IR 05000321/2007004

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Download: ML073030452

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October 30, 2007

Southern Nuclear Operating Company, Inc.ATTN:Mr. Dennis R. MadisonVice President - HatchEdwin I. Hatch Nuclear Plant 11028 Hatch Parkway North Baxley, GA 31513

SUBJECT: EDWIN I. HATCH NUCLEAR PLANT - NRC INTEGRATED INSPECTIONREPORT 05000321/2007004 AND 05000366/2007004

Dear Mr. Madison:

On September 30, 2007, the U. S. Nuclear Regulatory Commission (NRC) completed aninspection at your Edwin I. Hatch Nuclear Plant, Units 1 and 2. The enclosed integrated inspection report documents the inspection results, which were discussed on October 11, 2007, with you and other members of your staff.The inspection examined activities conducted under your license as they relate to safety andcompliance with the Commission's rules and regulations and with the conditions of your license.

The inspectors reviewed selected procedures and records, observed activities, and interviewed personnel. The enclosed inspection report documents one self-revealing finding of very low safetysignificance which was determined to be a violation of NRC requirements. Additionally, one licensee-identified violation, which was determined to be of very low safety significance, is listed in the report. NRC is treating these violations as non-cited violations (NCVs) consistent with Section VI.A.1 of the NRC Enforcement Policy because of the very low safety significance and because you have entered them into your corrective action program. If you deny these NCVs, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the Nuclear Regulatory commission, ATTN.: Document Control Desk, Washington, DC 20555-0001; with copies to the Regional Administrator, Region II; the Director,Office of Enforcement, United States Nuclear Regulatory Commission, Washington, DC 20555-

001; and the NRC Resident Inspectors at the Hatch Nuclear Plant.

SNC2In accordance with 10 CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter, itsenclosures, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of the NRC's document system (ADAMS). ADAMS is accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).

Sincerely,/RA/Scott M. Shaeffer, ChiefReactor Projects Branch 2 Division of Reactor ProjectsDocket Nos.:50-321, 50-366License Nos.:DPR-57 and NPF-5

Enclosure:

Inspection Report 05000321/2007004 and 05000366/2007004

w/Attachment:

Supplemental Informationcc w/encl: (See page 3)

SNC2In accordance with 10 CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter, itsenclosures, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of the NRC's document system (ADAMS). ADAMS is accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).

Sincerely,/RA/Scott M. Shaeffer, ChiefReactor Projects Branch 2 Division of Reactor ProjectsDocket Nos.:50-321, 50-366License Nos.:DPR-57 and NPF-5

Enclosure:

Inspection Report 05000321/2007004 and 05000366/2007004

w/Attachment:

Supplemental Informationcc w/encl: (See page 3)X PUBLICLY AVAILABLE G NON-PUBLICLY AVAILABLEG SENSITIVE X NON-SENSITIVEADAMS: X YesACCESSION NUMBER:_________________________OFFICERII:DRPRII:DRPRII:DRPRII:DRPRII:DRSRII:DRSSIGNATURESMS /RA for/SMS /RA/JAH /via email/PKN /via email/SJV /via email/JYQ /via email/NAMECRappSShaefferJHickeyPNiebaumSViasJ. Quinones-NavarroDATE10/30/200710/30/200710/30/200710/30/200710/30/200710/30/2007 E-MAIL COPY? YESNO YESNO YESNO YESNO YESNO YESNO YESNO OFFICIAL RECORD COPY DOCUMENT NAME: C:\FileNet\ML073030452.wpd SNC3cc w/encls:J. T. Gasser Executive Vice President Southern Nuclear Operating Company, Inc.

Electronic Mail DistributionDavid H. JonesVice President - Engineering Southern Nuclear Operating Company, Inc.

P.O. Box 1295 Birmingham, AL 35201-1295 L. M. StinsonVice President , Fleet Operations Support Plant Hatch Southern Nuclear Operating Company, Inc.

Electronic Mail DistributionRaymond D. BakerManager Licensing - Hatch Southern Nuclear Operating Company, Inc.

Electronic Mail DistributionArthur H. Domby, Esq.Troutman Sanders Electronic Mail DistributionLaurence BergenOglethorpe Power Corporation Electronic Mail DistributionMoanica CastonSouthern Nuclear Operating Company, Inc.

Bin B-022 P. O. Box 1295 Birmingham, AL 35201-1295DirectorDepartment of Natural Resources 205 Butler Street, SE, Suite 1252 Atlanta, GA 30334Manager, Radioactive Materials ProgramDepartment of Natural Resources Electronic Mail DistributionChairmanAppling County Commissioners 69 Tippins St., Suite 201 Baxley, GA 31513Resident ManagerOglethorpe Power Corporation Edwin I. Hatch Nuclear Plant Electronic Mail DistributionSenior Engineer - Power SupplyMunicipal Electric Authority of Georgia Electronic Mail DistributionReece McAlisterExecutive Secretary Georgia Public Service Commission 244 Washington Street, SW Atlanta, GA 30334 SNC4Letter to Dennis from Scott M. Shaeffer dated October 30, 2007

SUBJECT: EDWIN I. HATCH NUCLEAR PLANT - NRC INTEGRATED INSPECTIONREPORT 05000321/2007004 AND 05000366/2007004Distribution w/encl:R. Martin, NRR C. Evans, RII L. Slack, RII OE Mail RIDSNRRDIRS PUBLIC EnclosureU. S. NUCLEAR REGULATORY COMMISSIONREGION IIDocket Nos.:50-321, 50-366License Nos.:DPR-57 and NPF-5 Report Nos.:05000321/2007004, 05000366/2007004 Licensee:Southern Nuclear Operating Company, Inc.

Facility:Edwin I. Hatch Nuclear Plant Location:Baxley, Georgia 31515 Dates:July 1 - September 30, 2007 Inspectors:J. Hickey, Senior Resident InspectorP. Niebaum, Resident Inspector S. Vias, Senior Reactor Inspector (Section 1R12)

J. Quinones-Navarro, Reactor Inspector (Section 4OA5.2)Approved by:Scott M. Shaeffer, ChiefReactor Projects Branch 2 Division of Reactor Projects Enclosure

SUMMARY OF FINDINGS

IR 05000321/2007-004, 05000366/2007-004; 07/1/2007-09/30/2007; Edwin I. HatchNuclear Plant, Units 1 and 2, Event FollowupThe report covered a three-month period of inspection by resident inspectors. OneGreen non-cited violation was identified during this inspection period. The significance of most findings is indicated by their color (Green, White, Yellow, or Red) using Inspection Manual Chapter 0609, Significance Determination Process (SDP). Findings for which the SDP does not apply may be Green or be assigned a severity level after management review. The NRC's program for overseeing the safe operation of commercial nuclear power reactors is described in NUREG-1649, "Reactor Oversight Process," Revision 4, dated December 2006.A.NRC-Identified and Self-Revealing Findings

Cornerstone: Initiating Events

Green.

A self-revealing non-cited violation (NCV) of 10CFR50 Appendix B, CriterionV, Instructions, Procedures, and Drawings, was identified for inadequate work instructions provided to workers for the calibration of a main generator output recorder. The calibration was performed with the main generator on-line which caused a sensed power load unbalance (PLU) resulting in a reactor scram.This finding is greater than minor because it is associated with EquipmentPerformance attribute and adversely affected the Initiating Events cornerstone objective in that it resulted in a challenge to safety functions at power. The finding was determined to be of a very low safety significance because no other mitigating equipment or functions were adversely affected. The inspectors determined this finding was related to the complete and accurate procedures aspect of the human performance cross-cutting area (H.2c). The licensee has entered this issue their corrective action program (CAP) as Condition Report (CR) 2006104201. (Section 4OA3.3 )

B.Licensee-Identified Violations

Violations of very low safety significance, which were identified by the licensee, havebeen reviewed by the inspectors. Corrective actions taken or planned by the licensee have been entered into the licensee's CAP. These violations and corrective actions are listed in Section 4OA7 of this report.

Enclosure

REPORT DETAILS

Summary of Plant StatusUnit 1 began the inspection period at or near 100% Rated Thermal Power (RTP). OnAugust 11, power was briefly reduced to 89% due to high balance of plant temperatures.

Unit 1 remained at 100% RTP through the end of the reporting period.Unit 2 began the inspection period at or near 100% RTP. On August 1, power wasbriefly reduced to 91% due to a pole mounted transformer fire. On August 7, a reactor scram occurred due to the loss of the 2D 4KV electrical bus. The unit was returned to service on August 9 and remained at 100% RTP through the end of the reporting period.1.REACTOR SAFETYCornerstones: Initiating Events, Mitigating Systems, and Barrier Integrity1R04Equipment Alignment

a. Inspection Scope

Partial Walkdowns. The inspectors performed partial walkdowns of the following foursystems when the opposite trains were removed from service. The inspectors checked system valve positions, electrical breaker positions, and operating switch positions to evaluate the operability of the opposite trains or components by comparing the position listed in the system operating procedure to the actual position. Documents reviewed are listed in the Attachment.*1A and 2C Emergency Diesel Generators (EDG) while 1B EDG was removed fromservice for breaker maintenance*Unit 1 Core Spray (CS) B system during maintenance on the CS A system

  • Unit 1 Reactor Core Isolation Cooling (RCIC) system while Unit 1 High PressureCoolant Injection (HPCI) system was removed from service for maintenance*1A and 1C EDGs during 1B EDG maintenance to replace a breakerComplete System Walkdown. The inspectors performed a complete walkdown of thefollowing system. The inspectors performed a detailed check of valve positions, electrical breaker positions, and operating switch positions to evaluate the operability of the system or components by comparing the required position in the system operating procedure to the actual position. The inspectors also interviewed personnel and reviewed control room logs to verify that alignment and equipment discrepancies were being identified and appropriately resolved. Documents reviewed are listed in the

.*Unit 1 Residual Heat Removal System (RHR)4Enclosureb.FindingsNo findings of significance were identified.

1R05 Fire Protectiona.Inspection ScopeFire Area Tours.

The inspectors toured the following 12 risk significant plant areas toassess the material condition of the fire protection and detection equipment, verify fire protection equipment was not obstructed and that transient combustibles were properly controlled. The inspectors reviewed the applicable fire zones on Pre-Fire Plan drawing A-43965 to ensure that the necessary fire fighting equipment, such as fire extinguishers, hose stations, ladders, and communications equipment, were in place. Documents reviewed are listed in the Attachment.*Unit 2 Southeast RHR and CS Room*Unit 2 Northeast RHR and CS Room

  • Unit 1 Standby Gas and HVAC room 164'
  • Refueling Floor
  • Unit 2 Chiller Room 164'
  • Unit 2 CRD Pump Room
  • Unit 1 Working Floor and Air Supply Room 203'
  • Unit 2 MG Set Rooms 158'
  • Unit 2 HPCI Pump Room
  • Unit 2 RCIC Pump and Turbine Room
  • Unit 2 Working Floor 158'Fire Drill Observation. The inspectors observed a fire drill conducted on August 28. The inspectors reviewed licensee procedure 34AB-X43-001-1, Fire Procedure, and the drill scenario to verify proper response of the on-shift fire brigade to a simulated fire.

The inspectors checked proper use of protective clothing, self contained breathing apparatus, fire fighting equipment, fire pre-plans, proper fire fighting strategy including smoke removal and fire propagation checks, communications, command and control, and coordination with offsite fire company support. In addition, the inspectors attended the post-drill critique to assess if the licensee identified performance issues were comparable to those identified by the inspectors.b.FindingsNo findings of significance were identified.

5Enclosure1R11Licensed Operator Requalificationa.Inspection ScopeResident Quarterly Observation. The inspectors observed the performance of licenseesimulator scenario LT-SG-51075-01, Torus Level Increase with Success Path/

Feedwater Line Break in the Drywell. The scenario included placing torus cooling in service, HPCI surveillance termination due to high torus level, a feedwater line break in the drywell resulting in an Alert due to high drywell pressure. The inspectors reviewed licensee procedures 10AC-MGR-019-0S, Procedure Use and Adherence, and DI-OPS-59-0896N, Operations Management Expectations, to verify formality of communication, procedure usage, alarm response, control board manipulations, group dynamics, and supervisory oversight. The inspectors attended the post-exercise critique of operator performance to assess if the licensee identified performance issues were comparable to those identified by the inspectors. In addition, the inspectors reviewed the critique results from previous training sessions to assess performance improvement.

b. Findings

No findings of significance were identified.

1R12 Maintenance Effectivenessa.Inspection ScopeResident Review.

The inspectors reviewed the sample listed below associated with risksignificant structures, systems, and components to assess the licensee's implementation of the Maintenance Rule (MR) (10 CFR 50.65) with respect to the characterization of failures and the appropriateness of the associated (a)(1) or (a)(2)classification. For the equipment identified below, the inspectors reviewed operator logs, associated CRs, Maintenance Work Orders (MWO) and the licensee's procedures for implementing the Maintenance Rule. The review was to determine if equipment failures were being identified, properly assessed, and corrective actions established to return the equipment to a satisfactory condition. Documents reviewed are listed in the

.*Unit 1 and 2 Standby Liquid Control System Triennial Evaluation. The inspectors reviewed the licensee's MR periodic assessment,for the period of June 2004 to June 2007, to assess the effectiveness of the assessment and verify that it was issued in accordance with the requirements of 10 CFR 50.65,

"Requirements for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants." The inspectors evaluated the periodic assessment timeliness, balancing of reliability and unavailability, (a)(1) activities, (a)(2) activities, and the use of industry operating experience for the 24-month period covered by the assessment. The inspectors reviewed selected MR activities covered by the assessment period for the Reactor Building HVAC, Station Auxiliary DC Power, and HPCI systems. Additionally, 6Enclosurethe inspectors conducted a plant walkdown to assess the condition of risk-significantplant structures within the MR scope to verify that condition monitoring was adequately performed. The inspectors reviewed selected plant work order data, system health reports, reliability and unavailability monitoring status documents, significant adverse condition investigation reports, MR system scoping documents, and MR expert panel meeting minutes to verify the application of MR requirements. The inspectors also discussed and reviewed relevant corrective action reports, and discussed MR issues with system engineers and licensee management. The inspectors reviewed the most recent MR structures inspection report. Documents reviewed are listed in the

.b.FindingsNo findings of significance were identified.

1R13 Maintenance Risk Assessments and Emergent Work Evaluationa.Inspection ScopeThe inspectors assessed the planning and control for the following five Plan of the Daydocuments listed below to verify that risk assessments were performed prior to

components being removed from service. The inspectors reviewed the risk assessment and risk management controls implemented for these activities to verify they were completed in accordance with licensee procedure 90AC-OAM-002-0, Scheduling Maintenance, and 10 CFR 50.65 (a)(4). For emergent work the inspectors assessed whether any increase in risk was promptly assessed and that appropriate risk management actions were implemented.*July 30 through August 3, Low Voltage Switchyard excavation, 1A Residual HeatRemoval Service Water (RHRSW) Strainer maintenance and 2E11F008 Shutdown Cooling Outboard Isolation Valve Starter maintenance*August 20 through August 24, 1C EDG Battery Charger preventive maintenance, 1AEDG Oil Heater Temperature Switch replacement, Reactor Manual Scram functional testing*July 14 through July 20, 1B Hydrogen/Oxygen Analyzer preventive maintenance, 1BRHRSW Strainer differential pressure instrument tubing replacement, Unit 2 Main Turbine Weekly testing*August 11 through August 16, Unit 1 Analog Transmitter Trip System functional testand calibration, Unit 1 Reactor Core Isolation Cooling relay replacement, Unit 2 Reactor Feed Pump Turbine Testing*September 8 through September 14, Unit 1 HPCI planned outage, Unit 1 Switchyardwork, Unit 2 Switchyard workb.FindingsNo findings of significance were identified.

7Enclosure1R15Operability Evaluationsa.Inspection ScopeThe inspectors reviewed the following five operability evaluations and compared theevaluations to the system requirements identified in the Technical Specifications (TS)and the FSAR to ensure operability was adequately assessed and the system or component remained available to perform it's intended function. Also, the inspectors assessed the adequacy of compensatory measures implemented as a result of the condition. Documents reviewed are listed in the Attachment.*Unit 1 Main Steam Chase steam break vent area obstructions*Unit 2 Main Steam Chase steam break vent area obstructions

  • Fisher Butterfly Valves tapered pin integrity
  • Henry Pratt Butterfly Valve disc integrity
  • EDG Fuel Oil Quality Samplingb.FindingsNo findings of significance were identified.

1R19 Post Maintenance Testinga.Inspection ScopeFor the following seven maintenance activities, the inspectors reviewed the test scope toverify the test demonstrated the work performed was completed correctly and the

affected equipment was functional and operable in accordance with TS requirements.

Following the maintenance activities, the inspectors reviewed equipment status and alignment to verify the system or component was available to perform the required safety function. Documents reviewed are listed in the Attachment.*2G11F004 Drywell Floor Drain Outboard Isolation Valve failed local leak rate test*2T48D343A1 Vacuum Breaker Instrument Air Supply Filter replacement

  • 2T48F319 Drywell Vent Inboard Isolation Valve failed local leak rate test
  • 2C11D0013 Hydraulic Control Unit 18-51 Scram Valve diaphram replacement
  • 1E21F012A1 Spray Line Discharge Relief Valve lift test
  • 1E11F048A RHR Heat Exchanger Bypass Valve motor operator grease inspectionb.FindingsNo findings of significance were identified.

8Enclosure1R22Surveillance Testinga.Inspection ScopeThe inspectors reviewed licensee surveillance test procedures and either witnessed thetest or reviewed test records for the following five surveillances to determine if the scope of the test adequately demonstrated the affected equipment was operable. The inspectors reviewed these activities to assess for preconditioning of equipment, procedure adherence, and equipment alignment following completion of the surveillance. The inspectors reviewed licensee procedure AG-MGR-21-0386N, Evolution and Pre-and Post-Job Brief Guidance, and attended selected briefings to determine if procedure requirements were met. Documents reviewed are listed in the

.Surveillance Tests*34SV-R43-002-1, Diesel Generator 1B Monthly Test*34SV-E21-002-1, Core Spray Valve Operability

  • 34SV-T48-002-1, Suppression Chamber to Drywell Vacuum Breaker Operability andContainment Purge/Vent Valve Position CheckIn-Service Test*34SV-E21-001-1, 1A Core Spray Pump Inservice Test Reactor Coolant System Leakage Test*34SV-SUV-019-1, Drywell Floor Drain Leakageb.FindingsNo findings of significance were identified.

1R23 Temporary Plant Modificationsa.Inspection ScopeThe inspectors reviewed the following two temporary modifications (TMM) and assessedthe evaluation using criteria defined in licensee procedure 40AC-ENG-018-0S,

Temporary Modification Control. In addition, the 10 CFR 50.59 evaluation was assessed using the design basis information provided in the FSAR to verify the modification did not affect the safety functions of this system. The inspectors also verified the modification was installed in accordance with the TMM requirements.*TMM 2-07-003, Restoration of Control Power to Sampling Panel 2P33-P211*TMM 2-07-010, Reactor Feed Pump Vibration Alarm Setpoint Changeb.FindingsNo findings of significance were identified.

9EnclosureCornerstone: Emergency Preparedness1EP6Drill Evaluationa.Inspection ScopeDuring the following emergency plan drill, the inspectors observed licensee activities inthe simulator, Technical Support Center and Operations Support Center to verify implementation of licensee procedure 10AC-MGR-006-0, Hatch Emergency Plan. The inspectors reviewed the classification of the simulated events and the development of protective action recommendations to verify these activities were conducted in accordance with licensee procedure 73EP-EIP-001-0, Emergency Classification and Initial Actions. The inspectors also reviewed licensee procedure 73EP-EIP-073-0, Onsite Emergency Notification, to verify the proper offsite notifications were made. The inspectors attended the post-exercise critique to assess the licensee's effectiveness in identifying areas of improvement. Documents reviewed are listed in the Attachment.*Emergency Plan Drill conducted on July 11, 2007b.FindingsNo findings of significance were identified.4.OTHER ACTIVITIES 4OA2Identification and Resolution of ProblemsDaily Screening of Corrective Action Items. As required by Inspection Procedure 71152,Identification and Resolution of Problems, and in order to help identify repetitive equipment failures or specific human performance issues for follow-up, the inspectors performed a daily screening of items entered into the licensee's CAP. This review was accomplished by either attending daily screening meetings that briefly discussed major CRs, or accessing the licensee's computerized corrective action database and reviewing each CR that was initiated.4OA3Event Followup.1Notice of Unusual Event Due to a Pole Mounted Transformer Firea.Inspection ScopeThe inspectors responded to site for a pole mounted transformer fire in the ProtectedArea that occurred on August 1. The inspector observed the fire location and assessed the potential for impact on adjacent structures. The inspectors reviewed the licensees actions associated with the Emergency Plan activation, forced load reduction of the Unit 2, Fire Team response and compliance with 34AB-R81-001-0 Loss of 12 KV Supplemental Power System.

10Enclosureb.FindingsNo findings of significance were identified..2Unit 2 Scram on Low Reactor Water Level Due to Loss of the 2D Busa.Inspection ScopeThe inspectors responded to the site for a reactor scram that occurred on August 7. The inspectors reviewed operator actions taken in accordance with licensee procedures and reviewed unit and system indications to verify that actions and system responses were as expected. The inspectors discussed the scram with operations, maintenance and licensee management to gauge each groups understanding of the sequence of events. The licensee's investigation revealed that during the installation of a relay cover following calibration, the cover contacted the relay output contacts which caused a loss of the 2D Bus.b.FindingsNo findings of significance were identified..3(Closed) Licensee Event Report 05000366/2006-002, Inadequate Procedure Results in Automatic Reactor Scrama.Inspection ScopeThe inspectors reviewed the results of the investigation and corrective actionsassociated with the LER.b.FindingsIntroduction. A Green self-revealing NCV of 10CFR50 Appendix B, Criterion V,Instructions, Procedures, and Drawings, was identified for inadequate work instructions provided to workers for the calibration of a main generator output recorder. The calibration was performed with the main generator on-line which caused a sensed power load unbalance (PLU) resulting in a reactor scram.Description. On April 5, 2006, Unit 2 was operating at 100% power when the licenseeperformed a calibration of a main generator output recorder. Procedure 57CP-CAL-010-2, Esterline Angus Megavar and KV Recorder, directed the technicians to ground the current transformer (CT) inputs to the recorder. When the technicians grounded the CT inputs, the PLU module sensed a loss of electrical generation. This condition caused a turbine control valve fast closure which then caused a reactor scram.Analysis. This finding is greater than minor because it is associated with EquipmentPerformance attribute and adversely affected the Initiating Events cornerstone objective in that it resulted in a challenge safety functions at power. The finding was determined 11Enclosureto be of a very low safety significance because no other mitigating equipment orfunctions were affected by the inadequate calibration procedure. The inspectors also determined the cause of the finding was related to, complete accurate procedures aspect of the human performance cross-cutting area (H.2c).Enforcement. 10CFR50 Appendix B, Criterion V, Instructions, Procedures, andDrawings, states that activities affecting quality shall be accomplished in accordance with documented instructions appropriate to the circumstances. Contrary to the above, on April 5, 2006, procedure 57CP-CAL-010-2 did not contain adequate guidance to prevent a reactor scram. Because the event was of a very low safety significance and has been entered into the licensee's CAP as CR 2006104201, this violation is being treated as an NCV, consistent with Section VI.A of the NRC Enforcement Policy: NCV 05000366/2007004-001, Inadequate Maintenance Instructions Results in Reactor Scram during Generator Recorder Calibration..4(Closed) LER 05000321/2006-003: Personnel Error Results in Failure to ReportCondition Prohibited by Technical SpecificationsThis LER was the result of a NRC-identified violation previously documented ininspection report 05000321, 366/2006-004. No additional findings of significance were identified..5(Closed) LER 05000366/2007-002: Excessive Feedwater Check Valve Leakage due toValve Internal Clearances Being out of ToleranceOn February 18, 2007, two of three "A" Feedwater check valves failed their local leakrate tests. The cause of the failure of the inboard check valve was due to internal valve dimensions found outside the required tolerances. The cause of the test check valve failure was degradation of the valve internals. Both valves were repaired and then tested satisfactorily. The condition for the inboard check valve was documented in CR 2007101979 and the test check valve in CR 2007101980. No findings of significance were identified.4OA5Other.1Operation of an Independent Spent Fuel Storage Installation (ISFSI)a.Inspection ScopeThe inspectors reviewed selected ISFSI operations to verify that the licensee performedISFSI activities safely and in compliance with approved procedures. The inspectors reviewed records to verify that the licensee had properly identified the parameters of each fuel assembly loaded. The inspectors also reviewed the TS to verify that the fuel placed in these casks met the requirements. The inspectors walked down the ISFSI pads to assess the material condition of the casks, the installation of security equipment, the performance of the monitoring systems and that the casks were placed in the identified locations. The inspectors also reviewed ISFSI document control 12Enclosurepractices to verify that any changes to the required ISFSI procedures were performed inaccordance with guidelines established in local procedures and 10CFR72.48.

Documents reviewed are listed in the Attachment.*Licensing Document Change Request 2007-037, Approval of Spent Fuel Casks - 2007Loading Campaign Corresponding*Licensing Document Change Request 2007-039, Miscellaneous Changes to the Hatch10 CFR 72.212 Reportb.FindingsNo findings of significance were identified..2(Closed) Unresolved Item 05000321,366/200606-002: Inadequate Testing of RemoteShutdown Panel Transfer SwitchesThe licensee provided completed surveillance results for testing of the isolation functionof the remote shutdown panel transfer switches. After further in-office review of this documentation, it was determined that all the transfer switches were tested adequately.

The licensee also provided information that determined this test was required to meet Appendix R requirements, but it was not required to satisfy Technical Specifications Operability.4OA6Meetings, Including ExitOn October 11, 2007, the inspectors presented the inspection results to Mr. DennisMadison and the other members of his staff who acknowledged the observations. The inspectors confirmed proprietary information was not provided or examined during the inspection.4OA7Licensee-identified ViolationsThe following violation of very low safety significance (Green) was identified by thelicensee and is a violation of NRC requirements which meet the criteria of Section VI of the NRC Enforcement Policy, NUREG-1600, for being dispositioned as NCVs.*10 CFR 50, Appendix B, Criterion III, Design Control, requires measures to beestablished to assure the design basis requirements for structures, systems and components are correctly transferred into specifications, drawings, procedures and instructions. Contrary to this, on August 29, 2007, the licensee determined that procedures did not exist to ensure the vent paths were capable of performing their intended function(s) in the event of a High Energy Line Break (HELB) in the Torus Room for Units 1 and 2. Tool boxes stored in the steam chase reduced the vent area assumed to be available in the accident analysis. Additionally, on Unit 2, a hinged plate was restrained and was not available to perform its pressure relieving function.

The licensee initiated immediate corrective actions to restore the vent area and performed an evaluation of the effects of this unanalyzed condition. This finding is 13Enclosuredetermined to be of very low safety significance because the evaluation of the ventareas in the as-found condition showed that Unit 1 and Unit 2 were still within the bounds of the FSAR design basis. The licensee entered the finding into their CAP as CR 2007106943 and CR 2007106973. ATTACHMENT:

SUPPLEMENTAL INFORMATION

KEY POINTS OF CONTACT

Licensee personnel

M. Ajluni, Plant Support Manager
J. Dixon, Health Physics Manager
S. Douglas, Plant Manager
B. Goodwin, Engineering Manager
G. Johnson, Operations Manager
J. Lewis, Training and Emergency Preparedness Manager
D. Madison, Hatch Vice President
J. Thompson, Nuclear Security Manager
R. Varnadore, Maintenance Manager

LIST OF ITEMS OPENED, CLOSED, AND DISCUSSED

Opened and

Closed

05000366/FIN-2007004-01NCVInadequate Maintenance Instructions Results inReactor Scram during Generator Recorder
Calibration (Section 4OA3.3)

Closed

05000366/FIN-2007004-01NCVInadequate Maintenance Instructions Results inReactor Scram during Generator Recorder
Calibration (Section 4OA3.3)

LIST OF DOCUMENTS REVIEWED

Section 1R04: Equipment AlignmentProcedures: 34SO-R43-001-2, Diesel Generator Standby

AC System
34SO-E21-001-1, Core Spray System
34SO-E51-001-1, Reactor Core Isolation Cooling System
34SO-E11-010-1, Residual Heat Removal System
34SO-R43-001-1, Diesel Generator Standby AC SystemDrawings: H-16331, H-16328, H-16334, H-16335, D11004, H-16329, H-16330 , H-13412, H-13413, H-13414, H-11631
FSAR Sections: 8.1, 8.4.1, 8.4.2, 6.3.3, 6.4.2.4, 7.4.3.4, 4.7, 4.8, 7.4, 10.6
Tech Specs: SR 3.8.1.1, T.S. 3.5.1, 3.5.3, 3.3.5.2, SR 3.5.1.1, SR 3.5.1.2, SR 3.5.1.4, T.S.
2Attachment3.7.1, SR 3.7.1.1CRs:
2007106026,
2007107101, 2007108112

Section 1R05: Fire ProtectionCR:

CR2007108188Drawings:
A-43965 sheets 065B, 066B, 073B, 074B, 123B, 099B, 100B, 101B, 102B, 103B,
106B, 107B, 109B, 110B, 113B, 114B, 112B, H-23274, H-19636, H-11828
Procedures: 42SV-FPX-037-0, Fire Detection Instrumentation Surveillance

Section 1R12: Maintenance EffectivenessResident ReviewSystem Health Report for the 2nd Quarter 2007Leak List Database as of 9/9/2007

MWOs:
2061085501,
1061660601,
2050967901,
2051018601, 2062056201
CRs:
2006100509,
2006102224,
2006102576,
2006103579,
2006104976, 2006105418,
2006106634,
2006106640,
2006106728,
2006106837,
2006107419, 2007100403,
2006112359,
2006112229,
2005104368, 2005104433Triennial ReviewSystem Health Reports: 1st Quarter 2007Component Health Reports:
Large Pumps, Air-Operated Valves, Motor-Operated Valves
CRs:
2005103366,
2005103367,
2005112049,
2005103369,
2006107938, 2006107940,
2006107941,
2006107942,
2006107943,
2006107944,
2006111086, 2006104896,
2005112049, 2006102117
Current A(1) systems:
Plant Service Water (P41), Turbine Building Chilled Water (P63), Station Auxiliary DC Power (R42), Reactor Building HVAC (T41), Remote Shutdown (C82)
A1 SSC Monthly/Classification Status Reports: 2P63, 1P51, 1P63, 1W33, 1C82, 2R42, 2P41,2P51
Meetings:
Expert Panel Meeting - July 18, 2007, Daily CAP Management Review - July 17,
2007Procedures:MP-GM-002-001, Corrective Action Program Instructions, Rev. 2.040AC-ENG-020-0, Maintenance Rule (10CFR50.65) Implementation and Compliance, Rev. 5.0
NMP-GM-003-GL01, Self Assessment NMP, Self-Assessment Guideline, Rev. 2.0Self Assessments:
June 2004 (SA04-ENG-02) and June 2006 (SA06-ENG-02)Maintenance Rule Periodic Assessment Reports:
June 2000 and June 2002
Expert Panel Meeting Minutes:
1/16/07, 3/28/07, 4/12/07, 5/10/07, 5/31/07, 2/7/06, 6/8/06,
9/19/06, 10/13/06, 11/16/06, 12/12/06Other DocumentsMPFFs since 7/17/2004Root Cause Evaluations: CR-2005103369
Followup to
NCV 2006-002-02, Failure to Demonstrate that the Traveling Water Screen System was Effectively Controlled per 10CFR50.65
3AttachmentApril 2007 Maintenance Rule Report (SSC Failures and Status)Operator Work Arounds, Burdens and Needs - 4/19/07

==Section 1R15: Operability EvaluationsCRs:

2007106851,
2007106973,
2007106943,
2007107087,
2007106994,
2007107632,2007107623,
2007103001, 2007108243ProceduresNMP-GM-002, Corrective Action ProgramSCM-CGDP-001, Commercial Grade Dedication Plan Number 2 Diesel Fuel OilNRC==
IN 2005-023, Vibration-Induced Degradation of Butterfly ValvesNRC Regulatory Guide 1.137, Fuel Oil Systems for Standby Diesel Generators Intra company Correspondence
LR-PA-001-0406 Response to NRC IN 2005-023
Action Item: 2006201277

Section 1R19:

Post Maintenance TestingMWOs:
2070580801,
2070580801,
2070581101,
2050613101,
1070306201,
2060416523,2060420901,
1070329501, 1050895601Procedures:34SV-SUV-008-2, Primary Containment Isolation Valve Operability50AC-MNT-001-0, Maintenance Program
2CM-MME-060-0, Copes Vulcan Valve/Actuator Maintenance
57CP-CAL-250-0, AOV Stroke/Positioner Test and Setup
34SV-T48-002-2, Suppression Chamber to Drywell Vacuum Breaker Operability
2SV-T48-001-0, Torus to Drywell Vacuum Breaker Inspection
2PM-T48-013-0, Purge and Vent Valve T-Ring Replacement
51GM-MNT-017-0, Control of Lubricants
2PM-MNT-005-0, Limitorque Valve Operator Inspection
2PM-C11-003-2, CRD Scram Valve Maintenance
34SV-E21-001-1, Core Spray Pump Operability
95IT-OTM-001-0, Maintenance Work Order Functional Test Guideline
2SV-SUV-004-0S, IST for Safety Relief Valves
34SV-E11-002-1, RHR Valve Operability

==Section 1R22: Surveillance TestingCRs:

2006106704,
2006106687,
2006106704,
2006109233, 2006105249Tech Specs:==
SR 3.4.4.1, 3.5.1.1, 3.5.2.3,

Section 4OA5: OtherMWO 1070774101,

MPC S/N 179 and Hi-Storm S/N 254 loading and transport activitiesProcedures:57CP-CAL-186-0S, Bourdon tube Style Test Gauge34FH-OPS-002-0, Dry Fuel Movement Prerequisites
NMP-DP-001, Operational Risk Awareness
4AttachmentNMP-MA-007-003, SNC Rigging and Lifting Program Rigging Hardware Inspection52PM-F18-003-0, Spent Fuel Dry Storage Transporting Equipment
NMP-AD-006, Infrequently Performed Tests and Evolutions
51GM-MLH-004-0,
NUREG-0612 Heavy Load Movement
45QC-INS-020-0, Spent Fuel Dry Storage Helium Leak Rate Testing
45QC-INS-018-0S, Visual Examination of Hydrostatic Testing of Holtec Hi-Star/Storm 100 MPC
NMP-ES-024-302, Liquid Penetrant Testing Procedure (High Temperature) Color Contrast
2FP-FPX-004-0, Fire Protection Checklist for MWOs
2PM-F18-001-0,
HI-STORM,
HI-TRAC and MPC Staging
2SV-F18-006-0, Hi-Storm/Trac Fuel Loading
2FH-ERP-014-0S,
ENG-0965
MPC-68 Loading Verification
2FH-ERP-014-0S,
ENG-0190 Fuel Movement Sheets
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