IR 05000331/2008003

ODAM. This inspection constituted one inspection planning sample as defined in Inspection Procedure 71122.01. b. Findings No findings of significance were identified.

16.2 Onsite Inspection a. Inspection Scope The inspectors performed a walkdown of selected components of the gaseous and liquid discharge systems (e.g., gas compressors, demineralizers and filters in use or standby, tanks, and vessels) and reviewed current system configuration with respect to the description in the

UFS [[]]

AR. The inspectors evaluated temporary waste processing

activities, system modifications and the equipment material condition. For equipment or areas that were not readily accessible, the inspectors reviewed the licensee's material condition surveillance records as applicable. During the walkdown, the inspectors assessed the operability of selected point of discharge effluent radiation monitoring systems and flow measurement devices. The

effluent radiation monitor alarm set point values were reviewed for agreement with

ODAM [[requirements. The inspectors observed the gaseous sampling of waste processing and observed selected portions of the routine processing and discharge of radioactive gaseous effluent. The inspectors verified that appropriate treatment equipment was used and that the radioactive gaseous effluent was processed and discharged in accordance with]]

ODAM requirements, including the projected doses to members of the public. The inspectors assessed the liquid waste processing system; however, the licensee was not processing liquid waste during the inspection. The inspectors evaluated if appropriate effluent treatment equipment was being used and if radioactive liquid waste was being processed in accordance with procedure requirements. The inspectors also interviewed staff concerning effluent discharges

made with inoperable (declared out-of-service) effluent radiation monitors and determined if appropriate compensatory sampling and radiological analyses were being conducted at the required frequency specified in the

ODAM values. The inspectors assessed how the licensee identified any normally non-radioactive systems that may have become contaminated and ensured that 10

ODAM. For compensatory sampling methods, the inspectors verified that representative samples were being obtained and that the licensee did not routinely rely on the use of compensatory

sampling in lieu of adequate system maintenance or calibration of effluent monitors. The inspectors reviewed surveillance test results for non-safety-related ventilation and gaseous discharge systems (high efficiency particulate air (HEPA) and charcoal filtration) to ensure that the system was operating within acceptance criteria. In addition, the inspectors assessed the methodology the licensee uses to determine the stack/vent

flow rates and verified that the flow rates were consistent with

CFR 50.59 evaluations were performed per IE Bulletin 80-10. The inspectors did not identify unidentified contaminated systems that may have been unmonitored discharge

pathways to the environment. The inspectors also reviewed instrument maintenance and calibration records (i.e., both installed and counting room equipment) associated with effluent monitoring and

17reviewed quality control records for the radiation measurement instruments. The inspectors did not identify degraded instrument performance during the inspection. The inspectors verified the radionuclides that were included in the source term to ensure that all applicable radionuclides were included, within detectability standards, in the licensee evaluation of effluent. The inspectors reviewed Part 61 analyses to ensure that hard-to-detect radionuclides were also included in the source term analysis for the

year 2007. The inspectors reviewed the meteorological dispersion and deposition factors and hydrogeologic characteristics used in the licensee's

OD [[]]

AM and effluent dose calculations to verify that appropriate factors were being used for public dose calculations. This also included a review the land-use census for any new public dose

receptors or pathways. The inspectors reviewed the annual dose calculations to ensure that the licensee had properly demonstrated compliance with

10 CFR Part 50, Appendix I, and

TS s dose criteria. The inspectors also reviewed and assessed the licensee's implementation of the voluntary Nuclear Energy Institute (NEI)/Industry Ground Water Protection Initiative (GPI). The inspectors reviewed changes made to the

GPI , monitoring results of the

GPI,

identified leakage or spill events and entries made into 10 CFR 50.75(g) records, and evaluations of leaks or spills including any remediation actions taken for effectiveness. There were no abnormal effluent discharges since the last radioactive gaseous and liquid effluents monitoring inspection in 2006. To date, the licensee records did not indicate any abnormal gaseous or liquid tank discharges (e.g., discharges resulting from

misaligned valves, valve leak-by, etc). The inspectors reviewed onsite contamination events involving contamination of ground water and assessed whether the source of the leak or spill was identified and mitigated. Since the last inspection in 2006, there were no unmonitored spills, leaks, or unexpected radioactive liquid or gaseous discharges. The inspectors verified that significant leaks

and spills were properly documented in the site=s corrective action program and/or in the decommissioning file, per 10 CFR 50.75 (g). The inspectors verified whether sufficient radiological surveys were performed to evaluate the extent of the contamination and the radiological source term,

and the inspectors reviewed survey/evaluation records that include consideration of hard-to-detect radionuclides. The inspectors assessed the licensee program to evaluate and analyze any new or additional effluent discharge pathways as a result of a spill, leak, abnormal, or unexpected liquid discharge or gaseous discharges. The inspectors reviewed whether

the licensee monitors groundwater discharges and verified that significant leaks and spills were properly documented. The inspectors evaluated if the licensee's program included provisions for required or voluntary offsite notifications to the State and local government if appropriate, the NRC. The inspectors assessed the licensee's evaluations of discharges from onsite surface water bodies (ponds, retention basins, lakes) that contain or potentially contain

18radioactivity and the potential for ground water leakage from these onsite surface water bodies. The inspectors evaluated if the licensee was properly accounting for discharges from these surface water bodies as part of their effluent release reports and reviewed routine groundwater monitoring results to assess whether the licensee was monitoring for unknown leakage. The inspectors verified that the licensee sufficiently evaluated monitoring results, properly documented and reported the results, entered any abnormal

results into its corrective action program, and implemented adequate corrective actions. Additionally, the inspectors reviewed the licensee's self-assessments, audits, and event reports that involved unanticipated offsite discharges of radioactive material. The inspectors reviewed the results of the inter-laboratory comparison program to verify the quality of radioactive effluent sample analyses. The inspectors verified that the

licensee maintained adequate effluent sampling records (sampling locations, sample analyses results, flow rates, and source term for radioactive liquid and gaseous effluent, (i.e., information needed to satisfy the requirements of 10 CFR 20.1501)). This inspection constituted one sample as defined in Inspection Procedure 71122.01. b. Findings No findings of significance were identified. .3 Identification and Resolution of Problems a. Inspection Scope The inspectors reviewed the licensee's self assessments, audits, Licensee Event Reports, and Special Reports related to the radioactive effluent treatment and monitoring program since the last inspection to determine if identified problems were entered into the corrective action program for resolution. The inspectors also verified that the

licensee's self-assessment program was capable of identifying repetitive deficiencies or significant individual deficiencies in problem identification and resolution. The inspectors also reviewed corrective action reports from the radioactive effluent treatment and monitoring program since the previous inspection, interviewed staff and reviewed documents to determine if the following activities were being conducted in an

effective and timely manner commensurate with their importance to safety and risk: * Initial problem identification, characterization, and tracking; * Disposition of operability/reportability issues; * Evaluation of safety significance/risk and priority for resolution; * Identification of repetitive problems; * Identification of contributing causes; * Identification and implementation of effective corrective actions; * Resolution of NCVs tracked in the corrective action system; * Implementation/consideration of risk-significant operational experience feedback; and * Ensuring problems were identified, characterized, prioritized, entered into the corrective action system, and resolved.

19This inspection constituted one identification and resolution of problems sample as defined in Inspection Procedure 71122.01. b. Findings No findings of significance were identified. 4.

OTHER [[]]

ACTIVI TIES

4OA 1 Performance Indicator Verification (71151) .1 Data Submission Issue a. Inspection Scope The inspectors performed a review of the data submitted by the licensee for the first Quarter 2008 performance indicators (

PI s) for any obvious inconsistencies prior to its public release in accordance with

IMC [[0608, "Performance Indicator Program." This review was performed as part of the inspectors' normal plant status activities and, as such, did not constitute a separate inspection sample. b. Findings No findings of significance were identified. Cornerstone: Barrier Integrity .2 Reactor Coolant System Specific Activity a. Inspection Scope The inspectors sampled licensee submittals for the reactor coolant system (]]

RCS ) specific activity

PI for the period from the second quarter 2007 through first quarter 2008. To determine the accuracy of the

PI data reported during those periods,

PI definitions and guidance contained in the

NEI Document 99-02, "Regulatory Assessment Performance Indicator Guideline," Revision 5, were used. The inspectors reviewed the

licensee's

RCS chemistry samples,

TS requirements, corrective action program documents, event reports and

NRC [[Integrated Inspection reports for the period of April 2007 through March 2008 to validate the accuracy of the submittals. The inspectors also reviewed the licensee's corrective action program database to determine if any problems had been identified with the]]

PI data collected or transmitted for this

indicator and none were identified. In addition to record reviews, the inspectors observed a chemistry technician obtain and analyze an

RCS sample. Specific documents reviewed are described in the Attachment to this report. These inspection activities constituted one

RCS specific activity sample as defined in Inspection Procedure 71151-05. b. Findings No findings of significance were identified.

20.3 Reactor Coolant System Leakage a. Inspection Scope The inspectors sampled licensee submittals for the

RCS Leakage

PI for the period from the second quarter 2007 through the first quarter 2008. To determine the accuracy of the

PI data reported during those periods,

PI definitions and guidance contained in the

NEI Document 99-02, "Regulatory Assessment Performance Indicator Guideline," Revision 5, were used. The inspectors reviewed the licensee's operator logs,

RCS leakage tracking data, corrective action program documents, event reports and

NRC [[Integrated Inspection reports for the period of April 2007 through March 2008 to validate the accuracy of the submittals. The inspectors also reviewed the licensee's corrective action program database to determine if any problems had been identified with the]]

PI data collected or transmitted for this indicator and none were identified. Specific documents reviewed are described in the Attachment to this report. These inspection activities constituted one

RCS leakage sample as defined in Inspection Procedure 71151-05. b. Findings No findings of significance were identified. Cornerstone: Public Radiation Safety .4 Radiological Effluent

TS /Offsite Dose Calculation Manual Radiological Effluent Occurrences a. Inspection Scope The Inspectors sampled the licensee's

PI submittals for the period indicated below. The inspectors used

PI definitions and guidance contained in Revision 5 of NEI Document

99-02, "Regulatory Assessment Performance Indicator Guideline," to verify the accuracy of the

PI data. The inspectors reviewed data associated with the

RETS /ODCM

PI to determine if the indicator was accurately assessed and reported. The inspectors reviewed the licensee's corrective action program database and individual corrective action process (

CAP) documents generated in 2007 to identify any potential occurrences

such as unmonitored, uncontrolled or improperly calculated effluent releases that may have impacted offsite dose. The inspectors also reviewed gaseous and liquid effluent summary data and the results of associated offsite dose calculations for the four quarters in 2007 to determine if indicator results were accurately reported. The inspectors also discussed with the licensee the methods for quantifying gaseous and

liquid effluents and for determining effluent dose. These reviews constituted one sample as defined in Inspection Procedure 71151-05. b. Findings No findings of significance were identified.

214OA2 Identification and Resolution of Problems (71152) .1 Routine Review of Items Entered Into the Corrective Action Program a. Inspection Scope As part of the various baseline inspection procedures discussed in previous sections of this report, the inspectors routinely reviewed issues during baseline inspection activities and plant status reviews to verify that they were being entered into the licensee's

corrective action program at an appropriate threshold, that adequate attention was being given to timely corrective actions, and that adverse trends were identified and addressed. Attributes reviewed included: the complete and accurate identification of the problem; that timeliness was commensurate with the safety significance; that evaluation and disposition of performance issues, generic implications, common causes,

contributing factors, root causes, extent of condition reviews, and previous occurrences reviews were proper and adequate; and that the classification, prioritization, focus, and timeliness of corrective actions were commensurate with safety and sufficient to prevent recurrence of the issue. Minor issues entered into the licensee's corrective action program as a result of the inspectors' observations are included in the Attachment. These routine reviews for the identification and resolution of problems did not constitute any additional inspection samples. Instead, by procedure they were considered an

integral part of the inspections performed during the quarter and documented in Section 1 of this report. b. Findings No findings of significance were identified. .2 Daily Corrective Action Program Reviews a. Inspection Scope In order to assist with the identification of repetitive equipment failures and specific human performance issues for follow-up, the inspectors performed a daily screening of items entered into the licensee's corrective action program. This review was accomplished through inspection of the station's daily condition report packages. These daily reviews were performed by procedure as part of the inspectors' daily plant status monitoring activities and, as such, did not constitute any separate inspection samples. b. Findings No findings of significance were identified.

2.3 Semi-Annual Trend Review a. Inspection Scope The inspectors performed a review of the licensee's corrective action program and associated documents to identify trends that could indicate the existence of a more significant safety issue. The inspectors' review was focused on repetitive equipment issues, but also considered the results of daily inspector corrective action program item

screening discussed in Section

4OA [[2.2 above, licensee trending efforts, and licensee human performance results. The inspectors' review nominally considered the six month period of January 1, 2008 through June 30, 2008, although some examples expanded beyond those dates where the scope of the trend warranted. The review also included issues documented outside the normal corrective action program in major equipment problem lists, repetitive and/or reworks maintenance lists, departmental problem/challenges lists, system health reports, quality assurance audit/surveillance reports, self assessment reports, and Maintenance Rule assessments. The inspectors compared and contrasted their results with the results contained in the licensee's corrective action program trending reports. Corrective actions associated with a sample of the issues identified in the licensee's trending reports were reviewed for adequacy. This review constituted a single semi-annual trend inspection sample. b. Findings No findings of significance were identified. .4 Selected Issue Follow-up Inspection: Performance Issues Observed During an Extended Maintenance Window for the 'B']]

SDBG a. Inspection Scope During observation of

PMT being performed on the 'B'

SBDG , the inspectors observed two unexpected failures of support equipment: a leak in the

ESW discharge expansion bellows and an unexpected trip of the 'B'

SBDG. The inspectors observed site personnel's troubleshooting efforts to identify and correct the equipment issues. Site personnel generated

CAP s for each of the performance issues and an Apparent Cause Evaluation (

ACE ) was performed for each issue. The inspectors reviewed each of the

ACE s, comparing them to

DAEC's ACE Manual. Corrective actions associated with each of the issues were reviewed for adequacy. The inspectors did not identify any discrepancies. The documents reviewed during this inspection activity are listed in the

Attachment. The above constituted completion of one in-depth problem identification and resolution sample. b. Findings No findings of significance were identified.

234OA3 Follow-up of Events and Notices of Enforcement Discretion (71153) .1 Notice of Unusual Event Declaration for Loss of Offsite Communications Capability Due to River Flooding a. Inspection Scope The inspectors reviewed the plant's response for a Notice of Unusual Event declaration for a Loss of Offsite Communication Capabilities due to flooded river conditions on

June 2, 2008. Documents reviewed in this inspection are listed in the Attachment. This inspection constituted one sample as defined in Inspection Procedure 71153-05. b. Findings No findings of significance were identified.

4OA 5 Other Activities .1 Institute of Nuclear Power Operations (

INPO ) Plant Assessment Report Review a. Inspection Scope The inspectors reviewed the final report for the

INPO plant assessment conducted in November 2007. The inspectors reviewed the report to ensure that issues identified were consistent with the

NRC perspectives of licensee performance and to verify that there were not any significant safety issues identified that would require further NRC follow-up. .2 Quarterly Resident Inspector Observations of Security Personnel and Activities a. Inspection Scope During the inspection period, the inspectors conducted observations of security force personnel and activities to ensure that the activities were consistent with licensee security procedures and regulatory requirements relating to nuclear plant security.

These observations took place during both normal and off-normal plant working hours. These quarterly resident inspector observations of security force personnel and activities did not constitute any additional inspection samples. Rather, they were considered an integral part of the inspectors' normal plant status review and inspection activities. b. Findings No findings of significance were identified. 4OA6 Management Meetings .1 Exit Meeting Summary On July 10, 2008, the inspectors presented the inspection results to Mr. R. Anderson, Site Vice President, and other members of the licensee staff. The licensee

24acknowledged the issues presented. The inspectors confirmed that none of the potential report input discussed was considered proprietary. .2 Interim Exit Meetings Interim exits were conducted for: * Radioactive gaseous and liquid effluent treatment monitoring system under the public radiation safety cornerstone with Mr.

R. Anderson, Site Vice President, and with Mr. D. Curtland, Plant General Manager, on April 4, 2008. 4

OA 7 Licensee-Identified Violations None

ATTACH [[]]

MENT [[:]]

SUPPLE [[]]

MENTAL [[]]

INFORM [[]]

ATION [[]]

1SUPPLE [[]]

MENTAL [[]]

INFORM [[]]

ATION [[]]

KEY [[]]

POINTS [[]]

OF [[]]

CONTAC T Licensee

R. Anderson, Site Vice President D. Curtland, Plant Manager B. Eckes,

NOS Manager

S. Catron, Licensing Manager J. Cadogan, Engineering Director B. Kindred, Security Manager J. Morris, Training Manager C. Dieckmann, Operations Manager

G. Rushworth, Assistant Operations Manager R. Harter, Operations Support Manager G. Pry, Maintenance Manager J. Windschill, Chemistry & Radiation Protection Manager M. Davis, Emergency Preparedness Manager G. Ellis, Program Owner, Fire Protection M. Lingenfelter, Design Engineering Manager

S. Huebsch, System Engineering Supervisor J. Swales, Design Engineering Supervisor K. Kleinheinz, Program Engineering Manager J. Kuehl, Program Engineering Supervisor D. Albrecht, Radwaste Supervisor

G. Park,

ISI Program Owner

F. Dohmen,

NDE Level III B. Klotz, Program Engineering Supervisor J. Probst, Site Maintenance Rule Coordinator N. McKenney, General Supervisor Radiation Protection Support

S. Funk,

CHP ,

REMP Program Manager, Sr. Health Physics Coordinator D. Johnson, Radwaste Operator/Chem Tech, Rad Environmental Technician R. Porter, General Supervisor Radiation Protection Nuclear Regulatory Commission K. Feintuck, Project Manager,

NRR [[]]

K. Riemer, Chief, Reactor Projects Branch 2

LIST [[]]

OF [[]]

ITEMS [[]]

OPENED ,

CLOSED ,

AND [[]]

DISCUSSED Opened and Closed None

Discussed 05000331/2005002-02

URI Failure to Include the Analysis of Thermal Movements in Piping (Section 1R15.2)

LIST [[]]

OF [[]]

DOCUME [[]]

NTS [[]]

REVIEW [[]]

ED The following is a list of documents reviewed during the inspection. Inclusion on this list does not imply that the

NRC inspectors reviewed the documents in their entirety, but rather, that selected sections of portions of the documents were evaluated as part of the overall inspection effort. Inclusion of a document on this list does not imply

NRC acceptance of the document or

any part of it, unless this is stated in the body of the inspection report. 1R01 Adverse Weather Protection

CAP 055240; Non Condition Adverse to Quality (

NCAQ ) - Grid Operating Agreement Needs to Be Revised

CAP 056849;

NCAQ - Delay Filling

1VP [[]]

CC 001A Plant H&V Cooling Coil

CAP 057082;

NCAQ - Ineffective Corrective Actions for Tornado Hazards

CAP 057087; Condition Adverse to Quality (

CAQ ) - Unable to Determine Position of V29-0032

CAP 057096;

NCAQ - Mechanical Maintenance Resources to Support Rescheduling of

INPO [[]]

TSG "[Transformer, [[Area" contains a listed "[" character as part of the property label and has therefore been classified as invalid., and Grid] Review-Ops Coordination and Communication with]]

ATC [[[American Transmission Company]]]

CAP 057098;

IPOI [[[Integrated Plant Operating Procedure]]]

6 CAP 057099;

TSG Review-Switchyard Control House A/C Unit Restoration

INPO [[]]

CAP 057100;

TSG Review-Switchyard Coordinator Roles and Responsibilities

INPO [[]]

CAP 057210;

NCAQ - River Projected to Reach 748 Feet

CAP 057216;

NCAQ - 1E064B Iso Phase Bus Cooler Performance

AOP 902 Flood Entered

CAP 057366;

CAP 057430;

NC [[]]

AQ - Improvements to Main Intake Coil Procedure

CAP 057432;

CAQ - Inadequate Supplemental Cooling for 'A' Phase Main Transformer

CAP 057584;

NCAQ - Summer and Fall Set Up of 'A' and 'B' Chillers

1VCH 001A/B

IPOI 6 Administrative Control Procedure (ACP) 101.16; Midwest ISO Real-Time Operations: Communication and Mitigation Protocols for Nuclear Plant/Electrical System Interfaces; Revision 2

ACP 110.6; Seasonal Readiness; Revision 2

AOP 304; Grid Instability; Revision

16 AOP 410; Loss of River Water Supply; Revision 19

AOP 902; Flood; Revision 28 AOP 902; Flood; Revision 29

IPOI 6; Weather Impacted Operations; Revision 45

GMP -ELEC-30; Installation of Temporary Power to Intake Structure Load Centers 1B09 and 1B20; Revision 0 L-2006-073; Florida Power and Light Company letter,

RE [[:]]

NRC Generic Letter 2006-02 60-Day Response, Attachment 4 (DAEC Response; April 3, 2006)

Individual Plant Examination; Section 3.3.6, Internal Flooding Analysis; November 1992 Preventative Work Order (PWO) 1142133; Convert to Summer Mode and Inspect and Clean the External Cooling Coils; April 5,

2008 PWO 1142149; Semi-Annual Spring Inspection on 1

VCH 001A, 'A'

CBC ; April 15, 2008

PWO 1142153; Semi-Annual Spring Inspection on

1VCH 001B, 'B'

CBC; April 27, 2008

31R04 Equipment Alignment

CAP 050230; Incorrect Clearance Hanging Instructions Would Have Led to Valve Mispositioning

CAP 052954;

CAQ - "A"

SBDG Governor Droop Setting at "MAX" Instead of "Zero"

CAP 057150;

CB Chiller Temperature Load Controller

TLC 6924A

CAP 057435;

CAQ - EDG Scavenging Air to Lube Oil Heat Exchanger Bolting Thread Engagement

CAP 057443;

CAQ - Instrument Isolation Valve Found Out of Position During Valve Lineup

CAP 057489;

NCAQ - CNO Indicator for Component Mispo. (J-7) was not correct for April '08 Drawing M133<1>; Fire Protection Yard Loop; Revision 29 Drawing M122<2>; Fire Protection; Revision 17 Drawing M117; Control Rod Drive Hydraulic System; Revision 60

Drawing M118; Control Rod Drive Hydraulic System; Revision 25 Operating Instruction (OI) 255A1; Control Rod Drive System Electrical Lineup; Revision

3 OI 255A2; Control Rod Drive System Valve Lineup and Checklist; Revision 4

OI 255A3; Control Rod Drive System

HCU [[[Hydraulic Control Unit] Valve Lineup and Checklist; Revision 1]]

OI 324A4;

SBDG 1G-21 System Valve Lineup and Checklist; Revision 11

OI 324A8;

SB [[]]

DG 1G-21 System Control Panel Lineup; Revision 2

OI 324A9;

SBDG Operating Checklist; Revision

8 OI 324A10;

SBDG Standby/Readiness Condition Checklist; Revision

7 OI 454A2; 'A'

ESW System Valve Lineup and Checklist; Revision

9 OI 454A6;

ESW System Control Panel Lineup; Revision

2 OI 454A1;

ESW System electrical Lineup; Revision 2

OI 454A2; 'A'

ESW System Valve Lineup and Checklist; Revision

9 OI 513A1; Fire Protection System Electrical Lineup; Revision 7

OI 513A2; Fire Protection System Valve Lineup; Revision

14 OI 730A1; Control Building

HVAC [[[Heating, Ventilation, and Air Conditioning] System Electrical Lineup; Revision 2]]

OI 730A2; Control Building Ventilation Compressed Air System Valve Lineup; Revision 4

OI 730A3; Control Building Ventilation System Valve Lineup; Revision

7 OI 730A6; Control Building

HVAC System Control Panel Lineup; Revision

9 STP 3.7.5-02; Two (2) Control Building Chillers Inoperable; Revision 0

UFSAR Section 4.6 Functional Design of Reactivity Control Systems; Revision 19

TS Bases 3.1 Reactivity Control Systems; April 18, 2008 Control Rod Drive System Health Report; May 1, 2008 Open Work Order Report for Control Rod Drive System; May 20, 2008 1R05 Fire Protection (Annual/Quarterly)

ACP 1412.2; Control of Combustibles; Revision

33 ACP 1412.3; Control of Ignition Sources; Revision 20

AFP 01; Reactor Building Torus Area and North Corner Rooms; Revision

24 AFP 02; Reactor Building South Corner Rooms; Revision 23

AFP 07; Reactor Building Laydown Area, Corridor and Waste Tank Area, and Spent Resin Tank Room; Revision

28 AFP 09; Reactor Building

RBCCW Heat Exchanger Area, Equipment Hatch Area and Jungle

Room; Revision

27 AFP 20; Turbine Building Aux Boiler Room Emergency Diesel Generator Rooms, and Generator Day Tank Room; Revision 29

AFP 21; Turbine Building North Turbine Operating Floor; Revision 24

1R06 Flood Protection Measures Drawing M137 <1>; Radwaste Sump System; Revision 33 Drawing M137 <2>; Radwaste Sump System; Revision 16 Drawing E125 <025>; Reactor Building Water Level Indication; Revision 2 Emergency Operating Procedure 3; Secondary Containment Control Guideline; Revision

10 DAEC Individual Plant Examination; Section 3.3.6 Internal Flooding Analysis; November 1992 1R07 Heat Sink Performance

CAP 057404; CAQ - Very Small Pitting of the Flange Sealing Face of 1E053B3 (1G-21 Jacket Cooling Water)

CAP 057408;

CAQ - Scratch on the New Tube on the Lube Oil Tube Bundle

CAP 057412;

CAQ [[- Small Corroded Areas on 1G021 Jacket Cooling Water Hx [Heat Exchanger] Packing Gland Area Condition Evaluation (CE) 006396; Small Corroded Areas on 1G021 Jacket Cooling Water Hx [Heat Exchanger] Packing Gland Area]]

CAP 057423;

CAQ - Water Entered the 'B'

SBDG [[]]

LO Cooler During the Pressure Test

DA [[]]

EC Heat Exchanger Program; Revision 1

Heat Exchanger Thermal Performance and Trending Program; Equipment Monitoring Manual; Revision 7 Calculation

CAL -M05-027; Emergency Diesel Generator Heat Exchanger Heat Transfer Calculation; Revision 3 1R11 Licensed Operator Requalification Program

ESG 66; Simulator Guideline Training Scenario; Revision

0 ACP 110.1; Conduct of Operations; Revision 14

IPOI 5; Reactor Scram; Revision 49 Emergency Action Level (EAL)-01; Emergency Action Level Matrix; Revision 7

1R12 Maintenance Effectiveness

CAP 056000;

CAQ - Perform Pro-Active

MR Evaluation for March 2008

HPCI Planned

LCO [[[Limiting Condition for Operation]]]

DAEC Maintenance Rule Program Module 0; Overview; Revision 3

DAEC Maintenance Rule Program Module 2; Risk-Significance Determination; Revision 2

DAEC Maintenance Rule Availability Criteria; Revision

0 DAEC Performance Criteria Basis Document for High Pressure Coolant Injection (

SUS 52.00); Revision

3 DAEC System Checklist/Health Report for

SUS 52.00: High Pressure Coolant Injection; dated

April 1, 2008 Open Work Order Report for

HPCI System; dated April 3, 2008 System Monitoring and Reporting Tool System Report; dated April 7, 2008 1R13 Maintenance Risk Assessments and Emergent Work Control

CAP 057395;

STP 3.3.8.1-01B 4kv Degraded Voltage Functional Test Not Performed Per Schedule

CAP 057453;

NCAQ - Two Different Risk Evaluations for the Same STP

5CAP 057454;

CAQ - Pre-planned Risk Assessment may not be Applicable for Changing Plant Conditions

CAP 057492;

CAQ - Error Found in Technical Requirements Manual basis Document

CAP 057519;

NCAQ - Protected Equipment Work Approval for 'B'

SBDG Run per

OI -324

CAP 058097;

CAQ - 1X001 Main Transformer Hot Connection

CAP 058501;

CAQ [[- 1D62 Division 2 Battery 1D6 24 volt DC [Direct Current] Charger]]

PWO 1128149; Replace

AC Input Caps (C20) and Filter Circuit Caps (C1)

DAEC On-line Schedule for Work Week 9819 Maintenance Risk Evaluations for Work Week 9819; Revision 0 and Revision 1

DAEC On-line Schedule for Work Week 9822 Maintenance Risk Evaluations for Work Week 9822; Revisions 0 and Revision 1

DAEC On-line Schedule for Work Week 9823 Maintenance Risk Evaluations for Work Week 9823; Revision 0 and Revision 1

DAEC On-line Schedule for Work Week 9825 Maintenance Risk Evaluations for Work Week 9825; Revisions 0 through Revision

3 DAEC On-line Schedule for Work Week 9826 Maintenance Risk Evaluations for Work Week 9826; Revisions 0 through Revision 2 1R15 Operability Evaluations

CAP 054384;

CAQ - Valve Operator Fell Off of

CV 2436

RCIC Condenser Pump Discharge Operability Recommendation (

OPR ) 000373; Operator Fell Off of

CV 2436

RCIC Condenser Pump Discharge

CAP 054422;

CAQ - CV2235 Operator Snap Ring Engagement

OPR 000374;

CV 2235 Operator Snap Ring Engagement

CAP 057465;

CAQ - 1E053B3 Expansion Bellows Leaking

CAP 057575;

CAQ - Unplanned

LCO 'A' Chiller Trouble Alarm on 1C026A

CAP 057579;

1VCH 001B Readings Out of Spec

CAP 057653;

NCAQ - Control Building

HVAC Operation with Both Chillers Inoperable

CAQ - Hot Gas Capacity Control Does Not Function on the 'A' Chiller, 1

VCH 001A

CAP 057879;

1VCH 001B, Control Building Chiller, Trip; Unplanned

LCO [[]]

CAP 057899;

TCV 6935B Valve Body's Seat Ring Threads Worn

OPR 000379; CAQ - Hot Gas Capacity Control Does Not Function on the 'A' Chiller,

1VCH 001A

CAP 058355;

CAQ - 1G-21 'B'

SBDG Lube Oil Temperature High Out of Specification

OPR 000380; 1G-21 'B'

SBDG Lube Oil Temperature High Out of Specification 09-600-B; 6 Inch Conv. Coupling; Revision 0 D2008-004; Commercial Grade Dedication/Upgrade Evaluation for Expansion Bellows for EDG;

Revision

1 EMA A84042;

EDG Heat Exchanger Inlet/Outlet Expansion Joint; Revision

0 DAEC -

SC -PEG-04;

DAEC Dedication and Upgrade of Commercial Grade Items; Revision 3

DAEC Engineering Department Operable But Degraded/Non-Conforming Conditions Listing; dated May 20,

2008 COC 08P2780; Certificate of Conformance for Metal Bellows Expansion Joint 1R19 Post-Maintenance Testing

CAP 056210;

NCAQ - Perform Pro-Active

MR Eval for April/May

CV 1956A Did Not Open When

CV 1956A Was Failed Open and

MO 2077 Closed to Establish Seismic Boundary

CAP 057016;

NCAQ - Contingency for

CV 1956A Was Discussed But Not Planned

CAP 057039;

TCV 6924A Failed Post-Maintenance Testing

CAP 057070;

CAQ - TCV6924A-O, Hydraulic Pump Motor Stalled During Initial Maintenance Run

CAP 057411;

CAQ - Wire of Sensing Tubing for 1G21 Engine for Lube for

PS 3241B and

PI 3254B

CAP 057414;

CAQ - Tubing Clamp on A

SBDG 1G031

CAP 057423;

CAQ - Water Entered the 'B'

SBDG Lube Oil Cooler During the Pressure Test

CAP 055428;

CAQ - B

SB [[]]

DG Lube Oil Temperature Low Out of Spec per Aux Logs

CAP 057434;

CAQ - Oil samples Water Content Greater than 0.2% A

SBDG 1G021 Alarm Response Procedure 1C94; Annunciator Response Procedure Panel 1C94, Diesel Generator 1G21; Revision 37

OI 324A9;

SBDG Operating Checklist; Revision 8

OI 324A10;

SBDG Standby/Readiness Condition Checklist; Revision 7

STP 3.8.1-05; Standby Diesel Generators Operability Test (Slow Start From Emer Start Air); Revision 34

STP 3.7.5-01; Control Building Chiller Operability; Revision 13 Corrective Work Order (

CWO ) A84042; Replace the Expansion Joint on the Outlet of 1E053B3

CWO A78814; Replace Piping and Elbow Between 1G021/

OH and V32-0203

CWO A83069; Replace Tubing, Listed Below, in Support of Extent of Condition Investigation for Lube Oil Tubing Failure Documented in

CAP 055329

PWO 1142188; Change Oil in 1P214A, 'A' Fuel Pool Cooling Pump

CWO A83656; Replace Oil Pump on

TCV 6924A Hydraulic Operator

CWO A83468; Perform Troubleshooting Instruction Form for

TLC 6924A

CWO A67788; Replace Copper Tubing at the Load/Unload Valves on 'A' CB Chiller Compressor with Stainless Steel

CWO A76381; Inspect/Repair or Replace Potentiometer on

TCV 6924A

CWO A78123; Replace Actuator Stem Seal on

TCV 6924A-O

PWO 1136682; Replace Oil Filled Capacitors on 1D25

CWO A75183; Replace Front Right Most Fan on 1D25 Enclosure PWO 1140145; Perform Calibration Procedure on Elgar Inverter 1D25

1R22 Surveillance Testing

CAP 058142;

CAQ - "A"

SBLC Pump Momentary Pressure Drop and Increase Noise during

STP 3.7.1-01

CAP 058143;

CAQ - STP 3.7.1-01 Steps Incorrect Almost Causes Test Tank Overflow

OI 324A10;

SBDG Standby/Readiness Condition Checklist; Revision

7 STP [[]]

NS 500001;

RCIC System Leakage Inspection Walkdown; Revision 4

STP 3.5.3-02;

RCIC System Operability Test; Revision 24

STP 3.1.7-01;

SBLC Pump Operability Test; Revision 23

STP 3.8.1-03; Standby Diesel Generators Operability Test; Revision

15 TS Bases 3.1.7 Standby Liquid Control System; April 18, 2008

UFSAR Section 9.34 Standby Liquid Control System; Revision 19

Surveillance Work Order S014334; Perform

STP [[]]

NS 540002 Emergency Service Water Operability Test for 'B' Division to Verify Operability of System Pump and Motor Operated Valves

STP [[]]

NS "540002; Emergency Service Water Operability Test; Revision 33 Surveillance Work Order S012358; Perform STP 3.4.6-01 Reactor Coolant [[Atomic Element" contains a listed "[" character as part of the property label and has therefore been classified as invalid. Activity]]

7STP 3.4.6-01; Reactor Coolant Iodine Activity; Revision 4

ACP 1407.5; Surveillance Testing Program; Revision 26 Plant Chemistry Procedure (PCP) 2.1; Plant Chemistry Sampling Program Guidelines; Revision

13 PCP 2.13; Reactor Water Sampling; Revision 17

PCP 6.10; Reactor Coolant Iodine and

CR [[]]

UD Activity; Revision 9

1EP 6 Drill Evaluation Emergency Plan Implementing Procedure (

EPIP ) 1.1; Determination of Emergency Action Levels; Revision

27 EP [[]]

IP 1.2; Notifications; Revision 39

EAL -01; Emergency Action Level Matrix - Modes 1, 2, 3; Revision 7

EAL -02; Emergency Action Level Matrix - Modes 4, 5; Revision

6 EPIP 6.1; Drill and Exercise Program; Revision 0 Emergency Planning Department Manual (

EPDM ) 1008; Emergency Response Drill and Exercise Program; Revision

12 EPDM 1010; Emergency Planning Department Performance Indicators; Revision 10

EPDM 1015; Scenario Development Program; Revision 6

EPDM [[]]

FORM [[]]

EP -035; Drill/Exercise Objective & Eval Process; Revision 7

08TD 2-Declaration of 10

ENS Communicator Contacted

NRC Via Public Phone System

CAP 057794;

CAQ - 08

TD 2-NOTE 5 Initiation from EOF Not Performed to Expectations

CAP 057810;

EC Did Not Clearly Announce Transfer of Command & Control to the

08TD 2-

TSC [[]]

CAP 057829;

CAQ - 08

TD 2-General Emergency Note 5 Deficiencies

CAP 057836;

EAL Bases Document Index in Manual is Incorrect

08TD 2-

CAP 057896;

DEP -PI Opportunities from the

08TD 2-Failed

EOF for Notifications at

GE [[]]

ACE 001851;

DEP -PI Opportunities from the

08TD 2-Failed

EOF for Notifications at

GE [[]]

2PS 1 Radioactive Gaseous And Liquid Effluent Treatment And Monitoring Systems

CAP 056724;

NCAQ - Two Out of Three Telephones and

GAY -Tronic Pages at Offgas Stack Does Not Work

CAP 043695; Precursors to Declining Performance in the Environmental Monitoring Program as a Result of an environmental Monitoring Program Assessment

PDA -06-018

CE 005381; Trace Levels of Tritium were Identified in the Liquid Effluent of the Sewage Treatment Plant in February and March 2007

CE 004888; Failure to Collect Tritium sample Prior to Discharging 1T-22 Neutralizer Tank

Corrective Action (CA) 047225;

2007 RP [[[Radiation Protection]/Chem Focused Self Assessment-]]

REMP and

ODAM to Add Palo Strawberry Farm to

REMP [[]]

CAP 052110;

CAQ - Effluent Monitor Setpoints; No Consideration Given to Hard to Detect Isotopes

CE 005716;

NCAQ - Investigate Analysis of Gaseous Effluent Particulate Filters for Iron-55

CA 047679;

NCAQ - Tritium Identified in

CST [[[Condensate Storage Tank] Pit Sample]]

CA 046756; Two

RE [[]]

MP Program Sample Locations are Not Precise

CA 046754; Enhance

ODAM Description of Surveillance and Sampling Frequency

CE 004194; Precursors to Declining Performance in the environmental Monitoring Program 08-36628; Power Off to Required

REMP Air Samplers

DAEC [[]]

ODAM ; Appendix B, Technical Bases for Effective Dose Factors; Revision 25

8STP [[]]

NS 790301;

GSW [[[General Service Water] Radiation Monitor Calibration; Revision 10]]

STP [[]]

NS 790305;

RHRSW [[[Residual Heat Removal Service Water] Radiation Monitor Calibration; Revision 8 06-006-R; Radiological Engineering Calculation;]]

10 CFR 61 Compliance Data Technical Basis for

DAEC Reactor Water Clean-up Resin; dated April 17,

2007 DAEC [[]]

ODAM; Offsite Dose Assessment Manual for Gaseous and Liquid Effluents; Revision 25

X/Q Accumulation for Elevated Average sec/cm3 from Four Release Points, 2005 - 2006; Various Dates

STP 3.6.4.3-03; Surveillance Test Procedure; Standby Gas Treatment System

HEPA and Charcoal Filter Efficiency Tests; Revision

19 STP [[]]

NS 290201; Surveillance Test Procedure;

TSC Standby Filter Unit

HEPA and Charcoal

Testing; Revision 2 Radiation Engineering Calculation No. 07-002-C; Calculated Default Setpoint Value for Reactor Building

KAMAN with a Realistic Building Release Flow Rate; dated November 29, 2007

DAEC Ground Water Protection Initiative Site Conceptual Model; dated December 19,

2007 EBD -R; Abnormal Rad Levels Radiological Effluents;

EAL Bases Document; Revision

9 SA 044334;

RP [[[Radiation Protection]/Chem Focused Self Assessment:]]

REMP and

ODAM [[]]

OTH [[]]

ER 021502; Review Recent Meteorological and Dispersion Coefficient Data as Compared

to

ODAM Defaults Procedure Change Request 047495;

ODAM Figure 5-2, Map of Location is Missing Location No. 3 1.5

DAEC Safety; Characterize and Control Potential Inputs of Radioactive Water to Groundwater to Minimize Impact and Meet

NEI Industry Initiative; from June 13, 2006; dated

June 13, 2007 Radiation Engineering Calculation No. 07-002-C; Calculated Default Setpoint Value for Reactor Building

KAMAN with a Realistic Building Release Flow Rate; dated November 29, 2007

STP [[]]

NS 791005; K2 Calibration; Surveillance Test Procedure;

KAMAN Turbine Vent Shaft Normal Range Kaman Monitor; Revision 11

STP [[]]

NS 791007; K4 Calibration; Surveillance Test Procedure;

KAMAN Reactor Building Vent Shaft 1 Normal Range; Revision 9

STP [[]]

NS 791012; K10 Functional Test Surveillance Test Procedure;

KAMAN Off Gas Stack Normal Range; Revision 4 06-001-R; Radiological Engineering Calculation;

10 CFR 61 Compliance Data Technical Basis for

DAEC Condensate Resin; dated May 22, 2006 06-005-R; Radiological Engineering Calculation;

10 CFR 61 Compliance Data Technical Basis for

DAEC Dry Active Waste; dated August 13,

2006 NG -107Z;

UFSAR Change Request N0.05-031; Main Steam Line Radiation Monitor Safety Functional Trip; dated April 16, 2007

PCP 7.2A;

ORTEC Spectroscopy System Calibration; Revision

3 PCP 7.3A; Operation of

ORTEC Gamma Spectroscopy System; Plant Chemistry Procedures 3200 Manual; Revision 5

4OA 1 Performance Indicator Verification

NRC PI Data Calculation, Review and Approval; Report Quarter No. 1 Year 2007; dated April 12, 2007

NRC [[]]

PI Data Calculation, Review and Approval; Report Quarter No. 2. Year 2007; dated July 12,

2007 NRC [[]]

PI Data Calculation, Review and Approval; Report Quarter No. 3. Year 2007; dated October 15, 2007

9NRC [[]]

PI Data Calculation, Review and Approval; Report Quarter No. 4. Year 2007; dated January 14,

2008 FPL Nuclear Division Nuclear Administrative Procedure-206;

NRC Performance Indicators; Revision

3 ACP 1402.4;

NRC &

WANO Performance Indicator Reporting; Revision 13

NRC [[]]

PI Data Calculation, Review and Approval Report for

RCS Activity; Report Quarter No. 2

Year 2007; dated July 13,

2007 NRC [[]]

PI Data Calculation, Review and Approval Report for

RCS Activity; Report Quarter No. 3. Year 2007; dated October 12, 2007

NRC [[]]

PI Data Calculation, Review and Approval Report for

RCS Activity; Report Quarter No. 4. Year 2007; dated January 14, 2008

NRC [[]]

PI Data Calculation, Review and Approval Report for

RCS Activity; Report Quarter No. 1. Year 2008; dated April 10, 2008

NRC [[]]

PI Data Calculation, Review and Approval Report for

RCS Leakage; Report Quarter No. 2 Year 2007; dated July 18,

2007 NRC [[]]

PI Data Calculation, Review and Approval Report for

RCS Leakage; Report Quarter No. 3. Year 2007; dated October 12, 2007

NRC [[]]

PI Data Calculation, Review and Approval Report for

RCS Leakage; Report Quarter No. 4.

Year 2007; dated January 7, 2008

NRC [[]]

PI Data Calculation, Review and Approval Report for

RCS Leakage; Report Quarter No. 1. Year 2008; dated April 9, 2008

NEI 99-02; Regulatory Assessment Performance Indicator Guideline; Revision 5

4OA 2 Identification and Resolution of Problems

CAP 057150;

CB Chiller Temperature Load Controller

TLC 6924A

CAP 057445;

CAQ - 1G21 'B'

SBDG Tripped during Maintenance Run

CAP 057465;

CAQ - 1E053B3 Expansion Bellows Leaking

CAP 057492;

CAQ - Error Found in Technical Requirements Manual Basis Document

ACE 001848; 1G21/

ENG Tripped During Maintenance Run

ACE 001849; Apparent Cause Evaluation for 1E053B3 Expansion Bellows Leakage

ACP 114.4; Corrective Action Program; Revision

23 ACP 114.5; Action Request System; Revision 69

ACP 114.8; Action Request Trending; Revision 6

TRMCR -030; Technical Requirements Manual Change Request: Revise Bases for

TLCO 3.0.5 to match the wording of

TS [[]]

LCO 3.0.5 Bases

ACEM ; Apparent Cause Evaluation Manual; Revision 9

RCEM ; Root Cause Evaluation Manual; Revision 14

4OA 3 Follow-up of Events and Notices of Enforcement Discretion

CAP 058266;

CAQ - Lack of Diverse Communications (Phone and Data)

CAP 058284;

NCAQ - Evaluate if Additional Domestic Water Sampling is needed due to Flood

CAP 058291;

CAQ - Flood - Normal Operator Rounds at Intake and "D" Well not Completed

CAP 058292;

CAQ - 8-hour Reportable Notification Made for Loss of Offsite Response Capability

CAP 058295; CAQ - 8-hour Reportable Notification Made for Loss of Offsite Communications

Capability

CAP 058298;

CAQ - Unusual Event Declared Based on Loss of Communication Capability

CAP 058296;

CAQ - Partial Loss of Communications see

SEL 08-091

CAP 058301;

NC [[]]

AQ - Sixth Street Line Unavailable as Offsite Power Source

10CAP 058302;

NCAQ - Hiawatha Line Unavailable as Offsite Source

CAP 058303;

NCAQ - Adequate Grid Voltage Available Upon Loss of Fairfax Line

CAP 058304;

CAQ - Aux Outside Out Rounds Suspended due to River Level Concerns

CAP 058305;

NCAQ - Notification by

ATC of Contingency Grid Voltage from Trip of

DAEC [[]]

CAP 058307;

NCAQ "- Hazelton-Hills Line [[power source" contains a listed "[" character as part of the property label and has therefore been classified as invalid. [kilovolt] Alarms in Switchyard House]]

CAP 058313;

CAQ - Flood - Normal Operator Rounds not Completed

CAP 058315;

NCAQ - Lessons Learned From Flood

CAP 058317;

NCAQ - 50.59 Applicability Question

CAP 058320;

CAQ - Partial Loss of Pager Functionality

CAP 058324;

CAQ - Water in Bottom of

CST [[[Condensate Storage Tank] Level Switch Panel]]

LS 5219

CAP 058326;

CAQ - Degraded Barrier

CAP 058328;

CAQ - Flood 2008 - Recovery Strategy to Return to Daily

RWS [[[River Water Supply] Pump Swaps]]

CAP 058332;

CAQ - Minor Backfill Washout Noted on Northwest Corner of Intake Structure

CAP 058335;

NCAQ - Difficulty in Receiving Severe Weather Watch and Warning Info

CAP 058339;

ATC Unable to Run Grid Voltage Contingency Cases -

MISO Can

CAP 058340;

NC [[]]

AQ - Water Coming into Turbine Building along Cableway

CAP 058348;