ML21137A292
| ML21137A292 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 02/18/2021 |
| From: | Gregory Roach NRC/RGN-III/DRS/OLB |
| To: | FirstEnergy Nuclear Operating Co |
| Roach G | |
| Shared Package | |
| ML20136A254 | List: |
| References | |
| Download: ML21137A292 (193) | |
Text
Davis-Besse DB1LOT21 NRC Exam Admin JPM A1.1
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A1.1 NUREG-1021, Revision 11 Page 1 of 8 Facility: Davis-Besse Task No:
005-012-04-0100 Task
Title:
Identify required notifications for a contaminated injured person K/A
Reference:
2.1.38 (3.8) Job Performance Measure No: A1.1 (New)
Examinee:
NRC Examiner:
Date:
Method of testing:
Simulated Performance ___
Actual Performance _X_
Classroom _X_
Simulator ___
Plant ___
Read to the examinee:
I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues.
When you complete the task successfully, the objective for this job performance measure will be satisfied.
Initial Conditions:
The plant conditions are specified in the Initial Conditions and Initiating Cues.
Task Standard:
Identify all notifications required by regulatory requirement and their associated reporting time requirements for a contaminated injured person.
Required Materials:
NOP-OP-1015, Event Notifications NOBP-OP-1015, Event Notifications NOBP-OP-1015-01, Event Notification Review Aid General
References:
None Initiating Cue:
The plant conditions are specified in the Initial Conditions and Initiating Cues.
Time Critical Task:
No Alternate Path:
No Validation Time:
45 minutes
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A1.1 NUREG-1021, Revision 11 Page 2 of 8 EXAMINER COPY INITIAL CONDITIONS:
The plant is operating in Mode 1 at 100% power A Press Release is being drafted at this time for the following event A mechanic, working on Makeup Pump 1, fell and injured their back The First Aid Team responded and treated the individual RP reported the injured person is contaminated The contaminated injured person was transported by ambulance to the local hospital and admitted as a patient for further treatment INITIATING CUES:
You are the Shift Manager, document below the required notifications for a contaminated injured person AND associated time limits IAW NOP-OP-1015, Event Notifications (Hand Candidate a copy of NOP-OP-1015, Event Notifications NOBP-OP-1015, Event Notifications NOBP-OP-1015-01, Event Notification Review Aid)
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A1.1 NUREG-1021, Revision 11 Page 3 of 8 CANDIDATE COPY INITIAL CONDITIONS:
The plant is operating in Mode 1 at 100% power A Press Release is being drafted at this time for the following event A mechanic, working on Makeup Pump 1, fell and injured their back The First Aid Team responded and treated the individual RP reported the injured person is contaminated The contaminated injured person was transported by ambulance to the local hospital and admitted as a patient for further treatment INITIATING CUES:
You are the Shift Manager, document below the required notifications for a contaminated injured person AND associated time limits IAW NOP-OP-1015, Event Notifications
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A1.1 NUREG-1021, Revision 11 Page 4 of 8 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is NOT critical unless denoted in the "Comments".
START TIME: _________
NOTE: Steps can be performed in any order
- 1.
PERFORMANCE STEP: Reviews NOBP-OP-1015-01, Event Notification Review Aid STANDARD: Uses the Event Notification Review Aid to Identify and circle potential Event Numbers Identifies the associated shortest Notification Times Identifies the associated NOBP Attachment Numbers Identifies if a Notification is required NOTE: May elect to not use NOBP-OP-1015-01, Event Notification Review Aid CUE: None SAT UNSAT
- 2.
PERFORMANCE STEP: Reviews NOP-OP-1015, Event Notifications STANDARD: Identifies ATTACHMENT 1: EVENTS OF POTENTIAL PUBLIC INTEREST Goal of 60 Minute Response Timeframe:
Radiation exposure to an individual in excess of regulatory limits, or the transfer of a radioactive contaminated individual to an off-site medical facility.
- CUE: None SAT UNSAT
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A1.1 NUREG-1021, Revision 11 Page 5 of 8
- 3.
PERFORMANCE STEP: Reviews NOP-OP-1015, Event Notifications STANDARD: Identifies ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS
- 1. Duty Team, SLT, ELT See NOBP-OP-1015, Event Notifications, Attachment 9 Notification O1.2 Table 1 for notification requirements Table 1 Triggers:
All medical emergencies responded to by the First Aid Team, Emergency Medical Technicians, or the Health Center Events of Potential Public Interest (EPPI) or NRC Reportable Event NOBP-OP-1015 O1.2
- 2. NRC Resident Any event or condition that causes entry into the emergency plan, emergency plan off-normals, Abnormal Operating Procedures, Off Normal Instructions, or Emergency Operating Procedures Any condition that requires a 10 CFR 50.72 notification Any notification to the NRC Headquarters duty officer NOBP-OP-1015 O1.3
- 3. Area OSHA Office Work related fatality, in-patient hospitalization or an employees amputation or an employees loss of an eye, because of a work-related incident.
NOBP-OP-1015 O1.18
- 4. NRC Operations Center Any event requiring the transport of a radioactively contaminated person to an offsite medical facility for treatment.
NOBP-OP-1015 R1.9 News release or notification to other government agency. Any event or situation related to the health and safety of the public or onsite personnel or protection of the environment, for which a news release is planned or notification to other government agencies has been or will be made.
NOBP-OP-1015 O1.12
- 5. Various Event of Potential Public Interest (EPPI)
NOBP-OP-1015 O1.7 CUE: None SAT UNSAT
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A1.1 NUREG-1021, Revision 11 Page 6 of 8
- 4.
PERFORMANCE STEP: Review NOBP-OP-1015, Event Notifications STANDARD: Identifies the following Attachments
- 1. Attachment 9 - O1.2 Duty Teams, SLT and ELT Notifications
- 2. Attachment 10 - O1.3 NRC Resident Notification
- 4. Attachment 39 - R1.9 Transport of Radioactively Contaminated Person (NRC Operations Center)
- 5. Attachment 19 - O1.12 News Release or Notification to Other Government Agency (NRC Operations Center)
- 6. Attachment 14 - O1.7 Event of Potential Public Interest CUE: None SAT UNSAT
- 5.
PERFORMANCE STEP: Determines notification requirements and time limit STANDARD: Determines that a notification must be made to the Duty Team, SLT, and ELT (O1.2)
Time Limit: As Soon As Possible (ASAP). No specific notification time requirements however, notifications need to be completed to allow timely support CUE: None SAT UNSAT
- 6.
PERFORMANCE STEP: Determines notification requirements and time limit STANDARD: Determines that a notification must be made to the NRC Resident (O1.3)
Time Limit: No specific time restrictions but it is the sites responsibility to ensure that the NRC Resident has required information to perform his role and brief the region on the event, as necessary.
NOTE: N/A is an acceptable Time Limit, NOBP-OP-1015-01 Event Notification Review Aid CUE: None SAT UNSAT
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A1.1 NUREG-1021, Revision 11 Page 7 of 8
- 7.
PERFORMANCE STEP: Determines notification requirements and time limit
........C........
STANDARD: Determines that a notification must be made to OSHA (O1.18)
Time Limit: Within twenty-four (24) hours NOTE: Eight (8) hours is also acceptable, NOBP-OP-1015-01 Event Notification Review Aid CUE: None SAT UNSAT
- 8.
PERFORMANCE STEP: Determines notification requirements and time limit
........C........
STANDARD: Determines to notify the NRC Operations Center (O1.12 and R1.9)
Time Limits:
- 1. The licensee shall notify the NRC as soon as practical and, in all cases, within eight (8) hours of occurrence of any event requiring the transport of a radioactively contaminated person to an offsite medical facility for treatment.
- 2. The licensee shall notify the NRC as soon as practical and in all cases, within four (4) hours of the occurrence of any event or situation, related to the health and safety of the public or onsite personnel, or protection of the environment, for which a news release is planned or notification to other government agencies has been or will be made.
NOTE: Both notifications can be made at the same time, within the 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> time limit.
CUE: None SAT UNSAT
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A1.1 NUREG-1021, Revision 11 Page 8 of 8
- 9.
PERFORMANCE STEP: Determines notification requirements and time limit STANDARD: Determines other notifications are required due to EPPI (O1.7 NOP-OP-1015 Attachment 1)
Time Limit: Goal of 60 Minutes NOTE: The candidate must identify that notifications are required IAW O1.7. The specific agencies are NOT required to be listed. They will be contacted by the Duty Team.
CUE: None SAT UNSAT TERMINATING CUES: This JPM is complete (Terminated by the examinee)
END TIME
Event Notification Review Aid NOBP-OP-1015-01 Rev. 7 Requires Notification Event Number (Circle items from flow chart)
Shortest Notification Time NOBP Attachment Number Short Description Y / N O1.1 15 Minutes 8
Declaration of Emergency Class Y / N O1.2 ASAP 9
FENOC Duty Teams, ELT, SLT Notifications Y / N O1.3 N/A 10 NRC Resident Notification Y / N O1.4 As Required 11 Follow-Up Notifications Y / N O1.5 As Required 12 Follow-Up Notifications - ISFSI Y / N O1.6 1 Hour 13 Deviation from Tech Specs (50.54(x) or ISFSI license deviation)
Y / N O1.7 1 Hour 14 Event of Potential Public Interest Y / N O1.8 ASAP 15 ANI Notification of Nuclear Emergency or Drill Y / N O1.9 4 Hours 16 Plant Shutdown Required by Technical Specifications Y / N O1.10 4 Hours 17 ECCS Injection/Actuation Y / N O1.11 4 Hours 18 RPS Actuation Y / N O1.12 4 Hours 19 News Release or Notification to Other Govt Agency Y / N O1.13 8 Hours 20 Degraded or Unanalyzed Condition Y / N O1.14 8 Hours 21 System Actuation not Including RPS Y / N O1.15 8 Hours 22 Event or Condition that could have Prevented the Fulfillment of a Safety Function Y / N O1.16 8 Hours 23 Major Loss of Emergency Preparedness Capabilities Y / N O1.17 8 Hours 24 Defect or Reduction in Effectiveness of Spent Fuel Storage Installation Y / N O1.18 8 Hours 25 Fatality, Hospitalization, Amputation, and Loss of an Eye Incidents Y / N O1.19 24 Hours 26 Loose Part Y / N O1.20 2 Days 27 Incomplete or Incorrect Information Y / N O1.21 2 Days 28 Notification of Failure to Comply or Existence of a Defect (10CFR21 Notification)
Y / N O1.22 Immediate 29 Malfunction or Failure of FAA Warning Light Y / N O1.23 As Required 30 NEIL Condition Reporting Y / N OB.1 1 Hour 31 Seismic Event (Beaver Valley)
Y / N OD.1 N/A 33 Steam Relief/Vent Valve Operation (Davis-Besse)
Y / N R1.1 Immediate 34 Significant Personnel Radiation Exposure or Radioactive Material Release Y / N R1.2 Immediate 35 Removable Package Contamination Y / N R1.3 Immediate 36 External Radiation Levels on Packages Y / N R1.4 Immediate 37 Lost, Stolen, or Missing Licensed Material Y / N R1.7 24 Hours 38 Contaminated Spills or Groundwater Issues Y / N R1.9 8 Hours 39 Transport of Radioactively Contaminated Person Y / N R1.10 12 Hours 40 Transportation Event Involving Radioactive Material Y / N RB.1 Immediate 41 Over Exposure from Radiation Producing Machine (Beaver Valley)
Y / N RB.2 Immediate 42 Lost, Stolen, or Missing Radiation Producing Machine Y / N RD.1 Immediate 43 Radiation Exposure or Radioactive Material Release - Davis-Besse Y / N RD.2 Immediate 44 Lost, Stolen, or Missing Licensed Radioactive Material - Davis-Besse Y / N RP.1 Immediate 45 Radiation Exposure or Radioactive Material Release - Perry Y / N RP.2 Immediate 46 Lost, Stolen, or Missing Licensed Radioactive Material - Perry Y / N S1.1 Immediate 47 NRC or NRC Contractor Fitness for Duty Y / N S1.2 Promptly 48 Confirmation of IAEA Credentials Y / N S1.3 Immediate 49 Failure to Receive Periodic Call during Shipment of SNM Y / N S1.4 ASAP 50 Delay in Receipt or Shipment of Special Nuclear Material Y / N S1.5 1 Hour 51 Loss or Recovery of SNM or Spent Fuel Y / N S1.6 1 Hour 52 Reportable Safeguards and Access Authorization Events - 1 Hour Y / N S1.7 1 Hour 53 Accidental Criticality or Special Nuclear Material Loss Y / N S1.8 1 Hour 54 Loss, Theft, or Other Unlawful Diversion of Special Nuclear Material Y / N S1.9 ASAP 55 Spent Fuel Transport Schedule Changes Y / N S1.10 4 Hours 56 Uranium or Thorium Theft or Attempted Theft Y / N S1.11 24 Hours 57 Significant Fitness for Duty Policy Violations or Programmatic Failures Y / N S1.12 4 Hours 58 Actual or Attempted Theft of Category 1 or 2 Radioactive Material Y / N S1.13 1 Hour 59 Cyber Security Event Y / N S1.14 ASAP 60 Lost, Missing, Theft, or Attempted Theft of Shipments of Category 1&2 Radioactive Material Y / N E1.1 Various 61 Spill or Environmental Release Y / N E1.2 Immediate 62 PCB Transformer Fire-Related Incident Y / N EB.1 24 Hours 63 Significant Environmental Impact - Beaver Valley Unit 2 Y / N EP.1 24 Hours 64 Significant Environmental Impact - Perry Y / N G1.1 1 Hour 65 Grid Security or Cyber Security Attack or Attempted Attack Y / N G1.2 20 Minutes 66 Generator Voltage Regulation Y / N G1.3 20 Minutes 67 Voltage Schedule, Capabilities and Control Y / N G1.4 ASAP 68 Tenaska Power Services Notifications Y / N G1.5 ASAP 69 Local Control Center Notifications
06/10/20
06/10/20
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
2 of 46 TABLE OF CONTENTS Page 1.0 PURPOSE 3
2.0 SCOPE 3
3.0 DEFINITIONS 3
4.0 PROCEDURE DETAILS 5
4.1 General Requirements 5
4.2 NRC Event Notification 6
4.3 Reportability Reviews of Condition Reports 9
4.4 Transportation Emergencies 10 5.0 RECORDS 11
6.0 REFERENCES
11 7.0 SCOPE OF REVISION 15 ATTACHMENTS - Communicating Events of Potential Public Interest 16 - Event Notification Requirements 17
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
3 of 46 1.0 PURPOSE This procedure establishes the requirements for the identification and development of notifications (verbal, short-term) submitted to meet various Nuclear Regulatory Commission (NRC), other federal and state rules and regulations and company required notifications. The procedure also establishes the process requirements for fleet notifications of events or conditions and Events of Potential Public Interest (EPPI).
2.0 SCOPE 2.1 Applicability This procedure applies to the Executive Leadership Team, Site Duty Team, and management for the verbal notifications provided to outside regulatory agencies and other required notifications related to the operation of a company power plant. Notifications are verbal, short term communications to the personnel identified by the procedure.
2.2 Exceptions This procedure does not apply to the following notification criteria:
Security Event-Related Reporting - 10 CFR 73/10 CFR 26/Physical Security Plan (Reference NOP-LP-1103 / NOBP-LP-1103)
Environmental Reporting (Reference Site Procedures)
Written reports to regulatory agencies covered in NOBP-LP-4021 Regulatory Reports Management and the FENOC Reports Management Database (FRMD).
3.0 DEFINITIONS 3.1 Duty Team - Duty Team is a list of on-call personnel designated by Fleet and each sites Director Site Operations (DSO) per NOBP-OP-0014 FENOC Duty Teams.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
4 of 46 3.2 Emergency Notification System (ENS) - The Emergency Notification System is a commercial telephone system utilized to notify the NRC Operations Center. The ENS is part of the Emergency Telephone System.
3.3 Events of Potential Public Interest (EPPI) - Events that are not classified on the Nuclear Regulatory Commission emergency scale yet may create media interest or raise concern by the general public, public safety agencies, elected officials, or regulators.
3.4 FirstEnergy (FE) External Communications - The principal group within FirstEnergy responsible for conducting media and community relations for the nuclear plants.
3.5 FirstEnergy (FE) Internal Communications - The principle group within FirstEnergy responsible for internal communications within the Company.
3.6 Immediate Notification - Verbal notification to the NRC or other outside agencies as required by regulations, and/or the operating license.
Immediate notifications are those required within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or less from the time of discovery or occurrence of the reportable condition or event.
3.7 Manager, External Affairs - The manager, external affairs interfaces with local and county officials representing FirstEnergy for the exchange of information, discussion of topics that affect the corporation, and negotiation/resolution of topics that involve the Company and local and county government.
3.8 National Pollutant Discharge Elimination System (NPDES) Permit - A permit issued by the state (OH/PA) describing the effluent limitations, monitoring requirements, and reporting requirements for authorized/
unauthorized discharges.
3.9 Reportability Review - An evaluation of an identified condition to determine whether it is required to be reported.
3.10 Reportable Condition/Event - Any situation or occurrence (for example, equipment inoperability, significant design discrepancy) that is reportable to the NRC or other outside agency.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
5 of 46 3.11 Shutdown - As used in the context of 10 CFR 50.72, shutdown is defined as all regulating rods are in the core and shutdown margin is being maintained.
3.12 Time of Discovery - Time of Discovery is the moment the Shift Manager (SM) decides on the status of the condition, i.e. Operable or Inoperable. The time clock for a Limiting Condition of Operation, or an Action Statement starts at the time of discovery.
4.0 PROCEDURE DETAILS 4.1 General Requirements 4.1.1 and 2 may be used in determining the required notifications for events. NOBP-OP-1015, Event Notifications, provides flow charts and a job aid to assist in the determination of applicable notifications. In addition, the following groups may be contacted for assistance in determining notification requirements:
Site Regulatory Compliance / Fleet Regulatory Affairs regarding 10 CFR notifications Site/Fleet Access Authorization regarding fitness for duty notifications Site/Fleet Site Protection regarding physical security notifications Chemistry/Environmental for 40 CFR / NPDES / state notifications Site Reactor Engineering regarding special nuclear material (SNM) notifications 4.1.2 Notifications to the NRC shall be complete and accurate in all material aspects.
4.1.3 Notifications that cannot be performed within the required time period shall be brought to the attention of the Manager, Regulatory Compliance as soon as possible.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
6 of 46 4.1.4 If an event results in multiple notification requirements, duplicate notifications are not required. However, notifications should be made within the time limits imposed by the more limiting (i.e. shorter time limit) notification requirement. All applicable notification requirements should be included in the notification.
4.1.5 Notifications for conditions or events that may not be documented in a Condition Report for reason of confidentiality or safeguards reasons is the responsibility of the department administering the applicable process.
4.1.6 of this procedure outlines the required notifications. Each notification in the Attachment contains a short description, the notification requirement source document, the recipient of the notification, the required notification time and method, required notification content and the NOBP-OP-1015 Event Notifications Reference.
4.1.7 Each Notification in Attachment 2 has an associated NOBP-OP-1015 Attachment that provides the basis for the notification, the notification requirements and interpretive guidance on the associated events. In some cases, NOBP-OP-1015 also provides instructions for completing the notification.
4.2 NRC Event Notifications NOTES Notification of regulatory agencies other than the NRC may require NRC Notification. (10 CFR 50.72(b)(2)(xi))
For significant plant transients or events, several conditions may occur which each require notification per Attachment 2. It is acceptable to provide each required notification in a single telephone call provided such a call is made within the most restrictive notification time limit.
Only those non-emergency events meeting the one-hour, four-hour, or eight-hour notification requirements that occurred within three years of the date of discovery require NRC notification via the Emergency Notification System. (10 CFR 50.72(a)(1)(ii))
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
7 of 46 4.2.1 The Shift Manager shall ensure that notifications for events or conditions listed in Attachment 2 are made within the specified time requirements.
- 1.
Notifications to the NRC should be made to the NRC Operations Center via the Emergency Notification System (ENS) unless otherwise specified.
IF the ENS is unavailable, THEN the following commercial numbers shall be used to reach the NRC Operations Center:
(301) 816-5100 (301) 951-0550 (Backup)
(301) 816-5151 (Telecopy)
The NRC Resident Inspector shall be notified for any notification made to the NRC Headquarters Operations Officer (HOO). See Notification O1.3 for other NRC Resident Inspector notifications.
An open, continuous communications channel shall be maintained with the NRC Operations Center at their request.
Where permitted, notification forms can be emailed to hoo.hoc@nrc.gov in place of faxing.
- 2.
Notifications made to offsite agencies should be made using the commercial telephone system.
Any condition or event that warrants an immediate notification to an outside agency shall have the basis for the reportability determination documented in the Condition Report.
- 3.
Contact the Duty Manager-Regulatory Compliance for assistance when an entry into Technical Specification 3.0.3 occurs.
Entry into Tech Spec 3.0.3 may require a four-hour notification under 10 CFR 50.72(b)(2)(i), for initiation of a nuclear plant shutdown.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
8 of 46 4.2.2 Ensure that information provided to the NRC is recorded on NOP-OP-1015-01, Reactor Plant Event Notification Worksheet.
- 1.
The completed form should also receive a peer/management/Regulatory Compliance review prior to submittal.
- 2.
Request an Event Notification Number from the NRC Duty Officer and enter this number in the appropriate block of the form.
- 3.
Ensure any follow-up notification requirements are identified and noted on the form.
- 4.
The form shall be faxed or e-mailed to the NRC Operations Center at the time the notification is provided to avoid discrepancies.
- 5.
The completed form should be provided to Regulatory Compliance to be included with the Condition Report.
4.2.3 The time clock for events that require notification pursuant to 10 CFR 50.72 should follow guidance provided in this NOP and NOBP-OP-1015 and generally starts at the Time of Discovery of the event/condition.
For discovery of a previously unrecognized reportable event or condition, the time clock for reportability begins at the time when it has been determined that a reportable event or condition exists.
Any event or condition requiring an evaluation in order to determine reportability must be evaluated on a schedule commensurate with its safety significance per the guidance of NRC Regulatory Issue Summary (RIS) 2005-20. Whenever a reasonable expectation no longer exists that the equipment in question is operable, or significant doubts begin to arise, appropriate actions, including event notifications, should be taken.
4.2.4 If more than one notification requirement is applicable, multiple notifications are not required. However, notifications shall be made within the time limits imposed by the most limiting notification requirement. All applicable notification requirements shall be identified in the notification.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
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9 of 46 4.2.5 The reportability of many events and conditions is self evident. However, the reportability of other events and conditions may not be readily apparent and the use of engineering judgment is involved in determining reportability.
Engineering judgment may include either a documented engineering analysis or a judgment by a technically qualified individual, depending on complexity, seriousness, and nature of the event or condition. A documented engineering analysis is not a requirement for all events or conditions, but it would be appropriate for particularly complex situations.
In addition, although not required by 10 CFR, it may be prudent to record in writing that a judgment was exercised by identifying the individual making the judgment, the date made, and briefly documenting the basis for this judgment. In any case, the NRC considers that the use of engineering judgment implies a logical thought process that supports the judgment.
4.3 Reportability Reviews of Condition Reports 4.3.1 The Manager, Regulatory Compliance shall assign to appropriate staff personnel the responsibility for reviewing each Condition Report to determine if additional reportability requirements apply per NOP-LP-2001, Corrective Action Program.
4.3.2 When a reportability review indicates that an immediate notification is required, but has not been performed, the identifying staff member shall immediately inform the Duty Manager - Regulatory Compliance and the Shift Manager for action to ensure that the required notification is issued.
- 1.
The staff member identifying this delayed notification shall coordinate with Regulatory Compliance development of the information necessary to ensure the required notification is issued.
- 2.
The circumstances associated with this delayed notification shall be documented in a Condition Report.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
10 of 46 4.3.3 When a reportability review indicates that an immediate notification submitted to an outside agency was not required, the identifying staff member shall promptly inform the Duty Manager - Regulatory Compliance for action to determine if the required notification should be retracted.
- 1.
The staff member identifying this not-required notification shall coordinate with Regulatory Compliance development of the information necessary to retract the required notification and to ensure that the retraction is issued.
- 2.
The revised reportability status shall be documented in the Condition Report.
- 3.
There is no set time limit for ENS telephone retractions. All retractions will be reviewed by the NRC. Ensure each retraction is properly justified and documented as appropriate.
4.4 Transportation Emergencies 4.4.1 When a hazardous waste or radioactive shipment is made the carrier and/or driver will be given instructions to notify the Shift Manager in the event of an accident.
4.4.2 If a call is received with information on a transportation emergency, the Shift Manager shall request the following information:
Name of the Caller Telephone number where the caller can be contacted Name and address of the carrier Type of shipment Date, time, and location of the emergency Nature and severity of emergency 4.4.3 Inform the caller that you will notify the proper knowledgeable person and request that the caller remains at the contact telephone.
4.4.4 If the emergency could be a radiation hazard, notify the Duty Manager -
Radiation Protection. Notify the Director, Site Operations to determine if additional notifications are required to the NRC Region.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
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11 of 46 4.4.5 If the emergency could be an environmental hazard, notify the Duty Manager - Chemistry.
4.4.6 Make a Unit Log Entry to document the transportation emergency, persons contacted, and actions taken.
5.0 RECORDS 5.1 Records Handling Records completed/generated by this procedure shall be handled in accordance with each plants established records management program.
5.2 Records Capture The following records are completed/generated by this document:
Quality Records None Non-Quality Records NOP-OP-1015-01, Reactor Plant Event Notification Worksheet
6.0 REFERENCES
6.1 Discretionary 6.1.1 Multi-site NOBP-SS-1208, Cyber Security Incident Response NOP-LP-2001, Corrective Action Program NOP-LP-4007, Regulatory Agency Communications NOP-NF-3001, Special Nuclear Material Control and Accounting Program NOP-OP-2012, Groundwater Monitoring NOP-OP-4207, Occupational Exposure Reporting
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
12 of 46 NOP-OP-4705, Response to Contaminated Leaks/Spills NOBP-LP-4017, Preparation and Submittal of Licensee Event Reports NOBP-LP-4021, Regulatory Reports Management NORM-LP-4015, Development Criteria for Regulatory Reports NOPL-LP-4001, Completeness and Accuracy of Information NOPL-LP-4002, Regulatory Communications NOP-LP-1103, Reportable Events NOP-OP-1003, Grid Reliability Protocol 6.1.2 BV 1/2-ADM-0601, Environmental Reporting 1/2-ADM-0602, Environmental Spill and Release Preparedness, Prevention and Response 1/2-ADM-1107, Alert Notification System (Sirens) Maintenance and Testing 1OM-31.4AAM, Cooling Tower Aircraft Warning Lights Trouble 2OM-31.4.AAF, Cooling Tower Aircraft Warning Lights Trouble 6.1.3 DB RA-EP-02850, Hazardous Chemical and Oil Spills 6.1.4 PY PAP-0806, Oil or Chemical Release Contingency Plan PAP-0808, Environmental Reports PAP-0809, Radiological Environmental Contamination Response
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
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13 of 46 6.2 Obligations 6.2.1 Multi-site 10 CFR Part 11, Determining Eligibility For Access To or Control Over Special Nuclear Material 10 CFR Part 20, Standards for Protection Against Radiation 10 CFR Part 21, Reporting of Defects and Noncompliance 10 CFR Part 25, Access Authorization 10 CFR Part 26, Fitness for Duty Programs 10 CFR Part 30, Rules of General Applicability of Byproduct Material 10 CFR Part 31, General Domestic Licenses for Byproduct Material 10 CFR Part 34, Industrial Radiography and Radiation Safety Requirements 10 CFR Part 37, Physical Protection of Category 1 and Category 2 Quantities of Radioactive Material 10 CFR Part 40, Domestic Licensing of Source Material 10 CFR Part 50, Domestic Licensing of Production and Utilization Facilities 10 CFR Part 70, Domestic Licensing of Special Nuclear Material 10 CFR Part 71, Packaging and Transportation of Radioactive Material 10 CFR Part 72, Reports of Accidental Criticality or Loss of Special Nuclear Material 10 CFR Part 73, Physical Protection of Plants and Materials 10 CFR Part 74, Material Control and Accounting of Special Nuclear Material 10 CFR Part 75, Safeguards on Nuclear Material - US/IAEA Agreement
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14 of 46 10 CFR Part 95, Facility Security Clearance and Safeguarding of National Security Information 10 CFR Part 110, Export and Import of Nuclear Equipment and Material 10 CFR Part 140, Financial Protection Requirements and Indemnity Agreements 29 CFR Part 1904, Recording/Reporting of Occupational Injuries and Illnesses 40 CFR Part 82, Protection of Stratosphere Ozone 40 CFR Part 112, Oil Pollution Prevention 40 CFR Part 122, National Pollutant Discharge Elimination System 40 CFR Part 280 Requirements of Underground Storage Tanks 40 CFR Part 302/355, Designation, Reportable Quantities and Notification 40 CFR Part 370, Hazardous Chemical Reporting 40 CFR Part 403, Existing/New Sources of Pollution 40 CFR Part 761, Polychlorinated Biphenyls (PCBs) Manufacturing, Processing, Distribution and Use Prohibitions 49 CFR Part 171, Transportation - Incident Reporting NUREG-1022, Rev. 3, Event Reporting Guidelines 10 CFR 50.72 and 50.73 NEI 07-07, Industry Groundwater Water Protective Initiative United States Nuclear Industry Event Response Framework, Revision 0 ANI Information Bulletin 11-01, Emergency Notification Procedures for ANI Policyholders NERC VAR-002 Generator Operation For Maintaining Network Voltage Schedules
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15 of 46 NERC TOP-001 Reliability Responsibilities and Authorities 6.2.2 BV Beaver Valley Power Station Unit No. 2, License No. NPF-73/Technical Specifications Unit 1 and Unit 2 Beaver Valley Power Station Licensing Requirements Manuals Pennsylvania Code Title 25, Environmental Protection 6.2.3 DB Ohio Administrative Code Ohio Revised Code 6.2.4 PY Perry Nuclear Power Plant Unit No. 1, License No. NPF-58/Technical Specifications Ohio Administrative Code Ohio Revised Code L00811 B00977 L00987 L01123 L02348 L00173 7.0 SCOPE OF REVISION
- 1. Updated from FE grid notifications via RTO Interface Services to Tenaska services. Also updated references associated with the grid notifications.
- 2. Eliminated the word FENOC where possible.
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16 of 46 ATTACHMENT 1: EVENTS OF POTENTIAL PUBLIC INTEREST Page 1 of 1 EPPIs are events that are not classified on the Nuclear Regulatory Commission emergency scale yet may create media interest or raise concern by the general public, public safety agencies, elected officials, or regulators.
EPPI Examples (not all inclusive):
60 Minute Response Timeframe:
Unintended release of chemicals or radioactivity or any unusual operational issues such as fuel defect identification, (Inform offsite agencies once plant announcement is made to the plant staff.)*
Fires on the plant site that require off-site assistance
- Activist group protests on plant property or at the entrance to plant property
- Radiation exposure to an individual in excess of regulatory limits, or the transfer of a radioactive contaminated individual to an off-site medical facility.
- Accidents involving transport of radioactive material to or from the plant site.*
A near site event that could be mistakenly attributed to the plant - Any unexpected or unplanned occurrences on or in the vicinity of the plant that could reasonably be expected to cause the local media or general public to ask questions of the local and state emergency management agencies and elected officials (e.g., aircraft crash outside protected area, major boating accident adjacent to facilities, an event near the site that could be mistakenly attributed to the plant, etc.).*
A major storm in the plant vicinity that may have little or no impact on the nuclear facility but that may draw public and media scrutiny.
- 4 Hour Response Timeframe:
Planned/forced outage or significant down power (greater than 40%). If replacement power has not been secured, await plant management concurrence prior to notification of offsite agencies. Premature notification could result in higher replacement power costs due to competition.
Significant mitigating equipment failures.
Offsite emergency vehicle entering plant property for emergency response situation (in addition to fire assistance). (PY and DB host county and state only; BV all 3 counties and all 3 states)
Any 10 CFR 50.72 or 10 CFR 73.77 telephone call to the NRC 24 Hour Response Timeframe:
Groundwater issues, e.g. tritium. See Communication of Groundwater Issues. Also, Radiation Protection and Chemistry Supervisors and Shippingport and Midland Boroughs (Beaver Valley only) should be contacted.*
(*) Additionally, the Nuclear Energy Institute should be informed for items annotated with an asterisk (*).
NOTE:
NEI contact information:
- neiresponsecenter@nei.org - for EPPI examples (within a GOAL of 60 minutes)
- GW_Notice@nei.org - for groundwater issues Institute of Nuclear Power Operations (INPO):
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17 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 1 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Declaration of an Emergency Classification by the Emergency Plan.
10 CFR 50.72(a)(1)(i) 10 CFR 72.75(a)
- Counties, State(s), NRC Operations Center 15 minutes for state and local governments via phone Immediate via ENS to NRC after State and local notifications but not more than 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> after declaration O1.1 Change in status or capability of any Generator Reactive Power Source, including Automatic Voltage Regulator or Power System Stabilizer or reactive power source under the sites control.
NERC VAR-002 NOP-OP-1003 Tenaska Power Services 20 Minutes Document notification in Unit Log including: Date and time of notification, actions taken, persons involved, etc.
G1.2 Notify Local Control Center of inability to follow voltage schedule or inability to follow grid operator directives.
Notify Tenaska Power Services or Local Control Center of relay or equipment issues that could impact grid reliability.
NERC TOP-001 NOP-OP-1003 Tenaska Power
- Services, Duquesne Light or FE West Control Center 20 minutes via telephone Document notification in Unit Log including: date and time of notification, actions taken, persons involved, etc.
G1.3
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18 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 2 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Duty Teams, SLT, ELT Notifications See NOBP-OP-1015 Attachment 9 Notification O1.2 Table 1 for notification requirements See NOBP-OP-1015 Attach. 9 Notification O1.2 Table 1 for Notification Matrix Various company Positions Alpha Pagers See NOBP-OP-1015 Attach. 9 Notification O1.2 Table 1 for notification matrix and conference call template.
Site Name, Trigger, Critical Data, Conference Call Number/Pass code (if applicable)
O1.2 NRC Resident Notification Any event or condition that involves an unplanned change (> 5% RTP) in reactor power level, (e.g., as a result of the event itself or by some intentional/unintentional operator action).
RCS pressure, temperature, or inventory abnormalities that are outside specified procedural guidelines.
Any event or condition that causes entry into the emergency plan, emergency plan off-normals, Abnormal Operating Procedures, Off Normal Instructions, or Emergency Operating Procedures.
Major unplanned control system failure.
Any condition that requires a 10 CFR 50.72 notification.
Any notification to the NRC Headquarters duty officer (other than for administrative reasons).
Unplanned Technical Specification entry or violation of Technical Specification requirements.
Plant conditions are degraded in a manner that could significantly impact barrier integrity (fuel clad, RCS, CTMT) or significantly impair the function of a mitigating system (such as HPI, LPI, AFW, etc.)
NRC Resident Telephone or face to face O1.3
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19 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 3 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Follow-up notification of certain events, conditions and releases to indicate worsening (or changing) plant conditions or termination of the events related to 10 CFR 50.72(a) or (b).
NRC Operations Center Immediate via ENS (i) any further degradation in the level of safety of the plant or other worsening plant conditions (ii) any change from one Emergency Class to another, or (iii)termination of the Emergency Class O1.4 Independent Spent Fuel Storage Installation or Monitored Retrievable Storage Follow-up notification of certain events, conditions and releases to indicate worsening (or changing) plant conditions or termination of the events related to 10 CFR 72.75(a), (b), (c), or (d).
NRC Operations Center Immediate via ENS
- 1) Immediately notify if any further degradation in the level of safety of the ISFSI or MRS or other worsening conditions.
- 2) Immediately notify if the results of ensuing evaluations or assessments of ISFSI or MRS conditions; the effectiveness of response or protective measures taken; and information related to ISFSI or MRS behavior that is not understood.
O1.5
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20 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 4 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number
- 1) Any event involving radioactive material possessed by the licensee that may have caused or threatens to cause an individual to receive:
- a total effective dose equivalent of 25 rems (0.25 Sv) or more,
- an eye dose equivalent of 75 rems (0.75 Sv) or more,
- a shallow dose equivalent to the skin or extremities of 250 rads (2.5 Gy) or more or
- 2) The release of radioactive material, inside or outside of a restricted area, so that, had an individual been present for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, the individual could have received an intake five times the annual limit on intake (the provisions of this paragraph do not apply to locations where personnel are not normally stationed during routine operations, such as hot-cells or process enclosures) 10 CFR 20.2202(a)
NRC Operations Center Immediate via ENS R1.1 Radioactive material package with removable contamination on external surfaces exceeding limits of 10 CFR 71.87(i) 10 CFR 20.1906(d)(1) 10 CFR 71.87(i)
NRC Operations Center &
Final Delivery Carrier Immediate via ENS R1.2 Radioactive material package with external radiation levels that exceed the limits of 10 CFR 71.47.
10 CFR 20.1906(d)(2) 10 CFR 71.47 NRC Operations Center &
Final Delivery Carrier Immediate via ENS R1.3
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21 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 5 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Any lost, stolen or missing licensed material in an aggregate quantity 1,000 times the quantity specified in Appendix C to 10 CFR 20 under such circumstances that it appears to the licensee that an exposure could result in to persons in unrestricted areas.
Notification of material recovery is also required.
NRC Operations Center Immediate via ENS R1.4 Beaver Valley Only Each licensee or registrant shall notify the Department by telephone immediately, after its occurrence becomes known, a stolen, lost or missing radiation producing machine. (X-ray)
PA Code 25 Title 219.221(1)
PADEP Immediately RB.2 Davis-Besse and Perry Only Any licensed radioactive material that is stolen, lost, or missing in an aggregate quantity equal to or greater than one hundred times the quantity specified in appendix A to rule 3701:1-38-18 of the Administrative Code under such circumstances that it appears to the licensee that an exposure could result to individuals in unrestricted areas; Ohio Administrative Code Section 3701:1-38-21 Director, Ohio Department of Health Immediately at (800) 523-4439 RD.2 RP.2 Beaver Valley Only Over exposure from radiation producing machine (X-ray) or radiation levels in unrestricted area exceeds limit.
Follow 10 CFR 20.2202 and 20.2203 notification criteria with references to NRC or Commission replaced by PADEP PA Code 25 Title 219.222 PADEP Notify PADEP Following 10 CFR 20.2202 and 20.2203 Criteria RB.1
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22 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 6 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Davis-Besse and Perry Only Each event involving a source of radiation possessed by the licensee or registrant (e.g. x-ray device) that may have caused or threatens to cause any of the following conditions:
a) An individual receiving:
A total effective dose equivalent of 0.25 sievert (twenty-five rem) or more; A lens dose equivalent of 0.75 sievert (seventy-five rem) or more; or A shallow dose equivalent to the skin or extremities or a total organ dose equivalent of 2.5 gray (two hundred fifty rad) or more; or b) The release of radioactive material, inside or outside of a restricted area that, had an individual been present for twenty-four hours, the individual could have received an intake five times the occupational ALI. This provision does not apply to locations where personnel are not normally stationed during routine operations, such as hot-cells or process enclosures Ohio Administrative Code Section 3701:1-38-21 Director, Ohio Department of Health Immediately at (800) 523-4439 RD.1 RP.1 Reasonable belief that an NRC employee or NRC contractor may be under the influence of any substance, or is otherwise unfit for duty, the licensee or other entity may not deny access but shall escort the individual.
Notification is made to NRC Regional Administrator or, if not available, the NRC Operations Center followed up by a written notification (email or fax) to document the oral notification.
Immediate to NRC Regional Administrator followed by written notification Telephone to Region or, if not available, via NRC Operations Center S1.1
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23 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 7 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number International Atomic Energy Agency (IAEA) representative on site without having credentials previously confirmed by the NRC.
10 CFR 75.8 NRC Operations Center Promptly notify the NRC Operations Center Individuals name S1.2 Failure to receive periodic call during shipment of special nuclear material.
10 CFR 73.26(i)(6) 10 CFR 73.26(k)(4)
- Director, Division of Security Policy, Office of Nuclear Security and Incident
Response
& Law Enforcement Agencies Immediately S1.3 Delay in receipt or shipment of special nuclear material.
Director, NRR As soon as possible New dates, if known S1.4 Tenaska Power Services Notifications for:
Reactor or Turbine Trip Generation restrictions or inability to meet generation request Threat to plants ability to meet SCC transmission System Owners request Commencing an unplanned or planned shutdown Any power change > 100MWe or MVAR Commencing a normal plant startup Estimated time of Generator Sync to grid Planned or unplanned loss of automatic voltage regulation or power system stabilizer N/A Tenaska Power Services As Soon As Possible via telephone G1.4 Change in plant generation capabilities or characteristics.
NOP-OP-1003 Tenaska Power Services Immediate See NOBP for documentation requirements.
G1.3
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24 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 8 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Notify the Local Control Center of the following:
Unplanned disconnect of the generator from the grid Loss of normal station service to the transmission station Cause of unexpected Main, Auxiliary, or Startup Transformer Trouble.
Loss of the Main, Auxiliary, or Startup Transformers Any fire which threatens Main, Auxiliary, or Startup transformers or the main generator Loss or removal from service of one or more Emergency Diesel Generators Any oil/chemical spill in the switchyard or transformer areas Any control room relay or digital fault recorder alarms received (contact prior to resetting flags)
Unplanned switching operations.
Any question on a switching order Prior to allowing work/access to the switchyard Prior to allowing work/access to the main or startup transformer areas except normal access.
Changes to plant or weather conditions which require cancelling switchyard work (DB) High wind forecast from the West Entry into unplanned 14 day LCO when plant recognizes shutdown will be necessary Emergent plant activities that will impede or preclude scheduled switchyard maintenance (BV) Scheduled or unscheduled activities that restrict switchyard access Any abnormal condition or activity of off-site personnel reported in the switchyard Tornado spotted near the plant N/A Duquesne Light or FE West Control Center As Soon As Possible G1.5
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25 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 9 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number The shipping licensee shall notify the designated LLEA along the shipment route as soon as possible upon discovery of any actual or attempted theft or diversion of a shipment or suspicious activities related to the theft or diversion of a shipment of a category 1 quantity of radioactive material. As soon as possible after notifying the LLEA, the licensee shall notify the NRC's Operations Center upon discovery of any actual or attempted theft or diversion of a shipment, or any suspicious activity related to the shipment of category 1 radioactive material.
Local Law Enforcement Agency (LLEA)
NRC Operations Center As Soon As Possible Designated Local Law Enforcement Agency NRC via ENSS1.14 The shipping licensee shall notify the NRC's Operations Center as soon as possible upon discovery of any actual or attempted theft or diversion of a shipment, or any suspicious activity related to the shipment, of a category 2 quantity of radioactive material.
Local Law Enforcement Agency (LLEA)
NRC Operations Center As Soon As Possible Designated Local Law Enforcement Agency NRC via ENSS1.14
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26 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 10 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Any deviation from the plant's Technical Specifications authorized pursuant to 10 CFR 50.54(x) of this part.
NRC Operations Center 1 Hour via ENS O1.6 Event of Potential Public interest US Nuclear Industry Event Response Framework See and O1.7 Goal of 60 Minutes See Attachment 1 for examples O1.7 Beaver Valley Only Seismic event 0.01g (BV1) or 0.02g (BV2)
BV1/BV2 License Requirements Manual 3.3.6 NRC 1 Hour via ENS OB.1 During a shipment of special nuclear material:
- 1) Loss (other than normal operating loss) or theft or other unlawful diversion of special nuclear material
- 2) Attempt has been made to commit a theft or unlawful diversion of special nuclear material See NOP-LP-1103 for notification requirements 10 CFR 73.71(a)(1)
NRC Operations Center 1 Hour via ENSS1.5 Recovery or accounting for lost shipment of special nuclear material or spent fuel.
NRC Operations Center 1 Hour via ENSS1.5 Significant supplemental information that becomes available after the first notification of lost special nuclear material.
NRC Operations Center As Required via ENSS1.5
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27 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 11 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number See NOP-LP-1103 for Access Authorization Related Events.
- 1) An individual provides false or misleading information in an attempt to gain authorization for access (unescorted or visitor) to the protected or vital area(s) with the intent to commit a criminal act.
- 2) Unescorted access is authorized due to an Access Authorization program failure.
- a. Deliberate failure to perform a background check.
- b. A failure to conduct a complete background investigation or evaluate available information which results in an egregious granting of unescorted access.
- c. Several incidents of granting access without doing a complete background investigation or evaluation in a relatively short period of time indicating a programmatic failure.
- d. More than one individual involved in the Access Authorization process whose failures substantially contributed to the improper granting of access in a single case indicates a programmatic failure.
- e. One individual involved in the access process whose failure on several occasions, over a relatively short time period (e.g., three (3) months),
substantially contributes to a weakened access program and on at least one occasion resulted in an improper granting of access.
NRC Operations Center 1 Hour via ENSS1.6
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28 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 12 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number See NOP-LP-1103 for Security Related Notifications
- 1) Any event in which there is reason to believe that a person has committed or caused, or attempted to commit or cause, or has made a credible threat to commit or cause:
A theft or unlawful diversion of special nuclear material; or Significant physical damage to a power reactor its equipment or carrier equipment transporting nuclear fuel or spent nuclear fuel, or to the nuclear fuel or spent nuclear fuel a facility or carrier possesses; or Interruption of normal operation of a licensed nuclear power reactor through the unauthorized use of or tampering with its machinery, components, or controls including the security system.
- 2) An actual entry of an unauthorized person into a protected area, material access area, controlled access area, vital area, or transport.
- 3) Any failure, degradation, or the discovered vulnerability in a safeguard system that could allow unauthorized or undetected access to a protected area, material access area, controlled access area, vital area, or transport for which compensatory measures have not been employed.
- 4) The actual or attempted introduction of contraband into a protected area, material access area, vital area, or transport.
NRC Operations Center 1 Hour via ENS See NOP-LP-1103 S1.6 Significant supplemental information related to a safeguards event 10 CFR 73.71(a)(5) 10 CFR 73.71(b)(2)
NRC Operations Center As Required Via ENSS1.6
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29 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 13 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Accidental criticality or loss (other than normal operating loss) of special nuclear material 10 CFR 72.74(a) 10 CFR 70.52(a)
NRC Operations Center 1 Hour via ENS Notification of accidental criticality or loss of special nuclear material S1.7 Discovery of any loss or theft or other unlawful diversion of SNM which the licensee is licensed to possess (one gram or more of contained uranium-235, uranium-233, or plutonium), or any incident in which an attempt has been made to commit a theft or unlawful diversion of SNM. This does not pertain to measured discards or inventory difference quantities. Notifications required under 10 CFR 73.71 need not be duplicated under this requirement.
NRC Operations Center 1 Hour via ENSS1.8 The shipping licensee shall notify the appropriate LLEA and the NRC's Operations Center within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of its determination that a shipment of category 1 quantities of radioactive material is lost or missing. The appropriate LLEA would be the law enforcement agency in the area of the shipment's last confirmed location. During the investigation required by § 37.79(c), the shipping licensee will provide agreed upon updates to the NRC's Operations Center on the status of the investigation.
Local Law Enforcement NRC Operations Center Call to appropriate Local Law Enforcement in last confirmed location 1 Hour via ENS to NRC S1.14 The shipping licensee shall notify the NRC's Operations Center and the LLEA as soon as possible upon recovery of any lost or missing category 1 quantities of radioactive material reported under 10 CFR 31.81(a).
Local Law Enforcement NRC Operations Center Call to appropriate Local Law Enforcement As Soon As Possible via ENS to NRC S1.14
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30 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 14 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number A cyber attack that adversely impacted safety-related or important-to-safety functions, security functions, or emergency preparedness functions (including offsite communications); or that compromised support systems and equipment resulting in adverse impacts to safety, security, or emergency preparedness functions within the scope of § 73.54.
NRC Operations Center 1 Hour via ENS See NOBP-OP-1015 Notification S1.13 Note: Non-Reportable Cyber Security Events shall be input into the Corrective Action Program within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of their discovery. Reference NOBP-SS-1208 S1.13 Grid Related Security Event Physical attack that causes major interruptions or impact to critical infrastructure facilities or to operations.
Cyber event that causes interruptions of electrical system operations Physical attach that could potentially impact electric power system adequacy or reliability; or vandalism which targets components of any security systems Cyber event that could potentially impact electric power system adequacy or reliability Damage or destruction of the facility that results from actual or suspected intentional human action Physical threat to the facility, excluding weather or natural disaster related threats, which has the potential to degrade the normal operation of the facility or a suspicious device or activity at the facility.
GOBP-NERC-0001 DOE [All]
NERC [All]
Duquesne Light [BV]
FE West Control Center [DB and PY]
1 Hour via telephone and email Email DOE form OE-417 and copy NERC. See NOBP-OP-1015 Notification G1.1 DOE Email:
doehqeoc@hq.doe.gov NERC Email:
systemawareness@nerc.net G1.1
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31 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 15 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Malfunction or failure of top light or flashing obstruction light required by Federal Aviation Administration that lasts more than 30 minutes.
If not repaired by the previously reported return to service date then an additional notification is required, FAA Advisory Circular AC 70/7460-1L Change 1 FAA Flight Service Station Immediately (877) 487-6867
- 1. Name of persons or organizations reporting light failures including any title, address, and telephone number
- 2. Type of structure
- 3. Location of the structure (including latitude and longitude, prominent structures, landmarks, etc)
- 4. Height of structure above ground level (AGL)/above mean seal level (AMSL), if known
- 5. A return to service date
O1.22 Davis-Besse Only Main Steam Safety Valve/Atmospheric Vent Valve Operation N/A Ottawa County Sheriff Telephone This is (name) at the Davis-Besse Nuclear Power Station. This call is being made to inform you that a plant condition caused steam relief valves to operate at the plant, resulting in noise.
No condition exists which would jeopardize the safety of the public or cause initiation of the Emergency Plan.
OD.1 Schedule changes of more than 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for transportation of spent fuel 10 CFR 73.37(f)(4) 10 CFR 71.97(e)
Responsible individual in Governors Office of the State through which shipment was passing As Soon As Possible The number of hours of advance or delay relative to the written schedule information previously furnished.
S1.9
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32 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 16 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Spills or Environmental Release Notifications per Site Procedures:
Beaver Valley 1/2OM-53C.4A.75.7 Chemical Spills 1/2-ADM-0601 Environmental Reporting 1/2-ADM-0602 Environmental Spill and Release Preparedness Davis-Besse RA-EP-02850 Hazardous Chemical and Oil Spills DBBP-CHEM-2005 Spill Prevention and Control Countermeasure (SPCC) Plan DB-CN-00030 National Pollutant Discharge Elimination System (NPDES) Program Perry ONI-ZZZ-5 Radioactive or Chemical Spill PAP-0806 Oil or Chemical Release Contingency Plan PAP-0808 Environmental Programs and Reports Various Various Varies E1.1 Fire related incident involving a PCB transformer 40 CFR 761.30(a)(1)(xi)
National
Response
Center Immediately by telephone (800) 424-8802 Type of Transformer involved in the fire.
Readily ascertainable cause of the fire-related incident.
E1.2
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33 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 17 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Deleted ANI must be notified as soon as possible in the event of a nuclear emergency that requires notifying State or Federal authorities. This includes transportation incidents involving radioactive materials.
Any situation that might cause authorities to order or recommend off site persons evacuate their homes or businesses because of an actual or potential release of radioactive material from an ANI insured facility or shipment. Even if it appears to be only remotely probable that off-site persons will be affected, ANI must be notified.
In addition ANI must be notified of any Alert, Site Area Emergency, General Emergency. This includes drills.
ANI Information Bulletin 11-01 ANI 24 Hour Emergency Number Telephone (877) 680-2644 Press 1 for Actual Emergency Press 2 for Drill Name Call back number Facility Name of the reporting organization Date and time of event Extent of Damage Describe the nature of the event Contact person and phone number for follow up.
O1.8 Any action taken that departs from a condition or a Technical Specification contained in a license or certificate of compliance issued under 10 CFR 72.
NRC Operations Center 4 Hour via ENS O1.6 The initiation of any nuclear plant shutdown required by the plant's Technical Specifications.. If safety limit is violated, the reactor must be shutdown per 10 CFR 50.36(c)(1)(i)(A) 10 CFR 50.72(b)(2)(i)
NRC Operations Center 4 Hours via ENS O1.9 Any event that results or should have resulted in an Emergency Core Cooling System (ECCS) discharge into the reactor coolant system as a result of a valid signal except when the actuation results from and is part of a pre-planned sequence during testing or reactor operation.
NRC Operations Center 4 Hours via ENS O1.10
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
34 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 18 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Any event or condition that results in the actuation of the Reactor Protection System (RPS) when the reactor is critical except when the actuation results from and is part of a pre-planned sequence during testing or reactor operation.
NRC Operations Center 4 Hours via ENS O1.11 News release or notification to other government agency. Any event or situation related to the health and safety of the public or onsite personnel or protection of the environment, for which a news release is planned or notification to other government agencies has been or will be made. Such an event may include an onsite fatality or inadvertent release of radioactively contaminated materials.
10 CFR 50.72(b)(2)(xi) 10 CFR 72.75(b)(2)
NRC Operations Center 4 Hours via ENS O1.12 Recovery of any lost, stolen, or missing licensed material that is equal to or greater than Category II levels.
10 CFR 20.2201 RIS 2005-21 NRC Operations Center 4 Hours via ENS R1.4 Actual or attempted theft of Category 1 or Category 2 quantity of radioactive material 10 CFR 37.57 NRC Operations.
Center 4 Hours via ENSS1.12 Any incident in which an attempt has been made or is believed to have been made to commit theft or unlawful diversion of more than 15 pounds at one time or 150 pounds over any one calendar year of uranium or thorium.
NRC Operations Center 4 Hours via ENSS1.10
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
35 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 19 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number (i) After discovery of a cyber attack that could have caused an adverse impact to safety-related or important-to-safety functions, security functions, or emergency preparedness functions (including offsite communications); or that could have compromised support systems and equipment, which if compromised, could have adversely impacted safety, security, or emergency preparedness functions within the scope of § 73.54.
(ii) After discovery of a suspected or actual cyber attack initiated by personnel with physical or electronic access to digital computer and communication systems and networks within the scope of § 73.54.
(iii) After notification of a local, State, or other Federal agency (e.g., law enforcement, FBI, etc.) of an event related to the licensees implementation of their cyber security program for digital computer and communication systems and networks within the scope of § 73.54 that does not otherwise require a notification under paragraph (a) of this section.
NRC Operations Center 4 Hours via ENS See NOBP-OP-1015 Notification S1.13 Note: Non-Reportable Cyber Security Events shall be input into the Corrective Action Program within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of their discovery.
Reference NOBP-SS-1208 S1.13 The shipping licensee shall notify the NRC's Operations Center within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> of its determination that a shipment of category 2 quantities of radioactive material is lost or missing. If, after 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of its determination that the shipment is lost or missing, the radioactive material has not been located and secured, the licensee shall immediately notify the NRC's Operations Center.
Local Law Enforcement NRC Operations Center Call to appropriate Local Law Enforcement in last confirmed location 4 Hours via ENS to NRC S1.14
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
36 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 20 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number The shipping licensee shall notify the NRC's Operations Center as soon as possible upon recovery of any lost or missing category 2 quantities of radioactive material reported under 10 CFR 37.81(b).
Local Law Enforcement NRC Operations Center Call to appropriate Local Law Enforcement As Soon As Possible via ENS to NRC S1.14 Notify NEIL of the following conditions:
- Continued operation of damaged equipment where outage or significant physical damage may occur
- Adverse vibration conditions
- Adverse transformer oil results
- Crack indications in turbines
- Continued operation with failed or defeated safety devices which could lead to turbine water introduction or turbine over speed
- Fire involving actuation or malfunction of a fixed fire extinguishing or detection system
- Any physical damage loss in excess of $100,000
- Any fire impairment when the impairment is expected to exceed 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.
NOBP-SS-7005 NEIL Per NOBP-SS-7005 O1.23 Any event or condition that results in:
A)
The condition of the nuclear power plant, including its principal safety barriers, being seriously degraded.
B)
The nuclear power plant being in an unanalyzed condition that significantly degrades plant safety.
NRC Operations Center Within 8 Hours via ENS If not reported within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, the licensee shall notify the NRC as soon as practical and in all cases within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> If safety limit is violated, the reactor must be shutdown per 10 CFR 50.36(c)(1)(i)(A)
O1.13
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
37 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 21 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Any event or condition that results in valid actuation of any of the systems listed in 10 CFR 50.72(b)(3)(iv)(B) except when the actuation results from and is part of a pre-planned sequence during testing or reactor operation.
NRC Operations Center 8 Hours via ENS O1.14 O1.11 Any event or condition that at the time of discovery could have prevented the fulfillment of the safety function of structures or systems that are needed to:
Shutdown the reactor and maintain it in a safe shutdown condition.
Remove residual heat Control the release of radioactive material; or Mitigate the consequences of an accident Events covered in this section may include one or more procedural errors, equipment failures, and/or discovery of design, analysis, fabrication, construction, and/or procedural inadequacies.
However, individual component failures need not be reported if redundant equipment in the same system was operable and available to perform the required safety function. At PY HPCS is a single train safety system.
10 CFR 50.72(b)(3)(v) 10 CFR 50.72(b)(3)(vi)
NRC Operations Center 8 Hours via ENS O1.15
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
38 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 22 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Any event that results in a major loss of emergency assessment capability, offsite response capability, or offsite communication capability (e.g., significant portion of control room indication, ENS, or offsite notification system).
NRC Operations Center 8 Hours via ENS O1.16 Discovery of any of the following events or conditions involving spent fuel or high level waste:
A defect in any spent fuel storage structure, system, or component that is important to safety.
A significant reduction in the effectiveness of any spent fuel storage confinement system during use.
NRC Operations Center 8 Hours via ENS
- Caller's name and call back telephone number;
- Description of the event, including date and time;
- Exact location of the event;
- Quantities and chemical and physical forms of the spent fuel, HLW, or reactor-related GTCC waste involved in the event; and
- Any personnel radiation exposure data.
O1.17 Receipt or collection of information regarding observed behavior, activities, or statements that may indicate intelligence gathering or pre-operational planning related to a cyber attack against digital computer and communication systems and networks within the scope of § 73.54.
NRC Operations Center 8 Hours via ENS See NOBP-OP-1015 Notification S1.13 Note: Non-Reportable Cyber Security Events shall be input into the Corrective Action Program within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of their discovery. Reference NOBP-SS-1208 S1.13
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
39 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 23 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Work related fatality, in-patient hospitalization or an employees amputation or an employees loss of an eye, as a result of a work-related incident.
Notify of the following:
Any fatality caused by a heart attack at the plant is reportable per this requirement. Fatalities that occur within thirty days of an incident are required to be reported.
Notification is to be completed by the Director, Corporate Health and Safety per the FirstEnergy Process for Managing Interactions with Federal, State, and Local Health & Safety Agencies 29 CFR 1904.39 Area OSHA Office Contact
- Director, Corporate Health and Safety to make notification:
8 Hours via telephone (fatality)
Or 24 Hours via telephone (other events)
Area OSHA Office or (800) 321-6742 or www.osha.gov Plant Name Plant Location Time of the Incident Type of Reportable Event (i.e. fatality, in-patient hospitalization, amputation, or loss of an eye)
Number of employees who suffered the fatality, in-patient hospitalization, amputation, or loss of an eye Names of Injured Employees Your Contact person and their phone number Brief description of the incident O1.18 Any event requiring the transport of a radioactively contaminated person to an offsite medical facility for treatment.
10 CFR 50.72(b)(3)(xii) 10 CFR 72.75(c)(3)
NRC Operations Center 8 Hours via ENS The caller's name and call back telephone number Description of the event, including date and time; Exact location of the event R1.9
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
40 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 24 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Notification from the carrier in physical possession of the hazardous material whenever any of the following occurs during the course of transportation in commerce (including loading, unloading, and temporary storage):
- 1) As a direct result of a hazardous material:
A person is killed; A person receives an injury requiring admittance to a hospital; The general public is evacuated for one hour or more; A major transportation artery or facility is closed or shut down for one hour or more; or The operational flight pattern or routine of an aircraft is altered;
- 2) Fire, breakage, spillage, or suspected radioactive contamination occurs involving a radioactive material
- 3) Fire, breakage, spillage, or suspected contamination occurs involving an infectious substance other than a regulated medical waste;
- 4) A release of a marine pollutant occurs in a quantity exceeding 119 gallons for a liquid or 882 pounds for a solid;
- 5) A situation exists of such a nature that, in the judgment of the person in possession of the hazardous material, it should be reported to the NRC
- 6) During transportation by aircraft, a fire, violent rupture, explosion or dangerous evolution of heat occurs as a direct result of a battery or battery-powered device.
10 CFR 71.5(a)(iv) 49 CFR 171.15 National
Response
Center Within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (800) 424-8802 or (202) 267-2675 or online at www.nrc.usc g.mil (1) Name of person notifying; (2) Name and address of person represented by person notifying; (3) Phone number where person can be contacted; (4) Date, time, and location of incident; (5) The extent of injury, if any; (6) Class or division, proper shipping name, and quantity of hazardous materials involved, if such information is available; and (7) Type of incident and nature of hazardous material involvement and whether a continuing danger to life exists at the scene.
R1.10
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
41 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 25 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Contaminated Spills or Ground Water Issues See NOP-OP-4705 Response to Contaminated Spills/Leaks Contaminated leaks, spills or groundwater Issues such as tritium or other gamma emitters. See Attachment 1 for communication plan.
US Nuclear Industry Event Response Framework See 24 Hour
Response
per NOP-OP-4705 and Attach.1 R1.7 Any of the following events involving spent fuel, High Level Waste (HLW), or reactor-related Greater Than Class C (GTCC) waste:
(1) An event in which important to safety equipment is disabled or fails to function as designed when:
(i) The equipment is required by regulation, license condition, or certificate of compliance to be available and operable to prevent releases that could exceed regulatory limits, to prevent exposures to radiation or radioactive materials that could exceed regulatory limits, or to mitigate the consequences of an accident; and (ii) No redundant equipment was available and operable to perform the required safety function.
NRC Operations Center 24 Hours via ENS (i) The caller's name and call back telephone number; (ii) A description of the event, including date and time; (iii) The exact location of the event; (iv) The quantities and chemical and physical forms of the spent fuel, HLW, or reactor-related GTCC waste involved in the event; and (v) Any personnel radiation exposure data.
O1.17 Confirmed presence of a loose part in the reactor R.G. 1.133 NRC Operations Center 24 Hours O1.19
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
42 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 26 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number
- 1) Any event involving the loss of control of licensed material possessed by the licensee that may have caused, or threatens to cause, an individual to receive, in a period of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, any of the following:
a total effective dose equivalent to receiving 5 rems (0.05 Sv), or an eye dose equivalent exceeding 15 rems (0.15 Sv) or a shallow dose equivalent to the skin or extremities exceeding 50 rems (0.50Sv) or 2)The release of radioactive material, inside or outside the restricted area, so that, had an individual been present for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, the individual could have received an intake in excess of one occupational annual limit on intake (the provisions of this paragraph do not apply to locations where personnel are not normally stationed during routine operations, such as hot cells or process enclosures).
NRC Operations Center 24 Hours via ENS R1.1
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
43 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 27 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Davis-Besse and Perry Only Each event involving loss of control of a licensed or registered source of radiation possessed by the licensee or registrant that may have caused, or threatens to cause, any of the following:
a) An individual to receive, in a period of twenty-four hours:
A total effective dose equivalent exceeding 0.05 sievert (five rem);
An lens dose equivalent exceeding 0.15 sievert (fifteen rem); or A shallow dose equivalent to the skin or extremities or a total organ dose equivalent exceeding 0.5 sievert (fifty rem); or b) The release of radioactive material, inside or outside of a restricted area that, had an individual been present for twenty-four hours, the individual could have received an intake in excess of one occupational ALI. This provision does not apply to locations where personnel are not normally stationed during routine operations, such as hot-cells or process enclosures.
Ohio Administrative Code Section 3701:1-38-21 Director, Ohio Department of Health Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at (800) 523-4439 RD.1 RP.1
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
44 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 28 of 30 Operational Notifications Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number See NOP-LP-1103 for Fitness for Duty (FFD) Notification details Significant FFD policy violations or programmatic failures such as:
- 1) The use, sale, distribution, possession, or presence of illegal drugs, or the consumption or presence of alcohol within a protected area;
- 2) Any acts by any person licensed under 10 CFR part 55 to operate a power reactor, as well as any acts by SSNM transporters, FFD program personnel, or any supervisory personnel who are authorized under this part, if such acts
- Involve the use, sale, or possession of a controlled substance;
- Result in a determination that the individual has violated the licensee's or other entity's FFD policy or
- Involve the consumption of alcohol within a protected area or while performing the duties that require the individual to be subject to the FFD program;
- 3) Any intentional act that casts doubt on the integrity of the FFD program; and
- 4) Any programmatic failure, degradation, or discovered vulnerability of the FFD program that may permit undetected drug or alcohol use or abuse by individuals within a protected area, or by individuals who are assigned to perform duties that require them to be subject to the FFD program.
See NOP-LP-1103 for notification and logging requirements and criteria NRC Operations Center 24 Hours See NOP-LP-1103 S1.11
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
45 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 29 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Drug and Alcohol Testing errors where:
False positive error occurs on a blind performance test sample submitted to an HHS-certified laboratory False negative error occurs on a quality assurance check of validity screening tests, as required in § 26.137(b) 10 CFR 26.719(c)
NRC 24 Hours See NOP-LP-1103 S1.11 Beaver Valley 2 and Perry Only Significant environmental impact casually related to plant operation.
BV2 License Appendix B Section 4.1 PY License Appendix B Section 4.1 NRC Operations Center Within 24 Hours via ENS EB.1 EP.1 Incomplete or incorrect information that has a significant implication on public health and safety, common defense or security.
10 CFR 50.9(b) 10 CFR 30.9(b) 10 CFR 40.9(b) 10 CFR 70.9(b) 10 CFR 71.7(b) 10 CFR 72.11(b)
NRC IN 95-51 NRC Regional Administrator Within 2 working days of identifying information O1.20
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1015
Title:
Event Notifications Use Category:
General Skill Reference Revision:
8 Page:
46 of 46 ATTACHMENT 2: EVENT NOTIFICATION REQUIREMENTS Page 30 of 30 Notification/Subject Requirements Recipient Time &
Method of Notification Content NOBP-OP-1015 Notification Number Receipt of information reasonably indicating that a notification required pursuant to 10 CFR 21 exists.
Reportability under 10 CFR 21 is established when creation of a substantial safety hazard (i.e. loss of safety function to the extent that there is a major reduction in the degree of protection provided to the public health and safety) can be postulated if a condition adverse to quality had gone uncorrected which also represents:
A noncompliance with the Atomic Energy Action of 1954, as amended, or any applicable rule, regulation, order, or other license of the NRC or standard design approval under part 52 relating to substantial safety hazard; or A defect in the licensed facility or activity; or A defect in the basic component supplied to the licensed facility or activity Notification is not required if individual has actual knowledge that the Commission has been notified in writing of the defect or failure to comply.
See Section 4.5 for additional detail.
10 CFR 21.21(d)(3) 10 CFR 21.21(a)(2)
NRC Operations Center Within 2 days via facsimile with verbal verification that the fax was received O1.21 30 days after the occurrence of any lost, stolen, or missing licensed material becomes known to the licensee, all licensed material in a quantity greater than 10 times the quantity specified in Appendix C to part 20 that is still missing at this time.
NRC Operations Center 30 Days via ENS R1.4
Admin JPM A1.2
Facility: Davis-Besse Task No: 333-014-01-0300 Task
Title:
Perform review of a Boric Acid Batch Calculation K/A
Reference:
2.1.37 (4.6)
Job Performance Measure No: A1.2 (OPSJPM307)
Examinee:
NRC Examiner:
Date:
Method of testing:
Simulated Performance ___
Actual Performance _X_
Classroom _X_
Simulator ___
Plant ___
Read to the examinee:
I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues.
When you complete the task successfully, the objective for this job performance measure will be satisfied.
Initial Conditions:
The plant conditions are specified in the Initial Conditions and Initiating Cues.
Task Standard:
Perform review of a Boric Acid Batch Calculation Required Materials:
DB-OP-06001, Boron Concentration Control Attachment 2 (completed) and Attachment 7 DB-NE-06201, Reactor Operator Curve Book Procedure Straight edge, Calculator General
References:
None Initiating Cue:
The plant conditions are specified in the Initial Conditions and Initiating Cues.
Time Critical Task:
No Alternate Path:
No Validation Time:
19 minutes
EVALUATOR COPY INITIAL CONDITIONS:
A plant startup is in progress TI RC 7 indicates Tavg is 582 F PRS RC2A1 indicates RCS Pressure is 2155 PSIG PZR Level is 220 inches RCS Boron concentration is 1000 PPM INITIATING CUE:
Reactor Engineering recommends lowering RCS boron concentration to 975 PPM to ensure Control Rod index is adequate to complete the power increase to 100%
A Reactor Operator has performed a batching calculation per DB-OP-06001, Boron Concentration Control, Attachment 2: Batching Equations.
The Shift Manager directs you to perform a review of the boric acid batching calculation and approve the batch addition or make any corrections if necessary.
The batch will be made from CWMT 1 with a boron concentration of 0 ppm (Provide examinee a copy of completed Attachment 2 and Attachment 7 of DB-OP-06001 and DB-NE-06201)
CANDIDATE COPY INITIAL CONDITIONS:
A plant startup is in progress TI RC 7 indicates Tavg is 582 F PRS RC2A1 indicates RCS Pressure is 2155 PSIG PZR Level is 220 inches RCS Boron concentration is 1000 PPM INITIATING CUE:
Reactor Engineering recommends lowering RCS boron concentration to 975 PPM to ensure Control Rod index is adequate to complete the power increase to 100%
A Reactor Operator has performed a batching calculation per DB-OP-06001, Boron Concentration Control, Attachment 2: Batching Equations.
The Shift Manager directs you to perform a review of the boric acid batching calculation and approve the batch addition or make any corrections if necessary.
The batch will be made from CWMT 1 with a boron concentration of 0 ppm Document the results of your review on this page.
PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is NOT required unless denoted in the "Comments".
START TIME:
- 1.
PERFORMANCE STEP: Verify RCS temperature recorded on Attachment 2 STANDARD: RCS average temperature recorded: 582 F CUE: None SAT UNSAT
- 2.
PERFORMANCE STEP: Verify RCS pressure recorded on Attachment 2 STANDARD: RCS Pressure recorded: 2155 + 14.7 = 2169.7 to 2170 PSIA CUE: None SAT UNSAT
- 3.
PERFORMANCE STEP: Verify RCS Volume recorded on Attachment 2 STANDARD: DB-NE-06201, Figure 7, RCS Volume: 11375 to11385 ft3 CUE: None SAT UNSAT
- 4. PERFORMANCE STEP: Determine the RCS Specific Volume from Attachment 7 of
........C........
DB-OP-06001 value recorded on Attachment 2 is incorrect STANDARD: Determine RCS Specific Volume recorded is incorrect. From bottom of Attachment 7 of DB-OP-06001, determine actual value is 0.02245 ft3 /lbm NOTE: May also interpolate a value for Specific Volume = 0.02240 to 0.02250 CUE: None SAT UNSAT
- 5.
PERFORMANCE STEP: Verify RCS Boron concentration recorded on Attachment 2 STANDARD: Initial RCS Boron concentration: 1000 PPM CUE: None SAT UNSAT
- 6.
PERFORMANCE STEP: Desired RCS Boron concentration recorded on Attachment 2 STANDARD: Desired RCS Boron concentration: 975 PPM CUE: None SAT UNSAT
- 7.
PERFORMANCE STEP: Batch Solution Boron concentration recorded on Attachment 2 STANDARD: Batch Solution Boron concentration: 0 PPM CUE: None SAT UNSAT
- 8.
PERFORMANCE STEP: Determine calculated mass of the RCS is incorrect and calculate
........C........ correct value STANDARD: Determine calculated mass of the RCS is incorrect.
Calculate the mass of the RCS by dividing the RCS Volume by the Specific Volume as follows:
(11375 to11385) ft3 (0.02240 to 0.02250) ft3 /lbm = 505555 to 508259 lbm CUE: None SAT UNSAT
- 9.
PERFORMANCE STEP: Determine the total calculated mass is incorrect and calculate
........C........ correct value STANDARD: Determine the total calculated mass is incorrect.
Calculate the total mass by adding the mass of the RCS to the constant for the mass of the MU System as follows:
(505555 to 508259) lbm+ 23765 lbm = (529320 to 532024) lbm CUE: None SAT UNSAT
- 10. PERFORMANCE STEP: Determine the calculated batch size is incorrect and calculate
........C........
the correct value STANDARD: Determine the calculated batch size is incorrect.
Calculate the batch size as follows:
(k)(Mtotal)(Cf - Ci) (Cb - CF)
(.12) (529320 to 532024) (975 - 1000) = (1628 to 1637) gallons (0 - 975)
CUE: None SAT UNSAT TERMINATING CUES:
This JPM is complete (Terminated by examinee)
END TIME: ____________
Page 1 of 53 Davis-Besse Nuclear Power Station PLANT PROCEDURE DB-NE-06201 REACTOR OPERATORS CURVE BOOK REVISION 20 Prepared by:
Ryan Magruder Procedure Owner:
Supervisor - Nuclear Reactor Engineering Effective Date: ____________________________
LEVEL OF USE:
GENERAL REFERENCE 06/10/20
2 DB-NE-06201 Revision 20 REACTOR OPERATORS CURVE BOOK TABLE OF CONTENTS Page 1.0 PURPOSE............................................................................................................... 7 2.0 LIMITS AND PRECAUTIONS............................................................................. 7 2.1 Administrative........................................................................................... 7 2.2 Equipment.................................................................................................. 7 3.0 FIGURE USE......................................................................................................... 7
4.0 REFERENCES
....................................................................................................... 7 5.0 RECORDS.............................................................................................................. 7
3 DB-NE-06201 Revision 20 REACTOR OPERATORS CURVE BOOK TABLE OF CONTENTS (Continued)
FIGURE TITLE Page 1
Fuel Excess Reactivity Worth, "Power" Reference Condition, Page 1 of 2, 400 EFPD.......................................................................................... 8 Fuel Excess Reactivity Worth, "Power" Reference Condition, Page 2 of 2, 400 EFPD.......................................................................................... 9 2
Fuel Excess Reactivity Worth, "Critical" Reference Condition, Page 1 of 2, 400 EFPD.......................................................................................... 10 Fuel Excess Reactivity Worth, "Critical" Reference Condition, Page 2 of 2, 400 EFPD.......................................................................................... 11 3
Integral Worth of Soluble Boron, 0 EFPD, Page 1 of 2, 1500 ppmB........................................................................................ 12 Integral Worth of Soluble Boron, 0 EFPD, Page 2 of 2, 1500 ppmB........................................................................................ 13 4
Integral Boron Worth Correction Factor, Page 1 of 2, 400 EFPD......................... 14 Integral Boron Worth Correction Factor, Page 2 of 2, 400 EFPD......................... 15 5A Differential Reactivity Worth of Soluble Boron, "Critical" Reference Condition, Page 1 of 2, APSRs In.......................................... 16 Differential Reactivity Worth of Soluble Boron, "Critical" Reference Condition, Page 2 of 2, APSRs Out........................................ 17 5B Differential Reactivity Worth of Soluble Boron, "Power" Reference Condition, Page 1 of 2, APSRs In............................................ 18 Differential Reactivity Worth of Soluble Boron, "Power" Reference Condition, Page 2 of 2, APSRs Out......................................... 19
4 DB-NE-06201 Revision 20 REACTOR OPERATORS CURVE BOOK TABLE OF CONTENTS (Continued)
FIGURE TITLE Page 6A Minimum Boron Concentration to Assure 1% k/k Shutdown Margin, NO Known Stuck/Dropped/Misaligned Rod, Page 1 of 2, 400 EFPD.................. 20 Minimum Boron Concentration to Assure 1% k/k Shutdown Margin, NO Known Stuck/Dropped/Misaligned Rod, Page 2 of 2, 400 EFPD.................. 21 6B Minimum Boron Concentration to Assure 1% k/k Shutdown Margin, ONE Known Stuck/Dropped/Misaligned Rod, Page 1 of 2, 400 EFPD................ 22 Minimum Boron Concentration to Assure 1% k/k Shutdown Margin, ONE Known Stuck/Dropped/Misaligned Rod, Page 2 of 2, 400 EFPD................ 23 6C Minimum Boron Concentration to Assure 1% k/k Shutdown Margin, MORE THAN ONE Known Stuck/Dropped/Misaligned Rod, T560F, Page 1 of 2, 400 EFPD.......................................................................................... 24 Minimum Boron Concentration to Assure 1% k/k Shutdown Margin, MORE THAN ONE Known Stuck/Dropped/Misaligned Rod, T560F, Page 2 of 2, 400 EFPD.......................................................................................... 25 7
RCS Water Volume Versus Pressurizer Level, Page 1 of 2, 210 inches......................................................................................... 26 RCS Water Volume Versus Pressurizer Level, Page 2 of 2, 210 inches......................................................................................... 27 8
Integral Control Rod Worth Groups 5-7, "Power" Reference Condition, Page 1 of 4, GRPs 5-7, APSRs In............................................................................ 28 Integral Control Rod Worth Groups 5-7, "Power" Reference Condition, Page 2 of 4, GRPs 5-7, APSRs Out......................................................................... 29 Integral Control Rod Worth Group 7, "Power" Reference Condition, Page 3 of 4, APSRs In............................................................................................. 30 Integral Control Rod Worth Group 7, "Power" Reference Condition, Page 4 of 4, APSRs Out........................................................................................... 31
5 DB-NE-06201 Revision 20 REACTOR OPERATORS CURVE BOOK TABLE OF CONTENTS (Continued)
FIGURE TITLE Page 9A Integral Control Rod Worth Groups 5-7, "Critical" Reference Condition, NO Xenon, Page 1 of 4, GRPs 5-7, APSRs In........................................................ 32 Integral Control Rod Worth Groups 5-7, "Critical" Reference Condition, NO Xenon, Page 2 of 4, GRPs 5-7, APSRs Out...................................................... 33 Integral Control Rod Worth Group 7, "Critical" Reference Condition, NO Xenon, Page 3 of 4, APSRs In.......................................................................... 34 Integral Control Rod Worth Group 7, "Critical" Reference Condition, NO Xenon, Page 4 of 4, APSRs Out....................................................................... 35 9B Integral Control Rod Worth Groups 5-7, "Critical" Reference Condition, PEAK Xenon, Page 1 of 4, GRPs 5-7, APSRs In.................................................... 36 Integral Control Rod Worth Groups 5-7, "Critical" Reference Condition, PEAK Xenon, Page 2 of 4, GRPs 5-7, APSRs Out................................................. 37 Integral Control Rod Worth Group 7, "Critical" Reference Condition, PEAK Xenon, Page 3 of 4, APSRs In..................................................................... 38 Integral Control Rod Worth Group 7, "Critical" Reference Condition, PEAK Xenon, Page 4 of 4, APSRs Out................................................................... 39 10 Adjusted Reactivity Worth of Control Rod Groups 1-7: R (for Shutdown Margin Calculations only), Critical Reference Condition, Page 1 of 2, 400 EFPD........................................................................................... 40 Adjusted Reactivity Worth of Control Rod Groups 1-7: R (for Shutdown Margin Calculations only), Critical Reference Condition, Page 2 of 2, 400 EFPD.......................................................................................... 41 11A APSR Reactivity Worth- "Critical" Reference Condition....................................... 42 11B APSR Reactivity Worth- "Power" Reference Condition......................................... 43 12 Temperature Coefficient, Group 1 @ 100% WD, 2-7 @ 0% WD, 532F, Page 1 of 2, APSRs In............................................................................................. 44 Temperature Coefficient, Group 1 @ 100% WD, 2-7 @ 0% WD, 532F, Page 2 of 2, APSRs Out........................................................................................... 45
6 DB-NE-06201 Revision 20 REACTOR OPERATORS CURVE BOOK TABLE OF CONTENTS (Continued)
FIGURE TITLE Page 13 Deleted 14 Power Reactivity Deficit, Page 1 of 2, APSRs In.................................................... 46 Power Reactivity Deficit, Page 2 of 2, APSRs Out................................................. 47 15 Minimum Boron Concentration to Ensure 1% k/k Shutdown Value, CRG 1 @ 100% WD, CRG 2-7 @ 0% WD, NO Xenon, No Stuck Rod Assumed, Page 1 of 2, 400 EFPD........................................................................................... 48 Minimum Boron Concentration to Ensure 1% k/k Shutdown Value, CRG 1 @ 100% WD, CRG 2-7 @ 0% WD, NO Xenon, No Stuck Rod Assumed, Page 2 of 2, 400 EFPD.......................................................................................... 49 16 Deleted 17A Deleted 17B Deleted 18A Deleted 18B Deleted 19 Deleted 20A Transient Plutonium-239 Build-in Fraction 50 20B Maximum Excess Plutonium-239 Worth, Page 1 of 2, 50 EFPD. 51 Maximum Excess Plutonium-239 Worth, Page 2 of 2, 50 EFPD. 52 TABLE TITLE Page 1
Cycle 22 Miscellaneous Physics Parameters........................................................... 53
7 DB-NE-06201 Revision 20 1.0 PURPOSE 1.1 This procedure provides curves that are: 1) guidelines in operating the reactor and, 2) necessary to execute various procedures (e.g., DB-OP-06001, Boron Concentration Control, and DB-NE-06202, Reactivity Balance Calculations). The curves are based on RATED THERMAL POWER equal to 2817 MWt.
2.0 LIMITS AND PRECAUTIONS 2.1 Administrative 2.1.1 Some figures contain curves for different times in core life (i.e., different Effective Full Power Days - EFPDs). Values at other times in core life should be determined by linear interpolation between the two curves that bound the desired time in core life. An approximate interpolated value may be determined by reading the value directly from the figure. A formal calculation is not required.
2.1.2 The user shall not attempt to interpolate between two curves that are at different temperatures or between the "Power" and "Critical" reference conditions. These types of interpolations may not be linear.
2.1.3 Some curves have a step change near the end of core life due to Axial Power Shaping Rod (APSR) removal. After APSRs are removed, the curve segment after the step change shall be used.
2.1.4 Due to extended cycle lengths, the data for some figures is split into two curves on separate pages.
2.1.5 Figures that are labeled APSRs In have the data for APSRs Out on a separate page.
The curves labeled APSRs In shall be used until the APSRs are removed towards the end of core life. After the APSRs are removed, the curves labeled APSRs Out shall be used.
2.2 Equipment None.
3.0 FIGURE USE Prerequisites None.
Procedure 3.1 See LIMITS AND PRECAUTIONS.
4.0 REFERENCES
4.1 Developmental 4.1.1 C-NRE-062.02-172, Rev. 0 - Cycle 22 Reactor Operators Curve Book (ROCB) Figure Update 4.1.2 C-NRE-062.02-172, Rev. 0, Addendum 01 - Cycle 22 Reactor Operators Curve Book (ROCB) Figure Update 4.2 Implementation None.
5.0 RECORDS This procedure contains information that is referenced by other procedures and does not generate any records, therefore, there are no documentations requirements associated with this procedure. The procedures that direct the use of this procedure will identify any required documentation.
8 DB-NE-06201 Revision 20 8.0 8.5 9.0 9.5 10.0 10.5 11.0 0
20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 Fuel Reactivity Worth (% k/k)
EFPD Cycle 22 Figure 1: Fuel Excess Reactivity Worth - "Power" Reference Condition Figure 1 Page 1 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:02:47
9 DB-NE-06201 Revision 20 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 6.5 7.0 7.5 8.0 8.5 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 Fuel Reactivity Worth (% k/k)
EFPD Cycle 22 Figure 1: Fuel Excess Reactivity Worth - "Power" Reference Condition Figure 1 Page 2 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:02:47
10 DB-NE-06201 Revision 20 10.5 11.0 11.5 12.0 12.5 13.0 13.5 0
20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 Fuel Reactivity Worth (% k/k)
EFPD Cycle 22 Figure 2: Fuel Excess Reactivity Worth - "Critical" Reference Condition Figure 2 Page 1 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:07:25
11 DB-NE-06201 Revision 20 4.5 5.0 5.5 6.0 6.5 7.0 7.5 8.0 8.5 9.0 9.5 10.0 10.5 11.0 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 Fuel Reactivity Worth (% k/k)
EFPD Cycle 22 Figure 2: Fuel Excess Reactivity Worth - "Critical" Reference Condition Figure 2 Page 2 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:07:25
12 DB-NE-06201 Revision 20
-10.0
-9.5
-9.0
-8.5
-8.0
-7.5
-7.0
-6.5
-6.0
-5.5
-5.0
-4.5
-4.0
-3.5
-3.0
-2.5
-2.0
-1.5
-1.0
-0.5 0.0 0
100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 Integral Boron Worth @ 0 EFPD (% k/k)
RCS Boron Concentration (ppmB)
Cycle 22 Figure 3: Integral Worth of Soluble Boron 0 EFPD Critical Power Figure 3 Page 1 of 2 1500 ppmB DATE: Mar 1, 2020 TIME: 07:48:31
13 DB-NE-06201 Revision 20
-20.0
-19.5
-19.0
-18.5
-18.0
-17.5
-17.0
-16.5
-16.0
-15.5
-15.0
-14.5
-14.0
-13.5
-13.0
-12.5
-12.0
-11.5
-11.0
-10.5
-10.0
-9.5
-9.0
-8.5 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 Integral Boron Worth @ 0 EFPD (% k/k)
RCS Boron Concentration (ppmB)
Cycle 22 Figure 3: Integral Worth of Soluble Boron 0 EFPD Critical Power Figure 3 Page 2 of 2 1500 ppmB DATE: Mar 1, 2020 TIME: 07:48:31
14 DB-NE-06201 Revision 20 0.99 1.00 1.01 1.02 1.03 1.04 1.05 1.06 1.07 1.08 0
20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 BCF = (Boron Worth)/(Boron Worth @ 0 EFPD)
EFPD Cycle 22 Figure 4: Integral Boron Worth Correction Factor Power Critical Figure 4 Page 1 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:15:11
15 DB-NE-06201 Revision 20 1.06 1.07 1.08 1.09 1.10 1.11 1.12 1.13 1.14 1.15 1.16 1.17 1.18 1.19 1.20 1.21 1.22 1.23 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 BCF = (Boron Worth)/(Boron Worth @ 0 EFPD)
EFPD Cycle 22 Figure 4: Integral Boron Worth Correction Factor Figure 4 Page 2 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:15:11 After APSR Pull Power Critical
16 DB-NE-06201 Revision 20
-0.0081
-0.0080
-0.0079
-0.0078
-0.0077
-0.0076
-0.0075
-0.0074
-0.0073
-0.0072
-0.0071
-0.0070
-0.0069
-0.0068
-0.0067
-0.0066
-0.0065
-0.0064
-0.0063
-0.0062
-0.0061
-0.0060 0
100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 Differential Boron Worth (% k/k)/ppmB RCS Boron Concentration (ppmB)
Cycle 22 Figure 5A: Differential Reactivity Worth of Soluble Boron "Critical" Reference Condition APSRs In Figure 5A Page 1 of 2 APSRs In 0 EFPD 100 EFPD 200 EFPD 658 EFPD DATE: Mar 1, 2020 TIME: 07:55:13 600 EFPD 500 EFPD 400 EFPD 300 EFPD
17 DB-NE-06201 Revision 20
-0.0083
-0.0082
-0.0081
-0.0080
-0.0079
-0.0078
-0.0077
-0.0076
-0.0075
-0.0074
-0.0073
-0.0072
-0.0071
-0.0070 0
100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 Differential Boron Worth (% k/k)/ppmB RCS Boron Concentration (ppmB)
Cycle 22 Figure 5A: Differential Reactivity Worth of Soluble Boron "Critical" Reference Condition APSRs Out Figure 5A Page 2 of 2 APSRs Out 638 EFPD 679 EFPD 710 EFPD DATE: Mar 1, 2020 TIME: 07:55:13
18 DB-NE-06201 Revision 20
-0.0075
-0.0074
-0.0073
-0.0072
-0.0071
-0.0070
-0.0069
-0.0068
-0.0067
-0.0066
-0.0065
-0.0064
-0.0063
-0.0062
-0.0061
-0.0060
-0.0059
-0.0058
-0.0057
-0.0056 0
100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 Differential Boron Worth (% k/k)/ppmB RCS Boron Concentration (ppmB)
Cycle 22 Figure 5B: Differential Reactivity Worth of Soluble Boron "Power" Reference Condition APSRs In Figure 5B Page 1 of 2 APSRs In 0 EFPD 100 EFPD 500 EFPD 600 EFPD 400 EFPD 200 EFPD 658 EFPD DATE: Mar 1, 2020 TIME: 07:55:57 300 EFPD
19 DB-NE-06201 Revision 20
-0.0077
-0.0076
-0.0075
-0.0074
-0.0073
-0.0072
-0.0071
-0.0070
-0.0069
-0.0068
-0.0067 0
100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 Differential Boron Worth (% k/k)/ppmB RCS Boron Concentration (ppmB)
Cycle 22 Figure 5B: Differential Reactivity Worth of Soluble Boron "Power" Reference Condition APSRs Out Figure 5B Page 2 of 2 APSRs Out 638 EFPD 679 EFPD 710 EFPD DATE: Mar 1, 2020 TIME: 07:55:57
20 DB-NE-06201 Revision 20 1150 1200 1250 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 0
20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 RCS Boron Concentration (ppmB)
EFPD Cycle 22 Figure 6A: Minimum Boron Concentration to Assure 1% k/k Shutdown Margin NO Known Stuck/Dropped/Misaligned Rod Figure 6A Page 1 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:32:51 T < 300 oF 300 oF T < 500 oF
21 DB-NE-06201 Revision 20 450 500 550 600 650 700 750 800 850 900 950 1000 1050 1100 1150 1200 1250 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 RCS Boron Concentration (ppmB)
EFPD Cycle 22 Figure 6A: Minimum Boron Concentration to Assure 1% k/k Shutdown Margin NO Known Stuck/Dropped/Misaligned Rod Figure 6A Page 2 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:32:51 T < 300 oF 300 oF T < 500 oF After APSR Pull
22 DB-NE-06201 Revision 20 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 1850 0
20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 RCS Boron Concentration (ppmB)
EFPD Cycle 22 Figure 6B: Minimum Boron Concentration to Assure 1% k/k Shutdown Margin ONE Known Stuck/Dropped/Misaligned Rod Figure 6B Page 1 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:32:51 T < 300 oF 300 oF T < 500 oF
23 DB-NE-06201 Revision 20 500 600 700 800 900 1000 1100 1200 1300 1400 1500 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 RCS Boron Concentration (ppmB)
EFPD Cycle 22 Figure 6B: Minimum Boron Concentration to Assure 1% k/k Shutdown Margin ONE Known Stuck/Dropped/Misaligned Rod Figure 6B Page 2 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:32:51 T < 300 oF 300 oF T < 500 oF After APSR Pull
24 DB-NE-06201 Revision 20 1750 1800 1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 0
20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 RCS Boron Concentration (ppmB)
EFPD Cycle 22 Figure 6C: Minimum Boron Concentration to Assure 1% k/k Shutdown Margin MORE THAN ONE Known Stuck/Dropped/Misaligned Rod, T 560 °F Figure 6C Page 1 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:32:51
25 DB-NE-06201 Revision 20
900 1000 1100 1200 1300 1400 1500 1600 1700 1800 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 RCS Boron Concentration (ppmB)
EFPD Cycle 22 Figure 6C: Minimum Boron Concentration to Assure 1% k/k Shutdown Margin MORE THAN ONE Known Stuck/Dropped/Misaligned Rod, T 560 °F Figure 6C Page 2 of 2 400 EFPD DATE: Apr 28, 2020 TIME: 12:32:51 After APSR Pull
26 DB-NE-06201 Revision 20
10800 10850 10900 10950 11000 11050 11100 11150 11200 11250 11300 11350 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 RCS Water Volume (ft3)
Pressurizer Level (inches)
Cycle 22 Figure 7: RCS Water Volume vs. Pressurizer Level Figure 7 Page 1 of 2 210 inches DATE: Mar 1, 2020 TIME: 08:07:16
27 DB-NE-06201 Revision 20
11300 11350 11400 11450 11500 11550 11600 11650 11700 11750 11800 11850 11900 210 220 230 240 250 260 270 280 290 300 310 320 330 340 350 360 370 380 RCS Water Volume (ft3)
Pressurizer Level (inches)
Cycle 22 Figure 7: RCS Water Volume vs. Pressurizer Level Figure 7 Page 2 of 2 210 inches DATE: Mar 1, 2020 TIME: 08:07:16
28 DB-NE-06201 Revision 20
0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300
-3.5
-3.4
-3.3
-3.2
-3.1
-3.0
-2.9
-2.8
-2.7
-2.6
-2.5
-2.4
-2.3
-2.2
-2.1
-2.0
-1.9
-1.8
-1.7
-1.6
-1.5
-1.4
-1.3
-1.2
-1.1
-1.0
-0.9
-0.8
-0.7
-0.6
-0.5
-0.4
-0.3
-0.2
-0.1 0.0 0
10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300 Inserted Rod Worth (% k/k)
Cycle 22 Figure 8: Integral Control Rod Worth Groups 5 - 7 "Power" Reference Condition GRP 5 GRP 6 GRP 7 Rod Index APSRs In Figure 8 Page 1 of 4 GRPs 5-7 APSRs In 658 EFPD 0 EFPD 200 EFPD 400 EFPD DATE: Mar 1, 2020 TIME: 08:07:23
29 DB-NE-06201 Revision 20
0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300
-3.5
-3.4
-3.3
-3.2
-3.1
-3.0
-2.9
-2.8
-2.7
-2.6
-2.5
-2.4
-2.3
-2.2
-2.1
-2.0
-1.9
-1.8
-1.7
-1.6
-1.5
-1.4
-1.3
-1.2
-1.1
-1.0
-0.9
-0.8
-0.7
-0.6
-0.5
-0.4
-0.3
-0.2
-0.1 0.0 0
10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300 Inserted Rod Worth (% k/k)
Rod Index Cycle 22 Figure 8: Integral Control Rod Worth Groups 5 - 7 "Power" Reference Condition APSRs Out Figure 8 Page 2 of 4 GRPs 5-7 APSRs Out 710 EFPD 638 EFPD DATE: Mar 1, 2020 TIME: 08:07:23 GRP 5 GRP 6 GRP 7
30 DB-NE-06201 Revision 20
25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100
-0.80
-0.75
-0.70
-0.65
-0.60
-0.55
-0.50
-0.45
-0.40
-0.35
-0.30
-0.25
-0.20
-0.15
-0.10
-0.05 0.00 225 230 235 240 245 250 255 260 265 270 275 280 285 290 295 300 Inserted Rod Worth (% k/k)
Group 7 Position (% WD)
Cycle 22 Figure 8: Integral Control Rod Worth Group 7 "Power" Reference Condition Rod Index APSRs In Figure 8 Page 3 of 4 APSRs In 658 EFPD 0 EFPD 200 EFPD 400 EFPD DATE: Mar 1, 2020 TIME: 08:07:23
31 DB-NE-06201 Revision 20
25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100
-0.80
-0.75
-0.70
-0.65
-0.60
-0.55
-0.50
-0.45
-0.40
-0.35
-0.30
-0.25
-0.20
-0.15
-0.10
-0.05 0.00 225 230 235 240 245 250 255 260 265 270 275 280 285 290 295 300 Inserted Rod Worth (% k/k)
Group 7 Position (% WD)
Cycle 22 Figure 8: Integral Control Rod Worth Group 7 "Power" Reference Condition Rod Index APSRs Out Figure 8 Page 4 of 4 APSRs Out 710 EFPD 638 EFPD DATE: Mar 1, 2020 TIME: 08:07:23
32 DB-NE-06201 Revision 20
0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300
-3.0
-2.9
-2.8
-2.7
-2.6
-2.5
-2.4
-2.3
-2.2
-2.1
-2.0
-1.9
-1.8
-1.7
-1.6
-1.5
-1.4
-1.3
-1.2
-1.1
-1.0
-0.9
-0.8
-0.7
-0.6
-0.5
-0.4
-0.3
-0.2
-0.1 0.0 0
10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300 Inserted Rod Worth (% k/k)
Rod Index Cycle 22 Figure 9A: Integral Control Rod Worth Groups 5 - 7 "Critical" Reference Condition, NO Xenon APSRs In Figure 9A Page 1 of 4 GRPs 5-7 APSRs In 658 EFPD 0 EFPD 200 EFPD 400 EFPD DATE: Mar 1, 2020 TIME: 08:07:34 GRP 5 GRP 6 GRP 7
33 DB-NE-06201 Revision 20
0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300
-3.0
-2.9
-2.8
-2.7
-2.6
-2.5
-2.4
-2.3
-2.2
-2.1
-2.0
-1.9
-1.8
-1.7
-1.6
-1.5
-1.4
-1.3
-1.2
-1.1
-1.0
-0.9
-0.8
-0.7
-0.6
-0.5
-0.4
-0.3
-0.2
-0.1 0.0 0
10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300 Inserted Rod Worth (% k/k)
Rod Index Cycle 22 Figure 9A: Integral Control Rod Worth Groups 5 - 7 "Critical" Reference Condition, NO Xenon APSRs Out Figure 9A Page 2 of 4 GRPs 5-7 APSRs Out 710 EFPD 638 EFPD DATE: Mar 1, 2020 TIME: 08:07:34 GRP 5 GRP 6 GRP 7
34 DB-NE-06201 Revision 20
25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100
-0.80
-0.75
-0.70
-0.65
-0.60
-0.55
-0.50
-0.45
-0.40
-0.35
-0.30
-0.25
-0.20
-0.15
-0.10
-0.05 0.00 225 230 235 240 245 250 255 260 265 270 275 280 285 290 295 300 Inserted Rod Worth (% k/k)
Group 7 Position (% WD)
Cycle 22 Figure 9A: Integral Control Rod Worth Group 7 "Critical" Reference Condition, NO Xenon Rod Index APSRs In Figure 9A Page 3 of 4 APSRs In 658 EFPD 0 EFPD 200 EFPD 400 EFPD DATE: Mar 1, 2020 TIME: 08:07:34
35 DB-NE-06201 Revision 20
25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100
-0.80
-0.75
-0.70
-0.65
-0.60
-0.55
-0.50
-0.45
-0.40
-0.35
-0.30
-0.25
-0.20
-0.15
-0.10
-0.05 0.00 225 230 235 240 245 250 255 260 265 270 275 280 285 290 295 300 Inserted Rod Worth (% k/k)
Group 7 Position (% WD)
Cycle 22 Figure 9A: Integral Control Rod Worth Group 7 "Critical" Reference Condition, NO Xenon Rod Index APSRs Out Figure 9A Page 4 of 4 APSRs Out 710 EFPD 638 EFPD DATE: Mar 1, 2020 TIME: 08:07:34
36 DB-NE-06201 Revision 20
0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300
-3.2
-3.1
-3.0
-2.9
-2.8
-2.7
-2.6
-2.5
-2.4
-2.3
-2.2
-2.1
-2.0
-1.9
-1.8
-1.7
-1.6
-1.5
-1.4
-1.3
-1.2
-1.1
-1.0
-0.9
-0.8
-0.7
-0.6
-0.5
-0.4
-0.3
-0.2
-0.1 0.0 0
10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300 Inserted Rod Worth (% k/k)
Rod Index Cycle 22 Figure 9B: Integral Control Rod Worth Groups 5 - 7 "Critical" Reference Condition, PEAK Xenon APSRs In Figure 9B Page 1 of 4 GRPs 5-7 APSRs In 658 EFPD 0 EFPD 200 EFPD 400 EFPD DATE: Mar 1, 2020 TIME: 08:07:41 GRP 5 GRP 6 GRP 7
37 DB-NE-06201 Revision 20
0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300
-3.2
-3.1
-3.0
-2.9
-2.8
-2.7
-2.6
-2.5
-2.4
-2.3
-2.2
-2.1
-2.0
-1.9
-1.8
-1.7
-1.6
-1.5
-1.4
-1.3
-1.2
-1.1
-1.0
-0.9
-0.8
-0.7
-0.6
-0.5
-0.4
-0.3
-0.2
-0.1 0.0 0
10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220 230 240 250 260 270 280 290 300 Inserted Rod Worth (% k/k)
Rod Index Cycle 22 Figure 9B: Integral Control Rod Worth Groups 5 - 7 "Critical" Reference Condition, PEAK Xenon APSRs Out Figure 9B Page 2 of 4 GRPs 5-7 APSRs Out 710 EFPD 638 EFPD DATE: Mar 1, 2020 TIME: 08:07:41 GRP 5 GRP 6 GRP 7
38 DB-NE-06201 Revision 20
25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100
-0.85
-0.80
-0.75
-0.70
-0.65
-0.60
-0.55
-0.50
-0.45
-0.40
-0.35
-0.30
-0.25
-0.20
-0.15
-0.10
-0.05 0.00 225 230 235 240 245 250 255 260 265 270 275 280 285 290 295 300 Inserted Rod Worth (% k/k)
Group 7 Position (% WD)
Cycle 22 Figure 9B: Integral Control Rod Worth Group 7 "Critical" Reference Condition, PEAK Xenon Rod Index APSRs In Figure 9B Page 3 of 4 APSRs In 658 EFPD 0 EFPD 200 EFPD 400 EFPD DATE: Mar 1, 2020 TIME: 08:07:41
39 DB-NE-06201 Revision 20
25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100
-0.85
-0.80
-0.75
-0.70
-0.65
-0.60
-0.55
-0.50
-0.45
-0.40
-0.35
-0.30
-0.25
-0.20
-0.15
-0.10
-0.05 0.00 225 230 235 240 245 250 255 260 265 270 275 280 285 290 295 300 Inserted Rod Worth (% k/k)
Group 7 Position (% WD)
Cycle 22 Figure 9B: Integral Control Rod Worth Group 7 "Critical" Reference Condition, PEAK Xenon Rod Index APSRs Out Figure 9B Page 4 of 4 APSRs Out 710 EFPD 638 EFPD DATE: Mar 1, 2020 TIME: 08:07:41
40 DB-NE-06201 Revision 20
-5.40
-5.30
-5.20
-5.10
-5.00
-4.90
-4.80
-4.70
-4.60
-4.50
-4.40
-4.30
-4.20
-4.10
-4.00 0
20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 Reactivity Worth of Rods (% k/k)
EFPD Cycle 22 Figure 10: Adjusted Reactivity Worth of Control Rod Groups 1-7: R (for Shutdown Margin Calculations only)
"Critical" Reference Conditions NO Known Stuck/Dropped/Misaligned Rod ONE Known Stuck/Dropped/Misaligned Rod Figure 10 Page 1 of 2 400 EFPD DATE: Mar 1, 2020 TIME: 08:07:59
41 DB-NE-06201 Revision 20
-5.60
-5.50
-5.40
-5.30
-5.20
-5.10
-5.00
-4.90
-4.80
-4.70
-4.60
-4.50
-4.40
-4.30
-4.20 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 Reactivity Worth of Rods (% k/k)
EFPD Cycle 22 Figure 10: Adjusted Reactivity Worth of Control Rod Groups 1-7: R (for Shutdown Margin Calculations only)
"Critical" Reference Conditions ONE Known Stuck/Dropped/Misaligned Rod Figure 10 Page 2 of 2 400 EFPD DATE: Mar 1, 2020 TIME: 08:07:59 NO Known Stuck/Dropped/Misaligned Rod After APSR Pull After APSR Pull
42 DB-NE-06201 Revision 20
-0.19
-0.18
-0.17
-0.16
-0.15
-0.14
-0.13
-0.12
-0.11
-0.10
-0.09
-0.08
-0.07
-0.06
-0.05
-0.04
-0.03
-0.02
-0.01 0.00 0
5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 Inserted Rod Worth (% k/k)
Group 8 Position (% WD)
Cycle 22 Figure 11A: APSR Reactivity Worth - "Critical" Reference Condition Figure 11A DATE: Mar 1, 2020 TIME: 08:08:06 0 EFPD 658 EFPD
43 DB-NE-06201 Revision 20
-0.14
-0.13
-0.12
-0.11
-0.10
-0.09
-0.08
-0.07
-0.06
-0.05
-0.04
-0.03
-0.02
-0.01 0.00 0
5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 Inserted Rod Worth (% k/k)
Group 8 Position (% WD)
Cycle 22 Figure 11B: APSR Reactivity Worth - "Power" Reference Condition 658 EFPD Figure 11B DATE: Mar 1, 2020 TIME: 08:08:06 0 EFPD
44 DB-NE-06201 Revision 20
-0.030
-0.028
-0.026
-0.024
-0.022
-0.020
-0.018
-0.016
-0.014
-0.012
-0.010
-0.008
-0.006
-0.004
-0.002 0.000 0.002 0
100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 Temperature Coefficient (% k/k)/oF RCS Boron Concentration (ppmB)
Cycle 22 Figure 12: Temperature Coefficient Group 1 @ 100% WD, 2-7 @ 0% WD, 532oF 658 EFPD 0 EFPD APSRs In Figure 12 Page 1 of 2 APSRs In DATE: Mar 1, 2020 TIME: 08:08:18
45 DB-NE-06201 Revision 20
-0.030
-0.028
-0.026
-0.024
-0.022
-0.020
-0.018
-0.016
-0.014
-0.012
-0.010
-0.008
-0.006
-0.004
-0.002 0.000 0.002 0
100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 Temperature Coefficient (% k/k)/oF RCS Boron Concentration (ppmB)
Cycle 22 Figure 12: Temperature Coefficient Group 1 @ 100% WD, 2-7 @ 0% WD, 532oF APSRs Out Figure 12 Page 2 of 2 APSRs Out DATE: Mar 1, 2020 TIME: 08:08:18 638 EFPD 710 EFPD
46 DB-NE-06201 Revision 20
0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 1.2 1.3 1.4 1.5 1.6 1.7 1.8 1.9 2.0 2.1 2.2 2.3 2.4 2.5 2.6 2.7 2.8 2.9 3.0 0
5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 Power Deficit (% k/k)
Power Level (%FP)
Cycle 22 Figure 14: Power Reactivity Deficit APSRs In 658 EFPD 400 EFPD 200 EFPD 0 EFPD Figure 14 Page 1 of 2 APSRs In DATE: Mar 1, 2020 TIME: 10:59:26
47 DB-NE-06201 Revision 20
0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 1.2 1.3 1.4 1.5 1.6 1.7 1.8 1.9 2.0 2.1 2.2 2.3 2.4 2.5 2.6 2.7 2.8 2.9 3.0 0
5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 Power Deficit (% k/k)
Power Level (%FP)
Cycle 22 Figure 14: Power Reactivity Deficit APSRs Out 710 EFPD 638 EFPD Figure 14 Page 2 of 2 APSRs Out DATE: Mar 1, 2020 TIME: 10:59:26
48 DB-NE-06201 Revision 20
1200 1250 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 0
20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 RCS Boron Concentration (ppmB)
EFPD Cycle 22 Figure 15: Minimum Boron Concentration to Ensure 1% k/k Shutdown Value CRG 1 @ 100% WD, CRG 2-7 @ 0% WD, NO Xenon, No Stuck Rod Assumed T < 300 oF Figure 15 Page 1 of 2 400 EFPD 300 oF T < 500 oF DATE: Apr 28, 2020 TIME: 12:32:51
49 DB-NE-06201 Revision 20
450 500 550 600 650 700 750 800 850 900 950 1000 1050 1100 1150 1200 1250 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 RCS Boron Concentration (ppmB)
EFPD Cycle 22 Figure 15: Minimum Boron Concentration to Ensure 1% k/k Shutdown Value CRG 1 @ 100% WD, CRG 2-7 @ 0% WD, NO Xenon, No Stuck Rod Assumed T < 300 oF Figure 15 Page 2 of 2 400 EFPD 300 oF T < 500 oF DATE: Apr 28, 2020 TIME: 12:32:51 After APSR Pull
50 DB-NE-06201 Revision 20
0.00 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00 1.10 0
48 96 144 192 240 288 336 384 432 480 528 576 624 672 720 Transient Pu-239 Build-in Fraction, f Time after Shutdown (h)
Cycle 22 Figure 20A: Transient Plutonium-239 Build-in Fraction Figure 20A Page 1 of 1 DATE: Mar 2, 2020 TIME: 17:35:00
51 DB-NE-06201 Revision 20
0.000 0.010 0.020 0.030 0.040 0.050 0.060 0.070 0.080 0.090 0.100 0.110 0.120 0.130 0.140 0.150 0.160 0
5 10 15 20 25 30 35 40 45 50 Maximum Excess Pu-239 Worth, (Pu-max) (% k/k)
EFPD Cycle 22 Figure 20B: Maximum Excess Plutonium-239 Worth Figure 20B Page 1 of 2 50 EFPD DATE: Mar 2, 2020 TIME: 17:35:00
52 DB-NE-06201 Revision 20
0.130 0.140 0.150 0.160 50 80 110 140 170 200 230 260 290 320 350 380 410 440 470 500 530 560 590 620 650 680 710 Maximum Excess Pu-239 Worth, (Pu-max) (% k/k)
EFPD Cycle 22 Figure 20B: Maximum Excess Plutonium-239 Worth Figure 20B Page 2 of 2 50 EFPD DATE: Mar 2, 2020 TIME: 17:35:00
53 DB-NE-06201 Revision 20 Table 1 Cycle 22 - Miscellaneous Physics Data Description Value Units Flux Redistribution Penalty 0.350Note 1
% k/k Safety Rod Worth Group 1-4 (CRG 1-4 inserted)
Group 2-4 (CRG 1 withdrawn)
-3.0661
-2.3440
% k/k
% k/k Transient Poison Conversion Factor (TPCF) 86 ppmB
% k/k Note 1: A value of 0.0 %k/k may be used at 0 EFPD.
Davis-Besse DB1LOT21 NRC Exam Admin JPM A2
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A2 NUREG-1021, Revision 11 Page 1 of 5 Facility: Davis-Besse Task No:
005-012-04-0100 Task
Title:
Initiate a Short Term Configuration Change to isolate MU6 K/A
Reference:
2.2.14 (4.3) Job Performance Measure No: A2 (OPSJPM211)
Examinee:
NRC Examiner:
Date:
Method of testing:
Simulated Performance ___
Actual Performance _X_
Classroom _X_
Simulator ___
Plant ___
Read to the examinee:
I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this job performance measure will be satisfied.
Initial Conditions:
The plant conditions are specified in the Initial Conditions and Initiating Cues.
Task Standard:
Initiate a Short-Term Configuration Change to isolate MU6 Identify required isolation point Identify second SRO approval is required Required Materials:
NOP-OP-1014 Plant Status Control Ops Schematics, OS-002 SH 1 Standard log entry for NOP-OP-1014 Plant Status Control General
References:
DB-OP-06006 Makeup and Purification Procedure Initiating Cue:
The plant conditions are specified in the Initial Conditions and Initiating Cues.
Time Critical Task:
No Alternate Path:
No Validation Time:
21 minutes
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A2 NUREG-1021, Revision 11 Page 2 of 5 EXAMINER COPY INITIAL CONDITIONS:
The plant is at full power with all systems in normal alignment MU4 Letdown Block Orifice Isolation is open MU6 Letdown Flow Control valves positioner leads are making intermittent contact, causing RCS inventory control problems due to MU6 spurious repositioning The ATC Reactor Operator requests isolation of MU6 until the FIN Team corrects the problem with MU6 positioner leads The alignment should exist for less than one shift The FIN Team does NOT require Clearance Tags hung to repair MU6 positioner signal leads INITIATION CUE:
Initiate a Short Term Configuration Change to isolate MU6 and document required log entry below.
(Hand Candidate a copy of NOP-OP-1014 Plant Status Control and Ops Schematic OS-002 SH 1)
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A2 NUREG-1021, Revision 11 Page 3 of 5 CANDIDATE COPY INITIAL CONDITIONS:
The plant is at full power with all systems in normal alignment MU4 Letdown Block Orifice Isolation is open MU6 Letdown Flow Control valves positioner leads are making intermittent contact, causing RCS inventory control problems due to MU6 spurious repositioning The ATC Reactor Operator requests isolation of MU6 until the FIN Team corrects the problem with MU6 positioner leads The alignment should exist for less than one shift The FIN Team does NOT require Clearance Tags hung to repair MU6 positioner signal leads INITIATION CUE:
Initiate a Short Term Configuration Change to isolate MU6 and document required log entry below.
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A2 NUREG-1021, Revision 11 Page 4 of 5 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Specific sequence is NOT required.
START TIME: _________
- 1.
PERFORMANCE STEP: Determine isolation point for MU6
........C........
STANDARD: Determines MU85 and/or MU86 is required to be closed CUE: If asked, provide DB-OP-06006 Makeup and Purification Procedure SAT UNSAT
- 2.
PERFORMANCE STEP: Evaluate the effect of the Short Term Configuration Change from Normal Configuration on the following:
Personnel safety Technical Specification related equipment Unit load (Step 4.6.2)
STANDARD: Determines no effect on Personnel safety, Technical Specification related equipment, or Unit load NOTE: Technical Specification related equipment and Unit load effects would require additional log entries if applicable. Personnel safety issues would be discussed at the pre-job brief May request RP assistance to determine dose rate and RWP requirements CUE: If asked, the Field Supervisor will request RP support SAT UNSAT
- 3. PERFORMANCE STEP: Obtain a second SRO/Shift Managers concurrence
........C........
(Step 4.6.3)
STANDARD: Request for SRO/Shift Managers concurrence, makes Unit Log entry to document concurrence (Request for concurrence is not critical if it is documented in the log entry)
CUE: (As SM/SRO) I agree with the Short Term Configuration Change SAT UNSAT
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A2 NUREG-1021, Revision 11 Page 5 of 5
- 4.
PERFORMANCE STEP: Enter authorization into the Unit Log (Step 4.6.4)
STANDARD: 1. Obtain the Shift Managers approval to place the component(s) in a Non-Normal position
- 2. Enter the authorization (two SRO's) to position MU85 and/or MU86 to a Non-Normal position into the Unit Log, describing both the normal (OPEN) and as-left position (CLOSED), and the reason for the desired change in status NOTE: Candidate may also make log entries for positioning and restoration.
CUE: If asked, a copy of the Standard Log entry may be given to the candidate SAT UNSAT TERMINATING CUES: This JPM is complete (Terminated by the examinee)
END TIME
02/14/19
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1014
Title:
Plant Status Control Use Category:
General Skill Reference Revision:
07 Page:
2 of 47 TABLE OF CONTENTS Page 1.0 PURPOSE 4
2.0 SCOPE 4
3.0 DEFINITIONS 6
4.0 PROCEDURE DETAILS 7
4.1 Responsibilities 7
4.2 Methods for Maintaining and Documenting Plant Status Control 8
4.3 Interface with the Clearance & Tagging Program 9
4.4 Procedure Guidelines 10 4.5 Operations Evolution Orders 11 4.6 Short Term Configuration Change Process 12 4.7 General Controls for Operation of Positionable Components 15 4.8 Independent or Concurrent Verifications 16 4.9 Specific Guidelines for Non-Operations Personnel 17 4.9.1 Specific Guidelines for Instrumentation & Control (I&C)
Maintenance Personnel 18 4.9.2 Specific Guidelines for Personnel Performing Local Leak Rate Test (LLRT) and In Service Test (IST) Evolutions 18 4.10 Specific Guidelines for Specialized Components 19 4.10.3 Control of Lighting Panel Breakers 19 4.10.4 Control of Service Connections 20 4.11 Control Room Annunciators 20 4.11.1 Disabling Control Room Annunciators 20 4.11.2 Enabling Control Room Annunciators 21 4.12 Operations Information Tags 22 4.12.1 Operations Information Tagging Rules 22 4.12.2 Operations Information Tag Preparation and Placement 23 4.12.3 Operations Information Tag Removal 24
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1014
Title:
Plant Status Control Use Category:
General Skill Reference Revision:
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3 of 47 TABLE OF CONTENTS (Continued)
Page 4.12.4 Operations Information Tag System Reviews 25 4.13 Valve Operation, Position Check, and Position Verification 26 4.13.1 General 26 4.13.2 Manual Valves 27 4.13.3 Motor Operated Valves (MOV) 29 4.13.4 Pneumatically Operated Valves 34 4.14 Use of Valve Wrenches/Tools 35 4.15 Breaker Position Verification and Operation 38 4.16 Ventilation Damper Position 38 4.17 Locked Components 39 5.0 RECORDS 43
6.0 REFERENCES
43 7.0 SCOPE OF REVISION 45 ATTACHMENTS
- Examples of Positionable Components 46 - IAW What? Graphic 47
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1014
Title:
Plant Status Control Use Category:
General Skill Reference Revision:
07 Page:
4 of 47 1.0 PURPOSE This procedure provides a common process for capturing methods and requirements for maintaining status control of plant components. It provides direction and guidance for manipulation, verification, and checking position of components for the purposes of system operation to ensure that components are positioned to maintain personnel safety and operational configuration.
2.0 SCOPE 2.1 Applicability 2.1.1 This procedure applies to all personnel involved with activities affecting or controlling component configuration. It is the responsibility of all personnel involved in an activity that may affect the configuration of Positionable Components to follow the requirements of this procedure.
2.1.2 This procedure is applicable to all structures, systems, and components including office building equipment which are:
- a.
Safety-related, or
- b.
Part of the Augmented Quality (AQ) program, or
- c.
Fire Protection components which may adversely affect any portion of the Plant Fire Protection System, or
- d.
Any other structure, system, or component which may affect safe operation, safe shutdown, or are otherwise required to support power production.
2.2 Exceptions 2.2.1 This procedure is not applicable to an interim change to restore operability or to otherwise enhance the capability of degraded or nonconforming SSCs to maintain UFSAR-credited function/performance. Ensure the correct change process (e.g. NOP-CC-2003, Engineering Changes, NOP-SS-3001, Procedure Review and Approval) is utilized.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1014
Title:
Plant Status Control Use Category:
General Skill Reference Revision:
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5 of 47 2.2.2 The following are not covered by this procedure:
- Buildings and equipment outside of the protected area that do not provide direct power block support.
- Office Buildings, Warehouses, and Shops that are inside the protected area.
- Sewage Treatment Plant and Lift Stations
- Temporary Power installations downstream of station breakers
- Elevators (From disconnect to elevator)
- Fire systems outside the protected area. Note: manipulation of fire systems may cause automatic actuation of the fire pumps. The response of the pumps due to a valid low-pressure condition is not considered a plant status control event.
- (BV) SAPS Long Term Storage Facility
- (PY) MB 100 and Unit 2 Construction Power
- (PY) Unit 2 systems and components that are not required to support a Unit 1 function.
- Specifically included in plant status control is the equipment outside the protected area that provides direct power block support including the Alternate Intake (BV), cooling towers, circ water pumphouses, intake structures, radiation monitors, plant discharge, switchyard, met towers, fuel oil storage tanks, and chemical addition systems.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1014
Title:
Plant Status Control Use Category:
General Skill Reference Revision:
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6 of 47 3.0 DEFINITIONS 3.1 Check - To note a condition and compare with a requirement. Check does not allow the repositioning or the realignment of switches, valves, etc.
Checking a valve position does allow for minor movement in the closed direction without actually repositioning a valve.
3.2 IAW What? - Plant status control slogan that refers to the three ways we manipulate plant components, as depicted on Attachment 2:
- Procedures or Work Instructions
- Clearance Tagout
- Short-Term Configuration Control Process 3.3 Non-Normal - This refers to a configuration, condition, position, or situation where a component is not in a Normal Configuration.
3.4 Normal Configuration - The position that a Positionable Component is required to be in, as specified in Operations, Chemistry or other Station procedures, for a given mode of operation of that system. If a system has more than one normal mode of operation, then a component may have more than one normal position. For example, a purification demineralizer inlet valve may be opened if the demineralizer is in service or closed if the demineralizer is in standby. Both positions are normal.
3.5 Operations Evolution Order (OEO) - Written guidance to enhance coordination of existing procedures and processes for a specific task which is prepared by an SRO and receives technical review and approval. The OEO expires at the completion of the task.
3.6 Positionable Component - A component such as a valve, breaker, switch, damper, fuse, slide link, jumper, lifted leads (as directed by clearance/procedure), dial and modular components such as plug-in relays or fuse blocks or circuit cards with more than one selectable configuration or alignment. Components generally falling outside of the positionable component definition include pipe caps (except those forming a functional portion of containment or a system boundary), errors in wire landing as part of maintenance activities, positionable components installed backwards, or foreign material exclusion covers, shielding not properly installed, or doors ajar. This list is not meant to be all inclusive, but illustrates the intent.
This specific example needs to be provided here for positionable components. If a setpoint control device (computer input, potentiometer,
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1014
Title:
Plant Status Control Use Category:
General Skill Reference Revision:
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7 of 47 Human Interface Device, etc.) is improperly set and then placed in service, this would not be a Plant Status Control Event. If the wrong setpoint control device is manipulated or the setpoint control device is put in service before it is intended to be put in service (i.e., missed step in procedure or work order),
this would be a Plant Status Control Event.
3.7 Service Connections - Domestic Water, Demineralized Water, Nitrogen, Station Air and Instrument Air connection points normally used to support maintenance and testing activities. The connection points are normally configured with an isolation valve and a quick disconnect fitting for hooking up hoses.
3.8 System Prints - Those prints maintained in the Control Room that are updated to reflect in-field configuration of plant components for increased awareness of system operational status.
3.9 Verification - The process of positioning (or physically checking position), of a device, component, or system in the condition or position specified.
3.10 Verify - The act of substantiating and assuring that an activity or condition has been implemented in conformance with the specified requirements.
Verify allows the repositioning or the realignment of switches, valves, etc.
4.0 PROCEDURE DETAILS 4.1 Responsibilities 4.1.1 Responsible Section Manager:
Ensures all section personnel adhere to the requirements of this procedure.
4.1.2 Shift Manager:
Ensures proper configuration is maintained and ensures completion of plant status control event response requirements.
4.1.3 Supervisors
Ensure status of Positionable Component is controlled and tracked using approved methods.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1014
Title:
Plant Status Control Use Category:
General Skill Reference Revision:
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8 of 47 4.1.4 Individuals Positioning Components:
- 1.
Ensure proper use of event-free tools and verification practices.
- 2.
Ensure status of Positionable Components is controlled and tracked using approved methods.
4.2 Methods for Maintaining and Documenting Plant Status Control 4.2.1 There are several methods used to maintain and document component positions for Plant Status Control:
- a.
The Clearance Process
- b.
Approved Plant Procedures
- c.
Work Orders
- d.
Operations Evolution Orders (OEO). Refer to Section 4.5.
- e.
Short Term Configuration Change Process 4.2.2 Updating System Prints is another form of documenting component positions and is used in the following manner:
- a.
As an enhancement for Plant Status Control, a graded approach to updating System Prints shall be implemented to increase awareness of system operational status.
- b.
While on-line, a minimum of Safety Significant System Prints should be updated, to include both Mechanical and Electrical systems.
Additional systems required to be maintained shall be at the direction of the Operations Manager.
- c.
During outage periods, System Prints associated with Key Shutdown Safety Defense in Depth Systems should be maintained. Additional systems required to be maintained shall be at the direction of the Operations Manager.
- d.
System Prints utilizing plastic covered, controlled drawings shall be provided in the Control Room for operator use.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1014
Title:
Plant Status Control Use Category:
General Skill Reference Revision:
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9 of 47
- e.
All valves, including MOV's, SOV's, and AOV's, which are placed out of normal system configuration or used as a clearance boundary, shall be properly identified on the System Prints. This scope is limited by the requirements of on-line and outage controls discussed in this sub-step.
- f.
The Operations personnel performing the valving or switching operation shall maintain the System Prints up to date.
4.3 Interface with the Clearance & Tagging Program 4.3.1 Components positioned within a clearance boundary by any work group shall be annotated on the Configuration Control Log of the work document or added to the clearance as Restoration Tag points to ensure proper configuration following job completion. See NOP-WM-4300, Order Execute Process, for use of NOP-WM-4300-04, Configuration Control Log.
4.3.2 The integration of Clearance restoration and procedural guidance for restoring systems shall be carefully coordinated using two steps. These two steps should be separate and briefed as individual activities to avoid confusion between the two processes:
- 1.
Clearance step - When a procedure section exists for the applicable system, determine the components on the Clearance that are not captured within this procedural guidance. The Clearance restoration should align these components to their Normal Configuration. The remaining component positions should be aligned to a status compatible with expected plant conditions assumed by the procedure to be performed.
- 2.
Procedure step - After the Clearance restoration is complete, perform the appropriate procedure steps to place the system in service. This will properly configure the remaining components that were part of the Clearance.
- 3.
When positioning reach rod valves as energy isolation boundaries for a clearance, special controls shall be applied to ensure an adequate boundary is established. Determine the following:
- a.
If the valve is closed while normal system pressure is present, then normal closed validation techniques are adequate.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1014
Title:
Plant Status Control Use Category:
General Skill Reference Revision:
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10 of 47
- b.
If the valve is closed when normal system pressure is not present, then the valve may experience leakage when normal system pressure is applied. Effort should be made to prevent personnel from being exposed to possible dangers associated with unexpected leakage if system conditions change, using the following techniques to achieve safe working conditions:
Make the clearance an Exceptional Clearance so that workers understand that system changes could cause valve leakage at a boundary valve.
If unable to verify proper valve closure using system pressure, flow rates, tank level changes etc., then perform (where possible) a visual check of the actual valve position.
4.4 Procedure Guidelines 4.4.1 Operating procedures should provide instructions to place a system into service from an out of service condition to the Normal Configuration. This would include guidelines such as the following:
Initial lineup requirements for valves, instrumentation, and electrical power supplies Any requirements for filling and venting the system Required actions for placing systems in a standby condition Required actions for the startup of systems normally in-service 4.4.2 Check lists or line-ups should identify the required position of valves, breakers, and instruments that support the operation of the system.
- 1.
The check lists or line-ups should reflect either the required position to support system startup or the Normal Configuration.
- 2.
When check lists or line-ups identify the startup position of a component, the normal, configuration should be specified in the steps of the procedure or in the steps of another controlling procedure.
4.4.3 System operating procedures and testing procedures should provide guidance on restoring a system to a baseline Normal Configuration when multiple configuration options exist for the system under various conditions.
NUCLEAR OPERATING PROCEDURE Procedure Number:
NOP-OP-1014
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11 of 47 4.4.4 Procedures that are controlled by Non-Operations departments or sections should identify the component manipulations that are to be performed and shall adhere to verification standards, consistent with site-specific system requirements for verification.
4.4.5 Procedures that are controlled by Non-Operations departments or sections that contain component manipulations by both Operations personnel and Non-Operations personnel should specifically identify the component manipulations that are to be performed by Operations personnel.
4.4.6 Maintenance activities, including SAP orders and procedures, shall document changes to component positions, and shall also document returning components to the as-found position at the completion of the maintenance activity. In the event a procedure does not specify a restoration position i.e.
open, closed, on, off, or provide for restoration to the as found position, then the position shall be tracked in accordance with an approved method, such as a clearance (NOP-OP-1001) or short term configuration change process in accordance with section 4.6. CR-2015-04245 4.5 Operations Evolution Orders 4.5.1 Operations Evolution Orders (OEO) are used as an enhancement to coordinate activities using existing guidance, procedures, and processes (Form NOP-OP-1014-01). Examples of use include:
Supplementing the direction provided in NOP-LP-2601, Procedure Use and Adherence, for use of N/A.
Provide guidance & coordination necessary for establishing or restoring plant conditions related to maintenance work.
4.5.2 The OEO process provides interim written guidance, which receives a level of technical review and approval. IF the OEO was implemented to enhance procedural guidance, THEN the OEO should be reviewed for possible inclusion into procedural guidance.
4.5.3 IF an OEO is coordinating work activities by craft(s) other than operations, THEN the OEO shall be reviewed by the work group(s) to ensure the appropriate work document steps are included.
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12 of 47 4.5.4 The OEO shall be reviewed and approved by two SRO's. The review and approval shall include verification that the OEO leaves the equipment or system in the appropriate configuration.
4.5.5 If an OEO is used for a recurring system fill and vent or partial system fill and vent, consider putting the specific fill and vent activity into a procedure.
4.5.6 An OEO may NOT be used to change any approved procedure, step, or instruction that exists in an approved procedure. IF a condition is identified that would require a change to a procedure to perform the evolution, THEN initiate a procedure change per NOP-LP-2601, Procedure Use and Adherence, do NOT use an OEO.
4.5.7 IF independent verification of components is performed as part of the OEO, THEN document the requirement to perform IV when preparing the OEO.
4.5.8 Operations Evolution Orders shall expire at the completion of the assigned task or two weeks after the approval date, whichever comes first, then forwarded to Records Management.
4.5.9 The activities or sequence of actions under an OEO may not have been considered during schedule review for Risk per NOP-OP-1007. Review NOP-OP-1007 Risk Management for unidentified elevated Risk conditions imposed by the OEO.
NOTE If a component will not be restored to its Normal Configuration within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, then a Clearance is hung IAW NOP-OP-1001, Clearance/Tagging Program to provide a plant status control tracking method and documentation of the deviation from the components normal alignment.
4.6 Short Term Configuration Change Process 4.6.1 The Short Term Configuration Change Process may be used as determined by the Shift Manager.
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13 of 47 4.6.2 Evaluate the effect of the Short Term Configuration Change from Normal Configuration on the following:
Personnel safety Technical Specification related equipment Unit load 4.6.3 A second SRO shall evaluate the proposed change.
4.6.4 WHEN it is determined that a component will be placed in a Non-Normal position, THEN these guidelines shall be followed:
- 1.
Obtain the Shift Managers approval to place the component in a Non-Normal position.
- 2.
Enter the authorization (two SRO's) to position components to a Non-Normal position into the Unit Narrative Log, describing both the normal and as-left positions, and the reason for the desired change in status.
- 3.
Position the components as required.
- 4.
In the Unit Narrative Log, perform the following:
Annotate in the Unit Narrative Log. This Narrative Log entry should be selected as an Open Item in the Unit Narrative Log until restored, or a Clearance is hung.
o Identify the individual who positioned the component o
What position the component was left in o
The expected Normal Configuration position (some components have multiple Normal Configuration positions and an expected position for this type of component may need additional explanation in the narrative entry for clarity) o Why the component status change was needed o
Identify the Independent Verifier, if applicable.
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14 of 47 4.6.5 IF the component is restored to its Normal Configuration within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, THEN these guidelines shall be followed:
- 1.
Obtain the Shift Managers approval to place the component in the expected Normal Configuration position (some components have multiple Normal Configuration positions and an expected position for this type of component may need additional explanation in the narrative entry for clarity).
- 2.
Enter the authorization to position components to the Normal position into the Unit Narrative Log.
- 3.
Position the components as required.
- 4.
In the Unit Narrative Log, perform the following:
Annotate in the Unit Narrative Log. This Narrative Log entry should be de-selected as an Open Item in the Unit Narrative Log.
o Identify the individual who positioned the component o
What position it was left in o
Identify the Independent Verifier, if applicable.
4.6.6 IF the component will not be restored to its Normal Configuration within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, THEN these guidelines shall be followed:
- 1.
A clearance shall be hung using NOP-OP-1001, Clearance/Tagging Program, to provide a plant status control tracking method. This step is not meant to imply that only Caution Tags may be used, merely that the plant status of the component (s) will now be controlled by the Clearance/Tagging Program. The Clearance/Tagging Program shall determine the type of tags to be used for this clearance.
- 2.
There should be a decision-making process associated with the Clearance, such as Work Management (SAP Notification), Corrective Action Program, or Procedure change process that will determine a closure method for the Clearance.
- 3.
Annotate the clearance number that will track the component status in the Unit Narrative Log. This Narrative Log entry should be de-selected as an Open Item in the Unit Narrative Log.
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15 of 47 NOTE may be referred to for examples of Positionable Components.
4.7 General Controls for Operation of Positionable Components 4.7.1 Components with an Abandonment Active Boundary tag attached shall not be operated. Details are contained in NOP-CC-2008, Abandonment of Equipment.
4.7.2 Unlabeled equipment shall not be operated unless positively described in a method for maintaining and documenting Plant Status Control per Section 4.2 of this procedure.
4.7.3 If a Positionable Component label is indiscernible, then perform the necessary actions to affix a temporary (Information Tag, Caution Tag, Temp Mod tag, etc) or permanent label to the equipment before it is positioned.
4.7.4 The operation of movable skid mounted equipment is exempted from the controls established in this procedure. Examples of this type of equipment include steam cleaners, movable High Efficiency Particulate Filters, and Sandblasters. The controls established in this procedure shall be followed when connecting this equipment to plant components.
4.7.5 Whenever equipment will be operated, a brief shall be held clearly identifying any precautions and limitations and acknowledged by the personnel operating the equipment. Refer to Subsection 4.10 for specific work group guidance.
4.7.6 Components positioned within a clearance boundary by any work group shall be annotated on the Configuration Control Log of the work document or added to the clearance as Restoration Points to ensure proper plant status following job completion. See NOP-WM-4300, Order Execute Process, for use of NOP-WM-4300-04, Configuration Control Log.
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16 of 47 4.7.7 During an outage, Operations Management may relax the plant status control requirements associated with component status for systems that meet all of the following criteria:
The system is not required to be operable by Technical Specifications.
The system is not required to be functional to satisfy Shutdown Defense in Depth risk considerations.
The system is not required to be functional to satisfy Fire Protection considerations.
The system does not move, store, or process radioactive waste.
4.7.8 Prior to returning any system to service following a relaxation of plant status controls requirements, at a minimum, the system lineup shall be verified.
4.7.9 NOBP-OP-1014, Component Control Program, provides guidelines for development and implementation program to prevent inadvertent bumping or mispositioning of plant components through risk recognition, assessment, and implementation of appropriate defenses and mitigation strategies. The program provides additional methods to ensure that positive control of plant components is maintained.
4.8 Independent or Concurrent Verifications 4.8.1 The performance of Independent or Concurrent Verifications are described in NOBP-LP-2601, Human Performance Program.
4.8.2 In general Independent or Concurrent Verifications are required to be performed for the following: (site specific guidance may provide more direction)
- 1.
All valves, breakers and other components in safety related systems where improper positioning could adversely affect system operation.
- 2.
All valves, breakers, and other components in the fire protection system major flowpaths (including fire fighting water storage and supply, halon and carbon dioxide storage systems, fire detection systems and all components necessary for the system to function and supply the extinguishing media to the fire).
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- 3.
All valves, breakers, and other components in gaseous and liquid radioactive waste handling and processing systems where improper positioning could result in release of radioactive material directly to the environment.
- 4.
The performance of other procedures which set forth requirements for independent verification.
4.9 Specific Guidelines for Non-Operations Personnel
- 1.
When a peer check is required and other section personnel are not available to perform the peer check, then the Control Room should be requested to assist in performing the peer check (i.e., only one Chemistry technician on back shift, requests a peer check).
- 2.
Personnel may operate Positionable Components as specifically directed by a Work Order. Permission to operate these components is given by approval of the Work Order to commence work.
- 3.
Personnel may operate Positionable Components in accordance with approved procedures.
- 4.
Personnel may operate Positionable Components in accordance with NOP-OP-1001, Clearance/Tagging Program.
- 5.
Personnel may operate Positionable Components not specifically directed by a Work Order to support maintenance activities provided Shift Manager permission is obtained, and the positioning is documented on a Configuration Control Log, form NOP-WM-4300-04.
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18 of 47 4.9.1 Specific Guidelines for Instrumentation & Controls (I&C) Maintenance Personnel
- 1.
I&C personnel are normally responsible for operating valves associated with instrumentation and actuators. This includes the following as applicable for a particular instrument or actuator:
For configurations with manifolds, I&C is normally responsible for operating the first isolation valve prior to an instrument manifold unless this valve is the source or root valve.
For configurations without manifolds, I&C is normally responsible for operating the first isolation valve prior to the instrument/actuator unless this valve is the source/root valve.
Manifold valves Blowdown/drain valves Vent valves Equalization valves
- 2.
Source/root valves and other instrument line isolation valves up to the first isolation valve prior to an instrument/actuator or a manifold shall be operated by Operations personnel.
- 3.
Instrument Air System valves located in flexible tubing should normally be operated by I&C personnel. Instrument Air System valves that are hard-piped should normally be operated by Operations personnel.
4.9.2 Specific Guidelines for Personnel Performing Local Leak Rate Test (LLRT) and In-Service Test (IST) Evolutions
- 1.
The Shift Manager may grant permission to personnel from other departments to operate plant components during LLRT and IST tests/evolutions.
- 2.
Operators shall be utilized to position components to establish/restore the test evolution boundary.
- 3.
Non-operations personnel may be used to perform component verifications of the test/evolution lineup. This allows non-operations personnel to perform Independent Verifications of both the system lineup for the test/evolution boundary and the restoration lineup from the test/evolution.
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- 4.
Non-operations personnel may perform any filling/draining or positioning of components within the test/evolution boundary to perform the test/evolution.
- 5.
Non-operations personnel may perform the test/evolution; i.e. use of vent rigs, test equipment, etc. within the test/evolution boundary to perform the test/evolution.
- 6.
As with any Operations test/evolution, a pre-job brief is conducted with the test/evolution participants. The brief should discuss any precautions and limitations associated with operation of the components and roles of the personnel for the test/evolution.
4.10 Specific Guidelines for Specialized Components 4.10.1 Slide Links/Knife Switches are normally maintained in the closed position, unless otherwise controlled. For instance, the normal position of some Slide Links/Knife Switches for test circuits may be open.
4.10.2 Fuses are normally maintained in the inserted position. When fuses are inserted they should be orientated so that the fuse label can be read.
NOTE Lighting Panel Breakers may be supplying equipment important to plant operations such as fire detection equipment.
4.10.3 Control of Lighting Panel Breakers
- 1.
Lighting Panel Breakers within the Protected Area should normally be operated by Operations Unit personnel.
- 2.
Electrical Maintenance can be consulted and drawings referenced prior to resetting a tripped Lighting Panel Breaker to determine what loads are affected.
- 3.
Nuclear Security personnel may operate lighting panels breakers that only supply power to equipment normally operated by the Nuclear Security Organization. For example, the Auto/Manual switch that controls the photocells for outside lighting may be operated by Nuclear Security.
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- 4.
Chemistry personnel may operate lighting panel breakers that only supply power to equipment normally operated by the Chemistry Organization.
- 5.
Radiation Protection personnel may operate lighting panel breakers that only supply power to equipment normal operated by the Radiation Protection Organization.
- 6.
Other lighting panel breakers that only supply general area lighting loads or electrical outlets in office or shop areas may be operated by personnel who normally occupy that area.
- 7.
Other lighting panel breakers within the Protected Area may be operated by station personnel provided permission is obtained from the Shift Manager.
4.10.4 Control of Service Connections
- 1.
Service connection supply and source valves may be operated as needed when the process is continually attended and directly controlled by station personnel. Notify the Shift Manager or other on-shift SRO prior to using the service connection at the beginning of the job, and after the service connection has been secured at end of job.
- 2.
Unattended open service connection supply and source valves shall either have an information tag attached with contact name and work group, or use another approved configuration control process.
- 3.
Mis-operation of a service connection valve does not constitute a plant status control event, unless the mis-operation is consequential to the plant or consequential to personnel safety.
4.11 Control Room Annunciators 4.11.1 Disabling Control Room Annunciators
- 1.
The Shift Manager has determined that an Annunciator alarm should be disabled.
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- 2.
Disable the Annunciator IAW the following:
Davis Besse - refer to DB-OP-06411, Station Annunciator Operating Procedure Perry - refer to NOP-CC-2003 Engineering Changes and PYRM-ERS-5003 Equipment Important To Emergency Response Beaver Valley - refer to appropriate Operations Manual to identify correct knife switch
- 3.
Consider increased monitoring of the parameter whose alarm function is disabled. Additional required actions should be documented in the Unit Narrative Log, with a revision to the applicable Operator Round logs, if deemed necessary.
- 4.
Ensure a Notification is written for the condition that required the Annunciator alarm to be disabled, and post the Maintenance Deficiency sticker on the alarm window.
- 5.
Create and hang an Operations Information Tag/Label (this procedure) or Caution Tag (NOP-OP-1001 Clearance/Tagging Program) on the annunciator window and on the opened slide link/knife switch/removed card stating what alarm was removed from service.
4.11.2 Enabling Control Room Annunciators
- 1.
The Shift Manager has determined that a previously disabled Annunciator alarm should be enabled.
- 2.
Enable the Annunciator IAW the following:
Davis Besse - refer to DB-OP-06411, Station Annunciator Operating Procedure Perry - refer to NOP-CC-2003 Engineering Changes Beaver Valley - refer to appropriate Operations Manual to identify correct knife switch
- 3.
Once the actions above have been completed, performing an alarm test to ensure the annunciator will light and if practical test the circuit to ensure the alarm actuates appropriately.
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- 4.
Discontinue any increased monitoring of the plant parameters for the alarm function that was enabled. Cancellation of additional required actions should be documented in the Unit Narrative Log, with a revision to the applicable Operator Round logs, if deemed necessary.
- 5.
Remove the Operations Information Tag/Label (this procedure) or Caution Tag (NOP-OP-1001 Clearance/Tagging Program) from the annunciator window and the opened slide link/knife switch/removed card that was removed from service.
4.12 Operations Information Tags Information tagging provides a method of transmitting additional information or provides guidance of a temporary nature. This section applies to both Operations Information Tags and Operations Information Labels.
4.12.1 Operations Information Tagging Rules
- 1.
Information tags shall not be used in lieu of programmatic controls such as Red Danger Tags, Caution Tags, Maintenance Deficiency Tags, etc.
- 2.
Information tags should not be used to provide long-standing operating instructions or information that more appropriately belongs in an instruction or on a permanent label. Information of this type should be incorporated into procedures or posted on permanent labels.
- 3.
Operations Information Tags may be used to inform operators of possible consequences of operation of controls or equipment that need repair, but which may be operated if additional precautions are observed.
- 4.
Operations Information Labels should be used in place of Operations Information Tags on panel external controls and indications in areas such as the Main Control Room, or Radwaste Control Room if application of a tag would cover up other instruments or controls.
- 5.
Operations Information Tags/Labels should be used for equipment labels while permanent labels are being manufactured.
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- 6.
The Operations Information Tags and Labels shall be maintained in a computer program (currently the eSOMS Clearance Module) but are NOT to be used as safety tags.
4.12.2 Operations Information Tag Preparation and Placement:
- 1.
List the components or system affected.
- 2.
Describe reason for component being tagged.
- 3.
List any placement instructions, cautions, or guidance which will assist in removal.
- 4.
Operations Information Tags/Labels placed on Control Room components that are also operated from a remote panel shall be evaluated for the need to post them at the remote panel.
NOTE Initiation of a closure mechanism should occur at the time of initiating the Information Tag.
- 5.
The Operations Information Tag initiator shall identify the associated document (Work Order, Notification, or CR) that required hanging the Operations Information Tag unless N/Ad by the Tag reviewer. The Information Tag Number should also be referenced as an associated document for the closure document.
- 6.
An on-shift SRO or designee shall review the Operations Information Tags for completeness and accuracy and approve for placement.
NOTE Operations Information Tags do NOT specify position. Therefore, the verification of specified position and signing for placement are NOT required.
- 7.
Assign an operator or a person designated by the on-shift SRO to place the Operations Information tags as follows:
- a.
Confirm that the proper component is selected by comparing the information placed on the Operations Information Tags, the tag sheet and in-plant label. Abbreviated terms need not match exactly.
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- b.
Place the Operations Information Tags on the component in a secure manner and in a visible location such that other components are not obscured by tag placement. For Control Room Hand Indicating Switches (HIS), a plastic shroud may be used for tag placement.
- c.
Sign the paperwork for Placement 1st Verification.
- d.
Notify the on-shift SRO or designee when completed.
- 8.
An on-shift SRO or designee shall update the Operations Information Tag information in the computer program.
4.12.3 Operations Information Tag Removal
- 1.
Any person knowledgeable in the background information that led to the placement of the Information tag(s) may request approval from the Unit Supervisor or his designee for removal. Also, the Unit Supervisor or his designee may make a determination that the tags are no longer applicable and initiate action to cause their removal.
- 2.
An on-shift SRO or designee shall approve the removal of Operations Information Tags in the computer program.
NOTE Operations Information Tags do NOT specify position. Therefore, the verification of specified position and signing for removal are NOT required.
- 3.
Assign an operator or a person designated by the on-shift SRO to remove the Operations Information tags as follows:
- a.
Confirm that the proper component is selected by comparing the Operations Information Tags, the removal sheet and in-plant label. Abbreviated terms need not match exactly.
- b.
Remove the Operations Information Tags from the component.
- c.
Sign the paperwork for Removal 1st Verification.
- d.
Notify the on-shift SRO or designee when completed.
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- 4.
An on-shift SRO or designee shall close the Operations Information Tag in the computer program.
4.12.4 Operations Information Tag System Reviews
- 1.
The Operations Manager is responsible for ensuring that a semi-annual administrative review of the Operations Information Tags is performed. This review shall consist of the following:
- a.
For tags that are still required:
- 1)
An inventory of the active Operations Information Tags in SOMS, against the associated tags and labels to ensure that all tags and labels are in place.
- 2)
An inspection to ensure proper attachment of the tags and labels.
- 3)
An inspection to verify physical condition of the tags and labels is such that the information is legible.
- b.
For tags and labels that are no longer applicable, the initiation of a request to clear the tags.
- c.
Missing or illegible tags shall be replaced.
- e.
An Operations Work Control SRO shall review the completed administrative review to ensure that the listed closure documents are appropriately prioritized.
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26 of 47 4.13 Valve Operation, Position Check, and Position Verification CAUTION
- Excessive torque on valves may cause damage to valve internals. Valves requiring an excessive amount of torque to operate shall be documented in accordance with NOP-LP-2001, Corrective Action Program.
- Excessive force on valves can damage seats, stems, and gears. Valve wrenches shall only be used in accordance with this procedure.
- Weir and diaphragm type valves can be damaged by excessive force on the diaphragm. Extreme care is required when checking these valves shut.
- If a valve is backseated while it is cold and then subsequently heated to a higher temperature, thermal expansion of the metal may cause damage to the valve.
NOTE Site specific direction may provide more detailed guidance for each of the following components.
4.13.1 General NOTE Hydraulic pressure locking or vacuum locking may occur in isolated piping.
Excessive force may lead to diaphragm failure.
- 1.
IF an operator feels excessive resistance while operating a diaphragm valve, THEN depressurize/relieve vacuum in the line by cycling a boundary valve or a vent/drain valve.
- 2.
Throughout this section, a seated valve refers to the closed seat and a back seated valve refers to an open seat unless otherwise noted.
- 3.
Inaccessible valves should be pre-identified on valve verification lists, line-ups, clearances, etc with an alternate method of verification listed.
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- 4.
IF a valve is NOT pre-identified and is determined to be inaccessible (Shift Manager makes this determination), THEN the following should be conducted:
- a.
Identify the inaccessible valve, provide an explanation as to why the valve is inaccessible, and provide an alternate means of verification that the Shift Manager determines will provide assurance of valve position.
- b.
The Shift Manager shall initial the explanation showing his concurrence. Examples of alternate methods are as follows:
Vent is inaccessible, a visual check can be made that the pipe cap is in place and no leakage is present.
Process valve is inaccessible; valve may be verified by ensuring that the affected process variable is being maintained at the proper value or within the proper range.
- c.
The use of alternate methods of valve position verification should be limited to as little as possible.
NOTE Temporary conditions such as scaffolding blocking access to a valve or a radiation hot spot would not require a document change request.
- d.
IF the condition making the valve inaccessible is permanent, THEN initiate a Document Change Request to update the procedure.
4.13.2 Manual Valves
- 1.
Verifying a valve in the proper position would consist of first checking the current position and then repositioning the valve to the desired position if needed. Other methods to confirm desired position should be used when available such as:
Remote valve position indicator Stem position Local valve position indication Process variables (i.e. system pressure, flow rates, tank level changes etc.)
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- 2.
To check or verify a manual valve or stop check valve open, turn the handwheel in the close direction 1/4 - 1/2 turn. Then turn the handwheel in the open direction to the full open position as verified by position indication and firm tightness. Back off 1/8 turn of the handwheel if the valve is not to be back seated.
- 3.
To verify a manual valve or stop check valve closed, turn the handwheel in the close direction until the valve is closed as verified by position indication and firm tightness.
NOTE Valve movement cannot normally be determined by the feel of the reach-rod operator.
- 4.
When checking the position of valves which are normally operated via a remote valve operating linkage, additional means of verifying proper valve position shall be performed, such as the following:
When opening or closing a reach-rod operated valve, verify that the expected results are obtained (i.e. system pressure, flow rates, tank level changes etc.).
Verify the indicator pin is not hard against the indicating plate.
When closing or opening a reach-rod operated valve, verify the indicator pin is aligned with the closed or open indication.
If any discrepancies are noted, then perform (where possible) a visual check of the actual valve position and write a Nuclear Maintenance Notification if required for the discrepancy.
Operation of valves with remote valve operating linkage should not occur at the valve. If the valve must be manipulated, the remote operator shall be inspected for Clearance or Information Tags.
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- 5.
To check a valve throttled with a system in service, observe that the process parameter and system operation is normal, indicating the valve is at its proper position. IF the system is NOT in service, THEN check or verify the throttled position using procedural guidance such as a system operating procedure, a valve lineup, or a clearance as appropriate.
- 6.
When it is necessary to place a valve on its back seat, then:
- a.
Obtain authorization from the Shift Manager to place the valve on the back seat.
- b.
Back seat the valve hand tight, without the use of a valve wrench.
- c.
Place a Clearance on the valve stating that the valve is back seated and to use caution in moving the valve off of the back seat.
4.13.3 Motor Operated Valves (MOV)
- 1.
Valve position of motor operated valves should be checked or verified using a combination of methods, such as:
Remote valve position indication Stem position Local valve position indication Process variables Mechanical Position Indicator
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30 of 47 CAUTION It is possible to over tighten small MOVs (4 and smaller) using the manual handwheel. Exercise extreme caution when seating small MOVs.
Use of a calibrated torque wrench may be required to ensure proper valve operation.
- 2.
Engineering should be contacted prior to manually seating (open or closed) any MOV. Prior to manually seating gate or globe MOV handwheels, the operator size must be confirmed and the appropriate torque value selected. The System Engineer should provide the nominal seating torque value for all the subject valves in an order or other appropriate document.
- 3.
Manual seating (open or closed) of MOVs to torque values greater than that identified in normal documentation (procedures, tests, databases) may be required to stop system leakage. This should be accomplished by seating the MOV in increments up to the manufacturers recommended maximum stem torque. When such action is taken, the method and torque value shall be approved by the Shift Manager and documented in an order or other appropriate document.
- 4.
Valve wrenches/extension devices shall not be used to seat MOVs.
- 5.
Motor Operated Valves shall be back seated manually only by the use of the handwheel with minimum applied force to prevent exceeding the compensating spring pack deflection.
- 6.
When manually seating (open or closed) a motor operated valve, implement the following controls:
Place Operational Information Tags or Caution Tags on the valve and any associated control switches stating "This valve has been manually (open or closed) seated. Remove valve from its seat manually prior to stroking the MOV."
Valves which have been manually back-seated (open) shall be returned to normal operation by manually removing the valve from its seat and electrically stroking the MOV through one complete open and close cycle when plant conditions permit.
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31 of 47 Motor operated gate valves that have been manually seated (closed) should be manually unseated prior to motor operation and electrically stroked through one complete open and close cycle when plant conditions permit.
Motor operated globe and butterfly valves that have been manually seated (closed) do not require manual unseating but should be electrically stroked through one complete open and close cycle when plant conditions permit.
- 7.
Safety related MOVs that have been manually seated or backseated shall be declared inoperable until one of the following conditions have been met. A Condition Report and Unit Log entry should document the inoperable status.
An evaluation shall be performed (documented in a Condition Report, EER, or other appropriate means) to determine limiting torque values, methods of valve operation, and any other necessary steps to be followed in order to maintain or re-establish valve operability.
IF the preceding evaluation is not performed, THEN the valve shall remain inoperable until remote motor operation can be verified by satisfactory performance of the applicable Surveillance or other appropriate means of retest.
- 8.
After manually seating any MOV, notify System Engineering to trend valve use and performance.
- 9.
Electrical back seating of Motor Operated Valves is not a common practice, but may be performed under the following controls:
- a.
A motor operated valve is electrically back seated when the OPEN limit switches have been bypassed and the valve OPEN circuit has been energized. Normal valve operations with the torque and limit switches functional do not constitute electrical back seating evolutions.
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- b.
An evaluation shall be obtained from Engineering (documented in an SAP Order, EER, or other appropriate means) prior to electrically back seating a motor operated valve. This evaluation shall be the basis for the generation of a Work Order to perform the back seating evolution.
- c.
Identify retest requirements within the above Work Order, to verify that the valve is capable of performing in accordance with design requirements when it is returned to service.
- d.
An Operations Information Tag or Caution Tag shall be attached to the control switch, stating that the valve has been electrically back seated.
- e.
Safety related MOVs that have been electrically back seated shall be declared inoperable and remain inoperable until all required retests are completed.
CAUTION Do NOT declutch the manual actuator on MOV's unless directed by Shift Manager.
When declutching and engaging the manual actuator on motor operated valves, be aware that excessive force may result in damage to the valve and actuator.
- 10.
Declutch and manually check or verify the position of motor operated valves only if the valve is suspected of NOT being fully open or closed, there is no other method available to verify position, and Shift Manager has directed this verification.
- a.
To verify a motor operated valve open, engage the manual actuator and apply force (hand force only) in the close direction.
When motion in the close direction is obtained, re-open the valve.
Do NOT manually backseat the valve when re-opening the valve.
- b.
To verify a motor operated valve closed, engage the manual actuator and apply force (hand force only) in the close direction.
Motion in the close direction should NOT occur.
- 11.
Safety related valves which have been declutched shall be declared inoperable until tested for operability.
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33 of 47 CAUTION Manually declutching SB, SBD and SMB-000 and 00 MOV operators that are electrically closed should be avoided. Manual declutching could cause damage to the operators hypoid gear.
- 12.
Implement the following for Limitorque type SMB-00 & -000 valves:
Limitorque type SMB-00 & -000 valves that have been declutched (actuator placed in manual), shall not be used as isolation for personnel protection unless an Engineering evaluation has determined that the valve will remain closed and be capable of performing its isolation function.
Limitorque type SMB-00 & -000 valves that have been declutched (actuator placed in manual), shall be as a minimum partially stroked electrically to return the valve to service.
Limitorque type SMB-00 & -000 valves that have been declutched (actuator placed in manual) while the valve is on the closed seat shall be returned to normal operation by electrically stroking the valve one complete cycle (close to open and open to close). SMB-00 & -000 type actuators in this condition shall be identified with a Caution Tag. Plant Engineering shall be notified when this condition occurs.
NOTE The open/closed position indication occurs when the disc makes hard contact with the valve seat. The motor is de-energized by the shaft torque switch and coasts into the position that ensures proper tightness.
- 13.
WHEN stroking a motor operated throttle valve to the full open or closed position, THEN continue holding the open/closed pushbutton for 3 to 5 seconds (nominal) after the opposite position indicating light goes out.
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34 of 47 4.13.4 Pneumatically Operated Valves
- 1.
Valve position of pneumatically operated valves should be checked or verified using a combination of methods, such as:
Remote valve position indication Stem position Local valve position indication Process variables CAUTION Do NOT engage the manual actuator on pneumatic valves unless directed by Shift Management AND the manual actuator is capable of placing the valve in the desired position. If calibration of the valve, positioner, or actuator could be invalidated or if damage to the valve, positioner or actuator could occur as a result of manual positioning, physical verification using the manual actuator shall NOT be performed. Consult Plant Engineering if it is necessary to manually verify AOV's.
- 2.
Manually verify the position of pneumatically operated valves only if there is no other method available to verify position and Shift Manager has directed this verification.
- a.
To manually check or verify a pneumatically operated valve open, engage the manual actuator and apply force (hand force only) in the close direction. When motion in the close direction is obtained, re-open the valve.
- b.
To manually check or verify a pneumatically operated valve closed, engage the manual actuator and apply force (hand force only) in the close direction. Motion in the close direction should NOT occur.
IF motion in the close direction does occur, THEN contact the Control Room SRO for guidance.
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- 3.
When verifying a pneumatic valve as "In Service" the following items should be assessed if applicable:
No safety tags are hung removing the component from service Instrument Air is available and NOT isolated.
No Material Deficiency Tags exist that indicate that the component cannot function.
Local status indicators and controllers appear normal.
Hand jack will NOT interfere with valve operation.
4.14 Use of Valve Wrenches/Tools CAUTION Valve wrenches are used to apply additional mechanical leverage to a valve that is difficult to operate. This additional leverage has the potential to damage a valve or actuator; therefore, valve wrench use should be avoided if possible and evaluated if use is necessary. The following may be reasons why a valve may be difficult to operate:
o A differential pressure across the seat may impede operation.
o The packing in the valve may be too tight.
o The valve may be damaged and require repair.
o The valve may be pressure locked or thermally bound.
o The physical location or placement of the valve may make operation difficult.
o The design of the valve may be inappropriate for the application.
o Valve handwheel has been removed per an as-built condition.
Manual valves have been designed for the specific use in the plant, and the use of a valve wrench should NOT normally be necessary.
T-handle valve operator extensions typically do not provide added leverage that will damage a valve, however evaluation may be necessary.
4.14.1 Considerations
- 1.
Consider the following prior to using a valve wrench or tool:
- a.
Could there be something wrong with the valve making it difficult to operate?
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- b.
If a valve that is NOT normally difficult to operate requires the use of a valve wrench, then could the valve be lubricated?
- c.
What are the consequences of breaking the valve?
- d.
Is the valve isolable from the system?
- e.
Can the valve be repaired during normal plant operations?
- f.
Will damaging the valve result in a system or component inoperability, Tech Spec Action, or an impairment?
- g.
Would valve or handle construction materials be prone to failure at less force than others (brass, aluminum, cast iron, steel)?
- h.
Could environmental conditions make the valve or handle more likely to fail (corrosive conditions, extreme temperatures)
- 2.
Use of a valve wrench to prevent potential muscle strain or injury may be necessary when valve location does NOT allow easy access.
Caution should be used to prevent putting excessive force on the valve components.
4.14.2 Restrictions
- 1.
Valve wrenches should NOT be used to manually operate the following type valves. The actuator provides sufficient mechanical leverage, and a valve wrench should NOT be necessary. A Nuclear Maintenance Notification should be submitted if this type of valve is difficult to manually operate.
Motor Operated Valves (MOV)
Air Operated Valves (AOV)
Diaphragm Valves Butterfly Valves
- 2.
Valve wrenches should NOT be used to manually operate a reach rod valve. If a reach rod operated valve is difficult to operate, Mechanical Maintenance should be notified and allowed to observe the problem.
A Nuclear Maintenance Notification should be submitted, if necessary.
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37 of 47 4.14.3 Allowances
- 1.
Use of electric or pneumatic portable motors to assist in valve operation is allowed with an Operations Supervisor approval.
Electric or pneumatic portable motors are NOT to be used to seat/unseat valves.
When using electric or pneumatic portable motors on a manually operated valve, the valve stem position should be known at all times by direct visual observation.
The electric or pneumatic portable motors must be removed before the valve approaches the full open or closed positions to prevent possible injury or equipment damage.
To avoid operator injury, the electric or pneumatic portable motors shall have a clutch.
- 2.
Manual valves may have an Engineering evaluation performed to allow routine use of a valve wrench/tool. The evaluations shall be documented in an EER or other suitable process, and the allowed controls (specific valve or type of valve, type of tool, torque values, etc) may be used in procedures, permanent labels, or Information Tags to identify the allowance for routine use.
4.14.4 Actions
- 1.
If it is determined that a valve wrench or tool is necessary, then the following shall be performed:
- a.
If it is desired to use a valve wrench/tool on a manual valve with a geared actuator (torque converting mechanism), then an Engineering evaluation shall be performed prior to using the valve wrench/tool. The evaluation shall be in an EER or other suitable process, and document the allowable torque value, controls required, the circumstances leading to the use, and the effects of the use.
- b.
The size or length of a valve wrench or tool should not exceed two times the diameter of the installed handle or handwheel.
- c.
Shift Manager concurrence shall be obtained prior to use.
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- d.
The user shall inform the Shift Manager of the results of the use of a valve wrench or tool as soon as practical after its use.
- e.
Engineering shall be notified when valve wrenches are required, if they have not been previously notified for each specific valve.
This notification is to facilitate trending.
4.15 Breaker Position Verification and Operation
- 1.
The positions of High Voltage breakers are verified to be in the correct position through use of the remote or local indicating lights. In the absence of these indications or as a redundant check, mechanical position indication may be used to determine the breaker position.
- 2.
When verifying molded case circuit breakers open, such as on 480 VAC MCC's, the position of the operating handle shall be verified to ensure the breaker is actually open.
- a.
IF the breaker cannot be verified in the open position, or doubt exists, THEN request assistance from Electrical Maintenance in ensuring the breaker is open. The cubicle door should be opened if necessary to check the breaker itself to ensure the breaker is open.
- 3.
This guidance is not meant to be all inclusive and should be used in conjunction with standard zero energy checks.
4.16 Ventilation Damper Position
- 1.
Ventilation dampers may be operated from either side of the damper and the handle does not always line up with damper position. The conventional method of clockwise to close does not always apply.
When provided, a slot in the end matches up with actual damper position. Other methods of verifying position such as flow or a visual examination may be necessary to positively identify damper position.
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39 of 47 4.17 Locked Components NOTES
- This section applies to components in the site specific locked component programs and to locked Fire Protection valves.
- Site specific locked component program information may be found in:
o (BV) 1/2 OM-48.3.C, Padlocks/Locking Devices Administrative Requirement o (DB) DB-OP-00008, Operation and Control of Locked Valves o (PY) OAI-0201, Operations General Instructions and Operating Practices OAI-0503, Preparation Of Operations Section Lineup Instructions
- Locked components may be checked or verified using either a hands on (physical) approach or checked by virtue of the fact that the component is locked and there is an additional cue that the component is in the desired position, such as:
o Remote position indicator o
Valve stem position o
Local position indication o
Process variables (i.e. system pressure, flow rates, tank level changes, component running, etc.)
o Color-coded locks or locking tabs (Red = Open, Green = Closed, Tan or Yellow = Throttled).
- Locked components shall not be locked in their Non-Normal position except for when a clearance is used (Tags Plus).
- Unlocking a valve that is locked in a throttled position may cause unexpected changes to system parameters.
- 1.
To physically reposition a Locked component to a Non-Normal position, perform the following steps.
- a.
Obtain permission from the Shift Manager to physically reposition a Locked component.
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- b.
Determine the method of maintaining and documenting the position:
o A Clearance o
An approved procedure o
The Short Term Configuration Change Process
- c.
Unlock the component and secure the locking device or padlock near the component to prevent its loss.
- d.
Physically reposition the component.
- e.
If the method of maintaining and documenting the component position requires Independent Verification, then another person shall perform an Independent Verification of the component position using the guidance of this procedure for a component that is not locked.
- f.
Inform the Shift Manager that the component has been physically repositioned and, if required, Independently Verified.
- 2.
To restore a Locked component to its Locked position, perform the following steps.
- a.
Obtain permission from the Shift Manager to restore the component to its Locked position.
- b.
Determine the method of maintaining and documenting the position:
o A Clearance o
An approved procedure o
The Short Term Configuration Change Process
- c.
Physically check or verify the component in the desired position.
- d.
Another person shall perform an Independent Verification of the component position and then lock the component in position.
- e.
A person other than the person who locked the component shall Independently Verify that the component is properly Locked.
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- f.
Inform the Shift Manager that the component has been physically verified or checked and Independently Verified in its Normal Configuration.
- 3.
To physically (hands-on) check or verify Locked components with the intent that the component will be left in the Locked position, perform the following steps.
- a.
Obtain permission from the Shift Manager to physically verify a Locked component position.
- b.
Determine the method of maintaining and documenting the position:
o A Clearance o
An approved procedure o
The Short Term Configuration Change Process
- c.
Unlock the component and secure the locking device or padlock near the component to prevent its loss.
- d.
Physically check or verify the component position.
- e.
Another person shall perform an Independent Verification of the component position and then lock the component in position.
- f.
A person other than the person who locked the component shall Independently Verify that the component is properly Locked.
- g.
Inform the Shift Manager that the component has been physically verified or checked and Independently Verified in its Normal Configuration.
- 4.
To check Locked components using the fact that the component is locked and there is an additional cue that the component is in the desired position, perform the following steps.
- a.
Obtain permission from the Shift Manager to check a Locked component position.
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- b.
Determine the method of maintaining and documenting the position:
A Clearance An approved procedure The Short Term Configuration Change Process
- c.
Check that the locking device or padlock is properly installed on the component.
- d.
Use an additional cue to determine that the component is in the desired position, such as:
Remote valve position indicator Stem position Local valve position indication Process variables (i.e. system pressure, flow rates, tank level changes etc.)
Color-coded locks or locking tabs (Red = Open, Green =
Closed, Tan or Yellow = Throttled).
- e.
If an Independent Verification is desired, this same method shall be used for the Independent Verification.
- f.
Inform the Shift Manager that the component has been checked and if performed, Independently Verified, in its Normal Configuration.
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43 of 47 5.0 RECORDS 5.1 Records Handling Records completed/generated by this procedure shall be handled in accordance with each plants established records management program.
5.2 Records Capture The following records are completed/generated by this document:
Quality Records NOP-OP-1014-01, Operations Evolution Order Non-Quality Records None
6.0 REFERENCES
6.1 Discretionary 6.1.1 Multi-site Flowserve (Limitorque) Technical Update 05-02 NOBP-LP-2601, Human Performance Program NOP-CC-2008, Abandonment of Equipment NOP-LP-2001, Corrective Action Program NOP-LP-2601, Procedure/Work Instruction Use and Adherence NOP-LP-4003, Evaluation of Changes, Tests and Experiments NOP-OP-1007, Risk Management NOP-OP-1009, Operability Determinations And Functionality Assessments
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44 of 47 NOP-WM-4300, Order Execute Process NOP-WM-4300-04, Configuration Control Log OE20766 LIMITORQUE SMB/SB-000 & 00 DE-CLUTCH LIMITS 6.1.2 BV 1/2-ADM-2028, Temporary Configuration Control 1/2OM-48.3.C, Padlocks/Locking Devices Administrative Requirement 6.1.3 DB DB-OP-00008, Operation and Control of Locked Valves 6.1.4 PY OAI-0201, Operations General Instructions and Operating Practices OAI-0503, Preparation Of Operations Section Lineup Instructions PAP-1404, Miscellaneous Tagging PYRM-ERS-5003, Equipment Important To Emergency Response 6.2 Obligations 6.2.1 Multi-site G203-CA-2011-05339-5, additional standards when system conditions will place pressure against a previously unpressurized operated clearance boundary 6.2.2 BV None 6.2.3 DB None
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45 of 47 6.2.4 PY B00095, B00544, B00569 7.0 SCOPE OF REVISION
- 1.
Updated section 2.2.2 to be consistent across the fleet.
- 2.
Eliminated FENOC from section 3.2.
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46 of 47 ATTACHMENT 1: EXAMPLES OF POSITIONABLE COMPONENTS Page 1 of 1 POSITIONABLE COMPONENTS Manual operated valves Control power fuses and other fuses used to control component operation Motor operated valves Control switches associated with systems Air operated valves Switches used to control plant components such as:
Pumps Fans Controllers (Auto/Manual)
Strainer Motors Switches associated with instruments/monitors such as:
Generator Core Monitor Isophase Bus Hydrogen Monitor Containment Hydrogen Monitors Hydrogen/Oxygen Monitors Service Connections Air Demineralized Water Domestic Water Nitrogen Breakers Switchgear MCC's DC distribution panels AC distribution panels Lighting panels Disconnects Dampers Slide Links/Knife Switches
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47 of 47 ATTACHMENT 2: IAW What? Graphic Page 1 of 1
Please start printing after page 1 for drawing image NOTE:
This drawing is a USAR Figure or referenced drawing USAR figure.
A change to this drawing shall/may also require a USAR Change Notice (UCN)
See the most current USAR Manual for Cross Reference Information.
OPEN CLSD OPEN CLOSE 70(D) 2B
- CL-4*
72 68A 69A 73 68B(D) 69B(D) 64 OPEN OPEN CLSD CLOSE 1B
- CL-2*
1-1 COOLER LETDOWN E25-1 370 OPEN OPEN CLSD CLOSE 1A
- CL-2*
1-2 COOLER LETDOWN 369 E25-2 TSH 3745A 160 2-3-A F
T715 TSH 3745B 135 2-3-A F
T715 76(D)
COIL DELAY
- CL-4*
- CL-2*
77(V) 78(V) 310(D) 2A LEVEL 2 BLOCK Z740 CONTAINMENT INSIDE CONTAINMENT OUTSIDE OPEN OPEN CLSD CLOSE 4
87 83 82(V) 84(V) 85 86 6
Z742 FC 172 P742 25 PSID 2-4-A FG 4851 275 274 OPEN OPEN CLSD CLOSE 12B M
OPEN OPEN CLSD CLOSE 163 168(D) 170 PDS MU13 158 159 (D) 470 471 177 176 88(D) 295 F
276(V)
ZONE C-13 162 161 160 PDI MU13 93 M
M 71(V)
M M
1-2 FILTER MAKEUP F12-2 167(V)
SYSTEM WATER COOLING COMPONENT TO/FROM SYSTEM WATER COOLING COMPONENT TO/FROM ZONE B-13 14 P
LEGEND PURPLE DENOTES DEMINERALIZED WATER FLOWPATH BROWN DENOTES SPENT RESIN FLOWPATH RED DENOTES MAKEUP AND PURIFICATION NORMAL FLOWPATH GREEN DENOTES DEVICES LOCATED IN THE CONTROL ROOM
- CL-1*
P718 ROMU5 BREAKER BE2259 MCC E22B O S-051,B-58 BREAKER BE1171 MCC E11B BREAKER BE1172 MCC E11B BREAKER BF1237 MCC F12A BREAKER BF1238 MCC F12A S-001A,J-14 O
O S-051,E-54 O S-004,G-5 O S-046,D-13 O S-004,D-10 71A(V) 70A(D) 82A(V)
X X
X X
X X
X X
X X
X X
X X
X X
X X
( S-021,B-25)
O O
MU2B LETDOWN ISO HISMU2B BE1172-B CC1409 MU1A &
CLR 2 CLR 1 CC1410 MU1B &
HISMU1B BF1238-A ORANGE DENOTES RCP SEAL WATER RETURN FLOWPATH ZONE A-42 ZONE D-24 MU12B MU4 BLOCK ORIFICE HISMU4 BE2259-B HISMU12A BE1125-A MU12A FC MU6 HISMU1A BF1237-A CC1409 CLOSE MU1A OPEN INDICATE LIGHTS O S-021,D-24 O S-021,C-24 CC1410 CLOSE MU1B OPEN INDICATE LIGHTS HISMU12B BF1107-D Y
OUTLET REMOVAL COOLER DECAY HEAT FROM FLOW CONTROL MU6 SET POINT HCMU6 D
E R
U S
A E
M E
L B
A I
R A
V 165(V) 164(D) 434(V) 433(D) 84A(V) 77A(V) 78A(V) 310A(D)
HISMU2A1 BE1171-B HISMU2A MU2A LETDOWN CLRS OUTLET SAMPLING SYSTEM TO PUMP SUCTION REACTOR COOLANT FROM M
76A(D)
SUCTION REMOVAL PUMP DECAY HEAT TO SAMPLING SYSTEM TO FT MU7 F719 FI MU7 TE MU8 TT MU8 TI MU8 TS MU8 T715 135 2-3-A F
PT MU9 P719 PS MU9 2-2-A 140 PSIG P720 RE 1998 UJR 5093I R785 R786 2-1-A HI RAD 2-4-A 25 PSID PDT MU62 PDS MU62 PDI MU62 P718 PDT 1911 PDI 1911 AE 1999 AR 1999 OPEN CLOSE 91 92(V) 98(V) 94 101(D) 100(V) 99(V) 103 PW8 97 95 96 102(D) 90(D)
FUEL DETECTOR FAILED 89(V)
FI 1901 FE1901 381 133 447 446 445 ZONE E-4 F
DW26 FILTER 1-1 DEMIN PURIFICATION F35 1890 CONTROL LOGICS ZONE K-2 ZONE J-2 M
63 OVERFLOW PUMP SPENT RESIN TANK FROM TO OPEN A MAKEUP AND PURIFICATION VALVE DURING AN SFAS, EACH COMPONENT'S "BLOCK" PUSHBUTTON MUST BE DEPRESSED FIRST.
O S-029,E-1 O
PW28 PW9 DW67 DW22 BREAKER BE2268 MCC E22B O S-051,E-55 S-001A,E-47 O
O FEMU7 O S-049,B-13 150 PSIG RI 1998 AT 1999 X
X X
X X
X X
X X
X X
X HISMU63 BE2268-B MU63 BYPASS DRAIN TANK MISC WASTE TO WATER SYSTEM DEMINERALIZED FROM X
X 40 PSIG FI 1557 NN102 NN1900 NN103 NN104 SYSTEM NITROGEN SUPPLY FROM SAMPLING SYSTEM TO DRAIN TANK REACTOR COOLANT TO DEMIN POLISHING TO/FROM FEATURES ACTUATION SYSTEM (SFAS) SIGNAL:
FOLLOWING ACTIONS WILL OCCUR IN THE EVENT OF A SAFETY
- CL-1* WITH REGARD TO THE MAKEUP AND PURIFICATION SYSTEM, THE VALVE SIGNAL ZONE ACTION REMARKS 3
2A 66A 66B 66C 66D 59A 59B 59C 59D 38 SA272A SA271A SA332E SA331J SA331K SA332G SA331E SA331F SA331G SA331H SA332F C-6 C-5 K-28 CLOSES CLOSES CLOSES BLOCK PUSHBUTTON BLOCK PUSHBUTTON BLOCK PUSHBUTTON H-28 G-28 F-28 K-21 H-21 G-21 F-21 E-20 CLOSES CLOSES CLOSES CLOSES CLOSES CLOSES CLOSES CLOSES BLOCK PUSHBUTTON BLOCK PUSHBUTTON BLOCK PUSHBUTTON BLOCK PUSHBUTTON BLOCK PUSHBUTTON BLOCK PUSHBUTTON BLOCK PUSHBUTTON BLOCK PUSHBUTTON LEVEL 2 LEVEL 3
- CL-2* REACTOR COOLANT LETDOWN COOLER 1-1 INLET VALVE 1A (ZONE B-3) WILL AUTOMATICALLY OPEN WHEN THE LETDOWN COOLER 1-1 COMPONENT COOLING WATER INLET VALVE CC1409 (OS-021, D-24)
IS FULLY OPEN.
VALVE 1A CAN NOT BE MANUALLY OPENED BY ITS HANDSWITCH HISMU1A (ZONE A-3) "OPEN" PUSHBUTTON.
VALVE 1A WILL AUTOMATICALLY CLOSE WHEN IT IS 20% OPEN AND EITHER OF THE FOLLOWING CONDITIONS EXIST:
- LETDOWN COOLER 1-1 COMPONENT COOLING PRESSURE IS 135 PSIG AS SENSED BY PSH3711 (OS-021, A-25).
- REACTOR COOLANT LETDOWN LINE DECAY COIL INLET TEMPERATURE IS 160 F AS SENSED BY TSH3745A (ZONE B-4) AND HANDSWITCH HISMU1A "OPEN" PUSHBUTTON IS NOT DEPRESSED.
VALVE 1A IS MANUALLY CLOSED BY DEPRESSING ITS HANDSWITCH HISMU1A "CLOSE" PUSHBUTTON.
LOGIC FOR REACTOR COOLANT LETDOWN COOLER 1-2 INLET VALVE
- CL-3* REACTOR COOLANT LETDOWN ISOLATION VALVE 3 (ZONE C-6) WILL OPEN WHEN ITS HANDSWITCH HISMU3 (ZONE B-7) "OPEN" PUSHBUTTON IS DEPRESSED, AIR VOLUME TANK PRESSURE IS >75 PSIG AS SENSED BY PSLLMU3 (ZONE A-7) AND SFAS LEVEL 2 (CONTAINMENT HIGH PRESSURE/REACTOR COOLANT LOW PRESSURE, SEE *CL-1*) IS NOT ACTUATED.
VALVE 3 WILL AUTOMATICALLY CLOSE ON SFAS LEVEL 2 ACTUATION OR AIR VOLUME TANK PRESSURE IS 75 PSIG AS SENSED BY PSLLMU3.
VALVE 3 IS MANUALLY CLOSED BY DEPRESSING ITS HANDSWITCH HISMU3 "CLOSE" PUSHBUTTON.
WILL AUTOMATICALLY CLOSE WHEN IT IS 20% OPEN AND EITHER OF THE FOLLOWING CONDITIONS EXIST:
- REACTOR COOLANT LETDOWN LINE DECAY COIL INLET TEMP-ERATURE IS 135 F AS SENSED BY TSH3745B (ZONE C-5).
- LETDOWN COOLER 1 OR 2 COMPONENT COOLING OUTLET PRESSURE IS 135 PSIG AS SENSED BY PSH3759 OR PSH3763 VALVE 2B IS MANUALLY CLOSED BY DEPRESSING ITS HANDSWITCH VALVE 2B IS MANUALLY OPENED BY DEPRESSING ITS HANDSWITCH HISMU2B "OPEN" PUSHBUTTON.
- CL-5* TREATED WATER MAKEUP TANK HYDROGEN INLET VALVE G4977A HYDROGEN PRESSURE IS >20 PSIG AS SENSED BY PSL4977 (ZONE OPEN OPEN CLSD CLOSE 143 140 141 144 1909 344 S
PDI 1846 145 432 M
Z733 Z732 148 147 11 157(V)
M Z746 Z747 OPEN OPEN CLSD CLOSE 156(D) 40 44 154 152 153 380 42 437 438(V) 149 150 151 39 M
435(V) 173(D) 12A 175(V) 436(D) 296 FC 171 469(D)
F 155 1-1 FILTER MAKEUP F12-1 SS501A SS501 SS502A SS503A SS502 SS503 S-031-1 S-031-2 S-031-3 S-031-2 BREAKER BE1125 MCC E11A O S-051,E-55 O
O S-046,K-1 O S-051,A-40 O S-051,A-40 O S-051,A-40 BREAKER BE1109 MCC E11A BREAKER BE2278 MCC E22B O
O S-051,E-55 O S-046,H-14 O S-029,E-1 O S-046,J-13 O
O S-045,C-14 O S-045,B-1 DW66 DW24 PW10 ZONE D-11 O
O X
X X
X X
X X
X X
X X
X X
X X
X X
X FC MU39 HISMU40 BE1109-A MU40 BATCH ISO FSH MU39 FT MU39 2-5-C 130 GPM F737 F736 NOTE 5 A
MU TK WST CLN HISMU11 BE2278-B MU11 DIVERT VALVE ILMU11 PERMISSIVE FEED & BLEED STORAGE TANK SPENT RESIN TO RADWASTE SYSTEM CLEAN LIQUID FROM SAMPLING SYSTEM TO PUMP BORIC ACID FROM FLOWMETER PUMPS BORIC ACID FROM HEADER DRAIN TANK MISC WASTE TO SAMPLING SYSTEM FROM SAMPLING SYSTEM FROM SAMPLING SYSTEM FROM 174 SAMPLING SYSTEM TO STORAGE TANK SPENT RESIN TO TOTAL RATE BATCH INVENT AUX AUX AUX ACK 9
0 1
2 3
4 5
6 7
8 INHIB TOTAL RESET TOTAL STOP RUN ENTER BATCH VALVE CE SET BATCH CALIB TEST/
SET PARAM SET VALVE R
R R
R R
R FAULT FLOW HIGH FLOW LOW PSD DISPLAY DISPLAY R
R R
R R
R FYICMU39 BATCH CONTROLLER Q742
- CL-7*
- CL-6*
HCMU39 WATER SYSTEM DEMINERALIZED FROM X
X BOOSTER PUMPS CLEAN WASTE FROM 110 112 111 126 M
OPEN OPEN CLSD CLOSE 129(V) 132 382 108 107 M
OPEN OPEN CLSD CLOSE 125 128(V) 131 T5-2 138(D) 121 122 119 120 123(D) 117(V) 118(D) 113 130 134 T5-1 10B 279 M
OPEN OPEN CLSD CLOSE 10A 278 124 127(V) 106 137(D) 150 PSIG 142 139 116 115 150 PSIG 1905 135 150 PSIG 105(V) 104 440 449 448 468(D) 136 T5-3 DEMINERALIZERS PURIFICATION 1903 114 SS21A SS21 SS20 SS19A SS19 SS20A S-031-1 RO3830 RO3828 RO3829 S-031-3 O
O S-030,C-29 BREAKER BE2262 MCC E22B BREAKER BE2263 MCC E22B O S-051,A-40 O S-051,A-40 O S-051,A-40 S-001A,E-47 O
BREAKER BE2271 MCC E22B O
O 1904 NOTE 6 NOTE 6 X
X X
X X
X X
X X
X X
X X
X X
X X
X X
X X
X X
X X
X X
HISMU10B BE2263-B MU10B HIS1903 BE2271-B MU1903 STATION VENT TO HISMU10A BE2262-B MU10A TANK T17-2 RESIN FILL FROM POLISHING TANK LIQUID WASTE TO/FROM CLEAN SAMPLING SYSTEM TO DRAIN TANK REACTOR COOLANT TO SAMPLING SYSTEM TO SAMPLING SYSTEM TO ANNUNCIATOR ANNUNCIATOR ENGRAVING ANNUNCIATOR TABLE VALVE G4977A WILL AUTOMATICALLY CLOSE IF THE ABOVE CONDITIONS ARE NOT MET.
OPERATIONAL SCHEMATIC C
MAKEUP AND PURIFICATION SYSTEM JAM CML VS RSM 0
8-12-88 EWT HHB VMW MMH WGC HA INFORMATION ONLY APPROVED FOR OPERATION 1
S-002 SH 1 JPP
- CL-4*
- CL-2*
- CL-2*
NOTE 11
- CL-1*
NOTE 16 NOTE 16 NOTE 16 NOTE 16
- CL-7*
- CL-6*
- CL-7*
- CL-7*
- CL-6*
- CL-6*
NOTE 16 NOTE 16 NOTE 16 54 (ZONE C-44) IS OPEN.
JBG PNC JJH HA LWB VMW (V) 166 RT 1998 RSH 1998 NOTE 12 (OS-021, A-25 AND B-25).
OPEN CLSD ZONE D-3 S-028A,C-33 S-028A,C-56 S-028A,D-54 S-028A,F-54 S-028A,G-56 DEMINERALIZER PRIMARY TO S-028A,E-1 S-028A,J-46 S-028A,A-77
( S-021,B-25) 2-5-C BATCH MU FLOW HI 2-2-A LETDOWN PRESS HI 2-4-A LETDOWN OR MU FILT (DELTA)P HI 2-3-A LETDOWN TEMP HI 2-1-A LETDOWN RAD HI 1B (ZONE C-3) IS SIMILAR.
S-028A,E-54 5VM 2VM 2VM 1999C 1999A 1999B 1999D 5VM 5VM 5VM PDT MU13 5VM DW1901A DW1901B 5VM ZONE D-11 (ZONE C-41) WILL AUTOMATICALLY OPEN WHEN SUPPLY LINE B-42) AND TREATED WATER RC MU TANK HYDROGEN SUPPLY VALVE LOGIC FOR VALVE G4978A (ZONE C-42) IS SIMILAR.
7B 7A 7AA 7BA 9
9A 62B 62A 1911B 1911A DW1901BA DW1901AA
- CL-4* REACTOR COOLANT LETDOWN COOLER INLET VALVE 2B (ZONE B-1)
HISMU2B (ZONE A-1) "CLOSE" PUSHBUTTON.
1846AB 1846BB 13BA 13B 13AA 13A CLN WST MU TANK FOR NOTES AND REFERENCES SEE OS-002 SH 4 SBW SBW (D)
(D)
(D)
(D)
(D)
(D)
(D)
(D)
(D)
(D)
(D)
(D)
(V)
(D)
(D)
(D)
MIXED BED 140 GPM 1-3 CATION OR G:/OPSCH/OS02S1.DGN LEVEL 2 BLOCK OPEN OPEN CLSD CLOSE Z743 (V)
FC S
- CL-1*
TANK VOLUME AIR PSL MU3 PSLL MU3 PI MU3 IA637 IA641 IA639 IA638 NOTE 2 IA642
- CL-3*
AOV MU3 LETDOWN CLRS OUTLET SVMU3 Q739 NOTE 21
- CL-3*
SEE M-900I,D-10 NON-ESSEN HDR FROM AUX BLDG 640 IA (V)
IA1050 IA1041 IA1040 IA1051 15 GAL.
TANK VOLUME AIR IA1019 (V)
(V) 3 79 80 81(D)
- CL-3*
- CL-1*
79A 80A 81A(D)
SEE M-900I,D-10 NON-ESSEN HDR FROM AUX BLDG 8
12 88 4
10 89 5
25 11 3 9 12 B
NOTE 28 FU.DIS.SW. BF1107 MCC F11D IA979 (D) 07-24-18 62B1 62A1 DW1901A1 DW1901B1 13A1 13B1 1846BA 1846AA 1846A 1846B CJB SAC 29 PW29 NOTE 29 WATER SYSTEM DEMINERALIZED FROM NOTE 29 SAC RMS 30 WATER SYSTEM DEMINERALIZED FROM 145 REV.00 INC. DUN 02-0540 NOTE 31
-010 REV.00 INC. DUN 10-0490-002 PUMP ZINC INJECTION FROM HYDROXIDE PUMPS AND LITHIUM FROM HYDRAZINE 32 31 SAP
-001 REV.0 INC. PDUN 18-0105-001 NOTE 32 1-2 75 GPM MIXED BED 1-1 75 GPM MIXED BED SBW CDA 05 22 18 32 024 REV.0 INC. DUN 16-0507-001-SAP ANALYZER BORON 32 ECP 16-0507 PLACE PER ABANDONED IN NOTE 33 NOTE 33 07 25 18 CDA AJB 14 13 12 10 9
8 7
6 5
4 3
2 14 13 10 9
8 7
6 5
4 3
2 15 16 17 15 16 17 REV DAVIS-BESSE NUCLEAR POWER STATION UNIT NO 1 DRAWING NO SCALE DESIGNED DATE DRAWN DATE NO NONE J
H E
D C
B A
G F
K J
H E
D C
B A
G F
K REVISIONS BY CH'K ENGR ENGR SUPV ENGR SYS ENGR OPS ENGR DES MGR 11 1
1 12 11
Davis-Besse DB1LOT21 NRC Exam Admin JPM A3
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A3 NUREG-1021, Revision 11 Page 1 of 4 Facility: Davis-Besse Task No:
333-008-01-0300 Task
Title:
Review and Approve a Waste Gas Release Permit K/A
Reference:
2.3.6 (3.8) Job Performance Measure No: A3 (JPM 175)
Examinee:
NRC Examiner:
Date:
Method of testing:
Simulated Performance ___
Actual Performance _X_
Classroom _X_
Simulator ___
Plant ___
Read to the examinee:
I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues.
When you complete the task successfully, the objective for this job performance measure will be satisfied.
Initial Conditions:
The plant conditions are specified in the Initial Conditions and Initiating Cues.
Task Standard:
Review Waste Gas Release Permit and identify errors Required Materials:
DB-OP-03012, Radioactive Gaseous Batch Release, complete to step 4.3.14 Wallboard General
References:
Offsite Dose Calculation Manual Initiating Cue:
The plant conditions are specified in the Initial Conditions and Initiating Cues.
Time Critical Task:
No Alternate Path:
No Validation Time:
45 minutes
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A3 NUREG-1021, Revision 11 Page 2 of 4 EXAMINER COPY INITIAL CONDITIONS:
Plant is at 100% power.
Waste Gas RE 1822A and RE 1822B are Inoperable No other radioactive gaseous batch release is being performed INITIATING CUES:
You have just assumed the watch and are requested to approve a Waste Gas (Waste Gas Decay Tank 3) Release Permit per step 4.3.14 of DB-OP-03012, Radioactive Gaseous Release Review the release permit and approve the release or identify on this sheet any discrepancies preventing release authorization Step 4.2.2, Verify Applicable Surveillance Requirements are Current has already been peer checked by another SRO (Provide the following,
- 1. DB-OP-03012, Radioactive Gaseous Batch Release, completed up to step 4.3.14
- 2. E-Plan Wallboard)
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A3 NUREG-1021, Revision 11 Page 3 of 4 CANDIDATE COPY INITIAL CONDITIONS:
Plant is at 100% power.
Waste Gas RE 1822A and RE 1822B are Inoperable No other radioactive gaseous batch release is being performed INITIATING CUES:
You have just assumed the watch and are requested to approve a Waste Gas (Waste Gas Decay Tank 3) Release Permit per step 4.3.14 of DB-OP-03012, Radioactive Gaseous Release Review the release permit and approve the release or identify on this sheet any discrepancies preventing release authorization Step 4.2.2, Verify Applicable Surveillance Requirements are Current has already been peer checked by another SRO
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A3 NUREG-1021, Revision 11 Page 4 of 4 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is NOT assumed unless denoted in the "Comments".
START TIME: _______
- 1.
PERFORMANCE STEP: Recognize the permit is not approved by Environmental and
___C____ Chemistry Supervisor IAW step 4.2.1.
STANDARD: Identify item 4.h of Attachment 1 has not been signed.
CUE: None SAT UNSAT
- 2.
PERFORMANCE STEP: Recognize Step 4.3.12 performed incorrectly
___C____
STANDARD: Identify steps 4.3.12 b. and 4.3.12 c.2. were not performed NOTE: May also identify that steps 4.3.12 a. and 4.3.12 c.1. should not have been performed CUE: None SAT UNSAT
- 3.
PERFORMANCE STEP: Recognize a 2nd tank sample has not been analyzed
___C____
STANDARD: Identify a 2nd tank sample has not been analyzed Comment: Section 4.12 Sampling and Analysis, step 4.12.4 identifies steps for Chemistry documenting second sample analysis NOTE: May also identify steps 4.12.12 and 4.13.2 should not be N/A CUE: None SAT UNSAT Termination Cue: This JPM is complete. (Terminated by the Examinee).
END TIME
Davis-Besse DB1LOT21 NRC Exam Admin JPM SRO-A4
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A4 Page 1 of 7 Facility: Davis-Besse Task No: 334-004-05-0300 Task
Title:
Notify State and Counties of an Unusual Event K/A
Reference:
2.4.43 (3.2/3.8)
Job Performance Measure No: SRO A4 (JPM 241)
Examinee:
Examiner:
Date:
Method of testing:
Simulated Performance ____
Actual Performance __X__
Classroom ___
Simulator _X__
Plant ____
Read to the examinee:
I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues.
When you complete the task successfully, the objective for this job performance measure will be satisfied.
Initial Conditions:
The plant conditions are specified in the Initial Conditions and Initiating Cues.
Task Standard:
Notify State and Counties of an Unusual Event Required Materials:
RA-EP-02110 Davis-Besse Emergency Plan Telephone Directory General
References:
None Initiating Cue:
The plant conditions are specified in the Initial Conditions and Initiating Cues.
Time Critical Task:
Yes Alternate Path:
No Validation Time:
10 minutes
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A4 Page 2 of 7 SIMULATOR INSTRUCTIONS INITIAL CONDITION:
This JPM is not dependant on any specific simulator initial conditions since the task is administrative in nature.
The plant conditions are specified in the Initial Conditions and Initiating Cues.
ADDITIONAL SETUP/DEVIATION FROM INITIAL CONDITION:
If this JPM is not conducted in the simulator, the following references need to be available to the examinee:
RA-EP-02110, Emergency Notification Davis-Besse Emergency Plan Telephone Directory
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A4 Page 3 of 7 EXAMINER COPY INITIAL CONDITIONS:
You are a spare Senior Reactor Operator in the Control Room.
The plant is being shut down due to a Reactor Coolant System (RCS) leak calculated to be 35 gpm.
The Shift Manager has declared an Unusual Event based on RCS leakage.
INITIATING CUES:
The Shift Manager directs you to make an initial notification to the state and counties of the emergency in accordance with RA-EP-02110, Emergency Notifications.
CUE: Provide the candidate with filled out forms,
- Davis-Besse Nuclear Power Plant Initial Notification Form (DBEP-010)
- Davis-Besse Emergency Notification Coversheet (DBEP-012).
CUE: This is a time critical JPM. The clock starts now.
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A4 Page 4 of 7 CANDIDATE COPY INITIAL CONDITIONS:
You are a spare Senior Reactor Operator in the Control Room.
The plant is being shut down due to a Reactor Coolant System (RCS) leak calculated to be 35 gpm.
The Shift Manager has declared an Unusual Event based on RCS leakage.
INITIATING CUES:
The Shift Manager directs you to make an initial notification to the state and counties of the emergency in accordance with RA-EP-02110, Emergency Notifications.
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A4 Page 5 of 7 PERFORMANCE INFORMATION NOTE: Critical steps denoted with a "C". Failure to meet any one of these standards for this item constitutes failure. Sequence is NOT assumed unless denoted in the Comments".
CUE: This is a time critical JPM. The clock starts now. START TIME: _______
- 1.
PERFORMANCE STEP: Locate the correct procedure for emergency notification.
STANDARD: Obtains RA-EP-02110, Emergency Notification.
CUE: None SAT UNSAT
- 2.
PERFORMANCE STEP: Reviews the Initial Notification Form (DBEP-010) and Davis Besse Notification Cover Sheet (DBEP-012) and verify Initial Notification Form is signed by the Shift Manager (DB-EP-02110 Step 6.3.4)
(DBEP-012 Communicator: Step 1)
STANDARD: Reviews the forms from the Shift Manager and detects that the Shift Manager has not signed the approval signature on the FENOC Nuclear Power Plant Initial Notification Form.
CUE: When prompted by the examinee, sign the approval signature on the FENOC Nuclear Power Plant Initial Notification Form and direct that the notification proceeds.
SAT UNSAT
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A4 Page 6 of 7
- 3.
PERFORMANCE STEP: Make Initial Notification using the 4-Way Phone.
........C........
(DB-EP-02110 Step 6.3.5 a. and b.)
(DBEP-012 Communicator: Steps 2-5)
STANDARD: Picks up the 4-Way Phone in the Control Room.
- As agencies answer, identifies self by name and facility
- Record the Time of initial contact for Ottawa County and Lucas County on the Davis-Besse Emergency Notification Coversheet (DBEP-012)
- Reads the information from Davis-Besse Nuclear Power Plant Initial Notification Form (DBEP-010)
- Records Completion Time of Call
- Records if the 4-Way Phone was used when making the notification COMMENT: Critical Item
- 4-Way Phone must be picked up within 15 minutes of the event declaration time NOTE: Ohio State Highway Patrol Dispatcher does NOT answer.
CUE:
This is the Ottawa Country Sheriff's Dispatcher This is the Lucas County Sheriffs Dispatcher Repeat back the information as it is communicated.
Time 4-Way Ring-Down phone is picked up: __________
SAT UNSAT
- 4.
PERFORMANCE STEP: Notify Shift Manager that the Ohio State Highway Patrol Dispatcher was not notified.
STANDARD: Informs Shift Manager that the Ohio State Highway Patrol Dispatcher did not answer the 4-Way Ring-Down Circuit.
COMMENT: This step may not be needed if operator proceeds to use alternate notification methods without being prompted.
CUE:
If notified, tell the operator to continue with notifications as directed by procedure RA-EP-02110, Emergency Notification.
SAT UNSAT
Appendix C, Rev. 11 Job Performance Measure Form ES-C-1 Worksheet Admin JPM A4 Page 7 of 7
- 5.
PERFORMANCE STEP: Sign the Davis-Besse Emergency Notification Coversheet (DBEP-012) and check the location on the form.
(DB-EP-02110 Step 6.3.6)
STANDARD: Sign the Davis-Besse Emergency Notification Coversheet (DBEP-012) and check the location on the form.
COMMENT: This may be performed after Step 6 and/or 7.
CUE:
None SAT UNSAT
- 6.
PERFORMANCE STEP: Contact Ohio State Highway Patrol Dispatcher.
........C........
(DB-EP-02110 Step 6.3.7)
STANDARD: Locates the Ohio State Highway Patrol Dispatcher (614) 466-2660 or Administrative Office (614) 644-7622 telephone number.
COMMENT: The phone numbers are in the Immediate Notification Numbers tab of the Davis-Besse Emergency Plan Telephone Directory. Have the examinee point out and then dial one of the numbers.
CUE:
Answer the phone as either the Ohio Highway Patrol Dispatcher or the Administrative Office depending on who was dialed.
SAT UNSAT
- 7.
PERFORMANCE STEP: Make Initial Notification to the Ohio State Highway Patrol.
(DB-EP-02110 Step 6.3.7 a.)
STANDARD: Reads Initial Notification information to the Ohio State Highway Patrol Dispatcher or Administrative Office staffer.
Documents the time notified on the Davis-Besse Notification Cover Sheet (DBEP-012).
Record the name of the individual(s) on the Davis-Besse Emergency Notification Cover Sheet (DBEP-012)
Request a call back from the person receiving the information.
CUE:
Repeat back information as it is communicated. Provide your name as requested by the caller.
SAT UNSAT TERMINATING CUES: This JPM is complete. (Terminated by the evaluator).
END TIME