ML041620162
| ML041620162 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 06/01/2004 |
| From: | Grobe J NRC/RGN-III |
| To: | |
| References | |
| Download: ML041620162 (36) | |
Text
June 1, 2004 MEMORANDUM TO:
Davis-Besse Nuclear Power Station IMC 0350 Panel FROM:
John A. Grobe, Chairman, Davis-Besse Oversight Panel /RA/
SUBJECT:
REVISED JUNE 24, 2003, MINUTES OF INTERNAL MEETING OF THE DAVIS-BESSE OVERSIGHT PANEL (Revised Attachment)
The implementation of the IMC 0350 process for the Davis-Besse Nuclear Power Station was announced on April 29, 2002. An internal panel meeting was held on June 24, 2003. Attached for your information are the minutes from the internal meeting of the Davis-Besse Oversight Panel, the Electrical Issues Inspection Plan, the Restart Assessment Team Inspection Plan, the Information for Closure of Action Item 196, and the Open Action Items List.
Attachment:
As stated cc w/att:
D. Weaver, OEDO J. Caldwell, RIII G. Grant, RIII S. Reynolds, DRP B. Clayton, EICS DB0350 DOCUMENT NAME: C:\\ORPCheckout\\FileNET\\ML041620162.wpd To receive a copy of this document, indicate in the box:"C" = Copy without enclosure "E"= Copy with enclosure"N"= No copy OFFICE RIII RIII RIII NAME RBaker/dtp JGrobe for CLipa JGrobe DATE 06/01/04 06/ /04 06/01/04 OFFICIAL RECORD COPY
MEETING MINUTES:
Internal IMC 0350 Oversight Panel Meeting Davis-Besse Nuclear Power Station DATE:
June 24, 2003 TIME:
1:00 p.m. Central ATTENDEES:
J. Grobe D. Passehl D. Hills T. Mendiola J. Rutkowski C. Lipa J. Hopkins M. Phillips R. Gardner B. Ruland M. Farber Agenda Items:
1.
Discuss/Approve Electrical Issues Inspection Plan The Panel approved the electrical issues inspection plan with minor comments.
THE APPROVED PLAN WITH COMMENTS INCORPORATED IS ATTACHED TO THESE MINUTES.
2.
Discuss/Approve Restart Assessment Team Inspection Plan The Panel approved the Restart Assessment Team Inspection Plan with minor comments. THE APPROVED PLAN WITH COMMENTS INCORPORATED IS ATTACHED TO THESE MINUTES.
3.
Discuss OI Coordination Time Line and Outcome The Panel discussed the status of ongoing NRC Office of Investigation (OI) activities.
4.
Discuss Action Items The Panel discussed recent Action Items.
Item 192 (Open) - Draft an update to the March 31, 2003, inspection schedule letter The Panel approved the draft letter. Routing for concurrence.
Item 194 (Open) - Add to the Restart Checklist the licensees Technical Specification Amendment Request to relocate the high pressure injection and low pressure injection subsystems flow balance testing requirement in Technical Specification 4.5.2.h to the Updated Safety Analysis Report Technical Requirements Manual
The Panel approved the concept of adding the licensees Technical Specification Amendment Request to the Restart Checklist. A letter has been drafted and will be routed for concurrence.
Item 195 (Open) - Review worker fatigue issues at the site during the current inspection period J. Grobe took action to contact L. Myers and discuss.
Item 196 (Closed) - Determine whether the shift manager is qualified to fulfill the shift engineer position in an emergency and whether there is an adverse impact on the licensees emergency procedure Implementation CLOSURE INFORMATION ON THIS ACTION ITEM IS INCLUDED AS AN ATTACHMENT TO THESE MINUTES.
Item 197 (Open) - Tony Mendiola has lead Item 199 (Open) - Contact the EDOs office to discuss the Panels decision to include the Billie Garde response to 10 CFR 2.206 Petition as an attachment to the final Directors Decision The Panel determined that the description of the item should be changed to "Contact the EDOs office to discuss the Panels question on how to include whether the Billie Garde response to 10 CFR 2.206 Petition should be addressed."
Item 200 (Open) - Draft a TIA letter to send to B. Ruland regarding whether the proposed modification that the licensee is performing to the high pressure injection pumps is sufficient to address the design deficiency The Panel assigned D. Hills with action to send an email next week with summary of the concept.
Item 201 (Open) - Coordinate with L. Gerke and ask her to call Rep. Kapturs staff regarding the June 13, 2003, letter from Chairman Diaz to Kaptur. The purpose of the call would be to update Rep. Kaptur on the recent issues with the HPI Pumps and provide information on NRC actions to review LER 2003-02 The Panel determined that when the communication plan is developed for the HPI Pump issue that we consider interfaces with those people who receive the letter.
5.
Discuss New Allegations The Panel discussed two new allegations.
6.
Discuss Plant Status and Inspector Insights and Emergent Issues List The Panel discussed plant status and inspector insights and emergent issues list.
7.
Discuss New/Potential Licensing Issues The Panel discuss new/potential licensing issues. Specifically discussed was a possible Task Interface Agreement regarding a tornado missile impacting the emergency diesel generator exhaust piping.
8.
Discuss Items for Licensee Weekly Calls The Panel discussed items for the weekly calls with the licensee.
9.
Discuss Licensees Draft July 9 0350 Public Meeting Agenda The Panel discussed the licensees draft July 9 0350 public meeting agenda.
10.
Discuss/Update Milestones and Commitments The Panel reviewed and discussed upcoming milestones and commitments.
DAVIS-BESSE OVERSIGHT PANEL OPEN ACTION ITEM LIST Item Number Action Item (Date generated)
Assigned to Comments 24a Discuss making information related to HQ/licensee calls publicly available Panel Discuss by June 30, after safety significance assessment complete; 6/27 - Invite Bateman to panel mtg.
To discuss what else is needed to closeout the CAL (i.e. quarantine plan); 7/2 - NRR not yet ready to discuss; 7/16 - See if procedures have changed on CAL closeout -
does JD need to send letter?; 7/18
- Discussed - is there an applicable regional procedure?; 8/6 -
Discussed. Need to determine the final approach on the core removed from the head and the final approach on the head before the quarantine can be lifted; 8/22 -
Revisit action item after letter sent to licensee confirming plans with old vessel head (head may be onsite longer than originally anticipated); 8/29 - Memo to be sent to Region, with a letter to go out next week; 10/01-Discussed.
- 1) Conduct NRC staff survey-due 10/7 2)Memo to NRR - due 10/11
- 3) Region to issue letter; 11/07-Letter required from NRR on head quarantine status; 11/19 - Letter in draft; 01/03 - A. Mendiola to look at phone conference writeups on quarantine decision making to determine if they can be released to the public; 01/07 - discussed; 01/21 - discussed; 01/31-A.
Mendiolas action; 02/11 -
Completion of Licensee Phase 3 sampling plan required; 02/21 -
17.5 Rem to cut samples, Less samples may be required; 04/03 -
Completion of Phase 3 sampling plan scheduled for late April -
discuss again then; 04/08 - Revisit in June 2003
DAVIS-BESSE OVERSIGHT PANEL OPEN ACTION ITEM LIST Item Number Action Item (Date generated)
Assigned to Comments 54a Review TSP amendment and advise the panel on the need for a TIA on Davis-Besse (7/2)
D. Pickett 7/9 - Discussed. Will wait for response from licensee; 7/16 -
Discussed - added action item 54b; 8/6 - Sent to the licensee on 7/22 and a response is due by 8/22; 8/22 - Discussed - need to check if response has been received; 8/27
- Received response - DRS is reviewing - will fax to NRR for 54b; 8/29 - Discussed, DRS report of response to be issued to panel prior to item 54b; 10/1-Discussed.
DRS coordinating with NRR 11/07-Discussed - On hold for draft with specific information; 12/10 - B.
Dean believed B. Bateman thought a calculation for sufficient volume of TSP was completed to technical specification value. However questions whether the calculation was to technical specification or actual TSP level remain; 01/03 -
Item under NRR review.
Calculation completion expected on Jan 17. Allegation issue in RIII domain; 01/07 - Allegation Item #3 under NRR Review for Resolution; 01/21 - Item #3 is under Region III control for final letter, holding for NRR input; 02/11 - Writeup for NRR input provided 4 answers, going back to reviewer to ensure specific tasking is clear to answer allegation concerns. Action item 54c created; 02/21 - Allegation at 242 day mark. Effective expression of due date required; 04/03 -
Messrs. Beckner, Grobe, Ruland,
& Mendiola to discuss; 04/08 - J.
Hopkins to set up call for 4/11/03
DAVIS-BESSE OVERSIGHT PANEL OPEN ACTION ITEM LIST Item Number Action Item (Date generated)
Assigned to Comments 73 Send feedback form on IMC 0350 procedure to IIPB (8/6)
C. Lipa A. Mendiola 8/6 - Generate feedback after panel meetings reduced to once per week; 8/29 - Discussed - no change; 10/1 - Discussed; 11/7 -
D Passehl sent email to C Carpenter and D Coe indicating that we would be able to perform a review of the draft IMC 0350 during the first quarter of 2003; 12/3-discussed; 01/03 - 2 parts, short part-C. Lipa with P. Harris, long part-B. Dean; 01/07 - 2nd larger response will require meeting between all parties; 01/21
- Communications with P. Harris; 01/31-Meeting with P. Harris on Feb 4; 02/11 - Many concerns identified by the panel for inclusion; 02/21 - July 1 due date for larger input.
97 Bulletins 2002-01 and 2002-02 response and acceptance (9/5)
NRR 11/07 - Discussed, further research and discussion required; 01/07 - RAI response expected Mid February; 01/31-On track; 02/11 - New Orders will supercede BL2002-01 and BL2002-02 responses with the exception of the BL2002-01 Boric Acid Corrosion program information request; 02/21 - Licensee RAI response delayed. Both Order and BL2002-01 Boric Acid Corrosion program responses to be tracked as RAM items; 04/08 - Discussed, leave open pending NRR review; 05/27 - Discussed - close out need acknowledgment letter that the bulletin responses have been received; 06/17 - Need acknowledgment letter that the bulletin responses have been received. Expected date is June 30th.
DAVIS-BESSE OVERSIGHT PANEL OPEN ACTION ITEM LIST Item Number Action Item (Date generated)
Assigned to Comments 126 Review Davis-Besse/Vessel Head Degradation web site content for ease of use by the public (11/07)
J. Strasma 02/11 - Checked, but revisiting item; 02/21 - Web site being reassessed.
136 NRR acceptance of NOP criteria and method (01/03)
J. Grobe to send an email week of 05/19 with question of whether the licensees method and criteria are adequate to address the TS for zero unidentified reactor coolant leakage from the reactor coolant system.
By the end of the week of 05/19 NRR to formulate a proposed position for discussion. The position by NRR will be discussed by the Panel during the 05/27 0350-Panel meeting. After discussing on 05/27 the issue is to be presented internally within the NRC for dissenting views (05/27 - Reopen)
W. Dean/
J. Grobe 01/07 - Item discussed. Meeting summary of November 26, 2002 meeting has notation of NRR staff impressions of test plan. Once drafted, issue will be surveyed to staff to determine if consensus is correct; 01/21 - Meeting summary to discuss Flus System, Test agreement, and future inspections; 1/31 - T. Chan fwd to J. Hopkins; 2/11 - J. Jacobson questions need to be folded in (chem-wipes); 2/21
- Polling of staff discussed; 2/24 -
Polling of staff by March 7; 3/25 -
Staff to be polled after 4/4/03 meeting in headquarters, and meeting should address whether a rational basis exists that the bottom head is not leaking, and whether a critical flaw size will not appear during the next operating cycle; 04/08 - J. Hopkins writing mtg summary for 4/4, licensee to address additional questions on 4/9 telephone call; 05/16 - Closed; 05/27 - Reopen; 06/17 - Meeting held in HQ the week of June 9.
R. Barrett et. al. discussed that the licensee has no basis that the nozzles are not cracked. May need a TS Amendment. The next step is to engage the licensee.
138 Evaluate the effectiveness of the Comm Plan (01/07)
A. Mendiola/
C. Lipa 01/31 - Ongoing; 02/21 - New EDO Comm Plan for Crisis Update, A.
Mendiola to review for inclusion.
DAVIS-BESSE OVERSIGHT PANEL OPEN ACTION ITEM LIST Item Number Action Item (Date generated)
Assigned to Comments 145 Prepare a special inspection plan for the restart readiness team inspection (01/09)
D. Passehl 02/21 - date to be determined; 05/27 - discussed.
147 Generate a list of items to consider after restart as well as transition back to the normal 0350 when terminating the 0350 Panel. The items should include plans to augment inspection of corrective actions, inservice inspection, and safety culture monitoring (01/09)
D. Passehl 01/31 - working; 02/11 - Include dates and deadlines to Manual Chapter 0350 restart inspections planner 156 Read Generic Safety Issue-191, "Assessment of Debris Accumulation on PWR Sump Pump Performance" (01/09)
J. Hopkins 01/21 - Determine status of GSI-191; 02/21 - Check GL98-04 response on coatings. Draft GL and Draft Reg Guide needs review for DB relevance; 02/24 - Request Response Review and Program Implementation to GL98-04; 03/04
- activity to be reassigned to Reactor Engineer who will close sump LER; 04/08, D. Hills to discuss with K. Coyne and A.
Dunlop work assignments; 06/17 -
K. Coyne requested to review the emergency sump modification against the Bulletin 2003-01.
174 Review 2/4 transcript for Mr. Witts recommendations (2/18)
R. Licks
DAVIS-BESSE OVERSIGHT PANEL OPEN ACTION ITEM LIST Item Number Action Item (Date generated)
Assigned to Comments 178 Determine the type of backlog assessment that will be performed and by whom. Two attributes need to be considered:
(1) the capability of the licensee to manage the backlog in an operating environment; and (2) the impact of the backlog on equipment reliability (03/04)
C. Lipa 186 Add Dennis Kucinich to the standard distribution list on documents for Davis-Besse. Then remove Dennis Kucinich from distribution 90 days after the final NRC reply to his 10 CFR 2.206 Petition is signed out (04/22)
A. Saso 188 Arrange for Radiation Protection Inspection to evaluate stability in Radiation Protection organization effectiveness.
An inspection plan is to be drafted and presented to the Panel for approval, including applicable Restart Action Matrix items, for an inspection to be conducted in the July 2003 time frame (04/29)
K.Riemer
DAVIS-BESSE OVERSIGHT PANEL OPEN ACTION ITEM LIST Item Number Action Item (Date generated)
Assigned to Comments 189 Investigate how the NRC handled communication of potential inspection issues and findings during in-progress inspection work at Millstone in regards to their organization and human performance problems (05/16)
B. Ruland 05/27-Discussed 190 Discuss with T. Kozak removing Davis-Besse from the Operational Management Information Report (OMI) (05/16)
C. Lipa 05/27-Discussed; 06/17 - C. Lipa to discuss with T. Kozak changing the colors of the indicators in the report to gray.
191 Prepare Questions and Answers (Qs and As) once the GT 221 letter to Rep.
Kucinich is issued to ensure consistent communications regarding how the NRC articulates issues to the public (05/16)
C. Lipa/
A. Mendiola 192 Draft an update to the March 31, 2003, inspection schedule letter (05/16)
D. Passehl 6/24 - Approved draft letter, routing for concurrence.
193 Consider TIA on an issue pertaining to 10 CFR 50 Appendix R Section III-L, "Alternative and Dedicated Shutdown Capability" (05/27)
T. Mendiola A concern was identified for the shutdown function performance goal of maintaining reactor coolant level. An NRC safety evaluation report issued in 1991 apparently allows the licensee to maintain reactor coolant level above the top of active fuel instead of maintaining level within the range of indication in the pressurizer.
DAVIS-BESSE OVERSIGHT PANEL OPEN ACTION ITEM LIST Item Number Action Item (Date generated)
Assigned to Comments 194 Add to the Restart Checklist the licensees Technical Specification Amendment Request to relocate the high pressure injection and low pressure injection subsystems flow balance testing requirement in Technical Specification 4.5.2.h to the Updated Safety Analysis Report Technical Requirements Manual (06/17)
D. Passehl 6/24 - Approved the concept of adding the licensees Technical Specification Amendment Request to the Restart Checklist. A letter has been drafted and will be routed for concurrence.
195 Review worker fatigue issues at the site during the current inspection period (06/17)
S. Thomas 6/24 - J. Grobe took action to contact L. Myers and discuss 196 Determine whether the shift manager is qualified to fulfill the shift engineer position in an emergency and whether there is an adverse impact on the licensees emergency procedure Implemention (06/17)
S. Thomas 6/24 - Closed - see minutes for closure information.
197 Develop a communication plan with restart Qs and As (06/17)
A. Mendiola 6/24 - Lead changed
DAVIS-BESSE OVERSIGHT PANEL OPEN ACTION ITEM LIST Item Number Action Item (Date generated)
Assigned to Comments 198 Call Billie Garde on the section of the letter regarding "missed opportunities." The specific paragraph includes the statement:
"Mr. Siemasko has identified at least twenty-three separate "missed opportunities" that could have prevented the propagation of G9 nozzle crack during the 14 years prior to 12 RFO in the spring of 2000." This action is due June 27 (06/20)
B. Clayton 199 Contact the EDOs office to discuss the Panels question on how to include whether the Billie Garde response to 10 CFR 2.206 Petition should be addressed (06/20)
J. Hopkins 6/24 - Revised description 200 Draft a TIA letter to send to B. Ruland regarding whether the proposed modification that the licensee is performing to the high pressure injection pumps is sufficient to address the design deficiency (06/20)
C. Lipa 6/24 -The Panel assigned D. Hills with action to send an email next week with summary of the concept.
DAVIS-BESSE OVERSIGHT PANEL OPEN ACTION ITEM LIST Item Number Action Item (Date generated)
Assigned to Comments 201 Coordinate with L. Gerke and ask her to call Rep.
Kapturs staff regarding the June 13, 2003, letter from Chairman Diaz to Kaptur. The purpose of the call would be to update Rep. Kaptur on the recent issues with the HPI Pumps and provide information on NRC actions to review LER 2003-02 (06/20)
T. Mendiola 6/24 - The Panel determined that when the communication plan is developed for the HPI Pump issue that we consider interfaces with those people who receive the letter.
INFORMATION FOR CLOSURE OF ACTION ITEM 196 Action Item 196:
Determine whether the shift manager is qualified to fulfill the shift engineer position in an emergency and whether there is an adverse impact on the licensees emergency procedure Implemention.
The Davis Besse Technical Specification states the following guidance, in regards control room staffing and minimum shift compliment for operational Modes 1-4:
6.2.2.c - At least two licensed operators, one of which has a Senior Reactor Operators license shall be present in the control room while in Modes 1, 2, 3, or 4; and 6.2.2.a - Each duty shift shall be comprised of at least the minimum shift crew composition shown in Table 6.2-1.
Per Table 6.2-1, the minimum shift crew composition for Modes 1 - 4, consists of :
2 Senior Reactor Operators (SRO) 2 Licensed Operators 2 Non-Licensed Operators 1 Shift Technical Advisor (STA)
The table has guidance that one of the two individuals filling the SRO positions may also assume the STA function provided the individual meets the qualifications for the combined SRO/STA position specified for Option 1 of the Commissions Policy Statement on Engineering Expertise on Shift. If this option is used for a shift, then the separate STA position may be eliminated for that shift.
The Operations Manager, Mike Roder, informed me that they do not plan to routinely utilize the dual role SRO/STA option. The current plan is to man a five shift rotation in operation during/post plant restart. The current list of individuals that are qualified STA is as follows:
Eric Horvath (STA)
Paul Wadsworth (STA)
Bill Bentley (STA)
Bob Lakis (STA)
Randy Patrick (STA)
Charlie Steenbergen (SM and STA)
Of this group, Paul Wadsworth is currently on rotation with Radiation Protection, but is current with all his crew training. Bill Bentley has taken a job outside of operations and does not plan on maintaining his license or STA qualification.
During Operation in Modes 1-4, the Davis-Besse operations shift composition includes 4 SROs; Shift Manager, Unit Supervisor, Field Supervisor, and Shift Engineer (or STA). If a something happened that would require implementing the dual SRO/STA option, the Shift Manager would be the individual tasks to assume those roles.
The licensee has three SROs in the pipeline that are currently pursuing STA qualifications.
This would result in having approximately 7 to 10 qualified individuals available near term to man a 5 shift rotation.
This NRCs position on options for the implementation of the STA position is well documented in the following:
Information Notice 91-11 Information Notice 91-77 Information Notice 93-81 Generic Letter 86-04 NUREG 0737 NUREG 0578 Federal Register Notice, Dated 10/28/85 Commission Policy Statement on Engineering Expertise on Shift, dated 10/28/85 SECY-85-150 The licensee has an adequate number of qualified STAs to man a 5 shift rotation and are implementing the STA position IAW with their Technical Specification.
INSPECTION PLAN DAVIS-BESSE ELECTRICAL ISSUES INSPECTION Feeder for the Corrective Action Implementation Team Inspection Inspection Report Number 50-346/03-10 (DRS)
Inspection Objectives This inspection will determine the effectiveness of the corrective action process in identifying, correctly assessing, and promptly correcting specific electrical related issues at Davis-Besse.
The items that will be inspected relate to the Emergency Diesel Generators (EDGs), the ETAP (Electrical Transient Analyzer Program) load flow calculations, Instrument Uncertainty, and 10 CFR 50, Appendix R Safe Shutdown Analysis. Emphasis will be placed to ensure that the corrective actions are consistent with and maintain the design basis and license basis of Davis-Besse. This inspection will also review the progress, and, if possible, close the following Restart Action Matrix Open Items:
1.
C Electrical Distribution System Analysis (coordination, load flow, degraded voltage, fault protection, and ampacity);
2.
C Instrument Uncertainty Calculations; 3.
C Appendix R Thermohydraulic calculations and safe shutdown procedure; 4.
C Emergency Diesel Generator voltage/frequency control and room temperature.
The team will use this inspection plan and applicable portions of inspection procedures 71152 (Identification and Resolution of Problems) and 93812 (Special Inspection) as guidance for conducting this inspection. The inspection will be accomplished by direct observation, review of records and interface with personnel. The results of this inspection will be documented in the CATI (50-346/03-10 (DRS)).
Onsite Inspection Dates:
July 7 - 11, 2003 and July 14 -18, 2003 Applicable Inspection Procedures IP 71152 "Identification and Resolution of Problems" IP 93812 Special Inspection Prepared By:
Bob Daley, Inspector Date
Reviewed By:
DRS Branch Chief Date Reviewed By:
C. Lipa, DRP Branch Chief Date Approved By:
Jack Grobe, Chairman Date Oversight Panel
INSPECTION PLAN DETAILS I
Inspectors:
R. Daley, Team Leader One Electrical Consultant II Detailed Inspection Schedule Residents and Licensee Informed of Inspection: June 17, 2003 Inspection Preparation at Region III Offices: As time permits from June 9, 2003 through July 3, 2003 Onsite Inspection Time: July 7 - 11, 2003 and July 14 -18, 2003 Inspection Report Input to CATI Completed by: August 15, 2003 III Specific Inspection Activities:
The team will inspect the following Davis-Besse Design Areas:
Emergency Diesel Generator Issues Restart Action Matrix Open Item C-32, Emergency Diesel Generator voltage/frequency control and room temperature.
LOOP/LOCA Loading Transient Analysis (ETAP)
Steady State Load Table and Calculation
EDG Voltage and Frequency response
EDG Room temperature - EQ, ampacity Applicable CRs:
CR 02-05039
CR 02-05364
CR 02-05383
CR 02-05385
CR 02-05627
CR 02-05628
CR 02-05632
CR 02-05848
CR 02-05922
CR 02-05925
CR 02-06757
AC Systems Restart Action Matrix Open Item C-26, Electrical Distribution System Analysis (coordination, load flow, degraded voltage, fault protection, and ampacity) and C-30, Instrument Uncertainty Calculations.
NOTE: ETAP calculation review will be limited to those calculations that are most significant from a design and license basis perspective.
ETAP assumptions (loading)
Equipment ratings Input values
ETAP calculation and results Normal plant operations DBA with offsite power available
Specific ETAP issues Breaker and fuse coordination, including short circuit studies MOV capability Voltage drop UV (59 percent and 90 percent) relay setpoints
Instrument Uncertainty - (Not accounted for in certain calculations)
Steam and Feedwater Rupture Control System - Trip setpoint for reverse dp AFW - Pump flow acceptance criteria HPI - Flow calculation Condition Reports Applicable CRs:
CR 02-06305
CR 03-00565
CR 03-00575
CR 03-00585 Fire Protection Safe Shutdown Analysis (Appendix R)
Restart Action Matrix Open Item C-31, Appendix R Thermal Hydraulic calculations and safe shutdown procedure.
Appendix R Issues will only be inspected to the extent of those items directly impacted by the new revision to the Thermal Hydraulic Calculation. The inspection will include a review of the Thermal Hydraulic calculation. The impact of that calculation on the Appendix R Safe Shutdown Analysis and related Appendix R procedures will be evaluated.
Condition Reports listed above to be reviewed during this inspection were determined based upon the list of CRs already being reviewed by the CATI. However, this inspection is neither bound by or limited to the review of these specific CRs. The CRs above are a list of the Condition Reports from the CATI that appear to be applicable to this inspection effort.
IV RITS and Time Charge Information This is a special inspection with an allotted time of 80 hours9.259259e-4 days <br />0.0222 hours <br />1.322751e-4 weeks <br />3.044e-5 months <br /> (+/-30) hours of direct inspection effort. Preparation, inspection, and documentation will use the SEP, ER, or SED time codes.
V Documentation of Findings The report will be prepared in accordance with the guidance in MC 0612 and regional guidance. Any findings resulting from the inspection will be reviewed under the significance determination process, as appropriate. Findings other than green shall be coordinated with the SRA.
VI Interface and Coordination Meetings The entrance meeting will be held at 3:00 P.M. on Monday, July 7, 2003. An exit meeting will be held at 8:00 AM on Friday, July 18, 2003. Other meetings with the licensee will be held as appropriate, based on inspection findings.
INSPECTION PLAN RESTART ASSESSMENT TEAM INSPECTION Davis-Besse Nuclear Power Station Inspection Report Number 50-346/2003011(DRP)
(Do not share this Inspection Plan with the licensee)
Inspection Objectives The objective of this inspection is to (1) Verify that the plant is ready to be operated safely and in conformance with regulatory requirements; (2) Verify that the organizations that control and support plant operations, including operations, maintenance, work control, management oversight, technical support, safety review, quality assurance, and the corrective action organizations are functioning effectively to ensure operational safety; (3) Verify that the licensee has properly prepared the staff and the plant for resumption of power operations after an extended shutdown.
At the conclusion of this inspection, the team will present its findings to the Davis-Besse Oversight Panel. The NRC will use the findings from this inspection as input for the staffs restart readiness assessment.
Inspection Dates:
TBD/Approach to 2nd Mode 4 Through Mode 2 EXIT:
To Be Determined Applicable Inspection Procedures IP 93812, Special Inspection IP 93802, "Operational Safety Team Inspection" Prepared by:
David G. Passehl Date Project Engineer Reviewed by:
Christine A. Lipa, Chief Date Reactor Projects Branch 4 Approved by :
John A. Grobe, Chairman Date Davis-Besse Oversight Panel
INSPECTION PLAN DETAILS I.
Inspectors D. Passehl, Team Leader 3-4 OL/SRI/RI 1-2 RI (Davis-Besse)
II Detailed Inspection Schedule Preparation and Inspection Activities Team Inspection Preparation at Region III offices: TBD Entrance Meeting: TBD On-site Inspection Weeks: TBD/Approach to 2nd Mode 4 Through Mode 2 Exit Meeting: TBD Licensee Contacts Davis-Besse Lead: Mike Roder (ext. 7951)
Regulatory Interface Lead: Gerry Wolf (ext. 8114); Gary Becker (Support)
Inspection Documentation Inputs Due: TBD Draft Completed: TBD Management Review and Approval Completed (target): TBD An inspection report must be issued by 45 days from the exit III.
Inspection Objectives This inspection is scheduled to precede the Davis-Besse reactor restart from an extended outage. During this inspection, emphasis will be placed on the effectiveness of the licensees operations activities to ensure the safe operation of the plant, including the effectiveness of other organizational components in supporting operations. In general, the identification of programmatic deficiencies should be a by-product of the examination of the licensees safety significant performance problems, including the evaluation of test data and any exceptions taken to test acceptance criteria.
The Davis-Besse Oversight Panel developed a Restart Action Matrix (RAM) which identifies items requiring review and closure. The RAM assigned to the RATI is:
SUP-35 (IP95003 02.03.c 2.a) - Assessment of Performance in the Reactor Safety Strategic Performance Area: Key Attribute - Human Performance:
Review specific problem areas and issues identified by inspections to determine if concerns exist in organizational practices such as pre-job briefings, control room team work, shift turnover, self-checking and procedural use and adherence.
IV.
Team Inspection Plan A list of documents to be provided prior to the inspection is included at the end of this plan. The detail and depth of coverage in each area will be dependent upon actual licensee activities being performed during the inspection and any issues or findings identified during the inspection.
In preparation for this inspection the team will evaluate how operations department personnel performed during significant operational events that have occurred over the last two months (e.g., ILRT, NOP). In addition, this inspection will incorporate the conclusions of the Management and Human Performance Phase 3 inspection teams assessment of the licensees restart readiness review meeting, to allow for an integrated assessment of the plants readiness to resume operation.
A.
OPERATIONS The overall goal of this assessment is to verify that the plant operations department is prepared to conduct a safe startup and continued plant operations. The RATI will make this assessment by evaluating the effectiveness of several operations management control processes and directly observing shift operations. The RATI will conduct inspection activities during plant evolutions both during day and backshift periods in a 72-hour continuous control room observation period. The start of the continuous control room observation period will occur during the oncoming midnight shift. Three shifts will be assigned for 2300 - 0700 hrs, 0700 - 1500 hrs, and 1500 - 2300 hrs.
Inspectors who are assigned to the control room (below) will document their observations on the attached "Control Room Inspectors Log." This will be done during the actual time on shift. Oncoming inspectors will review the previous log entries as part of their turnover. The operations observations will be integrated and summarized to support the licensee daily debriefs and the exit meeting. These logs will be the primary basis for report documentation. As such, observations will be documented in sufficient detail to support entry into an inspection report and in the table in the back of the report.
For example, procedures observed need to be fully described, with the name, title, revision, etc. Issues with specific operators need to include their name and title/position during the shift. Positive and negative observations are to be recorded. Use extra sheets if necessary. Negative observations need to be completely described with supporting/reference information.
A.1 Control Room
Assess the effectiveness of shift turnovers. Determine if adequate time is allotted for the conduct of turnovers and if control room documentation (e.g., shift logs and night orders) is useful and available.
Verify that operating shift staffing is adequate to support plant restart. Determine the qualification and license status of on-shift operators. Ensure that the Technical Specification requirements controlling overtime and minimum shift staffing are satisfied.
Assess the quality of the shift supervision and control room Senior Reactor Operators command and control. Evaluate access control and traffic in the control room.
Determine whether collateral duties of the operators (e.g., filling out tag-outs and interfacing with maintenance and surveillance test performers) have an adverse effect on their ability to operate the plant safely.
Assess operator professionalism and communications within the control room.
Determine the effectiveness with which operations appropriately controls support activities in progress, including maintenance, troubleshooting, and testing activities which can potentially influence plant operations.
Determine the availability and currency of normal and abnormal operating procedures in the control room, including alarm response procedures. Evaluate procedure usage/adherence by operators against the licensees standards and expectations.
Determine if the licensees process to revise and control procedures encourages or discourages identification and correction of procedure deficiencies.
Verify that control room drawings are current approved revisions.
Determine whether operator training, including simulator usage, includes appropriate core characteristics and system response. Through operator interviews, control room observations, and review of alarm response procedures, establish whether shift personnel are prepared to properly respond to abnormal plant conditions, instrumentation and control (I&C) set point and display anomalies, and the potential for a high number of challenges to safety systems during testing. Determine if operator training has been provided on recently modified systems or components where the equipment may be expected to operate differently than before modification.
Verify that equipment, including equipment required by Technical Specifications, secondary and support systems, is operable to support the current plant condition, pending mode changes, and power operations.
By accompanying control room operators and by reviewing operations logs, verify that log-keeping standards and implementation are adequate to support plant restart.
Assess the adequacy of annunciator response, number of continuously lit annunciators, and response to out of service equipment and components.
Evaluate the status of control room annunciators, alarms, and recorders. Verify the acceptability of the licensee's methodology for compensatory measures for those indications not operating properly.
Evaluate control room/plant operator awareness of equipment status. Walk down portions of selected safety systems and evaluate the licensee's configuration control practices. Confirm that valve and breaker positions conform to procedure requirements and that positions required by procedure are consistent with those on controlled plant drawings and system lineup procedures.
Assess the ability of the plant staff to identify, prioritize, and resolve plant deficiencies.
Coordinate with other RATI inspectors to evaluate engineering/technical issues, concerns, or operability determinations.
Assess any outstanding control room and plant deficiencies to determine if the current available plant equipment can appropriately support a safe plant restart. This should include an assessment of acceptability of the existing operator workarounds.
Select two recent required reading documents and familiarize yourself with their contents. By questioning and discussing these documents with on-shift reactor operators and senior reactor operators, assess the effectiveness of the required reading program.
A.2 Field Operator Tours
Accompany an auxiliary operator during routine rounds. Verify plant equipment status, concerns, or operability determinations. Review the field operators logs and verify that log-keeping standards and implementation are adequate to support plant restart.
Determine and evaluate the field operators knowledge of significant system modifications implemented during the extended outage. Verify that the operators have been adequately trained to successfully operate the modified systems.
Assess the adequacy of housekeeping, radiological controls, lighting, equipment labeling, and vital area access controls.
Assess the ability of operators to observe areas secured as a result of radiation levels.
A.3 Equipment Status (Configuration Management)
Verify adequacy of system lineups for service water, auxiliary feedwater, decay heat removal, and the emergency power distribution systems. Use system P&IDs and procedure checklists. Include within the scope instrument root valves, transmitters, indicators, etc., to verify proper alignment, labeling, etc.
Select one or more safety system tag-outs for inspection. Determine if the tag-out is adequate for the work to be accomplished. Verify that operators are thorough in tagging and isolating plant equipment. Verify that tags are properly hung and equipment has been placed in the designated position. Determine if equipment status changes and corresponding entry into or exit from Technical Specification Action Statements are appropriately documented. Determine if the licensee has adequate controls to ensure the independent verification of equipment status, particularly when equipment is returned to service. Assess the adequacy of operability verification testing when returning equipment to service.
Review jumper, lifted lead, and other temporary modification logs. Determine (1) if an adequate technical review was performed before the plant modification was performed, and (2) if plant drawings were updated, as needed, to reflect the change before operators must operate the plant as changed. Temporary modification reviews should include an assessment of the licensee's root cause analysis process and thoroughness of 10 CFR 50.59 evaluations. The licensee's controls for limiting the duration of temporary modifications should be reviewed. Assess the role of the plant, system, and design engineering groups in the temporary modification process.
A.4 Operations Quality Assurance and Self-Assessments Review Operations Department, restart and power ascension plan assessments, and verify that safety significant issues that could impact a safe plant restart have been addressed.
Assess the effectiveness of the Quality Assurance (QA) organizations involvement in operations. Verify that the QA identified issues are being tracked and resolved by the plant staff in a timely manner.
Verify those significant QA audit findings, with potential plant restart implications, have been adequately resolved.
B.
MAINTENANCE AND SURVEILLANCE TESTING B.1 Maintenance
Verify that maintenance jobs that could affect Technical Specification Limiting Conditions for Operation or safety-related equipment performance, or otherwise influence the safe operation of the plant, are appropriately prioritized and dispositioned in a timely manner.
Verify that maintenance activities are coordinated with control room operations and that appropriate briefings and turnovers are held with control room operators.
Verify that the maintenance is performed in accordance with current written and approved instructions that are detailed enough to perform the intended maintenance and adequately document the maintenance performed. Also review a sample of completed work packages and machinery history records and verify that they demonstrate these same attributes.
Review the maintenance training program and selected craftperson's training records to verify that training is adequate and appropriate for the level of work being performed by that individual.
Review licensee performance in conducting preventive maintenance activities on schedule and in exercising appropriate control over deferred preventive maintenance.
Determine the nature and extent of the licensee's backlog of corrective and preventive maintenance, especially concerning equipment of high safety significance. Assess the licensee's efforts to integrate preventive and corrective maintenance to minimize equipment unavailability. Identify licensee efforts to reduce the corrective maintenance and preventive maintenance deferrals.
Assess the adequacy and implementation of the preventive maintenance program through the selection and examination of several safety significant components or components for which machinery history indicates high corrective maintenance frequency.
Assess the adequacy of trending of corrective maintenance history and measures to deal with high maintenance components. Maintenance history and trending should support the identification and correction of repetitive work.
Determine if engineering input into maintenance activities is at an appropriate level to ensure safe and reliable plant operations.
Determine whether quality control (QC) inspections are being conducted during the performance of maintenance and whether the number and nature of QC inspections are adequate to contribute to effective maintenance.
Determine if specific guidance exists with regard to designation of QC hold points and that the guidance is being effectively applied.
Determine if appropriate post-maintenance testing is being specified following the conduct of maintenance activities and that there is involvement of engineering in specifying the tests when appropriate.
Observe activities and review documents related to the licensees control of measuring and test equipment. Verify that calibrations are being performed at the required frequencies and that the program includes a tracking system so that when measuring and test equipment are found to be out of calibration, an evaluation is made and documented of the validity of previous inspection or test results and of the acceptability of items previously inspected or tested. Verify that appropriate measures are identified and employed to handle, store, and distribute contaminated test and measurement equipment.
B.2 Surveillance Testing
Observe a number of surveillance tests being performed by licensee personnel in the mechanical, electrical, and instrumentation and control maintenance groups and verify that:
Required administrative approvals were obtained before testing was started and, when appropriate, entry into Technical Specification action statements was documented.
Testing is being accomplished by qualified personnel in accordance with current and approved procedures that are adequate to meet Technical Specification requirements.
Test instrumentation is calibrated and properly used.
Procedures are adequate to satisfy the test requirements of the Technical Specification surveillances.
Test results meet technical specification acceptance criteria.
Test discrepancies or problems are documented and properly resolved in a timely manner.
Surveillance testing is completed within the required technical specification frequency.
Review a sample of completed surveillance tests. Determine if the test procedures used are of the correct revision and are technically accurate and if qualified personnel adequately tested the designated equipment. Determine if the acceptance criteria are clearly specified and shown to have been met in the tests reviewed. Where discrepancies are noted, determine if they have been adequately evaluated and if any required corrective actions have been initiated.
C.
ENGINEERING AND TECHNICAL SUPPORT
By interviewing personnel and reviewing documents related to equipment performance problems, evaluate the effectiveness of the technical staff, including plant, technical, and design engineers, in supporting safe operation of the plant. Verify that the work backlog is manageable and that items that could affect safety are given a high priority and are addressed in a timely manner.
Evaluate the effectiveness of system engineers (when applicable) to determine the extent that:
The system engineer has received classroom training and practical experience on the systems assigned that individual.
The system engineer is active and involved in the performance of the assigned system(s) and components and communicates effectively with operations, maintenance, and other engineering groups.
System engineers effectively coordinate with design engineering to evaluate and improve system performance and safely modify the system when required.
Inspect a sample of completed modifications and review the conduct and adequacy of any additionally required operator training, the need for updating operating and emergency procedures, the adequacy of post-modification testing, and the proper control of affected drawing revisions to include the issuance of updated drawings to all controlled drawing areas (e.g., control room, technical support center, and emergency operations facility) before making the modification operational.
By review of selected modification packages determine the effectiveness of the licensees efforts to meet its licensing commitments and to preserve the design basis.
Through observations during the inspection assess the licensees concern for control over plant configuration by attempting to identify unauthorized or undocumented modifications to plant equipment. This review should include:
Identification of all temporary modifications currently in place and an assessment of their impact upon the plants approved design configuration including appropriateness of the installation duration.
Review of selected field change requests (FCRs) and nonconformance reports (NCRs) to ensure that an appropriate and timely evaluation, and where necessary, a corrective action has been completed.
Ensure that the 10 CFR 50.59 safety evaluations have been prepared or reviewed by engineering personnel familiar with the technical basis of the associated licensing commitments.
Review the backlog of design changes (DCs) to be installed. Ensure that safety evaluations of other later DCs appropriately consider the status of related and yet to be installed DCs.
Review the technical basis of selected DCs to ensure that all multi-disciplinary licensing commitments are met and a documented technical basis exists for the DC.
Verify that the corrective action associated with NCRs, as well as DCs, address the root cause of the initiating concern, and are not addressing merely the proximate cause or a symptom.
Review the FCNs associated with selected DCs to ensure that a modification is not engineered by FCN. Design changes should not have an excessive number of FCNs written against them.
Review DCs to ensure that appropriate and timely changes have been made to Emergency Operating Procedures (EOPs), off normal response procedures, or maintenance, surveillance, and test procedures.
Review a select number of DCs to verify the proper procedural steps were taken to declare a modification operable, and verify appropriate operator training was performed.
Review temporary modifications to verify proper 10 CFR 50.59 review and appropriate involvement of the onsite safety review committee.
Review maintenance records to verify changes to design were not made under maintenance requests.
Assess the communication interface between operations, maintenance, and engineering. Verify that appropriate engineering guidance is requested and obtained to resolve technical problems. Assure that such guidance is accurate, complete, and technically correct and that it is incorporated into a corrective action plan.
V Issues and Findings The Risk Informed Inspection Notebook and the Significance Determination Process (SDP) for Davis-Besse Nuclear Power Station have been developed and approved.
Inspectors will address the questions of Manual Chapter 0612 and process the finding through Phase 2 of the SDP as necessary. Green findings will be documented in the
inspection report. Findings that appear to be "other than green" will be immediately discussed with the team leader, the licensee and the senior reactor analyst, to ensure that Davis Besse PRA information is correctly considered. Enforcement action for green or non-SDP issues will be handled in accordance with the Enforcement Policy.
Unless an issue can be shown to be greater than minor, additional inspection time should not be spent. If an issue appears greater than minor, then sufficient questions need to be asked of the licensee to enable the inspectors to confirm any assumptions and complete the Phase 1 and 2 worksheets. If a color cannot be determined by the end of the inspection, the issue will be described as an "unresolved item," pending final determination of the appropriate risk significance. Some flexibility will be allowed for documenting non-green observations due to the nature of the inspection.
VI Documentation Inspection findings normally result in a number of questions being raised. These questions are to be given to the licensee verbally or, if written, the licensee must copy the information and the inspector must retain the written document. As part of the daily interfaces with the licensee, the team leader will go over the status of outstanding questions. Therefore, the team members need to keep the team leader informed of any concerns with timeliness or quality of responses to questions. Lack of response to questions will not be accepted as a reason for any delay in providing an input unless the team leader has been informed prior to the exit and the issue is one that will necessitate a writeup in the report. Any document requests generated on the day of the exit or afterwards must be approved by the team leader, must pertain to areas already inspected, and must be only for the purpose of ensuring an accurate document list entry.
Issues which the inspector deems meet the criteria for report writeups will be discussed with the team lead prior to preparing an input. Inputs are to be e-mailed to the team lead within 5 working days (7 calendar days) of the exit. All documents critically/deliberately reviewed will be included in the document list. Corrective action documents generated as a result of the inspector's questions will be listed separately from corrective action documents that were in the licensee's system prior to the inspection.
VII Interface and Coordination Meetings Meetings with the Licensee Status meetings will be held each day during the inspection. Daily debriefings with the licensee will start on DATE. Team members are not expected to attend the daily debriefs unless there are significant or complex issues. An expanded debrief will be held with the licensee (excluding management) on the day prior to the exit meeting. All inspectors are expected to attend the expanded debriefing unless there are extenuating circumstances.
Exit Meeting The team leader will conduct the exit meeting on DATE. Unless there are extenuating circumstances, team members will need to attend the final exit meeting and be prepared to answer any questions that may be raised by the licensee. Team members are expected to provide the team leader with a summary of findings for use at the exit meeting.
VIII Starfire Information This special inspection is estimated to require approximately 350 (+/- 50) hours of direct inspection effort. Approximately 75 percent of these hours should be spent as direct inspection. Charge to IP 93812 with IPE code of ER. Preparation and documentation for this inspection will use IPEs, SEP, SED, respectively.
IX General Information Travel Charges All travel time is to be charged in HRMS to an IPE code of "AT."
Overtime Overtime will be approved to accomplish the objectives of the inspection. Any overtime spent traveling (although there shouldn't be any) also must be claimed in HRMS using the overtime code of "ADDLT".
Attachment Control Room Inspectors Log Inspector:
Date:
Shift:
Attribute Assessment Assess the effectiveness of shift turnovers.
Determine if adequate time is allotted for the conduct of turnovers and if control room documentation (e.g., shift logs and night orders) is useful and available.
Verify that operating shift staffing is adequate to support plant restart. Determine the qualification and license status of on-shift operators. Ensure that the Technical Specification requirements controlling overtime and minimum shift staffing are satisfied.
Assess the quality of the shift supervision and control room Senior Reactor Operators command and control. Evaluate access control and traffic in the control room. Determine whether collateral duties of the operators (e.g., filling out tag-outs and interfacing with maintenance and surveillance test performers) have an adverse effect on their ability to operate the plant safely.
Assess operator professionalism and communications within the control room.
Determine the effectiveness with which operations appropriately controls support activities in progress, including maintenance, troubleshooting, and testing activities which can potentially influence plant operations.
Determine the availability and currency of normal and abnormal operating procedures in the control room, including alarm response procedures.
Evaluate procedure usage/adherence by operators against the licensees standards and expectations.
Determine if the licensees process to revise and control procedures encourages or discourages identification and correction of procedure deficiencies.
Verify that control room drawings are current approved revisions.
Attachment Control Room Inspectors Log Inspector:
Date:
Shift:
Determine whether operator training, including simulator usage, includes appropriate core characteristics and system response. Through operator interviews, control room observations, and review of alarm response procedures, establish whether shift personnel are prepared to properly respond to abnormal plant conditions, instrumentation and control (I&C) set point and display anomalies, and the potential for a high number of challenges to safety systems during testing. Determine if operator training has been provided on recently modified systems or components where the equipment may be expected to operate differently than before modification.
Verify that equipment, including equipment required by Technical Specifications, secondary and support systems, is operable to support the current plant condition, pending mode changes, and power operations.
By accompanying control room operators and by reviewing operations logs, verify that log-keeping standards and implementation are adequate to support plant restart.
Assess the adequacy of annunciator response, number of continuously lit annunciators, and response to out of service equipment and components.
Evaluate the status of control room annunciators, alarms, and recorders. Verify the acceptability of the licensees methodology for compensatory measures for those indications not operating properly.
Evaluate control room/plant operator awareness of equipment status. Walk down portions of selected safety systems and evaluate the licensees configuration control practices. Confirm that valve and breaker positions conform to procedure requirements and that positions required by procedure are consistent with those on controlled plant drawings and system lineup procedures.
By directly observing operator activities, assess the ability of the plant staff to identify, prioritize, and resolve plant deficiencies. Coordinate with other RATI inspectors to evaluate engineering/technical issues, concerns, or operability determinations.
Attachment Control Room Inspectors Log Inspector:
Date:
Shift:
Assess any outstanding control room and plant deficiencies to determine if the current available plant equipment can appropriately support a safe plant restart. This should include an assessment of acceptability of the existing operator workarounds.
Select two recent required reading documents and familiarize yourself with their contents. By questioning and discussing these documents with on-shift reactor operators and senior reactor operators, assess the effectiveness of the required reading program.
Additional Comments:
List of Documents Request 1.
Site organizational charts 2.
Copies of detailed work schedule for the two weeks onsite (planned operations evolutions, maintenance and surveillance testing) 3.
Access to a copy of EOPs, abnormal procedures, IPE, TS, USAR, TS interpretations, system descriptions (accessible from work area at site) 4.
Listing of points of contacts and phone numbers for personnel in Operations, Maintenance, Engineering, Operator training, and Quality Assurance (including system engineers for systems listed in 15) 5.
Administrative/Operations procedures governing:
Procedure Use and Adherence
Conduct of operations
Control room operator and SS Logkeeping
Standards/expectations on communications, panel walkdowns, shift briefings
Initiation of a work order, isolation of equipment, post maintenance testing control, return to service/operations
Corrective Action Program procedure
System configuration controls
Jumper/Bypass/Temporary Modifications
Locked Valve and Breaker Program
Independent Verification
Operator Workarounds
Reactivity management 6.
Power ascension test schedule 7.
Copies of station or Operations long term operational objectives/ operating plan (if one exists) 8.
Plant Startup and Operations procedures, (from cold S/D thru full power Ops, including dilution to ECP, approach to criticality, etc.)
9.
TS required operations surveillances - hourly, shiftly, and daily completed copies of each for a day when the plant was last operated at 100 percent power and blank copies of each to be taken when the plant returns to Mode 1 operation 10.
Log sheets for all operator tours outside of the control room:
completed copy for a day when the plant was last operated at 100 percent power
completed copy for a recent day in the plants current mode
blank copy of logs to be taken when the plant returns to Mode 1 operation 11.
Last 21 days of Control Room Narrative Logs
12.
List of Operator workarounds and control room deficiencies (as of 2 weeks prior to inspection) 13.
List of outstanding jumper/bypass/temporary modifications (as of 2 weeks prior to inspection) (include system, #, date installed) 14.
List of degraded equipment conditions (as of 2 weeks prior to inspection) 15.
Normal system operating procedures, and valve lineup checklists for the following systems: service water, auxiliary feedwater, decay heat removal, and the emergency power distribution systems.
16.
Planned simulator training schedule and objectives for on-site weeks 17.
List all licensed ROs/SROs. Specify whether license is active or inactive.
18.
Provide copies of shift assignments and schedules 19.
List of open Operability evaluations (GL 91-18 issues) (as of 2 weeks prior to inspection) 20.
List of outstanding safety-related work requests (as of 2 weeks prior to inspection; need minimum: No., description, system; sorted by system) 21.
List of open condition reports (include description) 22.
List of oldest safety-related work requests still open (for all systems; include ID, system, description, date initiated) 23.
Listing of problem reports involving configuration control problems (i.e., components found out of position) for last 6 months and current status 24.
Maintenance Rule system performance indicators/summaries for the last 6 months, for the systems 25.
Copies of last completed surveillance test for the systems listed in 15.
26.
Copies of the most recent run on each diesel generator (include operators logs (local and control room). Also provide DG air-start drawing, air-start logic, and electric control logic.
27.
List of major design changes implemented in last 2 years (include ID, description, affected systems).
28.
List of open and closed conditions adverse to quality/deviation reports/nonconformance reports for last 6 months 29.
Administrative procedure governing self-assessments and performance of QA/PA assessments and audits 30.
List of any self-assessments performed since 1/03 for Ops, Maint, Engr
31.
List of QA surveillances and audits in Ops, Maint, Engr since 1/03 32.
List of findings (condition reports) that resulted from Engineering self-assessments since 1/03 33.
List of QA/PA findings sorted by functional areas 34.
System Final Readiness Review Reports for systems in 15 35.
System Restart Deferred Items/Justification Lists for systems in 15 (if there are any) 36.
System Readiness Review Restart Procedure for systems in 15 37.
Administrative/engineering procedures for design changes and 10 CFR 50.59 safety evaluations 38.
Containment close-out inspection procedure and results (if already performed)