ML13154A324
| ML13154A324 | |
| Person / Time | |
|---|---|
| Site: | Peach Bottom  |
| Issue date: | 02/25/2013 |
| From: | Exelon Generation Co |
| To: | Todd Fish Operations Branch I |
| Jackson D | |
| Shared Package | |
| ML12328A009 | List: |
| References | |
| TAC U01867 | |
| Download: ML13154A324 (335) | |
Text
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET m~ Peach Bottom I
~ JPM D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR TRAINING PLOR -337CA LICENSED OPERATOR REQUALIFICATION 001 M. J. Kelly mda Lineup Standby Gas Treatment System for Automatic Operation - Alternate Path (Switches Are Out of Position)
APPROVALS:
Signature I Title Dale Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _ _-_ _ _-_ __
NAME: ISSUE DATE:
Last First M_1.
EMPLOYEE 10#: COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMSCODE:
LMS ENTRY:
Signature/Date PLQR337CA Rev001 Page 1 of 8
EXELON NUCLEAR PEACH BOnOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2610030101 - PLOR-337CA KIA: 261000 G2.1.29 URO: 4.1 SRO: 4.0 TASK DESCRIPTION: Knowledge of how to conduct system lineups, such as valves, breakers, switches, etc.
A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph D .2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph D.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
PLOR337CA Rev001 Page 2 of 8
B. TOOLS AND EQUIPMENT
- 1. Partial procedure COL 9A.1.A "Standby Gas Treatment System Automatic Operation",
Rev. 10. All steps are marked uN/A" except for step:
5 (A fan) 20 (AO 20469-01)
. 6 (B fan) 21 (AO 20469-02) 8 (AO 2507) 22 (AO 20470-01) 9 (AO 2512) 23 (AO 20470-02) 10 (AO 2514) 24 (PO 20465) 11 (AO 2510) 25 (AO 20466) 16 (AO 00475-01)
I 17 (AO 00475-02)
C. REFERENCES
- 1. COL 9A.1.A "Standby Gas Treatment System Automatic Operation", Rev. 10.
D. TASK STANDARD
- 1. Satisfactory task completion is indicated when the Unit 2 Main Control Room related steps of COL 9A.1.A, A "Standby Gas Treatment System Automatic Operation", are complete.
- 2. Estimated time to complete: 10 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to lineup the Unit 2 Main Control Room portion of the Standby Gas Treatment System using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. A Unit 2 startup is in progress.
- 2. Emergent maintenance was performed on various components of the Standby Gas Treatment System (SGTS).
- 3. Shift Management directs that a lineup verification of the Unit 2 Main Control Room portion of the SGTS be performed.
- 4. A partial of COL 9A.1.A "Standby Gas Treatment System Automatic Operation" has been reviewed and approved for use.
PLOR337CA Rev001 Page 3 of 8
G. INITIATING CUE The Control Room Supervisor directs you to perform an Independent Verification (IV) of the Unit 2 Main Control Room portion of the SGTS using the approved partial of COL 9A.1.A "Standby Ga~ Treatment System Automatic Operation". Do NOT manipulate any components.
PLOR337CA Rev001 Page 4 of 8
H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD
- NOTE TO EVALUATOR**
Hand partial of COL 9A.1.A " Standby Gas Treatment System Automatic Operation" to the Examinee to start this JPM.
1 Verify Standby Gas Treatment Fan 'A' P On panel 20C012 verify Standby Gas (OAV020) control switch is in "AUTO". Treatment Fan 'A' (OAV020) control switch is in "AUTO" position.
, Initial and date the check off list step.
- 2 Verify Standby Gas Treatment Fan 'B' P On panel 20CO 12 recognize that the (OBV020) control switch is in "AUTO". Standby Gas Treatment Fan 'B' (OBV020) control switch is in the "PULL-TO-LOCK" (Cue: If notified that the Fan 'B' (OBV020) position and NOT in "AUTO" position.
control switch is NOT in "AUTO" position, acknowledge report. If necessary, direct May report to the Control Room candidate to continue task and report all Supervisor that the switch is out of target discrepancies upon completion of task.) position now or report all mispositionings after COL is completed.
Annotate as-found position of switch.
3 Verify AO-2507 "Drywell Outboard 18" P On panel 20C003-3 verify that AO-2507 Vent" is in "CLOSED" position. "Drywell Outboard 18" Vent" is in "CLOSED" position .
Initial and date the check off list step.
4 Verify AO-2512 "Torus Outboard 18" P On panel 20C003-3 verify that AO-2512 Vent" is in "CLOSED" position. liTorus Outboard 18" Vent" is in "CLOSED" position.
Initial and date the check off list step.
5 Verify AO-2514 "Torus Outboard 2" Vent" P On panel20C484A verify that AO-2514 is in "CLOSED" position. "Torus Outboard 2" Vent" is in "CLOSED" position.
Initial and date the check off list step.
PLOR337CA Rev001 Page 5 of 8
STEP NO STEP ACT STANDARD 6 Verify AO-251 0 "Drywell Outboard 2" P On panel 20C4848 verify that AO-251 0 Vent" is in "CLOSED" position. "Drywell Outboard 2" Vent" is in "CLOSED" position.
Initial and date the check off list step.
- 7
- Verify AO-00475-01 "Standby Gas P On panel 20C012 recognize that AO Treatment A Filter Inlet" is in "AUTO" 00475-01 "Standby Gas Treatment A position. Filter Inlet" control switch is in the "CLOSE" position and NOT in "AUTO" position.
(Cue: If notified that the AO-00475-01 May report to the Control Room "Standby Gas Treatment A Filter Outlet" Supervisor that the switch is out of target is NOT in the "AUTO" position, position now or report all mispositionings acknowledge report. If necessary, direct after COL is completed.
candidate to continue task and report all discrepancies upon completion of task.) Annotate as-found position of switch.
- 8 Verify AO-00475-02 "Standby Gas P On panel 20C012 recognize that AO Treatment A Filter Outlet" is in "AUTO" 00475-02 "Standby Gas Treatment A position. . Filter Outlet" control switch is in "CLOSE"
- and NOT in the "AUTO" position .
May report to the Control Room (Cue: If notified that the AO-00475-02 Supervisor that the switch is out of target "Standby Gas Treatment A Filter Outlet" position now or report a" mispositionings is NOT in the "AUTO" position, after COL is completed.
acknowledge report. If necessary, direct candidate to continue task and report all Annotate as-found position of switch.
discrepancies upon completion of task.)
9 Verify AO-00476-01 "Standby Gas P On panel20C012 verify that AO-OO476 Treatment B Filter Inlef' is in "AUTO" 01 "Standby Gas Treatment 8 Filter Inlet" position. is in "AUTO" position.
Initial and date the check off list step.
PLOR337CA Rev001 Page 6 ofB
STEP NO STEP ACT STANDARD 10- Verify AO-00476-02 "Standby Gas P On panel20C012 verify that AO-OO476 Treatment B Filter Outlet" is in "AUTO" 02 "Standby Gas Treatment B Filter position. Outlet" is in "AUTO" position.
Initial and date the check off list step.
11 Verify AO-20469-01 "Standby Gas P On panel 20C012 recognize that AO-Treatment DNV Reactor Bldg Equipment 20469-01 "Standby Gas Treatment DIW Exhaust" is in "CLOSED" position. Reactor Bldg Equipment Exhaust" is in the "CLOSED" position.
Initial and date the check off list step 12 Verify AO-20469-02 "Standby Gas P On panel 20C012 recognize that AO-Treatment DNV Reactor Bldg Equipment 20469-02 "Standby Gas Treatment DIW Exhaust" is in "CLOSED" position. Reactor Bldg Equipment Exhaust" is in
- the "CLOSED" position .
Initial and date the check off list step 13 Verify AO-20470-01 "Standby Gas P On panel 20C012 recognize that AO-Treatment Refuel Floor Exhaust" is in 20470-01 "Standby Gas Treatment "CLOSED" position. Refuel Floor Exhaust" is in the "CLOSED" position.
Initial and date the check off list step 14 Verify AO-20470-02 "Standby Gas P On panel 20C012 recognize that AO-Treatment Refuel Floor Exhaust" is in 20470-02 "Standby Gas Treatment "CLOSED" position. Refuel Floor Exhaust" is in the "CLOSED" position .
. Initial and date the check off list step 15 Verify PO-20465 "Exhaust to Standby P On panel20C012 recognize that PO-Gas Treatment Equipment Cell" is in 20465 "Exhaust to Standby Gas "CLOSED" position. Treatment Equipment Cell" is in the "CLOSED" position.
Initial and date the check off list step 16 Verify PO-20466 "Exhaust to Standby P On panel20C012 recognize that PO-Gas Treatment Rx Bldg" is in "CLOSED" 20466 "Exhaust to Standby Gas position. Treatment Rx Bldg" is in the "CLOSED" position.
Initial and date the check off list step PLOR337CA Rev001 Page 7 of 8
STEP NO STEP ACT STANDARD 17 Inform Control Room Supervision of P Inform Control Room Supervision of completion of partial SGTS lineup. completion of partial COL 9A.1.A. A lineup verification of the Unit 2 Main Control Room portion of the SGTS has been performed.
18 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND
- procedures.
Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When a lineup verification of the Unit 2 Main Control Room portion of the SGTS has been performed the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.
PLOR337CA Rev001 Page 8 of8
TASK CONDITIONS/PREREQUISITES
- 1. A Unit 2 startup is in progress.
- 2. Emergent maintenance was performed on various components of the Standby Gas Treatment System (SGTS).
- 3. Shift Management directs that a lineup verification of the Unit 2 Main Control Room portion of the SGTS be performed.
- 4. A 'partial of COL 9A.1.A "Standby Gas Treatment System Automatic Operation" has been reviewed and approved for use.
INITIATING CUE The C9ntrol Room Supervisor directs you to perform an Independent Verification (IV) of the Unit 2 Main Control Room portion of the SGTS using the approved partial of COL 9A.1.A "Standby Gas Treatment System Automatic Operation". Do NOT manipulate any components.
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET 01 Peach Bottom I D Limerick Common
~ JPM D QUALIFICATION MANUAL OJTMODULE LICENSED OPERATOR TRAINING PLOR-272C LICENSED OPERATOR REQUALIFICATION 000 J. A. Verbillis Jav Recognize and Report License Medical Condition Challenge APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature f Title Date EFFECTIVE DATE: _ _---.;,_ _---.-.:'_ __
~
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE ID#: COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMSCODE:
LMS ENTRY:
Signature/Date PLOR272C RevOOO Page 1 of4
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2991090301 - PLOR-272C KIA: G2.1.4 URO: 3.3 SRO: 3.8 TASK DESCRIPTION: Admin Process for NRC License and Medical Requirements A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a
Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
PLOR272C RevOOO Page 2 of 4
B. TOOLS AND EQUIPMENT
- 1. OP-AA-1 05-1 01 "Administrative Process for NRC License and Medical Requirements" C. REFERENCES
- 1. OP-AA-1 05-1 01 "Administrative Process for NRC License and Medical Requirements" Rev 014 Related Operating Experience:
- 2. CR 158767 "Failure to Notify Medical Department of Change in Medical Status" (PB Opex - Licensed Operator in MCR with Fractured Wrist)
- 3. CR 961772 "NRC ADR Agreement Required Corrective Actions" (PB Opex - Licensed Operator failed to report arrest)
D. TASK STANDARD
- 1. Satisfactory task completion is indicated when the candidate identifies the individual's reporting requirements associated with the stated medical condition.
- 2. Estimated time to complete: 10 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, evaluate the stated conditions and determine what, if any, reports or notifications the individual is responsible to complete. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. An at-home accident results in a fracture of the wrist of your non-dominate hand.
- 2. You received treatment at the local hospital, and were given a return-to-work directive from the attending Emergency Room physician.
- 3. You are scheduled to relieve the Unit 2 Reactor Operator in 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.
G. INITIATING CUE Identify the entities, (if any) (by position or title) whom you are responsible to notify and the required time frame, if applicable, in which they must be notified. Document requirements on cue sheet.
PLOR272C RevOOO Ige 3*014
H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD
- NOTE TO EVALUATOR****
Upon request, candidate may be provided with a copy of OP-AA-105-101 "Administrative Process for NRC License and Medical Requirements."
- 1 Identify that the individual's supervisor is P Candidate correctly identifies need to to be notified. notify their supervisor. (Ref 1, Para 3.4 2r 4.6.1, 4.6.2)
J
- 2. Identify supervision must be notified prior P Candidate correctly identifies that the to the relieving the shift notification to supervision must be made prior to relieving the shift. (Ref 1, Para 3.4)
- 3 Identify that the Operations Support P Candidate correctly identifies need to Manager is to be notified. notify the Operations Support Manager.
(Ref 1, Para 3.4 2r 4.6.1, 4.6.2)
- 4 Identify that the Operations Support P Candidate correctly identifies that the Manager must be notified prior to the notification to the Operations Support relieving the shift Manager must be made prior to relieving the shift. (Ref 1, Para 3.4)
- 5 Identify that Occupational Health Services P Candidate correctly identifies need to (OHS) is to be notified. notify OHS - acceptable to refer to this as
.. Site Medical, Medical, Site Nurse or similar. (Ref 1, Para 3.4 2r 4.6.1, 4.6.5)
- 6 Identify that OHS must be notified prior to P Candidate correctly identifies that the the relieving the shift notification to OHS must be made prior to relieving the shift. (Ref 1, Para 3.4) 7 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simulate I. .. TERMINATING CUE When the candidate has turned in the cue sheet, the JPM can be terminated.
PLOR272C RevOOO Page 4 of4
TASK CONDITIONS/PREREQUISITES
- 1. An at-home accident results in a fracture of the wrist of your non-dominate hand.
- 2. You received treatment at the local hospital, and were given a return-to-work directive from the attending Emergency Room physician.
- 3. You are scheduled to relieve the Unit 2 Reactor Operator in 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.
INITIATING CUE Identify the entities, (if any) (by position or title) whom you a~e responsible to notify and the required time frame, if applicable, in which they must be notified.
Document requirements on cue sheet.
Entity o Notification Time
OP*AA*1 05*1 01 Exelon.!, Revision 14 Page 1 of 30 Level 3 - Information Use Nuclear ADMINISTRATIVE PROCESS FOR NRC LICENSE AND MEDICAL REQUIREMENTS
- 1. PURPOSE 1.1. This procedure describes the administrative process for United States Nuclear Regulatory Commission (NRC) licenses, including initial license applications, license renewal, Biennial Medical Examinations, and updates to the NRC to report changes in an individual's license status.
- 2. TERMS AND DEFINITIONS 2.1. Action Tracking' Action Tracking Item: Refers to the formal program used by the site to track performance of specific action items and commitments. Examples of formal programs include but are not limited to Passport, PIMS, etc. Within this context, the "owed to" individual is the on-site individual for whom the action or commitment is being completed.
2.2. "Administrative No Solo" An administrative restriction placed upon a NRC Licensed Operator by OHS pending further review of a "health status change".
2.3. "Administrative Hold": An administrative restriction placed upon a NRC Licensed Operator by OHS restricting the licensee from performing licensed duties pending further evaluation of a "health status change".
2.4. Annual
Once per calendar year. For example, an annual test last performed in January 1995, would be due again by December 31,1996.
2.5. Applicant
Person applying for a NRC Reactor Operator, Senior Reactor Operator, or Senior Reactor Operator - Limited license.
2.6. Biennial Medical Examination: The medical examination given every 2 years, required by the NRC for all licensed individuals. For purposes of the medical examination, "biennial" is a period of time equal to 730 days and synonymous with the term "two years". Biennial medical examination requirements can extend beyond 730 days if the requirement is met during the anniversary month of the second year. For example, a Biennial Medical Examination last performed on January 10, 1995, would be due again by January 31,1997. January is seen as the anniversary month, the period of time between the two examinations is longer than 730 days, but the biennial requirement is satisfied. This medical examination is required for ALL NRC licensed individuals (active and inactive license status).
2.7. Certificate of Medical History (CMH): Health history completed by the applicant.
See HR-AA-07-101, Licensed Nuclear Operator Medical Examination - Attachment 2 for a copy of the form.
OP-AA-1 05-1 01 Revision 14 Page 20f30 2.8. Comprehensive Written Examination: See Licensed Operator Requal Training Program description for definition.
2.9. Disability
Refers to the physical or mental incapacitation of the individual to the extent that performance of assigned duties is impaired. Examples of physical impairment include loss or partial loss of hearing, color perception, manual dexterity, or the need for corrective lenses. Examples of mental impairment include drug addiction, habitual or excessive use of alcohol, or nervous exhaustion.
2.10. Examining Physician: The individual designated by the Company to perform NRC license physical. This includes medical doctor, physician assistant, or nurse practitioner.
2.11. Exelon Medical Advisor: A licensed physician contracted by OHS to review all NRC physical exams and to medically certify, or disqualify the licensee. There is an Exelon Medical Advisor assigned to each NRC region applicable to Exelon Nuclear (RI and Rill) 2.12. Facility Licensee: Means an applicant or a holder of a license for a facility.
2.13. Facility Operator Report (FOR): Report completed by an Applicant's or Licensee's supervisor, signed by Station Management, and submitted to Occupational Health Services (OHS) to aid in the medical evaluation process. See HR-AA-07-101, Licensed Nuclear Operator Medical Examination - Attachment 1 for a copy of the form.
2.14. Licensee: Person holding an NRC Reactor Operator, Senior Reactor Operator, or SeniOfRe.~ ~rator-Limited license.
2.15. License Coordinator: Responsible individual on site who tracks NRC license and medical requirements. This is the Operations Training Manager or designee.
2.16. Medical Information: All identifiable information regarding employee health, diagnosis, and treatment. This includes copies of all correspondence to ! from the NRC concerning follow-up medical examination requests that specify an individual and a specific health issue, such as a request for a follow-up exam for a specific reason, etc for an identified individual. This also includes all correspondence to!
from OHS and personal health physician as requested by OHS.
2.17. "Need to Know": These are personnel necessary to effect accuracy! verification and concurrence of the correspondence to be transmitted to the NRC. This includes OHS, Regulatory Assurance, and the SVP or designated signature authority.
2.18. "No Solo" Operation: License restriction that prohibits solo operation in the Main Control Room.
2.19. NRC Form 396. Certification of Medical Examination by Facility Licensee: The form certifies that an individual meets certain medical fitness criteria provided in ANSI! ANS 3.4, "Medical Certification and Monitoring of Personnel ?~quiring Operator Licenses for Nuclear Power Plants,"
OP-AA-1 05-1 01 Revision 14 Page 10 of 30 NOTE: It is recommended that the Licensed Operator Requal (LORT)
Group Lead begin preparing an Accelerated Requalification Training Program no later than 18 months from the termination date of the license.
NOTE: The License Re-Application is required to be submitted to the NRC no later than 30 days prior to the expiration of the 2 year period since the termination of the license.
4.3.1. The License Coordinator shall ensure that an Accelerated Requalification Program is initiated.
NOTE: For License re-applications, the medical data in support of NRC Form 396 are good for 6 months from the date of the medical examination.
4.3.2. The Operations Support Manager shall ensure the Applicant's previous medical examination date is within 6 months of the anticipated license date.
- 1. If the date is NOT within 6 months, the License Coordinator shall ensure the Applicant's medical examination is scheduled with OHS and that the Operations Support Manager is informed of scheduled medical examination date.
4.3.3. The License Coordinator should ensure that the following is performed when processing a License re-application following termination:
- 1. USE the following forms for each individual re-applying for a license:
A. NRC Form 398 B. If a medical examination will be given, then OBTAIN from OHS the current, unsigned NRC Form 396, and FORWARD to the Facility Licensee's senior management representative on site for Signature through Regulatory Assurance.
C. Ensure the following completed forms are routed to OHS.
- 1. CMH
- 2. FOR
- 2. ROUTE the NRC Form 398 and the Certificate of Medical History to the Applicant to fill out and VERIFY any pre-printed information on the NRC Form 398 is correct. Both forms, as required, should be returned to the License Coordinator, with the CMH sealed in the envelope provided. (Use TQ-JA 150-25 as required)
OP-AA-1 05-1 01 Revision 14 Page 11 of 30
- 3. If a medical examination will be given, ROUTE the FOR to the applicant's Supervisor to be completed and signed by the Supervisor. The FOR shall then be routed to Station Management and then to OHS.
4.3.4. Afterthe medical examination is complete, OHS will forward completed NRC Form 396, to the License Coordinator.
- 1. In the event a license restriction other than Corrective Lenses or Hearing Aids is being proposed, the proposed wording of the restriction and the relationship of the restriction to disqualifying condition shall be documented. OHS shall create a letter describing the restriction, the NRC Form 396 block shall be checked and marked Usee attached", and any supporting medical evidence shall be attached.
- 2. The supporting medical evidence shall be controlled on a "Need to Know" basis necessary to support submitting the information to the NRC.
4.3.5. The Licensed Operator Requalification Training Group Lead Instructor shall ensure completion of the Accelerated Requalification Program no later than 45 days prior to the expiration of the 2 year period since the termination of the license.
4.3.6. The license Coordinator shall ROUTE the NRC Form 398 to the Applicant to complete, update, or revise as necessary.
- 1. INCLUDE in NRC Form 398, Block 17, "Comments", or in the cover letter sent to the NRC with the NRC Form 398, the following information:
A. "The Applicant" previously discharged his responsibilities competently and safely and is capable of continuing to do so.
B. "The Applicant" terminated participation in the facility licensee's requalification program less than 2 years (24 months) before the date of the license application.
C. "The Applicanf' successfully completed an Accelerated Requalification Program pursuant to 10 CFR 55.59(b), "Requalification," and a facility prepared written examination and operating test, which ensures that he is up-to-date in the licensed operator requalification training program.
D. "The Applicanf will successfully complete at least 40 hours4.62963e-4 days <br />0.0111 hours <br />6.613757e-5 weeks <br />1.522e-5 months <br /> of shift functions under the direction of an Operator or Senior Operator, as appropriate, and in the position to which he will be assigned (per 10 CFR 55.53(f), "Conditions of licenses") before being assigned to licensed duties.
OP-AA-105-101 Revision 14 Page 12 of 30 NOTE In the following statement, 10 CFR 55.31 (a)(3) discusses the ILT written and operating examinations, for which a waiver is being requested. 10 CFR 55.31 (a)(5) discusses the requisite 5 reactivity manipulations. Since the Operator was previously licensed, the statement certifying successful operation of the controls will suffice.
E. "The Applicanf has completed the requirements of 10 CFR 55.31, "How to apply," with the exception of 10 CFR 55.31 (a){3), (since a waiver is being requested) and 10 CFR 55.31 (a)(5), since the Facility Licensee's senior management representative on site is certifying that he successfully operated the controls as a licensed operator.
- 2. OBTAIN a signature from the Licensee and the Training Director when all of
_ the information on the NRC Form 398 has been verified and printed on the NRC Form 398.
- 3. OBTAIN from OHS a current, unsigned NRC Form 396, and FORWARD to the Facility Licensee's senior management representative on site for signature through Regulatory Assurance.
NOTE Signed, certified NRC Forms 396 and 398 shall be sent and postmarked for delivery to the NRC not less than 30 days before the expiration of the 2 year period since the termination of the license.
- 4. SUBMIT signed and certified NRC Forms 396 and 398 through Regulatory Assurance to the NRC, with a copy of Form 396 sent to OHS.
- 5. MAINTAIN a copy of signed NRC Form 398 in the individual's license file and a copy of signed NRC Form 396 in the individual's medical file.
- 6. FilE a copy of the license in the individual's license file once the operating license is issued and FORWARD a copy of the license to OHS for inclusion in the individual's medical file.
- 7. ENSURE the License File or other required Database(s) are updated as necessary.
OP-AA*1 05-1 01 Revision 14 Page 13 of 30 4.4. Processing Biennial Medical Examinations and Updates NOTE: REFER to Attachment 6 for process flowchart. This flowchart provides a method of tracking progress of individual Licensee Biennial Medical Examinations and updates.
NOTE: It is recommended that the License Coordinator begin preparing the paperwork for the Biennial Medical Examinations approximately 120 days prior to the medical expiration date (2 years from the last medical examination date on NRC Form 396 plus the end of the anniversary month).
NOTE: NRC will normally allow to the end of month of the Biennial Medical Examination due date to complete the required examination. This should be an exception and not the normal practice.
4.4.1. The License Coordinator shall ensure each Licensee's medical examination is scheduled with OHS no later than 30 days prior to the medical examination expiration date and that the Operations Support Manager is informed of scheduled medical examination dates.
4.4.2. The License Coordinator ENSURES the following is completed when processing a licensee's Biennial Medical Examination and update:
- 1. ROUTE the CMH to the Licensee with instructions to complete the form and return to tfte*.IAi8 Qeordinator sealed in the envelope provided.
- 2. ROUTE the FOR to the applicant's Supervisor to be complete and signed by the Supervisor prior to the medical examination date. The FOR should then be routed to Station Management. The FOR should then be routed to OHS prior to the medical examination date.
- 3. ENSURE the following completed documents are forwarded to OHS:
A. FOR B. CMH 4.4.3. OHS shall VERIFY the completion of each day's SCHEDULED medical examinations.
- 1. OHS shall notify the License Coordinator of any Licensee that failed to report for their scheduled medical exam.
A. The License Coordinator shall initiate an Issue Report to document the failure to report for a medical exam.
OP*AA-105*101 Revision 14 Page 14 of 30
- 2. If a Licensee fails to receive their medical exam as scheduled, then it is the
. responsibility of the License Coordinator to reschedule their exam within the required time period.
- 3. OHS should notify the License Coordinator if any Licensee scheduled to receive a medical exam on a given day failed to complete the exam.
A. The License Coordinator shall initiate an Issue Report to document the failure to complete a medical exam 4.4.4. If an individual fails to take their scheduled Biennial Medical Examination prior to the medical expiration date, then the License Coordinator shall immediately:
- 1. NOTIFY the Operations Support Manager to immediately REMOVE that person from license duties until such time as an examination is completed.
- 2. INITIATE an Issue Report.
- 3. NOTIFICATION to the NRC will be required to report the invalid license .
4.4.5. OHS shall NOTIFY the Licensee, License Coordinator and Operations Support Manager immediately if it is determined from the Biennial Medical Examination that Licensee is not medically qualified to perform license duties.
- 1. OHS shall NOTIFY the Operations Support Manager to have the individual removed from license duties until the medical qualification is satisfied.
4.4.6. If any follow-up medical information is requested of the Licensee by OHS to complete the medical certification, then DO the following:
- 1. OHS shall NOTIFY the individual Licensee for any follow-up visits to his / her personal health physician, if needed to complete the medical certification.
- 2. The Licensee shall FOLLOW UP with his/her personal health physician, or OHS. depending on instructions provided and PROVIDE that information to OHS by the date specified.
- 3. OHS shall NOTIFY the License Coordinator and Operations Support Manager if the Licensee fails to provide the follow-up medical information to OHS within the specified time period.
- 4. OHS shall NOTIFY the License Coordinator and may place the Licensee on temporary license restriction* until the information is provided.
- 5. OHS shall NOTIFY the Operations Support Manager if the decision is made to place the Licensee on temporary restriction.
OP-AA-1 05-1 01 Revision 14 Page 15 of 30 4.4.7. If any NRC Form 396 indicates a restriction change or an information notification, then OHS shall CHECK the appropriate box on NRC Form 396 and indicate, "See attached documentation".
- 1. OHS shall provide a letter indicating the change in restriction or condition, Q!
will provide a letter detailing "information only" notification.
4.4.8. OHS shall FORWARD the completed NRC Forms 396 in a sealed envelope, to the License Coordinator when all are completely certified.
4.4.9. OHS shall FILE the unsigned NRC Form 396 in the individual's medical file.
4.4.10. If there are any license restriction changes or other identified changes in medical status requiring NRC notification from the previous NRC Form 396, then the License Coordinator shall do the following:
- 1. INITIATE Attachment 3 to help track required notifications.
- 2. INFORM the Operations Support Manager.
- 3. CREATE an Action Tracking item owed to the Operations Support Manager to track completion of the required report.
- 4. ROUTE NRC Form 396 to Regulatory Assurance for signature by the Facility Licensee senior management representative on site.
- 5. FORWARD the signed NRC Form 396 and any supporting medical information to the NRC through Regulatory Assurance immediately, under cover letter signed by Facility Licensee senior management representative onsite.
A. If site Regulatory Assurance disagrees with or questions the reportability of medical information provided by OHS, then REFER the disagreement I question to the Nuclear OHS Manager and Corporate Licensing for resolution.
- 6. CLOSE the Action Tracking item created above when the required NRC notification has been completed.
- 7. Regulatory Assurance shall ROUTE a signed copy of the NRC Form 396 to OHS to file in the Licensee's medical file.
- 8. The License Coordinator shall UPDATE the Licensee File Database as necessary.
- 9. The License Coordinator shall NOTIFY the DTC of any changes in qualification.
- 10. The License Coordinator shall ENSURE the Qualification Tracking Database is updated.
OP-AA-105-101 Revision 14 Page 16 of 30 4.5. Processing Respirator Qualification 4.5.1. Respirator qualification is comprised of three distinct components.
NOTE: Respirator qualification is required annually per OSHA (10CFR29 Part 1910.134) regulations for ALL NRC licensed individuals (active and inactive license status).
- 1. The License Coordinator shall ensure each Licensee's respirator examination is scheduled with OHS no later than 30 days prior to the respirator examination expiration date and that the Operations Support Manager is informed of scheduled medical examination dates. Every other year this is completed as part of the Biennial Medical Examination for NRC licensed individuals.
- 2. The License Coordinator or designee shall ensure each Licensee's mask fit is scheduled with Radiation Protection no later than 30 days prior to the mask fit expiration date and that the Operations Support Manager is informed of scheduled medical examination dates. This is required annually.
- 3. The Department Training Coordinator shall schedule appropriate respirator training for ALL NRC licensed individuals (active and inactive license status).
- Normally this is performed as part of annual NGET training.
4.6. Process for Reporting Changes in Health Status 4.6.1. Some examples of changes in health status that could cause a condition I restricted license are:
NOTE: The following list is not all-inclusive. ANY change in health status shall be reported by the Licensee to OHS so proper evaluation against the ANSI standard of the impact on the individual's NRC license can be performed and any required notifications completed within the 30 day notification window.
NOTE: Whether the Licensee serves on shift or not, notifications of any change in health status to the NRC need to be evaluated by OHS against the ANSI standard prior to the next scheduled shift.
Usually, if the Licensee has a temporary disability that would preclude them from performing regular duties, the Licensee would be restricted from those duties, and the temporary disability would need to be reviewed per the ANSI standards for possible notification to the NRC. Generally, the NRC notification is only required in the case of a permanent disability but determination needs to be made for every health status change.
OP-AA-1 05-1 01 Revision 14 Page 17 of 30 NOTE: Personnel who are maintaining an NRC License are required to report the use of prescription or over the counter medications, other than aspirin, aspirin substitute, antibacterial, and birth control to their immediate supervisor and OHS in accordance with SY-AA-102-106.
High blood pressure and lor medication changes Angina or coronary disease (chest pain, heart disease)
Heart rhythm abnormality Stroke or TIA (cerebral vascular accident or transient ischemic attacks)
Fainting spells, seizures, or epilepsy Asthma Arthritis (limiting mobility)
Fracture or joint dislocation Diabetes and I or medication changes Cirrhosis, hepatitis, or other liver disorders Diagnosed psychiatric or psychological condition and medications used in treatment NOTE: Referral for dependency evaluation as a result of a DUI requires OHS notification.
Alcoholism, alcohol abuse, alcohol dependency Drug dependency Changes invision, including glaucoma, cataracts, or laser eye surgery Changes in hearing Cancer (even successful surgery)
Skin condition (limiting ability to work or wear respirator)
Bleeding from stomach or bowel Emphysema or chronic bronchitis Surgery or traumatic injury Sleep apnea Medications and medication changes NOTE: At any time the OHS identifies the need to inform the NRC of a change or follow-up to a medical condition, OHS will prepare and submit a NRC Form 396 with the appropriate supporting information to the Licensing Coordinator.
4.6.2. Licensee shall NOTIFY his I her immediate Supervisor and the Operations Support Manager.
OP-AA-1 05-1 01 Revision 14 Page 18 of 30 4.6.3. The immediate Supervisor or the Operations Support Manager shall INITIATE Attachment 3 when a change in health condition that affects or has the potential to affect license status occurs.
4.6.4. The License Coordinator shall CREATE an Action Tracking item, with sub assignments as appropriate, owed to the Operations Support Manager to track proper reporting of the status change.
4.6.5. Licensee shall NOTIFY OHS of the change in health status prior the next scheduled shift.
- 1. OHS shall EVALUATE information provided by the Licensee, and based on the evaluation may place the Licensee's license on "Administrative Hold" pending further evaluation of the condition.
A. OHS shall NOTIFY the Licensee, and the License Coordinator if an individual's license is placed on "Administrative Hold".
B. OHS shall NOTIFY the Operations Support Manager to remove the individual from license duties.
4.6.6. Changes in license status must be reported to the NRC within 30 days. The License Coordinator shall NOTIFY Regulatory Assurance to develop the letter required for NRC notification.
- 1. If site Regulatory Assurance disagrees with or questions the reportability of medical information provided by OHS, then REFER the disagreement I question to the Nuclear OHS Manager and Corporate Licensing for resolution.
4.6.7. When the required correspondence has been sent to the NRC providing notification of the status change, then the Operations Support Manager shall CLOSE the Action Tracking item created above.
4.6.8. Regulatory Assurance shall ROUTE a signed copy of the NRC Form 396 to OHS to file in the Licensee's medical file.
4.6.9. The License Coordinator will NOTIFY the OTC of any changes in qualifications.
4.7. Reporting Changes in License Status (refer to Attachment 4) 4.7.1. Changes in NRC license status can result from any of the following:
Permanent Licensee disability due to a physical or mental condition
" Permanent reassignment to a position not requiring a license Termination of Licensee
OP-AA-1 05-101 Revision 14 Page 19 of 30 Felony conviction of Licensee Significant Fitness for Duty Event Changes in health status (refer to Section 4.5)
Licensee name change due to marriage or divorce 4.7.2. licensee shall NOTIFY his I her immediate Supervisor, the Operations Support Manager to INITIATE Attachment 3 when an event that affects or has the potential to affect license status occurs.
4.7.3. license Coordinator shall CREATE an Action Tracking item, with sub-assignments as appropriate, owed to the Operations Support Manager to track proper reporting of the status change.
4.7.4. The Operations Support Manager shall assist the licensee in making the notifications required and shall assist in the determination of reportability.
4.7.5. Ghangesin license status must be reported to the NRC within 30 days. The License Coordinator shall NOTIFY Regulatory Assurance to develop the letter required for NRC notification.
4.7.6 . If Regulatory Assurance disagrees with or questions the reportability of information
- provided by the Operations Support Manager and Licensee. then REFER the disagreement I question to the Corporate licensing and Corporate Operations Director for resolution.
4.7.7. The Operations Support Manager shall CLOSE the Action Tracking item created above when the required NRC notification has been completed.
4.7.8. license Coordinator shall notify the DTC of any changes in qualification.
4.7.9. license Coordinator shall ensure that the Qualification Tracking Database is updated as necessary.
4.8. licenses with Operating Conditions Reguiring Medical Follow-Up 4.8.1. When a new or amended license with an operating condition requiring medical follow-up is received from the NRC, it is the licensee's responsibility to ensure compliance with the follow-up requirements.
4.8.2. licensee shall NOTIFY his I her immediate Supervisor, the Operations Support Manager, and OHS of the license condition.
4.8.3. licensee shall PROVIDE required follow-up information to OHS within the time frame specified.
OP-AA-1 05-1 01 Revision 14 Page 20 of 30 4.8.4. OHS shall NOTIFY the License Coordinator when the medical information required by the license condition has been received from the Licensee and shall FORWARD appropriate information to the License Coordinator for transmittal to the NRC through Regulatory Assurance.
- 1. The License Coordinator will create an Action Tracking item, with sub aSSignments as appropriate, owed to the Operations Support Manager to track completion of required follow-up medical information submitted to the NRC within the timeframe specified by the NRC.
4.8.5. If the Licensee fails to meet the reqUirements on the amended license within the time frame specified, then OHS shall immediately NOTIFY the Licensee. the Operations Support Manager, and License Coordinator.
4.8.6. If it is determined the Licensee is no longer medically fit to perform license duties, then OHS shall:
- 1. NOTIFY Licensee of medical disqualification pending receipt of required medical information.
- 2. Medically disqualify the Licensee
- 3. NOTIFY the Operations Support Manager to immediately remove the individual from license duties.
- 4. WORK with the License Coordinator and Regulatory Assurance to ensure NRC notifications are completed in accordance with Attachment 3.
NOTE: Attachment 5 must be completed annually at each site, but the timing of completion may vary. Typically this is during the first quarter of the year, but that timing may be delayed for site-specific reasons, such as being completed in the quarter following annual exams if the exams are completed early in the year.
4.9. NRC License Maintenance Requirements Tracking 4.9.1. Operations Training, typically the License Coordinator, shall complete Attachment 5, "NRC License Maintenance Requirements Tracking Sheet", annually for each license holder.
The Operations Training Manager and SOS or Operations Director shall review and approve each completed Attachment 5.
Each Licensee shall review and sign his I her completed Attachment 5.
4.9.2. A copy of the completed Attachment 5 will be provided to each Licensee and the original Attachment 5 will be placed in each individual's license file.
OP-AA-105-101 Revision 14 Page 21 of 30 4.9.3. Results of the annual NRC license maintenance requirements review for all licenses shall be reported out by the SOS I Operations Director and I or Operations Training Manager to the Operations Director and Training Director for their concurrence.
4.10. Periodically (approximately quarterly), the License Coordinator will provide each Shift Manager a listing of licensed personnel on his I her crew that have licenses with "No Solo" restrictions for information and verification of accuracy. Inaccuracies shall, be resolved in accordance with Sections 4.4 or 4.5 as appropriate.
- 5. DOCUMENTATION - None
- 6. REFERENCES 6.1. SAF 1.10, 1.36, 1.41:'1:42, 1.43: Exelon Reportability Manual 6.2. 10 CFR 26, Fitness for Duty 6.3. 10 CFR 29, OSHA General Industry Standards 6.4. 10 CFR 55, Operators' Licenses 6.5. 10 CFR 50.74, Notifications of Change in Operator or Senior Operator Status S.S. NUREG-1021 , Operator Licensing Examiner Standards for Power Reactors
~
6.7. ES-202, Preparing and Reviewing Operating Licensing Applications 6.B. ES-605, License Maintenance, License Renewal Applications. and Requests for Administrative Reviews and Hearings 6.9. NRC Form 39B, Personnel Qualifications Statement (License Application) 6.10. NRC Form 396, Certification of Medical Examination by Facility Licensee 6.11. Certificate of Medical History (CMH)
S.12. Facility Operator Report (FOR)
S.13. General Procedures Memorandum Ref. No. 345 Appendix A 6.14. HR-~-07-101. Licensed Nuclear Operator Medical Examination.
6.15. SY-AA-102-206, Reporting Use of Medication 6.16. TQ-JA-150-25, NRC Form 398 Submittal Checklist 6.17. AR 523435, Root Cause Investigation of Medical Disability of Licensed Individuals Not Reported to NRC.
OP-AA-1 05-1 01 Revision 14 Page 22 of 30
- 7. ATTACHMENTS
- 7.1 . Attachment 1, License Application Process Flow Chart 7.2. Attachment 2, License Renewal Process Flow Chart 7.3. Attachment 3, Reporting NRC License Status Changes 7.4. Attachment 4, License Status Change Flow Chart 7.S. Attachment 5, NRC License Maintenance Requirements Tracking Sheet 7.6. Attachment 6, Biennial Medical Examination Process Flow Chart
OP-AA-1 05-1 01 Revision 14 Page 23 of 30 ATTACHMENT 1 License Application Process Flow Chart Page 1 of1 l Im~iallicensJ
[.-
Application
~ r= H I ,--schedul;---H--Route'FoR to' Ap r t' Route NRC Form .
398 and CMH to ,
. APP,Jicant'S medical' supe~/:rnt: be Applicant 1 examination with completed and
__ __. ~_OHS.
- -.I*---
signed.
l i~~'~::~:~s'l return form s to lr~complete:~~i~~1 FOR. return to License license Coordinator. Coordinator.
--r~' --~----'-.-
R~~~~,~oJ r=---'
t---r SChed,Uled medical, Senior Mgmt. R ; ; ; l H Conduct medical exam.]
'-c-o-mplete--al'~
sign cover lett~;', exam send forpreliminary : comPleted'NRC Form 1-----+1 requirements for application (NRC J' 396 to License desired license
, Form 398). Coordinator. level.
Form 396) to NRC 396 in Applicant's completed/certified
>30 days before medical file. app6c:aoon (NRC
_~c:ense exam...:.....__ ",_ _ _. _ .
--_.]._
Form 396).
a~~f~~i:~=~H--;I:ce :~y of
~
Place copy of license in Yes License
'*Y/
>41-----< Form 398) to NRC signe,d NRC Form Applicant's license, ", received? / / >14 days before 398,in Applicant's
____ file. __ J No _n_~~~am:......
_ I. . ___.hcense file.
<",,~~:pI~::~'4es ~:~Z~~-~ca-<~-LJ.R=n~e~-p::~:1I Place copy of license in Applicant's medical file. "-..... ./' months old. * ' at Step 4.1.
No
"-.....(/ -- - - -...._ -i I
~-- ..--.---.... _...
STOP
OP-AA-1 05-1 01 Revision 14 Page 24 of 30 ATTACHMENT 2 License Renewal Process Flow Chart Page 1 of 1
-120 Days No VVait lIlIiI -120 days POOr 10 license >---____ prior 10 license expiration? expiration
~---. - - - H--- - - - , Yes l
Retun completed Send NRC Fonn 398 NRC Fonn 39810 10 Applicant 10 license Coordinator ~; update, reIIISe
- .:-~~~~-~~ HC.-;cMe~~~l Training Director signatures on printed current unsigned NRC Fonn 396 to I
to Regulatoly Assurance for NRC Form 398. I Senior ~ Rep_ - processing 10 NRC
~ _____ .~
. for ~nature i
,_------1 I
,--- --.i-Submit signed aM certified NRC Forms
~nIain copy of signedNRCFonn 398 in license file
- 398 and 39610 NRC
>30 days and
<60 days before STOP L-_
rICeI1Se expiration Yes
~--
~nIain copy of No
~
signed NRC Fonn Change in. ")
396 in medical file
-,----------- __5(:
, File copy of license in liCense file
-.~-.~.----.-
Go 10 Allachment 4
~~-***-*-
l File copy of license in medical file
~--'----~"'---~- .~
" OP-AA-1 05-101 Revision 14 Page 25 of 30 ATTACHMENT 3 Reporting NRC License Status Changes Page 1 of3 Changes in health status that affect NRC license restrictions are required to be reported to the NRC within 30 days ofleaming of the diagnosi!l. Similarty, the NRC must be notified within 30 day~ of an event that could affect the status of an NRC license~ The following actions should be taken to ensure that timely notification is made.
- 1. The License holder is made aware of a change that may affect license status.
- 2. The License holder notifies the appropriate personnel:
- a. Immediate Supervisor
- b. Operations Support Manager
- c. OHS
- d. Regulatory AssU!lilnce
- 3. The immediate Supervisor initiates Attachment 3 and hand delivers it to the License Coordinator
- 4. The License Coordinator initiates an Action Tracking item owed to the Operations Support Manager and due 28 days from the time the License holder submits documentation that could affect license status.
- 5. The License Coordinator notifies OSM, OTM. and OHS thata licensed individual has reported a potential change in license status and that an Ac1ion Tracking item has been assigned to theOSM for tracking of the issue. The Action Tracking number will be documented in the notification.
S. OHS determines if a permanent or temporary license restriction is required.
- 7. OHS determines if NRC notifICation is required, and by what date. '
- 8. If NRC notification is req~ired, or follow-up actions are required, continue below. If not, exit this process.
,,9. OHS notifies* License Coordinator that NRC notification andlor follow-up action is required.
- 10. License Coordinator issues a new Action Tracking item owed to the OSM to track the NRC notification andlor follow-up action. Due date is based on input from OHS.
- 11. OHS provides pertinent information to t"- License Coordinator for delivery to Regulatory Assurance for formal processing ofa notification letter.. ' ..
- 12. Regulatory Assurance develops NRC notification package and provides the package to the License Coordinator for review and approval routing.
- 13. License Coordinator coordinates the nMew and, ~pprovaJ of the notification package.
- 14. Regulatory Assurance issues the notificalion package to the NRC.
- 15. OSM completes associated Action TracPtg item.
OP*AA*1 05-1 01 Revision 14 Page 26 of 30 ATTACHMENT 3 Reporting NRC License Status Changes Page 20f3 IT IS THE RESPqNSIBIUTY OF THE IMMEDIATE SUPERVISOR OR THE OPERATIONS SUPPORT
- MANAGER TO INITlATE THIS ATTACHMENT, COMPLETE STEPS 1-5, AND THEN HAND DELIVER IT TO THE LICENSE COORDINATOR
- 1. License Holder Name: _ _ _ _ _ _ __
- 2. Date potential License status change was identified: _ _ _ _ _ _ __
- 3. Description of potential license status change and how it was identified:
- 4. Notify the following personnel as appropriate: (N/A those NOT notified and state why notification was NOT required
- Supervisor: Date or N/A: _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __
- OHS: Date or N/A: ___________________
- If Security related, forward information to Security:
D~eorN/A: ___________________________________
- Regulatbry Assurance: Date or N/A: _____________________
- 5. Attachment 3 delivered to the License Coordinator Date: _ _ _ _ _ _ _ _ _ __
- 6. Action Tracking item initiated to track determination of Permanent or Temporary Restriction of Duty_ Due date to be the date the potential change in license status was identified plus 21 days.
Date initiated: Initiated by: _ _ Date ATI is due:
- 7. OHS determines if license status is affected.
- Notification of PERMANENT change required Yes I No
- Temporary Restriction of Duty required Yes I No Date:
- 8. License Coordinator notified by OHS that a PERMANENT change or Temporary Restriction of Duty is required or not.
Date:
.If determined -to be a PERMANENT change, NRC notification is required within 30 days.
Continue on next page.
OP-AA-1 05-1 01 Revision 14 Page 27 of 30 ATTACHMENT 3 Reporting NRC License Status Changes Page 3 of3
- 1. Action Tracking item created by Licensed Coordinator (or designee) to notify NRC of license holders PERMANENT change in license status.
- Action Tracking number:
- Action Tracking due date:
(Date PERMANENT change identified plus 30 days. If due date falls on a weekend or holiday, due date is moved to next normal working day)
- 2. Pertinent information provided by OHS to the License Coordinator for routing to Regulatory Assurance.
Date:
- 3. License Coordinator performs the following:
- Notifies Regulatory Assurance of the need to develop NRC notification package
- Provides pertinent information obtained from the OHS.
- Peer checks the date that Regulatory Assurance will place on the cover letter for the NRC notification package.
Date:
- 4. License Coordinator routes NRC notification package for review and approval and returns package to Regulatory Assurance for final approvals.
Date:
- 5. Regulatory Assurance obtains final approval from the Plant Manager and Site Vice President for the NRC notification package.
Date:
- 6. Regulatory Assurance issues the NRC notification package to the NRC and notifies OSM of transmittal.
Date:
- 7. Operations Support Manager (or designee) documents NRC notification in associated Action Tracking item.
Date:
OP-AA-105-101 Revision 14 Page 28 of 30 ATTACHMENT 4 License Status Change Flow Chart Page 1 of 1 Recei~~
Lice!'lse with w restriction
<:~ a~!ifying
~vent?
- - - ---._-J l Notify Supervisor and Operations Support Manager
- ~-~.-
I Notify Supervisor and Operations Support Manager Notify Supervisor and Operations L~-i::~-
edical Follow-up required? r.Ta&~-1 Manager due in 30 days
=_=r_-~___ _ _
j l
-~-* Notify Regulatory Notify OHS of Assurance to Notify ()HS of health Process NRC Form I
H . .
restriction change condItIOn change : 396 t d t develop required and provide needed and provide needed 0 acumen correspondence to documentation status change do:umentation NRC
~=r~=
-.----[-~-
..1____._..___ ,
[
~nsmitan~-req~: Transmit required Notify Regulatory Assuranc to Review NRC Form correspondence to correpsondenceto develop required 396 for accuracy NRC NRC correspondence to NRC
- .. ~~---~.-~-,,~-
Close Action Transmit required Tracking Item correpsondence to created above NRC Close Action Tracking Item created above
OP*AA*1 05*1 01 Revision 14 Page 29 of 30 ATTACHMENT 5 NRC License Maintenance Requirements Tracking Sheet Page 1 of 1 '
License Holder:, _ _ _ _ _ _ _ _ _ _ _ _ _ _ __
NRC REQUIREMENT Required Last Due Date Requirement .
Frequency Completed Current Initials/Date j successfully complete a requalification program developed by the Facility Ucensee that has been approved by the Commission. This program shall be Less than or equal conducted for a continuous period not to exceed 24 months in duration. (10CFR to 24 months 55.53 10CFR55.59) j Pass a comprehensive requalification written examination. Every 730 days (or The written examination will sample the items specified in §§55.41 and 55.43 of once per requal this part, to the extent applicable to the facility, the licensee, and any limitation of ification cycle I the license under §55.53(c) ofthis part. (10CFR55.59) program)
Pass an annual operating test.
The operating test will require the Operator or Senior Operator to demonstrate Each calendar year an understanding of and the ability to perform the actions necessary to accomplish a comprehensive sample of items speCified in §55.45(a) (2) through (13>>)nclusive to the extent applicable to the facility. (10CFR55.59)
Complete a Biennial Medical Examination (10CFR55.53) Every 730 days (or more if met during anniversary month of second year)
NRC Ucense is current Every 6 Years I Action Tracking Completed required Biennial Medical Examination follow-up requirements. Number
,wed and Approved: Operations Training Manager SOS I Operations Director Reviewed: License Holder
OP-AA-105-101 Revision 14 Page 30 of 30 ATTACHMENT 6 Biennial Medical Examination Process Flow Chart Page 1 of 1
-120 Days Prior to Medical Expiration Date
~~3=~~~=-=~
Route CMH Schedule Applicanfs
- 1 Route FOR to f 4 . - - - - - I medical examination i - - - - - - I l l o i Applicant's supervisor to Applicant with OHS to be completed and, signed I
-'~-J-~-~--
~~-.~~.~--~----
~
CO:~I:te form, verify data, and return form Complete and sign FOR, return to to License License Coordinator i Coordinator L_~~-~-'~r~~'-'-- "T'~
Route forms to OHS prior to scheduled i medical exam '
-- 1~_I
~~~i~l-l h///~~"
/'
~Medical Conduct
<St~~s
~/
Change?
exam, send comp e I ted NRC Form 396 to license
~", MedIcal Change?
status",>
//
/'
'r L_~~O~~din~tor~~.~~ ' ' ' 1,,// //
Yes
.---~--~----j.-~~-~----
1 Yes File unsigned NRC Form 396 in individual's medical Initiate Attachment 3 file.
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET
((]I Peach Bottom I 01 Limerick I DI Common I
~- JPM D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR TRAINING PLOR-274C Licensed Operator Requalification 000 C. N. Croasmun cnc ISOLATING THE 3B RBCCW HEAT EXCHANGER DUE TO A LEAK APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _----" _ _ _.1_ __
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE 10#: COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMSCODE:
LMS ENTRY:
Signature/Date PLOR274C RevOOO Page 1 of6
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2002300401/ PLOR-274C KIA: G2.2.41 RO: 3.5 TASK DESCRIPTION: Ability to obtain and interpret station electrical and mechanical drawings A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
PLOR274C RevOOO Page 2 of6
B. TOOLS AND EQUIPMENT
- 1. A Full Set of each of the following P & IDs:
- a. M-314 series
- b. M-315 series
- c. M-316 series C. REFERENCES
- 1. P&ID M-316 sheet 3, Rev. 52
- 2. P&IO M-314 sheet 8, Rev. 65
- 3. P&IO M-315 sheet 4, Rev. 54
- 4. OP-AA-108-101 "Control of Equipment and System Status" D. TASK STANDARD
- 1. Satisfactory task completion is indicated when the isolation points and vent/drain paths for the RBCCW, Service Water, and Emergency Service Water side of the 3B RBCCW heat exchanger have been identified.
- 2. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE
- When given the initiating cue, determine the isolation points, vent paths, and drain paths necessary to isolate a tube leak located on the 3B RBCCW heat exchanger.
F. TASK CONDITIONS/PREREQUISITES A suspected tube leak has been identified on the standby 3B Reactor Building Closed Cooling Water (RBCCW) heat exchanger 3BE018. The Work Control Supervisor will be developing an Abnormal Component Position Sheet for isolation, venting, and draining of the 3B RBCCW heat exchanger.
G. INITIATING CUE The Control Room Supervisor directs you to identify the components and their required positions to isolate, vent and drain the tube and shell side of the 3B RBCCW heat exchanger.
Document your results on the CUE SHEET.
PLOR274C RevOOO Page 30f6
H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1* Locate the' component that is leaking on P Locate 3BE018 on M-316 sheet 3, P&ID drawings M-316 sheet 3 (RBCCW (Coordinates B-3) and on M-314 sheet 8 side) and M-314 sheet 8 (Service Water (Coordinates F-3).
side).
(Cue: Provide the candidate(s) with a full set of the M-314, M-31S and M-316 series P & IDs)
(Cue: If asked, inform candidate(s) that PIMS is down for IT maintenance)
-NOTE***
It should be determined by the Examinee that isolation points are selected first and then vents anq drains are to'be opened. This applies to both the RBCCW and Service Water sides of the heat exchanger.
- 2 Close HV-3-3S-3420SB "RBCCW HX P Identifies that HV-3-3S-3420SB "RBCCW 3BE018 Inlet Block Valve". HX 3BE018 Inlet Block Valve" must be CLOSED in order to ISOLATE RBCCW to the heat exchanger.
- 3 Close HV-3-3S-34210B "RBCCW HX P Identifies that HV-3-35-34210B "RBCCW 3BE018 Outlet Block Valve". HX 3BE018 Outlet Block Valve" must be CLOSED in order to ISOLATE RBCCW to the heat exchanger.
- 4 Open HV-3-3S-34206B "RBCCW HX P Identifies that HV-3-3S-34206B "RBCCW 3BE018 Drain Valve" HX 3BE018 Drain Valve" must be
- OPENED in order to DRAIN the RBCCW
- side of the 3B RBCCW heat exchanger.
PLOR274C RevOOO Page 4 of6
- 5 Open HV-3-35-34209B "RBCCW HX P Identifies that HV-3-35-34209B "RBCCW 3BE018 Lower Vent Valve" HX 3BE018 Lower Vent Valve" must be OPENED in order to VENT the lower section of the 3B RBCCW heat exchanger AND/OR AND lOR HV-3-35-34207B "RBCCW HX 3BE018 Open HV-3-35-34207B "RBCCW HX Upper Vent Valve" must be OPENED in 3BE018 Upper Vent Valve" order to VENT the upper section of the 3B RBCCW heat exchanger.
- 6 Close HV-3-30-31866B "Service Water P Identifies that HV-3-30-31866B "Service Inlet to B RBCCW HX Block Valve". Water Inlet to B RBCCW HX Block Valve"
- must be CLOSED in order to ISOLATE Service Water to the heat exchanger.
- 7 Close HV-3-30-31867B "Service Water P Identifies that HV-3-30-31867B "Service Outlet from B RBCCW HX Block Valve". Water Outlet from B RBCCW HX Block Valve" must be CLOSED in order to ISOLATE Service Water to the heat exchanger.
- 8 Close HV-3-33-520B "ESW to RBCCW Identifies that HV-3-33-520B "ESW to HX 3BE018 Inlet Block Valve". RBCCW HX 3BE018 Inlet Block Valve" must be CLOSED in order to ISOLATE Emergency Service Water to the heat exchanger.
- Tube Side Inlet Drain Valve" RBCCW HX Tube Side Inlet Drain Valve" must be OPENED in order to DRAIN the Service Water side of the 3B RBCCW heat exchanger.
- 10 Open HV-3-30-31869B "B RBCCW HX P Identifies that HV-3-30-31869B "B Tube Side Low Point Drain Valve" RBCCW HX Tube Side Low Point Drain Valve" must be OPENED in order to DRAIN the Service Water side of the 3B RBCCW heat exchanger.
- 11 Open HV-3-30-70B "B RBCCW HX Tube P Identifies that HV-3-30-70B "B RBCCW Side High Point Drain Valve" HX Tube Side High Point Drain Valve" must be OPENED in order to DRAIN the Service Water side of the 3B RBCCW heat exchanger.
~
PLOR274C RevOOO Page 5 of6
- 12 Open HV-3-30-71B uB RBCCW HX Tube P Identifies that Open HV-3-30-71 BUB Side Vent Valve" RBCCW HX Tube Side Vent Valve" must be OPENED in order to VENT the Service Water side of the 3B RBCCW heat exchanger.
13 Inform Control Room Supervisor of task P The operator informs the Control Room completion . Supervisor of task completion.
(Cue: The Control Room Supervisor acknowledges the report.)
14 As an evaluator ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simulate L TERMINATING CUE When the RBCCW, Service Water and Emergency Service Water isolation points, vent paths, and drain paths to the 3B RBCCW heat exchanger have been identified, and the Control Room Supervisor informed, the evaluator will terminate the exercise.
PLOR274C RevOOO Page 60f6
TASK CONDITIONS/PREREQUISITES A suspected tube leak has been identified on the standby 3B Reactor Building Closed Cooling Water (RBCCW) heat exchanger 3BE018. The Work Control Supervisor will be developing an Abnormal Component Position Sheet for isolation, venting, and draining of the 3B RBCCW heat exchanger.
INITIATING CUE
. The Control Room Supervisor directs you to identify the components and their required positions to isolate, vent and drain the tube and shell side of the 3B RBCCW heat exchanger. Document your results on this CUE SHEET:
34..11-6' Tl
~
~l 168 Y
~-T ORW l<4J1l-I' REACTOR BUlt.DINC CLOSm COQ.JNC WATER HEAT EXCHANGERS B:::J!!:
y y ORW DRW RBCCW Heat Exchangers M-316 sheet 3
U<.
(WTiir>--<Jjf.
_____,~~=_.~~__~~_~
______W._T_____n~___________
~~.~"'_~_~_ _
.~~~~
Service Water to RBCCW HX M-314 sheet 8
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET 01 Peach Bottom I DI Limerick I DI Common
~ JPM QUALIFICATION MANUAL OJTMODULE LICENSED OPERATOR TRAINING PLOR-258C LICENSED OPERATOR REQUALIFICATION 001 M. J. Kelly jav PRO DUTIES FOR A LIQUID RADWASTE DISCHARGE APPROVALS:
Signature J Title Date Signature I Title Date Signature I Title Date Signature J Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _ _ _,____,_ __
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE ID#: COMPLETION DATE:
COMMENTS:
TraiRing Review for Completeness: LMSCODE:
LMS ENTRY:
Signature/Date PLOR258C Rev001 Page 1 of4
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE:
- Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 27301302021 PLOR-258C KIA: 2.3.11 URO: 3.8 SRO: 4.3 TASK DESCRIPTION: Ability to control radiation releases.
A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning property or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "'n-PIant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance ofltis JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time aiical JPMs, completion within double the estimated time (listed in paragraph D.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph D.2)is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
PLOR258C Rev001 Page 2 of4
B. ~ TOOLS ANO EQUIPMENT
- 1. AT2 -In progress ST-C-095-805-2, Rev. 13, completed through step 6.12.B.
C. REFERENCES
- 1. ST-C-095-B05-2, Rev. 13, "Liquid Radwaste Discharge".
D. TASK STANDARD
- 1. Satisfactory task completion is indicated when section 6.13 has been completed in its entirety.
- 2. Estimated time to complete: 12 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform the necessary steps to set-up the plant in preparation for a Liquid Radwaste discharge. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. Both units are operating at 100% power.
- 2. The Floor Drain Sample Tank (FDST) needs to be discharged.
- 3. Chemistry and Shift Management have completed ST-C-095-B05-2, illiquid Radwaste Discharge" through step 6.12.B.
- 4. Six Circulating Water Pumps are in operation.
- 5. The discharge Canal-To-Intake Pond crosstie gate is closed.
- 6. The PRO review and set-up has not been completed.
G. INITIATING CUE You are the PRO. Complete section 6.13 of ST-C-095-805-2 "Liquid Radwaste Discharge" in preparation for a liquid radwaste discharge.
PLOR258C Rev001 Page 3 of 4
H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO 1 Record actual number of operating P Verifies six Circulating Pumps are Circulating Pumps. operating from Task Conditions/Prerequisite information, record and initial step 6.13.1.
- 2 Set the Hlfrip Setpoint. P Manually adjust the HI Setpoint Pot
~
setting for RIS-0-17-3S0 to::s. 3.81, and record and initial step 6.13.2.
- 3 Set the HI HI Trip Setpoint. P Manually adjust the HI HI Setpoint Pot setting for RIS-0-17-3S0 to::s. 3.84, and record and initial step 6.13.3.
4 Mark step 6.13.4 "N/A" P Step 6.13.4 is reviewed and marked "N/A".
S Review PRO steps. P Visually verify all the PRO steps in section 6.13 are complete, and initial step 6.13.S SAT.
6 Record yoyr name and initials. P Print your name and initials in Section
~ 10.0.
7 Inform Control Room Supervision of P Inform Control Room Supervision of completion of task. completion of section 6.13 of ST-C-095 80S-2 "Liquid Radwaste Discharge".
8 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When Section 6.13 of ST-C-095-805-2 has been completed, terminate the exercise.
PLOR258C Rev001 Page 4 of4
TASK CONDITIONS/PREREQUISITES
- 1. Both units are operating at 100% power.
- 2. The Floor Drain Sample Tank (FDST) needs to be discharged.
- 3. Chemistry and Shift Management have completed ST-C-09S-S0S-2, "Liquid Radwaste Discharge" through step 6.12.S.
- 4. Six Circulating Water Pumps are in operation.
S. ~ The discharge Canal-To-Intake Pond crosstie gate is closed.
- 6. The PRO review and set-up has not been completed.
INITIATING CUE You are the PRO. Complete section 6.13 of ST-C-09S-S0S-2 "Liquid Radwaste Discharge" in preparation for a liquid radwaste discharge.
Exelon Nuclear ST-C-095-805-2
£feach Bottom Rev. 13 Unit 2 & 3 Page 1 of 27 Surveillance Test RLA:rla ST-C-095-805-2 LIQUID RAD~TE DISCHARGE TEST FREQUENCY: Unscheduled (See Section 1.0)
TECH SPEC: 5.5.1 AND ODCMS Sections 4.8.B.1.1, 4.8.B.1.2, 4.8.B.1.3, 4.8.B.3.1, 4.8.B.3.2, Table 4.8.B.1. Func. 1 AND Func. 4,4.8.B.4.3, 4.8.B.4.4, AND 4.8.B.4.5 APPLICABILITY: At all times TANK To Be DISCHARGED: SOURCE: CSAR No: 176-10 Approved By SMgt: N/A / /
Printed Name Time Date Initials INITIAL one of the following Test Results:
A: All
- steps are SATISFACTORY B: One OR More
- steps are UNSATISFACTORY Refer to Section 9.0 for Tech Spec LCO's i i Performed By: Cliem rrecli Current 'Today.
(CT) Printed Name Time Date Initials Reviewed By: / /
(SMgt) Printed Name Time Date Initials Completedd By: / /
(CTR) Printed Name Time Date Initials
. UNSAT Notification:
(N/A IF SAT) SMgt Discretion: Plant Mgr OR Others Notified By:
(N/A IF SAT) 3 IF other portions of the test did NOT function properly, OR other discrepancies were noted, THEN COMPLETE the following:
DESCRIBE discrepancies/actions taken: A/R OR ETT #: - - - - -
Reviewed/Approved CHEM Staff:
Printed Name Time Initials
ST-C-095-805-2 Rev. 13 Page 2 of 27 0 Pl1RPOSE This procedure prescribes normal methods to be used for the discharge of planned batch releases of liquid radioactive waste to the discharge canal. Also provided is the mechanism to verify initial conditions, complete required calculations AND record specifi~d data associated with radioactive liquid effluents.
This procedure satisfies Offsite Dose Calculation Manual (ODCM) surveillance requirements for 4.8.B.1.1, 4.8.B.1.2, 4.8.B.1.3, 4.8.B.3.1, 4.8.B.3.2, Table 4.8.B.l.Func. 1 AND Func. 4, 4.8.B.4.3, 4.8.B.4.4, AND 4.8.B.4.5. This procedure may be TC'ed. However, a thorough review of the UFSAR (for example, Section 9.2, Liquid Radioactive Waste System) must be completed as part of the TC process. WHEN TCing OR revising this document, THEN ensure that the requirements of the procedure, as described in the UFSAR, are satisfied.
0TEST EQUIPMENT None.
~REREQUISITES Initial
~ocument Review
~ ENSURE procedure is current revision.
C.f!:
~ OBTAIN CY-PB-120-401 " Liquid Radioactive
~ Waste" for tank to be released. C.f!:
~ther Prerequisite Activities
~ RECORD the tank to be discharged Source
~ AND CSAR No. in Section 1 of this test's cover sheet. C.f!:
~est Initiation
~ This test has been initiated in accordance
~ with CY-PB-120-401.
~uipment Configuration None.
~eqUired Redundant Safety Related Equipment None.
~pproval to Start Test None.
ST-C-095-805-2 Rev. 13 Page 3 of 27
~CAtl'HONS. LIMJ:TATIONS. AND GENERAL INSTRUCTIONS
~lant Impact Statement j~ This procedure does NOT impact plant availability in
~ any manner AND may be performed in any Reactor Mode.
~recautions None.
~imitations
. ~ IF the discharge Canal-To-Intake pond Cross tie is
~ OPEN, THEN the following alarms shall be clear prior to AND during release:
~arm Panel 204 Window F-4 "OUTER SCREEN
~;~RUCTURE HI HI DIFF WTR LVL"
~larm Panel 304 Window F-4 "OUTER SCREEN
~ ~TRUCTURE HI HI DIFF WTR LVL"
@ IF the discharge Canal-To-Intake pond Crosstie is OPEN, THEN a minimum of three circulating water pumps must be in operation during the release of radioactive liquid to the discharge canal.
IF the release is terminated for lack of dilution flow, THEN only may be restarted WHEN the calculated release conditions are reestablished.
~neral Instructions
, ~ The Chemistry Technician (CT) initiates this test as
~ required by CY-PB-120-401 criteria AND performs all
, CT in ialed steps. The CT forwards this test to Shift Supervisor (SMgt) for review AND approval; completing all SMgt initialed steps. SMgt THEN forwards test to Plant Reactor Operator (PRO). The PRO performs all PRO initial steps AND forwards to Radwaste Operator (RWO). The RWO THEN performs all RWO initialed steps AND forwards this test to SMgt for review of all Operations' responsible steps.
The SMgt places this test in the Chemistry bin in the Main Control Room for retrieval AND review by Chemistry Technician Reviewer (CTR).
ST-C-095-805-2 Rev. 13 Page 4 of 27
~RECADTIONS, LIMITATIONS, AND GENERAL INSTRUCTIONS (Continued)
~ IF any procedure step CANNOT be completed OR
~ produces an unexpected response, THEN STOP the test AND RETURN the equipment to a safe condition AND NOTIFY the RO OR SMgt AND Chemistry Supervision.
~ IF any Black Box is initialed, THEN STOP the test
~ AND RETURN the equipment to a safe condition AND NOTIFY the RO OR SMgt AND Chemistry Supervision.
~ This procedure shall be aborted WHEN it is
~ discovered that a Tank is NOT going to be released.
~ IF procedure is aborted, THEN NOTIFY SMgt AND WRITE "TEST ABORTED" in Section 3 of Cover Page.
@ A I l persons who initial steps in Sections 3.0, 6.0, OR 7.0 are responsible for completing Section 10.0.
~ All applicable
- steps are identified immediately in
~ front of the initials.
~CEPTANCE CRITERIA The following conditions must be met:
Copy of Gamma Isotopic Analysis Report attached to this rocedure.
Tank to be released has been processed through one OR more of these systems: Waste Collector Filter AND Demineralizer, Floor Drain Filter, Fuel Pool Filter Demineralizer, Chemical/Oily Waste Cleanup. (Epicore oil/water emulsion),
Laundry Drain Filter OR Projected Body Dose for Month is less than 0.12 mRem AND Projected Organ Dose for Month is less than 0.40 mRem.
RIS-0-17-350 "Rad Waste Effluent" Rad Monitor operable.
FR-0-20-441 "RWS Low Purity Waste" Flow Recorder/Monitor operable.
FS-0-20-493 "RWS Low Purity Waste" High Flow Trip Set Pot AND associated Flow Control Valve are operable.
~Actual No. of Circ Pumps Providing Dilution is greater than
. ~ OR equal to the Required No. of Circ Pumps Providing Dilution.
~RIS-0-17-350 HI Trip Setpoint is less than OR equal to
~ Required HI Trip CPS.
ST-C-095-805-2 Rev. 13 Page 5 of 27 CCEPTANCE CRITERIA (Continued)
RIS-O-17-350 HI HI Trip Setpoint is less than OR equal to Required HI HI Trip CPS.
~ ~ctual Maximum Release Rate GPM is less than OR equal to the
~~equired Maximum Release Rate value.
~ctual % Setting for Discharge is less than OR equal to the
~~equired Maximum % Setting for Discharge.
Sample retained for Monthly Composite.
Every release Start AND Stop Time has been recorded on the appropriate data chart.
Initial Sat UnSat Steps 6.1 and 6.2 may be performed in any order or concurrently.
~CORD chemistry data obtained in the
~~erformance of CY-PB-120-401, the tank source AND the associated CSAR No. on Data Sheet 1 below. CM-l
~CORD
~~o. on thle tatnhk sourcl~ ANDbl itdstassohciattedCMcSA1R a l 0 er app lea e a a S ee s.
C.~
~--------
ST-C-095-805-2 Rev. 13 Page 6 of 27
~PERFO~CZ STEPS (Continued) Initial Sat Unsat
~he water placed in OBT061 is to be
~n~idered "Processed", THEN an RW-PB-625, Attachment 4, (as directed from RW-PB-591) will be given to Chemistry for attachment to ST-C-095-805-2.
~the water placed in OBT061 is considered
~nprocessedll, THEN an RW-S92, Exhibit 9.1 will be given to Chemistry for attachment to ST-C-095-805-2.
~ the water placed in OBT061 is "Post
~ushn demineralized water, THEN no further documentation will be given to Chemistry for ST-C-095-80S-2, since the contents of the tank will be processed by the Laundry Drain Tank filter.
~dry Drain Tank water that is NOT
~~~essed by the Epicore Water Emulsion System shall be dispositioned in accordance with RW-S92, nTransfer of Unprocessed Waste Water to the nB" Laundry Drain Tank". In this case, the Laundry Drain Tank contents will ther be considered "Unprocessed" water or will be considered "Processed" by the Laundry Drain Filter, as determined by Chemistry/Radwaste Management.
~ ~~tank to be discharged has NOT been processed
~hrough a Radwaste system, as specified in ODCMS 3.8.B.4, THEN CALCULATE AND RECORD Projected Body Dose AND Projected Organ Dose for Month on Data Sheet 1. OTHERWISE, N/A the applicable blocks for this step AND on Data Sheet 1. C.~
(0 DCMS 3. 8 . B . 4 )
~ VERIFY Projected Organ Dose is less than 0.40 mRem.
.!N/}f CT CJ J VERIFY Projected Body Dose is less than 0.12 mRem.
- !N/}f (1'
Cl
ST-C-095-805-2 Rev. 13 Page 7 of 27 DATA SHEET 1 TANK TO BE DISCHARGED SOURCE: pq)sq' CSAR No. 176 - 10 REASON FOR DISCHARGE Water ImJetr.tory Control liiali Sil'ta RECIRCULATI9N TIME (minutes) 45
- ANALYSIS ANALYSIS LIMIT FOR REMARKS RESULT DISCHARGE UCTIVITY 0.91 uS/cm < 2500 uS/cm [V] ~
pH :J{q{ 4.0 - 10.0 [A] ~
TEMPERATURE 24.5 C AS READl ,,~
TURBIDITY 0.861 NTU < 30 NTU [V] ,,~
~
GAMMA SCAN TOTAL ACTIVITY 4.85 n 7 J,lCi/mL <1 E-4 ,uCi/mL [F)
ESTIMATED BODY DOSE 0 mRem 0.05 mRem [V] ~
ESTIMATED ORGAN DOSE 0 mRem 0.15 mRem [V) ~
THE FOLLOWING IS REQUIRED FOR RELEASE OF UNPROCESSED TANKS ONLY (ODCM ACCEPTANCE CRITERIA)
PROJECTED BODY DOSE FOR MONTH !}fIji mRem 0.12 mRem [D] ~
PROJECTED ORGAN DOSE FOR MONTH
!}fIji mRem 0.40 mRem [D) ~
[ FJ IF THE ACTIVITY IS LESS THAN OR EQUAL TO 1.0E-3, THEN A VARIANCE MAY BE GRANTED, OTHERWISE IF THE ACTIVITY IS GREATER THAN 1.0E-3, THEN A VARIANCE MAY NOT BE GRANTED UNLESS A PROJECTED DOSE IS CALCULATED, COMPARED TO THE REGULATORY LIMITS, AND COMMUNICATED TO THE CONTROL ROOM.
[V) AN ADMINISTRATIVE LIMIT FOR WHICH A VARIANCE MAY BE OBTAINED FROM CHEMISTRY SUPERVISION OR ON-CALL INDIVIDUAL.
CAl CORRECTION OF pH FOR RELEASES MAY BE MADE BY DILUTION. pH IS NOT REQUIRED AND pH LIMIT DOES NOT APPLY IF CONDUCTIVITY OF TANK IS LESS THAN 2.5 ~S/cm.
[DJ THIS LIMIT APPLIES ONLY TO RELEASES WHEN THE SAMPLED TANK'S CONTENTS HAVE NOT BEEN PROCESSED THROUGH AT LEAST ONE RADWASTE SUBSYSTEM OR EQUIVALENT PE~ ODCMS BASES B 3.8.
(See CY-PB-120-401) 1 Required on tanks to be released WHEN the conductivity is greater than equal to 2.5 pS/cm
ST-C-095-805-2 Rev. 13 Page 8 of 27 PERFORMANCE STEPS (Continued) Initial Sat UnSat
~~IFY tank sample results recorded on Data
- ~ ~heet 1 are Satisfactory for release to discharge canal per CY-PB-120-401.
c.er.
CT ariances may NOT be granted for any projected dose limit which has been exceeded.
IF a Variance is Required AND NOT granted, THEN this test should be aborted.
~F any chemical analysis exceeds its Limit
~ FO'r Discharge, THEN RECORD "Variance Required" in remarks section of Data Sheet 1 AND obtain approval for Discharge with a "Variance". OTHERWISE, N/A this Step. CM-2 IF a "Variance" was required for discharge, THEN CONTACT Chemistry Supervision OR on-call individual for Variance AND RECORD Name of Chemistry Supervisor OR responsible Staff person granting "Variance(s)"
below:
(IF a Variance is NOT required, THEN N/A these spaces for this step.)
- N/JI / /
- N/JI Time Date
~TTACH a copy of the Gamma Isotopic Analysis Report to this test. (ODCMS 4.8.B.1.1, 4,8.B.1.2, 4.8.B.1.3, Table 4.8.B.1 Func. 1 & 4) c.er.
CT CJ
ST-C-095-805-2 Rev. 13 Page 9 of 27
~PBRFORMANCE STEPS (Continued) Initial Sat UnSat
~RIFY a portion of sample (approx 1 Liter) c.tI.
~ ;etained for Monthly composite.
Chemistry Management approved computer programs may be used, AND is the preferred method, to perform the worker verification for the calculation of the values for the alarm setpoints (Section 6.8) AND the radwaste discharge pump high AND low flow setpoints (Section 6.10).
~BTAIN the Background Count Rate for RIS-0-17-350 in counts per second (CPS) from the PRO AND CALCULATE RIS 0-17-350 uRad Waste Effluent" Monitor HI Trip AND HI HI Trip Settings using formulas below. (Calculations are in accordance with ODCM.)
~ CALCULATE Monitor Net CPS.
0.532 X 6 3.19
--::-:W=-e"""'l-,;'l--::C::--o-u-n-t:-e-r Monitor Net CPS net cpm/mL c.tI.
o CALCULATE Gross CPS 50 + 3.19 = 53.19 CT R I S 1 7 - 3 5 0 CPS -;CM:-o-n-ri-;-to-r---;C}-;-le-;-t--;::;-C~Pso; Background Count Rate c.r;(.
~ DETBRMrNE log CPS from Gross CPS.
log (53.19 ) 1.73 c.r;(.
ST-C-095-S05-2 Rev. 13 Page 10 of 27 PERFORMANCE STEPS (Continued) Initial e CALCULATE Adjusted Log CPS Sat UnSat
~ CALCULATE RIS-0-17-350 HI Trip
~ Setpoint AND RECORD results as Required RIS-0-17-350 HI Trip Value on Data Sheet 3. (ODCMS 3.S.B.3.C)
- 1. 44 + 2.37 3.81
-=:--::"..--,--=---:---:--;
Adjustment Log CPS Hi Trip Setting C.rt.
CALCULATE RIS-O-17-350 HI HI Trip Setpoint AND RECORD results as Required RIS-O-17-350 HI HI Trip Value on Data Sheet 3. (ODCMS 3.S.B.3.C)
- 1. 47 + 2.37 3.84 Adjustment Log CPS Hi Hi Trip Setting C.rt.
Chemistry Management ~....... y programs may be used, AND is the preferred method, to perform the worker verification for the calculation of the values for the alarm setpoints (Section 6.8) AND the radwaste discharge pump high AND low flow set points (Section 6.10l.
PERFORM a Worker Verification of calculations made in Section 6.8.
Any discrepancies between the results of section 6.8 AND the worker verification shall be resolved prior to the release of the affected tank. O.rt.
ST-C-095-S05-2 Rev. 13 Page 11 of 27 ERFORMANCE STEPS (Continued) Initial Sat UnSat
~TCULATE the Maximum Allowed Tank Release Rate
~follows: (ODCMS 4.S.B.1.1)
~ OBTAIN position of Discharge Canal
~ To-Intake crosstie gate from the PRO AND CIRCLE the position (OPEN OR CLOSED) in Section 1.0 of Data Sheet 2.
err
- "J..
~F Crosstie Gate is CLOSED, THEN
~PERFORM the following to complete Data Sheet 2 AND Data Sheet 3, OTHERWISE, NIA the spaces in this step.
~ORD "N/A" in spaces of
~ection 2.0 of Data Sheet 2. C.fJ'.
~TAIN the Actual Number of Circ Pumps Operating from the PRO AND RECORD this number in Sections 3.0 AND 5.0 of Data Sheet 2 AND ENTER "1" for the "Required No. of Circ Pumps Operating" on Data Sheet 3. C.fJ'.
~F the Crosstie Gate is OPEN,
~THmN PERFORM the following to complete Data Sheet 2 AND Data Sheet 3, OTHERWISE, NIA the spaces in this step.
~BTAIN the River-To-Intake
~ ~ond Differential Level Readings from the PRO AND RECORD in Section 2.0 of Data Sheet 2. N/)f.
ST-C-095-805-2 Rev. 13 Page 12 of 27
~ERFO~CE STEPS (Continued) Initial Sat UnSat
~BTAIN the Actual Number of
~Circ Pumps Operating from the PRO AND RECORD in Section 3.0 of Data Sheet 2. Also RECORD "3" for the "Required No. of Circ. Pumps Operating" on Data Sheet 3. (A minimum of three circ pumps must be operating. )
~Sing Section 4.0 of Data
~~heet 2, DETERMINE the No. Of eire. Pumps Providing Dilution AND RECORD this value in Section 5.0. !Nj}f.
ST-C-095-805-2 Rev. 13 Page 13 of 27 DATA SHEET 2 CALCULATION OF NUMBER OF CIRC PUMPS PROVIDING DILUTION (PRE-RELEASE DATA)
TANK TO BE DISCHARGE SOURCE: p<DSrr CSAR No. 176 10 1.0 Discharge Canal-To-Intake POSITION: OPEN OR ~LOS~
crosstie gate (Circle current p ~;ri I.
Traveling Screens Outer Screens ~L 2.0 RIVER-TO-INTAKE POND < At Control Room >
DIFFERENTIAL LEVEL READINGS DLI-2207 @ DLI-3207 @
Console 20C007A Console 30C007A
- N/)I" H20 :N/)I "H2 O 6
3.0 NUMBER OF CIRC PUMPS OPERATING 4.0 USrNG THE CHART BELOW DETERMrNE THE NUMBER OF PUMPS PROVIDING DILUTION FOR THIS
- RELEASE. TAKE THE ACTUAL NUMBER OF ClRe PUMPS OPERATrNG FROM SECTION 3.0 OF THIS DATA SHEET, READ DOWN THE COLUMN TO THE HIGHEST DIFFERENTIAL LEVEL RECORDED IN SECTION 2.0 OF THIS DATA SHEET, MOVE ACROSS THE ROW AND FIND THE NUMBER OF CIRC PUMPS PROVIDING DILUTION. IF EITHER DLI-2207 OR DLI-3207 ARE INOPERABLE, THEN TAKE THE NUMBER OF CIRC PUMPS OPERATING FROM SECTION 3.0 AND SDBTRACT 2.
ACTUAL NUMBER OF CIRC PUMPS OPERATING No. OF CIRC PUMPS PROVIDING DILUTION 3 4 5 6
~ LEVEL " --- --- --- 0 - 1.8 5 WATER
--- --- 0 - 2.4 1.8 - 10 4
--- 0 - 2.7 2.4 - 10 --- 3 0 - 3.1 2.7 - 10 --- --- 2
- 3.1 - 10 --- --- --- 1 5.0 No. OF CIRC PUMPS PROVIDING DILUTION 6
ST-C-095-805-2 Rev. 13 Page 14 of 27 PERFORMANCE STEPS (Continued) Initial Sat UnSat
~OBTAIN the Max Discharge Flow (gpm) from
~ ~he Gamma Isotopic Analysis Report AND ENTER for maximum rate to discharge canal on Data Sheet 4. C.rr.
~CULATE the High AND Low Flow Set Points as
~directed below: (Calculations are in accordance wi th the ODCM.)
IF the calculated value is greater than 100%, THEN RECORD 100% for the setting values.
~ DETERNcrNE Maximum Allowable discharge
~ settings as follows AND RECORD as "High Flow" AND "Low Flow" in applicable spaces on Data Sheet 4. (ODCMS 3.8.B.3c)
~i9h Flow Discharge CT
~ow Flow Discharge 1.2 X Max Release Rate 300 GPM = 100 %
0.15 Setting C.t!
ST-C-095-805-2 Rev. 13 Page 15 of 27
~~CE STEPS (Continued) Initial Sat UnSat Chemistry Management approved computer programs may be used, AND is the preferred method, to perform the worker verification for the calculation of the values for the alarm setpoints (Section 6.8) AND the radwaste discharge pump high AND low flow set points (Section 6.10).
~ PERFORM a Worker Verification of
~ calculations made in Section 6.10. Any discrepancies between the results of section 6.10 AND the worker veri cation shall be resolved prior to the release of the affected tanks. D.q:
~REVIEW all CT responsible steps in Sections 6.1 through 6.10 for completeness, RECORD name AND initials in Section 10.0, Participants Record, SIGN cover sheet of this test at "Performed By:"
AND FORWARD this procedure to SMgt. c.q:
~gt Review AND Signature r ~ VERIFY all CT steps to this point have
~ been Init led AND completed Satisfactorily. S.:M.
SMgt
~ VERIFY, using an appropriate calculating
~ device, the calculations performed in Section 6.8 AND Section 6.10 by the CT are correct AND that the correct results have been recorded on Data Sheet 3 AND Data Sheet 4. S.:M.
SMgt
~ VERIFY that the sample tank named on the
~ cover sheet of this test is intended to be released. S.:M.
SMgt
~ GRANT Permission to operate HV-0-20C-144
~ "Waste Sample PP Disch To Pond" AND HV 0-20C-146 "Outer Block Valve for Wa~t8 Sample Tank Disch to River". OTHER N/A this step. S.9t1._
'Mgt
ST-C-095-805-2 Rev. 13 Page 16 of 27 6.0 PERFORMANCE STEPS (Continued) Initial Sat UnSat
~ VERIFY RIS-O-17-350 "Rad Waste
~ Effluent" Rad Monitor is operable.
(ODCMS 3.8.B.3a)
- S.9(/..
SMgt CI
~ VERIFY FS-0-20-493 "RWS Low Purity
~ Waste" High Flow Trip Set Pot AND associated Flow Control Valve are operable (This means that there are NO ETTs OR AIRs against this equipment).
(ODCMS 3.8.B.3c)
- S.9(/..
SMgt CI
~ RECORD name AND initials in Section 10.0, Participants Record. S.9(/..
SMgt
~ FORWARD this test to the PRO. S.9(/..
SMgt DATA SHEET 3 TANK TO BE
. '.~_**SOURCE: P(})S'T CSAR No. 176-10 PLANT SYSTEM REQUIRED PARAMETERS FOR LIQUID RADWASTE RELEASE REQUIRED VALUE Required No. of Circ. Pumps Operating 1 PUMPS Required RIS-0-17-350 HI Trip Setpoint A
- 3.81 SETTING Required RIS-0-17-350 HI HI Trip Setpoint POT 3.84 SETTING
ST-C-095-805-2 Rev. 13 Page 17 of 27 6.0 PERFORMANCE STEPS (Continued) Initial Sat UnSat 6.13 PRO Review AND set-up of Plant in Preparation For Discharge 6.13.1 RECORD the Actual No. of Circ. Pumps Operating below AND VERIFY the Actual No. of Circ. Pumps Operating is greater than OR equal to the required No. of Circ. Pumps as recorded on Data Sheet 3.
(ODCMS 4.8.B.1.1)
Actual No. of Circ. Pumps Operating
- --CJ PRO 6.13.2 SET RIS-0-17-350 HI Trip Setpoint to less than OR equal to Required value from Data Sheet 3 AND RECORD Actual Setpoint POT value below: (ODCMS 3.8.B.3.c)
Actual HI Trip Pot Setting PRO CJ 6.13.3 SET RIS-O-17-350 HI HI Trip Setpoint to less than OR equal to Required value AND RECORD the Actual HI HI Setpoint Pot value below: (ODCMS 3.8.B.3.c)
Actual HI HI Trip Pot Setting PRO CJ 6.13.4 IF the discharge Canal-To-Intake Pond crosstie gate is OPEN, THEN VERIFY the following. OTHERWISE, N/A the spaces in this step.
- 1. Alarm Panel 204 Window F-4 "OUTER SCREEN STRUCTURE HI HI DIFF WTR LVL" is CLEAR.
PRO
- 2. Alarm Panel 304 Window F-4 "OUTER SCREEN STRUCTURE HI HI DIFF WTR LVL" is CLEAR.
ST-C-095-805-2 Rev. 13 Page 18 27 6.0 PERFORMANCE STEPS (Continued) Initial Sat UnSat 6.13.5 REVIEW all PRO steps, to this point, in Section 6.13 for completeness.
6.13.6 RECORD name AND initials in Section 10.0, Participants Record, AND FORWARD this test to the Radwaste Operator (RWO) .
DATA SHEET 4 TANK TO BE DISCHARGED SOURCE: p(])Srr CSAR No. 176-10 RADWASTE SYSTEM REQUIRED PARAMETERS PRIOR TO LIQUID RADWASTE RELEASE REQUIRED VALUE FS-0-20-493 "RWS Low Purity Waste" High Flow Trip Set Pot 100 %
FS-O 0-493 "RWS Low Purity Waste" Low Flow Trip Set Pot 4
100 %
MAXIMUM Release Rate to Discharge Canal 300 GPM 6.14 RWO ESTABLISHMENT OF RADWASTE DISCHARGE (At Radwaste Control Room Panel OOC077) 6.14.1 VERIFY tank to be discharged, as written in Section 1 of the coversheet, is the same tank intended to be released.
RWO Cl 6.14.2 VERIFY tank to be discharged has been processed through one OR more of these systems: Waste Collector Filter AND Demineralizer, Floor Drain Filter, Fuel Pool Fi Demineralizer, AND Chemical/Oily Waste Cleanup (EPICORE Oil/Water Emulsion), Laundry Drain Filter OR Projected Body Dose AND Projected Organ Dose for the Month have been recorded on Data Sheet 1.
(ODCMS 3.8.B.4)
- -Cl
ST-C-095-805-2 Rev. 13 Page 19 of 27 6.0 PERFORMANCE STEPS (Continued) Initial Sat UnSat RWO 6.14.3 SET FS-O-20-493 "RWS Low Purity Waste" High Flow Trip Set Pot to less than OR equal to Required Maximum % Setting for High Flow Discharge as found on Data Sheet 4 above, AND RECORD the Actual Setting below:
Actual FS-O-20-493 High Flow Trip Set Pot Setting RWO Cl 6.~4.4 SET FS-0-20 493 "RWS Low Purity Waste" Low Flow Trip Set Pot to less than OR equal to Required Maximum % Setting for Low Flow Discharge, as found on Data Sheet 4 above, AND RECORD the Actual Setting below:
Actual FS-O-20-493 Low Flow Trip Set Pot Setting RWO Cl 6.14.5 RECORD RR-O-17-337 OR RIS-O-17-350 before Discharge CPS below:
CPS RWO 6.14.6 COMMENCE release of the sampled AND analyzed tank as follows:
6.14.6.1 If Sampled and analyzed tank was the Floor Drain Sample Tank, perform SO 20A.1.E and perform a concurrent verification that AO-O-20-227, "Floor Drain Sample Pumps Disch Valve to River" is opened in step 4.20. Otherwise, N/A this step.
ST-C-095-805-2 Rev. 13 Page 20 of 27 6.0 PERFORMANCE STEPS (Continued) Initial Sat UnSat 6.14.6.2 If Sampled and analyzed tank was the 'A' Waste Sample Tank, perform SO 20C.7.N and perform a concurrent verification RWO that AO-0-20-142A, "Discharge Valve for 'A' Waste Sample Pump" is opened in step 4.20. Otherwise, N/A this step.
6.14.6.3 If Sampled and analyzed tank was the 'B' Waste Sample Tank, perform SO 20C.7.N and perform a concurrent verification RWO that AO-O-20-142B, "Discharge Valve for
'B' Waste Sample Pump" in step 4.20. Otherwise, N/A this step.
6.14.6.4 If Sampled and analyzed tank was 'B' Laundry Ora Tank, perform SO 20B.7.A and perform a concurrent verification that AO-O 0-191, "Laundry Dr Tk Pumps Disch to Laundry Drain Filter" is opened in step 4.3.11.
Otherwise, N/A this step .
ST-C-095-805-2 Rev. 13 Page 21 of 27 6.0 PERFORMANCE STEPS (Continued) Initial Sat UnSat NOTE
- 1. Portions of the following Section must be completed during the release.
- 2. IF the release is terminated early for lack of dilution flow, THEN it may only be restarted WHEN the original release conditions are re-established.
- 3. The following Steps may be repeated, as applicable, for each release start AND stop time.
- 4. The RIS-O 17-350 Trip Setpoints recorded on Data Sheet 3 correspond to 125% (HI) AND 135% (HI-HI) of the radiation monitor reading expected during the release. Typically, any appreciable change in the radiation monitor readings during the release is unusual AND should be reported to SMgt.
6.14.7 RECORD each release Start Time, Start Date, Stop Time, Stop Date, Start Tank
%, Stop Tank %, the FR-O-20-441 Flow (GPM) reading AND the RR-O-17-337 (CPS)
OR RIS-O-17-350 (CPS) as required in chart below: (N/A spaces NOT used.)
(ODCMS 4.8.B.2.1, 4.8.B.3.1, 4.8.B.3.2)
TIME DATE TANK LEVEL FR-O-20-441 RR-O-17-337 OR RIS-O-17-350 START %
GPM CPS
'STOP %
RWO CJ
ST-C-095-805 Rev. 13 Page 22 of 27
<<.0 PERFORMANCE STEPS (Continued) Initial Sat UnSat TIME DATE TANK LEVEL FR-O-20-441 RR-O-17-337 OR RIS-O-17 350 START %
- ___ I RWO TIME DATE TANK LEVEL FR-O-20-441 RR-O-17-337 OR RIS-O-17-350
,START
. 90 GPM CPS P %
- 1 I RWO 6.14.8 RECORD below the actual maximum Re se Rate GPM value from FR-O-20-441 observed during the release AND VERIFY the actual Release Rate is less than OR equal to the value recorded on Data Sheet 4.
(ODCMS 3.B.B.3.C)
Actual Maximum Release Rate FR-O-20-441 GPM
- RWO CJ 6.14.9 IF this release is NOT immediately followed by another discharge, THEN PERFORM the following post release steps. OTHERWiSE, N/A these Steps.
- 1. RECORD RR-O-17-337 recorder CPS Reading BEFORE FLUSH.
_ _ _ CPS
ST-C-095-805-2 Rev. 13 Page 23 of 27 6.0 PERFORMANCE STEPS (Continued) Initial Sat UnSat
- 2. PERFORM SO 20C.5.B "Liquid Radwaste Discharge Radiation Monitor Flushing."
RWO
- 3. RECORD RR-0-17-337 recorder CPS Reading after flush.
- - - CPS RWO 6.14.10 IF a Waste Sample Tank was Released, THEN PERFORM the following. OTHERWISE N/A these Steps:
- 1. CLOSE HV-0-20C-144 "Waste Sample PP DISCH To Pond".
- 2. CLOSE HV-0-20C-146 "Outer Block Valve For Waste Sample Tank Disch To River".
RWO 6.14.11 REVIEW all RWO Steps, to this step, in Section 6.14 for accuracy AND completeness.
RWO 6.14.12 RECORD name AND initials in Section 10.0, Participants Record, AND FORWARD this test to SMgt for review.
6.15 SMgt REVIEW OF OPERATIONS' PERFORMANCE AFTER DISCHARGE 6.15.1 REVIEW this test to this point for completeness paying attention to the Steps requiring PRO AND RWO data entry AND initials.
SMgt 6.15.2 SIGN coversheet of this test at "Reviewed By:ff SMgt 6.15.3 PLACE this test in the Chemistry bin located in the Main Control Room.
ST-C-095-805-2 Rev. 13 Page 24 of 27 e
6.0 PERFORMANCE STEPS (Continued) Initial Sat UnSat 6.16 CHEMISTRY TECHNICIAN REVIEWER (CTR) COMPLETE THE TEST.
6.16.1 VERIFY sample Retained (approximately 1 Liter) for Monthly Radwaste Composite per ST-C-095-833-2, "P-32, FE-55, SR-89 and SR-90, and Tritium Analysis in Liquid Radwaste". (OOCMS Table 4.8.1)
CTR CJ NOTE AWST or BWST volume is 25488 gallons. FOST volume is 19844 gallons. BLOT volume is 1072 gallons.
6.16.2 USE data from this release, as applicable, to update OpenEMS records in the computer.
6.16.3 ENSURE all data for the applicable waste tank has been entered into the Chemistry Oata Management System (OMS).
7.0 PROCEDURE COMPLETION Initial e 7.1 Independent Verification None.
7.2 Records Completion 7.2.1 REVIEW all Sections of this test AND VERIFY these are complete.
CTR 7.2.2 VERIFY copy of the Gamma Isotopic Analysis Report attached to this test.
CTR 7.2.3 COMPLETE Section 2 of this test's coversheet by signing at "Completed By:" (AND Section 3 IF applicable)
AND FORWARD this test to Chemistry Supervision OR Staff for review.
ST-C-095-805-2 Rev. 13 Page 25 of 27
8.0 REFERENCES
8.1 Governing 8.1.1 ODCMS 3.8.B.3 8.1. 2 ODCMS 3.8.B.4 8.1. 3 ODCMS 4.8.B.1.1
- 8.1. 4 ODCMS 4.8.B.1.2 8.1. 5 ODCMS 4.8.B.1.3 8.1. 6 ODCMS 4.8.B.3.1 8.1. 7 ODCMS 4.8.B.3.2 8.1. 8 ODCMS Table 4.8.B.1 8.1. 9 ODCMS 4.8.B.4.3 8.1.10 ODCMS 4.2.B.4.4 8.1.11 ODCMS 4.8.B.4.5 8.1.12 ODCMS Bases B 3.8 8.1. 13 CM-1, Licensed Event Report 2-91-036 8.1.14 CM-2, NRC Inspection Report Doc No. 76070103 8.2 Interfacing 8.2.1 PBAPS Offsite Dose Calculation Manual (ODCM) 8.2.2 CY-PB-120-401, Liquid Radioactive Waste 8.2.3 ST-C-095-833-2, P-32, FE-55, SR-89 and 90, and Tritium Analysis in Liquid Radwaste 8.2.4 SO 20A.l.E, Floor Drain Sample Tank Release to the Conowingo Pond 8.2.5 SO 20C.7.N, Waste Sample Tank Release to Conowingo Pond 8.2.6 SO 20B.7.A Laundry Drain Tank Release to Conowingo Pond 8.2.7 RW-PB-591, Transfer of Processed Waste Water to the "B" Laundry Drain Tank 8.2.8 RW-PB-592, Transfer of Unprocessed Waste Water to the "B" Laundry Drain Tank
ST-C-095-805-2 Rev. 13 Page 26 of 27
8.0 REFERENCES
(Continued) 8.2.9 SO 20C.5.B, Liquid Radwaste Discharge Radiation Monitor Flushing 8.3 Developmental 8.3.1 CH-600, Determination of Gamma Isotopic Activity with the Canberra Gamma Spectrometers 8.3.2 10 CFR 20 Appendix B, Table 2, Column 2 8.3.3 10 CFR 50 8.3.4 LS-AA-I04, "Exelon 50.59 Review Process" 8.3.5 NPDES Permit No. PAOO09733 8.3.6 UFSAR Section 9.2.4.2.4 8.3.7 UFSAR Section 9.2.4.3 8.3.8 UFSAR Section 9.2.5 8.3.9 UFSAR Section 9.2.7 8.3.10 Prints E-540-55, Sht.l, Console 20C007A Condensate Enhancement Arrangement M-370, Shts. 1, 2, & 3, Radwaste Process & Disposal System-Liquid M-371, Sht 5, Radwaste Process and Disposal-Solid 9.0 ODCMS LIMITING CONDITIONS FOR OPERATION (LCOs)
Section 3.8.B
ST-C-095-805-2 Rev. 13 Page 27 of 27 10.0 PARTICIPANTS RECORD Printed Name Initials CFiem q'ecli C.rt.
Otlier q'ecli O.rt.
Sliift fManaoer S.fM.
I I
EXELON NUCLEAR Nuclear Generation Group OJTfTPE MATERIAL COVERSHEET I Peach Bottom I DI Limerick I DI Common I
~ JPM D QUALIFICATION MANUAL O"ITMODULE LICENSED OPERATOR TRAINING PLOR-259C LICENSED OPERATOR REQUALIFICATION 002 M. J. Kelly jav Review and Evaluate Reactor Coolant Chemistry Limits APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _----:'_ _ _.,_ __
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE ID#: COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMSCODE:
LMS ENTRY:
Signatu re/Date PLOR259C -Rev002 Page 1 of6
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POS'ITION TITLE: Senior Reactor Operator TASK-JPM DESIGNATOR: 34431004021 PLOR-259C KIA: 2.1.34 SRO: 3.5 TASK DESCRIPTION: Knowledge of primary and secondary plant chemistry limits A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. jpM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph D.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
PLOR259C Rev002 Page 2 ot6
B. TOOLS AND EQUIPMENT
- 1. CH-10 "Chemistry Goals"
- Provide candidate blank copy of procedure
- Fill out four separate CH-10-1 Chemistry Recommendation Forms using Attachment 2 of this JPM as a reference. One form for reactor water, the other three are for A, B, and C condensate pump discharge.
- 2. ON-126 "High Condensate Conductivity" (give access to if requested)
C. REFERENCES
,1. CH-10, Rev. 16, "Chemistry Goals"
- 2. ON-126, Rev. 3, "High Condensate Conductivity"
- 1. Satisfactory task completion is indicated when ON-126 "High Condensate Conductivity" reactor coolant chemistry actions and Technical Requirements Manual (TRM) Action Levels are determined in response to a condenser tube leak.
- 2. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE
- When given the initiating cue, perform necessary steps to determine immediate plant impact and compensatory measures, if any, for identified system chemistry limits using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. Unit 2 has been at 100% power for 160 days.
- 2. The Hydrogen Water Chemistry System is in service.
- 3. Chemistry has delivered four CH-10-1 Chemistry Recommendation Forms related to Unit 2 condensate conductivity and Reactor Water chloride concentration.
- 5. All the samples have been verified.
PLOR259C Rev002 Page 3 ef6
G. INITIATING CUE The Shift Manager directs you to determine what immediate plant and/or Technical SpecificationlTRM/ODCM actions, if any, exist for the above conditions.
PLOR259C Rev002 Page 4 of6
H. PERFORMANCE CHECKLIST STEP -
NO' STEP ACT STANDARD
- NOTE TO EVALUATOR****
Provide all four CH-10-1 forms to the Examinee at the start of the JPM.
- NOTE TO EVALUATOR****
The following steps can be performed in any order.
1 Review the four CH-1 0-1 Chemistry P Review CH-10-1 Chemistry Recommendation Forms for Unit 2. Recommendation Forms.
Review CH-1 0 "Chemistry Goals".
2 Enter ON-126 "High Condensate P Recognize that condensate pump Conductivity" . discharge conductivity> 0.4 IJS/cm is a symptom for entry into ON-126.
- 3 Determine that a plant shutdown per GP- P Recognize the chemistry change as a 3 "Normal Plant Shutdown" is required. severe conductivity intrusion (condenser tube leak) and ON-126 directs a plant shutdown using GP-3.
- 4 Determine that the 2A condenser P Determines that ON-126, step 2.4, directs waterbox needs to be removed from isolation of the source of the high service. conductivity. Using the CH-10-1 Chemistry Recommendation Forms the examinee determines that conductivity is high on the discharge of the 2C
- condensate pump which is tied to the 2A waterbox.
PLOR259C Rev002 Page 5 of6
STEP NO STEP ACT STANDARD
- 5 Verify, immediately, by administrative P Recognize that Reactor Coolant System methods that Reactor Coolant System chloride concentration is > 0.2 ppm chloride concentration has not been> 0.2 (actual is 0.22 ppm) limit in TRM Table ppm for> 2 weeks in the last calendar 3.9-1, therefore, TRM 3.9.B applies.
year.
TRM 3.9.B applies. Verify that Reactor (Cue: if asked to assist with Coolant System chloride concentration administrative check of chloride has not been> 0.2 ppm for> 2 weeks in
. concentration, reply as the Chemistry the last calendar year.
Manager and report that chloride concentration has been < 0.2 ppm for the last calendar year.
6 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simulate I. "TERMINATING CUE When the determination of what immediate plant and/or regulatory actions, if any, exist, the evaluator will then terminate the exercise.
PLOR259C Rev002 Page 6 at6
TASK CONDITIONS/PREREQUISITES
- 1. Unit 2 has been at 100% power for 160 days.
- 2. The Hydrogen Water Chemistry System is in service.
- 3. Chemistry has delivered four CH-10-1 Chemistry Recommendation Forms related to Unit 2 condensate conductivity and reactor water chloride concentration.
- 5. All the samples have been verified.
INITIATING CUE The Shift Manager directs you to determine what immediate plant and/or Technical SpecificationlTRM/ODCM actions, if any, exist for the above conditions.
CH-10, Rev. 16 Page 11 of 17 ATTACHMENT CH-10-1 ATTACHMENT CH-10-1 EXAMPLE ONLY CHEMISTRY RECOMMENDATION (CR)
CR #3659-08 FROM: CHEMISTRY TO: SHIFT SUPERVISOR
SUBJECT:
CHEMISTRY RECOMMENDATION SECTION A ** COMPLETED BY SHIFT CHEMIST **
~
DATE/TIME SYSTEM PARAMETER LIMITS VALUE FOUND To-da-y / Unit 2 2A Condensate Pump 0.4 0.065 Now Condensate Discharge Conductivity llS/cm ll S /cm IS THIS CR A FOLLOW-UP TO A VERBAL NOTIFICATION? YES ~
IF YES, DATE/TIME AND PERSON NOTIFIED. N/A DATE / TIME N/A PERSON NOTIFIED CORRECTIVE ACTION REQUIRED: Confirm, investigate, and determine corrective actions, if any.
SECTION B ** COMPLETED BY SHIFT OPERATIONS PERSONNEL **
THE FOLLOWING CORRECTIVE ACTION WAS TAKEN:
DATE TIME CORRECTIVE ACTION TAKEN:
SHIFT OPERATOR VERBALLY NOTIFY CHEMISTRY AFTER CORRECTIVE ACTION IS COMPLETED PERSON NOTIFIED: ________________________ DATE/TIME____________________
- RETURN THIS SHEET TO CHEMISTRY *****
CHEMISTRY REVIEW: ____________________________________________________
DATE
CH-I0, Rev. 16 Page 11 of 17 ATTACHMENT CH-I0-l EXAMPLE ONLY CHEMISTRY RECOMMENDATION (CR)
CR #3660-08 FROM: CHEMISTRY TO:
- SHIFT SUPERVISOR
SUBJECT:
CHEMISTRY RECOMMENDATION SECTION A ** COMPLETED BY SHIFT CHEMIST **
r-~~;~/~~~~T--;~-~~--I--;~~~;;:~;------F~~~-;~-r~~~~~l r-*~~*=*~*=*; ****;*************t**~~i*~*****2************************t**2*;*****~~~d;~*~~*~;*****~;*************************. *t***o..~***~*****************************T***o**~***O*65. * * * * *. ****1 I: Now I Condensate I Discharge Conductivity :
- ~
I pS/cm ; I pS/cm :
IS THIS CR A FOLLOW-UP TO A VERBAL NOTIFICATION? YES ~
IF YES, DATE/TIME AND PERSON NOTIFIED. N/A DATE / TIME N/A PERSON NOTIFIED CORRECTIVE ACTION REQUIRED: Confir.m, investigate, and deter.mine corrective actions, if any.
SECTION B ** COMPLETED BY SHIFT OPERATIONS PERSONNEL **
THE FOLLOWING CORRECTIVE ACTION WAS TAKEN:
DATE / TIME CORRECTIVE ACTION TAKEN:
SHIFT OPERATOR VERBALLY NOTIFY CHEMISTRY AFTER CORRECTIVE ACTION IS COMPLETED PERSON NOTIFIED: - - - - - - - - - - - - - - - - - - - - - - - - DATE/TIME- - - - - - - - - - - - - - - - - - - - -
- RETURN THIS SHEET TO CHEMISTRY *****
CHEMISTRY REVIEW: ______________________________________________________
DATE
CH-I0, Rev. 16 Page 11 of 17 EXAMPLE ONLY CHEMISTRY RECOMMENDATION (CR)
CR #3661-08 FROM: CHEMISTRY TO: SHIFT SUPERVISOR
SUBJECT:
CHEMISTRY RECOMMENDATION SECTION A ** COMPLETED BY SHIFT CHEMIST **
DATE/TIME SYSTEM PARAMETER LIMITS VALUE FOUND To-da-y / Unit 2 2C Condensate Pump 0.4 2.6 Now Condensate Discharge Conductivity liS/em liS/em IS THIS CR A FOLLOW-UP TO A VERBAL NOTIFICATION? YES ~
IF YES, DATE/TIME AND PERSON NOTIFIED. N/A DATE / TIME N/A PERSON NOTIFIED CORRECTIVE ACTION REQUIRED: Confirm, investigate, and determine corrective actions, if any.
SECTION B ** COMPLETED BY SHIFT OPERATIONS PERSONNEL **
THE FOLLOWING CORRECTIVE ACTION WAS TAKEN:
DATE / TIME CORRECTIVE ACTION TAKEN:
SHIFT OPERATOR VERBALLY NOTIFY CHEMISTRY AFTER CORRECTIVE ACTION IS COMPLETED PERSON NOTIFIED:
DATE/TIME---------------------
- RETURN THIS SHEET TO CHEMISTRY *****
CHEMISTRY REVIEij: ____________________________________________________
DATE
CH-I0, Rev. 16 Page 11 of 17 ATTACHMENT CH-IO-l EXAMPLE ONLY CHEMISTRY RECOMMENDATION (CR)
CR #3662-08 FROM: CHEMISTRY TO: SHIFT SUPERVISOR
SUBJECT:
CHEMISTRY RECOMMENDATION SECTION A ** COMPLETED BY SHIFT CHEMIST **
DATE/TIME SYSTEM PARAMETER LIMITS VALUE FOUND To-da-y / Unit 2 Chlorides <
- 0.2 ppm 0.22 ppm Now Reactor Coolant Conductivity < 1.0 llS/cm 0.97 ll S /cm IS THIS CR A FOLLOW-UP TO A VERBAL NOTIFICATION? YES ~
IF YES, DATE/TIME AND PERSON NOTIFIED. N/A DATE / TIME N/A PERSON NOTIFIED CORRECTIVE ACTION REQUIRED: Confirm, investigate, and determine corrective actions, if any.
SECTION B ** COMPLETED BY SHIFT OPERATIONS PERSONNEL **
THE FOLLOWING CORRECTIVE ACTION WAS TAKEN: --------------------------
DATE TIME CORRECTIVE ACTION TAKEN:
SHIFT OPERATOR VERBALLY NOTIFY CHEMISTRY AFTER CORRECTIVE ACTION IS COMPLETED PERSON NOTIFIED:
DATE/T
- RETURN THIS SHEET TO CHEMISTRY *****
............................................................................................. /I ................................ ..
CHEMISTRY REVIEW: ________________________________
DATE
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET Peach Bottom DI Limerick I DI Common
~. JPM D QUALIFICATION MANUAL OJT MODULE Licensed Operator Training PLOR-347CA Licensed Operator Requalification 000 J. A. Verbillis jav Evaluation of High CRD Temperature on Control Rod Scram Time (SRO)
APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _ _.1_ _----" _ __
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE ID NO. COMPLETION DATE:
COMMENTS:
~
Training Review for Completeness: LMSCODE:
LMS ENTRY:
Signature/Date PLOR347CA RevOOO Page 1 of6
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Senior Reactor Operator TASK-JPM DESIGNATOR: 20110504021 PLOR-347CA KIA: G2.1.32 SRO: 4.0 TASK DESCRIPTION: Review AO 3.8 Attachment 1 for High CRD Temperature A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are th9se steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
PLOR347CA RevOOO Page 2 of6
B. TOOLS AND EQUIPMENT
- 1. Calculator
- 2. Unit 3 Tech Spec 3.1.3, 3.1.4 and Bases
- 3. AT2 - In-progress AO 3.8, with data recorded - Required
- 4. AT3 - Core Map (NF-PB-721, At 7) - Optional- for classroom setting C. REFERENCES
- 1. AO 3.8 Rev 0, "Evaluation of High CRD Temperature on Control Rod Scram Time"
- 2. Tech Spec 3.1.3, 3.1.4 and Bases
- 3. Core Map, such as NF-PB-721 At 7 D. TASK STANDARD
- 1. Satisfactory task completion is indicated when Control Rod 18-55 is declared SLOW or INOPERABLE and AO 3.8 is complete.
- 2. Estimated time to complete: 20 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE
~ When given the initiating cue, complete the Shift Management review of the in-progress AO 3.8 for Control Rod 18-55. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. Unit 3 is at 100% power.
- 2. Eight Control Rods (10-35,14-43,14-55,18-59,22-35,30-27,34-51,42-43) are currently classified as SLOW.
- 3. Control Rod 18-55 temperature is 405 OF and cannot be lowered.
- 4. System Manager has provided the latest Scram Time data for CR 18-55:
PositiQn 46 - 0.343 Sec Position 36 - 0.844 Sec Position 26 - 1.396 Sec Position 06 - 2.599 Sec
- 5. AO 3.B has been completed up through Step 4.7. including Attachment 1.
PLOR347CA RevOOO Page 3 of6
G. INITIATING CUE As the Control Room Supervisor, review Attachment 1 of AO 3.8, "Evaluation of High CRD Temperature on Control Rod Scram Time" for Unit 3 Control Rod 18-55 and complete AO 3.8.
Identify Technical Specification compliance issues and required actions, if any. (Candidate to
- document results on back of Cue Sheet) (Hand the candidate the in-progress copy of AO 3.8 with Attachment 1 complete through the Independent Verification.)
PLOR347CA RevOOO Page 4 of6
- H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO 1 REVIEW AO 3.8 up to and including step P AO 3.8, "Evaluation of High CRD 4.6. Temperature on Control Rod Scram Time" is reviewed.
- NOTE ****
The Alternate Path portion of this JPM begins with the next step.
2 RECOGNIZE that Scram Time for Control P Scram time for position(s) 46,36, and/or Rod 18-55 is unacceptable. 26 are recognized to be greater than Tech Spec allowance.
(CUE: If informed, acknowledge as appropriate.)
- 3 DECLARE Control Rod 18-55 "slow*. P Control Rod 18-55 declared slow.
(CUE: If informed, acknowledge as appropriate. )
4 VERIFY Compliance with Technical P TS 3.1.3 and 3.1.4 reviewed.
Specifications 3.1.3 AND 3.1.4.
(Cue: N/A) 5 RECOGNIZE Non-Compliance with LCO P LCO 3.1.4.b being exceeded is 3.1.4.b. recognized. (Control Rods 14-55, 18-59 are identified as SLOW in the Initiating (CUE: If informed, acknowledge as Cue; Control Rod 18-55 results in THREE appropriate. ) Control Rods occupying "adjacent locations". )
6 NOTIFY EDM and direct that Engineering P EDM is involved as required by
- IMMEDIATELY verify the accuracy of the procedure.
temperature corrected control rod scram time calculation.
(CUE: Inform candidate that Engineering concurs with all calculations and control rod speed data.)
- NOTE ***
Either of the alternatives in step 7 are acceptable.
PLOR347CA RevOOO Page 50f6
STEP STEP ACT STANDARD NO
- 7 DETERMINE that Tech Spec 3.1.4 P Action Statement understood.
Condition A Required Actions will require Unit 3 to be placed in Mode 3 within 12 -OR-Hours.
Tech Spec 3.1.3 ACTION C Required
- OR- Actions are identified as an acceptable and in fact preferred alternative. (One of DECLARE"Control Rod 18-55 (OR 18-59 the three adjacent rods must be declared
- OR 14-55) INOPERABLE, and apply INOPERABLE)
Tech Spec 3.1.3 Condition C Required Actions.
(CUE: If informed, acknowledge as appropriate.)
8 Verify an Issue Report is generated for P Issue Report generated or task to Control Rod 18-55. generate issue has been assigned.
(Cue: IR generated.)
9 Notify System Manager of status of P System Manager notified.
Control Rod 18-55 AND Tech Spec Required Shutdown.
- (Cue: As System Manager, acknowledge report.)
10 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simUlate I. TERMINATING CUE
- When Control Rod 18-55 is declared SLOW or INOPERABLE and AO 3.8 is complete, the evaluator will terminate the exercise.
PLOR347CA RevOOO Page 6 of6
TASK CONDITIONS/PREREQUISITES
- 1. Unit 3 is at 1000/0 power.
- 2. Eight Control Rods (10-35, 14-43, 14-55, 18-59, 22 3~, 30-27, 34-51, 42-43) are currently classified as SLOW.
- 3. Control Rod 18-55 temperature is 405 of and cannot be lowered.
- 4. System Manager has provided the latest Scram Time data for CR 18-55:
Position 46 - 0.343 Sec Position 36 - 0.844 Sec Position 26 - 1.396 Sec Position 06 - 2.599 Sec
- 5. AO 3.8 "Evaluation of High CRD Temperature on Control Rod Scram Time" has been completed up through Step 4.7, including Attachment 1.
INITIATING CUE As th~ Control Room Supervisor, review Attachment 1 of AO 3.8, "Evaluation of High CRD Temperature on Control Rod Scram Time" for Unit 3 Control Rod 18-55 and complete AO 3.8. Identify Technical Specification compliance issues and required actions, if any.
(Document your results on the back of this cue sheet.)
NF-PB-721 Revision 2 Page 10 of 11 Attachment 7 - Full Core Control Rod Map PREDICTED VALUES POWER PIrNT _ _ __ STATION/UNIT _ _~
POWER% _ _ __ PATTERN TinE _ _ _ _ _ _ __
FlOW MLBlHR (%) _ _ _ _ _ _ _ _ VAliD FROM _ _ _THROUGH _ __
Maximum MFLCPR _ _ _ _ AT _ _ __
Maximum MFLPD AT Maximum MAPRAT AT PREPARED BY APPROVED BY_ _ _ _ _ __
A = Actual Position * = POSITION 48 T = Target Position GIB 59 A T 55 ii',........,;'**
I . ,
I I 51 ;
I I I I 47 I;tigol":
I I I I I 43 il';:>'iiHi':. :)'[0;;,: J:t;~:;: ~3'~li'L I I I I I I 39 I I I I I I I 35 .'
I I I I I I 31 . ,'!:t:it::> :.'~t: Ik~' 11"'00:' .iUCt I I I I I I I 27 [:::~t:\:; ;8iAJr; I;;:'i.<<\(: t£t;t'AV~ ;'_18 lif:tcti' I I I I I I 2::: [nust, I"'",!!ow I I I I r I I 1S ,::_11':.
I E12'tB:H:
I ~ p;m !n:~
I
~::i;lltriil:i,'
T 15 thm;t,'b rS56B!i' I I I I I 11 ,:8tm:} Iic2ct::il; .
I I I 1 7 I:'*.~ ~;:mt!:2 I I r 3
02 06 10 14 18 22 26 30 34 38 42 46 50 54 58
AO 3.8 Rev. 0 Page 1 of 9 NHN:nhn Exelon Nuclear Peach Bottom Units 2 and 3 EVALUATION OF HIGH CRD TEMPERATURE ON CONTROL ROD SCRAM TIME PURPOSE This procedure provides the instructions necessary to evaluate the impact of high CRD hydraulic temperature on control rod scram
'me, as recommended by GE SILs 173 and 173S1, to ensure compli~nce with Technical Specifications 3.1.3 and 3.1.4.
RD hydraulic temperature has reached OR exceeded 350°F.
igh CRD hydraulic temperature may result in the associated control rod being declared slow in accordance with Technical Specification 3.1.4. Technical Specifications 3.1.3 AND 3.1.4 should be reviewed when this procedure is entered.
he control rod scram tim ositions 46, 36, 26, and 06 for he associated control rod will be obtained from copies located in the System Status Files of the last performance of either ST-R-003-475-2(3), ST-R-003-485-2(3) or ST-R-003-495-2(3) , OR f m the control rod scram time database located on computer
__~~rive S:\Scram Time\scramtime.mdb.
T e last performance of ST-R-003-475 (3), ST-R-003-485-2(3), or T-R-OO 495-2(3) is reviewed first to determine if the associated control rod was included in the scope of testing. If so, the necessary scram times will be obtained from this source ince the control rod scram time database may not have been updated to reflect the latest scram time data.
IF the associated control rod was NOT included in the scope of testing for the last performance of ST-R-003-475-2(3),
ST-R-003-485-2(3), or ST-R-003-495-2(3) , THEN the necessary cram times will be obtained from the control rod scram time database.
1, "Control Rod Scram Time Impact Calculation", will document performance of this procedure.
IF CRD hydraulic temperature can not be lowered below 350° F, THEN RECORD the associated Unit, control rod number
AO 3.8 Rev. 0 Page 2 of 9 eRD hydraulic temperature on Attachment 1 pages 6, 7, 8, 9.
the control rod scram times for Positions 46, 36, 26, for the associated control rod as follows:
1.0 IF the control rod was scram timed in the last performance of ST-R-003-475-2(3), ST-R-003-485-2(3) OR ST-R-003-495-2(3) during the current operating cycle, THEN RECORD the control rod scram times documented in the Surveillance Test in the appropriate location in Attachment 1 pages 6, 7, 8, and 9.
2.0 IF the control rod was NOT timed the last performance of the Surveillance Tests in the previous step, THEN 9V/~ OBTAIN the latest control rod scram times during the current operating cycle from the control rod scram time database located on computer drive S:\Scram Time\scramtime.mdb AND RECORD in appropriate location in Attachment 1 pages 6, 7, 8, and 9.
~~ the control rod scram time for the current operating
~cle could not be obtained by one of the previous steps, THEN COlftACT Engineering AND OBTAIN the latest control rod scram times during the current operating cycle AND RECORD in the appropriate location in Attachment 1 pages 6, 7, 8, and 9.
~ETERMINB the Table 1(2, 3, Position 46(36, 26, 06) Penalty using
- 4) on page 6(7, 8, 9) AND RECORD in the appropriate location in Attachment 1.
~nD the Position 46(36, 26, 06) control rod scram time to
~the Position 46(36, 26, 06) penalty to determine the temperature corrected Position 46(36, 26, 06) control rod scram time AND RECORD in the appropriate location in Attachment 1.
~VCORD the Maximum Notch 46(36, 26, 06) Scram Time allowed
~~ Tech Spec Table 3.1.4-1 in the appropriate location in Attachment 1.
~IRECT that an Independent Verification be performed for all
~ntries on Attachment 1 AND DOCUMENT in the appropriate location in Attachment 1.
AO 3.8 Rev. 0 Page 3 of 9
~DIRBCT Reactor Engineering to perform ST-R-003-480-2(3) ,
~~Average Scram Time For ODYN/B Minimum Critical Power Ratio (M,CPR) requirements, II wi thin 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
Person Contacted: ~ tE. 9danaser Time: lili"mm Date: rtotfay's (})ate 4.8 DETERMINE if the temperature corrected Position 46(36, 26,
- 06) control rod scram time is greater than the Maximum Notch 46(36, 26, 06) Scram Time allowed by Tech Spec Table 3.1.4-1.
1.0 IF ALL temperature corrected control rod scram times are less than OR equal to the Maximum Notch Scram Time allowed by Tech Spec Table 3.1.4-1, THEN GO to Step 4.11. OTHERWISE, N/A.
2.~ IF ANY temperature corrected control rod scram t is greater than the Maximum Notch Scram Time allowed by Tech Spec Table 3.1.4-1, THEN GO to Step 4.9.
OTHERWISE, N/A.
4.9 IF ANY temperature corrected control rod scram time is greater than the Maximum Notch Scram Time allowed by Tech Spec Table 3.1.4-1, THEN DECLARE the control rod "slow" AND COMPLY with Technical Speci cations 3.1.3 AND 3.1.4.
OTHERWISE N/A.
4.10 IF ANY control rod scram time is greater than 7 seconds to notch position 06, THEN DECLARE the control rod inoperable AND COMPLY with Technical Specification 3.1.3. OTHERWISE N
'CAO'ftONS
- 1. In accordancewftht~~~i.C?il;S~~~~'f.ication 3.1.4, specific combinat1on$ .of uS1QW't*i:::ii;onttQl~otis ,requir~ a plant shutdown.
The intent of thefolJ:o,itin(j.s.t,etr~stoepsure any temperature correctiqn for ,a qon~.:cq~~,Qti;*t;;l;t~:tl1~~the POTENTIAL to require a pliint shut.gown is veriffied.<:SinCe' ~ plant shutdown either will be, or will not betP~:i~oniedbas!!!d6nt;hecalculation.
- 2. The followfngstep is Htit.intepdi;id,.to .:restrain performance of a plant shutdown if reQl.lired,by'Tecihnical Specification 3.1.4.
4.11 REGARDLESS of whether or not the rod was evaluated as slow, IF control rod is adjacent to another IIslow" control rod OR IF 12 other control rods have already been declared
AO 3.8 Rev. 0 Page 4 of 9 "slow", THEN IMMEDIATELY NOTIFY the EDM AND DIRECT that Engineering IMMEDIATELY verify the accuracy of the temperature corrected control rod scram time calculation.
OTHERWISE, N/A.
4.12 DOCUMENT Shift Management review of Attachment 1.
4.13 INITIATE an Issue to correct the high CRD temperature condition.
4.14 NOTIFY the CRD System Manager that AO 3.8 has been performed AND FORWARD Attachment 1 to the System Manager.
AO 3.8 Rev. 0 Page 5 of 9 5.0 CONTROL STATIONS 5.1 None
6.0 REFERENCES
6.1 GE SIL 173 6.2 GE SIL 173S1, Revision 1 7.0 TECHNICAL SPECIFICATIONS 7.1 3.1.3 7.2 3.1.4 8.0 INTERFACING PROCEDURES 8.1 ARC 2(3)11 G-5, "CRD Hydraulic Hi Temp" 8.2 ST-R-OO 475-2(3), "CRD Scram Insertion Timing Following Reactor Scram" 8.3 ST-R-003-485-2(3) , "CRD Scram Insertion Timing of Selected Control Rods" 8.4 ST-R-003-495-2(3), "CRD Scram Insertion Timing Selected Control Rods During Hydro"
AO 3.8 Rev. 0 Page 6 of 9 : Control Rod Scram Time Impact Calculation Initial/Date
(.step 4.1) Unit: 3 Associated control rod: 18-55 VlJ(O /l'otfay Record the CRD Temperature: 405 of VlJ(O /l'otfay (Step 4.2) Position 46 Scram Time: 0.343 sec VlJ(O /l'otfay (Step 4.3) Position 46 Penalty (from Table 1 below): 0.35 sec VlJ(O /l'otfay (Step 4.4) Determine Temperature eorrected Position 46 Control Rod Scram Time by adding the Position 46 Scram Time and Position 46 Penalty: 0.693 sec VlJ(O /l'otfay (Step 4.5) Maximum Notch Position 46 Scram Time allowed by Tech Table 3.1. 4 1: 0.44 sec V<.RO /l'otfay Table 1: GE SIL 173 Position 46 Penalty CRD Temp Position 46 Penalty
-> 350 0 F and < 400 0 F 0.07 sec
> 400 0 F 0.35 sec (Step 4.6) Position 46 temperature corrected Control Rod Scram Time Independent Verification performed by: ~d4.y
- 1. V.
AO 3.8 Rev. 0 Page 7 of 9 : Control Rod Scram Time Impact Calculation Initial/Date (Step 4.1) Unit: 3 Associated control rod: 18-55 V<RO/Toaay Record the CRD Temperature: V<RO /Totfay
(~tep 4.2) Position 36 Scram Time: 0.844 sec V<RO/Toaay (Step 4.3) Pos ion 36 Penalty (from Table 2 below): 0.60 sec V<RO/Toaay (Step 4.4) Determine the Temperature Corrected Position 36 Control Rod Scram Time by adding the Pos ion 36 Scram Time and Position 36 Penalty: 1. 444 sec V<RO/Toaay (Step 4.5) Maximum Notch Position 36 Scram Time allowed by Tech Spec Table 3.1.4-1: 1. 08 sec V<RO/Toaay Table 2: GE SIL 173 Position 36 Penalty CRD Temp Position 36 Penalty
> 350 0 F and < 400 0 F 0.14 sec
> 400 0 F 0.60 sec (Step 4.6) Pos ion 36 temperature corrected Control Rod Scram Time Independent Verification performed by:
AO 3.8 Rev. 0 Page 8 of 9 : Control Rod Scram Time Impact Calculation Initial Date (Step 4.1) Unit: 3 Associated control rod: 18-55 V'RO !TOday Position 26 Scram Time Penalty Calculation (Step 4.2) Pos ion 26 Scram Time: 1. 396 sec V'RO !TOday (Step 4.3 ) Position 2 6 Penalty (from Table 3 below): 0.70 sec V'RO IIhday (Step 4.4) Determine the Temperature Corrected Position 26 Control Rod Scram Time by adding the Position 26 Scram Time and Position 26 Penalty: 2.096 sec V'RP !Today (Step 4.5) Maximum Notch Position 26 Scram Time a-llowed by
~
Tech Spec Table 3.1.4-1: 1. 83 sec V'RP !TOday Table 3: GE SIL 173 Position 26 Penalty CRD Temp Position 26 Penalty 350 0 F and < 400 0 F 0.17 sec
> 400 0 F 0.70 sec (Step 4.6) Position 26 temperature corrected Control Rod Scram Time Independent Veri cation performed by: I~d4J
- 1. V.
AO 3.8 Rev. 0 Page 9 of 9 A~tachment 1: Control Rod Scram Time Impact Calculation Initial/Date (Step 4. 1) Unit: 3 Associated control rod: 18-55 V~OlIotfay Record the CRD Temperature: V~OlIoaay Position 06 Scram Time Penalty Calculation (Step 4.2) Position 06 Scram Time: 2.599 sec V~OlIoaay (Step 4.3) Position 06 Penalty (from Table ~ below): 0.70 sec V~O!fgaay (Step 4.4) Determine the Temperature Corrected Position 06 Control Rod Scram Time by adding the Position 06 Scram Time and Position 06 Penalty: 3.299 sec V~OlIoaay (Step 4.5) Maximum Notch Position 06 Scram Time allowed by Tech Spec Table 3.1.4-1: 3.35 sec Vf,ROlIoaay Table 4: GE SIL 173 Position 06 Penalty CRD Temp Position 06 Penalty
-> 350 0 F and < 400 0 F 0.15 sec
> 400 0 F 0.70 sec (Step 4.6) Position 06 temperature corrected Control Rod Scram Time Independent Verification performed by: l1A1L/IOdaJ
- 1. V.
(Step 4.12) Shift Management review of Attachment 1 pages 6, 7, 8, and 9 performed by:
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET I Peach Bottom I DI Limerick I DI Common ~
JPM D QUALIFICATION MANUAL OJTMODULE LICENSED OPERATOR TRAINING PLOR-273C Licensed Operator Requali'fication 000 C. N. Croasmun cnc Compensatory Actions for an Inoperable Fire Door APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _----:1_ _----:1_ __
. ~
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE ID#: COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMSCODE:
LMS ENTRY:
Signature/Date PLOR273C RevOOO Page 1 of 5
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 3410170302 I PLOR-273C KIA: G2.2.40 SRO: 4.7 TASK DESCRIPTION: Ability to determine actions required for an Inoperable Fire Door A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical ..IPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
PLOR273C RevOOO Page 2 of 5
B. TOOLS AND EQUIPMENT
- 1. A copy of ST-0-037-390-2 "Fire Door Electrical Supervisory Alarm System"
- 2. Drawing A-486 "Barrier Plan" Elev. 135'
- 3. Technical Requirements Manual section 3.14 C. REFERENCES
- 1. ST-0-037-390-2 "Fire Door Electrical Supervisory Alarm System"
- 2. Drawing A-486 "Barrier Plan" Elev. 135'
- 3. Technical Requirements Manual section 3.14 D. TASK STANDARD
- 1. Satisfactory task completion is indicated when the Technical Requirements Manual compensatory measures have been identified.
- 2. Estimated time to complete: 15 minutes Non-Time Critical.
E. DIRECTIONS TO EXAMINEE When given the initiating cue, determine any actions required to be taken for Fire Door #217 Supervisory Alarm System failing to alarm.
F. TASK CONDITIONS/PREREQUISITES
- 1. Fire Door supervisory alarm testing is in progress in accordance with ST-0-037-390-2 "Fire Door Electrical Supervisory Alarm System".
- 2. You have just been notified that Fire Door #217 has been fully open for eleven minutes, and has failed to alarm.
- 3. Previous fire surveillance testing has determined that all smoke detectors on Turbine Building 135' are operable.
G. INITIATING CUE As the Unit 2 Control Room Supervisor review ST-0-037-390-2 "Fire Door Electrical Supervisory Alarm System" and identify any required action(s) for Fire Door #217. Document required action(s) on the cue sheet.
PLOR273C RevOOO "age 3 of 5
H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Obtain a copy of ST-0-037-390-2 "Fire P ST-0-037-390-2 "Fire Door Electrical Door Electrical Supervisory Alarm Supervisory Alarm System" obtained.
System".
(Cue: Provide the candidate with a copy of ST-0-037-390-2) 2 Determine Fire Door location. P Review ST-0-037-390-2 Data Sheet 1, and determine Fire Door 217 is located on TB2 elevation 135' in the 2A & 2C
- Battery Room .
3 Review ST-0-037-390-2 sections 4 and P Review ST-0-037-390-2 "Fire Door
- 5. Electrical Supervisory Alarm System" for Precautions, Limitations, General Instructions, and Acceptance Criteria.
- 4 Identify Fire Door #217 classification. P Review ST-0-037-390-2 section 4 and determine Fire Door #217 is a Safety Related door identified by an
- on Data Sheet 1.
5 Review ST-0-037-390-2 Performance P Review ST-0-037-390-2 section 6 for Steps and Corrective actions. Test Requirements and Corrective Actions.
- 6 Identify alarm requirements for Fire Door P Determine Fire Door #217 is required to
- 217. alarm in less than or equal to 10 minutes, and is INOPERABLE.
7 Obtain a copy of the Unit 2 Technical P Obtain a copy of the Unit 2 Technical Requirements Manual. Requirements Manual and review section 3.14 Fire Protection Systems.
(Cue: Provide the candidate with a copy of the Unit 2 Technical Requirements Manual.)
- 8 Determine Unit 2 Technical P Review Technical Requirements Manual Requirements Manual required action. section 3.14.8 condition A and establish a Fire Watch Patrol within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and once per hour there after for Unit 2 TB 135' 2A
- & 2C Battery Room .
PLOR273C RevOOO Page 4 of 5
9 Inform the Evaluator of task completion. P The operator informs the Evaluator of task completion.
(Cue: The Control Room Supervisor acknowledges the report.)
10 As an evaluator ensure that you have P Positive control established.
positive control of all exam material provided tQ the examinee (Task
. Conditions/Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the Technical Requirement Manual compensatory actions have been identified, and the evaluator has been informed, the evaluator will terminate the exercise.
PlOR273C RevOOO Oage 5 of 5
TASK CONDITIONS/PREREQUISITES
- 1. . Fire Door supervisory alarm testing is in progress in accordance with ST 0-037-390-2 "Fire Door Electrical Supervisory Alarm System".
- 2. You have just been notified that Fire Door #217 has been fully open for eleven minutes, and has failed to alarm.
- 3. Previous fire surveillance testing has determined that all smoke detectors on Turbine Building 135' are operable INITIATING CUE As the Unit 2 Control Room Supervisor review ST-0-037-390-2 "Fire Door Electrical Supervisory Alarm System" and identify any required action(s) for Fire Door #217. Document required action(s) on the cue sheet:
E}telon Nuclear ST-O-037-390-2 Peach Bottom Rev. 5 Unit 2 & 3 Page 1 of 11 Surveillance Test DWD:dwd ST-O-037-390-2 FIRE DOOR ELECTRICAL SUPERVISORY ALARM SYSTEM FUNCTIONAL TEST TEST FREQUENCY: Once/92 days TECH SPEC: TR 3.14.8.4 APPLICABILITY: At All Times 1
CHECK why this procedure is being performed:
D Schedule DOVF D Retest Due To Unsat Test D Other Reason:
Approved by SMgt: I /
Time Date 2
INITIAL one of the following Test Results:
A: All R steps are SATISFACTORY B: One or More R steps are UNSATISFACTORY Refer to Section 9.0 Tech Spec LCO's I I Performed By: --=-.-- - I I Time Date s RO/PRO Informed of Test Completion:
SMgt Informed of Test Results: I UNSAT Notification:
rs Notified By: ------------------ -----
/
3 IF other portions of the test did NOT function properly, OR other discrepancies were noted, THEN COMPLETE the following:
DESCRIBE discrepancies/actions taken: Issue or ETT#:
Reviewed/Approved Fire Protection / /
Program Manager: Printed Name Time Date
ST-O-037-390-2 Rev. 5 Page 2 of 11 1.0 PURPOSE This test verifies operability of the Fire Door Electrical Supervisory Alarm System once per 92 days (quarterly) in accordance with the Technical Requirements Manual TR 3.14.8.4.
2.0 TEST EQUIPMENT 2.1 Digital Watch 3.0 PREREQUISITES Initial 3.1 Test Initiation 3.1.1 COMPLETE Section 1 of cover page.
3.2 Document Review 3.2.1 ENSURE procedure is current revision.
3.3 Equipment Configuration None 3.4 Required Redundant Safety Related Equipment None 3.5 Other Prerequisite Activities 3.5.1 CONTACT Health Physics for RWP requirements prior to entering any Radiologically Controlled Area listed on Data Sheet 1.
3.6 Approval to Start Test 3.6.1 OBTAIN SAS Attendant Permission to begin.
4.0 PRECAUTIONS, LIMITATIONS, AND GENERAL INSTRUCTIONS 4.1 Plant Impact Statement 4.1.1 This test does NOT affect plant availability in any manner AND may be performed in any Reactor Mode.
ST-O-037-390-2 Rev. 5 Page 3 of 11 4.0 PRBCA~IONS, LIMITATIONS, AND GENERAL INSTROCTIONS (Continued) 4.2 Precautions None 4.3 Limitations None 4.4 General Instructions 4.4. 1 Communications shall be established between the Secondary Alarm Station (SAS) Attendant (at extension 4277 or 4285) and persons performing door tests in order that the SAS Attendant may be informed and conduct tests as required.
4.4.2 IF any procedure step can NOT be completed OR produces an unexpected response THEN stop the test AND initiate compensatory measures as required AND notify Supervisor, Nuclear Security (SNS) and SMgt.
4.4.3 IF any Black Box is initialed THEN stop the test AND initiate compensatory measures as required AND notify the SNS and SMgt.
4.4 .4 IF procedure is aborted, THEN NOTIFY SNS AND SMgt AND write "TEST ABORTED" in Section 3 of Cover Page.
4.4.5 All persons who initial steps in Sections 3.0, 6.0, or 7.0 are responsible for completing Section 10.0.
4.4.6 All applicable
- steps are identified immediately in front of the init Is.
4 .'4 . 7 Fire Doors which are Safety-Related are identified with an
- in the initials column on Data Sheet 1 AND are subject to the requirements of TR 3.14.8.4 4.4.8 Fire Doors listed on Data Sheet 1 which are NOT Safety-Related are provided for convenience of inspection AND are NOT subject to the requirements of the Technical Requirements Manual.
5.0 ACCEPTANCE CRITERIA Fire doors listed on Data Sheet 1 are tested in accordance with Section 6.0 of this procedure, verified operable, AND their respective zone alarms received by SAS.
ST-O-037-390-2 Rev. 5 Page 4 of 11 6.0 PERFORMANCE STEPS 6.1 Fire Door Supervisory Alarm Functional Test NOTE Tests of Fire Doors listed on Data Sheet 1 may be performed in any order AND at times appropriate for the purpose of the test.
6.1.1 SELECT Fire Door to be tested AND RECORD time AND date of test on Data Sheet 1.
6.1. 2 PERFORM test of each door as follows:
- 1. FULLY OPEN door.
- 2. HOLD door open for up to ten minutes until alarm occurs.
- 3. VERIFY door marked with a # sign on Data Sheet 1 alarm immediately.
- 4. VERIFY door zone is in ALARM.
- 5. VERIFY time for doors NOT marked with the # sign on Data Sheet 1 is less than or equal to ten minutes.
- 6. CLOSE door AND VERIFY SAS alarm zone is RESET.
- 7. RECORD all comments AND INITIAL test results either Sat or UnSat on Data Sheet 1.
6.2 Corrective Action 6.2.1 IF any fire door OR alarm zone is found inoperable, THEN INITIATE a Corrective Action AND ETT as necessary.
OTHERWISE, N/A this step.
6.2.2 IF any Safety-Related fire door is found inoperable, THEN INITIATE compensatory measures in accordance with the Technical Requirements Manual.
OTHERWISE, N/A this step.
ST-O-037-390-2 Rev. 5 Page 5 of 11 7.0 PROCEDURE COMPLETION Initial 7.1 Independent Verification None 7.2 Records Completion 7.2.1 VERIFY all fire doors have been tested AND Data Sheet 1 is COMPLETE.
7.2.2 COMPLETE Section 2 of Cover Page (AND Section 3 IF applicable) .
8.0 REFERENCES
8.1 Governing 8.1.1 UFSAR (Fire Protection Program, Chapter 7) 8.1. 2 Technical Requirements Manual TR 3.14.8.4 8.J.3 10CFR50, Appendix R, Section N.1 8.1. 4 Engineering Technical Evaluation AIR 1478378 E-3 8.2 Inter ng None 8.3 Developmental
8.3.1 Prints
A-167, Fire Detection and Suppression - Floor an at El. 116'-0" A-484, Barrier Plans, Elev. 91'-6" A-485, Barrier Plans, Elev. 116'-0" A-486, Barrier Plans, Elev. 135'-0" A-487, Barrier Plans, Elev. 165'-0" A-488, Barrier Plans, Elev. 195'-on A-489, Barrier Plans, Elev. 234'-0" A-490, Barrier Plans, C.W. Pump Structure, Emergency Cooling Tower & Diesel Generator Building
ST-O-037-390-2 Rev. 5 Page 6 of 11 UFSAR Section 10.12 8.3.3 PBAPS Fire Protection Program (FPP) 8.3.4 This procedure supersedes RT-S-037-390-2.
8.3.5 AG-CG-028.1-10, Peach Bottom Atomic Power Station Maintenance Rule Structural Monitoring Program 9.0 CORRECTIVE ACTIONS 9.1 Technical Requirements Manual Specification 3.14.8 Fire Barriers.
10.0 PARTICIPANTS RECORD Printed Name Initials
ST-O-037-390-2 Rev. 5 Page 7 of 11 DATA SHEET 1 FIRE DOOR SUPERVISORY ALARM TEST DOOR BMlRIER NUMBER TIME INITIAL NO. PLAN'l' LOCATION DATE CCH4EN'l'S SAT UNSAT RB2-91-3-NE (TORUS ACCESS)
- -c TIME:
II 2 C RHR PUMP AREA, 91' 6", R2-7 DATE: I I RB2-91-4-SE (TORUS ACCESS) TIME: _ ....
II 3 B RHR PUMP AREA, 91' 6", R2-6 DATE: I I
- C
- -c RW2-88-S'J:-24-W TIME:
- 5 D RHR PUMP AREA, 91' 6*', R2-8 DATE: I I RW2-88-ST-24-E TIME:
6 HPCI PUMP ROOM, R2-13 91' 6",
DATE: / /
- C 7 RW-2-88-8-E U/2 RCIC
- -c TIME:
91' 6" R2-13 DATE: I /
RB2-91-10-N TIME:
9 D CORE SPRAY PUMP ROOM, 6 u , R2-12 91' DATE: / I
- C
-c TBC-91-17-W, OUTSIDE TIME: -_....
32 CONDENSATE BACKWASH PUMP ROOM, 91' 6", T2-6 DATE: / /
RB3-91-39-NE(TORUS ACCESS) TIME:
II 38 C RHR PUMP AREA, 91' 6", R3-7 DATE: / /
- C
- -c RB3-91-40-SE(TORUS ACCESS) TIME:
1I 40 B RHR PUMP AREA, 91' 6 lf
, R3-6 DATE: I /
RW3-91-46-N TIME:
48 RB3 SUMP ROOM/A CS PUMP ROOM, 91' 6", R3-9 DATE: / I
- C 50 RW-3-88-48-E U/3 RCIe TIME:
91' 6" R3-14 DATE: / / *' Li RW2-116-104-E TIME:
68 ABOVE D RHR PUMP, 116' , R2-19 DATE: / /
- C RW2-116-105-S TIME:
70 RBCCW ROOM, REAR DOOR TO RHR, 116' , T2-44 DATE: / I
- ' C
- '-c RB2-116-107-E TIME:
75 B & D CORE SPRAY PUMP TRIANGLE ROOM, 116'
- R2-21 DATE: / I RB2-116-ST-18-E TIME:
79 A & C CORE SPRAY PUMP TRIANGLE ROOM, 116 t , R2-20 DATE:
~ ...
/ /
- ' C
ST-O-037-390-2 Rev. 5 Page 8 of 11 DATA SHEET 1 (Continued)
FIRE DOOR SUPERVISORY ALARM TEST DOOR BARRIER NUMBER TIME INITIAL NO. PLANT LOCATION DATE COMMENTS SAT UNSAT
- TB2-116-139-S, ROLL-UP DOOR, TIME:
It 89 LUBE OIL TANK AREA, 116' , T2-22 DATE: / / ---
TB2-116-8T-01-E, TIME:
It 91 SE STRWLL EMERG EXIT, 116' ,
T2-21 DATE: / / ---
TB2-116-8T-03-E, OUTSIDE TIME:
- 108 ENTRANCE TO NE STAIRWELL, 116' , TZ-155 DATE: / / -
T82-116-185-E, OUTSIDE TIME:
- 110 ENTRANCE, EQUIP. HATCH AREA, 116' ,T2-155 DATE: / / ---
TB2-116-185- E, OVERHEAD DOOR, TIME
- 111 EQUIP. HATCH AREA, 116' , T2 155 DATE: / / ---
TBC-116-126-W TIME:
134 RADWASTE BUILDING CORRIDOR, 116' , R/W-15 DATE: / /
- *******-C RB3-11 3-E 144 NE 116' TIME:
.. C
- R3-81 DATE: / /
RB3-116-161-E
- --c TIME 147 RB3 A & C CORE SPRAY ROOM, 116, R3-20 DATE: / /
TB3-116-ST-05-E TIME:
- 176 TB3 NORTHWEST STAIRWELL EMERG EXIT, 116' , T3-21 DATE: / I --
RB-2-115 ACCESS TO DOOR A AND TIME:
182 C RHR, Rx BLDG, 116 R2-22 DATE: / / ---
RB2-135-ST-26-N TIME 184 Rx BLDG SW GENERAL AREA, 135' ,
R2-22, STAIRWELL DATE: / /
- C 191 RB2-135-ST-19-E; TB2 COND FLTR DEMIN CORRIDOR, TIME:
.. C 135' , R2-81 DATE: / /
RB2-135-213-S, TIME:
197 EQUIP ACCESS INNER R/R DOOR, Rx BLDG :),35', R2-29 DATE: / / ----
201 TBC-135-262-S HALLWAY OUTSIDE RADWASTE BLDG, TIME:
.. C 135' , T2-69 IS) DATE: / /
ST-O-037-390-2 Rev. 5 Page 9 of 11 DATA SHEET 1 (Continued)
FIRE DOOR SUPERVISORY AL.A:RM TEST DOOR BARRIER NUMBER TIME INITIAL NO. PLANT LOCATION DATE COMMENTS SAT tlNSAT TB2-135-217-E TIME:
216 E-32 EMERG AUX SWTCHGR RM, 135' , T2-170 (INSIDE) DATE: / /
- 1::1 T82-135-218-E TIME:
217 2A & 2C BATTERY ROOM, 135' ,
T2-70 ( INSIDE) DATE: / / *-1::1 TB2-135-226-E TIME:
223 E-42 EMERG AUX SWTCHGR RM, 135' , T2-172 (INSIDE) DATE: / /
- 1::1 RWC-135-ST-34-W TIME
- 231 RADWASTE STAIRWELL EXIT, 135' , R/W-37 (W) DATE: / / ---
RWC-135-242-W TIME:
- 232 ROLL-UP DOOR, RADWASTE BLDG,
- 135', R/W-18 (W) DATE: / / ---
RB3-135-238-W TIME 238 U/3 MG SBT ROOM SW STAIRWAY 2:).
135' TO DATE: I I
- -.. - 1::1 RB3-135-ST-36-S TIME:
243 NW STAIRWELL, Rx BLDG NW GENERAL AREA, 135, R3-23 DATE: I I
- 1::1 RB3-135-251-N RAILROAD DOOR, TIME:
247 Rx BLDG NE GENERAL AREA, 135',
R3-116 DATE: / / - ...... -~
RB3-135-251-NP, PERS. DOOR IN TIME:
247P R/R DOOR, Rx BLDG NE GEN AREA, 135' , R3-l16 DATE: I / ~.- ...--
RB3-135-ST-22-E TIME:
254 SE STAIRWELL, Rx BLDG, 135' R3-56 (ENTRANCE) DATE: / /
- 1::1 TB3-135-266-E TIME:
256 3A & 3C BATTERY ROOM, 135' ,
T3-70 (INSIDE) DATE: / /
- -- 1::1 TB3-135-265-E TIME:
258 E-43 EMERG AUX SWTCHGR RM, 135' , T3-172 (INSIDE) DATE: / /
- 1::1 T83-135-261-E TIME 262 E-33 EMERG AUX SWTCHGR RM, 135' I T3-170, (INSIDE) DATE: / / *-1::1 TB3-135-272-N TIME:
278 COND FLTR DEMIN CORRIDOR, 135' , T3-69 (N) DATE: I I
- 1::1 RB2-165-ST-Z6-N TIME:
293 SW STAIRWELL, Rx BLDG SW 165',
RZ-114 (EXIT) DATE: I /
- 1::1 RB2-16S-ST-19-E TIME:
- -1::1
-~-.~----
301 TB2 ACCESS AIRLOCK, NE STAIRWELL,16S', R2-116 DATE: / /
DATA SHEET 1 (Continued)
FIRE DOOR SUPERVISORY A.LA.RM TEST
- BARRIER NUMBER TIME INITIAL PL.l\NT LOCATION DATE CQIlHENTS -~'!-~
ST-O-037-390-2 Rev. 5 Page 10 of 11 RWC-165-375-W TIME; 305 U/2 RECIRC MG SET fAN ROOM, .. c::::I 165' , R/W-33 DATE: / /
307 RWC-165-377-W RADWASTE CENTRIFUGE GEN AREA fAN RM, 165' , R/W-27 TIME:
DATE: / /
. - c::::I RB2-165-ST-19-N 312 NE STAIRWELL, Rx BLDG, 165' ,
TIME:
.. c::::I R2-116 (EXIT TO R/W) DATE: / /
343 RB3-165-ST-22-E SE STAIRWELL, Rx BLDG, 165' ,
R3-117 (ENTRANCE)
TIME:
DATE: / /
...- c::::I RB3-165-ST-22-S TIME 345 SE STAIRWELL, Rx BLDG, 165' ,
R3-1l7 (EXIT TO R/W) DATE: I /
- c::::I RB3-165-ST-27-S TIME:
346 NW STAIRWELL, Rx BLDG NW GEN.
AREA, 165, R3-115 DATE: / /
c::::I RWC-165-382-W 356 DOOR TO U/3 MG SET SUPPLY FAN TIME:
. c::::I ROOM, 165' , R/W-34 DATE: / /
380 TB2-181-431-W TB2 BLDG ELEVATOR MACHINE ROOM, 181' T2-175 TIME:
DATE:
/ /
. - c::::I 385 RB2-195-ST-26-N SW STAIRWELL, Rx BLDG, TIME
.. c::::I 195' R2-73 (EXIT) DATE: I /
TB2-195-512-N TIME:
- 389 EXIT TO R/W BLDG ROOf, 195' , T2-101 DATE: / I - .......
- RB3-195-ST-27-S TIME:
394 NW STAIRWELL, Rx BLDG NW 195',
R3-l15 (EXIT) DATE: / I c::::I 417 RB3-116-ST-36-W ACCESS DOOR TO B&D RHR ROOMS, 116' , R3-29 TIME:
DATE: /
. - c::::I C-6 CWC-1l2-802-S TIME:
DOOR TO DIESEL !"IRE PUMP ROOM, 112' , P/H-7 DATE: / I
- c::::I C-9 CWC-112-801-N EMERGENCY PUMP STRUCTURE, TIME:
.. -- c::::I 112', P/H-8 (INSIDE) DATE: / /
0-6 DGC-127-819-S
£3/E4 DOOR, #4 (D) DIESEL TIME:
.. c::::I GEN., WEST 127', D/G-lO DATE: / /
ST-O-037-390-2 Rev. 5 Page 11 of 11 DATA SHEET 1 (Continued)
FIRE DOOR SUPERVISORY ALARM TEST DOOR BARRIER NUMBER TIME INITIAL NO.
- PLANT LOCATION DATE COMMENTS SAT UNSAT DGC-127-817-S 0-8 E1IE2 DOOR, 112 (B) DIESEL GEN.,
TIME:
.. C WEST 127' , D/G-6 DATB: 1 1 0-16 DGC-151-811-S, CARDOX RM STAIRS, ill (A) DIESEL GBN., WEST 151',
D/G-14 DGC-151-812-S, E1IE2 TIMB:
DATE:
TIME:
-~--
1
.. --------~
1
-c 0-17 E'AN RMS, #2 (B) DIESEL GEN, WEST .. C 151', D/G-16 DATE: 1 1 0-18 DGC-151-813--S, E2/E3 FAN RMS, 113 (C) DIESEL GEN, WEST 151', D/G-18 DGC-1S1-814 **S, E3/E4 TIME: - - - -
DATE:
TIME I I
--c 0-19 FAN RMS, #4 (0) DIESEL GEN, WEST .. C lSI', D/G-20 DATE: I I RCC-13S-001'-N, EQUIP ACCESS AREA, TIME:
IIR-06 NW ENTRANCE " 13S' , R/B-8 DATE: I I -
RCC-13S'-ST-01-N TIME
'#R-OB RECOMBINER BLDG, NE STRWLL ENTRANCE, 135, R/B-B DATE: I 1 --
RCC-1S7-003-W TIME:
- R-22 RECOMBINER BLDG, WEST ENTRANCE, 157', R/B-ll DATE: I I _ _--
- Indicates doors which should alarm immediately after door is opened.
COMMENTS:
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET 01 Peach Bottom I DI Limerick I 1l==..o.....111 Common ~
~ JPM D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR TRAINING PLOR-256C LICENSED OPERATOR REQUALIFICATION 001 M. J. Kelly Mda REV(EW AND APPROVE PRIMARY CONTAINMENT PURGENENT ISOLATION VALVE CUMULATIVE HOUR LOG APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _______,_______,_ __
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE 10#: COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMSCODE:
LMS ENTRY:
. Signature/Date PLOR256C Rev001 Page 1 of 5
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2270140201/ PLOR-256C KIA: G2.3.13 SRO: 3.8 TASK DESCRIPTION: Perform Primary Containment PurgeNent Isolation Valve Cumulative Log.
A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when ,no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" ..IPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
PLOR256C Rev001.doc Page 2 of 5
B. TOOLS AND EQUIPMENT
- 1. Calculator
- 2. Copy of ST-O-007-560-2, "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log".
- 3. A calculation error made on Data Sheet 1 such that "Accumulated Total Time Since Beginning of Calendar Year" is greater than 90 hours0.00104 days <br />0.025 hours <br />1.488095e-4 weeks <br />3.4245e-5 months <br />, with the procedure completed to indicate total time is less than 90 hours0.00104 days <br />0.025 hours <br />1.488095e-4 weeks <br />3.4245e-5 months <br /> (use Attachment 2 of this JPM for exact values).
C. REFERENCES
- 1. ST-O-007-560-2, Rev. 2, "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log",
D. TASK STANDARD
- 1. Satisfactory task completion is indicated when the Shift Management review has been completed, the calculation error on Data Sheet 1 identified, and the total accumulated time a purge/vent valve is open has been determined to be greater than 90 hours0.00104 days <br />0.025 hours <br />1.488095e-4 weeks <br />3.4245e-5 months <br />.
- 2. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to review the Primary Containment PLirgeNent Isolation Valve Cumulative Hour Log. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. The "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log" for Unit 2 (ST-O-007-560-2) has been completed.
- 2. The "Accumulated Total Time Since Beginning of Year" is greater than 80 hours9.259259e-4 days <br />0.0222 hours <br />1.322751e-4 weeks <br />3.044e-5 months <br />. Shift Management has been notified as required by Step 6.1.6.
G. INITIATING CUE You are the Work Control Supervisor. Perform the Plant Staff review and approval of ST-O 007-560-2, "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log".
PLOR256C Rev001 Page 3 of 5
- H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Cue: Hand the Examinee a completed copy of ST-O-007-560-2," Primary Containment PurgeNent Isolation Valve Cumulative Hour Log" with Data Sheets 1 and 2 data filled in by hand from Attachment 2 of this JPM.
2 Review ST-0-007-560-2 for P Verifies all procedure steps, Data Sheet completeness. 1, and Data Sheet 2 have been completed satisfactorily.
3 Verify calculations. P Performs all calculations that were done on Data Sheet 1 to verify they are correct
- and properly recorded.
- 4 Recognize calculation errors. P Recognizes the following calculation errors on Data Sheet 1:
- 1. Second row of the "Flow Path Open Total Time" column should be 17 Hr, 4 Min versus 5 Hr, 4 Min.
- 2. Fourth row of the "Accumulated Total Time Since Beginning of Calendar Year" column total is incorrect... one additional hour should be added.
NOTE: the "critical" part of this step is to recognize the first error and the fact that the accumulated total time has exceeded
- 90 hours0.00104 days <br />0.025 hours <br />1.488095e-4 weeks <br />3.4245e-5 months <br />.
- 5 Determines the "Accumulated Total Time P Determines the "Accumulated Total Time Since Beginning of Year" is beyond the Since Beginning of Year" is 93 Hr, 22 Min Acceptance Criteria specified in Step 5.0. versus 80 Hr, 22 Min.
6 Notify Shift Management of unsatisfactory P Reports to Shift Manager and/or Control test results. Room Supervisor that the "Accumulated Total Time Since Beginning of Year" is (Cue: Acknowledge report.) greater than 90 hours0.00104 days <br />0.025 hours <br />1.488095e-4 weeks <br />3.4245e-5 months <br />.
7 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.
PLOR256C Rev001 Page 4 of 5
Under "ACT" P - must perform 5 - must simulate I. TERMINATING CUE When the review of ST-0-007-560-2 has been completed, the calculation error on Data Sheet 1 identified, and the total accumulated time a purge/vent valve is open has been determined to be greater than 90 hours0.00104 days <br />0.025 hours <br />1.488095e-4 weeks <br />3.4245e-5 months <br />, the evaluator will terminate the exercise.
PLOR256C Rev001 Page 5 of 5
TASK CONDITIONS/PREREQUISITES
- 1. The "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log" for Unit 2 (ST-0-007-560-2) has been completed.
- 2. The "Accumulated Total Time Since Beginning of Year" is greater than 80 hours9.259259e-4 days <br />0.0222 hours <br />1.322751e-4 weeks <br />3.044e-5 months <br />.
Shift Management has been notified as required by Step 6.1.6.
INITIATING CUE You are the Work Control Supervisor. Complete the Plant Staff review and approval of ST 007 560-2, "Primary Containment PurgeNent Isolation Valve Cumulative Hour Log".
DATA SBEZT 1 6" AND 18" FLOW PATH TOTAL HOUR LOG Any 5" or 18' Flow Palh Open OR Req'd Conditions Palhs Closed OR ALL S' or 18' Flow Required Condilions Flow Palh OpenToIal Time Accumulated Tolal Time Since Beginning of Calendar Year (Note 1)
Accumulated Total Time Since Beginning of Calendar Year < 90 hrs Exist for riming No Longer Exisls with Valves Open (Hours &
Minutes)
Initial TIME DATE TIME DATE I Total Fwd: 61 Hr, 28 Min .§i!!.. Unsat
~
- 0131 12119/08 0411 12119,1)8 2 Hr,40Min 64 Hr, 8 Min R-C 0428 12119/08 2132 12119/08 5Hr, 4 Min 69Hr, 12 Min R-C 2147 12119/08 2319 12119/08 1Hr, 32 Min 70Hr, 44 Min R-C 0916 12123/08 1706 12123,1)8 7Hr, 50 Min 77Hr, 34 Min R-C 1154 12/24108 1442 12124,1)8 2Hr, 48 Min 80 Hr, 22 Min R-C R-C R-C R-C R-C R-C R-C
. R-C R-C R-C NOTE 1: IF "Accumulated Total Time Since Beginning of Year" greater than or equal to 80 hrs, THEN NOTIFY SMgt.
~~---- ~--------------------------
DATA SHEBT 2 DAY / SHIFT DATE FLOW PATHS USED Initial (See below) Sat Unsat 1 2 3 4 5 6 7 MON D 1211Bn:18 N/A N/A N/A N/A N/A N/A N/A N " N/A N/A ..J ..J ..J ~N/A TUE N
D
~ N/A N/A N/A N/A N/A
>J
..J
>J N/A
>J
~
>J N/A N/A WED D 12f.10108 N/A N/A N/A N/A N/A N/A N/A N " N/A N/A N/A N/A N/A N/A N/A THUR D 12f.ll108 N/A N/A N/A N/A N/A N/A N/A
- ~
N " N/A N/A N/A N/A N/A FRI 'D 12f.l2J08 N/A N/A N/A N/A N/A N " N/A N/A N/A N/A N/A N/A N/A SAT D 12f.l3108 N/A --J N/A N/A >J N/A N/A N " N/A N/A N/A N/P, N/A N/A N/A SUN D 12f.l4108 ..J >J N/A N/A >J v N/A N " N/A N/A N/A Nip, N/A N/A N/A
.... ~ ~
L AO-2-07B-2519 and AO-2-()'7B*":2520 OPEN in a Drywell N2 Purge Flowpath
- 2. AO-2-07B-2519 and AO-2-07B-Z521B OPEN in a Torus N2 Purge Flowpath
- 3. AO-2-07B-2505 and AO-Z-07B-2520 OPEN in a Drywell Purge Supply Flowpath
- 4. AO-2-07B-2521A and AO-2-07B-2521B OPEN in a Torus Purge Supply Flowpath
- 5. AO-2-07B-2506 and AO-2-07B-2507 OPEN in a Drywell Exhaust Flowpath
- 6. AO-2-07B-2511 and AO-2-07B-2512 OPEN in a Torus Exhaust Flowpath
- 7. Abnormal Flowpath.
Description:
____~---------------------------------------------------------------------
D Day Shift - 6:30a - 6:30p N Night Shift - 6:30p - 6:30a
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET
[))I Peach Bottom I DI Limerick I
~ JPM D QUALIFICATION MANUAL OJTMODULE LICENSED OPERATOR TRAINING PLOR-230C LICENSED OPERATOR REQUALIFICATION 002 J. T, Hanley jth EAL CLASSIFICATION WITH STATE AND LOCAL NOTIFICATIONS (FS1, wind from 0 degrees, airborne release in progress)
APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _ _,_ _ _ 0 _ __
NAME: ISSUE DATE:
Last First Mol.
EMPLOYEE 1.0. NO, COMPLETION DATE:
COMMENTS:
Trair}ing Review for Completeness: LMS CODE:
LMS ENTRY:
Signature/Date PLOR230C Rev002 P 1e 1 of 7
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: ' Senior Reactor Operator TASK-JPM DESIGNATOR: 2007540502 I PLOR-230C KIA: 2.4.40 SRO: 4.5 lTASK DESCRIPTION: Emergency Director A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "'n-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. . The task standard is met.
- b. . JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
PLOR230C Rev002.doc Page 2 of 7
B. TOOLS AND EQUIPMENT
- None C. REFERENCES
- 1. EP-AA-112-100, Rev. 10, "Control Room Operations"
- 2. EP-AA-111, Rev. 16, "Emergency Classification and Protective Action Recommendations"
- 3. EP-MA-114-100, Rev. 16, "Mid-Atlantic State/Local Notifications"
- 4. EP-MA-114-1 00-F-01, Rev K, "State/Local Notification Form
- 5. EP-AA-112-1 00-F-01, Rev. N, "Shift Emergency Director Checklist"
- 6. EP-AA-1007, Table PBAPS 3-1, Rev. 22, "Emergency Action Level (EAL) Matrix
- 7. EP-AA-114-F-02, Rev. A, "BWR Release in Progress Determination Guidance"
- 8. EP-AA-125-1002, Rev 007, "ERO Performance - Performance Indicators Guidance" D. TASK STANDARD
- 1. Performance Location: Simulator
- 2. Satisfactory task completion is indicated when EP-MA-114-1 00-F-01, "State/Local Event Notification Form" has been completed accurately.
(NOTE: The criteria for accurate Event Notification form completion was derived from EP-AA-125-1002, Rev. 007, "ERO Performance - Performance Indicators Guidance".)
- 3. Estimated time to complete: TIME CRITICAL
- Event Classification: 15 minutes
- State/Local Notification Form: 13 minutes E. DIRECTIONS TO EXAMINEE When given the initiating cue, make the Emergency Classification and complete the State/Local Notifications, if required. 'will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. A plant event occurred 15 minutes ago that resulted in damage to the reactor fuel on Unit 2.
- 2. A Main Steam Line (MSL) HI-HI radiation signal generated a Group I isolation signal.
PLOR230C Rev002 Page 3 of7
- 3. Six of the eight MSIVs closed.
- 5. A full reactor scram occurred; all rods are in.
- 7. 2 VENT EXH STACK RAD MONITOR HI-HI B (218 C-4) annunciator is in alarm.
- 8. Vent Stack release rate has been 4.5 E+6 uCi/sec for the last 15 minutes as read on RI 2979A and B.
- 9. A sample of the Reactor coolant has an activity of 265 uCilgm 1-131 dose equivalent.
- 10. A steam leak has just been identified in the Turbine Building.
G. INITIATING CUE As Emergency Director, make the EAL Classification, if required, and complete EP-MA-114 100-F-01, State/Local Notification Form.
PLOR230C Rev002 Page 4 of7
H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO
. *** NOTE "'***
Record the time using the clock above the Full Core Display. Time =
1 Obtain a copy of EP-AA-112-100-F-01 P Copies of EP-AA-112-100-F-01 and EP-and EP-AA-1007. AA-1007 are obtained.
- 2 Determine that the Vent Stack release P Radiological Effluent EAL RA 1 is rate is greater than the ALERT level reviewed. Vent Stack release rate is threshold but less than the SITE AREA determined to be above the ALERT level EMERGENCY level threshold. (>3.83 E+6 uCi/sec) but less than the SITE AREA EMERGENCY level <<3.36 E+7 uCi/sec).
- 3 Determine that the reactor coolant activity P Abnormal Rad Level EAL RU3 and level is greater than the UNUSUAL Fission Product Barrier Matrix is EVENT level but less than the threshold reviewed. Reactor Coolant activity is value for a LOSS of FUEL CLAD determined to be above the UNUSUAL BARRIER. - EVENT level (> 4.0 uCi/gm) but less than
- a FUEL CLAD BARRIER LOSS <<300 uCi/gm).
"'4 Determine that the failure of the "An MSL P The failure of the "An MSL to isolate to isolate exceeds the Fission Product exceeds the Fission Product Barrier Barrier Matrix thresholds resulting in a Matrix thresholds resulting in a LOSS of LOSS of both the REACTOR COOLANT both the REACTOR COOLANT SYSTEM SYSTEM BARRIER and the PRIMARY BARRIER and the PRIMARY CONTAINMENT BARRIER. CONTAINMENT BARRIER.
- 5 Using the Fission Product Barrier Matrix, P A SAE (FS1) is declared based on the identify that these losses constitute a two losses identified in the Fission SITE AREA EMERGENCY (SAE) Product Barrier Matrix.
declaration (FS 1) 6 Announce the event classification to the S SAE is announced.
facility staff.
- - NOTE *-*
Record the time using the clock above the Full Core Display. Time =
-* NOTE-*
Inform the examinee that the Public Address Announcement and the ERO Notification required by EP AA-112-100-F-01, Shift Emergency Director Checklist, are NOT required for this JPM.
- -NOTE-The following steps are associated with completion of EP-MA-114-1 00-F-01, "State/Local Event Notification Form."
PLOR230C Rev002 Page 5 of7
STEP STEP ACT STANDARD NO
- 7 Check the call status. P "This is a drill" line is checked in Block #1.
- 8 Check the affected station. P "Peach Bottom" is checked in Block #2.
- 9 Check the event classification. P "SITE AREA EMERGENCY" classification is checked in Block #3a.
- 10 Check the affected unit. P Unit "Two" is checked in Block #3b.
- 11 Enter the time and date of the P Declaration time (in 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> clock declaration. nomenclature) and today's date are entered in Block #3c. The declaration lime should match the time the examiner entered in the note before JPM step 1.
- 12 Check the applicable change in P "Inilial Declaration" is checked in Block classification status. #3d.
- 13 Enter the EAL number declared AND/OR P EAL# "FS1" is annotated in Block #4a provide a brief non-technical description AND a simplified explanation for the of event. event classification is provided in Block
- 4b. Acronyms, abbreviations or other terms that would not be recognized by state and local response agencies are avoided. The Offsite EAL Reference Manual may be referred to, if necessary.
- 14 Check the non-routine radiological P "Airborne" non-routine radiological release status. release in progress is checked in Block
- 5b. EP-AA-114-F-01, "Release in Progress Determination Guidance" may be referenced.
- 15 Enter the wind direction "degrees from." P "0" is entered as the wind direction degrees from in Block #6a.
(Cue: Wind direction is from 0 degrees.)
- 16 Enter the wind speed. P Wind speed is entered as "3" miles per hour in Block #6b.
(Cue: Wind speed is 3 mph.)
- 17 Check the utility Protective Action P 7a, NOT APPLICABLE is checked.
Recommendation.
I *18 Check the appropriate conclusion. P "This is a drill" line is checked in Block #8.
19 Approve the event notification form. P The event notification form is signed in the form's header area by the Emergency Director.
PLOR230C Rev002 Page 6 of7
STEP STEP ACT STANDARD NO
- NOTE ***
WHEN the examinee completes the Event Notification form, THEN record the time using the clock above the Full Core Display_ Time =
Determine if the elapsed time since the classification exceeds 13 minutes.
20 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material
- provided to the examinee (Task Conditions/Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When EP-MA-114-100-F-01, "State/Local Event Notification Form" has been completed, the evaluator will terminate the exercise.
PLOR230C Rev002 Page 7 of7
TASK CONDITIONS/PREREQUISITES
- 1. A plant event occurred 15 minutes ago that resulted in damage to the reactor fuel on Unit 2.
- 2. A Main Steam Line (MSl) HI-HI radiation signal generated a Group I isolation signal.
- 3. Six of the eight MSIVs closed.
- 4. The "A" MSl inboard and outboard MSIVs failed to close.
- 5. A full reactor scram occurred; all rods are in.
- 6. RPV level and pressure are normal, being maintained with
- 7. 2 VENT EXH STACK RAD MONITOR HI-HI B (218 C-4) annunciator is in alarm.
- 8. Vent Stack release rate has been 4.5 E+6 uCi/sec for the last 15 minutes as read on RI-2979A and B.
- 9. A sample of the Reactor coolant has an activity of 265 uCi/gm 1-131 dose equivalent.
- 10. A steam leak has just been identified in the Turbine Building.
INITIATING CUE As Emergency Director, make the EAl Classification, if required, and complete EP-MA-114-1 OO-F-01, State/local Notification Form.
EP-MA-114-100-F-01 Revision G Nuclear Page 1 of 3
- STATE/LOCAL EVENT NOTIFICATION FORM UTILITY MESSAGE NO. _ __
EMERGENCV DIRECTOR APPROVAL;,_________---'-_---'-_ _ __
PERFORM INITIAL ROLL CALL PRIOR TO TRANSMITTING - Refer to Page 3 of Fonn
- 1. CALL STATUS is: 2. This is _ _ _ _ _ _ _ _ _ __
[Xl This Is a DRILl. for [ ] LIMERICK I (Xl PeACH' BOTTOM I [
[ ] This is an ACTUAL EVENT. My phone number is ..,....,..._ _~___...,.-.,..
/Communicator will provide his/her NAME * .-n'-_""I::
TIME (in 24-hour clock) when notification is 3.a EMERGENCY CLASSIFICATION b. AFFECTED UNITtS) isfare:
[ ] UNUSUAL EVENT [ ] ONE [Xl 'TWO [ 1THREE
[ ] ALERT
[Xl SITE AREA EMERGENCY c. DECLARED AT:
[ ]GENERALEMERGENCY TI ME: ---'-...-....-..;....-o....J?~h,."jilV'....1
[ J RECOVERY LASSIFICATION STATUS
[ ] TERMINATION ing does NOT have to be exact.)
5.~---,--,--,-,
.' AU~BC)RNtli radiolOgiCal rel~e j~ress I9diiologlical release TERMINATED
- 6. METEOROLOGY is:
- a. WIND DIRECTION is FROM: _~O__
- _ _. (degrees)
- b. WIND SPEED is: ____-z;..3__ - _____ - (miles per hour)
DocUl" ) - 58.100
EP-MA-114-100-F-01 Revision G Page 2 of 3 STATE/LOCAL EVENT NOTIFICATION FORM
- 7. UTILITY PROTECTIVE ACTION RECOMMENDATION: (a 2! b) - No action should be taken until government officials have been notified: by State:
[X] a. NOT APPLICABLE (Unusual Event. Alert. Site AlBa Emergency. Tennination or Recovery only)
(Complete the following for Shelter or Evacuation for a General Ememency only for the applicable
[ ] b. The PROTECTIVE ACTION RECOMMENDATION (PAR) from the utility is:
] SHELTER 360 DEGREES FROM 0 MILES (SITE BOUNDARY) TO AND SHELTER THE FOLLOWING SECTORS FROM _ _
[]N []E S
( ] NNE [ ] ESE SSW
[ ) NE [ ] SE
[ ] ENE [ J SSE AND The utility recommends that government officials notify the ~11 **'(e potassium iodide (KI) for those sectors where shelter is recommended and of the EPZ to monitor EAS Messages.
[ 1 EVACUATE 360 DEGREES FROM 0 MI 5 MILES AND EVACUATE THE FOLLOWING 10 MILES:
[ ] N [ J [X] W
[ ] NNE [ ] [Xl WNW
[ ] NE [ 1 [Xl NW
[ ] ENE [ ] NNW AND officials notify the general public to take potassium iodide is recommended and advise remainder of the EPZ to o MILES (SITE BOUNDARY) TO _ _
government officials notify the general public to take potassium iodide shelter is recommended and advise remainder of the EPZ to monitor DEGREES FROM 0 MILES (SITE BOUNDARY) TO _ _ MILES recommends that government officials notify the general public to take potassium iodide areas where evacuation is recommended and advise remainder of the EPZ to EAS
- 8. [XlThis is a DRILL. [ 1This is an ACTUAL EVENT.
IrtFlrlRl1i FINAL ROLL CALL UPON COMPLETION - Refer to Page 3 of Fonn
- ASK if there are any questions regarding message or repeat backs needed
- READ "This concludes the notification message"
- INFORM the Shift Manager (Shift Emergency Director). TSC Director or EOF Director, as applicable. when notification is completed to required contacts.
Document Retention SR q (' - 5B.1 00
EP-MA-114-100-F-01 Revision G Page 3 of 3 STATE/LOCAL EVENT NOTIFICATION FORM "15 Minute Notifications" "15 Minute Notifications" PEACH BOTTOM (CAN 833) LIMERICK (CAN 841)
"Notification Line", Dial "833" for conference call. Stay on the
- line until agencies come on Initial Roll Call Final Roll Call "3 Digit Extensions". Make these calls from 3-digit lines. (Time Contacted: 24-hour clock) <..J)
"Commercial,. From PBAPS": Make these calls from a 4-digit line. Dial "9-1-Area Code-Number" "Commercial # From PBABS Higtt lines": Dial"7-1-9-1-Area Pennsylvania AD Ext. 116 or 9-1-800-424 Code-Number" 9-1-717-6 1 Initial Roll Call Final Roll Call (Time Contacted: 24-hour clock) (..J)
Montg Ext. 117.
Pennsylvania EMA D Ext. 216 or 9-1-800-424-7362 I 9-1-717-651-2001 Maryland EMA D Ext. 205 or 9-1-410-517-3600 York County D Ext. 219 or 9-1-717-854-5571 Harford County D Ext. 214 or 9-1-41 0-638-3400 I 9-1-410-638-4900 Cecil County ""'~-'"""'-:--:-'-"'"'-:':':!':'''=-' Dial the #'5 exactly Ext. 234 or 9-1-410-398-2222 Final Roll Call 9-1-410-392-201 (Time Contacted: 24-hour clock) (..J>
Pennsylvania EMA D Ext. 315 or 9-1-800-424-7362 or 9-651-2001 Cumberland County Ext. 319 or 9-238-9676,9-243-4121 or 9-532-8878 Lebanon County D Ext. 321 or 9-272-2025/-7621/-2054 Lancaster County Ext. 318 or 9-664-1190 /-1200 York County D Ext. 317 or 9-854-5571,9-840-2955 or of the Environment 9-1-800-427-8347 ext. 292 or 235 __ Dauphin County D 9-1-866-633-4686 Ext. 320 or 9-911 or 9-558-6900 at: (time: 24-hour clock) Initial Roll Call Completed
[ ] PA State Police, York Barracks Ext. 284 or 9-1-717-428-1011 FOLLOW-UP NOTIFICATIONS * (TMI)
Contacted at: (time: 24-hour clock)
[ ] York Haven Power Station 9-266-3654 or 9-818-3962
- NOT required within 15 minutes of Classification Contacted at: (time: 24-hour clock)
)- 5B.100
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET 01 Peach Bottom I DI Limerick I Common
~ JPM D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR TRAINING LICENSED OPERATOR REQUALIFICATION 000 J. A. Verbillis , jav HPSW Injection into the Fuel Pool (ALTERNATE PATH: HPSW Pump Overcurrent, Use Other Pump)
APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _ _'_ _ _.'_ __
NAME: . ISSUE DATE:
Last First M.1.
EMPLOYEE I.D. NO. COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMS CODE:
LMS ENTRY:
Signature/Date Page 1 of 8
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2770390401 / PLOR-376CA KIA: 233000A2.02 RO: 3.1 SRO: 3.3 TASK DESCRIPTION: HPSW Injection into the Fuel Pool A. . NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. ' When performing "In-Plant" JPMs, no equipment wm be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. ..IPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph D.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph D.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
Page 2 of 8
B. TOOLS AND EQUIPMENT
- 1. Keys for MO-174 and MO-176 C. REFERENCES Procedure AO 32.3-2, Rev. 2, HPSW Injection into the Fuel Pool D. ' TASK STANDARD
- 1. Performance Location: Simulator
- 2. Satisfactory task completion is indicated when HPSW is injecting into the Fuel Pool via RHR using "B" HPSW pumps.
- 3. Estimated time to complete: ?? minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to inject HPSW into the Fuel Pool using the 2B HPSW pumps using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 2. All of the 4 KV busses are receiving power from the off-site startup source.
- 3. Unit 2 is in Mode 3.
- 4. 2B, D HPSW pumps are available.
- 6. Access is available to:
- Fuel Pool Service Water Booster Pump Area, Elev. 165', Reactor Bldg.
- North Isolation Valve Room, Elev. 135', Reactor Bldg.
- MCC E324-R-B, Elev. 135', Reactor Bldg.
- 7. Shift Manager has authorized delaying installation of Equipment Status Tags as permitted by Precaution 3.1 of the referenced procedure.
S. Unit 2 Reactor Operator has authorized use of B loop of HPSW for injection into the Fuel Pool.
Page 3 of8
G. . INITIATING CUE The Control Room Supervisor directs you to inject HPSW into the Fuel Pool using the "S" Loop of HPSW per AO 32.3-2, "HPSW Injection into the Fuel Pool", starting at Step 4.1.
Page 4 ot8
H. PERFORMANCE CHECKLIST TEP STEP ACT STANDARD NO 1 Verify 2BP035 "B RHR Pump" shutdown. P B RHR pump 2BP035 green light verified ON at panel 20C003 2 Verify 2DP035 "D RHR Pump" shutdown. P D RHR pump 2DP035 green light verified ON at panel 20C003 3 Verify 2BP042 "B HPSW Pump" P HPSW pump 2BP042 green light verified
, shutdown. ON at panel 20C003-02.
4 Verify 2DP042 "D HPSW Pump" P HPSW pump 2DP042 green light verified shutdown. ON at panel 20C003-02.
5 Verify MO-2-10-89B, 2B HPSW HX Outlet P MO-2-10-89B, green light verified ON at valve closed. panel 20C003.
6 Verify MO-2-10-89D, 2D HPSW HX Outlet P MO-2-10-89D, green light verified ON at valve closed. panel 20C003.
7 Verify MO-2-10-0398, "Torus Header P MO-2-10-0398, green light verified ON at Valve" closed. pane120C003.
8 Verify MO-2-10-025B, "LPCI Injection P MO-2-10-0258, green light verified ON at Valve" closed. panel 20C003 .
9 Verify MO-2-1 0-026B, "Containment Spray P MO-2-10-026B, green light verified ON at Valve" closed. panel 20C003.
- NOTE ***
Procedure requires MO-013B(D) be "verified" closed - since the normal position is OPEN, the candidate is expected to use the definition of the word "verified" as direction to manipulate the valve. A short discussion of this with supervision would be expected, and the Evaluator should role playas required without cuing the candidate.
- 10 CLOSE MO-2-10-013B, "B RHR Suction P Key is obtained from SSV key box and Valve". inserted into the MO-2-10-13B keylock switch. Key lock switch is taken to the CLOSED position.
11 Verify MO-2-1 0-013B, "8 RHR Suction P MO-2-1 0-013B, green light verified ON at Valve" closed. panel 20C003.
Page 5 of 8
STEP. STEP ACT STANDARD NO 12 Verify MO-2-10-015B, "B RHR Suction P MO-2-10-015B, green light verified ON at Valve" closed. pane120C003.
- Valve". inserted into the MO-2-1 0-130 keylock switch. Key lock switch is taken to the CLOSED position.
14 Verify MO-2-1 0-0130, "0 RHR Suction P MO-2-10-013D, green light verified ON at Valve" closed. panel 20C003.
15 Verify MO-2-10-015D, "0 RHR Suction P MO-2-10-015D, green light verified ON at Valve" closed. panel 20C003.
16 Verify MO-2-32-2344 (10-186) "HPSW P MO-2-32-2344 (10-186), green light Loop Cross Tie" closed. verified ON at panel 20C003-03.
- NOTE ***
~imulator Operator action is required for the following step.
17
- Direct an Operator to Close or Verify P Operator dispatched to manipulate valve Closed HV-2-10-70B, RHR Pressurizing as directed, candidate does not proceed Line Block Valve To RHR Loop B" until report of valve status is received.
18 Direct an Operator to Unlock and Open P Operator dispatched to manipulate valve HV-2-10-180, "RHR Discharge to Fuel as directed, candidate does not proceed Pool Block Valve" until report of valve status is received.
19 Direct an Equipment Operator to throttle P Operator dispatched to manipulate valve open throttle open EITHER as directed, candidate does not proceed HV-2-19-24457A OR HV-2-19-24457B, until report of valve status is received.
"RHR to Fuel Storage Pool Diffuser Block Valve"
- NOTE ***
- Simulator Operator action is required for the following step.
20 Direct an Equipment Operator to CLOSE P Operator dispatched to manipulate valve E324-R-B (3863), "Emerg Intertie Valve as directed, candidate does not proceed MO-2-10-176" until report of valve status is received.
21 Verify pOSition indication for MO-2-10-176, P MO-2-10-176, green light verified ON at "HPSW to RHR Emergency Outer Cross- panel 20C003-03 Tie" is ON at Panel 20C003-03.
PageS of 8
STEP STEP T STANDARD NO
- 22 Open MO-2-10-174, "HPSWI RHR Inner P Key is obtained from SSV keybox, Cross Tie" valve. inserted into MO-2-10-174, keylock switch and placed in the OPEN position at panel 20C003-03.
23 Verify MO-2-10-174, "HPSW/RHR Inner P MO-2-10-174, red light verified ON at Cross Tie" valve open. paneI20C003-03.
- 24 Open MO-2-1 0-176, "HPSW/RHR Outer P Key is obtained from SSV keybox, Cross Tie" valve. inserted into MO-2-10-176, keylock switch and placed in the OPEN position at panel 20C003-03.
25 Verify MO-4-10-176, "HPSW/RHR Outer P MO-2-10-176, red light verified ON at
- Cross Tie" valve open. panel 20C003-03 .
26 Notify Shift Management that the "B" P Notification made.
HPSW Loop Pre-injection lineup is complete.
27 Perform GP-15 evacuation of Reactor S GP-15 evacuation requirement recognized Bldg. and discussed with Evaluator.
- NOTE**
Alternate Path starts with next step.
- NOTE**
Whichever HPSW pump is initially selected for start will exhibit Overcurrent indications.
Candidate is expected to respond by tripping the pump. IF candidate fails to take this action, the pump will trip automatically after 60 seconds. Automatic trip will require Simulator Operator action to remove trip function from other HPSW pump.
28 Start the "2B" or "20" HPSW pump. P "2B" or "20" HPSW pump control switch is momentarily placed in the START position at paneI20C003-04.
29 Identify HPSW pump overcurrent P Recognizes ammeter indicates condition. overcurrent condition, acknowledges 225 E-5 or 226 E-3 pump overcurrent alarm.
30 Secure the running HPSW pump. P "2B" or "20" HPSW pump control switch is momentarily placed in the STOP position at paneI20C003-04.
Page 7 of 8
STEP STEP ACT STANDARD NO
- 31 Start the "28" or "20" HPSW pump. P "28" or "20" HPSW pump control switch is momentarily placed in the START position at panel 20C003-04.
32 Verify proper start of the running HPSW P HPSW pump red light is ON, pump motor pump. amps are -70 on ammeter 10A-A28(D).
33, Verify fuel pool level is rising by requesting S Candidate discusses need to monitor Fuel observation of fuel pool level or indirectly Pool level for effect of injection either by by monitoring Fuel Floor and/or Fuel Pool direct observation or by indirect Rad levels. observation using Rad levels as described in AO 32.3-2 Step 4.3.15. The candidate may discuss requirement to secure pump to control Fuel Pool level as described in Step 4.3.16.
34 Inform the Control Room Supervisor of P Task completion reported.
task completion.
35 As an evaluator ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND
. procedures .
Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When either the "28" or "2D" HPSW pump is injecting into the fuel pool, the Control Room Supervisor should be informed. The candidate should make effort to ascertain effect of HPSW injection per procedure guidance. The evaluator will then terminate the exercise.
Page 8 of 8
TASK CONDITIONS/PREREQUISITES
- 2. All of the 4 KV busses are receiving power from the off site startup source.
- 3. Unit 2 is in Mode 3.
- 4. 2B, D HPSW pumps are available.
- 6. Access is available to:
- Fuel Pool Service Water Booster Pump Area, Elev. 165', Reactor Bldg.
- North Isolation Valve Room, Elev. 135', Reactor Bldg .
- MCC E324-R-B, Elev. 135', Reactor Bldg.
- 7. Shift Manager has authorized delaying installation of Equipment Status Tags as permitted by Precaution 3.1 of the referenced procedure.
- 8. Unit 2 Reactor Operator has authorized use of B loop of HPSW for injection into the Fuel Pool.
INITIATING CUE The Control Room Supervisor directs you to inject HPSW into the Fuel Pool using the "B" Loop of HPSW per AO 32.3-2, "HPSW Injection into the Fuel Pool",
starting at Step 4.1.
AO 32.3-2 Rev. 2 Page 1 of 10 ESC:esc Exelon Nuclear Peach Bottom Unit 2 AO 32.3-2 HPSW INJECTION INTO THE FUEL POOL
- 1. 0 PURPOSE This procedure provides the instructions necessary to provide Fuel Pool injection using one or two HPSW pumps via the RHR/HPSW Cross-Tie when an actual or imminent condition exists for uncovering fuel in the Fuel Pool. CM-l 2.0 PREREQUISITES 2.1 Reactor in MODE 3, 4 OR 5.
2.2 HPSW pump(s) available.
2.3 RHR to FPC 16" Spool Piece installed (165 elev -Normally Installed) .
2.4 Access to Fuel Pool Service Water Booster Pump Area, Elev. 165', Reactor Bldg.
2.5 Access to North Isolation Valve Room AND MCC E324-R-B, Elev. 135', Reactor Bldg.
2.6 One MCR operator is required.
2.7 Two Equipment Operators are preferred.
3.0 PRECAUTIONS 3.1 An Equipment Status Tag (EST) will be installed on HV-2-19-24457A OR HV-2-19-24457B, "RHR to Fuel Storage Pool Diffuser Block Valve". Depending on the urgency of implementing this procedure, the EST may be installed later AND the appropriate step initialed out of sequence.
3.2 Locked valves shall be manipulated in accordance with OP-AA-108-103, "Locked Equipment Program".
AO 32.3-2 Rev. 2 Page 2 of 10 INITIALS 4.0 PERFORMANCE STEPS NOTES
- 1. Since Fuel Floor access may not be possible, maintaining Fuel Pool AND Fuel Floor Rad Levels below the High Radiation Alarm setpoint will ensure the Spent Fuel is submerged.
- 2. "B" AND "0" HPSW pumps are the preferred pumps for Fuel Pool injection. This allows injection without opening MO-2-32-2344(10-186), "HPSW Loop Cross Tie". However, the "An AND "C" HPSW pumps may be used if necessary.
4.1 "B" HPSW Loop System Pre-Injection Lineup (Preferred) 4.1.1 IF the "B" HPSW loop will be used for Fuel Pool injection, THEN perform Section 4.1 AND N/A Section 4.2.
Otherwise, N/A Section 4.1 AND proceed to Section 4.2 to inject with "A" HPSW loop.
4.1. 2 Verify the following RHR AND HPSW pumps are shutdown at Panel 20COO3:
0 2BP035, uB RHR Pump" 0 20P035, "0 RHR Pump" 0 2BP042, fiB HPSW Pump" 0 20P042, nO HPSW Pump"
AO 32.3-2 Rev. 2 Page 3 of 10 INIT 4.1. 3 Verify closed the following valves at Panel 20C003:
o MO-2-10-089B, "B HPSW Hx Out" o MO-2-10-089D, "0 HPSW Hx Out" o MO-2-10-039B, "Torus Header Valve" o MO-2-10-025B "LPCI Inj ection Valve" o MO-2-10 026B, "Containment Spray Valve" o MO-2-10-013B, "B RHR Pump Suction Valve" o MO-2-10-015B, "B RHR Pump Suction Valve" o MO-2-10-013D, "0 RHR Pump Suction Valve" o MO-2-10-015D, "0 RHR Pump Suction Va "
4.1.4 Verify closed MO-2-32 2344(10-186),
"HPSW Loop Cross Tie" at Panel 20C003-03.
4.1. 5 Direct an Operator to close OR verify closed HV-2-10-70B, "RHR Pressurizing Line Block Valve To RHR Loop B".
4.1. 6 Unlock AND open HV-2-10-180, "RHR Discharge to Fuel Pool Block Valve" located in North Isolation Valve Room.
4.1. 7 Direct an Operator to throttle open EITHER HV-2-19-24457A OR HV-2-19-24457B, "RHR to Fuel Storage Pool Diffuser Block Valve" (located on Reactor Bldg.
Elev. 165 1 near Fuel Pool Service Water Booster Pumps).
AO 32.3-2 Rev. 2 Page 4 of 10 INITIALS 4.1. 8 Attach an Equipment Status Tag to the valve opened in Step 4.1.7 stating "HV-2-19-24457A(B) is throttled open in accordance with AO 32.3-2".
4.1. 9 Direct an Operator to close E324-R-B (3863), "Emerg Intertie Valve MO-2-10-176".
4.1.10 Verify position indication for MO-2-10-176, "HPSW to RHR Emergency Outer Cross e" is ON at Panel 20COO 03..
4.1.11 Open the following valves using the keylock swi on Panel 20C003:
o MO-2 10-174, "HPSW to RHR Emergency Inner Cross-Tie" o MO-2-10-176, "HPSW to RHR Emergency Outer Cross-Tie" 4 A .12 Notify Shift Management the "B" HPSW Loop Pre-injection lineup is complete.
4.1.13 Perform GP-15, "Local Evacuation" for the Unit 2 Reactor Building due to potential flooding.
NOTE The following steps will inject using the "B" OR "0" HPSW Pumps injection. Before starting a HPSW pump that is being supplied by a Diesel Generator, ensure the load on the associated Diesel Generator is below 2,300 KW. CM-l 4.1.14 Start "B" OR "0" HPSW pump.
4.1.1.5 IF Fuel Pool Level cannot be verified, THEN monitor Fuel Floor AND Fuel Pool Radiation levels on Panel 20C010 during HPSW injection.
AO 32.3-2 Rev. 2 Page 5 of 10 INITIALS 4.1.16 Secure pump(s) as necessary to maintain Fuel Pool level above spent fuel by maintaining radiation Levels below the High radiation alarm setpoints AND minimize the overflow of Fuel Pool inventory to the Reactor Building.
4.2 "A" HPSW Loop System Pre-Injection Lineup CAUTION Shutdown Cooling will be unavailable if using this lineup.
4.2.1 Verify the following RHR and HPSW pumps are shutdown at Panel 20C003:
0 2BP035, "B RHR Pump" 0 20P035, "0 RHR Pump" 0 2AP042, !fA HPSW Pump" 0 2BP042, "B HPSW Pump" 0 2CP042, "c HPSW Pump" 0 20P042, "0 HPSW Pump"
AO 32.3-2 Rev. 2 Page 6 of 10 INITIALS 4.2.2 Verify closed the following valves at Panel 20C003:
0 MO-2-10-089A, "A HPSW Hx Out" 0 MO-2-10-089C, "c HPSW Hx Out" 0 MO-2-10-089B, "B HPSW Hx Out" 0 MO-2-10-089D, "0 HPSW Hx Out" 0 MO-2-10-039B, "Torus Header Valve" 0 MO-2-10-025B, "LPCI Injection Va "
0 MO-2-10-026B, "Containment Spray Valve" o MO-2-10-013B, "B RHR Pump Suction Valve" o MO-2-10-015B, "B RHR Pump Suction Valve" o MO-2-10-013D, "0 RHR Pump Suction Valve" o MO-2-l0-0l5D, "0 RHR Pump Suction Valve" 4.2.3 Open MO-2-32-2344(lO-186), "HPSW Loop Cross Tie" using its keylock switch at Panel 20C003-03.
4.2.4 Direct an Operator to ose OR verify closed HV-2-10-70B, "RHR Pressurizing Line Block Valve To RHR Loop B".
4.2.5 Unlock AND open HV-2-10-180, "RHR Discharge to Fuel Pool Block Valve" located in North Isolation Valve Room.
AO 32.3-2 Rev. 2 Page 7 of 10 INITIALS 4.2.6 Direct an Operator to throttle open EITHER HV-2-19-24457A OR HV-2-19-24457B, "RHR to Fuel Storage Pool Diffuser Block Valve" (located on Reactor Bldg.
Elev. 165' near Fuel Pool Service Water Booster Pumps).
4.2.7 Attach an Equipment Status Tag to the valve opened in Step 4.2.6 stating "HV-2-19-24457A(B) is throttled open in accordance with AO 32.3-2".
4.2.8 Direct an Operator to close E324-R-B (3863), "Emerg Intertie Valve MO-2-10-176".
4.2.9 Verify position indication for MO-2-10-176, "HPSW to RHR Emergency Outer Cross-Tie" is ON at Panel 20C003-03.
4.-2.10 Open the llowing valves using the keylock switches on Panel 20C003:
o MO-2-10-174, "HPSW to RHR Emergency Inner Cross-Tie" o MO-2-10-176, "HPSW to RHR Emergency Outer Cross-Tie" 4.2.11 Inform Shift Management the HPSW "A" Loop Pre-injection lineup is complete.
4.2.12 Perform GP-15, "Local Evacuation" for the Unit 2 Reactor Building due to potential flooding.
NOTE The following steps will inject using the "A" OR "C" HPSW Pump for injection. Before starting a HPSW pump that is to be supplied by a Diesel Generator, ensure the load on the associated Diesel Generator is below 2,300 KW. CM-l 4.2.13 Start "An OR "C" HPSW pump.
AO 32.3-2 Rev. 2 Page 8 of 10 INITIALS 4.2.14 IF Fuel Pool level cannot be verified, THEN monitor Fuel Floor AND Fuel Pool radiation levels on Panel 20C010 during HPSW injection.
4.2.15 Secure pump(s) as necessary to maintain Fuel Pool level above spent fuel by maintaining Radiation levels below the High Radiation alarm setpoints AND minimize the overflow of Fuel Pool inventory to the Reactor Building.
4.3 System Restoration 4.3.1 Shutdown the running HPSW Pump(s)aligned for injection.
4.3.2 Close OR verify closed MO-2-32-2344 (10-186) , "HPSW Loop Cross Tie" using its keylock switch at Panel 20C003-03.
IV 4.3.3 Open HV-2-10-70B, "RHR Pressurizing Line Block Valve To RHR Loop B".
IV 4.3.4 Close OR verify closed the following valves using the keylock switches on Panel 20C003:
a MO-2-10-174, "HPSW to RHR Emergency Inner Cross-Tie" IV o MO-2-10-176, "HPSW to RHR Emergency Outer Cross-Tie" IV
AO 32.3-2 Rev. 2 Page 9 of 10 INITIALS 4.3.5 Direct an Operator to close AND lock HV-2-10-180, "RHR Discharge to Fuel Pool Block Valve" located in North Isolation Valve Room.
IV 4.3.6 Direct an Operator to close OR verify closed HV-2-19-24457A AND HV-2-19-24457B, "RHR to Fuel Storage Pool Diffuser Block Valve" RB 165 Elv.
IV 4.3. 7 Remove Equipment Status Tag from HV-2-19-24457A OR HV-2-19-24457B.
4.3.8 Director an Operator to open breaker E324-R-B (3863), "Emerg Intertie Valve MO-2-10-176".
IV 4.3.9 Notify Shift Management the "B(A)" loop of HPSW (whichever was aligned for Fuel Pool injection) has been restored to normal lineup.
5.0 CONTROL STATIONS 5.1 20C003, Reactor And Containment Cooling And Isolation 5.2 20COIO, Process Radiation Monitor Board
AO 32.3-2 Rev. 2 Page 10 of 10
6.0 REFERENCES
6.1 P&ID M-361, Residual Heat Removal 6.2 P&ID M-315, High Pressure Service Water 6.3 CM-l, May 31, 2005 Letter from J.A. Benjamin (Exelon) to NRC on I.C.M. B.5.b compliance (T04584) 6.4 A1754609, MSOPS Scenario 2p (ECR 11-00133) 6.5 OP-AA-108-103, "Locked Equipment Program" 7.0 TECHNICAL SPECIFICATIONS 7.1 LCO 3.7.1 8.0 INTERFACING PROCEDURES 8.1 GP-15, "Local Evacuation"
PBAPS ALARM RESPONSE CARD WINDOW LOCATION ALARM WORDING A B C 0 E 1
0 2 HIGH PRESS SERVICE 3 X WATER PUMP OVERCURRENT 4
5' AUTOMATIC ACTIONS:
- 1. "0" High Pressure Service Water Pump may trip.
NOTE: This pump will NOT trip if only the Time Overcurrent Relay has energized.
OPERATOR ACTIONS:
- 1. IF the pump has NOT tripped, THEN check pump indicated amps (120 amps max) at Panel 20C003-02 AND remove the pump from service ASAP in accordance with SO 32.2.A-2, "High Pressure Service Water System Shutdown".
- 2. IF required by ON, OT I or TRIP procedures, THEN start other HPSW Pump(s) in accordance with SO 32.1.A-2, "High Pressure Service Water system Startup and Normal Operations".
- 3. Investigate cause of pump overcurrent.
- 4. Review Tech Specs.
CAUSE:
- 1. Motor overcurrent relay 150/151 actuated on:
- a. Time Overcurrent (alarm only)
- b. Instantaneous Overcurrent fault condition AND locked rotor
{pump trip}
ALARM SETPOINT: ALARM RESET:
- 1. Time Overcurrent: Variable (lS1/TOC)
- 2. Instantaneous Overcurrent: Fault Condition (1S1/IOC-A) AND Locked Rotor (151 / I OC - B ) MANUAL ACTUATING DEVICE(S}:
Overcurrent Alarm Relay lSlX-1804
REFERENCES:
ARC NUMBER: 226 E-238 SO 32.2.A-2 E-18S 20C203D E-3 M-l-S-65 SO 32.1.A-2 Rev. 1
+-------------------------------------------------------------------------+
P B A P S A L ARM RES P 0 N SEC A R D
+- -----------------------------------------------------------------------:
WINDOW LOCATION ALARM WORDING ABC D E
+--------------+ +------------------------------+
1:
+--+--+--+--+--:
2: :X : D
+--+--+--+--+--: HIGH PRESS 3: SERVICE
+--+--+--+:-+--: WATER PUMP 4: TRIP
+--+--+--+--+--:
5:
+--------------+ +------------------------------+
__________ ___ 1
+------------------------------------------_.----- --------
~
I AUTOMATIC ACTIONS:
"0" High Pressure Service Water Pump Trips
+------------------------------------------_._-----------------------------:
OPERATOR ACTIONS:
- 1. Verify "D" High Pressure Service Water Pump Tripped.
- 2. Notify Shift Management.
- 4. Dispatch an operator to investigate the cause of the pump trip.
- 5. Review Tech Specs for LCO.
+-------------------------------------------------------------------------:
CAUSE:
- 1. 150/151;.Motor Overcurrent Relay
- 2. 150G; Motor Ground Inst. Overcurrent Relay
- 3. 186BX-18; E-42 Bus Overcurrent Relay
- 4. 127X-18; E-42 Bus Undervoltage Relay
- 5. 186-18; E-42 Bus Differential Relay
- 7. Relay 10A-K62B energized due to HPSW Manual Override Switch (10A-S19B) in AUTO and 10A-K9B energized.
- 8. Breaker Prop Reset spring failure.
+--------------------------------------------------- ---------- --
ALARM SETPOINT: ALARM RESET:
N/A Rev. 0
+----------------------------------------------- ----
ACTUATING DEVICE(S):
"D" HPSW Pump Control Switch (152-1804) in UNORMAL : MANUAL AFTER START and "D" HPSW Pump circuit breaker open:
as proven by: 152-1804
- b :
+-----------------------------------------------------+-------------------:
REFERENCES:
ARC NUMBER: 226 E-238 E-185 20C203D E-2 E-188 I
I M-1-S-65 Rev.
+-------------------------------------------------------------------------+
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET each Bottom i!=:.....Il 1 Limerick I DI Common
~ JPM D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR TRAINING LICENSED OPERATOR REQUALIFICATION 000 M. J. Kelly mjk RAISE HPCI FLOW (ALTERNATE PATH - SUCTION VALVES FAIL TO AUTO SWAP ON LOW CST LEVEL)
APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _ _-,_ _-----:'_ __
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE NO. COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMS CODE:
LMS ENTRY:
Signature/Date Page 1 of6
EXELON NUCLEAR PEACH BOlTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2060250101/ PLOR-333CA KIA: 206000A2.09 URO: 3.5 SRO: 3.7 TASK DESCRIPTION: Transfer of HPCI Suction From CST To Torus A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
CR_Sys_b_JPM_RevOOO Page 2 of6
B. TOOLS AND EQUIPMENT None C. REFERENCES
- 1. Alarm Response Card 221 C-3. Rev. 4, Condensate Storage Tank level low-low
D. TASK STANDARD
- 1. Satisfactory task completion is indicated when HPCI flow has been raised to 5000 gpm and pump suction is manually transferred from the CST to the Torus (Torus suction valves open and CST suction valve closed) without adverse effects on RPV injection.
- 2. Estimated time to complete: 10 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to raise HPCI flowrate to 5000 gpm.
will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 2. RCIC IS isolated.
G. INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to raise HPCI flowrate to 5000 gpm.
Page 30f6
H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Raise HPCI Flow Rate to 5000 gpm. P The HPCI Flow Controller knob is adjusted in the clockwise direction to raise the flow rate setting from 4000 gpm to 5000 gpm.
- (Cue: The 'HPCI Flow Controller is now indicating 5000) 2 HPCI Flow is verified to rise toward 5000 P FI-2-23-108 is monitored to verify that the gpm. actual flow rate rises to 5000 gpm.
(Cue: The Flow Indicator is reading 5000 gpm.) i NOTE Approximately 15 seconds after flow has been raised to 4950 gpm, Annunciator 221 C-3 "CONDENSATE STOR TANK LEVEL LOW - LOW" will be received initiating the next part of the JPM.
3 Recognize the Condensate Storage Tank P Recognize by reporting annunciator 221 Low Level Condition alarm. C-3 is alarming indicating a Low CST Level condition.
(Cue: Report Annunciator 221 C-3 is alarming.)
4 Obtain a copy of Alarm Response Card P Candidate references ARC 221 C-3, 221 C-3. CONDENSATE STOR TANK LEVEL LOW- LOW.
5 Verify the Low CST Level Condition. P Candidate verifies that CST Level is low by referencing LR-2217 on 20C007A or lI-2217 OR LI-8453 on 20C004. (The (Cue: CST level is indicating 5 feet.)
candidate may also send an EO to verify level on lI-2210.)
- 6. Recognize that HPCI failed to P Candidate will recognize by reporting that automatically swap suction paths on low the HPCI suction path failed to CST level. automatically swap. (A RCIC suction swap is not required due to RCIC being isolated.)
(Cue: Acknowledge report.)
Page 4 of6
7 Obtain a copy of procedure SO 23.7.B-2 P A copy of procedure SO 23.7.B-2,
- OR "Transfer of HPCI Pump Suction from CST to Torus", is obtained. Steps 4.6 Implement auto actions of ARC 221 C-3.
through 4.9, OR The auto actions of ARC 221 C-3 should be referenced for transient conditions.
- 8 Open MO-2-23-057 HPCI Torus Suction P MO-2-23-057 control switch is valve. momentarily placed in the OPEN position then released at panel 20C004B.
(Cue: Acknowledge control switch operation.)
- 9 Open MO-2-23-058, HPCI Torus Suction P MO-2-23-058 control switch is
- valve. momentarily placed in the OPEN position
!then released at panel 20C004B.
(Cue: Acknowledge control switch operation. )
10 Verify MO-2-23-057 and MO-2-23-058, P MO-2-23-057 and MO-2-23-058 red lights HPCI Torus Suction valves are open. are verified ON, and green lights OFF at panel 20C004B.
(Cue: MO-57 and MO-58 red lights are on, green lights are off.)
11 Verify MO-2-23-017 Cond Tank Suction P Recognize that MO-2-23-017 failed to valve automatically closes when close as indicated by the green light MO-2-23-057 and MO-2-23-058 are full verified OFF and red light verified ON at open. - panel 20C004B.
(Cue: MO-17 green light is off, red light is on.)
- 12 Close MO-2-23-017, Cond Tank Suction P MO-2-23-017 control switch is valve. momentarily placed in the CLOSE position then released at pane120C004B.
(Cue: Acknowledge control switch operation.)
13 Verify MO-2-23-017, Cond Tank Suction P MO-2-23-017 green light is verified ON, valve is closed. and red light OFF at panel 20C004B.
I (Cue: MO-17 green light is on, red light is Page 50f6
off.)
14 Check Level Switches responsible for the P Direct that LS-2-23-74 and LS-2-23-75 be automatic swap. checked for proper operation due to the (Cue: Acknowledge direction.) failed auto transfer.
15 Inform Control Room Supervisor of task P Task completion reported.
completion.
(Cue: Acknowledge report.)
16 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the HPCI suction has been transferred to the Torus, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.
Page 6 of6
TASK CONDITIONS/PREREQUISITES
- 2. RCIC is isolated.
INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to raise the HPCI flowrate to 5000
, gpm.
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET I Peach Bottom I DI Limerick ID Comm"n II
~ JPM D QUALIFICATION MANUAL OJT MODULE Licensed Operator Training Licensed Operator Requalification 000 M. J. Kelly jav Reopen The Main Steam Isolation Valves After a GP I Isolation APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _---.;'____1_ __
NAME: ISSUE DATE:
Last First M.1.
EMP.LOYEE 10#: COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMSCODE:
LMS ENTRY:
Signature/Date Page 1 of 7
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2000800501/ PLOR-083C KIA: 239001A4.01 RO: 4.2 SRO: 4.0 TASK DESCRIPTION: Reopen the Main Steam Isolation Valves after a GP Iiso/ation A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" ..IPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift
~ Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
Page 2 of 7
B. TOOLS AND EQUIPMENT None C. REFERENCES Procedure T-221-2, Rev. 10, "Main Steam Isolation Valve Bypass" D. TASK STANDARD
- 1. Satisfactory task completion is indicated when Inboard MSIVs are open.
- 2. Estimated time to complete: 10 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to reopen the MSIVs using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. Use of this procedure has been directed by the TRIP procedures.
- 2. Main Condenser is available.
- 3. RPV level is known.
- 4. There is no indication of gross fuel failure.
- 5. There is no indication of a Main Steam Line break.
- 6. All T-221 Tool Packages have been obtained.
- 7. Inboard and Outboard MSIVs are closed.
- 8. Steps 4.1 thru 4.5 of T-221-2, "Main Steam Isolation Valve Bypass" are cornplete.
G. INITIATING CUE
- The Control Room Supervisor directs you to perform T-221-2, "Main Steam Isolation Valve Bypass" steps 4.6 through 4.12 in order to reopen the MSIVs.
Page 3 of7
H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Obtain a copy of procedure T -221-2. P A copy of procedure T-221-2 is obtained.
- 2 Open AO-2-02-086A "Aft Outboard MSIV. P AO-2-02-086A control switch is placed in the "AUTO/OPEN" position at panel 20COO3-01.
3 Verify AO-2-02-086A "A" Outboard MSIV P AO-2-02-086A red light is verified ON at is open. panel 20C003-01.
- 4 Open AO-2-02-0868 "8" Outboard MSIV. P AO-2-02-0868 control switch is placed in the "AUTO/OPEN" position at panel 20COO3-01 .
5 Verify AO-2-02-0868 "8" Outboard MSIV P AO-2-02-0868 red light is verified ON at is open. panel 20C003-01.
- 6 Open AO-2-02-086C "C" Outboard MSIV. P AO-2-02-086C control switch is placed in the "AUTO/OPEN" position at panel 20COO3-01.
7 Verify AO-2-02-086C "c" Outboard MSIV P AO-2-02-086C red light is verified ON at is open. panel 20COO3-01.
- 8- Open AO-2-02-086D "0" Outboard MSIV. P AO-2-02-0860 control switch is placed in the "AUTO/OPEN" position at panel 20C003-01.
9 Verify AO-2-02-0860 "0" Outboard MSIV P AO-2-02-086D red light is verified ON at is open. panel 20COO3-01.
- 10 Open MO-2-02-077, Outboard Main P MO-2-02-077 control switch is Steam Drain valve. momentarily placed in the "OPEN" position at panel 20COO3-03.
Page 4 of 7
STEP NO STEP ACT STANDARD 11 Verify MO-2-02-077, Outboard Main P MO-2-02-077 red light is verified ON at Steam Drain valve open. paneI20C003-03.
- 12 Open MO-2-02-074. Inboard Main Steam P MO-2-02-074 control switch is Drain valve. momentarily placed in the "OPEN" position at panel 20C003-03 .
13 Verify MO-2-02-074 Inboard Main Steam P MO-2-02-074 red light is verified ON at Drain valve is open. panel 20COO3-03.
14 Verify closed MO-2-02-079, Orifice 8ypass P MO-2-02-079 green light is verified ON at to Main Cndr valve. panel 20C003-03.
- 15 Open MO-2-02-078, Downstream Drain P MO-2-02-078 control switch is valve. momentarily placed in the "OPEN" position at panel 20C003-03 .
16- Verify MO-2-02-078 Downstream Drain P MO-2-02-078 red light is verified ON at valve is open. panel 20C003-03.
17 Observe pressure differential across the P Pressure differential across the Inboard Inboard MSIVs. MSIVs is determined using PI-2-06-090A(8)(C) at panel 20C005A, Determine the difference between Reactor and "Steam Line" PR-2865 at panel pressure on PI-2-06-090A(8)(C) and 20C008A.
"Steam Line" pressure on PR-2865 on panel 20C008A.
18 Verify differential pressure across the P Differential pressure across the inboard
. inboard MSIVs is less than 150 psid . MSIVs is verified less than 150 psig on PI-2-06-090A(8)(C) at panel 20C005A, and "Steam Line" PR-2865 at panel 20C008A.
Page 50f7
STEP NO STEP ACT STANDARD
- 19 Open AO-2-02-080A "A" Inboard MSIV. P AO-2-02-080A control switch is placed in the "AUTO/OPEN" position at panel
. 20C003-01 .
20
. Verify AO-2-02-080A "A" Inboard MSIV is P AO-2-02-080A red light is verified ON at open. panel 20C003-01.
- 21 Open AO-2-02-0808 "8" Inboard MSIV. P AO-2-02-0808 control switch is placed in the "AUTO/OPEN" position at panel 20C003-01.
22 Verify AO-2-02-0808 "8" Inboard MSIV is P AO-2-02-0808 red light is verified ON at open. paneI20COO3-01.
- 23 Open AO-2:-02-080C "C" Inboard MSIV. P AO-2-02-080C control switch is placed in
- the "AUTO/OPEN" position at panel 20COO3-01.
24 Verify AO-2-02-080C "C" Inboard MSIV is P AO-2-02-080C red light is verified ON at open. panel 20COO3-01.
- 25 Open AO-2-02-080D "0" Inboard MSIV. P AO-2-02-080D control switch is placed in the "AUTO/OPEN" position at panel 20COO3-01.
26 Verify AO-2-02-080D "0" Inboard MSIV is P AO-2-02-080D red light is verified ON at open. panel 20COO3-01.
27 Inform Control Room Supervisor of task P Task completion reported.
completion.
28 As an evaluator ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.
Page 6 of 7
Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When the MSIVs have been reopened, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.
Page 7 of 7
TASK CONDITIONS/PREREQUISITES
- 1. Use of this procedure has been directed by the TRIP procedures.
- 2. Main Condenser is available.
- 3. RPV level is known.
- 4. There is no indication of gross fuel failure.
- 5. There is no indication of a Main Steam Line break.
- 6. All T-221 Tool Packages have been obtained.
- 7. Inboard and Outboard MSIVs are closed.
- 8. Steps 4.1 thru 4.5 of T-221-2, "Main Steam Isolation Valve Bypass" are complete.
INITIATING CUE The Control Room Supervisor directs you to perform T-221-2, "Main Steam Isolation Valve Bypass" steps 4.6 through 4.12 in order to reopen the MSIVs.
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET
[))I Peach Bottom I Common
~~ JPM D QUALIFICATION MANUAL OJTMODULE LICENSED OPERATOR TRAINING LICENSED OPERATOR REQUALIFICATION 000 M. J. Kelly jav PERFORM CORE SPRAY B PUMP CAPACITY TEST FOR 1ST (Alternate Path Minimum Flow Valve Fails to Open)
APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _----:'_ _----:'_ __
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE ID#: COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMSCODE:
LMS ENTRY:
Signature/Date Page 1 of 8
EXELON NUCLEAR PEACH BonOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2090140101/ PLOR-335CA KIA: 209001A4.04 URO: 2.9 SRO: 2.9 TASK DESCRIPTION: Ability to manually operate and/or monitor Core Spray minimal flow valves in the control room A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room a/l perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
Page 2 of8
B. TOOLS AND EQUIPMENT
- 1. None C. REFERENCES
- 1. ST-0-014-212-2, Rev. 2, "Core Spray B Pump Capacity Test for 1ST' D. TASK STANDARD
- 1. Satisfactory task completion is indicated when it is recognized that the Core Spray 8 Pump. has no minimum flow protection, the pump is secured, and Core Spray B loop is returned to a normal standby lineup, as specified in the performance steps of ST-0-014 212-2, Section 6.0.
- 2. Estimated time to complete: 15 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to perform Core Spray 2B pump capacity test for 1ST using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQU ISITES
- 1. The plant is operating at 100% power.
- 2. An Equipment Operator is standing by in the 2B and 20 Core Spray Pump Rooms.
- 3. Communications are available between the Control Room, 28 and 20 Core Spray Pump Rooms, Band 0 Core Spray Pump Triangle Room, and Cable Spreading Room.
- 4. Core Spray pump 28 oil level is between the minimum and maximum lines on the sightglass.
- 5. Core Spray pump 2B static pump suction pressure is 6 psig.
- 6. All data recording will be performed (simulated) by a second operator.
- 7. 28 Core Spray pump flow (Computer point H056) is displayed on XI-80187E on the C03-04 panel and on TRIP Table left-side computer screen.
Page 3 of 8
G. INITIATING CUE The Control Room Supervisor directs you to perform Core Spray 28 Pump Capacity Test for 1ST in accordance with ST-0-014-212-2 (provided).
Provide examinee a copy of ST-0-014-212-2 with the following items completed:
- Section 1 of the cover page
- Procedure section 2.0, "Test Equipment"
- Procedure section 3.0, "Prerequisites" Page 4 of8
H.
- PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Complete step 6.1.1 of ST-O-014-212-2 P Places liN/A" at step 6.1.1 of ST-O-014 as "Not Applicable" 212-2.
2 Verify oil level in the 2B Core Spray pump P Places initials in "Sat" column of step is between the operating range minimum 6.1.2 of ST-O-014-212-2.
and maximum lines on sightglass.
3 Record static pump suction pressure from P Documents "6 psig" and places initials in PI-2-14-036B "2B Core Spray Pump "Sat" column of step 6.1.3 of ST-O-014 Suction Pressure". 212-2.
4 CLOSE MO-2-14-011B "Core Spray P MO-2-14-011 B control switch is Outboard Disch". momentarily placed in "CLOSE" at Panel 20COO3.
5 VERIFY CLOSED MO-2-14-011 B "Core P Verifies that MO-2-14-011 B green light is Spray Outboard Disch". ON; red light is OFF at PaneI20COO3.
- NOTE: ****
If this JPM is being performed in parallel with another JPM, direct candidate - NOT to make the plant page announcement prior to starting 28 Core Spray pump.
- 6 START 2BP037 "Core Spray B Pump". P "Starting 2B Core Spray pump" is
, announced on plant page prior to starting Core Spray pump 2B.
2B Core Spray pump control switch is momentarily placed in the "START" position at PaneI20COO3.
7 VERIFY Core Spray 2B Pump STARTS P 2B Core Spray pump green light is and is RUNNING by observing motor verified OFF, red light is verified ON.
current on 14A-M1 B and discharge Pump motor amps on ammeter 14A-M 1B pressure on PI-2-14-048B "Core Spray and discharge pressure on PI-2-14-048B Disch P". are verified rising at Panel 20COO3.
8 VERIFY MO-2-14-00SB "Core Spray B P MO-2-14-005B green light is verified Min Flow" automatically OPENS. OFF; red light is verified ON at Panel 20COO3.
Page 5 of 8
STEP NO STEP ACT STANDARD 9 VERIFY 2DP037 "Core Spray D Pump" is P Directs Equipment Operator to verify NOT rotating. Core Spray D Pump is NOT rotating.
- 10 OPEN MO-2-14-0268 "Core Spray Full P MO-2-14-0268 control switch is Flow Test": momentarily placed in "OPEN" at Panel 20C003.
11 VERIFYOPEN MO-2-14-0268 "Core P MO-2-14-0268 green light is verified Spray Full Flow Test". OFF; red light is verified ON at Panel 20C003.
12 VERIFY MO-2-14-0058 "Core Spray 8 P MO-2-14-0058 green light is verified ON; Min Flow" automatically CLOSES. red light is verified OFF at Panel 20C003.
- NOTE: ****
Time-compress by telling the examinee Core Spray B Pump has been running for 5 minutes.
Remind examinee that a second operator has successfully recorded all full flow test data on Data Sheet 1.
- NOTE: ****
The Alternate Path portion of this JPM begins with the next step.
13 THROTTLE MO-2-14-0268 "Core Spray P MO-2-14-0268 control switch is Full Flow Test" to obtain Rated Flow of momentarily placed in "CLOSE" at Panel 3125 to 3175 gpm as read on computer 20C003. Red pushbutton is depressed to point H056. stop valve stroke. Attempt made to operate valve control switch and red pushbutton to achieve 3125 to 3175 gpm as read on PMS computer point H056.
Recognizes that the MO-2-14-0268 has ramped close unexpectedly and that the green closed light is ON and that the red open light is verified OFF at Panel 20C003.
Report to the CRS that the MO-2-14 0268 full flow test valve for the 28 Core Spray Pump has failed to properly operate Page 6 of 8
STEP NO STEP ACT STANDARD 14 VERIFY MO-2-14-00S8 "Core Spray 8 P Recognizes that the MO-2-14-00S8 green
- light is ON; red light is OFF at Panel Min Flow" automatically OPENS.
. 20C003. The Min. Flow Valve has not automatically opened.
Report to the CRS that the minimum flow valve for the 28 Core Spray Pump has failed to properly operate.
Page 7 ot8
- - NOTE: ***
IF after 2 minutes, a flowpath is not established AND the Core Spray pump has not been secured, THEN the Simulator Operator will TRIP the Core Spray pump, resulting in inability to successfully complete the critical step and the candidate will FAIL this JPM.
- 15 SHUTDOWN 28P037 "Core Spray 8 P 28 Core Spray pump control switch is Pump". momentarily placed in the "STOP" position at Pane120C003.
MO-2-14-0268 "Core Spray Full Flow Test". 28 Core Spray pump green light is verified ON, red light is verified OFF.
. Pump motor amps on ammeter 14A-M18
- and discharge pressure on PI-2-14-0488 are verified at zero at Panel 20C003.
OR MO-2-14-0268 control switch is momentarily placed in "OPEN" at Panel 20C003. Verifies valve is full open.
16 Inform Control Room Supervisor of task P Control Room Supervisor notified MO-2 completion. 14-0268 malfunction and test being aborted.
17 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task
- Conditions/Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When it is recognized that the Core Spray 8 Pump has no minimum flow protection and the pump is secured, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.
Page 8 of8
. TASK CONDITIONS/PREREQUISITES
- 1. The plant is operating at 100% power.
- 2. An Equipment Operator is standing by in the 28 and 20 Core Spray Pump Rooms.
- 3. Communications are available between the Control Room, 28 and 20 Core Spray Pump Rooms, 8 and o Core Spray Pump Triangle Room, and Cable Spreading Room.
- 4. Core Spray pump 28 oil level is between the minimum and maximum lines on the sightglass.
- 5. Core Spray pump 28 static pump suction pressure is 6 psig.
- 6. All data recording will be performed (simulated) by a second operator.
- 7. 28 Core Spray pump flow (Computer point H056) is displayed on XI-S01S7E on the C03-04 panel and on
. XI-S0190E at the TRIP Table left-side computer screen.
INITIATING CUE The Control Room Supervisor directs you to perform Core Spray 28 pump capacity test for 1ST in accordance with ST-O-014-212-2 (provided).
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET Peach Bottom imerick Common
[3J JPM D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR TRAINING LICENSED OPERATOR REQUALIFICATION 000 M. J. Kelly jav PERFORM A GROUP I PCIS ISOLATION RESET (GP-8A)
APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _______,_______,_ __
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE 10#: COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMSCODE:
LMSENTRY:
Signature/Date Page 1 of 8
EXELON NUCLEAR PEACH BOnOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: . Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2000490501 I PLOR-024C KIA: 223002A4.03 URO: 3.6 SRO: 3.5 TASK DESCRIPTION: Perform a Group I PCIS Isolation Reset GP-8A)
A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph D.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph D.2) is required.
- 5. 'The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
Page 2 of8
B.
- TOOLS AND EQUIPMENT Hand the Examinee a copy of C.O.L. GP-8.A with "As Found Position" column initials already filled in.
C. REFERENCES
- 1. Procedure GP-8.A, Rev. 10, "PCIS Isolation - Group I"
- 2. C.O.L. GP-8.A, Rev. 8, "Group I Isolation" D. TASK STANDARD
- 1. Satisfactory task completion is indicated when the PCIS Group I Isolation is reset.
- 2. Estimated time to complete: 8 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to reset the PCIS Group I isolation using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CON DITIONS/PREREQUISITES
- 1. The plant had been at 100% power.
- 2. A PCIS Group I isolation has occurred and has been verified to be a result of Main Steam tunnel high temperature.
- 3. The cause of the PCIS Group I isolation has been corrected, and the isolation signal is clear. 4
- 4. The plant is in a safe, stable shutdown condition.
- 5. CAV (Crack Arrest Verification) System is not in operation.
- 6. GP-8.A, "PC IS Isolation - Group I" steps 3.1 and 3.2 have been completed.
- 7. There is no indication offuel damage.
- 8. There is no evidence of a steam leak.
G. INITIATING CUE The Control Room Supervisor directs you to reset the PCIS Group I isolation logic per steps 4.1 through 4.4 ot GP-8.A, "PCIS Isolation - Group I".
Page 3 of 8
H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Obtain copies of procedures GP-8A P Copies of procedures GP-8A and and COL GP-8A. COL GP~8A are obtained.
- NOTE**
Provide examinee with the marked up COL GP-SA.
- 2 Place switch to "CLOSE" for P AO-2~02-080A control switch placed AO-2-02~080A. in the "CLOSE" position at panel 20C003-01.
3 Initial the AO-2-02-080A box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-080A initialed on COL GP-8A. GP-8A.
- 4 Place switch to "CLOSE" for P AO-2-02-080B control switch placed AO-2-02-080B. in the "CLOSE" position at panel 20C003-01.
5 Initial the AO-2-02-080B box in the P "CHECKED BY" column for
- 6 Place switch to "CLOSE" for P AO-2-02-080C control switch placed AO-2-02-080C. in the "CLOSE" position at panel 20C003-01.
7 Initial the AO-2-02-080C box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-080C initialed on COL GP-8A. GP-8A.
- 8 Place switch to "CLOSE" for P AO-2-02-080D control switch placed AO-2-02-080D. in the "CLOSE" position at panel 20C003-01.
9 Initial the AO-2-02-080D box in the P "CHECKED BY" column for
- 10 Place switch to "CLOSE" for P AO-2-02-086A control switch placed AO-2-02-086A. in the "CLOSE" position at panel 20C003-01.
Page 4 of 8
11 Initial the AO-2-02-086A box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-086A initialed on COL GP-8A. GP-8A.
~2 Place switch to "CLOSE" for P AO-2-02-086B control switch placed AO-2-02-086B. in the "CLOSE" position at panel 20COO3-01.
13 Initial the AO-2-02-086B box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-086B initialed on COL GP-8A. GP-8A.
- 14 Place switch to "CLOSE" for P AO-2-02-086C control switch placed AO-2-02-086C. in the "CLOSE" position at panel 20COO3-01.
15 Initial the AO-2-02-0S6C box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-086C initialed on COL GP-8A. GP-SA.
""'16 Place switch to "CLOSE" for P AO-2-02-0S6D control switch placed AO-2-02-086D. in the "CLOSE" position at panel 20COO3-01.
17 Initial the AO-2-02-0S6D box in the P "CHECKED BY" column for "CHECKED BY" column on COL AO-2-02-086D initialed on COL GP-8A. GP-8A 18 Verify switch in "CLOSE" for P AO-2-02-039 control switch verified AO-2-02-039. in the "CLOSE" position at panel 20COO4A.
19 N/A or initial the AO-2-02-039 box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-2-02-039 N/A'd or initialed on GP-SA COL GP-8A 20 Verify switch in "CLOSE" for P AO-2-02-040 control switch verified AO-2-02-040. in the "CLOSE" position at panel 20C004A 21 N/A or initial the AO-2-02-040 box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-2-02-040 N/A'd or initialed on GP-8A. COL GP-SA.
22 Verify switch in "CLOSE" for P AO-2-02-316 control switch verified AO-2-02-316. in the "CLOSE" position at panel 20COO3-03.
Page 5 of 8
23 N/A or initial the AO-2-02-316 box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-2-02-316 N/A'd or initialed on GP-8A. COL GP-8A.
24 Verify switch in "CLOSE" for P AO-2-02-317 control switch verified AO-2-02-317. in the "CLOSE" position at panel 20COO3-04.
25 N/A or initial the AO-2-02-317 box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-2-02-317 N/A'd or initialed on GP-8A. COL GP-8A.
26 Verify MO-2-02-074 is CLOSED. P MO-2-02-074 green light verified ON at panel 20COO3-03.
27 N/A or initial the MO-2-02-074 box in P "CHECKED BY" column for the "CHECKED BY" column on COL MO-2-02-074 N/A'd or initialed on GP-8A. COL GP-8A.
28 Verify MO-2-02-077 is CLOSED. P MO-2-02-077 green light verified ON at paneI20COO3-04.
29 N/A or initial the MO-2-02-077 box in P "CHECKED BY" column for the "CHECKED BY" column on COL MO-2-02-077 N/A'd or initialed on GP-8A. COL GP-8A.
30 Verify switch in "CLOSE" for P AO-8098A control switch verified in AO-8098A. the "CLOSE" position at panel 20COO3-04.
31 N/A or initial the AO-8098A box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL 8098A N/A'd or initialed on COL GP-8A. GP-8A.
32 Verify switch in "CLOSE" for P AO-809SC control switch verified in AO-809SC. the "CLOSE" position at panel 20COO3-04.
33 N/A or initial the AO-S09SC box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-S09SC N/A'd or initialed on COL GP-SA. GP-SA.
34 Verify switch in "CLOSE" for P AO-8099A control switch verified in AO-S099A. the "CLOSE" position at panel 20COO3-04.
35 N/A or initial the AO-S099A box in P "CHECKED BY" column for the "CHECKED BY" column on COL AO-8099A N/A'd or initialed on COL GP-SA. GP-SA.
Page 6 of8
36 Verify switch in "CLOSE" for P AO-S099C control switch verified in AO-S099C. the "CLOSE" position at panel 20C003-04.
37 N/A or initial the AO-S099C box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL S099C N/A'd or initialed on COL GP-SA. GP-SA.
3S Verify switch in "CLOSE" for P AO-S09SB control switch verified in AO-S09SB the "CLOSE" position at panel 20COO3-02.
39 N/A or initial the AO-S09SB box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL S09SB N/A'd or initialed on COL GP-SA. GP-SA.
40 Verify switch in "CLOSE" for P AO-S09SD control switch verified in AO-S09SD. the "CLOSE" position at panel 20C003-02.
41 N/A or initial the AO-S09SD box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL S09SD N/A'd or initialed on COL GP-SA. ,
GP-SA.
42 Verify switch in "CLOSE" for P AO-8099B control switch verified in AO-8099B. the "CLOSE" position at panel 20C003-02.
43 N/A or initial the AO-8099B box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL S099B N/A'd or initialed on COL GP-SA. GP-8A.
44 Verify switch in "CLOSE" for P AO-8099D control switch verified in AO-S099D. the "CLOSE" position at panel 20C003-02.
45 N/A or initial the AO-S099D box in P "CHECKED BY" column for AO the "CHECKED BY" column on COL 8099D N/A'd or initialed on COL GP-8A. GP-8A.
fi
-NOTE**
The C.O.L. steps for AO-2256 "Condenser Offgas to Mechanical Vacuum Pump (MVP)"
and the MVP are not required to be performed and can be marked as N/A.
Page 7 of8
- 46 Place the Inboard PCIS Reset P The Inboard PCIS Reset Switch is Switch, j 6A-S32, in the "GRP I" momentarily placed in the "GRP I"
- position. position at panel 20C005A .
- 47 Place the Outboard PCIS Reset P The Outboard PCIS Reset Switch is Switch, 16A-S33, in the "GRP I" momentarily placed in the "GRP I" position. position at panel 20C005A.
48 Verify "CHANNEL A and B GROUP I P The "CHANNEL A and B GROUP I ISOLATION RELAYS NOT RESEr' ISOLATION RELAYS NOT RESEr' annunciators clear. annunciators 211 H-1 and 211 J-1 are verified not lit.
49 Inform Control Room Supervisor of P Task completion reported.
task completion.
50 As an evaluator, ensure that you P Positive control established.
have positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND procedures.
Under "ACr' P - must perform S - must simulate I. TERMINATING CUE When the PCIS Group I isolation is reset, the Control Room Supervisor should be informed.
The evaluatoLwili then terminate the exercise.
Page 8 of8
TASK CONDITIONS/PREREQUISITES
- 1. The plant had been at 1000/0 power.
'2. A PCIS Group I isolation has occurred and has been verified to be a result of Main Steam tunnel high temperature.
- 3. The cause of the PCIS Group I isolation has been corrected, and the isolation signal is clear.
- 4. The plant is in a safe, stable shutdown condition.
- 5. CAV (Crack Arrest Verification) System is not in operation.
- 6. GP-S.A, "PCIS Isolation - Group I" steps 3.1 and 3.2 have been completed.
7~'There is no indication of fuel damage.
S. There is no evidence of a steam leak.
INITIATING CUE The Control Room Supervisor directs you to reset the PCIS Group I isolation logic per steps 4.1 through 4.4 of GP-S.A, "PCIS Isolation - Group I".
EXELON NUCLEAR Nuclear Generation Group OJTfTPE MATERIAL COVERSHEET
~ JPM D QUALIFICATION MANUAL D OJT MODULE LICENSED OPERATOR TRAINING LICENSED OPERATOR REQUALIFICATION 000 M. J. Kelly jav EXCITING THE MAIN GENERATOR APPROVALS:
Signature I Title Date Signature / Title Date Signature / Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _ _.1____1_ __
NAME: ISSUE DATE:
Last First M.1.
Employee ID NO. COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMS CODE:
LMS ENTRY:
Signature/Date Page 1 of 5
EXELON NUCLEAR PEACH BOTfOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 23701101011 PLOR-031C KIA: 262001A4.04 RO: 3.6 SRO: 3.7 TASK DESCRIPTION: EXCITING THE MAIN GENERATOR A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
,2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical ..IPMs, completion within double the estimated time (listed in paragraph D.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph D.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard. is not to be given to the examinee.
Page 2 of 5
B. TOOLS AND EQUIPMENT None C. REFERENCES Procedure SO 50.1.A-2 Rev. 16, "Main Generator Synchronizing and loading" (R)
D. TASK STANDARD
- 1. Performance Location: Simulator
- 2. Satisfactory task completion is indicated when the Main Generator is excited, generator termil1al voltage is adjusted to 22 KV, and the automatic voltage regulator is in service.
- 3. Estimated time to complete: 10 minutes (A5) Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to excite the Main Generator using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. Plant startup in progress with reactor power at approximately 18%.
- 2. All SO 50.1.A-2, "Main Generator Synchronizing and Loading" prerequisites are met.
- 3. The Power System Director has been notified.
G. INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor Operator, to excite the Main Generator and place the automatic voltage regulator in service in accordance with steps 4.1 through 4.10 of SO 50.1.A-2, "Main Generator Synchronizing and loading."
Page 3 of 5
H. PERFORMANCE CHECKLIST
~ STEP ACT STANDARD 1 Obtain a copy of SO 50.1.A-2. P A copy of SO 50.1.A-2 is obtained.
2 Verify "GENERATOR INSULATION OVER P "GENERATOR INSULATION OVER HEATINGIf annunciator is clear. HEATINGII annunciator is verified clear on
- alarm panel 206 L-2.
3 Verify the "Load Selector" pushbutton is P Load Selector REMOTE/AUTO light is selected to REMOTE/AUTO. verified ON at panel 20C008A.
4 Verify "ReglTransfer" switch 43-0601 in P Regulator Transfer switch 43-0601 is MANUAL. verified in the MANUAL position at panel 20C009.
5 Verify the Manual DC Volt Regulator P Manual DC Voltage Regulator 70-0601 70-0601 set at minimum. green and amber lights are verified ON at Panel 20C009.
6 Direct an Equipment Operator to P Equipment Operator is directed to periodically monitor machine gas pressure periodically monitor machine gas pressure on PI-4356: on PI-4356.
- 7 Close the "Alt Exc Fld Bkr"41-0601. P Alterrex Exciter Field Breaker control switch 41-0601 is momentarily placed in the CLOSE position at pane120C009.
8 Verify Field Volts, Amps and Generator P FIELD AMPS and VOLTS and Volts rise and red deexcitation backup GENERATOR VOLTS are verified to RISE light lit. and DEEXCITATION backup red light is verified ON and green light OFF at panel 20C009.
- 9 Adjust GENERATOR output voltage to P Manual DC Voltage Regulator 70-0601 is obtain 21.5 - 22.5 KV using MAN. DC adjusted to obtain a GENERATOR output VOLT REGULATOR 70-0601. voltage between 20.9 and 23.1 KVat panel 20C009.
10 Verify GENERATOR output voltage is P GENERATOR output voltage is verified between 21.5 - 22.5 KV. between 21.5 and 22.5 KV on GEN VOLTMETER at panel 20C009.
- 11 Adjust the "Auto Voltage Reg P Auto Voltage Reg Rheostat 90P is Rheostat"(90P) to obtain a "Reg Man/Auto adjusted to obtain a reading within 2 volts Deviation" voltage of 0 VDC. of 0 on the Reg Man/Auto Deviation meter at pane120C009.
Page 4 of 5
!STEP STEP ACT STANDARD NO ~
12- Verify "Reg Man/Auto Deviation voltage is P Reg Man/Auto Deviation voltage is verified 0VDC. to be 0 VDC on the Reg Man/Auto Deviation voltmeter at panel 20C009.
13 Verify "GEN VOL T REG AUTO TO MAN P lIGEN VOLT REG AUTO TO MAN UNBALANCED" annunciator is clear. UNBALANCED" annunciator is verified clear on alarm panel 220 C-3.
- 14 Place the "ReglTransfer" switch 43-0601 P ReglTransfer switch 43-0601 is placed in in "AUTO". the AUTO position at pane120C009.
15 Verify the "ReglTransfer" lights indicate P ReglTransfer red light is verified ON and auto regulation. green light verified OFF at pane120C009.
16 Verify generator speed control. P Candidate operates the Load Selector
- pushbuttons to Raise freq by 0.5 hz, then Lower freq by 0.5 hz (below initial value) then raise freq to initial value.
17 Verify generator voltage control. P Candidate operates the Auto Voltage Reg Rheostat to Raise voltage by 0.5 KV, then Lower voltage by 0.5 KV (below initial value) then raise voltage to initial value.
18 Inform the Control Room Supervisor of P Task completion reported.
task completion.
19 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material
. provided to' the examinee (Task Conditions/Prerequisites) AND procedures.
Under "ACT' P - must perform S - must simulate I. TERMINATING CUE When the Main Generator exciter field breaker is closed, the automatic voltage regulator is in service, and frequency and voltage control is verified, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.
Page 5 of 5
TASK CONDITIONSIPREREQUISITES
- 1. Plant startup in progress with reactor power approximately 18%.
- 2. All SO 50.1.A-2, "Main Generator Synchronization and Loading" prerequisites are met.
- 3. The Power System Director has been notified.
INITIATING CUE The Control Room Supervisor directs you, the Plant Reactor
. Operator, to excite the Main Generator and place the automatic voltage regulator in service in accordance with steps 4.1 through 4.10 of SO 50.1.A-2, "Main Generator Synchronization and Loading."
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET
~...!II Peach Bottom I JPM II QUALIFICATION MANUAL OJT MODULE Licensed Operator Requalification 000 Jav APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature f Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _-----:'_ _----',_ __
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE ID #: COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMS CODE:
LMS ENTRY:
Signature/Date Page 1 of 7
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2120090101/ PLOR-004C KIA: 212000A4.14 RO: 3.8 SRO: 3.8 TASK DESCRIPTION: SCRAM RESET A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. ...IPM Performance
- a. "Control Room" . .'PMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this . .'PM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
Page 2 of 7
B. TOOLS AND EQUIPMENT Key for Scram Discharge Volume High Level Bypass Switch.
C. REFERENCES GP-11.E, Rev. 21, "Reactor Protection System - Scram and ARI Reset" D. TASK STANDARD
- 1. Satisfactory task completion is indicated when the Reactor Protection System is reset and the Scram Discharge Volume Vent and Drain valves are open.
- 2. Estimated time to complete: 19 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to reset a scram and begin draining the Scram Discharge Volume using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F..,IASK CONDITIONS/PREREQUISITES
~ ...~'
- 1. A Main Turbine trip has caused a reactor scram.
- 2. Plant conditions have stabilized with RPV level at 23 inches.
- 3. RPV pressure is being maintained below 1050 psig with Bypass Valves.
- 4. T-100, "Scram" is complete.
- 6. A CRD pump is operating.
- 7. Both RPS buses are energized.
- 8. The Reactor Mode switch is in "SHUTDOWN".
- 9. ARI was NOT initiated.
- 10. No fuel damage is suspected.
G. INITIATING CUE The Control Room Supervisor directs you to reset the scram in accordance with GP-11.E, "Reactor Protection System - Scram and ARI Reset" and begin draining the Scram Discharge Volume.
Page 30f7
H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD 1 Obtain a copy of GP-11.E, "Reactor P A copy of GP-11. E, "Reactor Protection
. Protection System - Scram and ARI System - Scram and ARI Reset" is Reset". obtained.
- NOTE: -
Due to initial conditions, the examinee will begin at procedure step 3.6 2 Verify scram initiating signal clear or P "TURBINE STOP VLV. CLOSURE AND bypassed. CONTROL VLV. FAST CLOSURE SCRAM BYPASS" annunciator is verified lit on alarm panel 210 A-2.
- 3 Place Scram Discharge Volume High P Key is obtained from CRS keybox, Water Level Bypass Keylock Switch to inserted into the Scram Discharge Volume "BYPASS". High Water Level Bypass Keylock Switch 5A-S8 and placed in the "BYPASS"
- position at panel 20C005A.
4 Acknowledge the "SCRAM DISCHARGE P The annunciator "ACKNOWLEDGE" VOLUME HI WATER LEVEL SCRAM pushbutton is depressed on panel BYPASS" annunciator. 20C005A.
5 Prior to resetting a full scram, notify P Contacts Rad. Protection personnel via Radiation Protection. radio, phone, or plant page.
- 6 Place Scram Reset switch in Group 1 and P Scram Reset switch 5A-S9 is taken to the 4 position then Group 2 and 3 position. "GROUP 1 & 4", and then "GROUP 2 & 3" positions at panel 20C005A.
- 7. Verify the four scram group white lights P All scram group white lights verified LIT on are lit on both the RPS cabinets. panels 20C015 and 20C017.
Page 4 of7
STEP NO STEP ACT STANDARD 8 Verify: P "A CHANNEL REACTOR AUTO SCRAM" "A CHANNEL AUTO SCRAM" and "B CHANNEL REACTOR AUTO SCRAM" "B CHANNEL AUTO SCRAM" and "A CHANNEL REACTOR MANUAL "A CHANNEL REACTOR MANUAL SCRAM" and SCRAM" "B CHANNEL REACTOR MANUAL "B CHANNEL REACTOR MANUAL SCRAM" SCRAM" annunciators are clear. annunciators are verified clear on alarm panels 211 B-1, 211 C-1, 211 D-1 and 211E-1.
9 . Monitor Scram Air header pressure. P Scram air header pressure is verified to be approximately 70 psig on PI-2-3-312 on pane120C124.
10 Verify "SCRAM VALVE PILOT AIR P "SCRAM VALVE PILOT AIR HEADER HEADER PRESS HI-LOW" annunciator is PRESS HI-LOW" annunciator is verified clear. clear on alarm panel 211 0-2.
11 Verify blue scram lights are off. P AI! blue scram lights are verified OFF on the Full Core Display.
- NOTE **
Steps 12 and 13 will take 20-30 minutes to clear.
12 Verify "ACCUMULATOR TROUBLE" lights P All "ACCUMULATOR TROUBLE" lights are clear. are verified clear on the Full Core Display.
13 Verify "CRD ACCUMULATOR LO PRESS P nCRD ACCUMULATOR LO PRESS HI HI LEVEL" annunciator is clear. LEVEL" annunciator is verified clear on alarm panel 211 E-2.
- NOTE **
Step 14 will take approximately 5 minutes to complete.
14 Verify CRD System Cooling Water flow is P CRD System Cooling Water flow is 55 - 65 gpm. verified to be 55 - 65 gpm on FI-2-03-306 on panel 20COO5A.
Page 5 of7
STEP NO STEP ACT STANDARD 15 Place the Rod Drift Alarm Reset switch to P Rod Drift Alarm Reset switch 3A-S7 is the "Reset" position. momentarily placed to the "RESET" position and then released at panel 20C005A.
16 Verify the rod drift alarm lights are clear. P All of the rod drift alarm lights are verified J
clear on the Full Core Display.
17 Verify "ROD DRI Fr' annunciator is clear. P "ROD DRIFT" annunciator is verified clear on alarm panel 211 D-4.
- 18 Place SDV Inboard Vent and Drain Valves P The SDV Inboard Vent and Drain Valve Switch, 5A-S14A, in "OPEN". control switch 5A-S 14A is momentarily placed in the "OPEN" position and then released at panel 20COO5A.
19 Verify the SDV Inboard Vent and Drain P SDV Inboard Vent and Drain Valves red Valves indicate open. lights are verified ON, at panel 20COO5A.
- 20 Place SDV Outboard Vent and Drain P The SDV Outboard Vent and Drain Valve Valves Switch, 5A-S14B, in "OPEN". control switch 5A-S14B is momentarily
, placed in the "OPEN" position and then
- released at panel 20COO5A.
21 Verify the SDV Outboard Vent and Drain P SDV Outboard Vent and Drain Valves red Valves indicate open. lights are verified ON. at panel 20C005A.
22 Inform Control Room Supervisor of task P Task completion reported.
completion.
23 As an evaluator ensure you have positive P Positive control established.
control of all exam material provided to the examinee (Task Conditions I Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simulate Page 6 of7
I. TERMINATING CUE When the scram is reset and the Scram Discharge Volume Vents and Drains are open, the
- Control Room Supervisor should be informed. The evaluator will then terminate the exercise.
P~ge 7 of 7
- TASK CONDITIONS/PREREQUISITES
- 1. A Main Turbine trip has caused a reactor scram.
- 2. Plant conditions have stabilized with RPV level at 23 inches.
- 3. RPV pressure is being maintained below 1050 psig with Bypass Valves.
- 4. T-100, "Scram" is complete.
- 6. A CRD pump is operating.
- 7. Both RPS buses are energized.
- 8. The Reactor Mode switch is in "SHUTDOWN".
- 9. "ARI was NOT initiated.
- 10. No fuel damage is suspected.
INITIATING CUE The Control Room Supervisor directs you to reset the scram in accordance with GP-11.E, "Reactor Protection System - Scram and ARI Reset" and begin draining the Scram Discharge Volume.
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET JPM D QUALIFICATION MANUAL OJT MODULE LICENSED OPERATOR REQUALIFICATION 000 J. E. McClintock jav VERIFY ISOLATION OF DRYWELL CHILLED WATER AND RBCCW (ALTERNATE PATH - RBCCW IS SUPPLYING DRYWELL CHILLED WATER LOADS)
APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _...............' _ _ _,_ __
NAME: ISSUE DATE:
Last First M.1.
Employee 10 NO . COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMS CODE:
LMS ENTRY:
Signature/Date Page 1 of6
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2130220401/ PLOR-310CA KIA: 400000 A4.01 RO: 3.1 SRO: 3.0 TASK DESCRIPTION: Verify Isolation of Drywell Chilled Water and RBCCW (Alternate Path RBCCW is Supplying Drywell Chilled Water Loads)
A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" J PM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. c When performing "In-Planf' JPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
Page 2 of6
B. TOOLS AND EQUIPMENT None C. REFERENCES GP-8.B, Rev. 18 "PCIS Isolation - Groups II and III" (R)
D. TASK STANDARD
- 1. Satisfactory task completion is indicated when all of the following valves are closed:
- Drywell Chilled Water isolation valves, MO-2200A & Band MO-2201A & B
- RBCCW isolation valves, MO-2373 and MO-2374.
- 2. Estimated time to complete: 12 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform step 3.5 of GP-8.B "PCIS Isolation - Groups II and III".
I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. The Reactor has just been scrammed.
- 2. The Drywell Chilled Water System has been shutdown due to system leakage.
- 3. RBCCW is supplying DWCW loads.
- 4. DWCW return header pressure is 10 psig.
- 5. Drywell pressure is approximately 17 psig.
G. INITIATING CUE The Control Room Supervisor directs you to perform step 3.5 of GP-8.B, "PCIS Isolation Groups II and III".
Page 30f6
H. PERFORMANCE CHECKLIST STEP -
NO STEP ACT STANDARD 1Tobtain a copy of procedure GP-8.B. P A copy of procedure GP-8.B is obtained.
2 Verify MO-20245 AND MO*20246 aligned P MO*20245 AND MO*20246 red "RX BLDG in the "RX BLDG CLG WATER" position. CLG WATER" lights are lit. MO-20245 AND MO-20246 red "CHILLED WATER" lights are out at Panel 20COO5A.
3 Calculate Corrected RBCCW Pressure P Indicated RBCCW pressure is checked, (CRP) by taking indicated RBCCW then 25 psig is subtracted to determine a pressure on PI-2350 - 25 psig. CRP of approximately 8 psig.
- NOTE**
. - Alternate Path starts with next step.
4 Compare Drywell pressure to Corrected P Corrected RBCCW Pressure (CRP) is RBCCW Pressure (CRP) to determine determined to be lower than PR-2508 or which pressure is greater. PR-4805 or PR-8102A(B) at panels 20COO3/20COO4C.
- 5 Trip BOTH Recirc pumps. P A and B Recirc "DRIVE MOTOR" breaker green lights are verified ON at panel 20COO4A.
- 6 Close MO-2200A, Drywell Chilled Water P MO-2200A control switch is momentarily Header Supply isolation valve. placed in the "CLOSE" position at panel 20C012 .
7
. Verify the MO-2200A, Drywell Chilled P MO-2200A green light is verified ON and Water Header Supply valve is closed. red light is verified OFF at pane120C012.
- 8 Close MO-2200B, Drywell Chilled Water P MO-2200B control switch is momentarily Header Supply isolation valve. placed in the "CLOSE" position at panel 20C012.
9 Verify the MO-2200B, Drywell Chilled P MO-2200B green light is verified ON and Water Header Supply valve is closed. red light is verified OFF at pane120C012.
== Page 4 of6
STEP NO STEP ACT STANDARD
- 10 Close MO-2201A. Drywell Chilled Water P MO-2201A control switch is momentarily Header Return isolation valve. placed in the "CLOSE" position at panel 20C012.
11 Verify the MO-2201A. Drywell Chilled P MO-2201A green light is verified ON and Water Header Return valve is closed. red light is verified OFF at panel 20C012 .
- 12 Close MO-2201 B, Drywell Chilled Water P .MO-2201 B control switch is momentarily Header Return isolation valve. placed in the "CLOSE" position at panel 20C012.
13 Verify the MO-2201 B, Drywell Chilled P MO-2201 B green light is verified ON and Water Header Return valve is closed. red light is verified OFF at panel 20C012.
- 14 Close MO-2373, RBCCW ISOL valve. P MO-2373 control switch is momentarily placed in the "CLOSE" position at panel 20C012.
15 Verify MO-2373, RBCCW ISOL valve is P MO-2373 green light is verified ON and
- red light is verified OFF at panel 20C012.
. closed.
- 16 Close MO-2374, RBCCW ISOL valve. P MO-2374 control switch is momentarily placed in the "CLOSE" position at panel 20C012.
17 Verify MO-2374, RBCCW ISOL valve is P MO-2374 green light is verified ON and closed. red light is verified OFF at panel 20C012.
Page 5 af6
STEP NO STEP ACT STANDARD 18 Verify all the Drywell cooler fans are P The following Drywell cooler fan green tripped. lights are verified ON at pane120C012:
- 2AV026A, 2AV026B
. 2 BV026A, 2BV026B 2CV026A, 2CV026B 2DV026A, 2DV026B 2EV026A, 2EV026B 2FV026A, 2FV026B 2GV026A, 2GV026B 19 Inform Control Room Supervisor of task P Task completion reported.
completion.
20 As an evaluator, ensure that you have P Positive control established.
positive control of all exam material provided to the examinee (Task Conditions/Prerequisites) AND
- procedures.
Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When step 3.5 of GP-8.B has been completed, the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.
Page 6 of6
TASK CONDITIONS/PREREQUISITES
- 1. The Reactor has just been scrammed.
- 2. The, Drywell Chilled Water System has been shutdown due to system leakage.
- 3. RBCCW is supplying DWCW loads.
- 4. DWCW return header pressure is 10 psig.
- 5. Drywell pressure is approximately 17 psig.
INITIATING CUE The Control Room Supervisor directs you to perform step 3.5 of GP-8.B, "PCIS Isolation - Groups II and III".
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET 01 Peach Bottom I I Limerick J Common I
~ JPM D QUALIFICATION MANUAL OJT MODULE Licensed Operator Requalification Licensed Operator Requalification 000 J. A. Verbillis mda Defeat Of RCIC Interlocks (Unit 3)
APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I TItle Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _----:'_ _----:'_ __
NAME: ISSUE DATE:
Last First M.1.
EMPLOYEE ID NO. COMPLETION DATE:
COMMENTS:
Trair,)ing Review for" Completeness: LMSCODE:
LMS ENTRY:
Signature/Date Page 1 of 7
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2005810599/PLOR-157P KIA: 217000 A4.07 URO: 3.9 SRO: 3.8 TASK DESCRIPTION: Defeat Of RCIC Interlocks (Unit 3)
A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when '00 system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" ..IPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. ,JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
Page 2 of7
B. TOOLS AND EQUIPMENT
- 1. T-251 Tool Package
- 2. EOP Tool Locker Key C. REFERENCES T-251-3, Rev. 5, "RPV Pressure Control Using RCIC" D. TASK STANDARD
- 1. Performance Location: Plant
- 2. Satisfactory task completion is indicated when relay contacts have been booted per Step 4.1.1 of T-251-3.
- 3. Estimated time to complete: 12 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to defeat Unit 3 RCIC interlocks using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. Unit 3 scrammed.
- 2. Use of this procedure has been directed by T-100 procedures.
- 4. RCIC is available.
G. INITIATING CUE The Control Room Supervisor directs you, the Equipment Operator, to perform Step 4.1 of T 251-3, "RPV Pressure Control Using RCIC".
Page 3 of7
~~---~~.----------
H. PERFORMANCE CHECKLIST STEP NO STEP ACT STANDARD
- 1 Obtain the key for the Emergency S Emergency Operating Procedure Tool Operating Procedure Tool Locker. Locker Key requested from WECS OR (Cue: When examinee requests EOP examinee identifies the location of the Tool Locker key from WECS OR WECS key box and its associated key.
examinee identifies the location of the WECS key-box and its associated key
- then evaluator should provide the EOP Tool Locker key.)
- 2 Open Emergency Operating Procedure P Tool Locker located on Radwaste Build ing Tool Locker and obtain T-251 Tool Kit. EI. 165' (near Unit 2 Remote Shutdown Panel) is unlocked, opened and T-251 (Cue: Equipment obtained.) Tool Kit is located.
- NOTE-**
When examinee locates tool kit, report that the tools to perform the procedure have been acquired. Provide the examinee with a copy of the T-200 procedure which corresponds to the tool kit that has been chosen. DO NOT allow equipment to be removed from the locker. Relock the locker before leaving the area.
- 3 Remove front cover from relay 13A-K1 on S The two front cover fasteners are turned
- Cable Spreading Room Panel 30C34 COUNTERCLOCKWISE until loose, front (front). cover is then pulled from the face of relay 13A-K1 at panel 30C34 [FRONT] in the (Cue: Cover is removed) Cable Spreading Room.
- 4 Boot contact 5-6 on relay 13A-K1. S The THIRD FROM THE RIGHT relay contact arm is moved away from its (Cue: Boot is installed.) mating contact and a boot from the tool kit is placed over the contact arm.
- 5 Boot contact 11-12 on relay 13A-K 1. S The FAR LEFT relay contact arm is moved away from its mating contact and a (Cue: Boot is installed.) boot from the tool kit is placed over the contact arm.
6 Replace fro.nt cover on relay 13A-K1. S Front cover is held in place while turning
- the two front cover fasteners (Cue: Cover is replaced.) CLOCKWISE until tight.
Page 4 of7
STEP NO STEP ACT STANDARD
- 7 Remove front cover from relay 23A-K 1 on S The two front cover fasteners are turned
. Cable Spreading Room Panel 20C39 (front).
COUNTERCLOCKWISE until loose, front cover is then pulled from the face of relay 23A-K 1 at panel 30C39 [FRONT] in the (Cue: Cover is removed.) Cable Spreading Room.
- 8 Boot contact 3-4 on relay 23A-K 1. S The SECOND FROM THE RIGHT relay contact arm is moved away from its (Cue: Boot is installed.) mating contact and a boot from the tool kit is placed over the contact arm.
9 Replace front cover on relay 23A-K 1. S Front cover is held in place while turning the two front cover fasteners (Cue: Cover is replaced.) CLOCKWISE until tight.
- 10 Remove front cover from relay 23A-K4. S The two front cover fasteners are turned COUNTERCLOCKWISE until loose, front (Cue: Cove'r is removed.) cover is then pulled from the face of relay 23A-K4 at panel 30C39 [FRONT] in the Cable Spreading Room.
- 11 Boot contact 5-6 on relay 23A-K4. S The THIRD FROM THE RIGHT relay contact arm is moved away from its (Cue: Boot is installed.) mating contact and a boot from the tool kit is placed over the contact arm.
12 Replace front cover on relay 23A-K4. S Front cover is held in place while turning the two front cover fasteners (Cue: Cover is replaced.) CLOCKWISE until tight.
13 Inform Control Room that initiation S Task completion reported using telephone interlocks for MO-3-13-021, MO-3-13-030 or GAI-TRONICS page system.
and MO-3-23-024 have been defeated to
~ allow RCIC* operation for pressure control. NOTE: Hand held radio is NOT to be used in the Cable Spreading Room.
(Cue: Control Room acknowledges report.)
14 As an evaluator ensure you have positive P Positive control established control of all exam material provided to the examinee (Task Conditions/Prerequisites)
AND procedures.
Under "ACT" P - must perform S - must simulate Page 50f7
I. TERMINATING CUE When Step 4.1.1 of T-251-3. "RPV Pressure Control Using RCIC" is complete. the Control Room Supervisor should be informed. The evaluator will then terminate the exercise.
Page 6 of 7
TASK CONDITIONS/PREREQUISITES
- 1. A fire has occurred in the 3A and 3C Emergency Battery Room.
- 2. The ADS valves do NOT currently have a long term pneumatic supply_
INITIATING CUE The Control Room Supervisor directs you to perform T-331-3 to install a bypass around the SV-9130A and SV-9130B valves.
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET
~.....!II Peach Bottom I 01 Limerick I Common
~ JPM D QUALIFICATION MANUAL OJT MODULE Licensed Operator Training LICENSED OPERATOR REQUALIFICATION 000 C. N. Croasmun cnc Bypass of SV-9130A and SV-9130B APPROVALS:
Signature I Title Date Signature I Title Date Signature I Title Date Signature I Title Date APPROVED FOR USE:
Signature I Title Date EFFECTIVE DATE: _ _----'I -----',---
NAME: ISSUE DATE:
last First M.1.
EMPLOYEE ID NO* COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMSCODE:
LMS ENTRY:
Signature/Date Page 1 ot6
EXELON NUCLEAR PEACH BOTTOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: Task# 2008450599/ PLOR-275P KIA: 218000 K4.04 RO: 3.5 SRO: 3.6 TASK DESCRIPTION: Perform EO Actions to Bypass SV-9130A&B, ADS Nitrogen Supply A. NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. "Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" JPMs, no equipment will be operated without Shift Management approval .
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. JPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph D.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
Page 2 of6
B. TOOLS AND EQUIPMENT
- 1. Copy of T -331-3 Area 31 Fire Guide Attachment 1 C. REFERENCES
- 1. T-331-3 Area 31 Fire Guide D. TASK STANDARD
- 1. Satisfactory task completion is indicated when a bypass around the SV-9130A & B valves has been installed ..
- 2. Estimated time to complete: 10 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform the necessary steps to install a bypass around the SV 9130A and SV-9130B valves using the appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. A fire has occurred in the 3A and 3C Emergency Battery Room.
- 2. The ApS valves do NOT currently have a long term pneumatic supply.
G. INITIATING CUE The Control Room Supervisor directs you to perform T-331-3 Attachment 1 to install a bypass around the SV-9130A and SV-9130B valves.
Page 3 of6
H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO 1 Obtain a cOpy of T -331-3 Attachment 1. S Copy of Attachment 1 obtained.
(Cue: Provide the candidate with a copy of T -331-3 Attachment 1.)
2 Obtain bypass line for SV-9130A. S Remove bypass line for SV-9130A from its holder on the wall.
(Cue: Bypass line has been removed.)
3 Remove FME plugs. S Remove FME plugs from the female Parker fittings on each end of the bypass (Cue: FME plugs have been removed.) line.
'It*'It* NOTE: -
Next two steps are not sequence dependant.
- 4 Install bypass line. S INSTALL one end of the bypass line on the Parker fitting downstream of HV-3 16A-33155A ("ADS Backup N2 Sup Test Tap Upstream of SV-3-16A-9130A") by (Cue: Bypass line INSTALLED.) matching the bypass line and test tap color codes.
- 5 Install bypass line. S INSTALL the other end of the bypass line on the Parker fitting downstream of HV-3 16A-33156A '{"ADS Backup N2 Sup Test Tap Dwnstrm of SV-3-16A-9130A") by (Cue: Bypass line INSTALLED.) matching the bypass line and test tap color codes.
- - NOTE: 'It"'**
. Next two steps are not sequence dependant.
- 6 Open Test Tap Isolation Valve to bypass S OPEN HV-3-16A-33155A "ADS Backup nitrogen around SV-9130A. N2 Sup Test Tap Upstream of SV-3-16A 9130A" by rotating the handwheel counter (Cue: Test Tap isolation valve OPEN.) clockwise to the full OPEN position.
- 7 Open Test Tap Isolation Valve to bypass S OPEN HV-3-16A-33156A "ADS Backup nitrogen around SV-9130A. N2 Sup Test Tap Dwnstrm of SV-3-16A 9130A" by rotating the handwheel counter (Cue: Test Tap isolation valve OPEN.) clockwise to the full OPEN position.
t Page 4 of6
STEP STEP ACT STANDARD NO 8 Verify nitrogen supply pressure. S VERIFY supply pressure is >85 psig on PI-9130, "ADS Backup Nitrogen Supply (Cue: PI-9130 is reading 92 psig.) Press" at RB SWel. 135'.
9 Notify the Control Room S Notify the Main Control Room that SV 9130A "ADS Backup Nitrogen A HDR (Cue: Control Room notified.) Supply to Drywell" bypass line is in service.
10 Obtain bypass line for SV-9130B. S Remove bypass line for SV-9130B from its holder on the wall.
(Cue: Bypass line has been removed.)
- 11. Remove FME plugs. S Remove FME plugs from the female Parker fittings on each end of the bypass (Cue: FME plugs have been removed.) line.
- - NOTE: **
Next two steps are not sequence dependant.
- 12 Install bypass line. S INSTALL one end of the bypass line on the Parker fitting downstream of HV-3 16A-33155B ("ADS Backup N2 Sup Test Tap Upstream of SV-3-16A-9130B") by (Cue: Bypass line INSTALLED.) matching the bypass line and test tap color codes.
- 13 Install bypass line. S INSTALL the other end of the bypass line
~
on the Parker fitting downstream of HV-3 16A-33156B ("ADS Backup N2 Sup Test Tap Dwnstrm of SV-3-16A-9130B") by (Cue: Bypass line INSTALLED.) matching the bypass line and test tap color codes.
- NOTE: ****
Next two steps are not sequence dependant.
- 14 Open Test Tap Isolation Valve to bypass S OPEN HV-3-16A-33155B "ADS Backup nitrogen around SV-9130B. N2 Sup Test Tap Upstream of SV-3-16A 9130B" by rotating the handwheel counter (Cue: Test Tap isolation valve OPEN.) clockwise to the full OPEN position.
- 15 Open Test,Tap Isolation Valve to bypass S OPEN HV-3-16A-33156B "ADS Backup
- nitrogen around SV-9130B . N2 Sup Test Tap Dwnstrm of SV-3-16A 9130B" by rotating the handwheel counter (Cue: Test Tap isolation valve OPEN.) clockwise to the full OPEN position.
Page 5 of6
STEP STEP ACT STANDARD NO 16 Verify nitrogen supply pressure. S VERIFY supply pressure is >85 psig on PI-9130, "ADS Backup Nitrogen Supply (Cue: PI-9130 is reading 92 psig.) Press" at RB SWet. 135'.
17 Notify the Control Room S Notify the Main Control Room that SV 9130B "ADS Backup Nitrogen A HDR (Cue: Con!rol Room notified.) Supply to Drywell" bypass line is in
- service .
18 As an evaluator ensure you have positive P Positive control established control of all exam material provided to the examinee (Task ConditionS/Prerequisites) AND procedures. I Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When a bypass has been installed around SV-9130A. and SV-9130B, the Control Room Supervisor should be informed, the evaluator will terminate the exercise.
Page 6 of6
TASK CONDITIONS/PREREQUISITES
- 1. A fire has occurred in the 3A and 3C Emergency Battery Room.
- 2. The ADS valves do NOT currently have a long term pneumatic supply.
INITIATING CUE The Control Room Supervisor directs you to perform T-331-3 to install a bypass around the SV-9130A and SV-9130B valves.
T-331-3 Rev. 3 Page 1 of 9 JPW: jpw Exelon Nuclear Peach Bottom Unit 3 T-331-3 AREA 31 FIRE GUIDE FOR FIRE IN:
Unit 3 3A and 3C Emergency Battery Rm.
1.0 PROTECTED EgUIPMENT 1.1 PROTECTED INSTRUMENTS RPV LEVEL LOCATION LI-3-02-3-085B 30COO5A LR-3-02-3-110B 30COO3-02 LI-3-02-3-113 30COO3-04 RPV PRESSURE LOCATION PI-3-06-090A 30COO5A PI-3-06-090B 30COO5A PR/LR-3-06-096 30COO5A PR/RR-3-2-3-404B 30COO3-01
- CST LEVEL LOCATION LI-3217 30COO4C LI-9453 30COO4C TORUS LEVEL LOCATION TORUS TEMP LOCATION LR/TR-9123B 30COO3-02 TIS-3-02-71B 30C124 LI-9027 30COO3-03 TRS-3-10-131 30COO4C DW PRESS LOCATION DW TEMP LOCATION PR-9102B 30COO3-02 PR/TR-5805 30C003-02 PR/TR-5805 30COO3-02
T-331-3 Rev. 3 Page 2 of 9 1.2 PROTECTED LEVEL CONTROL SYSTEMS AND INSTRUMENTS INST SYSTEM INSTRUMENT LOCATION FI-3-23-108
- BPCI SPI-5505 30C004B 1.3 PROTECTED PRESSURE CONTROL SYSTEMS NOTE Performance of Attachment 1, "Bypass of SV-9130A and SV-9130B" may be required to ensure a long term pneumatic supply to SRVs C and G.
SRVs C,G 1.4 TORUS COOLING SYSTEMS AND INSTRUMENTS J
INST SYSTEM INSTRUMENT LOCATION RBR BLoop Band D RHR FI- 10-139B 30COO3-02 Pumps BPSW BLoop FI-3-10-132B B HPSW Pump PI-3330B 30COO3-02 o HPSW Pump PI-3330D
T-331-3 Rev. 3 Page 3 of 9 1.5 AL~TE SBtJ'.rDOWN COOLING SYS'l'EMS AND INSTRUMENTS NOTES
- 1. The protected method of achieving cold shutdown uses the systems listed below in accordance with AO 10.12-3, "Alternate Shutdown Cooling".
- 2. If a Service Water pump is not operating, use of Core Spray pumps will require an ESW pump to be placed in service to provide cooling water to the motor oil cooler.
INST SYSTEM INSTRUMENT LOCATION RBR BLoop
£ and D RHR FI-3-10-139B 30C003-02 Pumps Core Spray B Loop FI-3-14-050B 30C003-02 Band D Core Spray Pumps 1.6 PROTECTED ELECTRICAL POWER SYS'l'EMS, ESW AND INSTRUMENTS SYSTEM EQUIPMENT El DIG Emergency E2 DIG DIGs E4 DIG
" E13 Bus 4KV E23 Bus E43 Bus INST SYSTEM INSTRUMENT LOCATION ESW PI-7465 00C026B A ESW Pump PI-0236A 00C026B
T-331-3 Rev. 3 Page 4 of 9 2.0 CONTINGENCY ACTIONS NOTES
- 1. Copies of T-300 Fire Guides are maintained in the fire supply cage (Unit 2 TB 165' by the RB entrance) and Radwaste 135' (Northeast corner of Room 239). Access to the fire supply cage requires a "CAT 143" key, which is available from the WECS key cabinet in the Main Control Room.
- 2. Security card readers may be impacted by the fire. Master Security keys are available in the Main Control Room and may be issued by the Shift Manager. Security Officer assistance may also be utilized.
2.1 IF a long term pneumatic supply to the ADS Valves is NOT in service, THEN PERFORM Attachment 1, "Bypass of SV-9130A and SV-9130B".
3.0 REFERENCES
3.1 Calculation PF-OOI6-031, "Fire Area 31 Fire Safe Shutdown Analysis" 3.2 Specification NE-0296, "Specification for Post Fire Safe Shutdown Program Requirements at Peach Bottom Atomic Power Station".
3.3 M-333, Sheet 2, P & I Diagram, Instrument Nitrogen 3.4 This procedure supersedes T-331 (U/3) and T-331 (U/3)
Attachment 1 4.0 ATTACHMENT 4.1 Attachment 1, "Bypass of SV-9130A and SV-9130B"
T-331-3 Rev. 3 Page 5 of 9 ATTACHMENT 1 (Page 1 of 5)
BYPASS OF SV-9130A and SV-9130B 1,..0 PURPOSE The purpose of this attachment is to provide instructions to align the Backup Instrument Nitrogen bottles to the ADS valves by installing a bypass line around SV-9130A, "ADS Backup Nitrogen A HDR Supply to Drywell" and SV-9130B, "ADS Backup Nitrogen B HDR Supply to Drywell". These instructions are used in the event that a fire prevents operation of SV-9130A and SV-9130B.
2.0 EQUIPMENT REQUIRED 2.1 None 3.0 PROCEDURE 3.1 SV-9130A Bypass Line Installation 3.1.1 REMOVE bypass line from its holder on wall.
Initials 3.1.2 REMOVE the FME plugs installed in the female Parker fittings on each end of the bypass line.
In 3.1.3 INSTALL bypass line on the Parker fittings downstream of the following valves, matching bypass line and test tap color codes:
o HV-3-16A-33155A, "ADS Backup N2 Sup Test Tap Upstream of SV-3-16A-9130A" o HV-3-16A-33156A, "ADS Backup N2 Sup Test Tap Dwnstrm of SV-3-16A-9130A"
T-331-3 Rev. 3 Page 6 of 9 ATTACHMENT 1 (Page 2 of 5) 3.1.4 OPEN the following test tap isolation valves to bypass nitrogen around solenoid valve SV-9130A:
o HV-3-16A-33155A, "ADS Backup N2 Sup Test Tap Upstream of SV-3-16A-9130A" Initials o HV-3-16A-33156A, "ADS Backup N2 Sup Test Tap Dwnstrm of SV-3-16A-9130A" 3.1.5 VERIFY supply pressure is above 85 psig on PI-9130, "ADS Backup Nitrogen Supply Press" at RB SW El. 135'.
I s 3.1.6 NOTIFY Control Room that SV-9130A, "ADS Backup Nitrogen A HDR Supply to Drywell" bypass line is in service.
T-331-3 Rev. 3 Page 7 of 9 ATTACHMENT 1 (Page 3 of 5) 3.2 SV-9130B Bypass Line Installation 3.2.1 REMOVE bypass line from its holder on wa Initials 3.2.2 REMOVE the FME plugs installed in the female Parker fittings on each end of the bypass line.
3.2.3 INSTALL bypass line on the Parker fittings downstream of the following valves, matching bypass line and test tap color codes:
o HV-3-16A-33155B, "ADS Backup Nz Sup Test Tap Upstream of SV-3-16A-9130B" Initials o HV-3-16A-33156B, "ADS Backup Nz Sup Test Tap Dwnstrm of SV-3-16A-9130B" Initials 3.2.4 OPEN the following test tap isolation valves to bypass nitrogen around solenoid valve SV-9130B:
o HV-3-16A-33155B, "ADS Backup Nz Sup Test Tap Upstream of SV-3-16A-9130B" Initials o HV-3-16A-33156B, "ADS Backup Nz Sup Test Tap Dwnstrm of SV-3-16A-9130B" Initials 3.2.5 VERIFY supply pressure is above 85 psig on PI-9130, "ADS Backup Nitrogen Supply Press" at RB SW El. 135'.
s 3.2.6 NOTIFY Control Room SV-9130B, "ADS Backup Nitrogen B HDR Supply to Drywell" Bypass Line is in service.
Initials
T-331-3 Rev. 3 Page 8 of 9 ATTACHMENT 1 (Page 4 of 5) 4.0 RETURN ~O NORMAL 4.1 SV-9130A Bypass Line Restoration 4.1.1 CLOSE HV-3-16A-33155A, "ADS Backup N2 Sup Test Tap Upstream of SV-3-16A-9130A".
Performer Initials/Date 4.1. 2 CLOSE HV-3-16A-33156A, nADS Backup N2 Sup Test Tap Downstrm of SV-3-16A-9130A".
Performer Initials/Date Date NOTE Bypass line is pressurized.
4.1.3 REMOVE bypass line from the Parker fittLngs downstream of HV-3-16A-33155A AND HV-3-16A-33156A.
Per I.V. Initials/Date 4.1.4 INSTALL FME plugs in the female Parker fittings on the bypass line.
I.V. Initials/Date 4.1.5 ATTACH bypass line to wall holder provided.
Performer Initials/Date 4.1.6 NOTIFY Control Room that bypass line around SV-9130A is removed.
Performer Initials/Date
T-331-3 Rev. 3 Page 9 of 9 ATTACHMENT 1 (Page 5 of 5) 4.2 SV-9130B Bypass Line Restoration 4.2. 1 CLOSE HV-3-16A-33155B "ADS Backup N2 Sup Test Tap Upstream of SV-3-16A-9130B".
Per 4.2.2 CLOSE HV-3-16A-33156B "ADS Backup N2 Sup Test Tap Dwnstrm of SV-3-16A-9130B".
Performer Initials/Date NOTE Bypass line is pressurized.
4.2.3 REMOVE bypass line from the Parker fittings downstream of HV-3-16A-33155B AND HV-3-16A-33156B.
Pe I.V.
4.2.4 INSTALL FME plugs in the female Parker fittings on the bypass line.
Per 4.2.5 ATTACH bypass line to wall holder provided.
Performer Initials/Date 4.2.6 NOTIFY Control Room that bypass line around SV-9130B is removed.
Performer Initials/Date
EXELON NUCLEAR Nuclear Generation Group OJTITPE MATERIAL COVERSHEET JPM D QUALIFICATION MANUAL OJTMODULE Licensed Operator Training Licensed Operator Requalification 000 J. T. Hanley jth Diesel Driven Fire Pump Manual Start (Alternate Path - Battery Status Lights Not Lit)
APPROVALS: J. A. Verbillis, Instructor lsI 1/20/12 Signature I TItle Date C. P. Breidenbaugh, SMS lsi 1/25/12 Signature / Title Date Signature I Title Date Signature I TItle Date APPROVED FOR USE: R. J. Artus for B. A. Hennigan. OTM lsI 2/27/12 Signature I TItle Date EFFECTIVE DATE: _--=2_..:.../_2=7,--.....:/_.....:1=2_
NAME: ISSUE DATE:
Last First M.1.
Employee 10. NO. COMPLETION DATE:
COMMENTS:
Training Review for Completeness: LMS CODE:
LMS ENTRY:
Signature/Date Page 1 of5
EXELON NUCLEAR PEACH BOnOM ATOMIC POWER STATION JOB PERFORMANCE MEASURE POSITION TITLE: Unit Reactor Operator/Senior Reactor Operator TASK-JPM DESIGNATOR: 2860080101 I PLOR-327PA KIA: 286000A4.06 RO: 3.4 SRO: 3.4 TASK DESCRIPTION: Diesel Driven Fire Pump Manual Start (Alternate Path - Battery Status Lights Not Lit)
A NOTES TO EVALUATOR:
- 1. An asterisk (*) before the step number denotes a CRITICAL STEP. CRITICAL STEPS are those steps which when not performed correctly will prevent the system from functioning properly or prevent successful task completion.
- 2. System cues included in the performance checklist are to be provided to the examinee when no system response is available.
- 3. JPM Performance
- a. -"Control Room" JPMs are designed to be performed in the simulator. If a "Control Room" JPM is to be performed in the Control Room all perform steps (P) shall be simulated (S).
- b. When performing "In-Plant" ..IPMs, no equipment will be operated without Shift Management approval.
- 4. Satisfactory performance of this JPM is accomplished if:
- a. The task standard is met.
- b. ...IPM completion time requirement is met.
- 1) For non-time critical JPMs, completion within double the estimated time (listed in paragraph 0.2) is acceptable provided the evaluator determines that the progress to completion is acceptable.
- 2) For time critical JPMs, completion within the estimated time (listed in paragraph 0.2) is required.
- 5. The estimated time to complete this JPM, though listed in the task standard, is not to be given to the examinee.
Page 2 of 5
- 8. TOOLS AND EQUIPMENT
- 1. Diesel Driven Fire Pump Room door key (#3702)
C. REFERENCES
- 1. SO 378.1.8 Rev 6, "Fire Water System Pump Manual Startup"_
D. TASK STANDARD
- 1. Satisfactory task completion is indicated when the Diesel Driven Fire Pump battery status circuit has been reset and the Diesel Driven Fire Pump has been started locally in accordance with SO 378.1.8, "Fire Water System Pump Manual Startup."
- 2. Estimated time to complete: 8 minutes Non-Time Critical E. DIRECTIONS TO EXAMINEE When given the initiating cue, perform necessary steps to locally start the Diesel Driven Fire Pump using appropriate procedures. I will describe initial plant conditions and provide you access to the materials required to complete this task.
F. TASK CONDITIONS/PREREQUISITES
- 1. Fire Water system is lined up for operation in accordance with SO 37.1.A, "Common Plant Fire Water System Lineup for Automatic Operations."
G. INITIATING CUE The Control Room Supervisor directs you, the Equipment Operator, to locally start the Diesel Driven Fire Pump in accordance with SO 378.1.8, "Fire Water System Pump Manual Startup."
Page 3 of 5
H. PERFORMANCE CHECKLIST STEP STEP ACT STANDARD NO 1 Obtain a copy of procedure SO 37B.1.B. P A copy of procedure SO 37B.1.B is obtained. Section 4.1 is referenced.
- - NOTE: ****
The Alternate Path portion of this JPM begins with the next step.
2 Verify blue "Battery Connected" lights are 5 Determine that Blue "Battery 'A' lit. Connected" and "Battery 'B' Connected" lights are NOT lit.
. (Cue: Blue-battery status lights are NOT lit.)
3 Notify Shift Management that Battery P Notifies Shift Management.
Connected lights are NOT lit.
(Cue: Acknowledge report) 4 Open the Panel OOC126 door. S Panel door handle is turned, and door pulled outward to gain access to the (Cue: Panel door is open.) DDFP controls inside Panel OOC126.
(Simulation is acceptable since the DDFP controls are visible through a window on the panel door.)
- 5 Turn the Diesel Driven Fire Pump Local 5 "Diesel Driven Fire Pump Local Control Control SW HS-O-37D- CS 1/12' to "OFF". SW HS-O-37D- CS1/12'" switch placed in
- "OFF" inside Panel OOC126.
- (Cue: Diesel Driven Fire Pump Local Control SW HS-O-37D- CS1/12'switch has been placed in "OFF".)
- 6 Momentarily depress the "RESET" 5 "RESET" pushbutton momentarily pushbutton. depressed inside Panel OOC126 (right hand side).
(Cue: "RESET" pushbutton has been depressed. )
7 Turn the Diesel Driven Fire Pump Local 5 Diesel Driven Fire Pump Local Control Control SW HS -O-37D-CS 1/12' to SW HS -O-37D-CS 1/12' switch placed in "AUTO". "AUTO" inside Panel OOC126.
(Cue: Control Selector switch has been placed in "AUTO". The blue "Battery Ready" lights are lit.)
Page 4 of 5
STEP STEP ACT STANDARD NO 8 Verify the blue "Battery A(B) Connected" S Determine that blue "Battery Ready" lights are lit. lights are lit (Cue: The blue "Battery Ready" lights are lit.)
- 9 Place the Diesel Driven Fire Pump Local S Inside Panel OOC 126, Diesel Driven Fire
- control switch HS-0-37D-CS1/12 in the "MANUAL A" or "MANUAL B" position Pump Local control switch HS-0-37D CS1/12 placed in the "MANUAL A" or and depress the "START" pushbutton "MANUAL B" position and the "START" pushbutton depressed (left hand side)
(Cue: Control switch manipulation is complete. Cylinder combustion noise is heard, DDFP engine speed rises to 1750 RPM as indicated on skid mounted panel and pump discharge pressure rises to 150 psig on PI-0290 near South wall of the DDFP.)
10 Place the Diesel Driven Fire Pump Local S Diesel Driven Fire Pump Local control control switch HS-0-37D-CS1/12 in the switch HS-0-37D-CS1/12 placed in the "TEST" position 'TEST" position
- (Cue: Control Selector switch has been placed in "TEST".)
11 Close the Panel OOC126 door. S Panel door is closed and relatched using handle.
(Cue: Panel door is closed and relatched. )
12 Inform Control Room Supervisor of task P Task completion reported using hand completion. held radio, telephone or GAI-TRONICS page system.
(Cue: Control Room Supervisor acknowledges report.)
13 As an evaluator, ensure you have positive P Positive control established.
control of all exam material provided to the examinee (Task Conditions I Prerequisites) AND procedures.
Under "ACT" P - must perform S - must simulate I. TERMINATING CUE When then Diesel Driven Fire Pump battery status circuit has been reset and the Diesel Driven Fire Pump has been locally started, then Control Room Supervisor should be informed. The evaluator will then terminate the exercise.
Page 5 of5
TASK CONDITIONS/PREREQUISITES Fire Water system is lined up for operation in accordance with SO 37.1.A, "Common Plant Fire Water System Lineup for Automatic Operations."
INITIATING CUE The Control Room Supervisor directs you, the Equipment Operator, to locally start the Diesel Driven Fire Pump in accordance with SO 378.1.8, "Fire Water System Pump Manual Startup."
Scenario Outline Simulation Facility Peach Bottom Scenario No. #1 OpTest No. 2013 NRC Examiners Operators CRS (SRO)
URO (ATC)
_ _ _ _ _ _ _ _ PRO (BOP)
Scenario The scenario begins with the reactor at 100% power.
Summary Following shift turnover, the crew will stroke Main Steam Sample Valves AO-2-02-316 and 317 as part of a surveillance test for primary containment isolation valves. Shortly after stroking the valves, Reactor Building to Torus vacuum breaker isolation valve AO-2502A will fail partially open requiring the crew to declare the valve inoperable per Technical Specifications.
Next, the running Service Water pump will trip on overcurrent. requiring the crew to place the standby pump in service using the system operating procedure. Following this, a drywell pressure instrument will fail upscale without causing the expected half scram. The crew will apply Tech Specs and (with time compression) insert a half scram lAW GP-25 "Installation of Tripsllsolations to Satisfy Tech SpecffRM Requirements" .
Next the 'A' Condensate pump will trip without the expected Recirc System runback. Power must be manually reduced using recirc flow to prevent a low-level scram.
When conditions have stabilized, #2 Auxiliary Bus will trip on overcurrent. causing a loss of the remaining Condensate pumps. HPCI and RCIC will initiate on low RPV leveL The HPCI system flow controller will fail in automatic and must be adjusted in manual to allow the system to inject. The HPCI system will trip shortly after it injects and will not be recoverable. An RPS failure will prevent the automatic and manual scrams, requiring entry into T-101 "RPV Control" and the use of Alternate Rod Insertion (ARI) to shutdown the reactor. A small Reactor coolant leak will occur in the drywell and require the use of containment sprays. The crew should enter T-102 "Primary Containment Control". A containment spray logic failure will complicate the crew's efforts to spray containment. The crew will not be able to spray containment with the initial loop of RHR selected. The other loop of RHR will be available and should be used to spray containment.
The reactor coolant leak inside the drywell will be greater than the capacity of RCIC (the only remaining high-rressure feed source). The crew should enter T-111 "Level Restoration". As level deteriorates, the crew should start available low pressure ECCS pumps and when it is determined that level cannot be restored and maintained above -172 inches, the reactor should be depressurized in accordance with T -112 "Emergency Blowdown". Low pressure ECCS will be available to recover reactor level. The scenario will be terminated when the reactor has been depressurized and reactor level has been recovered and controlled.
Initial IC-118, 100% power Conditions Turnover See Attached "Shift Turnover" Sheet Event Malfunction Event Event
. No. No. Type" Description 1 See Scenano Guide N PRO Stroke time primary containment isolation valves for surveillance CRS testing 2 See Scenario Guide TS CRS Reactor Bldg to Torus vacuum breaker isolation valve fails open (Tech Spec) 1~ ____ ~ ____________ '~ _____ ~-----r ____----__--__--_______________--__--____ -~ __- _____--U 3 See Scenario Guide C URO Service Water pump trip I manual start of the standby pump L-____ ~ ____________ ~
__________ ~ ______________________________________.________.________
2013 NRC Scenario #1 - T-III Low Level, Rev O.doc
Event Malfunction Event Event No. No. Type" Description 4 See Scenario Guide I PRO Orywell pressure instrument fails upscale without the expected half TS CRS scram (Tech Spec) I insert half scram lAW GP-25 5 See Scenario Guide R URO Condensate pump trip with recirc runback failure I power reduction CRS 6 See Scenario Guide M ALL Loss of #2 auxiliary bus 1 loss of condensate & feedwater I reactor coolant leak inside the drywell 7 See Scenario Guide C PRO HPCI controller fails in automatic CRS 8 See Scenario Guide C URO RPS failure requires ARI to scram the reactor CRS 9 See Scenario Guide C ALL HPCI turbine trip, requiring an emergency blowdown to restore level
. with low-pressure ECCS 10 See Scenario Guide I PRO Containment spray logic failure hampers effort to spray the CRS containment, requiring crew to use alternate RHR loop
.. (N)ormal, (R)eactJvlty, (I)nstrument. (C)omponent, (M)aJor, (TS) Tech Spec 2013 NRC Scenario #1 - T-III Low Level, Rev O.doc
SIMULATOR OPERATOR INSTRUCTIONS FOR 2013 NRC SCENARIO #1 GENERAL REQUIREMENTS
- Recorders will be rolled prior to the scenario and paper from selected recorders will be retained for the examination team as requested.
- All procedures, flow charts, curves, graphs. etc. will be in their normal storage places.
- All markable procedures, boards, etc. will be erased.
- All paper used by the crew will be retained for the examination team as requested.
- The simulator operators will keep a log of all communications during the scenario as requested by the examination team.
SCENARIO SOURCE HISTORY
- A previous version was used on the 2009 NRC ILT exam. It was modified (altered) slightly and submitted as a spare scenario for the 2011 NRC ILT exam. It has been modified again for use in the 20131LT 11-1 NRC Exam.
INITIAL SETUP Initial Conditions
- IC-118, 100% power
- Ensure recorder power is on; roll recorders as required
- Ensure annunciator horns are active
- Setup a TRIP Table PMS screen by typing in "NCPCIS" on the GROUP DISPLAY screen to support ST-0-007-420-2 performance in Event 1 Blocking Tags
- None Activate APP u2013_NRC_SCN1" or insert the following:
Event Triggers TRG E5 ARI_A_DEPRESSED
=
TRG E4 BAT BUS_2_0VERCURRENT_LOCKOUT
=
TRG E5 MRF ARI01TO NORMAL Malfunctions IMF SWS01B (E1 00) ('8' Service Water pump trip)
IMF MCS05A (E3 0 0) ('A' Condensate pump trip)
IMF RRS20(E4 2:00 0) 420:000 (Recirc loop rupture at 4% severity, 2 minute delay and 20 minute ramp)
IMF HPC03 (E6 0 0) (HPCI turbine trips)
IMF HPC04 (E4 0 0) (HPCI flow controller fails low in auto) 1013 NRC Scenario #1 - T-III Low Level, Rev O.doc
Overrides lOR ZLORP15DS26B (none 0 0) ON (5A-OS26B light at RPS Panel20C017 to ON) lOR ZYP06A521S16 FALSE (SFCS recirc run back inhibit) lOR ZYP12A1S19 (none 0 0) OFF (Override Switch 10A-17A, prevents containment sprays) lOR ZYP12A3S19 (none 0 0) OFF (Override Switch 10A-17B, prevents containment sprays) lOR AN0205LD4 (E2 0 0) ALARM_ON (RPS INSTRUMENT GROSS FAILURE - 2100-4) lOR AN0205LF1 (E2 00) ALARM_ON (OW HI PRESSURE - 210 F-1) lOR ZLOPC03A02502A_2 (E7 0 0) ON (AO-2502A red light on) lOR AN0203CE3 (E7 0 0) ALARM_ON (A TORUS VACUUM RELIEF VALVE OPEN - 224 E-3)
Trip Overrides MRF ARI01TO OVERRIDE (prevents ARI auto-initiation on 'A' channel)
MRF RPS03TO OVERRIDE (prevents RPS B1 trip)
MRF RPS04TO OVERRIDE (prevents RPS B2 trip)
MRF RPS06TO OVERRIDE (prevents RPS B3 trip)
Batch Files (Verify the following Batch File exists - DO NOT ENTER AT THIS TIME)
BAT BUS_2...0VERCURRENT_LOCKOUT IMF MAP06D IMF MAP06E IMF MAP06F lOR AN0209LA2 ALARM_ON lOR AN0209LC4 ALARM_OFF lOR ZYP14A3S04 TRIP IORZYP14A3S08 TRIP lOR ZYP14A3S37 TRIP Turnover Procedures ST-0-007-420-2 "PCIS Normally Closed Valves Operability Test", marked complete up to and including step 6.1.5 (rev 17) 2013 NRC Scenario #1 - T-III Low Level, Rev O.doc
SIMULATOR OPERATOR DIRECTIONS EVENT 1 Support crew for stroking of main steam sample valves AO-316 and 317 per ST-O 007-420-2.
EVENT 2 After stroking of main steam sample valves AO-316 and 317 per ST-0-007-420-2 is complete, initiate ET7 for split indication on normally closed PCIV AO-2S02A, and verify the following:
- lOR ZLOPC03A02S02A_2 (E7 0 0) ON, AO-2S02A red light on
- lOR AN0203CE3 (E7 0 0) ALARM_ON, A TORUS VACUUM RELIEF VALVE OPEN - 224 E-3 When dispatched as the Equipment Operator to the valve to verify ARC 224 E-3 step 3.c, wait 1 minute and report that the valve appears to be closed and that you hear an air leak but cannot tell where it is coming from.
EVENT 3 After the Tech Spec evaluation is complete, or when directed by the Lead Examiner, initiate ET1 (IMF SWS01 B) to trip the 'B' Service Water pump.
When requested to check the 'B' Service Water pump breaker, report that it tripped on instantaneous overcurrent.
Support the crew while placing the 'C' Service Water pump in service lAW SO 30.1.A-2, section 4.2. When dispatched as the Equipment Operator for a start of the 'c' Service Water, wait 2 minutes and report steps 4.2.3 and 4.2.4 are complete and the 2C SW Pump is ready for a start.
Support the crew while restoring the Fuel Pool Service Water booster pumps lAW SO 19.1.A-2, section 4.2.
EVENT 4 When Fuel Pool Service Water is restored, or when directed by the Lead Examiner, initiate ET2 for the drywell pressure instrument failure, and verify the following:
- lOR AN020SLF1 ALARM_ON, OW HI PRESSURE (210 F-1)
- lOR AN020SLD4 ALARM_ON, RPS INSTRUMENT GROSS FAILURE (210 0-4)
When requested to check the 2AC06SD and 2BC06S0 instrument racks, report Orywell Pressure Instrument PIS-2-S-12A is upscale high with the gross failure light lit. If directed to reset the gross failure, report that it will NOT reset.
EVENT S After the crew has inserted a half scram on RPS channel A 1 and before inserting a PCIS channel trip, or when directed by the Lead Examiner, initiate a trip of the 'A' condensate pump using ET3 (IMF MCSOSA).
- Recirc pumps will fail to automatically runback due to a pre-inserted override (lOR ZYP06AS21S16 FALSE).
When requested to check the 'A' condensate pump breaker, mc"rt that it tripped on instantaneous overcurrent. If dispatched to the 'A' condensah wait 2 minutes and report there is nothing abnormal.
Support the crew as necessary during the power reduction.
2013 NRC Scenario # I - T-III Low Level, Rev O.doc
SIMULA TOR OPERA TOR DIRECTIONS EVENTS 6 When actions for the condensate pump trip are complete, or when directed by the Lead Examiner, initiate ET4 to cause an overcurrent lockout on #2 aux bus and fail the HPCI flow controller low, and verify the following:
- Activate BAT BUS_2_0VERCURRENT_LOCKOUT, Loss of #2 Aux Bus
- IMF HPC04, HPCI flow controller fails low in auto Verify a Recirc loop rupture initiates 5 minutes later at 4% severity on a 20 minute ramp (IMF RRS20 4 20:00).
If asked, report OWCW return header pressure is 28 pSig.
Support performance of T-223 "Orywell Cooler Fan Bypass" if requested to perform step 4.6 for placing the fan breakers in SLOW.
EVENT 8 RPS fails to scram automatically or manually (manual ARI works) - pre-inserted.
The 'A' ARI channel will fail to automatically initiate. When the URO arms the 'A' ARI channel, verify ET5 (MRF ARI01TO NORMAL) initiates to restore the 'A' ARI channel to normal.
When directed to close HV-2-3-56 (per T-246), MRF T220_2 CLOSE and report HV-2-3-56 is closed.
EV~NT 9 30 seconds after HPCI automatically starts and is injecting after operators take manual control, initiate ET6 (IMF HPC03) (HPCI turbine trips)
When directed to investigate the HPCI turbine trip, wait 5 minutes and then report unable to determine the cause of the trip.
EVENT 10 Pre-inserted instrument failures will prevent the crew from spraying the torus or the drywell.
After the crew attempts to spray the containment (either torus or drywell), delete the override on the OPPOSITE RHR LOOP:
- To delete the override on the 'B' RHR Loop, DOR ZYP12A3S19
- To delete the override on the 'A' RHR Loop, DOR ZYP12A1S19 NOTE: Adjust the severity of RRS20 as necessary to control the pace of RPV level trend toward -172 inches. Ensure the crew has time to enter T-111 and inhibit ADS before raising the leak severity. Consider MMF RRS20 to 6% with remaining ramp time when HPCI is tripped. HPCI will likely restore RPV level to 0 inches before RRS20 initiates, even with RCIC 005.
TERMINATION The scenario may be terminated after the reactor has been depressurized and reactor level has been recovered and is controlled.
2013 NRC Scenario #1 - 1'-111 Low Level, Rev O.doc
SHIFT TURNOVER PLANT CONDITIONS:
'. Unit 2 is steady at 100% power.
INOPERABLE EQUIPMENT/LCOs:
- None SCHEDULED EVOLUTIONS:
- ST-0-007-420-2, "PCIS Normally Closed Valves Operability Test".
SURVEILLANCES DUE THIS SHIFT:
- Completion of ST-0-007-420-2 "PCIS Normally Closed Valves Operability Test". The test is done up to and including step 6.1.5 (Rev 17). Continue with step 6.2 (stroking AO-2-02-316 and 317)
- Stopwatch is available
- None GENERAL INFORMATION:
- Unit 2 is steady at 100% power.
2013 NRC Scenario #1 ~ T-III Low Level, Rev O.doc
CRITICAL TASK LIST
- 1. Recognize failure of the Reactor Protection System to scram the reactor and initiate Alternate Rod Insertion (ARI) to insert control rods in accordance with T-101 "RPV Control" and RRC 38.1-2 "Alternate Rod Insertion During A Plant Event".
- 2. Spray the drywell in accordance with T-204 "Initiation of Containment Sprays Using RHR" when conditions permit, but before drywell temperature exceeds 281 degrees F.
- 3. Perform an emergency blowdown in accordance with T-112 "Emergency Blowdown" when reactor water level cannot be restored and maintained above -172 inches.
2013 NRC Scenario # I - T -111 Low Level, Rev O.doc
n _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __
Operator Actions OpTestNo.: 1 Scenario No.: 1 Event No.: 1 Page: 10f18 Event
Description:
Stroke main steam sample isolation valves A0-2-02-316 and 317 per ST-O 007-420-2 Cause: Stroke open and close PCIVs associated with Main Steam Sample System Effects: N/A- Normal evolution Position Applicanfs Actions or Behavior CRS Directs the PRO to continue with ST-0-007 -420-2 "PCIS Normally Closed Valves Operability Test" starting at step 6.2 (Rev 17).
PRO Performs step 6.2 of ST-0-007-420-2:
Strokes open AO-2-02-316 "Main Steam Sample Inboard" Strokes closed and times AO-2-02-316 "Main Steam Sample Inboard" Records time in surveillance test Strokes open AO-2-02-317 "Main Steam Sample Outboard" Strokes closed and times AO-2-02-317 "Main Steam Sample Inboard" Verifies PMS computer points associated with both valves have changed state by verifying historical tabular trend 2013 NRC Scenario # I - T-II I Low Level, Rev O.doc
Operator Actions Op Test No.: 1 Scenario No.: 1 Event No.: 2 Page: 20f18 Event
Description:
Reactor Building to Torus Vacuum Breaker Isolation Valve AO-2502A has split indication Cause: Deflation of boot seal for AO-2502A Effects: Valve is no longer leak tight and inoperable for primary containment purposes Position Applicant's Actions or Behavior PRO Acknowledges and reports alarm 224 E-3 "A TORUS VACUUM RELIEF VALVE OPEN" Verifies that AO-2502A is open CRS References ARC 224 E-3 Direct that an Equipment Operator be dispatched to check instrument air supply, backup nitrogen supply, and valve seal operation for AO-2502A.
Refer to Tech Spec 3.6.1.5 Declare AO-2502A inoperable per Tech Spec 3.6.1.5. Condition A Determine that AO 250A must be closed within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
2013 NRC Scenario #1 - T-II ! Low Level. Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 3 Page: 30f18 Event
Description:
'8' Service Water pump trips on overcurrent Cause: Motor winding failure Effects: 1. Alarms:
- 216 H-1 B' Service Water Pump Trip"
- 216 H-2 B' Service Water Pump OVLD"
- 216 F-1 "Service Water Header La Press"
- 216 F-S "Fuel Pool Service Water To HX La Press"
- 2. Loss of 'B' Service Water pump, requiring manual start of 'C' Service Water pump.
Time Position Applicant's Actions or Behavior URO/PRO Recognize and report the following alarms and enter corresponding Alarm Response Cards:
- 216 H-1B' Service Water Pump Trip"
- 216 H-2 "'B' Service Water Pump OVLD"
- 216 F-1 "Service Water Header La Press"
- 216 F-S "Fuel Pool Service Water To HX La Press" Recognize and report trip of the 2B Service Water pump.
Recognize and report trip of the 2A and 2B Fuel Pool Service Water (FPSW) booster pumps.
Green flag the 2B Service Water pump control switch.
Green flag the 2A and 2B FPSW booster pump control switches.
Dispatch an Equipment Operator to investigate the Service Water pump and breaker.
CRS Enter and direct actions of Alarm Response Cards 216 H-1, 216 H-2, 216 F-1 and 216 F-S.
Direct placing the 2C Service Water pump in service lAW SO 30.1.A-2 "Unit 2 Service Water System Normal Operations".
Request Maintenance assistance to investigate trip of 2B Service Water Pump.
URO Place the 2C Service Water pump in service lAW SO 30.1.A-2 as follows:
- Direct an Equipment Operator to prepare the 2C Service Water pump for start lAW SO 30.1.A-2, steps 4.2.3 and 4.2.4.
- Start the 2C Service Water pump by placing the pump control switch in "Run",
- Verify Service Water pump discharge pressure . psig (both in the Control Room and locally).
2013 NRC Scenario #1 - T-III Low Level, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 1 Event No.: 3 Page: 40f18 Event
Description:
'B' Service Water pump trips on overcurrent (continued)
Position Applicant's Actions or Behavior CRS Direct placing the 2A and 2B Fuel Pool Service Water booster pumps in service lAW SO 19.1.A-2 "Fuel Pool Cooling System Startup and Normal Operations".
URO Place the 2A and 2B Fuel Pool Service Water booster pumps in service lAW SO 19.1.A-2 as follows:
- Direct an Equipment Operator to prepare the 2A and 2B Fuel Pool Service Water booster pumps for start lAW SO 19.1.A-2, step 4.2.5.
- Start the 2A Fuel Pool Service Water booster pump by placing the pump control switch in "Run".
- Start the 2B Fuel Pool Service Water booster pump by placing the pump control switch in "Run".
- Direct an Equipment Operator to adjust differential pressure for the 2A and 2B Fuel Pool Service Water booster pumps lAW SO 19.1.A-2, step 4.2.8.
CRS Request troubleshooting/technical assistance through the Shift Manager.
2013 NRC Scenario #1 - T-III Low Level, Rev O.doc
Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 1 Event No.: 4 Page: 50f18 Event
Description:
Drywell pressure instrument fails upscale without the expected half scram Cause: PIS-2-5-12A fails upscale (gross failure)
Effects: 1. Alarms:
- 210 F-1 "Drywell Hi Pressure Trip>>
- 210 D-4 "RPS/PCIS Trip Units in Calibration of Gross Failure"
- 2. Drywell pressure instrument fails high (gross failure); RPS half scram fails to occur.
Position Applicant's Actions or Behavior URO Recognize and report the following alarms and enter the corresponding Alarm Response Cards:
- 210 F-1 "Drywell Hi Pressure Trip"
- 210 D-4 "RPS/PCIS Trip Units in Calibration of Gross Failure" Determine actual drywell pressure is below the scram setpoint.
Recognize and report the drywell pressure instrument failure did NOT cause the expected RPS half scram.
CRS Enter and execute the Alarm Response Cards for 210 F-1 and 210 0-4.
Direct an Equipment Operator to check the 2A(8)C065D instrument racks in the Reactor Building to aid in determining the cause of the trip.
CRS Direct troubleshooting in accordance with the Alarm Response Card for 210 D-4 "RPS/PCIS Trip Units in Calibration of Gross Failure".
Declare drywell pressure instrument PIS-2-5-12A inoperable.
Review Tech Spec 3.3.1.1 and determine Condition A applies (RPS Function 6 on Table 3.3.1.1-1):
- Place associated channel (or trip system) in trip within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, OR
- Be in Mode 3 within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
Review Tech Spec 3.3.6.1 and determine Condition A applies (PCIS Function 2.b on Table 3.3.6.1-1):
- Place associated channel (or trip system) in trip within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, OR
- Be in Mode 3 in the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in Mode 4 in the next 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.
Review Tech Spec 3.3.6.2 and determine Condition A applies (SCIS Function 2 on Table 3.3.6.2-1):
- Place associated channel (or trip system) in trip within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, OR
- Take the compensatory actions for Condition C.
Recognize that RPS/PCIS trips must be installed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
2013 NRC Scenario #1 - T-111 Low Level, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 4 Page: 6 of 18 Event
Description:
Drywell pressure instrument fails upscale without the expected half scram (continued)
Time Position Applicant's Actions or Behavior NOTE: This section is optional at discretion of Lead Examiner.
The Lead Examiner may act as the Shift Manager and direct the crew to perform GP-25 to install the RPS/PCIS trips OR the scenario can move on when the crew determines that GP-25 Appendices 1 &
5 apply.
CRS Initiate GP-25 Appendices 1 and 5 to install redundant RPS/PCIS trips.
PRO Install trip on A 1 RPS channel as directed by the CRS using GP-25 Appendix 1:
- Complete Appendix 1.
- Inform URO that a half scram on RPS channel A 1 will be inserted.
- At Panel 20C015. insert key and place the A 1 Test Keylock Switch to the TEST position.
NOTE: the next event will be initiated before the crew can perform Appendix 5 of GP-25 (PCIS).
2013 NRC Scenario #1 - T*III Low Level, Rev O.doc
Operator Actions ES-O-2 OpTest No.: 1 Scenario No.: 1 Event No.: 5 Page: 70f18 Event
Description:
'A' Condensate pump trip with Recirc runback failure / power reduction Cause: 'A' Condensate pump trips on overcurrent / relay failure in the Recirc runback logic Effects: 1. Alarms:
- 203 E-1 "A Condensate Pump Overload"
- 203 E-2 "A Condensate Pump BKR Trip"
- 2. Recirc automatic runback fails to occur, resulting in lowering reactor level and requiring manual recirc flow reduction to control reactor level.
Position Applicant's Actions or Behavior URO Recognize and report trip of the 'A' Condensate pump.
(May) recognize / report the Recirc pump runback (45%) failed to occur.
Recognize and announce entry into the OT-100 "Reactor Low Level":
- Recognize the reactor water level drop is caused by a lack of makeup capability, requiring power reduction with Recirc flow.
- Reduce power by lowering the 'A' and 'B' Recirc pump speed controllers per GP-9-2 "Fast Reactor Power Reduction" (this must be done in a controlled manner that does not result in level swell and a high level trip of the Reactor Feed pumps).
Recognize and announce entry into OT-112, "Unexpected/Unexplained Change in Core FloW".
NOTE: the crew must respond to this event by lowering power per GP-9' to prevent a low reactor water level scram. IF the crew recognizes that Feedwater flow was above 85% (12 Mlbm/hr) prior to the Condensate pump trip, they should reduce Recirc flow to the runback setpoint of 45%.
CRS Enter OT-100 "Reactor Low Level": direct the URO to lower power by lowering Recirc flow using GP-9-2 "Fast Reactor Power Reduction".
Enter I direct actions of ARC 203 E-2 "A Condensate Pump BKR Trip".
Enter I direct actions of OT-112 "Unexpected/Unexplained Change in Core FloW".
- Direct insertion of control rods per GP-9-2 "Fast Reactor Power Reduction" to exit Region 2 of Power to Flow map.
- Plot conditions on Power to Flow map. Determine that plant is in region 2.
- Direct the LlRO to monitor for THI (May) refer to GP-5 "Power Operations" to determine power must be limited to <80% total feedwater flow with 2 Condensate and 3 Reactor Feedwater pumps.
Request Maintenance assistance for investigationf 'A' Condensate Pump and failure of Recirc system to 2013 NRC Scenario # 1 - T -111 Low Level, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 5 Page: 8 of 18 Event
Description:
'A' Condensate pump trip with Recirc runback failure I power reduction (cont'd)
Position Applicant's Actions or Behavior URO Monitor for Thermal Hydraulic Instabilities (THI).
Insert control rods per GP-9-2 "Fast Reactor Power Reduction" to exit Region 2 of Power to Flow map.
PRO Investigate the cause of the 'A' Condensate pump trip using the applicable Alarm Response Card.
- Direct an Equipment Operator to investigate the breaker and pump.
- Green flag the 'A' Condensate pump control switch.
2013 NRC Scenario # 1 - T -111 Low Level, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 1 Event No.: 6 Page: 90f18 Event
Description:
Loss of #2 auxiliary bus (loss of Condensate and Feedwater)
Cause: Failure in the bus work results in an overcurrent condition and a bus lockout I RPS 'B' automatic and manual channel failure Effects: 1. Alarms:
- 219 A-2 "2 Aux Bus Overcurrent Relays"
! 219 B-2 "2 Aus Bus Lo Voltage"
- 2. #2 Auxiliary Bus breakers trip, de-energizing the bus and its loads
- 3. The immediate impact of loss of #2 Auxiliary Bus is the resultant loss of the remaining Condensate pumps, causing reactor water level to drop rapidly.
- 5. Reactor level drop is greater because more time is spent under power conditions with no high-pressure injection.
Position Applicant's Actions or Behavior PRO Recognize and report the loss of #2 Auxiliary Bus.
CRS URO Recognize and report Reactor water level is dropping rapidly.
Attempt to manually scram the Reactor by placing the Mode Selector Switch in "Shutdown".
Attempt to scram 'B' RPS by depressing the manual scram pushbutton.
Recognize and report an RPS scram has failed to occur. (See Event #8)
Report entry into T-101 "RPV Control" for the ATWS condition.
CT CRS Direct the mode switch be placed in SHUTDOWN if not previously performed by URO.
Recognize a failure to scram condition exists; enter and execute T-101 "RPV Control".
For RC/Q:
- Direct initiation of Alternate Rod Insertion (ARI) (See Event #8).
2013 NRC Scenario # I - T-Ill Low Level, Rev O.doc
Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 1 Event No.: 6 Page: 10 of 18 Event
Description:
Loss of #2 auxiliary bus (loss of Condensate and Feedwater)
Position Applicant's Actions or Behavior CRS Execute T-101 "RPV Control".
For RC/L:
For RC/P:
- Direct instrument nitrogen bypassed and restored lAW GP-8E.
- Direct reactor pressure stabilized below 1050 psig.
PRO Perform applicable scram actions:
- Transfer 13 KV house loads (#'1 bus only).
- Trip main turbine at approximately 50 MWe.
- Verify main generator lockout.
- Verify Group II & III isolations and SGTS initiation.
- Verify SDV vent and drain valves are closed.
- Verify HWC isolated.
- Verify recirc pumps are tripped.
- Monitor instrument air header pressure and drywell pressure; report instrument air header pressure is greater than drywell pressure.
PRO Bypass and restore drywell instrument nitrogen lAW RRC 94.2-2 or GP-8E.
- Place AO-2969A control switch to "CLOSE".
- Place AO-2969B control switch to "CLOSE".
- Place AO-2969A control switch to "OPEN".
- Place AO-2969B control switch to "OPEN".
NOTE: this activity may be coordinated between the URO and the PRO.
URO/PRO Announce an additional entry condition for T-101 based on Reactor level below -48 inches.
Operate HPCI and RCIC to restore reactor level to +5 to +35 inches.
2013 NRC Scenario # I - T -III Low Level, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 6 Page: 11 of 18 Event
Description:
Reactor coolant leak inside the drywell Cause: A leak develops on a weld joint on the suction piping of the "B" reactor recirculation pump after it tripped; the leak size propagates over time.
Effects: 1. Initial alarms:
- 210 F-2 "Drywell Hi-Lo Press"
- 225 A-4 "Drywell Hi-La Press"
- 2. Drywell pressure and temperature will rise at an increasing rate, eventually leading to a high drywell pressure alarm, ECCS automatic start signals, and PCIS isolation signals. Conditions will escalate requiring the use of containment sprays.
Time Position Applicanfs Actions or Behavior LlRO/PRO Recognize and report alarms 210 F-2 "Drywell Hi-Lo Press" and 225 A-4 "Drywell Hi-Lo Press" and enter corresponding Alarm Response Cards.
CRS Enter and execute follow-up actions of OT-101 "High Drywell Pressure":
- When drywell pressure reaches 2 psig, then enter T-101 "RPV Control" and T-102 "Primary Containment Control" and execute concurrently with OT-101.
- Direct additional drywell cooling placed in service.
WRO/PRO Maximize drywell cooling by placing all drywell cooler fans to RUN.
CRS Enter and execute T-102 "Primary Containment Control" when drywell pressure reaches 2 psig.
For P C / P : " "
- Direct torus sprays initiated lAW T-204 "Initiation of Containment Sprays Using RHR".
For DWIT:
- Direct drywell cooling maximized by performing T-223 "OW Cooler Fan Bypass".
For PC/G:
- Direct CAD placed in service as time permits.
Re-enter T -102 when Torus level reaches 14.9 feet, and when Drywell temperature reaches 145 degrees F.
Direct an RPV depressurization to 500-600 psig.
2013 NRC Scenario # I - T-III Low Level. Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 6 Page: 12 of 18 Event
Description:
Reactor coolant leak inside the drywall (continued)
Position Applicants Actions or Behavior URQ/PRO Monitor T-1 02 parameters (torus temperature, torus level, drywell pressure, torus pressure, drywell temperature) and provide trends to the CRS as appropriate.
URO Maximize drywell cooling by performing T-223 "DW Cooler Fan Bypass".
Shutdown drywell cooling fans when directed.
Depressurize the RPV to 500-600 psig using bypass valves.
PRO Spray the torus in accordance with T-204 "Initiation of Containment Sprays Using RHR" (see Event #10).
CT Spray the drywell in accordance with T-204 "Initiation of Containment Sprays Using RHR".
URO/PRO Place CAD in service when directed.
Monitor reactor level, and report to the CRS reactor level is continuing to lower.
CRS When drywell pressure and temperature plot within the safe region of the Drywell Spray Initiation Limit Curve:
- Direct drywell cooling fans shut down.
- Direct drywell sprays initiated lAW T-204 "Initiation of Containment Sprays Using RHR".
2013 NRC Scenario # I - T-I II Low Level. Rev O.doc
Operator Actions ES-O-2 OpTestNo.: 1 Scenario No.: 1 Event No.: 7 Page: 13 of 18 Event
Description:
HPCI flow controller fails low in automatic Cause: HPCI flow controller intemal malfunction while in automatic Effects: HPCI turbine speed will be too low to develop enough system discharge pressure to allow injection into the RPV. Controller must be placed in MANUAL and output raised manually to allow the system to inject.
Position Applicant's Actions or Behavior PRO Recognize that HPCI system automatic response is abnormal and that the system has low discharge pressure and no injection flow.
Place the HPCI system flow controller in MANUAL.
Using controller manual output knob, raise HPCI system speed high enough to develop enough discharge pressure to allow system injection into the RPV.
Report the abnormal HPCI response and actions taken to the CRS.
2013 NRC Scenario # I : 1'-1 II Low Level, Rev O.doc
Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 1 Event No.: 8 Page: 14 of 18 Event
Description:
RPS failure requires Alternate Rod Insertion (ARI) to scram the reactor Cause: RPS '8' automatic and manual channel failure Effects: Full Reactor scram does not occur; manual ARI initiation is required.
Position Applicant's Actions or Behavior CT CR~ Recognize a failure to scram condition exists; enter and execute T -101 "RPV Control".
For RC/Q:
- Direct initiation of Alternate Rod Insertion (ARI).
CT URO Initiate ARI lAW RRC 38.1-2 "Alternate Rod Insertion During a Plant Event":
- Rotate the "A" and "8" ARI pushbutton collars to "Armed".
- Depress the -A" and "8" ARI pushbuttons.
- Verify the folowing ARI solenoid valves open:
o SV-2-03-141A o SV-2-03-142A o SV-2-03-1418 o SV-2-03-1428
- Monitor and report when control rods begin to insert.
- Verify APRils are downscale and report to the CRS.
- Report the status of reactor level control, reactor pressure control, and control rods.
2013 NRC Scenario #1 - T-III Low Level, Rev O.doc
Operator Actions ES-D-2
~
Op Test No.: 1 Scenario No.: 1 Event No.: 9 Page: 15 of 18 Event
Description:
HPCI turbine trip I emergency blowdown Cause: Instrument failure Effects: HPCI will trip while in-service, RPV level lowers requiring emergency blowdown Position Applicanfs Actions or Behavior URO Recognize and report alarm 221 B-1 "HPCI Turb Trip" and enter the corresponding Alarm Response Card (as time permits).
Dispatch an Equipment Operator to determine the cause of the trip.
When report is received from the field, report to the CRS that there is no apparent cause for the HPCI trip.
CRS Direct SBlC initiation to augment reactor level control.
Direct T-246 "Maximize CRD Flow to the Reactor Vessel".
URO/PRO Initiate SBlC for reactor level control, as directed, using RRC 11.1-2 "SBlC Initiation During a Plant Event".
Perform T-246 "Maximize CRD Flow to the Reactor Vessel".
- Direct an Equipment Operator to open HV-2-3-129 "CRDHS Bypass Valve for Pump Suction Filter"
- Direct an Equipment Operator to check standby CRD Pump for start per step 4.4.
- Start the standby CRD Pump.
- Direct an Equipment Operator to open discharge valve for the CRD Pump placed in service HV-2-3-36A or B.
- While monitoring CRD Pump motor amps, direct an Equipment Operator to throttle open HV-2-3-1'70 "Inlet Valve to Drive Water Filters"
- Direct an Equipment Operator to place the standby drive water filter in service per step 4.8.
- Fully open MO-2-3-020 on Panel20C005A
- Close MO-2-2A-8029A and B on Panel 20C004A
- Verify CRD flow controller FIC-2-3-301 in MANUAL.
- While monitoring CRD Pump motor amps, open A0-2-3-19A(B) "Flow Control" using FIC-2-3-301.
2013 NRC Scenario #1 - T-III Low Level, Rev O.doc
Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 1 Event No.: 9 Page: 16 of 18 Event
Description:
HPCI turbine trip I emergency blowdown (continued)
Position Applicanfs Actions or Behavior CRS After it is determined reactor level cannot be maintained above -172 inches, exit the RC/L leg of T-101 and enter/execute T-111 "Level Restoration":
- Direct ADS inhibited.
- Direct Core Spray and LPCI pumps started.
CT When reactor level drops to -172 inches, enter and execute T -112 "Emergency Slowdown":
- Verify torus level is above 7 feet.
- Verify reactor pressure is 50 psig above torus pressure.
URO/PRO Inhibit ADS when directed.
CT Verify start of all available Core Spray and LPCI pumps.
When directed, manually open 5 ADS SRVs by placing their control switches in OPEN.
CRS After T-112 is executed, direct RPV injection maximized with all systems, subsystems, and alternate subsystems.
After it is determined reactor level ~an be maintained above -172 inches, exit T-111 and enter T-1 01 "RPV Control" at step RC/L-1.
Direct reactor level restored to +5 to +35 inches with Core Spray/RHR.
URO/PRO Maximize injection with all systems, subsystems, and alternate subsystems.
Restore and maintain reactor level +5 to +35 inches, as directed.
2013 NRC Scenario # I - T-III Low Level, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 1 Event No.: 10 Page: 17 of 18 Event
Description:
Pressure instrument failure prevents using containment spray on 1 RHR loop Cause: Drywell pressure input to spray logic permissive not functioning Effects: Prevents containment spray using 8 (A) loop of RHR, resulting in Drywell temperature rising toward 281 degrees F (the A (B) loop of RHR is available).
Position Applicant's Actions or Behavior NOTE: the spray logic failure will effect whichever loop of RHR (8 or A) is first selected to spray the containment. The simulator operator will delete the associated override (failure) on the opposite RHR loop to allow spraying the containment with that loop.
PRO Spray the torus in accordance with T -204 "Initiation of Containment Sprays using RHR":
- Verify System 1 and 2 Drywell Pressure Permits Containment Spray annunciators (224 D-3, 225 B-3) are lit.
- Place keylock switch 10A-S18 in "MANUAL OVERRIDE".
- Momentarily place switch 10A-S17 in "MANUAL".
- Open or verify open MO-2-10-39 "Torus Header".
- Open or verify open MO-2-10-89 HPSW Hx Outlet".
- Start a HPSW pump
- Start an RHR pump ..
- Close or verify closed MO-2-10-34 "Full Flow Test".
- Throttle open MO-2-10-38 "Torus Spray" to obtain 1,000 gpm on FI-2 10-136.
Recognize and report inability to spray the torus (drywell) with the B (A)
CT loop of RHR CT CRS Direct the operator to spray the torus (drywell) with the opposite loop of RHR CT PRO As directed, spray the torus (drywell) using the opposite loop of RHR in accordance with T-204 "Initiation of Containment Sprays using RHR" (refer to steps above for steps to spray the torus).
Spray the drywall per T -204 as follows:
- Verify both recirc pumps are tripped
- Verify all drywell cooling fans control switches are in OFF
- Open MO-2-10-31
- Open MO-2-10-26
- Monitor torus and drywell pressure
- Throttle MO-2-10-26 to adjust drywell spray as nf" 'ed 2013 NRC Scenario #1 - T-III Low Level, Rev O.doc
Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 1 Event No.: 10 Page: 18 of 18 Event
Description:
Pressure instrument failure prevents using containment spray on 1 RHR loop POST SCENARIO EMERGENCY CLASSIFICATION:
Classification is an Alert lAW EAL MA2 ("Failure to Scram") OR FA1 ("Loss of Reactor Coolant System Barrier").
TERMINATION CRITERIA:
The scenario may be terminated when the reactor has been depressurized and reactor level has been recovered and controlled.
2013 NRC Scenario # I - T -I II Low Level, Rev O.doc
Scenario Outline E8-1)..1 Simulation Facility Peach Bottom Scenario No. #!!-"2==--_ _ Op Test No. 2013 NRC Examiners Operators _ _ _ _ _ _ _ _ CRS (SRO)
URO(ATC)
_ _ _ _ _ _ _ _ PRO (BOP)
Scenario The scenario begins with the reactor at 100% power. After taking the shift, the crew will perform the Summary Master Trip Solenoid Valve Routine Test.
Next, a turbine stop valve will fail closed, requiring the crew to execute OT-102 "Reactor High Pressure",
which will require reducing reactor power to less than or equal to 95% in accordance with GP-5 "Power Operations* .
Next, a failure in the controller for the 'A' Recirc M-G set will cause the Recirc pump speed to oscillate. The crew should recognize the changes in core and jet pump flows and "lock up" the 'A' Recirc pump. The crew should verify compliance with Technical Specifications for recirc loop flow differentials.
Next, a spurious HPCI initiation will occur due to a logic system failure. The crew should enter OT-104
- Positive Reactivity Insertion" and shutdown HPCI. This event will cause a steam leak from the HPCI system piping in the HPCI pump room, requiring the crew to enter and execute T-103 "Secondary Containment Control", All attempts to isolate HPCI will be unsuccessful due to logic system and control switch~failures, The leak will gradually worsen, requiring a reactor scram and entry into T-101 "RPV Contro, While performing scram actions, the PRO should recognize the generator lockout failure following the main turbine trip and manually open the generator output breakers and exciter field breaker.
The URO should respond to the 'C' reactor feedpump discharge bypass valve failure by batch feeding through the 'C' reactor feed pump discharge valve.
Conditions will continue to deteriorate in the Reactor Building due to the HPCI steam leak. When the second Reactor Building area (Torus Room) exceeds its T-1 03 Action Level. the crew should perform a T~ 112 "Emergency Blowdown", The scenario will end when the RPV is depressurized and RPV level is being maintained with Condensate.
Initial IC-119. 100% power Conditions Turnover See Attached "Shift Turnover" Sheet 3 See Scenario Guide C URO 'A' Recirc pump speed oscillations (Tech Spec) I Lock up the 'A' TS CRS Recirc pump 4 See Scenario Guide C PRO Inadvertent HPCI initiation I shutdown HPCI (Tech Spec)
TS CRS 5 See Scenario Guide M
... *.......... steam leak into secondary containment 2013 NRC Scenario #2 - 1'-103 HPCI Steam Leak., Rev O.doc
Event Malfunction Event Event No. No. Type* Description 6 See Scenario Guide I PRO Generator lockout fails to occur following main turbine trip eRS 7 See Scenario Guide e URO 'e' reactor feedpump discharge bypass valve fails to open, eRS complicating post-scram and post-blowdown reactor level control 8 See Scenario Guide ALL Emergency blowdown due to exceeding Reactor Building temperature limits in more than one area
.. {N)ormal. (R)eactlVlty. (I)nstrument. (C)omponent, {M)ajor, (TS) Tech Spec 2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev O.doc
SIMULATOR OPERATOR INSTRUCTIONS FOR 2013 NRC SCENARIO #2 GENERAL REQUIREMENTS
- Recorders will be rolled prior to the scenario and paper from selected recorders will be retained for the examination team as requested.
- All procedures, flow charts, curves, graphs, etc. will be in their normal storage places.
- All markable procedures. boards, etc. will be erased.
- All paper used by the crew will be retained for the examination team as requested.
- The simulator operators will keep a log of all communications during the scenario as requested by the examination team.
SCENARIO SOURCE HISTORY
- This scenario was altered from one originally developed for the 2011 NRC ILT Exam.
INITIAL SETUP Initial Conditions
- IC-119, 100% power, created from IC-14
- Ensure recorder power is on; roll recorders as required
- Ensure annunciator horns are active Blocking Tags
- None Activate APP "2013_NRC_SCN2", or insert the following:
Event Triggers None Malfunctions IMF MTA03C (E1 00) (Turbine stop valve #3 fails closed)
IMF HPC02 (E2 0 0) (HPCI spurious automatic start)
IMF HPC07 (E3 0 0) 5 20:00 0 (HPCI steam supply line break)
IMF RFC04A (E4 0 0) 100 (Recirc M-G flow controller 'A' oscillations)
Overrides lOR ZYP01A2A1S02 (none 00) NORMAL eC' RFP discharge startup bypass MO-S090) lOR ZYP13A1S07 (none 0 0) OPEN (HPCI steam line isolation valve MO-23-15) lOR ZYP13A1S05 (none 0 0) OPEN (HPCI steam line isolation valve MO-23-16) 2013 NRC Scenario #2 - T-103 HPCI Steam Leak. Rev O.doc
Remote Functions None Trip Overrides MRF HP004TO Override (HPCI isolation override - includes K27, K28, K36, K57 relays)
MRF MGA01TO Override (Main Generator 86 lockout relay)
Batch Files None Turnover Procedures
- RT-0-010402-2 "Master Trip Solenoid Valves Operability Test" (provide a consumable copy) 2013 NRC Scenario
~
- 2 - T-103 HPCI Steam Leak, Rev O.doc
S/AfULATOR OPERATOR DIRECTIONS EVENT 1 Support the crew as necessary for the Master Trip Solenoid Valves Routine Test.
EVENT 2 When directed by the Lead Examiner, initiate pending events on ET 1 (IMF MTA03C) to cause turbine stop valve #3 to fail closed.
If requested as I&C to investigate annunciator 201 H-1 "Feedwater Field Instrument Trouble", acknowledge request.
EVENT 3 When directed by the Lead Examiner, initiate pending events ET4 (IMF RFC04A 100) to cause Recirc M-G flow controller 'A' oscillations.
EVENT 4 When directed by the Lead Examiner, initiate pending events on ET 2 (IMF HPC02) to cause a spurious start of HPCI.
If dispatched as the Equipment Operator to investigate the HPCI start, wait approximately 5 minutes and report no HPCI abnormalities.
EVENT 5 After the Tech Spec determination has been made, or when directed by the Lead Examiner, initiate pending events on ET 3 (IMF HPC07 5 20:00 0) to cause a HPCI steam supply line break.
Modify the leak severity as necessary to control the scenario pace and ensure a second Reactor Building area exceeds the Action Level for temperature.
This will vary based on the crew's action to depressurize the reactor.
EVENT 6 Following the GP-4 shutdown and Main Turbine Trip, the Main Generator will not lockout.
EVENT 7 When the URO attempts to establish reactor level control using MO-B090, the valve will not open.
EVENT 8 When the second area temperature exceeds the action level, the CRS will direct an emergency blowdown. The eRS may have directed a rapid depressurization with bypass valves prior the second parameter exceeding the action level.
TERMINATION The scenario may be tenninated when 5 SRVS are open, the reactor is depressurized, and reactor level is under control.
2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev O.doc
SHIFT TURNOVER PLANT CONDITIONS:
- Unit 2 is at 100% power.
INOPERABLE EQUIPMENT/LCOs:
- None SCHEDULED EVOLUTIONS:
- RT-O-O'I D-402-2 "Master Trip Solenoid Valves Operability Test" (provide a consumable copy)
SURVEILLANCES DUE THIS SHIFT:
- RT-O-01 D-402-2 "Master Trip Solenoid Valves Operability Test" ACTIVE CLEARANCES:
- None GENERAL INFORMATION:
- None 2013 NRC Scenario #2 - T -103 HPCI Steam Leak. Rev O.doc
CRITICAL TASK LIST
- 1. Following a positive reactivity addition, restore Reactor power below 100%.
- 2. When a Primary System is discharging into Secondary Containment through an unisolable leak, scram the Reactor when any parameter (temperature) exceeds a T-103 "Secondary Containment Control" Action Level.
- 3. Perform T-112 "Emergency Blowdown" when the same parameter (temperature) exceeds a T-103 "Secondary Containment Control" Action Level in more than one area and the system breach has not been isolated.
OR Perform a rapid depressurization using RC/P-12 when the blowdown limit in T-103 is approached.
2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 1 Page: 1 of 12 Event
Description:
Main turbine master trip solenoid valves routine test Cause: N/A Effects: None Position Applicant's Actions or Behavior CRS Direct PRO to perform RT-O-01D-402-2 "Master Trip Solenoid Valves Operability Test".
PRO Perform RT-0-01D-402-2 "Master Trip Solenoid Valves Operability Test":
- Review RT
- Place the Master Trip Test Selector switch to TRIP A
- Verify "TestA" lamp is OFF
- Release and place Master Trip Test Selector switch to RESET
- Verify "TestA" lamp is ON
- Place the Master Trip Test Selector switch to TRIP B
- Verify "TestB" lamp is OFF
- Release cnJ place Master Trip Test Selector switch to RESET
- Verify "Test B" lamp is ON
URO Monitor plant parameters/assist as directed .
2013 NRC Scenario #2 - T -103 HPCI Steam Leak,'" O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 2 Page: 20f12 Event
Description:
Turbine stop valve fails closed I Reactor power reduction Cause: An internal fault in the control pac for #3 stop valve causes the stop valve to go closed Effects: 1, Alarms: 201 H-1 "Feedwater Field Instrument Trouble" 206 A-4 "Main Steam Line Bypass Valve Open"
- 2. Reactor pressure will rise due to the valve closure; reactor power will rise in response to the rise in reactor pressure, Bypass valve(s) will open.
Time Position Applicanfs Actions or Behavior URO/PRO Recognize and report alarm 201 H-1 "Feedwater Field Instrument Trouble" and enter the corresponding Alarm Response Card.
Recognize and report alarm 206 A-4 "Main Steam Line Bypass Valve Open" Recognize and report main turbine bypass valve open Recognize and report the rise in reactor pressure, Recognize and report entry into OT-102 "Reactor High Pressure".
Enter and execute OT-102 "Reactor High Pressure",
Recognize and report Load Limit light lit on main turbine Panel 20C008A.
Recognize closure of the #3 Main Turbine Stop Valve.
Request I&C assistance to respond to alarm 201 H-1 "Feedwater Field Instrument Trouble" URO/PRO Recognize and report the rise in reactor power.
(May) recognize and report entry into OT-104 "Positive Reactivity Insertion" .
CRS Enter and execute OT-102 "Reactor High Pressure".
(May) enter and execute OT-104 "Positive Reactivity Insertion".
Exit OT-104 (per step 3.2).
Recognize OT-102 requirement to reduce reactor thermal power within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> in order to comply with Tech Spec 3.2.
Enter and execute GP-5 "Power Operation" per OT-102, step 3.5.
2013 NRC Scenario #2 - T -103 HPCI Steam Leak, Rev O.doc
Operator Actions Op Test No.: 1 Scenario No.: 2 Event No.: 2 Page: 3 of 12 Event
Description:
Turbine stop valve fails closed I Reactor power reduction (continued)
Position Applicanfs Actions or Behavior CT CRS Direct the URO to lower reactor power to s95% (3338 MWth) per GP-5, step 6.32.
Verify operation is within the acceptable region of AO 1E. 4-2 "Planned Removal of the Fifth or Fourth Stage Feedwater Heaters for Service During End of Cycle Coastdown and Return to Normal Shutdown Condition" .
CT URO Lower reactor power using Recirc until reactor power S95% (3338 MWth),
as directed.
PRO Recognize and report main turbine bypass valve open Recognize and report Load Limit light extinguished on main turbine Panel 20C008A NOTE: "Main Steam Line Hi Radiation" (218 0-2) may alarm and clear during the power reduction due to Hydrogen Water Chemistry injection.
2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev O.doc
Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 2 Event No.: 3 Page: 40f12 Event
Description:
'A' Recirc M-G Flow Controller oscillations Cause: Failure in the 'A' flow controller Effects: 1. - Jet pump flow oscillation
- 2. Total flow oscillations 3, Reactor level oscillations
- 4. 'A' Recirc parameter changes
- 5. Reactor power oscillations Position Applicant's Actions or Behavior URO Recognize and report the 'A' Recirc pump (controller) oscillations Recognize and report the oscillations as an entry into OT-112 "Unexpected/Unexplained Change in Core Flow",
URO may lockup the 'A' Recirc M-G set without direction at this time.
CRS Enter and execute OT-112 "Unexpected/Unexplained Change in Core Flow".
- Plot conditions on the Power to Flow map
- Direct monitoring for THI Direct the URO to Lock-up the 'A' Recirc pump by placing the Scoop Tube switch to "LOCK" at pane120C004A.
Refer to SO 20.7.8-2 "Recirculation MG Set Scoop Tube Lockup and Reset", especially for transient and scram actions for a locked up Recirc pump.
Verify the Jet pump flow mismatch is within:
- 10.25 Mlbm/hr IF total core flow < 71.75 Mlbm/hr
- 5.125 Mlbm/hr IF total core flow >71.75 Mlbm/hr Direct that reactor power be maintained ~ 95% based on Event 1.
(May) dispatch a licensed operator to manually operate the 'A' Recirc pump using AO 20.2-2 "Recirculation MG Set Scoop Tube Manual Operation" .
U~O "Lock up" the 'A' Recirc MG Set if not already completed.
Monitor for THI 2013 NRC Scenario #2 - T-I 03 HPCI Steam Leak, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 4 Page: 50f12 Event
Description:
Inadvertent HPCI initiation Cause: Initiation relay contacts short closed Effects: 1. Alarms:
- 222 D-5 "HPCI Auxiliary Oil Pump Running"
- 228 C-5 "HPCI Relays Not Reset"
- 2. HPCI injection to the reactor; reactor water level and reactor power increase Position Applicant's Actions or Behavior PRO Recognize and report HPCI initiation.
Verify, using at least two independent indications, misoperation of HPCI and/or adequate core cooling is assured.
URO Recognize and report entry into OT-104 "Positive Reactivity Insertion" and OT-110 "Reactor High Level".
Control feed pump speed I discharge pressure as necessary to maintain reactor water level below +35 inches.
CRS Enter and execute OT-104 "Positive Reactivity Insertion".
- Verify, using at least two independent indications, misoperation of HPCI and/or adequate core cooling is assured.
- Direct HPCI short term shutdown in accordance with RRC 23.1-2 "HPCI System Operation during a Plant Event".
Enter and execute OT-110 "Reactor High Level".
- Direct maintaining reactor water level below +35 inches.
Review Tech Spec 3.3.5.1 and determine Condition B applies:
- Declare HPCI inoperable within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
- Place the channel in trip within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Review Tech Spec 3.5.1 and determine Condition C applies:
- Verify RCIC operability immediately.
- Restore HPCI to operable status within 14 days.
May reference GP-25 "Installation of Tripsllsolations to Satisfy Tech SpeclTRM Requirements for Inoperable Instrumentation.
Request Maintenance and/or I&C assistance in investigating cause of inadvertent HPCI initiation.
20.1 3 NRC Scenario #2 - T- 103 HPCI Steam Leak, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 4 Page: 6 of 12 Event
Description:
Inadvertent HPCI initiation (continued)
Position Applicanfs Actions or Behavior PRO Perform RRC 23.1-2 "HPCI System Operation During a Plant Event",
Section E, "HPCI Shutdown With Initiation Signal Present (short-term shutdown):
- Place Aux Oil Pump control switch in START.
- Place Vacuum Pump control switch in START.
- Depress and hold Remote Trip pushbutton.
- When turbine speed reaches - 0 RPM, place Aux Oil Pump control switch in P-T-L and release the Remote Trip pushbutton.
2013 NRC Scenario #2 - T-I03 HPCI Steam Leak, Rev O.doc
Operator Actions' ES-O-2 Op Test No.: 1 Scenario No.: 2 Event No.: 5 Page: 70f12 Event
Description:
HPCI steam leak into Secondary Containment Cause: Urilsolable HPCI steam line break in the HPCI room Effects: Secondary containment temperature will increase. First alarm to actuate is 210 J-3 "High Area Temp". This will cause an entry into T-103 "Secondary Containment Control".
Position Applicant's Actions or Behavior PRO/URO Recognize and report the "High Area Temp" alarm (210 J-3) and enter the correspond Alarm Response Card.
Recognize and report the Fire Panel alarm (007 D-6 Lower).
PRO Report the rise in HPCI room temperature (Point #3).
Report the temperature alarm as an entry into T -103 "Secondary Containment Control".
CRS Enter and direct T-103 "Secondary Containment Control".
- Monitor and control secondary containment temperatures.
- Perform a local evacuation lAW GP-15.
- Direct operators to isolate HPCI.
- Determine a primary system is discharging into the Reactor Building.
PRO Monitor secondary containment temperatures on TR-2-13-139.
Inform the CRS of the inability to isolate HPCI.
Perform a GP-15 local evacuation as directed.
2013 NRC Scenario #2 - T-103 HPCI Steam Leak. Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 2 Event No.: 5 Page: 8 of 12 Event
Description:
HPCI steam leak into Secondary Containment (continued)
Position Applicant's Actions or Behavior CT CRS Direct a GP-4 "Manual Reactor Scram" before HPCI room temperature (Point #3) exceeds the action level of 150 degrees F.
Enter and direct T-101 "RPV Control".
CT URO Perform GP-4 "Manual Reactor Scram" as directed:
- Place the mode switch to SHUTDOWN.
- Verify control rods are inserting.
- Verify APRMs are downscale.
- When reactor level begins to recover, then "Emergency Stop" all 3 RFPTs.
- Depress "SLOW RAISE" or "FAST RAISE" on the RFPT to remain in service.
- Establish and maintain reactor level control with feedwater.
- Verify all control rods are inserted.
- Verify reactor pressure, trend, and status of EHC.
- Notify health physics of changing plant conditions.
PRO Perform GP-4 "Manual Reactor Scram" as directed:
- Transfer 13 KV house loads.
- Trip main turbine when less than 50 MWe.
- Verify main generator lockout. (See Event 6)
- Verify Group II and III isolations and SGTS initiation.
- Verify scram discharge volume vents and drains are closed.
- Verify hydrogen water chemistry is isolated.
- Verify both recirc pumps speed have runback to 30%.
- Monitor instrument air header pressure and drywell pressure.
2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 5 Page: 90f12 Event
Description:
HPCI steam leak into Secondary Containment (continued)
Position Applicant's Actions or Behavior CRS Direct the URO to control reactor level between +S" to +3S" with feedwater.
Direct the PRO to bypass and restore instrument nitrogen to the drywell.
URO Control reactor level between +S" to +35" with feedwater.
PRO Bypass and restore drywell instrument nitrogen lAW RRC 94.2-2 or GP-8E.
- Place AO-2969A control switch to "CLOSE".
- Place AO-2969B control switch to "CLOSE".
- Place AO-2969A control switch to "OPEN".
- Place AO-2969B control switch to "OPEN".
CRS Direct reactor depressurization to SOO-600 psig lAW T-101 "RPV Control" URO/PRO Perform reactor depressurization to 500-600 psig using the Bypass Valves, as directed.
2013 NRC Scenario #2 - T -103 HPCI Steam Leak, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 2 Event No.: 6 Page: 10 of 12 E'fent
Description:
Generator lockout fails to occur following Main Turbine trip Cause: Failure in the generator lockout circuit Effects: Main Generator output breakers fail to open Main Generator exciter field breaker fails to open Position Applicant's Actions or Behavior PRO Recognize the failure of the Main Generator lockout while performing PRO scram actions.
Open the Main Generator output breakers (215 BKR and 225 BKR).
Open the exciter field breaker (ALT EXC FLD BKR 41-0601).
Report to the CRS that the Main Generator lockout failed and that you manually opened the Main Generator output breakers and the field breaker.
2013 NRC Scenario #2 - T-103 HPCI Steam Leak, Rev O.doc
Operator Actions Op Test No.: 1 Scenario No.: 2 Event No.: 7 Page: 11 of 12 Event
Description:
rc' reactor feedpump discharge bypass valve fails to open Cause: Failure of the motor operator for MO-8090 ('C' feed pump discharge bypass) to engage and open the valve Effects: Reactor level must be controlled using the RFP discharge valve and not the RFP bypass, complicating post-scram and post blowdown Reactor level control.
Position Applicant's Actions or Behavior URO Recognize the failure of MO-8090 to open during URO scram actions.
Throttle open RFP discharge valve MO-2149A, B or C.
Maintain reactor level by controlling RFP discharge valve position and RFP speed (pump discharge pressure).
NOTE: when RFP's are no longer available (e.g., following emergency depressurization), the RPF discharge valve must be throttled to control Condensate flow to the reactor.
2013 NRC Scenario #2 - T-I03 HPCI Steam Leak, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 2 Event No.: 8 Page: 12 of 12 Event
Description:
Emergency blowdown due to exceeding Reactor Building temperature limits in more than one area Cause: Steam leak in the Reactor Building continues to degrade Secondary Containment parameters Effects: Reactor depressurization via Bypass Valves and ADS SRVs Position Applicant's Actions or Behavior CT CRS When a second Reactor Building area temperature approaches the Action Level, direct the URO to perform a rapid depressurization using T-101, RC/P-12.
CT URO Rapidly depressurize the reactor by opening all Main Turbine bypass valves.
CT CRS When the same parameter exceeds an action level in more than one area (HPCI Room and Torus Room) and the primary system breach has not been isolated, enter and execute T-112 "Emergency Blowdown":
- Verify torus level is above 7 feet.
- Verify reactor pressure is 50 psig or more above torus pressure.
CT PRO When directed, open 5 ADS SRVs by placing their control switches in OPEN.
POST SCENARIO EMERGENCY CLASSIFICATION:
- Classification is a Site Area Emergency lAW EAL FS1, Based on a Loss of the Primary Containment Barrier and a Loss of the Reactor Coolant System Barrier.
- Based on the scenario conditions and expected outcome, the CRS should determine that there is a Release in Progress.
TERMINATION CRITERIA:
The scenario may be terminated when 5 SRVS are open, the reactor is depressurized, and reactor level is under control.
2013 NRC Scenario #2 - T -103 BPCI Steam Leak, Rev O.doc
Scenario Outline ES-I)...J Simulation Facility Peach Bottom Scenario No. #3 Op Test No. 2013 NRC Examiners Operators _ _ _ _ _ _ _ _ CRS (SRO)
_ _ _ _ _ _ _ _ URO (ATC)
_ _ _ _ _ _ _ _ PRO (BOP)
Scenario The scenario begins with the reactor at 100% power. After taking the shift the crew is required to Summary swap operating TBCCW pumps for inspection of a noisy bearing on the 'A' TBCCW pump.
Next, an individual control rod drive scram accumulator will experience low pressure and alarm in the main control room. The crew will initiate corrective action but the accumulator pressure will remain low requiring the crew to declare the control rod slow or inoperable per Technical Specifications.
Shortly after this. the E-4 diesel generator will inadvertently start, requiring the crew to shutdown the E-4 diesel generator and apply Technical SpeCifications for an inoperable diesel generator.
The crew should then recognize and respond to lowering main condenser vacuum caused by a failure of the in service steam jet air ejector steam supply valve. The crew must enter OT-106 "Condenser low Vacuum" and reduce reactor power in accordance with GP-9-2 "Fast Power Reduction".
Following the power reduction, a turbine lube oil malfunction will result in a high bearing temperature and vibration condition for the main turbine, requiring the crew to scram the reactor and trip the main turbine. A CRD hydraulic malfunction will result in a low-power A TWS, requiring the crew to execute T-101"RPV Control>> and T-117 "level/Power Control." In addition. the scram discharge volume (SDV) will fail to completely isolate, requiring the crew to manually isolate the SDV.
When SBlC is initiated the SBlC pump will trip. requiring the LlRO to place the alternate SBlC pump in service. The second SBlC pump will trip shortly after being placed in service. A failure of the only available EHC pump will cause the turbine bypass valves to close, requiring the crew to utilize HPCI andlor SRVs for reactor pressure control. The crew should perform T-220 "Driving Control Rods During Failure to Scram" to insert control rods. The crew will need to adjust control rod drive water pressure in order to successfully insert the control rods. The scenario may be terminated when the crew has control of RPV power and level using T-240 "Termination and Prevention of Injection into the RPV" and the crew is inserting control rods.
Initial IC-120, 100% power Conditions Turnover See Attached "Shift Turnover>> Sheet Event Malfunction Event Event No. No. Type* Description 1 See Scenario Guide N PRO Swap operating TBCCW Pumps CRS 2 See Scenario Guide TS CRS Individual control rod drive scram accumulator low pressure (Tech Spec) 3 See Scenario Guide I PRO E4 diesel generator spurious start I diesel generator shutdown TS CRS (Tech Spec) 4 See Scenario Guide C PRO Failure of Steam Jet Air Ejector steam supply valve I re-open by plaCing additional valve air supply in service 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
Event Malfunction Event Event No. No. Type- Description 5 See Scenario Guide R URO Fast reactor power reduction (wI recirc)
CRS 6 See Scenario Guide C URO Main turbine high temperature and vibration I reactor scram CRS 7 See Scenario Guide M All ATWS (hydraulic) I turbine bypass valves fail closed 8 See Scenario Guide C URO Standby liquid control (SBlC) pump trips I start second SBlC pump CRS Isecond pump trips
. 9 See Scenario Guide C PRO Two in-series scram discharge volume (SDV) vent valves fail to CRS automatically isolate 10 See Scenario Guide C URO low CRD drive water pressure I adjust to drive control rods
.. (N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)aJor, (T8) Tech Spec 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
SIMULATOR OPERATOR INSTRUCTIONS FOR 2013 NRC SCENARIO #3 GENERAL REQUIREMENTS
- Recorders will be rolled prior to the scenario and paper from selected recorders will be retained for the examination team as requested.
- All procedures. flow charts, curves, graphs. etc. will be in their normal storage places.
- All markable procedures, boards, etc. will be erased.
- All paper used by the crew will be retained for the examination team as requested.
- The simulator operators will keep a log of all communications during the scenario as requested by the examination team.
SCENARIO SOURCE HISTORY
- This Scenario originated from the 2007 NRC Initial License Exam. It was significantly modified for the 2009 and 2010 CERT Exams. It has been altered here by replacing Event 1, adding new events 4 and 10, and deleting an event.
INITIAL SETUP Initial Conditions
- IC-120, 100% power (created from IC-14)
- Ensure recorder power is on; roll recorders as required
- Ensure annunciator horns are active Blocking Tags
- Apply Information Tag to the 2B EHC Pump control switch
.
- Apply Information Tag to Annunciator 205 K-3 EHC STANDBY PUMP NOT IN AUTO Activate APP "2013_NRC_SCN3" or insert the following:
Event Triggers TRG E5 REACTOR_MODE_SWITCH_NOT_IN_RUN TRG E6 RPV_LEVEL_LE_ -48 TRG E7 SBLC_SWITCH_IN_START-A TRG E8 SBLC_SWlTCH_IN_START-B TRG E9 SDV_INBD_NOT_IN_AUTO TRG E10 SDV_OUTBD_NOT_IN_AUTO TRG Eii MO_3_20_CLOSE TRG E5 = DMF IPM03 TRG =
E7 DMF SLCOi B TRG E8 = DMF SLC01 A TRG E9 ::I DMF CRH09B TRG =
Ei0 DMF CRH09D TRG E11 = MMF CRH01A (none 0 0) 55 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
Malfunctions IMF CRH09B (none 00) (inboard SDV vent valve fails to isolate)
IMF CRH09D (none 00) (outboard SOV vent valve fails to isolate)
IMF IPM03 (none 0 0) 80 0 0 (hydraulic ATWS)
IMF SLC01A (none 0 0) (SBlC Pump A trip)
IMF SLC01 B (none 0 0) (SBlC Pump B trip)
IMF CAR01 (E3 0 0) 2 0 0 (Main Condenser air in-leakage at 2% severity)
IMF MTA01B (E4 0 0) 100 10:00 0 (Main Turbine bearing 'B' high temperature)
IMF MTA02B (E4 0 0) 100 10:00 0 (Main Turbine bearing 'B' high vibration)
IMF MTA02C (E4 0 0) 100 10:000 (Main Turbine bearing 'c' high vibration)
IMF EHH04A (E6 2:000) (2A EHC pump trip ... 2 minutes after RPV level ~ -48 inches)
IMF EHH02A (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level ~ -48 inches)
IMF EHH02B (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level ~ -48 inches)
IMF EHH02C (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level::: -48 inches)
IMF EHH02D (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level ~ -48 inches)
IMF EHH02E (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level::: -48 inches)
IMF EHH02F (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level ~ -48 inches)
IMF EHH02G (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level ~ -48 inches)
IMF EHH02H (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level ~ -48 inches)
IMF EHH021 (E6 4:00 0) (Bypass valves fail closed 4 minutes after RPV level::: -48 inches)
IMF CRH01A (E8 0 0) 5 (CRD flow control valve fails to 5% open on start of B SBlC pump)
- Overrides lOR ZLOTC08A2BP17_1 (none 0 0) OFF (Block 2B EHC pump green light) lOR ZYP01A6S39 (none 0 0) STOP (Block 2B EHC pump control switch) lOR ZYP04A8S04 (E1 02) START (E-4 OG QUICK START pushbutton) lOR ZYP02A6S28 (E8 0 15) OPEN (MO-2-3-20 strokes open for 15 seconds after B SBlC pump is started) lOR ZYP02A6S27 (E816 2) THROTTLE (MO-2-3-20 open stroke is stopped 16 seconds after starting by depressing throttle pushbutton for 2 seconds)
Trip Overrides None Turnover Procedures None 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
SIMULATOR OPERATOR DIRECnONS EVENT 1 Support crew for TBCCW pump swap in accordance with SO 34.6.A-2.
- When directed, report Step 4.1 of SO 34.6.A-2 is complete.
- When directed per Step 4.2.1 of SO 34.6.A-2, report 'B' TBCCW pump discharge pressure is 85 pSig.
- When directed per Step 4.4 of SO 34.6.A-2, report 'B' TBCCW pump discharge pressure is 85 pSig.
EVENT 2 After the swap of TBCCW pumps, initiate ET2 (lMF CRH051423) to cause a low HCU accumulator alarm condition for control rod 14-23.
. When directed to go to the HCU for rod 14-23 per ARC 211 E-2, WAIT 2 minutes and report an unisolable leak on the accumulator and pressure is 900 psig and slowly lowering.
EVENT 3 After the Tech Spec determination is competed, or when directed by the Lead Examiner, initiate ET1 (lOR ZYP04A8S04 START) to cause a spurious start of diesel generator E4.
After the E4 diesel starts, verify override ZYP04A8S04 is deleted.
If directed to perform running inspection of E4 EDG, report as the Equipment Operator the E4 diesel is running and everything appears normal.
EVENTS 4 & 5 After the TS requirements have been determined for the EDG spurious start, or when directed by the Lead Examiner, insert Remote Function IRF MSS05A 'A' SJAE Steam Isolation Valve AO-2466A CLOSE to close AO-2466A and initiate a main condenser low vacuum condition.
Support the crew for GP-9, "Fast Power Reduction". Role-playas the Power System Director when called.
IF the Lead Examiner requires additional GP-9 power reduction, initiate ET3 (IMF CAR01 200) to cause Main Condenser air in-leakage at 2% severity. (NOTE: With NO power reduction, appox 2 minutes to Cond Lo Vac alarm.) THEN MMF CAR011 1 :00 0 to reduce the severity of the condenser in-leakage to 1% severity.
EVENT 6 After power is reduced, or as directed by the Lead Examiner, initiate ET4 and verify the following malfunctions:
- IMF MTA01B 100 10:00, "Main Turbine Bearing B High Temperature."
- IMF MTA02B 100 10:00, "Main Turbine Bearing B High Vibration."
- IMF MTA02C 10010:00, "Main Turbine Bearing C High Vibration."
If directed to investigate the main turbine, wait 5 minutes and when bearing #2 is
. above 225 degrees F (PMS shortcut "TGB"), report there is no oil flow to #2 bearing.
2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
SIMULA TOR OPERA TOR DIRECTIONS EVENT 7 Pre-inserted malfunction will result in a hydraulic A TWS When the mode switch is placed in SHUTDOWN (i.e .. not in RUN). verify trigger ET5 (DMF IPM03) deletes the A TWS malfunction.
When RPV level is lowered to -50 inches, verify trigger ET6 (IMF EHH04A) initiates
_a trip of the 'A' EHC pump 2 minutes later.
When requested to perform T-221 , wait 5 minutes then MRF T221_1 DEFEAT "Remove Low RPV Level/GP1 Isolation".
After 5 minutes report to the MCR by phone that T-221 jumpers (step 4.1) have been installed.
When requested as the Equipment Operator to perform T-216 steps 4.1 and 4.2, acknowledge direction but DO NOT COMPLETE THE TASK.
EVENT 8 Pre-inserted malfunctions will trip the 'A' or 'B' Standby liquid Control pump; whichever one is placed in service first. When the 'A' or 'B' SLC pump is started.
VERIFY the trip malfunction for the other pump is deleted:
When the B SLC Pump is started verify the following override initiates:
- lOR ZYP02A6S28 (E8 0 15) OPEN (opens MO-2-3-20 for 15 seconds after B SLC pump is started to lower CRD drive water pressure)
- lOR ZYP02A6S27 (E8 162) THROTTLE (stops the open stroke for MO-2 3-2016 seconds into its open stroke)
- lOR CRH01A (E8 0 0) 5 (CRD flow control valve fails to 5% open on start of B SBLC pump)
One minute after the standby SLC pump is started, trip the pump by inserting malfunction IMF SLC01A or SCL01 B (trip of a or B SLC pump)
EVENT 9 Two SDV vent valves (AO-0328 and AO-03S8) fail to automatically isolate on the scram - pre-inserted.
When the crew manually isolates the SDV vent valves, verify the following:
- TRG E9 =DMF CRH09B
SIMULATOR OPERATOR DIRECTIONS EVENT 10 -IF the operator strokes closed MO-2-3-20 to raise CRD drive water pressure, verify initiation of MMF CRH01A (none 0 0) 55 (repositions CRD flow control valve to 55%
open TERMINATION The scenario may be terminated when the crew has control of RPV power and level using T-240 "Termination and Prevention of Injection into the RPV" and the crew begins inserting control rods per T-220.
)013 NRC Scenario #3 - T -117 Hydraulic ATWS. Rev O.doc
SHIFT TURNOVER PLANT CONDITIONS:
- Unit 2 is at 100% power INOPERABLE EQUIPMENT/LCOs:
- Swap running TBCCW Pumps per SO 34.B.A-2. Noisy bearing on the lA' TBCCW pump motor; maintenance to install monitoring instrumentation.
SURVEILLANCES DUE THIS SHIFT:
- None ACTIVE CLEARANCES:
- 2B EHC pump GENERAL INFORMATION:
- None 2013 NRC Scenario #3 - T -117 Hydraulic ATWS, Rev O.doc
CRITICAL TASK LIST
- 1. Inhibit ADS before an automatic depressurization occurs.
- 2. Before torus temperature exceeds the limits of the Heat Capacity Temperature Limit (HCTl) curve, lower reactor power by performing T-240 "Terminating and Preventing Injection" to lower RPV level until:
- a. Reactor power is below 4%, OR
- c. All SRVs remain closed and drywell pressure is below 2 psig.
- 3. Initiate a reactor shutdown by inserting control rods in accordance with T-220 "Driving Control Rods During Failure to Scram" and/or shutdown the reactor by initiating Standby Liquid Control before torus temperature exceeds the limits of the Heat Capacity Temperature Limit (HCTl) curve.
2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 3 Event No.: 1 Page: 10f13 Event
Description:
Swap TSCCW pumps Cause: Noisy bearing on the 'A' TSCCW pump motor; maintenance to install monitoring instrumentation Effects: N/A Position Applicants Actions or Behavior CRS Direct the PRO to perform SO 34.6.A-2 "Placing the Standby Turbine Building Closed Cooling Water System Pump in Service."
PRO Perform SO 34.6.A-2 "Placing the Standby Turbine Building Closed Cooling Water System Pump in Service,"
- Contact the Equipment Operator to perform SO 34.6.A-2 Step 4.1 to vent the 'B' TBCCW pump and verify it ready for start NOTE: MCR TBCCW discharge pressure indication reads lower than local indication.
- Start the 'B' TBCCW pump and direct the EO to verify discharge pressure is greater than 70 psig on local pressure indicator.
- Stop the 'A' TBCCW pump and place it in AUTO.
- Direct the EO to verify discharge pressure of running pump is greater than 70 psig and less than or equal to 87 psig on local pressure indicator.
- Inform the CRS and Maintenance the pump swap is complete, URO Monitor plant parameters and assist as directed.
2013 NRC Scenario #3 - T-117 Hydraulic ATWS. Rev O.doc
Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 3 Event No.: 2 Page: 20113 Event
Description:
Individual control rod drive scram accumulator low pressure Cause: Leaking CRD HCU accumulator Effects: 1, Alarms:
- 211 E-2 HCRD Accum Lo Pres I Hi Level" 2, Control rod must be declared SLOW or INOPERABLE per Tech Spec, Position Applicant's Actions or Behavior URO Acknowledge and report alarm 211 E-2 HCRD Accum Lo Pres I Hi Level" Recognize alarm condition is for control rod 14-23.
Reference the corresponding Alarm Response Card.
CRS Reference Alarm Response Card 211 E-2 "CRD Accum Lo Pres I Hi Level",
Direct that an Equipment Operator is dispatched to HCU 14-23, URO Dispatch an Equipment Operator to HCU 14-23 CRS Upon field report of leaking HCU accumulator. references Tech Spec 3.1,5 for control rod scram accumulators.
Recognizes Tech Spec 3.1.5 Condition A applies.
Declare control rod 14-23 SLOW or INOPERABLE within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 3 Event No.: 3 Page: 30f13 Event
Description:
E4 diesel generator spurious start Cause: Spurious automatic start signal r:ffects: 3. Alarms:
- 005 F-4 "E4 Diesel Running"
- 002 A-5 "Emergency Service Water Pump Auto Start"
- 212 B-2 "Emergency Cooling Water Pump Auto Start"
- 4. The diesel will continue to run until manually shutdown ... it should not be left running for long periods unloaded due to accumulation of oil in the exhaust manifold.
Position Applicanfs Actions or Behavior PRO Acknowledge and report alarm 005 F-4 "E4 Diesel Running" and enter corresponding Alarm Response Card.
- Red flag the E4 Diesel Generator control Switch by placing the control Switch to "START' Recognize the E4 diesel is running unloaded.
Verify diesel automatic response using SO 52B.1.B "Diesel Generator Automatic Start".
- Verify an ESW pump started.
o Check pump discharge pressure (PI-0236A (8>> "DISCH PRESS" 25 to 64 psig.
o Check pump motor current "AMPS" 25 to 35 amps.
- Red-flag the ESW pump to remain in service.
- Shutdown the remaining ESW pump per ARC-002 A-5.
- Direct an Equipment Operator to perform a running inspection of the E-4 diesel generator.
NOTE: the Lead Examiner, acting as the Shift Manager, may prompt the CRS to remove the E-4 diesel generator from service (do NOT perform a 2-hour load run).
CRS Per SO 52B.1.B (step 4.7), direct a shutdown of the E-4 diesel generator lAW the applicable steps of section 4.5 of SO 52A.1.B "Diesel Generator Operations".
(May) direct placing the E4 diesel in Pull-to-Lock.
Request Maintenance and/or I&C assistance in troubleshooting E4 diesel generator spurious start.
2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 3 Event No.: 3 Page: 40f13 Event
Description:
E4 diesel generator spurious start (continued)
Position Applicant's Actions or Behavior PRO Shutdown the E4 diesel lAW SO 52A 1.B:
- Place the E4 diesel generator control switch to "STOP".
- Direct the Equipment Operator to continue with the E4 diesel shutdown in accordance with SO 52A 1.B, section 4.5.
Place the E4 diesel in Pull-to-Lock, as directed.
CRS Declare the E-4 diesel inoperable.
Review Tech Spec 3.8.1 and determine Condition B applies:
- Verify alignment/availability of the Conowingo tie line immediately.
- Verify breaker alignment for operable offsite circuits within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
- Restore the E-4 diesel generator to operable status within 14 days.
2013 NRC Scenario #3 - T -117 Hydraulic ATWS, Rev O.doc
Operator Actions ES-D-2 OpTestNo.: 1 Scenario No.: 3 Event No.: 4& S Page: Sofi3 Event
Description:
Failure of Steam Jet Air Ejector steam supply valve I fast reactor power reduction Cause: leak in normal air supply to steam supply valve Effects: 1. Alarms:
- 201 J-3, uHWC System Trip"
- 204 0-5, "SJAE Disch Hi/lo Press"
- PMS Major: Off Gas Flow
- 2. GP-9 "Fast Power Reduction" required due to degraded main condenser vacuum Position Applicant's Actions or Behavior URO/PRO Acknowledge and report alarms:
- 201 J-3. "HWC System Trip"
- 2040-5, "SJAE Disch Hilla Press" Recognize and report A SJAE steam supply isolation valve AO-2466A closed on Panel 20C006B.
Recognize and report lowering main condenser vacuum.
CREW Enter and execute OT-106 "Condenser low Vacuum" URO Reduce reactor power in accordance with GP-9-2 "Fast Power Reduction" until vacuum stops lowering.
- lower recirculation flow as required to a value of no lower than 61.5 Mlbs/hr.
- Stop power reduction when main condenser vacuum stops lowering andlor begins to improve.
CRS Recognize that step 3.8 of OT-106 applies to present condition (AO 2466A closed)
Directs PROto perform step 3.8 of OT-106.
PRO Place control switch "Alt Instr Air AO-2-0BA-2466A" to OPEN on Panel 20C007A.
Verify A0-2-08A-2466A indicates open at Panel 20C006B.
Place PIC..;2239A "A Steam Press" in MANUAL on Pane120C007A.
Restore SJAE steam supply pressure to between 115 and 125 pSig.
2013 NRC Scenario #3 - T -I 17 Hydraulic ATWs" Rev O.doc
Operator Actions ES-D-2 Qp Test No.: 1 Scenario No.: 3 Event No.: 6 Page: 60f13 Event
Description:
Main turbine high temperature and vibration I reactor scram Cause: Lack of lube oil flow to the #2 main turbine bearing Effects: 1. Initial Alarms:
- Alarm 205 H-4, "Turbine Bearing Metal Hi Temp"
- Alarm 205 A-2, "Turbine Vibration I Thrust High"
- 2. Turbine bearing temperature and vibrations will rise. With no operator action, the main turbine will (eventually) automatically trip.
Time PQ.Sition Applicanfs Actions or Behavior URO/PRO Recognize and report alarm 205 H-4, "Turbine Bearing Metal Hi Temp" and enter corresponding Alarm Response Card.
Identify affected bearing on temperature recorder TR-2401.
Check turbine lube oil temperature on TR-2401, and increase cooling water to lube oil coolers, if necessary.
Check vibration of the affected bearing on VR-2657.
Dispatch operator to check for proper oil flow and local temperature at the affected bearing.
CRS Direct operator actions lAW ARC 205 H-4, 'Turbine Bearing Metal Hi Temp" and 205 A-2, "Turbine VibrationlThrust High".
Direct the reduction of turbine load lAW GP-9-2, "Fast Power Reduction" (the CRS may go directly to GP-4 "Manual Reactor Scram").
URO Perform a GP-9-2 "Fast Power Reduction" as directed.
CRS When bearing metal temperature increases to 250 degrees F, then direct a manual scram lAW GP-4 "Manual Reactor Scram" then direct the PRO to trip the Main Turbine (see next event).
PRO When directed by the CRS, or when bearing metal temperatures exceed 250 degrees F, then trip the Main Turbine.
20 13 NRC Scenario #3 - 1'-117 Hydmulic ATWS, Rev O.doc
ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 7 Page: 70f13 Event
Description:
ATWS - hydraulic / turbine bypass valves fail closed Cause: Control rods insert to various positions due to limited Scram Discharge Volume Effects: Requires the crew to take actions to terminate the ATWS, as well as control RPV level/power Position Applicant's Actions or Behavior URO Perform GP-4 "Manual Reactor Scram":
- Reduce recirc flow controllers to minimum (20% demand)
- Place the mode switch to "SHUTDOWN".
- Verify control rods are inserting.
- Report APRMs are NOT downscale and that an ATWS is in progress with reactor power> 4% (T*,101 entry condition).
- Depress manual scram push buttons on Pane120C005A.
PRO Perform GP-4 "Manual Reactor Scram":
- Transfer 13 KV house loads using RRC 53.1-2.
CRS Enter/direct actions for T-101 "RPV Control":
- Verify URO/PRO scram actions.
- Direct tripping of the Main Turbine.
- Direct drywell instrument nitrogen restored.
- Direct actions for the ATWS (see later in this event).
2013 NRC Scenario #3 - T-117 Hydraulic ATWS. Rev O.doc
Operator Actions ES-D-2 OpTest No.: 1 Scenario No.: 3 Event No.: 7 Page: 80f13 Event
Description:
A TWS - hydraulic / turbine bypass valves fail closed (continued)
Position Applicant's Actions or Behavior PRO Trip the Main Turbine by depressing the "TRIP" pushbutton.
Stabilize reactor pressure below 1050 psig as directed using HPCI and/or SRVs.
When the isolation occurs (+1 inch RPV level):
- Verify Group II & III isolations and SGTS initiation.
- Verify HWC isolated.
- Place AO-2969A control switch to "CLOSE".
- Place AO-2969B control switch to "CLOSE".
- Place AO-2969A control switch to "OPEN".
- Place AO-2969B control switch to "OPEN".
NOTE: this activity may be coordinated between the URO and the PRO.
CRS DirectT-101, RC/QATWS actions:
- Initiation of ARI
- Trip recirc pumps at least 10 seconds apart CT
- T-220 "Driving Control Rods During Failure To Scram" CT
- Enter T-117 "Level/Power Control"
- SLC injection LlRO Perform T-101, RC/Q actions:
- Initiate ARI using RRC 3B.1-2, "ARI During a Plant Event"; report the scram air header is depressurized.
- Trip Recirc pumps at least 10 seconds apart.
- Direct an Equipment Operator to perform T-216 steps 4.1 and 4.2 (install jumpers in Cable Spreading Room and Main Control Room to defeat ARllnitiation Logic and bypass all RPS Auto Scram signals).
- Perform T-220 "Driving Control Rods During Failure To Scram" (see Event #10).
2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 7 Page: 90f13 Event
Description:
ATWS - hydraulic I turbine bypass valves fail closed (continued)
Time Position Applicanfs Actions or Behavior CRS Direct T -117 actions:
- Inhibit ADS.
- T-221 "Main Steam Isolation Valve Bypass".
- T-240 per Attachment 1 Figure 2 if:
o RPV level is > -172" and, o Reactor power is > 4% and, o An SRV is open and Drywell pressure> 2 psig and, o Torus temperature is > 110°F URO/PRO Perform T-117 actions:
- Direct 3rd Reactor Operator (via phone or radio) to perform T-221.
- Perform T -240: terminate and prevent injection from all injection sources except RCIC, SLC and CRD; control RPV level below -60 inches and within the specific RPV level band directed by the CRS.
o Place HPCI Aux Oil Pump in the "Pull-te-Lock" position.
o Press "Emergency Stop" for aU reactor feed pumps.
o Close reactor feed pump discharge valves MO-2149A, B, C.
o Verify closed MO-8090 "C RFP Discharge Bypass".
2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 3 Event No.: 7 Page: 10 of 13 Event
Description:
ATWS - hydraulic I turbine bypass valves fail closed (continued)
Time Position Applicant's Actions or Behavior URO/PRO When RPV level is below -60 inches, restore injection and maintain RPV level between -60 and -195 inches as follows:
- Using Feedwater:
o Place LlC-8091 in "MAN" and close the valve.
o Open MO-8090"C RFP Bypass>>.
o Raise RFP speed until discharge pressure is75-100 psig above RPV pressure.
o Control RPV injection by adjusting RFPT speed, OR LlC8091 setting, OR MO-2149C "RFP C Discharge" valve position.
- Using HPCI (manual initiation):
o Arm and depress the "HPCI Manual Initiation" pushbutton.
o Verify MO-2-23-014 "Supply" opens.
o Verify the aux oil pump starts.
o Verify MO-2-23-019 "To Feed Line" opens.
o Verify vacuum pump starts.
o Verify AO-2-23-042 and AO-2-23-043 "Drain Isol to Mn Cndr" close.
o Adjust HPCI flow controller setpoint to the desired RPV injection rate.
URO/PRO Recognize loss of only available EHC Pump.
Recognize complete loss of EHC System and eventual loss of turbine bypass valves for RPV pressure control.
CRS Direct RPV pressure control using SRVs and/or HPCI.
URO/PRO Control RPV pressure using SRVs and/or HPCI to stay below 1050 psig, OR to stay on safe side of T-102 Curve T/L-1 "SRV Tail Pipe Limit", as applicable.
URO/PRO Place Torus cooling in service using RRC 10.1-2
- Open MO-2-10-39A(B)
- Open MO-2-32-89A (B, C, or D)
- Start a HPSW Pump
- Start an RHR Pump
- Open MO-2-10-34A(B)
- Place additional pumps in service as required
- Direct an Equipment Operator to close stay full injection valve(s) for the RHR loop(s) in service 2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 8 Page: 11 of 13 Event
Description:
Both standby liquid control (SLC) pumps trip Cause: First SLC pump placed into service trips immediately on overcurrent Second SLC pump trips on overcurrent approximately 1 minute after being placed in service Effects: SLC system will not be available to mitigate the effects of the A ms. Reactor power must be reduced using T-240, "Termination And Prevention Of Injection Into The RPV' and T-220, "Driving Control Rods During Failure To Scram".
Position Applicant's Actions or Behavior URO Recognize the Standby Liquid Control (SLC) pump placed into service has failed to start (pump immediately trips).
Place the standby SLC pump in service using keylock control switch on the 20C005A panel.
Recognize that the standby SLC pump also tripped approx. 1 minute after being placed in service.
CRS Acknowledge SLC pump failure to start.
Direct placing the backup SLC pump in service, if not already done.
Acknowledge standby SLC pump trip.
2013 NRC Scenario #3 - T-117 Hydraulic ATWS. Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 9 Page: 12 of 13 Event
Description:
Two in-series scram discharge volume (SDV) vent valves fail to automatically isolate Cause: RPS failure in conjunction with an air header malfunction, which prevents air from venting off two SDV vent valves (common air supply).
Effects: A failure of the SDV vent valves is effectively a primary to secondary containment leak.
This requires manual isolation of the SDV vent valves.
Position Applicant's Actions or Behavior PRO Recognize and report failure of two SDV vent valves (AO-032B and AO 0358) to automatically isolate.
Upon recognizing failure to isolate, the PRO should:
- Manually isolate the valves by moving the SDV isolation hand switches counter-clockwise to the "Close" position.
- Verify all vent and drain valves are closed.
- Inform the CRS as conditions permit.
CRS Acknowledge SDV vent valve isolation failure.
Direct manual isolation of the SDV vent valves, if not already isolated.
NOTE: if the PRO scram actions (RRC 94.2-2) are not performed, or are delayed significantly, the SDV vent valve failure will result in T-103 and T-104 entry conditions, complicating this scenario.
2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 3 Event No.: 10 Page: 13 of 13 Event
Description:
Low CRD drive water pressure Cause: Blockage in the CRD hydraulic system Effects: Low pressure will prevent control rods from being inserted manually per T -220. The operator must manually adjust (close) drive water pressure control valve MO-2-3-20 in order to insert control rods.
Position Applicant's Actions or Behavior URO Perform T-220 "Driving Control Rods During Failure To Scram"
- Place FC-2-03-301 "CRD Flow Control" in MANUAL and open AO-2-3-19A "CRD Hydraulic System Flow Control" at Panel 20C005A.
- Attempt to insert control rods using the "Emergency In INotch Override" control switch on Panel 20C005A Recognize and report that control rods cannot be inserted due to drive water pressure being too low Raise CRD drive pressure by throttling closed MO-2-3-20 "Drive Water Pressure" at Panel 20C005A.
Insert control rods using the "Emergency In INotch Override" control switch on Panel 20C005A CRS Acknowledge report that control rods cannot be inserted due to drive water pressure being too low Direct closing of MO-2-3-20 if not already performed.
POST SCENARIO EMERGENCY CLASSIFICATION:
Classification is a Site Area Emergency lAW EAL MS2 (Scram condition >4% power with ARI not successful).
TERMINATION CRITERIA:
The scenario may be terminated when the crew has control of RPV power and level using T -240 "Termination and Prevention of Injection into the RPV" and the crew begins inserting control rods using T-220.
2013 NRC Scenario #3 - T-117 Hydraulic ATWS, Rev O.doc
Scenario Outline ES-()'I Simulation Facility Peach Sottom Scenario No. #4 Op Test No. 2013 NRC Examiners Operators _ _ _ _ _ _ _ _ CRS (SRO)
_ _ _ _ _ _ _ _ URO (ATC)
_ _ _ _ _ _ _ _ PRO (SOP)
Scenario The scenario begins with the reactor at approximately 6% power during a reactor startup.
Summary Following shift turnover, the crew is directed to secure drywell purge in preparation for inerting the drywell. Once drywell purge is secured, the 'B' drywell chiller will trip. The crew should place a standby drywell chiller in service in accordance with the system operating procedure. Next, a blown fuse will cause an ARt power supply failure, requiring the crew to initiate repairs and evaluate ARI RPT operability per Tech Specs.
Following the ARt failure, the crew should continue with the reactor startup by pulling control rods in accordance with the approved startup sequence. During this evolution a control rod will drift out, requiring the crew to execute ON-121 "Drifting Control Rod" and declare the affected control rod inoperable in accordance with Tech Specs. After the Tech Spec determination is made, while still executing ON-121, a second control rod will drift in, requiring the crew to perform an immediate reactor scram and enter T-100 "Scram" A subsequent trip of the 'C' reactor feed pump will complicate RPV level control post-scram.
While T-100 actions are in progress, a leak will develop in the torus, requiring the crew to enter T-103 "Secondary Containment Control" and T-102 "Primary Containment Control". When torus level reaches 12.5 feet, the crew will be directed to enter T-101 "RPV Control" and perform a depressurization.
A failure of the turbine bypass jack will require the crew to use alternate methods to depressurize the reactor in accordance with T-101 "RPV Control". Torus level will continue to lower to the point where the cr~w will be required to perform T-112 "Emergency Blowdown". The scenario may be terminated when the RPV is depressurized and HPSW is injecting into the torus.
Initial IC-121, 6% power Conditions Turnover See Attached *Shift Turnover" Sheet Event Malfunction Event Event No. No. Type" Description 1 See Scenario Guide N PRO Secure drywell purge CRS 2 See ScenariO Guide C PRO Drywell chiller trip I place standby chiller in service CRS 3 See Scenario Guide TS CRS ARI power supply failure (Tech Spec) 4 See Scenario Guide R URO Power ascension with control rods CRS
.5 See Scenario Guide C URO Drifting control rod (Tech Spec)
TS PRO CRS 2013 NRC Scenario #4 - T-I02 Torus Leak, Rev O.doc
Event Malfunction Event Event No. No. Type* Description 6 See Scenario Guide C ALL 2nd Drifting control rod, Manual Scram, T -100
.7 See Scenario Guide I URO 'C' reactor feed pump trip CRS 8 See Scenario Guide M ALL Torus leak into secondary containment I emergency blowdown 9 See Scenario Guide C PRO Turbine bypass jack fails, preventing rapid depressurization to the CRS main condenser
- (N)ormal, (R)eactivity, (I}nstrument. (C)omponent. (M)aJor, (TS) Tech Spec 2013 NRC Scenario #4 - T -102 Torus Leak, Rev O.doc
SIMULATOR OPERATOR INSTRUCTIONS FOR 2013 NRC SCENARIO #4 GENERAL REQUIREMENTS
- Recorders will be rolled prior to the scenario and paper from selected recorders will be retained for the examination team as requested.
- All procedures, flow charts, curves, graphs, etc. will be in their normal storage places.
- All markable procedures, boards, etc. will be erased.
- All paper used by the crew will be retained for the examination team as requested.
- The simulator operators will keep a log of all communications during the scenario as requested by the examination team.
SCENARIO SOURCE HISTORY
- This is a modified scenario developed for the 2013 NRC Exam; it originated from the 2009 NRC ILT Exam and was used on the 2010 CERT exam. Modification includes re-sequencing of events, and adding 2nd Drifting Rod as additional MAJOR event.
INITIAL SETUP Initial Conditions
- IC-121. -5% power (created from IC-9)
- Ensure recorder power is on; roll recorders as required
- Ensure annunciator horns are active
- Supply ReMA at step 1 of 4 covering startup from all rods in to generator synchronization Blocking Tags
- None Activate APP "2013_NRC_SCN4" or insert the following:
Event Triggers TRG E1 ROD_1851_TOGGLE_SCRAM
=
TRG E1 DMF CRM011851 TRG E5 REACTOR_MODE_SWITCH_IN_SHUTDOWN Malfunctions IMF CRM011851 (none 0 O)(Control rod 18-51 drifts out)
IMF DCW02B (E2 0 0) ('B' drywell chiller trips)
IMF ARIF2B (E3 0 0) ('B' ARI power supply failure - blown fuse)
IMF PCS07 (E4 0 0) 100 20:00 0 (torus leak)
IMF MFS01C (E5 0 0) ('C' reactor feed pump trip)
IMF CRH041827 (E12 0 0) (Control rod 18-27 drifts in)
Overrides 2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
lOR ZYP01A6A1S17 (none 0 0) "NO INCR" (fails the Bypass Jack RAISE pushbutton)
Trip Overrides None Turnover Procedures
- GP-2 "Normal Plant Start-Up" complete up to and including step 6.2.51 o Step 6.2.48 - in progress o Rod Sequence Sheet is complete up to Group 15 (RWM Array 8). withdrawal Group 16 is in progress, next rod to withdraw is Control Rod 18-35 from pos 12 to 48. Crew should reference for control rod withdrawal requirements
- Control rod withdrawal per SO 62.1.A-2 "Withdrawingllnserting a Control Rod" and GP-2 Attachment 10.
- SO 6C.1.A-2 "'C' Reactor Feedwater Pump Startup With Vessel Level Control Established Through AO-8091" up to step 4.4
- SO 1B.1.A-2 "Main Turbine Startup And Normal Operations" at step 4.10
- OP-AB-300-1003 Attachment 1 "Reactivity Maneuver Approval Form" at step 1 of 4 covering startup from all rods in to generator synchronization 2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
SIMULATOR OPERATOR DIRECTIONS EVENT 1 Support the crew as necessary while securing drywell purge.
EVENT 2 After drywell purge is secure, or at the Lead Examiner's direction, initiate a trip of the
'B' Drywell Chiller using ET2 (IMF DCW02B).
If an Equipment Operator is dispatched to inspect the 2B Drywell Chiller, report the chiller is shutdown and screen diagnostics indicate a severe power phase unbalance.
If an Equipment Operator is dispatched to inspect the 2B Drywell Chiller circuit breaker, report the breaker is tripped on overcurrent.
Support placing the 2C chiller in service using SO 44A.6.A-2 "Placing An Additional Drywell Chiller In Service". The Equipment Operator will be directed to perform steps 4.4 through 4.13 prior to starting the chiller, then verify 4.15 and perform 4.17.
EVENT 3 After the 2C Drywell Chiller is placed in service, or at the Lead Examiner's direction, initiate an ARI power supply failure using ET3 (IMF ARIF2B).
If/when directed to check the power supplies and fuses for the 'B' ARllogic channel in the Cable Spreading Room, report:
- fuse BB-F12 in Panel20C019 is blown
- fuse BB-F13 is good
- power supply 20D2406 is on.
When reported that fuse is replaced, remove the ARI power supply failure malfunction using DMF ARIF2B EVENT 4 Support the crew as necessary during control rod withdrawal.
EVENT 5 When control rod 18-51 is notched out, malfunction CRM011851 will activate to cause a control rod drift malfunction on control rod 18-51.
When sent as the Equipment Operator to inspect HCU 18-51, report back by phone or radio that nothing looks abnormal on the HCU.
When the scram toggle switch for control rod 18-51 is placed in the DOWN position at Panel20C016, verify ET1 initiates to delete the control rod drift malfunction (DMF CRM011851 ).
IF contacted as Reactor Engineering or Nuclear Fuels, DO NOT concur with exit from ON-121, report that rod pattern analysis is in progress.
EVENT 6 When the crew has reset the Rod Drift alarn,! or at the Lead Examiner's direction, activate Trigger E12 to initiate malfunction CRH041827 to cause a control rod drift malfunction on control rod 18-27.
2013 NRC Scenario #4 - T- 102 Torus Leak, Rev O.doc
SIMULA TOR OPERATOR DIRECTIONS IF sent as the Equipment Operator to inspect HCU 18-27, report back by phone or radio that the scram outlet valve riser is warm, but so are All the others due to the scram condition.
EVENT 7 When the Mode Switch is placed in SHUTDOWN, verify ET5 initiates (IMF MFS01C) to trip the 'C' reactor feed pump.
Support the crew as necessary for the 'C' reactor feed pump trip.
EVENTS NOTE: TORUS WATER lEVEL OUT OF NORMAL RANGE (226 A-4) will annunciate approximately 2 minutes after the leak malfunction is inserted.
After the scram reports are complete and at the lead Examiner's direction, initiate a leak in the torus using ET4 (IMF PCS07100 20:00 0).
If an Equipment Operator is dispatched to determine the source of the torus leak, wait 5 minutes, then report hearing a loud rush of water in the Torus Room and there are several inches of water on the Torus Room floor.
When dispatched to close E324-R-B (3863) per step 4.1 of T-231-2, WAIT 2 minutes and modify remote function MRF RHR25 CLOSE (closes feed for MO-176)
EVENT 9 Role-playas plant staff if asked to investigate why the bypass valves will not open on the manual jack.
TERMINATION The scenario may be terminated when the RPV is depressurized and HPSW is injecting into the torus.
2013 NRC Scenario #4 - T -102 Torus Leak, Rev O.doc
SHIFT TURNOVER PLANT CONDITIONS:
- Unit 2 startup lAW GP-2 "Normal Plant Startup" in progress. Procedure complete up to and including step 6.2.51.
o 6.2:48 is open (Drywell purge) to support Drywell inspections, which are now complete.
o Rod Sequence Sheet is complete up to Group 16. Withdrawal Group 16 is in progress, next rod to withdraw is Control Rod 18-35 from pos 12 to 48. Crew should reference GP-2 Attachment 10 for control rod withdrawal requirements.
- Currently in Step 1 of ReMA PB2C19-1.0.
INOPERABLE EQLIIPMENT/LCOs:
- None SCHEDULED EVOLUTIONS:
- Continue the Reactor startup in accordance with GP-2.
- Secure Drywell purge per step 6.2.48 of GP-2, using SO "lB.4.A-2.
- Commence inerting the containment lAW SO 7B.1.A-2 "Containment Atmosphere Inerting".
SURVEILLANCES DUE THIS SHIFT:
- None ACTIVE CLEARANCES:
- None GENERAL INFORMATION:
After turnover the crew will resume power ascension. GP-2 is complete up to and including step 6.2.51. A Reactivity Briefing was already completed and you are ready to begin withdrawing rods at Rod Group 16 (RWM Array 8), Control Rod 18-35.
- Control rod withdrawal per SO 62.1.A-2 "Withdrawingllnserting a Control Rod"
- Reactor level control is through A0-8091 using SO 6C.1.A-2 (at step 4.4).
- 2A Reactor Feed Pump is in standby per SO 6C.1.C-2 (at step 4.4.9).
- Containment purge is in progress using SO 7B.4.A-2 (at step 4.19).
~. Chest warming is in progress using SO 1B.1.A-2 (at step 4.10).
2013 NRC Scenario #4 - T -102 Torus Leak, Rev O.doe
CRITICAL TASK LIST
- 1. Shutdown the reactor by placing the Mode Switch in "SHUTDOWN" OR by depressing the manual scram pushbuttons when the a second rod drift condition is recognized lAW ON 121 "Drifting Control Rod ".
- 2. Perform an emergency blowdown in accordance with T-112 "Emergency Slowdown" when Torus level cannot be maintained above 10.5 feet
- 3. Secure HPCI in accordance with RRC 23.1-2 "HPCI System Operation During A Plant Event" OR SO 23.2.A-2 "HPCI System Shutdown" when Torus level cannot be maintained above 9.5 feet.
(NOTE: this CT only applies IF HPCI is in service for injection or pressure control, and IF Torus level lowers below 9.5 feet, which is dependent on when HPSW is placed in service to fill the Torus per T-231.)
2013 NRC Scenario #4 - T-I02 Torus Leak, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 4 Event No.: 1 Page: 10f14 Event
Description:
Secure drywell purge Cause: N/A Effects: N/A Time Position Applicant's Actions or Behavior CRS Direct drywell purge secured per step 6.2.48 of GP-2, using SO 7B.4.A-2.
PRO Secure drywell purge starting at step 4.19 of SO 7B.4.A-2 "Containment Atmosphere De-inerting and Purging Via SBGT System".
- Place the standby Drywell Purge Fan to OFF
- Stop the running Drywell Purge Fan
- Shutdown SBGT using SO 9A.2 . B "SBGT System Shutdown Following Manual Start" o Stop the 'A' SBGT fan by placing its control switch to STOP (spring returns to AUTO) o Close 'A' filter inlet AO-4~r5-1 by placing its control switch to AUTO o Close 'N filter outlet A0-475-2 by placing its control switch to AUTO
- Close AO-20459 and AO-20460 on panel 20C012
- Direct EO to verify HCS-00522-1 is OPEN on panel OBC452
- Close the following valves using SO 7B.7.A-2:
o AO-250S o AO-2520 o AO-2506 o AO-2S07
- Close SBGT valves AO-20469-1 and AO-20469-2 on the 20C012 panel NOTE: at the Lead Examiner's direction, step 4.4 of SO 9A.2.B (SBGT Shutdown Following a Manual Start) may be performed by an "extra" operator.
NOTE: if the crew desires to inert the drywell per GP-2, step 6.2.48.2, inform the CRS that an "extra" operator will be used to perform this task later in the shift.
2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 4 Event No.: 2 Page: 2 of 14 Event
Description:
'B' drywell chiller trip I place standby chiller in service Cause: Spurious chiller motor high temperature Effects: 1. Alarms:
- 217 D-1 "Drywell Chiller Trouble"
- 217 J-1 "Drywell Chilled Water Hi-Lo Temp" (approximately 15 minutes after chiller trip, depending on restoration time)
- 217 J-2 "A Drywell Chiller Discharge Hi Temp" (approximately 5 minutes after chilled trip)
- 2. 'B' chiller outlet temperature increases; chilled water supply and return, drywell cooler fan outlet and return, drywell equipment drain sump outlet, and recirc pump motor temperatures all increase. Drywell temperature and pressure rise accordingly.
Position Applicant's Actions or Behavior URO/PRO Recognize and report alarm 217 D-'I "Drywell Chiller Trouble" and enter the corresponding Alarm Response Card.
Recognize and report alarm 217 J-1 "Drywell Chilled Water Hi-Lo Temp" and enter the corresponding Alarm I~esponse Card. if it alarms.
Recognize and report alarm 217 J-2 "A Drywell Chiller Discharge Hi Temp" and enter the corresponding Alarm Response Card.
CRS Enter and execute ARC 217 D-1" Drywell Chiller Trouble":
- Direct placing additional drywell chillers in service lAW SO 44A.6.A-2 "Placing an Additional Drywell Chiller in Service."
NOTE: Drywell chillers are NOT in outage operation.
- Direct performing SO 44A.7.F-2 "Response to a Drywell Chiller Trouble Alarm."
- Request Maintenance assistance to investigate chiller trip.
PRO Place the control switch for the '8' drywell chiller in "STOP".
Start the standby drywell chiller lAW SO 44A.6.A-2 "Placing an Additional Drywell Chiller in Service."
- Direct an Equipment Operator to verify 2C Drywell Chiller is ready for start by performing steps 4.4 thmugh 4.7 of SO 44A.6.A-2.
- Place the 'C' drywell chiller in service by placing the chiller control switch in "START".
Dispatch an Equipment Operator to perform steps 4.9 and 4.10 of SO 44A.6.A-2.
Dispatch an Equipment Operator to perform SO 44.A. 7 .F-2 "Response to a Drywell Chiller Trouble Alarm.*
2013 NRC Scenario #4 - T-I 02 Torus Leak, Rev O.doc
Operator Actions Op Test No.: 1 Scenario No.: 4 Event No.: 3 Page: 30f14 Event
Description:
ARI power supply failure Cause: Blown fuse for the 'B' ARI logic power supply Effects: 1. Alarm: 207 E-3 uARI-RPT System INOP/Loss of Power"
- 2. Automatic and manual initiation of the 'B' logic channel is disabled.
Position Applicant's Actions or Behavior URO Recognize and report alarm 207 E-3 "ARI-RPT System INOP/Loss of Power" and enter the corresponding Alarm Response Card.
Determine the 'B' logic channel is affected by observing the ARI solenoid valve position (green) indicating lights on Panel 20C005A.
Dispatch an Equipment Operator to the Cable Spreading Room to check the 'B' ARI logic power supply and fuses.
CRS Refer to Tech Spec 3.3.4.1 for ARI-RPT Instrumentation.
- Determine Tech Spec 3.3.4.1 is not applicable in Mode 2, but the inoperable channel must be restored to OPERABLE prior to Mode 1.
Refer to TRM 3.1 for ARI Instrumentation.
- Determine Condition C applies: within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, restore ARI trip capability.
NOTE: the above application of Tech Specs and TRM is based on losing 125 VDC power to the 'B' ARllogic channel, which prevents the ARI function from occurring (both channels must trip for ARI to occur) and prevents the ATWS-RPT function from occurring since both channels must trip for the Recirc MG field breakers to trip (ARI-RPT contacts are in series in the drive motor breaker trip circuit).
NOTE: Lead Examiner will need to report that the fuse has been replaced in order for the startup to continue 2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 4 Event No.: 4 Page: 40f14 Event
Description:
Power ascension with control rods Cause: N/A Effects: N/A Position Applicant's Actions or Behavior CRS Direct the URO to commence rod withdrawal in accordance with the Startup REMA and the Startup Sequence beginning with Rod Group 16.
control rod 18-35 URO Commence rod withdrawal beginning with Rod Group 16. control rod 18 35.
Withdraw control rods by selecting the rod on the matrix and then using the Single Notch I Continuous Withdrawal switch to withdraw control rods.
Monitor nuclear instrumentation and reactor power during control rod withdrawal.
Performs a control rod coupling check when control rod is full out (48).
PRO Monitor balance of plant conditions during rod withdrawal.
2013 NRC Scenario #4* T-I02 Torus Leak, RevO.doc
Operator Actions Op Test No.: 1 Scenario No.: 4 Event No.: 5 Page: 50f14 Event
Description:
Control rod drifts out Cause: Lel:lking directional control valve on HCU Effects: Uncontrolled reactivity change Position Applicant's Actions or Behavior URO/PRO Acknowledge annunciator 211 (D-4) ROD DRIFT and inform CRS of alarm condition and that control rod 18-51 is drifting out.
CRS Enter ON-121 "Drifting Control Rod".
Direct an Equipment Operator to inspect HCU 18-51.
Request Shift Manager to notify Reactor Engineering.
URO Per ON-121 "Drifting Control Rod":
- Select control rod 18-51 on the select matrix.
- Monitor changes in reactor power, level, pressure.
- Insert control rod 18-51 to full in position using the Emergency-In control switch and HOLD at the full in position for 30 seconds (perform this step for a total of 5 times since the control rod will continue to drift).
NOTE: at the Lead Examiner'S direction, the crew can continue with ON-121, step 2.9 (individual rod scram) after 2 attempts at step 2.8.
- Insert control rod 18-51 to full in position using the Emergency-In control switch and HOLD at the full in position prior to the individual rod scram.
- After the individual rod scram for control rod 18-51 has been performed, release the Emergency-In control switch.
- Reset the ROD DRIFT alarm when control rod 18-51 is no longer drifting.
PRO Direct an Equipment Operator to inspect HCU 18-51.
Perform an individual scram of control rod 18-51 by placing its associated scram toggle switch in the DOWN position on panel 20C016.
After 15 seconds, return the toggle switch to the UP position.
CRS Refer to Tech Spec 3.1.3 for one inoperable control rod.
- Determine Condition C applies: fully insert the control rod within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> and disarm the rod drive mechanism within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 4 Event No.: 6 Page: 60f14 Event
Description:
2nd Control rod drifts in I Manual Scram Cause: Leaking Scram Outlet valve on HCU .
Effects: Uncontrolled reactivity change. potential for core damage due to unanalyzed rod pattern.
Position Applicant's Actions or Behavior URO/PRO Acknowledge annunciator 211 (0-4) ROD DRIFT and inform CRS of alarm condition and that control roo 18-27 is drifting in.
CT CRS Direct the Reactor Operator to place the Mode Switch in Shutdown (acceptable to direct the RO to depress the manual scram pushbuttons).
Direct PRO to perform Scram Actions.
Enter and execute T -100 CT URO Per ON-121 "Drifting Control Rod" and RRC- 94.1-2 "Unit Reactor Operator Scram Actions" :
- Place the mode switch to SHUTDOWN.
- Verify control rods are inserting.
- Verify APRMs are downscale.
- Verify all control rods are inserted.
- Notify health physics of changing plant conditions.
PRO Per RRC 94.2-2, PRO Scram Actions:
< 1 inch)
- Verify scram discharge volume vents and drains are closed.
- Verify hydrogen water chemistry is isolated.
- Verify both recirc pumps speed have runback to 30%.
- Monitor instrument air header pressure and drywell pressure.
2013 NRC Scenario #4 - T -102 Torus Leak, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 4 Event No.: 6 Page: 70f14 Event
Description:
2nd Control rod drifts in I Manual Scram (Continued)
Cause: Leaking Scram Outlet valve on HCU Effects: Uncontrolled reactivity change, potential for core damage due to unanalyzed rod pattern.
CRS Direct RPV level restored and maintained between +5 and +35 inches.
Direct restoration of drywell instrument nitrogen lAW GP-8.E "Primary Containment Isolation Bypass" (if RPV level < 1 inch).
URO Control RPV level between +5" to +35" with feedwater.
PRO Bypass and restore drywell instrument nitrogen lAW RRC 94.2-2 or GP-8E (if RPV level < 1 inch).
- Place AO-2969A control switch to "CLOSE".
- Place AO-2969B control switch to "CLOSE".
- Place AO-2969A control switch to "OPEN".
- Place AO-2969B control switch to "OPEN".
NOTE: this activity may be coordinated between the URO and the PRO.
2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 4 Event No.: 7 Page: 80f14 Event
Description:
'e' reactor feed pump trip Cause: Pressure switch fails, causing low suction pressure trip Effects: 1. Alarms:
- 201 J-4 lie RFPT Trip"
- 210 H-2 "Reactor Hi-Lo Water Lever (depending on when pump trip is discovered)
- 2. 'e' reactor feed pump trips, causing RPV water level to lower.
Position Applicant's Actions or Behavior URO Recognize and report alarm 201 J-4 "e RFPT Trip" and enter the corresponding Alarm Response Card (as applicable).
- Perform the following actions to control RPV level:
o Raise the speed of the 'A' RFP using the MIA station or MSC to raise RFP discharge pressure approximately 150 psig above Reactor pressure.
o Throttle open the 'A' RFP discharge valve to establish Feed flow to the RPV.
o Adjust RFP speed and/or RFP discharge valve position to control RPV water level.
2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 4 Event No.: 8 Page: 90f14 Event
Description:
Torus leak into secondary containment I emergency Slowdown Cause: Rupture in the torus shell Effects: 1. Alarms:
- 224 E~5 "Torus Room Flood"
- 226 A4 "Torus Level Out Of Normal Range"
- 2. Torus level lowers and will eventually equalize with the torus room at approximately 7 feet.
Position Applicanfs Actions or Behavior PRO Recognize and report alarm 226 A4 "Torus Level Out Of Normal Range" and enter the corresponding Alarm Response Card.
Direct an Equipment Operator to determine the source of the leak.
CRS Enter and execute T-102 "Primary Containment Control".
- Direct torus level restored using T-231 "HPSW Injection Into the Torus".
(May) enter and execute ON-110 "Loss of Primary Containment".
PRO Perform T -233 "CST Makeup to the Torus Via HPCI Minimum Flow Line" as directed.
- Verify HPCI suction MO-23-017 OPEN.
- Open HPCI minimum flow MO-23-025.
2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 4 Event No.: 8 Page: 10 of 14 Event
Description:
Torus leak into secondary containment I emergency blowdown (continued)
Position Applicant's Actions or Behavior PRO Perform T-231 "HPSW Injection Into the Torus" as directed.
- Direct an Equipment Operator to close E324-R-8 (3863) "Emer Intertie Valve MO-2-10-176".
- Verify closed MO-1 0-1548 "Outboard Discharge".
- Verify 2B and 2D RHR pumps are shutdown.
- Verify 28 and 2D HPSW pumps are shutdown.
- Verify closed MO-10-089B "B HPSW Hx Out".
- Verify closed MO-10-089D "D HPSW Hx Out".
- Verify closed MO-32-2344 (10-186) "HPSW Loop Cross Tie".
- OPEN MO-10-174 "HPSW/RHR Em Inner Cross Tie".
- OPEN MO-10-176 "HPSW/RHR Em Outer Cross Tie".
- OPEN MO-10-039B "Torus Hdr".
- Start a HPSW pump.
- Throttle MO-10-034B "Full Flow Test" to maintain HPSW flow below 5,300 gpm.
- Start a second HPSW pump in the same loop, if needed.
- Throttle MO-10-034B "Full Flow Test" to maintain HPSW flow below 10,600 gpm.
PRO Recognize and report alarm 224 E-5 ITorus Room Flood" and enter the corresponding Alarm Response Card.
CRS Enter and execute T-103 "Secondary Containment Control".
Direct an evacuation of the torus room in accordance with GP-15 "Local Evacuation" (make request to Shift Manager).
URO/PRO Recognize and report that torus level is approaching 12.5 feet.
CRS When torus level cannot be maintained above 12.5 feet, enter and execute T-101 "RPV Control" 2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
ES-D-2 Op Test No.: Scenario No.: 4 Event No.: 8 Page: 11 of 14 Event
Description:
Torus leak into secondary containment / emergency blowdown (continued)
Time Position Applicanfs Actions or Behavior CT CRS Direct RPV depressurization using bypass valves lAW T-101 "RPV Control", as required by T-102, step T/L-6 (see Event #9).
NOTE: the following RWCU system response steps are only applicable if RWCU stays in service URO/PRO Recognize and report the "Clean-LIp Filter Demin System Trouble Alarm" (215 C-3)
URO/PRO Recognize and report cavitation of the RWCU pump.
CRS Direct the URO/PRO to secure the RWCU pump.
URO/PRO Secure the RWCU pump by placing the control switch to stop.
URO/PRO Recognize and report that torus level is approaching 10.5 feet.
CT eRS When torus level cannot be maintained above 10.5 feet, direct an emergency blowdown.
Enter and execute T-112 "Emergency Slowdown".
- Verify torus level is above 7 feet.
- Verify reactor pressure is 50 psig above torus pressure.
CT PRO Perform an emergency blowdown by opening 5 ADS SRVs.
2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
Operator Actions ES*D*2 Op Test No.: 1 Scenario No.: 4 Event No.: 8 Page: 12 of 14 Event
Description:
Torus leak into secondary containment I emergency blowdown (continued)
Position Applicant's Actions or Behavior CRS Direct RPV level maintained between +5 and +35 inches using Condensate.
URO Maintain RPV level between +5 and +35 inches using Condensate.
CRS When torus level drops below 10.5 feet, if any RHR pumps are running, direct all operating RHR pumps secured.
URO/PRO As directed, secure all operating RHR pumps by plaCing their control switches in "STOP".
Recognize and report that torus level is approaching 9.5 feet.
CT CRS When Torus level cannot be maintained above 9.5 feet, direct HPCI secured (if running).
CT URO/PRO Secure HPCI when Torus level cannot be maintained above 9.5 feet, as directed, using RRC 23.1-2:
- Verify Aux Oil Pump control switch in "START'.
- Place Vac Pump control switch in "START'.
- Depress and hold "Remote Trip" pushbutton.
- When turbine speed reaches approximately 0 RPM, place Aux Oil Pump control switch in "PULL-TO-LOCK".
- Release the "Remote Trip" pushbutton.
NOTE: if HPCI was not in service, the crew should still place the Aux Oil Pump control switch in "PULL-TO-LOCK".
2013 NRC Scenario #4 - T-I02 Torus Leak, Rev O.doc
Operator Actions ES-O-2 Op Test No.: 1 Scenario No.: 4 Event No.: 9 Page: 13 of 14 Event
Description:
Turbine bypass valve jack fails to open bypass valves Cause: Instrument malfunction in the EHC logic card Effects: Reactor depressurization cannot be performed using the bypass jack.
Position Applicant's Actions or Behavior URO/PRO Determine and report the bypass jack has no effect on opening the main turbine bypass valves.
CRS Direct the URO to lower the pressure regulator setpoint in an effort to depressurize the reactor.
URO/PRO Lower the pressure regulator setpoint as directed by the CRS.
URO/PRO Recognize and report that RPV pressure is continuing to drop.
(Evaluator note; the low decay heat load will cause RPV pressure to continue to drop. The operators should recognize this and take actions to control RPV depressurization.)
CRS Direct the RO to control the RPV depressurization rate by removing steam users.
URO/PRO Remove the following steam users by:
- Isolating steam to the RFPs not in-service.
- Verifying the Main Steam line drains are closed.
- ClOSing the Main Turbine and RFPT drains.
- If depressurization continues closing the MSIVs.
CRS If the MSIVs are closed for RPV pressure control, direct RPV depressurization using HPCI in CST-to-CST mode, SRVs, or other methods per T-101.
URO/PRO Depressurize the RPV using SRVs, HPCI in CST-to-CST mode, or other methods, as directed.
2013 NRC Scenario #4 - T-102 Torus Leak, Rev O.doc
Operator Actions ES-D-2 Op Test No.: 1 Scenario No.: 4 Event No.: 9 Page: 14 of 14 P9ST SCENARld EMERGENCY CLASSIFICATION:
Classification is an Alert lAW EAL FA1 ("Loss of Reactor Coolant System Barrier - Emergency Blowdown Required").
TERMINATION CRITERIA:
The scenario may be terminated when the RPV is depressurized and HPSW is injecting into the torus.
2013 NRC Scenario #4* T*J02 Torus Leak, Rev O.doc