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Steve's Plant Specifics

  1. What happens at ABN when communication with the PLC that controls the unit output is lost?
    Units will offload to 80% for 4 hours and then to a controlled ramp down if communication is not re-established
  2. How would you shut down ABN G1 or G2 in an emergency?
    There are no stop buttons for G1 or G2???  It was confirmed with SFM, Bill Herman that it is acceptable to shut down G1 or G2 by opening the unit CB’s.  They will go through a shut down sequence after a period of time.
  3. Are there any environmental water control issues at ABN?
    No
  4. What supervisory controls do you have at ABN?
    Stop and re-synch only
  5. Where is ABN located?
    Near Cranbrook
  6. If a unit at ABN tripped offline how would you go about getting it restarted?
    Call-out, they can only be started locally
  7. FYI – Who’s the SFM (Subforeman) for ABN
    Bill Herman
  8. What would you do if both units were running at ALH, 500 CMS respectively, the forebay is at 431 meters and one unit trips and locks out @ 6 AM on Monday?
    • Forebay is irrelevant, unit locked out (cannot start or re-sync).
    • Loch keepers hours for weekday = 0600 – 1600 M-F
    •  
    • Call lock keeper to initiate RGO, if they cannot be contacted initiate remotely.  Notify FBC to callout ALH electrician, if operated remotely get a hold of loch keeper to reset alarms and lower gates in co-ordination with ALH unit restoration.

    Crow

    Complete CM implementation.
  9. What would you do if both units were running at ALH, 500 CMS respectively, the forebay is at 431 meters and both unit trip to SNL @ 5 AM on Monday?
    • Check that 2L290 / 81 L did not kick out.
    • Forebay is below 433 so the 24 minute channel stability timer will prevent governor set point changes.
    • Loch keepers hours for weekday = 0600 – 1600 M-F 
    •  
    • Initiate RGO to restore flows.
    • Dispatch Lock keeper to reset alarms and to co-ordinate restoration with ALH
    • Contact FBC to dispatch electrician

    Crow

    Complete CM implementation
  10. What would you do if both units were running at ALH, 500 CMS respectively, the forebay is at 433.5 meters and both unit trip to SNL @ 5 AM on Monday?
    • Check that 2L290 / 81 L did not kick out
    • Forebay is above 433 so the channel stability timer will not prevent governor set point changes.

    Re-sync units and load OAT.  ** must be OAT to prevent plant gross trip, see AO7 section 6.7**

    Notify FBC

    Crow
  11. What would you do if both units were running at ALH, 500 CMS respectively, the forebay is at 433.5 meters and one unit trips to SNL @ 3 PM on Saturday?
    Re-sync and load unit

    Notify FBC

    Crow
  12. What prevents governor set point changes when the FB is below 433m at ALH?  Why did ALH implement this sort of protection?
    24 minute Channel stability timer.  Pressure differential in the FB caused by flow changes through the units resulted in the concrete channel liner heaving.  This protection scheme was implemented to prevent future damage.
  13. For any operational procedures at ALH what document would you refer to?
    AO7
  14. Who dispatches electricians to ALH?
    FBC, we do not dispatch non-Hydro employees.
  15. Who holds AOR on HLK?  Where do you find this information?
    Columbia Basin Generation, field staff, 1J-11
  16. At HLK how do you lower the RGO gates once they have been raised?
    Can’t remotely, Loch keepers need to lower locally in co-ordination with ALH unit restoration.
  17. What does the RESET button do on the HLK RGO display?
    It resets the PLC input to the RGO and allows for the flow signal to populate in the event the remaining in service unit trips.
  18. After an HLK RGO operation what is the final implementation that must be completed?
    A web CM implementation must be completed to record the gate movement.
  19. What water course is ALU part of?  What plants are downstream of ALU
    Stave River System, ALU – SFN – RUS
  20. At ALU what is the unit de-rated to when the adit gate is open?
    5 MW
  21. Who’s responsible for following ramp rates at ALU?
    Field
  22. What does ALU discharge into?
    Stave Lake Reservoir
  23. What makes ASH unique in regard to VI generation?
    The only remote Black Start on the Island.
  24. Are there ramp rates for varying generation at ASH?
    There are no fisheries concerns however there are ramps that must be adhered to for mechanical reasons.  9 MW per minute for generation increases and 3 MW per minute for generation decreases.
  25. How would go about synchronizing ASH G1?
    Unit auto synchronizes.
  26. Are there any fisheries concerns at ASH?
    No
  27. If Ash G1 tripped to SNL what would be the first this to check prior to attempting to synchronize?
    Check 1L127 did not kick out
  28. At BRR what information is necessary to implement a Man Check?
    Name, mode of transport, cell number, contact’s name and #, length of time
  29. What kind of turbines are at BRR?
    Pelton
  30. What 3 plants make up the BRR system?
    LAJ, BRR, SON
  31. Are there any downstream restrictions on power house discharge at Bridge River?
    No
  32. What is the “normal minimum reservoir elevation” at BRR
    606.55m
  33. “FYI” – Who’s the SFM at BRR?
    George Jasicek
  34. If a BRR unit is forced out of service who is responsibility is it to set it to fully de-rated.  Where do you find this information?
    Plant operator, see 1T-83
  35. PSOSE requests a discharge change at DSY.  SPOG 1 from .16m to .3m.  Describe how you would go about this?
    • Open up the Converting WC operations screen in Web CM
    • Change operation to “Position to Flow”
    • Select ACC as LMC and Reservoir as CMS
    • Check Forebay indicated is accurate, if not than manually enter
    • Enter the current SPOG gate openings and record the CMS flow
    • .16 M with FB at 375.848 m = 19.197 CMS
    •  
    • This is between 10-62 CMS = max ramp of 13 CMS per 15 minutes
    • Target is .3m = 35.413
    • 35.413 (-) 19.197 = 16.216 CMS change
    •  
    • ** This gate change would have to be done in two 15 minute stages to adhere to the ramp rate. **
  36. Both units are online at CMS G1 = 40 MW & G2 = 40 MW.  G2 trips offline while ramping to 0 MW, what action would you take?
    Nothing plant output remains @ 40 MW
  37. At CMS G1 is offline and you are ramping G2 from 40 – 10.  Are there ramp rates? If so what are they? And what would you do if G2 tripped offline and locked out @ 30 MW?
    Yes.  40 – 10 MW @ 2 MW per min. than wait 5 minutes before shutting down.  Start G1 load to 30 MW and continue ramp down at 2 MW per min to 10 MW, wait 5 min before shutting down.  Notify PSOSE of violation.
  38. You are dispatched a generation change to target CMS output to 95 MW the FB is 365m.  How would you go about implementing this request?
    Cannot implement request Max output is 75 MW at that FB level.
  39. Why is CMS an important plant for a Lower Mainland system restoration.  Where would you find information in this regard?
    6T-70, CMS is the quickest source for a Station Service supply and unit start-up power (approximately 5 MW) for Burrard Thermal.
  40. What must mode must LFC be in for PID to work with CMS?  Why?
    ON, it was originally set up as an AGC controlled plant
  41. If a spill was required at COM what action would you take?
    None, auto spill
  42. You just shut down G1 at COM and 10 minutes later you get a start up instruction.  What action would you take?
    None, you must wait 30 minutes unless a creep alarm comes in. 
  43. PSOSE has instructed you to take COM G1 to 20 MW what would you check prior to implementing this request?
    Forebay elevation is greater than 45 meters
  44. What must be done prior to shutting down G1 at COM?
    Flush unit by fully loading (full load or if operating in low reservoir elevation conditions / de-rate then 20 MW) for 5 MIN.
  45. If ELK G1 & G2 are at full load (flash boards in) and G2 trips off line what would you do?
    Open sluice gate to 50% gate opening, notify PSOSE, call-out, Crow
  46. If ELK G1 & G2 are at full load (flash boards out) and G2 trips off line what would you do?
    Notify PSOSE, the weir crests are designed to handle the additional flow, however we still must meet the forebay elevation requirements issued to us by PSOSE.  Sluice gate operation and dispatch for tainter gate operation may be required
  47. Before calling out for any alarms at ELKO what action would you take?
    Do an “Alarm Group 1” reset
  48. At ELK why are we required to operate the FB under such tight constraints when the flash boards are in?
    Prevent wear on them
  49. FYI – Who is the SFM at ELK
    Mike Blackburn
  50. You get the following priority 4 alarm, FLS 22 – G1 winding temp high.  What would be your process for handling this alarm?
  51. Check SIS, (this should be done for every alarm you receive for this reason)
    This alarm is mis-prioritized in our EMS system as a Priority 4 (you can confirm this in the station tabular) ,however, it is actually a Priority 2 with an instruction to “Shut unit down” in SIS (3G-FLS-02)
  52. How often can you initiate a raise / lower command at FLS.
    One raise and lower nor more frequently 15 minutes
  53. Are there ramp rates at FLS?
    Yes, seasonal ramp rates apply
  54. What control would you use to adjust generation at FLS?
    Gate limit
  55. Why is Falls River important in a 2L101 outage?  What operating orders describe the actions taken by all parties during a 2L101 outage?
    Provides voltage and MW support and can be used to keep RPG units out of there respective RLZ’s
  56. How many CMS are represented by 2 MW of generation at FLS.
    5.2 CMS
  57. When starting a FLS unit what precaution would you take in order to prevent a possible negative power trip?
  58. After start-up give the unit several raises using the MW control to adjust up to the gate limit before using the Gate Limit to control the MW to avoid the unit going into reverse power.  For some reason at FLS the gate position continues to drift down after the unit is shut down.  When you start it back up the unit will motor unless you bias the MW’s up to the gate limit.
  59. What must be done at JHT after every Areva failover?
    Check plant total analogue warnings and alarms are correctly set.
  60. What must be done after every JHT plant output change?
    Change the plant total analogue warnings and alarms
  61. Are there ramp rates at JHT?  What are they?
    YES

    • Flow          Flow Increase      Flow Decrease >122CMS           None               None 
    • 79 – 122 CMS     1 hour             1hour 
    • < 79 CMS     14 CMS per hr     7 CMS per hr
  62. If you were required to shut down a unit at JHT while simultaneously starting-up a unit would you operate at the upper or lower plant total operating range?  Explain your answer.
    Operate at the upper range of the operating bandwidth.  Ie. If the plant target is 58 MW get the plant to ~60-61 MW near the upper limit so that a buffer is created for any unanticipated plant reductions before beginning the unit swap.  The true environmental (fisheries) violations are on the lower end of the plant output target.  A momentary overshoot is acceptable during these load changes (unit swaps) but a momentary under-shoot, below -3 MW plant output is a reportable violation.
  63. If you had a unit trip offline at JHT and all other units are at full load (ie. You cannot recover with generation) where would you find the value that you would require to spill to?
    Plant instructions
  64. Who is the PIC of the JHT spill gates?
    JHT shift electrician
  65. Who calculates the appropriate gate openings?
    JHT shift electrician
  66. If a unit trips offline at JHT and you are attempting to recover with online units must you still adhere to the ramp rates?
    No
  67. How long does it take for the water to get from the Spill Gates to the Power House if a spill is initiated?
    45 Minutes
  68. What must be done prior to spilling at JHT?
    Spillway must be patrolled.  It is a major public use area
  69. How many CMS is approximately 1 MW of generation at JHT?
    1 CMS = 1 MW
  70. What would you do if all generation was lost at JHT?
  71. Reduce LDR generation to 50% within ½ hour
    • Further reduce LDR generation to JHT reservoir level below 140.06m
    • This will provide the time to either determine if units can be returned to service or to initiate a spill.
  72. Where would you find the operating instructions indicating what to do after a significant earthquake at JHT?
    3T-JHT-01, Section 2.5
  73. What would you anticipate to happen in JHT Forebay were to get to 139.72m?  Where would you find this information?
    • JHT – LDR runback protection would operate.  LDR G1 would trip to SNL after 5 minutes at the FB level G2 would trip to SNL.
    •  
    • 3T-LDR-01
  74. Does JOR have a PRV?
    Yes
  75. Under what condition would the PRV at JOR be opened?  How can it be opened? What operating order lists the steps involved in this process?                                                    
    When running JOR in an islanded configuration.  Locally.  See 5T-1L143_1L146
  76. How many MVA can you put on JOR G1 before the second unit breaker has to be closed?
    75 MVA
  77. What is the most important thing to remember when shutting down JOR?
    Close the HCV
  78. The distribution feeder that supplies power to diversion is out and you’ve been asked to start up JOR.  How do you open the HCV?
    Start the diversion diesel
  79. At JOR what percentage HCV opening is equivalent to G1 output of 50 MW, 130 MW, 150 MW?
    16%, 58%, 70%
  80. FYI – Who’s the SFM at JOR
    Duane Walsh
  81. KCL G1 trips to SNL due to gen. shedding.  What would you do and what operating order would you find the information?  What would you do for all other plants?
    • Before re-synching and loading to 10% ask the TC if he has any breaker operations to initiate.  If any other plant trips due to gen shedding (without direction) re-synch and load to 10%
    • SOO 7T-10
  82. Before starting a unit at KCL what is imperative to check?
    The unit disconnect is closed
  83. Who should you give a heads up to prior to starting or stopping units at KCL?
    TC, the ring at KCL is level 1 equipment
  84. How is spilling at KCL achieved?
    FBC plants spill around KCL if required
  85. Are there any fisheries concerns at KCL?
    No
  86. Why don’t we always open the unit disconnect and close up the ring at KCL?
    We are supposed to limit the unit disconnect operations.  That being said, it is ultimately the TC’s decision as to what condition the ring is to be left in for system stability concerns.
  87. An RCMP officer calls screaming there is a child on an inner tube floating toward the penstocks inlet at KCL what do you do?
    Close all four intake gates and notify the GC / TC.  The units will go into an emergency stop when the intake gate gets to 95% open then trip the unit CB’s, unit disconnects will open to isolate units and lock out.
  88. Is there a PRV at LAJ?
    Yes
  89. Are there any fisheries restrictions at LAJ?
    Yes
  90. at LAJ how would you open the PRV and what precautions must you be aware of.
    MW lowers; if the person to last operate LAJ applied multiple raises with the MW controller and wound it into the gate limit than multiple lowers will be required to cancel them out before the PRV will open.
  91. At LAJ if a decrease of power house discharge is required who implements this request while adhering to the ramp rates?
    Facilities staff, downstream stage changes must be measured locally during ramps
  92. What water course system is LAJ part of?
    Bridge River System, LAJ, BRR, SON
  93. If LB1 trips offline what do you expect to happen?  WHY?
    PSOSE will request to have an electrician dispatched to close the CQD power tunnel.  Buntzen Reservoir has very little storage and it is preferred not to spill via the overflow weir due to the extensive erosion that can occur.
  94. What water course is LDR part of?
    Campbell River System
  95. If JHT is forced out of service what must be done at LDR?
  96. Reduce LDR generation to 50% within ½ hour
    • Further reduce LDR generation to JHT reservoir level below 140.06m
    • This will provide the time to either determine if units can be returned to service or to initiate a spill.
  97. Is LDR hydraulically balanced with JHT?
    No full output at LDR will cause the JHT forebay elevation to increase
  98. What is the protection scheme called that would trip LDR to SNL after JHT forebay reaches 139.72m
    LDR runback protection
  99. Are there any environmental restrictions on powerhouse discharge at LDR?
    No
  100. What must be done if a MCA unit has been shut down for more than 8 hours and you are required to start it?
    It must be run at SNL for 10 minutes before the field is applied
  101. What must you check prior to putting a unit in SC at MCA?
    Unit is unloaded to < 20 MW, PSI indication, no alarms are present that would restrict this operation and check all caution tags that may indicate an operating restriction.
  102. You are requested to shut a MCA unit down from SC, how would you go about this?
    Check all caution tags, transfer to generate, zero the MVARs and shut down unit.
  103. MCA G1, G2 & G4 trip to SNL when 5L71 and 72 trip out.  G3, however, stays online with (– 2) MW’s on the unit.  You are concerned that the unit may trip out on negative power.  Why do you think this is and what would you do?
    G3 stayed online to provide SS through MCA 12KV distribution.  Leave it until you’re ready to restore.
  104. You are trying to lower the gate limit at MCA and it is not responding what is probably the cause?
    LFC needs to be turned off.
  105. What are the min flow and ramp rates at G6?
    • Min Flow:         5.1 cms instantaneous
    •                         5.7 cms 3 day rolling average
    •                         6.0 cms control room min
    •  
    • Ramp:              2.8 cms per hour bx 5.1 & 19.8 CMS
  106. At PUN are there min flow’s or ramps rates at G8?
    Yes, seasonal, See 3T-PUN-01
  107. At PUN what is a pulse flow?
    A restriction that prevents us from reducing flow at G6 below 12 CMS for a period of 48 hours.
  108. At PUN G6 sharply drops by 1 CMS, what would your immediate reaction be and what do you think the cause is?
    Lower the PRV to the equivalent of 1 CMS to push the water back to G6.  City of Courtney municipal water supply drawing water off the penstock.
  109. At PUN how do you open the PRV at Puntledge?
    Lowering with the MW controller.
  110. With the PRV open will a lower with the MW controller affect water flow through the penstock?
    No, the PRV will open in proportion to the CMS decrease through the unit and the CMS through the penstock will remain unchanged.
  111. You have placed 3 coarse lowers on the MW controller and the PRV will not open what would you do?
    Keep giving it lowers, if the operator that last ramped the unit gave it multiple MW raises biasing it against the PRV gate limit than those pulses need to be reversed before the PRV will open.
  112. Are there min flows at REV?
    Yes, 140 MW or all 4 units at SNL
  113. At REV how is the field flashed on unit 1 – 4?
    Selecting the unit breaker and clicking on synch close.  After the field flashes click execute.
  114. At REV when is the field flashed on unit 5?
    Automatically
  115. At REV do you get a G5 unit running alarm?
    No, after the field has flashed the unit is ready to synch but you will not get a G5 running alarm like the other 4 units.
  116. At REV what should the air pressure read before putting a unit to SC?
    100 PSI
  117. Adjusting the VARs at REV affect what voltage the most?
    Ashton Creek
  118. Who has operating responsibility of the NPRF’s at REV?
    Field staff, 1J-11
  119. What line outage would require RPG to run in an islanded configuration?
    2L101
  120. What operating orders describe this operation at RPG?
    6T-73 and 3T-RPG-01
  121. Who must you call prior to starting RPG on gas?
    Spectra Energy
  122. After running RPG on Diesel for 50 hours what must be done?
    If after 50 hours running on liquid fuel, and circumstances do not permit a 1 hour run on natural gas then the unit should remain on liquid fuel until the fuel nozzles can be serviced.
  123. At RPG is a supply of gas required to start on diesel?
    Yes, gas assist is required for start-up however line pack is sufficient for multiple starts
  124. At RPG G1 is running in isochronous mode and the loading is getting high.  G2 is running @ 5 % droop and has very little loading.  How would you transfer the loading from the isoch unit to the droop unit.
  125. MW raises on the droop unit.  In islanded operation an increase in MW on the droop unit will be seen by the isoch unit as an increase in system frequency.  The isoch unit will then reduce generation to keep the frequency at 60 hz.  You do NOT raise or lower the MW on the Isoch unit.
  126. In order to close the bleed valves and reduce unit vibration what must be done when the units are started.
    Raise output past 15 MW before allowing unit to operate down to 12 MW.
  127. Why must Ruskin and SFN by operated in Hydraulic balance?
    Ruskin’s FB, Hayward, is very small
  128. Are their ramping restrictions at RUS?
    Yes, seasonal
  129. Are their min tail water levels that must be adhered to at RUS?
    Yes, 1.8M (Oct 15 – Nov 30) and 1.7M (Dec 1 – Oct 14)
  130. What would you do if you lost 1 unit at RUS?
    Recover the output with the other unit or if unable call PSOSE to discuss what value of MW they want SFN reduced to maintain hydraulic balance.
  131. What water course system is SCA part of?
    Campbell River System
  132. Why do the spillway gates at SEV indicate cubic feet per second?
    Because in an emergency Boundary (an American plant) will be spilling into Seven Mile’s forebay.
  133. Seattle City Light calls the plant desk and report that a spill of 150,000 cfs has been implemented due to an emergency what immediate action do you take at SEV?
    If all gates are operational, initiate a full 200 second gate movement on all gates releasing ~ 50,000 cfs.  While the gates are raising call PSOSE for precise gate openings, 2 more 200 second raises are likely required but PSOSE can calculate exact openings and keep the gates out of cavitation zones.
  134. After closing the gates at SEV what is good practice to do?
    Give an additional 10 second close pulse to relieve strain on the cables holding the gates
  135. FYI: Why is Seven Mile called Seven Mile?
    It is seven miles upstream of Waneta
  136. If you are required to initiate a spill at SEV in an emergency what notification needs to be made?
    Notify PSOSE who will contact Waneta (downstream of SEV) to coordinate spill
  137. What kind of turbine is SFN?
    Kaplan
  138. What is a Kaplan turbine?
    Variable pitch, good for low head plants
  139. Why does PSOSE often dispatch small load changes to SFN?
    They are trying to maintain hydraulic balance with RUS
  140. How is generation adjusted at SHU?
    Forebay controller
  141. What must be done immediately by the plant operator after loss of SHU generation?
    Contact those listed in notification sequence (3T-SHU-01)
  142. What are the MW control like at SON?
    Terrible, wait 5 – 10 minutes between pulses.  A coarse lower will sometimes give 1 MW or 11 MW.
  143. How what you go about synchronizing at SON?
    It auto-synchronizes.
  144. Are there fisheries restrictions at SON?
    • Yes, Seasonal
    •  
    • APRIL 1 - JUNE 30 (32 - 42 MW OR SHUT DOWN)
    • JULY 1 - AUG 31 & SEPT 28 - NOV 15 (32 AND ABOVE OR SHUT DOWN)
  145. What kind of turbine is WAH?
    Pelton, highest head plant in BCH fleet
  146. Can you operate WAH in SC when the tail race is greater that 19.6 m
    No
  147. If you get a high temp alarm at WAH while running in SC what must be done?
    The unit must be run in generate (greater than 15 MW) in every 6 hour period to prevent overheating.
  148. Are there ramp rates at WAH?
    Yes, when the tail water is greater that 18 m
Author
nibor222
ID
172550
Card Set
Steve's Plant Specifics
Description
Plant Specifics Steve's
Updated

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