HNP-12-032, Reactor and Senior Reactor Operator Initial Examinations 05000400/2012301/Harris Initial Exam 2012-301 Post Exam Comments
| ML12093A042 | |
| Person / Time | |
|---|---|
| Site: | Harris  |
| Issue date: | 03/05/2012 |
| From: | Scott S Progress Energy Co |
| To: | Junge M NRC/RGN-II |
| References | |
| 50-400/12-301, HNP-12-032 | |
| Download: ML12093A042 (20) | |
Text
Progress Energy March 5, 2012 SERIAL: HNP-12-032 Mr. Michael A. Junge, Region II United States Nuclear Regulatory Commission 245 Peachtree Center Ave., NE, Suite 1200 Atlanta, GA 30303-1257 SHEARON HARRIS NUCLEAR POWER PLANT DOCKET NO. 50-400/RENEWED LICENSE NO. NPF-63 REACTOR AND SENIOR REACTOR OPERATOR INITIAL EXAMINATIONS 05000400/2012301
Dear Mr. Junge:
Enclosed is the post-examination package for the Reactor and Senior Reactor Operator Initial Examinations given at the Harris Nuclear Plant February 13, 2012, through February 28, 2012.
Included from the administration of the Written Examination are the student cover sheets, answer sheets, master examinations, answer key, log of applicant questions and answers, and the student seating chart. Also, pertaining to the SRO Written Examination, are two post-examination comments (Question #79 and #93).
If you have any questions regarding this submittal, please contact me at (919) 362-3517.
Sincerely, Scotty Scott Superintendent Operations Training Harris Nuclear Plant JMS/mgw Enclosures c: Mr. J. D. Austin (NRC Senior Resident Inspector, HNP) w/o Enclosures Mr. V. M. McCree (NRC Regional Administrator, Region II) w/o Enclosures Ms. A. T. Billoch-Colon (NRR Project Manager, HNP) w/o Enclosures Progress Energy Carolinas, Inc.
Harris Nuclear Plant P. 0. Box 165 New Hill, NC 27562
HNP Licensed Operator Written Exam question #79 Post Exam Comment Comment for SRO question #79 is that the correct answer is A. EOP-EPP-00 1, page 56 contains a Caution that states SG pressures should be maintained above 130 PSIG. This will prevent injection of accumulator nitrogen into the RCS AND ensure SG pressures remain above the minimum required for TDAFW pump OPERABILITY (105 PSIG). The EOP Users Guide states in section 5.3.1 Entry into EPPs and FRPs that In general, NOTES and CAUTIONS apply to the step which they precede. A NOTE or CAUTION which precedes the first operator action step may also apply to the entire procedure. Therefore, this CAUTION applies to step 35, the step to depressurize the intact SGs.
The HNP EOP Setpoint Study (page 54) also states a value of 130 psig for Minimum SG pressure which prevents accumulator injection nitrogen injection. Refer to background document of ECA 0.0 During the depressurization in EOP-EPP-00 1, the caution limits the pressure reduction to a value above 130 psig. After getting to less than 230 psig a 50 psig control band is established. This control band is consistent with the EOP writers guide and standard operations practices and was not derived from the EOP basis document. The Step Deviation Document for EPP-001 states Added instructions to maintain pressure within a specified band (50 PSI). Specifying a control band is consistent with EOP Writers Guide and standard operations practices.
The question asks, In accordance with EPP-001, Loss of AC Power to 1A-SA and lB-SB Busses, which ONE of the following is (1) the MINIMUM pressure the intact SGs will be depressurized to. . . . Since the question asked for a minimum pressure and not the control band, answer A would be considered correct based on the references stated.
There is no contention about the fact that the second half of the question was appropriately answered by either answer A or C.
References:
Exam question 79 EOP-EPP-001 page 56 EOP USERS GUIDE page 23 EOP SETPOINT STUDY pages 52, 102,103 ECA-0.0 Background page 122 SDD-EPP-001 page 20
- 79. Given the foflowing plant conditions:
- The plant was operating at 100% power
- The ASI pump is under clearance
- A loss of Offsite Power has occurred
- EDG A and B started but neither EDG output breaker, 106 nor 126, will close In accordance with EPP-001, Loss of AC Power to 1A-SA and I B-SB Busses, which ONE of the following is (1) the MINIMUM pressure that the intact SGs will be depressurized to AND (2) what will this pressure reduction accomplish?
A. (1) 130 psig (2) Reduces the AP across RCP seals to minimize leakage and loss of RCS inventory.
B. (1)l3opsig (2) Maximizes Natural Circulation flow to allow Reactor Vessel Head to cool since CRDM cooling fans are unavailable.
C. (1)l8opsig (2) Reduces the tiP across RCP seals to minimize leakage and loss of RCS inventory.
D, (1)l8opsig (2) Maximizes Natural Circulation flow to allow Reactor Vessel Head to cool since CRDM cooling fans are unavailable.
Monday, February 20, 2012 11:15:05AM 79 Rev. FINAL
QUESTIONS REPORT for2O12NRCSROREVFINAL
- 1. Plausibility and Answer Analysis Reason answer is correct: With ASI pumps not avialble the SG pressure is reduce 230 psig while cooling down the RCS cold legs as close to 100°F/hr as possible. Once SG pressure is below 230 psig the pressure is controlled between 180 to 230 psi 9 in order to minimize RCS inventory loss while cooling the RCP seals in a controlled manner.
A. Incorrect. The first part is plausible because 130 psig is the lower end of the control band for SG pressure following depressurizing during FRP-C. 1. The second part is the correct basis for these actions. SG pressure reduction will cause an RCS cooldown and pressure reduction which will minimize RCS leakage through the RCP seals B. Incorrect. The first part is plausible because 130 psig is the lower end of the control band for SO pressure following depressurizing during FRP-C. 1. The second part is plausible because the CRDM5 are not available and the SG pressure reduction will promote RCS natural circulation, but natural circulation flow does not provide any flow in the Upper head region of the Reactor.
C. Correct.
- 0. Incorrect. The first part of the answer is correct. The second part is plausible because the CRDM5 are not available and the SO pressure reduction will promote RCS natural circulation, but natural circulation flow does not provide any flow in the Upper head region of the Reactor.
Thursday, March01, 2012 11:31 :38 AM 1
QUESTIONS REPORT for 2012 NRC SRO REV FINAL EPE: 055 Loss of Offsite and Onsite Power (Station Blackout) 055EG2.4.9 Knowledge of low power/shutdown implications in accident (e.g., loss of coolant accident or loss of residual heat removal) mitigation strategies.
(CFR: 41.10 /43.5/45.13)
Importance Rating: 3.8 4.2 Technical
Reference:
EPP-001, Step 35, Page 56, Rev 40 and WOG background document for ECA-0.0 (EPP-001) page 117 Rev. 2 References to be provided: None Learning Objective: EPP-001, 002 & 003, Loss of All AC Power and recovery w/ or w/o Safety Injection, EOP3-7 Obj. 6 Question Origin: New Comments: None Tier/Group: T1G1 SRO Justification: Assessing plant conditions (Normal, abnormal, or emergency) and the prescribing a procedure or section of a procedure to mitigate, recover or with which to proceed.
Thursday, March01, 2012 11:31 :38 AM 2
LOSS OF AC POWER TO IA-SA AND lB-SB BUSES I INSTRUCTIONS RESPONSE NOT OBTAINED CAUTION
. SG pressures should be maintained above 130 PSIG. This will prevent injection of accumulator nitrogen into the RCS AND ensure SC pressures remain above the minimum required for TDAFW pump OPERABILITY (105 PSIG).
. Level should be maintained greater than 25% [40%] in at least one intact SC during the depressurization to ensure adequate heat sink. (Depressurization should be stopped in at least one SC prior to its level decreasing below 25% [40%].)
NOTE
. The SGs should be depressurized at a rate sufficient to maintain a cooldown rate in the RCS cold legs near 1000 F/HR. This will minimize RCS inventory loss while cooling the RCP seals in a controlled manner.
. With no seal injection in service, reducing RCS pressure to less than 1710 PSIG within 2 HOURS minimizes the probability of RCS seal failure.
. SC depressurization may result in loss of PRZ level and reactor vessel upper head voiding. Do NQT stop SC depressurization to prevent these occurrences.
. During a loss of all AC power, SC C PORV can be controlled from the MCB for a limited number of operations.
- 35. Depressurize Intact SGs To 230 PSIC:
El a. Maintain cooldown rate in RCS cold legs LESS THAN 100° F/HR
El 1) Operate SC C PORV from El 1) Locally operate SC C PORV MCB. usinci OP-I 26, MAIN STEAM, EXTRACTION STEAM, AND STEAM DUMP SYSTEMS, Section 8.2.
El 2) Locally operate SC A and B PORVs usinq OP-I 26, MAIN STEAM, EXTRACTION STEAM, AND STEAM DUMP SYSTEMS, Section 8.2.
El c. SC pressures LESS THAN
- El c. WHEN SC pressures decrease to 230 PSIG less than 230 PSIG, THEN do Step 35d.
El Continue with Step 36.
El d. Control SG PORVs to maintain SC pressures between 230 PSIG and 180 PSIC.
EOP-EPP-00I I Rev. 40 I Page 56 of 94
GUIDE USERS 5.3 Control Room Usage of EPPs, Foldouts, and FRPs 5.3.1 Entry into EPPs and FRPs The cover page of each procedure presents the procedure number and title. The PURPOSE/ENTRY CONDITIONS section presents a detailed description of the conditions for hich the procedure was written. Operator action steps are presented in the two-column format. In this format, each step in the left-hand column contains a high-level statement which describes the task to be performed.
Certain information is emphasized by not following the standard two-column format. This information consists of:
- CAUTIONS these contain information about potential hazards to personnel or equipment, and may also provide guidance on how the hazard can be avoided.
- NOTES these contain descriptive or explanatory information not as critical as CAUTIONS but still intended to aid the operator in performing subsequent action step(s).
In general, NOTES and CAUTIONS apply to the step which they precede. A NOTE or CAUTION which precedes the first operator action step may also apply to the entire procedure.
When directed to GO TO Step 1 of an EPP or FRP, the operator should begin with the cover page and PURPOSE/ENTRY CONDITIONS of the respective procedure. After verifying that current plant conditions are consistent with the purpose of the entered procedure, and observing any initial NOTES and/or CAUTIONS, the operator should proceed to the first action step as directed.
5.3.2 Format of Action Steps If the high-level task requires multiple actions, then subtasks are specified. Following each task or subtask, the expected response or result is given in CAPITAL LETTERS, separated from the task by a dash.
Example: 6. PRZ Level - INCREASING Example: 12. Identify Any Faulted SG:
- a. Check for any of the following:
- Any SG pressure -
DECREASING IN AN UNCONTROLLED MANNER
- Any SG COMPLETELY DEPRESSURIZED (continued on next page)
EOP-USERS GUIDE Rev. 36 I Page 23 of 67
EOP SETPOINT STUDY 4.0 FOOTNOTE VALUES PARAMETER DESIGNATOR: 0 PARAMETER DESCRIPTION: STEAMLINE PRESSURE VALUES FOOTNOTE NUMBER FOOTNOTE/EXPLANATION VALUE 07 Minimum SC pressure which prevents accumulator 130 PSIG nitrogen injection. Refer to background document of ECA-O.O /From Section 5.27.
08 Minimum SC pressure which prevents injection of 230 PSIC accumulator nitrogen into the RCS, plus a margin for controllability. Refer to Background Document for guideline ECA-0.O. /From the ERG Footnote Basis Document 100 PSI is used as the margin of controllability and added to the value of Footnote 0.07.
09 Condensate pump discharge header pressure for 500 PSIG minimum flow operation on recirculation, minus allowances for normal channel accuracy.
/Condensate booster pump discharge pressure minus allowances for instrument uncertainties and pressure drops, rounded to 500 PSIG for use in EOPs.
(ERG Rev. 1C (based on DW-89-O68) changed setpoint to condensate discharge header pressure for minimum flow operation on recirculation, minus allowances for normal channel accuracy. The basis for the change is that for the reference plant, condensate pump recirculation flow is greater than that required to remove decay heat, and thus ensures adequate flow will be delivered to the SGs. Since SHNPP uses the condensate booster pumps to control header pressure, evaluation of condensate discharge head and recirculation flow is not applicable. The setpoint, 500 PSIG. is derived by subtracting 100 PSI from the nominal 600 PSIG condensate booster pump pressure specified in the FRP-H.1.)
10 SC pressure, including allowances for normal 440 PSIG channel accuracy, corresponding to the RCS pressure requirement for placing RHR System in service. /From Reference 2.2.5.16.
SETPOINT STUDY Rev. 12 Page 52 of 160
EOP SETPOINT STUDY 5.27 SG Pressure To Prevent Injection Of SI Accumulator Nitrogen Into The RCS.
NOTE: The value for Footnote 0.07 used in the EOPs is derived based on ERG Maintenance Item DW-06-0l4. This derivation supersedes that in Calculation # HNP-T/TNST-1014.
Minimum SG pressure which prevents injection of accumulator nitrogen into the RCS. Refer to applicable Background Documents. (Footnote 0.07)
From the background document:
[PiVijy = [P2V2]Y where:
Pi = initial accumulator pressure P2 = final accumulator pressure Vi = initial nitrogen volume V2 =
final nitrogen volume
= 1.00 The following conservative assumptions are made:
Pt = maximum N2 pressure allowed by Tech Spec 3.5.1
= 665.0 psig
= 679.7 psia Vi = total accumulator volume (neglecting the volume of the discharge piping) from TSAR Table 6.3.2-1 = 1450 ft 3
Minimum water volume is 66% from Tech Spec 3.5.1. a minimum value is used to conservatively maximize the nitrogen volume.
From SHNPP Curve 0-34:
66% level = 7430 gallons
= 7430 gallons x 0.13368 ft
/gal 3 = 993 ft 3
SETPOINT STUDY Rev. 12 Page 102 of 160
EOP SETPOINT STUDY 5.27 50 Pre5sure To Prevent Injection Of SI Accumulator Nitrogen Into The RCS (continued)
Therefore, V 1450 ft 3 - 993 ft 3 = 457 ft 3
y Vi 457 Pt = P2 = 679.7 PSIA = 214.1 PSIA V2 1450 RCS to SC delta P from Section 6.3.6 of thio document = 77.5 PSI.
Therefore. SG pressure to prevent nitrogen injection is:
214.1 PSIA - 77.5 PSI = 136.6 PSIA
= 121.9 PSIG Value rounded up 130 PSIG for conservatism.
SETPOINT STUDY Rev. 12 Page 103 of 160
STEP DESCRIPTION TABLE FOR ECA-O.O Step 16 STEP: Depressurize Intact SGs To (0.08) PSIG PURPOSE: To depressurize the intact steam generators BASIS:
Step 16 depressurizes the intact SGs, thereby reducing RCS temperature and pressure to reduce RCP seal leakage and minimize RCS inventory loss. The advantages to performing this action, as well as restrictions that apply during the action, are detailed in Subsection 2.3.
During SG depressurization, SG level must be maintained above the top of the SG U-tubes in at least one SG. Maintaining the U-tubes covered in at least one SO will ensure that sufficient heat transfer capability exists to remove heat from the RCS via either natural circulation or reflux boiling after the RCS saturates. Step 16a requires that SG level be in the narrow range in at least one SG before SG depressurization is initiated in Step 16b. If level is not in the narrow range in at least one SO, RNO 16a instructs the operator to maintain maximum AFW flow until narrow range level is established in one SG.
When narrow range level is established, SO depressurization can be started or continued via Step 16b.
Step 16b instructs the operator to reduce SG pressures by depressurizing the intact SOs. Depressurization should be accomplished by opening the PORVs on the intact SGs to establish a maximum steam dump rate, consistent with plant specific constraints. The step is structured assuming that the operator can open and control SG PORVs from the control room. This structure assumes that the PORVs are air-operated and have dc control power and pneumatic power (i.e., either air reservoirs or nitrogen bottles) available. Some plants may not have the capability to open the SO PORVs from the control room. These plants should evaluate their capability to accomplish this step locally via PORV handwheels. Such an evaluation should consider accessibility and communications necessary to accomplish local PORVoperation.
Once depressurization is initiated, maintenance of a specified rate is not critical. The depressurization rate should be sufficiently fast to expeditiously reduce SO pressures, but not so fast that SG pressures cannot be controlled. It is important that the depressurization not reduce SO pressures in an uncontrolled manner that undershoots the pressure limit, thus permitting potential introduction of nitrogen from the accumulators into the RCS.
ECA-O.O Background 122 HP-Rev. 2, 4/30/2005 HECAOOBG .doc
LOSS OFAC POWER TO 1A-SA AND lB-SB BUSES EOP Step ERG Step Justification of Deviation 24 16b, c, d and ERG I-16b: Specified local operations of SG PORVs A e and B in instruction column since these valves require AC power for remote operations. Added plant-specific procedure reference for local operations.
Revised target SG pressure setpoint to prevent nitrogen injection from the CLAs based on ERG Maintenance Item DW-06-014. The revised setpoint is based on a coefficient of expansion of 1.0 instead of 1.25. (Refer to EOP Setpoint Study Sections 5.27 and 5.28.)
ERG l-16c: Deleted since at SHNPP the T2 (2700 F) temperature cannot be met until SG pressure is less than 230 PSIG. Saturation temperature for 230 PSIG is approximately 386° F. Therefore, Tcold under natural circulation could never be less than 386° F with SG pressure greater than or equal to 230 PSIG. A Tcold of 270° F corresponds to a SG pressure of approximately 26 PSIG.
ERG R-16e: Deleted because EOP instruction column provides adequate information to perform required action.
Added instructions to maintain pressure within a specified band (50 PSI). Specifying a control band is consistent with EOP Writers Guide and standard operations practices.
25 17 Step reworded to clarify its intent. Changed ERG wording from Check to Monitor since this is intended to be a continuous action during the SG depressurization (ACER 94-00135).
None 18-NOTE Deleted since its associated step is deleted.
None 18 Deleted since it is not applicable. SI has already been reset prior to actions that prevent loads from automatically sequencing on to the emergency buses.
SDD-EPP-001 I Rev. 31 I Page 20 of 26
RNP Licensed Operator Written Exam question #93 Post Exam Comment Comment for question 93 is there is no correct answer. The question asks in accordance with OPS-NGGC-1000, who is responsible to review and sign the Batch Gaseous Effluent Permit to authorize the release. OPS-NGGC-1000 does not delineate who is responsible to review and sign the Batch Gaseous Effluent Release Permit. OPS-NGGC-1000 Section 4.4.16 states the CRS approves all radioactive releases but there is no requirement that the CRS will sign the permit.
Procedure OP-120.07 Section 8.39.2 Step 27 for a Waste Gas release specifically places responsibility to review and sign the Batch Release Permit on the Superintendent-Shift Operations. Additionally, the Batch Release Permit computer printout requires a Shift Supervisor signature for approval. (The Superintendent- Shift Operations and Shift Supervisor are previous titles for the current Shift Manager position. Title changes are updated during scheduled revisions.)
Based on 1-INP procedures the reference to OPS-NGGC- 1000 in the question stem is not correct for review and signature approval of Batch Gaseous Effluent Permits and therefore there is no correct answer.
References:
Exam question 93 OPS-NGGC-1000 Section 4.4.16 page 22 OP-120.07 Section 8.39.2.27 page 168 WGDT Release Permit Computer Printout
- 93. Given the following plant conditions:
- The plant is operating at 100% power
- Operators are aligning a Waste Gas release in accordance with OP-i 20.07, Waste Gas System
- The total concentration for the WGDT to be released is above the value for waiving the requirement to check the stability class
- The weather is degrading due to a temperature inversion
- ERFIS indicated Stability Class B when the permit was prepared but now indicates Stability Class E.
Which ONE of the following describes (1) the impact of the stability change on the planned release AND (2) in accordance with OPS-NGGC-l 000, Fleet Conduct Of Operations, who is responsible to review and sign the Batch Gaseous Effluent Permit to authorize the release?
A. (1) The release is on hold until a new permit with the current stability class is issued.
(2) The CRS B. (1) The release is on hold until it is predicted that the Stability Class will be a Stability Class C in the next 4 to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
(2) The CRS C. (1) The release is on hold until a new permit with the current stability class is issued.
(2) The Shift Manager D. (1) The release is on hold until it is predicted that the Stability Class will be a Stability Class C in the next 4 to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
(2) The Shift Manager Monday, February 20, 2012 11:15:05AM 93 Rev. FINAL
QUESTIONS REPORT for 2012 NRC SRO REV FINAL 93
- 1. Plausibility and Answer Analysis Reason answer is correct: OP-120.07 gives Stability Class A, B, and C as one of the ERFIS required Stability classes to release to the environment. OPS-NGGC-1 000 CRS responsibility #16 states that the CRS approves all liquid and gaseous release permits.
A. Incorrect. Plausible because any release requires an accurate permit but the stability class can change within those listed in the procedure, during the release. The second part is correct.
B. Correct.
C. Incorrect. Plausible because any release requires an accurate permit but the stability class can change within those listed in the procedure, during the release. The second part is plausible because per OP-120.07 the Shift Manager could approve the release (but this question asks who approves the release lAW OPS-NNGC-1000).
D. Incorrect. The first part is correct. The second part is plausible because per OP-120.07 the Shift Manager could approve the release (but this question asks who approves the release lAW OPSNNGC.-1000).
Thursday, March 01 2012 11:32:38 AM 1
QUESTIONS REPORT for 2012 NRC SRO REV FINAL 071 Waste Gas Disposal System (WGDS) 071A2.08 Ability to (a) predict the impacts of the following malfunctions or operations on the Waste Gas Disposal System; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: Meteorological changes (CFR: 41.5 /43.5 /45.3 /45.13)
Importance Rating: 2.5 2.8 Technical
Reference:
OP-120.07, Section 8.39.2 step 16, Page 165, Rev. 54, OPS-NGGC-1 000, CRS Responsibilities #16, Page 22, Rev. 6 References to be provided: None Learning Objective: Liquid Waste Processing StUdent Text, Obj 4 Question Origin: New Comments: None Tier/Group: T2G2 SRO Justification: Fuel handling facilities and procedures: Refuel floor SRO responsibilities Thursday, March 01, 2012 11:32:38 AM 2
4.4 Control Room SupeMsor (CRS) (continued)
- 9. The staffing rule requires the continuous presence of SRO in the Control Room (see 5 above) to ensure the following:
- a. The oversight function of the supervisor is maintained.
- b. The SRO is aware of plant conditions before, and resulting from, an abnormal event. This helps ensure that the experience, training, and knowledge of the SRO is available to aid in promptly mitigating the event.
- c. The QAC can concentrate on performing the immediate actions necessary to mitigate the event rather than having to brief the SRO about the event if the SRO was absent from the control room when the event occurred.
- 10. Directly supervise Control Room watchstanders in the manipulation of Reactor and plant controls. The CRS will refrain from manipulating plant equipment. [SOER 07-1 Rec. #2]
- 11. Ensure a licensed operator (RO/SRO) is present at the controls at all times during plant operation.
- 12. Ensure the plant is rigorously monitored and operating activities are conducted in accordance with applicable procedures.
- 13. Monitoring plant operation in a manner that obtains the highest possible level of nuclear safety and ensures protection of the health and safety of other employees and the general public.
- 14. Ensuring all Control Room and shift activities are carried out in a highly professional manner conducive to plant safety and personnel safety throughout the plant.
- 15. Ensure comprehensive tours are performed of all watchstations in accordance with station expectations.
Approves all Radwaste liquid and gaseous release permits.
- 17. Monitoring operator activities and providing feedback and coaching ensuring that the operations standards are being met.
- 18. Monitoring watchstander logs, records and evaluate data obtained from installed instrumentation and communicate information to the appropriate personnel. This review is to detect abnormal trends, assess potential operating problems and confirm the accuracy of information, Initiate plant corrective action, as appropriate based on this review and report per the condition reporting process.
OPS-NGGC-1000 Rev. 6 Page 22 of 147
8.392 Procedural Steps (continued)
(12) Using keypad, ENTER the High Alarm Permit Value (4EX837).
(13) DEPRESS ENTER. New setpoint should be entered.
(14) DEPRESSSELtogotochannel 10.
(15) Using keypad, ENTER the Alert Alarm Permit Value (4EX837).
(16) DEPRESS ENTER. New setpoint should be entered.
(17) RETURN RM-11 Key to Normal.
- b. SIGN the Waste Gas Decay Tank Vent Log indicating that correct WRGM Permit values have been entered. (Log Item 16)
- c. PERFORM independent verification that the correct WRGM values have been entered from the Batch Gaseous Effluent Permit Vent Stack 5 Attachment into the RM-1 1. LOG on Attachment 3.
(Log Item 17)
- 24. VERIFY the Batch Gaseous Effluent Permit passes the 1 OCFR5O compliance by ensuring there is not an A, S, N, or 0 indication in the FLAG Section of the permit.
- 25. RECORD the Max Effluent Flow Rate from the Batch Gaseous Effluent Permit (Log Item 18).
26 HAVE to review the release package and sign the Waste Gas Decay Tank Vent Log (Log Item 19) 27 REQUEST SuL d -hi1ionsjed sin the Gaseous Effluent Permifl
- 29. OPEN the Gas Decay Tank Outlet Valve on Gas Decay Tank to be vented:
- 3WG-19 -TankA
- 3WG-221 -Tank F
- 3WG-25 -Tank B
- 3WG-45 -TankG
- 3WG-31 -TankC
- 3WG-51 -TankH
- 3WG-37 -TankD
- 3WG-57 -Tank I
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