker is closed in plant operation, then AC power for auxiliary equipment in each unit is recovered. 1 from 0 after item 10)-(c).
--------------------------------------------------------------------------------------------------------------------------12) Select F27 screen and confirm that MCC Bus voltage normal relay status 27MC1N changes in 1 from 0.
13) Start the <HMI> system, and operate with <HMI> after that.
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12.5 Alarm Display
display lists alarms in the <RST> alarm queue in order of occurrence. The last
The Alarm Display can be accessed at any time by pressing the ALARMS key. The
annunciated alarm is shown in the upper left-hand field of page 1. The Alarm Display pages are divided into four fields; the upper right-hand field shows the number of unacknowledged and acknowledged alarms and the page number of the Alarm Display. The Displays three remaining fields display annunciated alarms. If more than three alarms are annunciated, subsequent pages of the Alarm Display can be accessed by
pressing the SCROLL DOWN key. Each annunciated alarm is displayed with an alarm drop number, the status flag/acknowledge condition, and the date and time the alarm occurred. An asterisk " * " in the status flag column indicates the alarm has not been acknowledged. 12.5.1 Silence
key on the <BOI> keypad. 12.5.2 Acknowledge
To silence the audible alarm horn in the Mark V Control Panel, press the ALARM SIL
To acknowledge an alarm using the <BOI> Alarm Display, press the ALARM ACK key on the device keypad. This action acknowledges the alarm(s) exhibited in the Displays current page and increments the acknowledged alarms counter in the upper right-hand field of the backup display. The asterisk in the status flag column of the alarm(s) will change to either "1" or "0", depending on the current condition of the alarm. To
acknowledge other annunciated alarms (if present), use the SCROLL DOWN key to move to the next page of the Alarm Display and press ALARM ACK until all alarms will show "00". Alarms must be acknowledged in order to be reset (removed from the display) once the alarm condition has been corrected. have been annunciated. The unacknowledged alarm counter in the upper right-hand field
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12.5.3 Reset
be reset (removed from the display) by pressing the ALARM RESET key. (Only an acknowledged alarm with a status field value of logic "0" can be reset.) Resetting an
An acknowledged (annunciated) alarm condition that has been corrected or satisfied may
alarm causes future occurrences of the alarm condition to be annunciated with an audible signal in order to alert the operator. Failure to reset an alarm condition which has been corrected or satisfied will prevent future occurrences of the alarm from being annunciated by an audible signal; they will, however, be logged to the printer and in the Historical Log Alarm Queue.
Refer to the following drawing for the details of "Alarm drop number". ALARM LIST (DWG.NO.310V027-500).
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DELTA III AVR
HITACHI
Automatic Voltage Regulator

Description
Hitachi, Ltd.
DOC. No.AVR050601
DELTA III AVR
HITACHI
1. Overview
System Overview
The PWM regulator controls the ac terminal voltage and/or the reactive volt amperes of the generator by controlling the field of the rotating brushless exciter. Figure 1-1 shows a typical one-line system of a Permanent Magnet Generator (PMG) fed brushless generator application. Power for the regulator is normally supplied from a PMG driven directly by the main generator field. This can be a single phase or 3phase PMG The control system contains both a generator terminal voltage regulator and an exciter field current regulator. These are known as the automatic or ac regulator and the manual or dc regulator respectively. When operating under control of the dc regulator, a constant exciter field current is maintained, regardless of the operating conditions on the generator terminals. When operating under control of the ac regulator, a constant generator terminal voltage is maintained under varying load conditions. If the generator is connected to a large system through a low impedance tie, the generator cannot change the system voltage appreciably. The ac regulator, with very small variations in terminal voltage, then controls the reactive volt amperes (Var)s. If the generator is isolated from a system, the ac regulator controls the terminal voltage and the Vars are determined by the load. Most systems operate in a manner that is between these two extremes. That is, both Vars and volts are controlled by the ac regulator. Normal operation is with the ac regulator in control, with an automatic transfer to the dc regulator in the event of loss of potential transformer feedback as detected through Potential Transformer Failure (PTFD) or PT Undervoltage Detection (PTUV). In the regulator, PT Failure Detection requires two sets of PT inputs. There is automatic tracking between the ac and dc regulators to ensure a bumpless transfer in either direction. A balance signal is available for display on the operator station or turbine control interface. A transfer between regulators can be initiated by the operator or, if supplied, by the PT failure detection algorithm. Besides the regulating functions, the excitation system contains protective limiter functions, startup and shutdown functions, and operator interfaces that are implemented in both hardware and/or software. The software is accessed via an RS-232C communication link using the GE Controls Systems Toolbox (toolbox). The toolbox is used to configure and maintain regulators and exciters. It is Windows -based and consists of a collection of programs (tools) running under a command shell.
DOC. No.AVR050601
DELTA III AVR
HITACHI
DOC. No.AVR050601
DELTA III AVR
HITACHI
2. Product Overview
The regulator hardware consists of a control core and a power converter section. The controller includes printed wiring boards containing programmable microprocessors with companion circuitry, including electricallyerasable programmable read-only memory (EEPROM) where the regulator.s system blockware pattern is stored. The power converter consists of input disconnects and filters, a dc link with charge control, IGBT devices, output contactor and shunt, and control circuitry.
Hardware Design
Control Core (Regulator Module)
is accessible while the regulator is operating. Also, behind the hinged outer door, several Input/Output (I/O) boards are mounted. The control core consists of all these circuit boards interconnected by ribbon cables and harnesses, which keep wiring to a minimum. Detailed hardware information including fuse and test point information, replacement instructions and board layouts are provided in the referenced documents for each of the following circuit boards. Power Supply and Contactor Driver (PSCD) board creates internal power supplies and redistributes the necessary power supply voltages for the other control core circuit boards. An isolated 70 V dc supply is also produced and used for LTB board inputs. The PSCD board also produces the contactor coil voltage for the MDA output and charge control contactor Gate Driver and Dynamic Discharge (GDDD) controls the gating of the IGBTs for bridge output and Dynamic Discharge control. It also isolates and scales dc output, dc link voltage, shunt feedback and heat sink temperature. LAN Terminal Board (LTB) provides an interface between control devices and external devices such as contactors, relays, indicators, lights, pushbuttons and interlocks.
DOC. No.AVR050601
DELTA III AVR

Microprocessor Application Board (TCCB) contains software transducering algorithms that mathematically manipulate the inputs from the isolation and scaling printed wiring boards. These inputs are analog feedback signals from the current and voltage transformers, which monitor generator output and line voltage, and from the bridge ac input and dc output voltages and shunt feedbacks I/O Terminal Board (NTB/3TB) includes an RS-232C communication port for connecting to a personal computer (PC). The optional field ground detector inputs are connected to the NTB board. Drive Control and LAN Control Board (LDCC) controls LAN communication and permits operator access and control via the Programmer keypad. It also contains the drive control microprocessor which monitors start/stop sequencing, alarms, trips and outer loop regulators and motor control microprocessors which monitors the field voltage and current regulators, gating and overcurrent protection. Relay Terminal Board (RTBA) provides seven output relays with form C contacts available for customer use which can be driven from a remote input or directly from the relays on the LTB board. ARCNET Link (ACNA) board provides the connection point for the ARCNET LAN communications.
HITACHI
Power Converter Module
The power conversion section consists of an input section, a dc link, and the converter output section. The input section is a 3-phase diode bridge with input filters. The range of the ac input is from 90 V rms up to 275 V rms. Frequency inputs range as high as a nominal 360 Hz. It can be a single phase or three phase input from a PMG, auxiliary bus or generator terminal fed. An input PPT is not required for the PMG input. A PPT is required for an auxiliary bus or generator terminal feed. An optional voltage doubling feature is available for units requiring higher forcing capability. isolated and combined with the three-phase diode bridge output. These sources charge the power capacitors through a charge control resistor, RCH, which forms the dc link portion of the power converter module. The dc link is the unregulated source voltage for the control core power supplies and the output power through the IGBTs. A coarse control of the voltage level of the dc link is provided by the dynamic discharge circuit. This circuit will dissipate excess power from the dc link (possible due to a regeneration effect from the field of the rotating exciter) through the dynamic discharge resistor, RDD. The converter output section takes the dc link source voltage and pulse width modulates it through the IGBT devices. The output voltage is determined by the following formula:
Voutput = Vinput * (time on/(time on + time off))
where Vinput is the dc link voltage, time-on is the conduction time of the IGBT devices and time-off is the non-conduction time of the IGBTs. The chopping frequency of the IGBTs is approximately 1000 Hz. This output is fed to the rotating exciter field as a regulated voltage or current. A single pole contact from the MDA contactor isolates the regulator from the field. An output shunt monitors the field current.
The regulator application software consists of modules (blocks) combined to create the required system functionality. Block definitions and configuration parameters are stored in read-only memory (ROM), while variables are stored in random-access
Software Design
DOC. No.AVR050601
DELTA III AVR

memory (RAM). Microprocessors execute the code. Diagnostic software is transparent to the user. A programmer module with a digital display and keypad allows an operator to request parameter values and self-checks.
HITACHI
Software
The exciter application emulates traditional analog controls. It uses an open architecture system, which uses a library of existing software blocks. The blocks individually perform specific functions, such as logical AND gates, proportional integral (PI) regulators, function generators, and signal level detectors. These blocks are tied together in a pattern to implement complex control functions. For example, a control function such as the under-excitation limit (UEL) is included as an ac regulator input by setting software jumpers in EEPROM. The relevant blockware is enabled by pointing the block inputs to RAM locations where the inputs reside (the UEL requires megawatts, kilovolts and megavars). The UEL output is then pointed to an input of the ac regulator summing junction. The software blocks are sequentially implemented by the block interpreter in an order and execution rate defined in the toolbox. The blockware can be interrogated while running by using the toolbox. The dynamically changing I/O of each block can be observed in operation. This technique is similar to tracing an analog signal by using a voltmeter.
AC and DC Regulators
The ac or automatic regulator and, dc or manual regulator are software functions again emulating traditional analog controls. The ac regulator reference is from a static counter and is compared to the generator terminal voltage feedback to create an error signal. In addition to the reference signal input to the ac regulator summing junction, the following inputs can be used to modify the regulator action.
Reactive Current Compensation (RCC): The generator voltage is allowed to vary in order to improve reactive volt amp (VA) sharing between generators connected in parallel. Generator voltage decreases as overexcited reactive current increases, and increases as underexcited reactive current decreases. Under-excitation Limit (UEL): Under-excited Vars must be limited to prevent heating of the generator iron core and to ensure dynamic stability of the turbine generator. This is done by an under-excitation limiter that takes over when a specified limit curve is reached and prevents operation below this limit. V/Hz: The ratio of generator voltage to frequency (V/Hz) must be limited. This prevents overfluxing the generator and/or line-connected transformers caused by overvoltage operation or under-frequency operation, or a combination of the two. Over-excitation Limiter (OEL): It is necessary to limit generator excitation current off-line to prevent overfluxing the generator and connected transformers. Online, it must be limited to prevent field thermal damage. The limiting action is performed by the excitation current regulator. The current regulator takes control of bridge gating if the regulator (automatic or manual) calls for exciter field excitation current in excess of a predetermined pick-up level. The dc or manual regulator is configured as a field current regulator using shunt feedback and comparing it to the manual regulator static adjust reference. It will maintain a constant exciter field current based on the setpoint adjuster. The online and offline field current regulators are low value gate selected with the inner loop regulator output to select the appropriate firing level for the IGBT bridge.
DOC. No.AVR050601
DELTA III AVR

Scaling
It is necessary to scale the software in each exciter for application with a particular generator. The regulators use normalized values of counts to represent one per unit (1 pu). Typically 1 pu equals either 5000 or 20000 counts. This means that the feedback value for a particular variable, such as dc link voltage (VDCLINK = 1 pu) or bridge current (AFFL = 1 pu), must be normalized by using a multiplier to equal the prerequisite value of counts when it is at 1 pu.
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Faults
The EX2000 exciter has a sophisticated self-diagnostic capability. If a problem occurs, a fault code flashes in the programmer display showing a fault name and number. The fault number also appears on the display on the LDCC in coded form.
Simulator
Located within the core software is a sophisticated system simulation program that models the exciter and generator behavior. The simulator is activated via a software jumper in EEPROM. Signals representing the field and the generator feedbacks are simulated in the microprocessor application board (TCCB) and fed to the transducering algorithms, in place of the real feedbacks. Once the exciter is scaled for a particular generator, the simulator uses that scaling. For example, after a successful startup sequence is performed in simulator mode, the operator interface will displays the exciter voltage and current and generator voltage applicable to that particular unit.
3. Software System Overview

Standard Functions
Figure 3-1 is a system overview of the AVR. Details are as follows:
Automatic Voltage Regulator (AVR) Ramp
The AVR ramp block accepts an input from the operator through the Status-S page for auto regulator raise or lower. The reference then ramps at a predetermined rate, within an upper and lower limit (usually 0.9 to 1.1 pu terminal V). The output can be preset to a value upon startup. Automatic tracking of the AVR track value is performed when operating in manual regulator (refer to Figure 3-2).
Automatic Voltage Regulator Setpoint
The AVR setpoint block sums the output from the reactive current compensation (RCC), AVR ramp, UEL output. This sumis compared to the V/Hz reference in a minimum select block and then passed through a high limiter as the AVR output signal. By selecting a negative or positive gain, line-drop or droop compensation mode may be selected on the RCC. An auto/manual command by the operator generates auto active or manual active status indicators. A PT failure can also select manual (refer to Figure 3-3).
DOC. No.AVR050601
DELTA III AVR

Automatic Voltage Regulator
The AVR block combines the AVR setpoint with the negative generator terminal volts to provide an error signal. This is passed through to the automatic regulator proportional and integral gain sub-blocks, and then passes through the auto regulator limits to the manual voltage regulator (refer to Figure 3-4). The auto regulator is modeled by the following transfer function:
AVR out = AVR error (Kp + KI)/S
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Field Regulator (FVR) Ramp
The FVR ramp block accepts an input from the operator through the Status-S page for manual regulator raise or lower. The reference then ramps at a predetermined rate within an upper and lower limit (usually 0.7 pu VFNL to 1.2 pu VFFL). The output can be preset to a value upon startup. When in auto regulator mode, the FVR ramp tracks the value of exciter field current (IFE) (refer to Figure 3-5).
Field Regulator
The exciter field regulator is configured as a current regulator. The reference input to the FVR is from either the manual regulator ramp block or the AVR. When fed from the AVR, the field regulator is used as an inner loop. A bridge firing enabled signal is also provided to keep the exciter turned off until bridge firing is enabled (refer to Figure 3-6).
Under Excitation Limiter (UEL)
The UEL blocks accept watts and volts as inputs and calculates a VAR reference. Using a table lookup, which approximates the underexcited capability of the generator, the Var reference is then compared to the actual unit Vars to develop a Var error signal. The error signal is then passed through a proportional and integral regulator sub-block to keep the machine within its underexcited capability (refer to Figure 3-7)
Over Excitation Limiter (OEL)
The alternate current regulator is initially enabled. If the signal level detect looking at exciter field current or either of the inverse time protection blocks activate, the alternate field current regulator is disabled and the primary current regulator setpoints are active. The output of either the alternate or primary field current regulator is fed to the firing block where a minimum select with the field regulator firing command is performed (refer to Figure 3-8).
Firing Block
The firing block accepts the field current reference and the field voltage reference and then selects the least of the two. This signal is passed on to the bridge only if the instantaneous overcurrent or the stop commands are not activated. If either of these are active, the firing signal is a preset retard limit (refer to Figure 3-9).
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DOC. No.AVR050601
DELTA III GCP
HITACHI
Generator Control Panel

Description
Hitachi, Ltd.
DOC. No.GCP050601
DELTA III GCP
HITACHI
Equipment
Digital Generator Protection (DGP) uses microprocessor technology to obtain a numerical relay system with a wide range of protection, monitoring, control, and recording functions. The display consists of 16 LED alphanumeric positions. Remote programming and data acquisition is possible through a dedicated RS-232C interface. Feature Description
Generator volts/hertz oroverexcitation (24G) Protects the generator and generator main step-up transformer from excessive volts/hertz (magnetic flux) conditions. Both alarm and trip relays are included. Generator undervoltage (27G) Will not allow the generator to be synchronized to the power system unless the voltages are matched. Reverse power or anti-motoring (32) Protects the turbine-generator from being motored by monitoring the direction of the real power flow. Loss of excitation (40) Detects loss of excitation on the generator. It includes two mho characteristics, looking into the generator, each with adjustable reach, offset, and time delay. Negative phase sequence or unbalanced current (46) Protects the generator field from being overheated by providing an operating characteristic described by I22T=K. There is an alarm and trip setpoint. Backup system phase overcurrent with voltage restraint (51V) Protects the power system against prolonged generator contribution to a fault on the system. This function is incorporated in the DGP to provide part of this system backup protection. Generator overvoltage (59G) Functions as a backup to the volts/hertz (24G) protection. against excessive terminal (stator) voltage. It protects the generator
Generator stator ground fault (64G) Consists of two overlapping zones (64G1 and 64G2) to detect stator ground faults in high-impedance grounded generator systems. The two zones together cover 100% of the stator windings. Generator overfrequency (81H) Protects the turbine-generator from overfrequency operation by providing two setpoints with adjustable time delays. Generator differential protection (87G) Provides high-speed protection of a generator stator during internal phase-to-phase, and three-phase faults. Voltage transformer fuse failure (VTFF) Detects the loss of ac voltage upon failure of one or more of the transformer fuses. Tripping from functions 40 and 51V is blocked; however, all other functions are allowed to trip.
Generator Digital Multimeter can accept either a wye-wye or open delta PT input. However, when an open delta PT input is used, the phase-to-neutral voltage reading is not displayed. This single meter provides the following functions: V - Volts: 1-2, 2-3, 3-1, 1-N, 2-N, 3-N
DOC. No.GCP050601
DELTA III GCP

A - Amps: Phases 1,2,3 and Neutral MW - Megawatts Mvar - Megavars Hz - Frequency MVA - MVA PF - Power Factor MWh - Megawatthours MVAh MVAhours
HITACHI
Generator Lockout Relay (86G-1) trips the generator breaker, the turbine, and the excitation system Ground Protection (59BN) This protection scheme is designed to protect the system (station bus) from ground faults. The function device nomenclature is 59BN. This function requires wye-wye four-wire neutral (or one phase) grounded PT and auxiliary PTs in a broken delta configuration (to measure the zero sequence voltage). A current limitting resistor bank (CLR) is placed on the secondary of the broken delta to minimize ferroresonance. DC Blown Fuse Protection (74) scheme is designed to increase the reliability of dc tripping busses, which provide power to the main protective relays, such as lockout circuits. Each lockout tripping circuit is fused independently in the generator protection panel. Power Feedback (96GG, 96GW) The main purpose of this system is to provide power feedback to speed governing control in place of the conventional fuel command feedback to make the droop setting constant even when the fuel heating value varies. Synchronizing Undervoltage Relays (27BS-1, 2) are used in conjunction with the synchronizing scheme to provide additional inputs to help determine whether the generator can be synchronized to a live or dead station bus.
DOC. No.GCP050601
DELTA III GTCP

HITACHI
GAS TURBINE CONTROL PANEL

Description
Hitachi, Ltd.
DOC. No.GTCP050601
DELTA III GTCP

HITACHI
The general specifications do not purport to cover all details or variations in equipment, nor to provide every possible contingency to be met during installation, operation, and maintenance. If further information is desired or if particular problems arise that are not covered sufficiently for the purchasers purpose, the matter should be referred to the instruction manuals. Section Page Introduction ....................................................................................................... 3 Control Modules ................................................................................................... 3 Protection Module.......................................................................................... 4 Software Voting......................................................................................... 4 Built-in Diagnostics......................................................................................... 5 Backup Interface ........................................................................................... 5 Memory ......................................................................................................... 5 Application Software......................................................................................... 6 Hardware Inputs and Outputs .............................................................................. 6 Operator-Maintenance Interface ......................................................................... 10 Log Functions ..................................................................................................... 10 Enclosures and Packaging .......................................................................... 10 Environmental Requirements........................................................................ 11 Power Requirements ........................................................................................... 11 Codes and Standards ...................................................................................... 12 Mark V I/O Capacity.......................................................................................... 12
ARCNET is a registered trademark of Datapoint Corporation. Ethernet is a trademark of Xerox Corporation. Modbus is a trademark of Gould, Inc. SPEEDTRONIC is a trademark of General Electric Company, USA.
DOC. No.GTCP050601
DELTA III GTCP
Introduction
HITACHI
Control Modules
The SPEEDTRONIC. Mark V is a fully programmable turbine control system designed to meet the needs of today.s power generation industry for the complex, dynamic behavior of gas and steam turbines. It is a flexible control system that delivers state-of-the-art control, monitoring, and protection. The Mark V utilizes GE.s extensive turbine control application and design experience with modern electronic hardware and software. This allows operators immediate access to all major control functions, extensive monitoring capabilities, and many built-in features that automatically protect the turbine-generator from a variety of abnormal operating conditions, such as over speed, excess vibration, and excess exhaust temperature . Features of Mark V include: . software-implemented fault tolerance . triple modular redundant (TMR) architecture . direct sensor interface . built-in diagnostics . common hardware platform for gas and steam applications
The identical controllers, <R>, <S>, and <T>, in a Mark V TMR configuration perform all the critical control algorithms, protective functions, and sequencing. They also acquire the data needed to generate outputs to the turbine. Protective outputs are routed through the module consisting of triple redundant processors X, Y, and Z, which also provide independent protection for certain critical functions such as over speed. All three controllers acquire data from triple-redundant sensors as well (as from dual or single sensors). The actual number of sensors will depend on the turbine type. All critical sensors for continuous controls, as well as protection, are triple-redundant. The <C> controller is the interface for non-critical and non-trip I/O, and provides operator-maintenance interface through two ARCNET_ ports. All operator commands and monitoring are performed from this interface, and all maintenance functions, including changing control constants, editing application software, changing I/O assignments and editing displays. All of the microprocessor-based controllers have a modular design for ease of maintenance. Each module or controller contains up to five boards, including a power supply. Multiple microprocessors residing in each controller distribute the processing for maximum performance. Individual microprocessors are dedicated to specific I/O assignments and application software. The communication processing is performed in a real-time, multi-tasking operating system. The controller boards use ribbon cables and gas-tight connectors. Communication between individual controllers is performed on high-speed ARCNET links.
DOC. No.GTCP050601
DELTA III GTCP

HITACHI
Protection Module
The protection module, provides a second level of protection for critical functions. It contains three sets of identical boards (X, Y, and Z) each with its own power supply and processor. These are used to provide separate relay drivers and relays for each of the <R>, <S>, and <T> controllers prior to interfacing with the hydraulic trip solenoids. The module also provides flame detection and automatic synchronization functions. Software Implemented Fault Tolerant (SIFT) and hardware voting are used by the Mark V control system. At the beginning of each computing time frame, each controller independently reads its sensors and exchanges this data with the data from the other two controllers. The median values of each analog input is calculated in each controller and then used as the resultant control parameter for that controller. The diagnostic algorithm monitors a predefined deadband for all analog inputs to each controller. If one of the analog inputs deviates from this deadband, a diagnostic alarm is activated to alert maintenance personnel. Contact inputs are voted in a similar manner. Each of the contact inputs is connected to a single terminal point and is parallel wired to three contact input boards. Each board optically isolates the 125 or 24 V dc input. A dedicated 80196 processor, located in each board, time stamps the input to within one millisecond resolution. These signals are then transmitted to the <R>, <S>, and <T> controllers for voting and execution of the application software. Redundant contact inputs for functions such as low lube oil pressure, are connected to three separate terminal points and then voted individually. The SIFT technique enables the control system to accept multiple failures of contact or analog inputs without causing an erroneous trip command from any of the three controllers as long as the failures are not from the same circuit. Another form of voting is accomplished through hardware voting of analog outputs. Three coil servos on the valve actuators are separately driven from each controller, and three LVDTs provide the position feedback. The normal position of each valve is the average of the three commands from <R>, <S>, and <T>. The resultant averaging circuit has sufficient gain to override a gross failure of any controller, such as a controller output being driven to saturation. Diagnostics monitor the servo coil
Software Voting
DOC. No.GTCP050601
DELTA III GTCP

currents and the D/A converters in addition to the LVDTs.
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Built-in Diagnostics
Backup Interface
The Mark V has extensive built-in diagnostics, including power up, background and manually initiated diagnostic routines. These routines are capable of identifying both control panel, sensor, and output device faults. These faults are identified down to the board level for the panel, and to the circuit level for the sensor or actuator component. Online replacement of boards is possible with the Mark V triple redundant design and is also available for those sensors where physical access and system isolation are feasible. If the operator interface becomes unavailable, a small backup interface is provided on the Mark V cabinet door. It has a liquid crystal display (LCD) with two lines of 40 characters per line to display essential control parameters and alarms. The Mark V accepts operator commands from this backup interface. Memory is located in the individual controllers and in the personal computer (PC) used by the operator interface. Controllers have electrically/erasable programmable read only memory (EPROM) for fixed memory, random access memory (RAM) for volatile memory, and electrically erasable programmable read-only memory (EEPROM) for permanent storage of up-to-date application software. Changes to sequencing, I/O assignments, gains, and such can be made from the operator interface and stored in the individual controller's EEPROM. All sequencing can be edited in ladder diagram format through the operator-maintenance interface. Changes to control constants such as gains and offsets can be made while the turbine is online by entering a security code. The hard disk of the PC has a copy of all application software and display programming. Alarm messages can be added and changed. Text for existing displays can be changed or new displays can be created. The I/O tag names can be added or changed in standard 12-character lengths as well as descriptive 40-character fields. These changes are stored on the hard disk.
Memory
Application Software
Application software is created from in-house software automation tools that select proven GE control and protection algorithms and integrate them with the I/O, sequencing, and displays for each application. Fixed-point data can be run at a frame of 62.5 ms (16 Hz). The frame rate is the elapsed time it takes to read control inputs, condition the inputs, execute the application software, and send output commands to the control valves. Changes to the application software can be made with password protection and downloaded to the control module while the turbine is running. All application software is stored in the control module in nonvolatile EEPROM memory. Application software is executed sequentially and is represented in a ladder diagram
DOC. No.GTCP050601
DELTA III GTCP

format. A library of software building blocks allows maintenance personnel to add or change analog loops and sequencing logic. Math blocks are also available. Application software documentation, including the primary elementary diagram, I/O assignments, and the settings of tuning constants is created directly from the source code and can be printed at the site.
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Hardware Inputs and Outputs

The Mark V I/O is designed for direct interface with the following turbine and generator devices: . magnetic speed pickups . servos and LVDT/Rs . vibration sensors . thermocouples . Resistive Temperature Devices (RTDs) Contact Inputs: The Mark V uses the 125 V dc bus from the internal power distribution core to provide a fuse isolated and current limited interrogation voltage for the contact inputs. Other input voltages between 24 V dc and 125 V dc can be used, however, they may require a power source external to the Mark V. Jumpers on the terminal boards can be used to isolate field grounds by disconnecting the interrogation voltage from the contact inputs in groups of eight. Every contact input is optically isolated and receives a time stamp within 1 ms of a status change. The Mark V printer can log each contact input status change with the time stamp, if that input is selected for sequence of events (SOE) logging. Diagnostic circuitry tests the internal electronics of each contact input every 1 ms and initiates an alarm if the circuitry fails. Contact and Solenoid Outputs: The Mark V exclusively uses plug-in type magnetic relays for contact outputs (no solid state outputs). All contacts are form C; three wire; one normally open and one normally closed contact with a common center conductor. In a TMR system, the three controllers <R>, <S>, and <T> separately determine the contact output status and the two out of three voting takes place at the relay driver. If the three controllers do not agree, a diagnostic alarm is annunciated. By selecting jumpers on the terminal boards, certain outputs can be internally powered by 125 V dc or 115 V ac. Elector-mechanical relay contacts are factory rated at:
Volts 120 ac 220-240 ac 125 dc 28 dc Inductive 2A 2A 0.2 A (no suppression) 2A Resistive 3A 3A 0.5 A 3A Other 10 A in-rush 10 A in-rush 0.5 A (with suppression)
Temperature Monitoring: The Mark V control can monitor grounded and ungrounded thermocouples and RTDs with linearization for various sensor types provided in software. The Mark V supports the following types:
Thermocouple E J K T RTD 10 ohm copper 100 ohm platinum 120 ohm nickel 200 ohm platinum
Analog Inputs and Outputs: Most of the analog inputs to the Mark V come directly from transducers on the turbine such as vibration or speed sensors however, 4-20 mA
DOC. No.GTCP050601
DELTA III GTCP

and 0-1 mA inputs are provided for other types of transducers. Each analog input can receive isolated 21 V dc excitation power for the transducer from the Mark V. Jumpers are provided for such selections as current or voltage input, burden resistor size, and grounding options. Some inputs can be used as either voltage or current inputs by selection of a jumper. In current input mode, a burden resistor produces a voltage from the transducer current. This voltage is then internally parallel wired with ribbon cables to the <R>, <S>, and <T> controllers. Any discrepancy between the three controller inputs is annunciated as an internal diagnostic fault while the control and protection system continues to perform their normal calculations based on the median signal. Additional diagnostics monitor the inputs to insure that they are within their proper range. Both 4-20 mA (500 . max burden) and 0-200 mA (40 . max burden) analog current outputs are available. These outputs can be independently configured from the Mark V operator interface, and are typically used for driving remote instrumentation for monitoring. Pulse Rate Inputs: The most common application for the pulse rate inputs is monitoring the turbine shaft speed with magnetic speed sensors. These sensors fall into three categories: . sensors which feed <R>, <S>, and <T> . TTL type inputs which feed <R>, <S>, and <T> . sensors which feed The Mark V can interface with the standard passive or the optional active speed sensors with an effective frequency range of 2 to 10,000 Hz. Circuit sensitivity allows detection of a two-rpm speed on a 60-tooth wheel to determine whether the turbine is stopped or on turning gear. Six magnetic speed sensors can be monitored by each of the <R>, <S>, and <T> controllers. One additional magnetic pickup is paralleled to all three controllers. A typical application has three speed sensors wired independently to each <R>, <S>, and <T> controller. The voting software then selects the median value for the governing speed parameter and the primary overspeed trip signal in the TMR systems. Turbines which do not have a mechanical bolt for the backup emergency overspeed protection require a totally separate and independent set of electronics for emergency trip protection. This is provided by the three boards in the module which has independent power supplies and processors. Each board can interface with two speed sensors, and the overspeed trip settings are adjustable. Master Trip Circuit: Turbine protection in the Mark V control system is performed by multiple cores within the control panel. There are two parts to the Master Trip Circuit: the inputs to the Mark V and the outputs from the Mark V. The hardwired or remote trip inputs to the Mark V (contact open to trip) connect to the 4.s relay coils (known as the 4.s for the ANSI standard device number). This circuit has redundant relay coils connected to the positive dc bus in series with the external trip contact inputs and another set of redundant relay coils connected to the negative bus. A failure of any one of the 4.s relay coils will not accidentally trip the turbine because the resultant hardware contact will out vote the failed relay. Only deenergizing both relays connected to the same (positive or negative) dc bus will trip the turbine. If an external trip signal is received, the 4.s trip circuit will de-energize and the voting contacts circuit will de-energize the internal 24 V dc protective bus. The 24 V dc protective bus then supplies all the primary trip relays (PTRs), emergency trip relays (ETRs), and other relays, which interface with the turbine trip solenoids. These PTRs and ETRs comprise the output portion of the Master Trip Circuit. The microprocessors on these protection boards monitor the status of the hardwired or remote trip inputs, however, the actual tripping is independent of any processors. Servo Valve Interface: The Mark V can control servo valves with up to three coils. In a typical TMR system, <R> is connected to one coil, <S> is connected to the
HITACHI
DOC. No.GTCP050601
DELTA III GTCP

second coil, and <T> is connected to the third coil of a three-coil servo valve. Bipolar current outputs are provided for 10, 20, 40, 80, and 120 mA ranges. The current of each servo valve output is the result of the comparison of a reference value and a feedback value by a digital control regulator defined for that output. The three currents through three coils wound around one steel laminated core produce one magnetic field. This magnetic field moves a valve that control the flow of high pressure oil to the actuator. This is a form of hardware voting, where the individual outputs of the redundant control processors are voted (summed) by the action of the servo valve.s coils. This avoids a potential single point failure within the electronics from tripping the turbine. A failure of a controller, its output port, or the physical connection to the output coil will result in the other two servo drivers compensating for the failed channel and keeping the valve properly positioned. LVDT or LVDR position feedback, flow-rate feedback and pressure feedback are the different types of feedback signals that are used by the control regulators. The Mark V control provides the excitation signals for the LVDTs and monitors their feedback. Vibration Measurement and Protection: Seismic (velocity) type sensors can be directly connected to the Mark V. In TMR systems, a discrepancy between the three control processors inputs is alarmed as an internal diagnostic fault message while the vibration protection system continues to perform its normal calculations based on the median vibration signal. Communication Interface: The Mark V system has powerful features for customizing control strategy for eachsite. For example, one operator interface can interface to multiple systems or more than one operator interface can communicate to a single Mark V. A hierarchy of control can be programmed on-site when multiple operator interfaces are used. Communication links to a Distributed Control System (DCS) or remote computers are available. These links include a Modbus. link or an Ethernet. TCP/IP link using GE Standard Messages as the application protocol. Synchronization Interface: Automatic synchronization is available by way of single-phase PT inputs from the generator and line. The control matches the turbine speed to the line frequency and the generator and line voltages. Three Mark V internal functions must be satisfied before a breaker close command is issued: . synchronize permissive or complete sequence from <R>, <S>, and <T> (25P) . sync check from <R>, <S> and <T> (25X) . automatic synchronization signal from <X>, <Y>, and <Z> in (25) A normally open contact on the breaker (not an auxiliary relay) is monitored to measure the actual time it takes to close the breaker. This time is used for selfadaptive adjustments of the breaker closure anticipation time constant and diagnostics. A maximum of two breakers can be controlled.
HITACHI
Operator-Maintenance Interface
The Mark V system.s primary operator interface consists of an IBM-compatible PC, color monitor, keyboard, cursor positioning device (either touch screen and/or trackball or mouse) and a printer. The operator interface is used to issue commands to start/stop the unit, load/unload the unit, manage and log alarms, and monitor unit operation. With the exception of the Plant Load Control option, no control or protection of the unit is accomplished by the operator interface. The operator interfaces are connected to a Mark V panel(s) with coaxial cable using ARCNET Local Area Network (LAN) communication. This connection between the operator interfaces and Mark V control panel(s) is call the Stage Link. In some cases, the Stage Link may include fiber optic cables and repeaters in order to accommodate long distances between the operator interface computers and the turbine control panel. The operator interface can also be used to configure or modify the control, protection, monitoring, and logging functions of the Mark V using programs supplied on the interface computer. The ability to modify or configure these functions is password protected
DOC. No.GTCP050601
DELTA III GTCP
Log Functions
HITACHI
Log functions include:
Alarms are logged as they occur and as they clear with a 62ms resolution. Up to 63 turbine parameters can be logged.
Enclosures and Packaging
The standard turbine control enclosure is a NEMA-1, convection-cooled cabinet with front access and top or bottom cable entrances. Panel material consists of hot-rolled, low carbon, 12-gauge steel (.105 in) with one exception, the access plates use thicker gauge (.187 in) steel. The paint build thickness for E-coat and powder painted parts is approximately 1.5 mils. The color of the exterior and interior is ANSI-70 (light) gray. It is rated for continuous operation in a 0 . 45C ambient and operation up to 50C during maintenance periods.
Note GE recommends locating this microprocessor-based product in an airconditioned environment. Other types of enclosures are available with built-in cooling and purification systems as required by specific applications. Printed circuit boards and terminal boards in a Mark V control panel are contained in, or are mounted on cores. Cores are sheet metal housings that can have stationary and moveable printed circuit board holders called board carriers. The cores have a maximum of five printed circuit boards mounted on the carriers. As many as four I/O terminal boards can also be mounted on a single core. Terminal boards are highdensity compression-type terminals.
Panel Specifications Panel Type TMR Weight 1000 lbs (453.6 kg) Heat Dissipation 700 W Dimensions 54 in x 20 in x 90 in (1372 mm x 508mm x 2286 mm)
Environmental Requirements
Power Requirements
Environmental requirements during operation: Ambient temperature 0 to 45 C Relative humidity 5 to 95% non-condensing Seismic capability Designed to Universal Building Code (UBC- Seismic Code section 2312 Zone 4) Vibration 1.0 G horizontal, 0.5 G vertical at 15 to 120 Hz Surge Designed to ANSI C37.90.1 Radio interference Operation of a 5 W radio transmitter at 27 MHz, 150 MHz, and 480 MHz will not disrupt operation. Note: Panel doors must be closed. Altitude 2000 m maximum Mark V panel can accept power from multiple power sources. Each power input source (dc and two ac sources) should be fed through its own external 30 A 2 pole thermal magnetic circuit breaker before entering the Mark V panel. Power sources can be any combination of a 125 V dc source and/or up to two 120/240 V ac sources. Each core within the panel has its own power supply board all of which operate from a common 125 V dc panel distribution bus.
DOC. No.GTCP050601
DELTA III GTCP

Voltage Power Source Requirements Frequency
HITACHI
Current Draw (measured at nominal voltage) Typical 7.0 A dc (Note 1) 7.0 A RMS (Notes 2 and 4) 3.5 A RMS (Notes 3 and 4)
Nominal (Tolerance range) Nominal (Tolerance range) 125 V dc (100 to 144 V dc) (Note 5) N/A 120 V ac (108 to 132 V ac) (Note 6) 60 Hz (47 to 63 Hz) 240 V ac (216 to 254 V ac) ( Note 6) 50 Hz (47 to 63 Hz) 1 - Add 0.5 A dc continuos for each dc solenoid powered 2 - Add 6.0 A RMS for a continuously powered ignition transformer (2 maximum) 3 - Add 3.5 A RMS for a continuously powered ignition transformer (2 maximum) 4 - Add 0.5 A RMS continuos foe each ac solenoid powered (inrush 3.0 A) 5 - Ripple not to exceed 10 V peak-to-peak 6 - Total Harmonic Distortion not to exceed 7.0%
Codes and Standards

Standard Safety Standards
Mark V General Standards Description UL 508A Safety Standard, Industrial Control Equipment CSA 22.2 No. 14, Industrial Control Equipment Printed wire board assemblies UL 796 Printed Circuit Boards UL-Recognized PWB Manufacturer, UL file no. E110691 ANSI IPC Guidelines ANSI IPC/EIA Guidelines Electromagnetic Compatibility (EMC) EN6100.4.2, Electrostatic Discharge Susceptibility Directive 89/336/EEC ENV 5014:1993, Radiated RF Immunity EN 50082.2:1994, Generic Immunity Industrial Environment EN 6100.4.4, Electrical Fast Transient Susceptibility EN 6100.4.5, Surge Immunity EN 50141, Conducted RF Immunity EN 50081.2, Generic Emissions Standards EN 55011:1991, ISM Equipment Emissions (CISPR.11) Low-Voltage Directive 72/23/EEC EN 61010, Safety of Electrical Equipment, Industrial Machines IEC 529, Intrusion Protection Codes/NEMA-1/IP/20 Machinery Directive 89/392/EEC EN 60204-1, Electrical Equipment for Machines EN 292-1, Basic Terminology, Methodology EN 954-1, General Design Principals PrEN 50100-1, ESPD General Requirements
ISO Certifications Standard Description ISO 9001 In accordance with Tick IT by Quality Management Institute (QMI) ISO 9000-3 Software certified to Quality Management and Quality Assurance Standards, Part 3: Guidelines for the Application of ISO 9001 to Development Supply and Maintenance of Software
Mark V I/O Capacity

I/O Type Contact inputs Contact outputs Pulse rate inputs LVDT/R position inputs Servo value inputs Vibration - seismic Thermocouple inputs RTD inputs
Qty 96 96 60 19 4 6 16 4 4 12 87 30
Comments 96 paralleled to <R><S><T> and 96 to <C> Paralleled to <R><S><T> (TMR only) 125 / 24 V dc, optical isolation 60 from <R><S><T> and 60 from <C> Magnetic relays, dry contacts, form C Magnetic pickups: 6 to each of <R><S><T>, 5 par TTL Magnetic pickups: 2 to each of X Y Z in 7 V rms, 3 kHz 70 mA 10, 20, 40 mA 10, 20, 40, 80, 120, 240 mA Paralleled to <R><S><T> 15 to each of <R><S><T> and 42 to <C> To <C>
10
DOC. No.GTCP050601
DELTA III GTCP

4 . 20 mA inputs 29 4 . 20 / 0-1 mA inputs 1 4 . 20 mA outputs 16 4 . 20 mA / 0-200 mA outputs 2 10 V dc inputs 8 0 . 5 V dc inputs 6 15 paralleled to <R><S><T> and others to <C> 1 paralleled to <R><S><T> 16 from <C> Valve positioners from <R><S><T> 2 to each of <R><S><T>, 2 paralleled to<R><S><T> 2 to each of <R><S><T>
HITACHI
11
DOC. No.GTCP050601
DELTA III GTCP Attachment

Extracts from the Instruction Manual D-38. <Q> Core - Pulse Rate Inputs on QTBA Terminal Board D-62. Core - Emergency Overspeed Magnetic Pickups on PTBA D-56. Core - Emergency Trip Pushbutton Connections on PTBA D-59. Core - Emergency Trip Circuit -Gas Turbine Figure 7-1 Simplified Block Diagram - TCEA Cards Mark V Case Layout
HITACHI
DOC. No.GTCP050602

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Note; GAC is arranged near the Generator.

GAC PANEL NO.1

GAC PANEL NO.2

Generator Generator Control Panel (GCP)

(closed the door)

SIGNAL LAMP (52G OPEN/52G CLOSE)

HANDLE with key

NP3: NEUTRAL GROUNDING / EQUIPMENT

PANEL NO. 3 NP3: NEUTRAL GROUNDING / EQUIPMENT

PANEL NO. 2 NP2: SURGE ABSOBER / VT,SA & LA

PANEL NO. 1 NP1: GENERATOR / BREAKER

Shop tour (Omika works) June. 20, PM

June 2005 Hitachi, Ltd.

H25 GAS TURBINE CONTROL SYSTEM

In case of Black Start Operation

LEVEL1 Navigation : Unit select

LEVEL2 Navigation : Functions select

LEVEL3 Navigation : Sub menu for

ALARM Viewing Windows

2.3 Start-up Permissive

2.2 Mode Select

2.4 Start Select

2.5 Startup Sequence check

Unit Control Display

2.2 Auto Mode select mode.

2.3 Check start-up permissive

2.5 Start-up Sequence Complete

3.2 Display Configuration 1.

Operator selector control push buttons.

- disables all the MKV synchronizing functions.

the BREAKER CLOSE control button shown in the

Monitor Monitor - enables Sync Monitor mode. This allows automatic

3.2.1.2 MANUAL MODE FUNCTIONS: Manual Control section

Turbine speed/load raise.

- Turbine speed/load lower. Generator voltage KV/VAR setpoint raise.

- Generator voltage KV/VAR setpoint lower.

Auto mode is selected as default setting.

(c) Monitor Synchroscope

(d-2) Calibration of Frequency

(e) Close Generator Circuit Breaker (52G)

4.2.3 Base load select

4.2.1 Inching operation

4.2.2 Input demand target

Unit Control Display

4.2 Change output 1) 2) 3)

4.2.1 Inching operation (One shot) Raise Lower

Lower button Decrease Decrease

4.2.2 Input demand target

4.2.3 Base Load select

5 Generator Control Operation

Unit Control Display

AVR Off FVR Auto

- enables AVR Control Mode.

- enables FVR Control Mode.

MANUAL MODE FUNCTIONS:

5.3 AVR/FVR Control:

In FVR mode, Volt is regulated by Raise/Lower PB manually. 5.4 EX2000 fault:

6.2 Stop select