IR 05000461/2011008

IR 05000461-11-008, on 05/16/2011 - 06/03/2011, Clinton Power Station; Identification and Resolution of Problems

ML11189A129
Person / Time
Site:	Clinton
Issue date:	07/08/2011
From:	Ring M A NRC/RGN-III/DRP/B1
To:	Pacilio M J Exelon Generation Co, Exelon Nuclear
References
IR-11-008
Download: ML11189A129 (35)

Text

UNITED STATES NUCLEAR REGULATORY COMMISSION REGION III 2443 WARRENVILLE ROAD, SUITE 210 LISLE, IL 60532

-4352 July 8, 2011 Mr. Michael Senior Vice President, Exelon Generation Company, LLC President and Chief Nuclear Officer (CNO), Exelon Nuclear 4300 Winfield Road Warrenville IL 60555

SUBJECT: CLINTON POWER STATIO N NRC PROBLEM IDENTIFICATION AND RESOLUTION INSPECTION REPORT 05000461/20 11008

Dear Mr. Pacilio:

On June 3, 2011, the U.S. Nuclear Regulatory Commission (NRC) completed a Problem Identification and Resolution inspection at your Clinton Power Station. The enclosed report documents the results of this inspection, which were discussed on June 3, 2011, with Mr. K. Taber and other members of your staff.

The inspection examined activities conducted under your license as they relate to safety and compliance 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 inspectors concluded that your staff was effective at identifying problems and incorporating them into the corrective action program (CAP). However, the NRC inspectors identified degradation in Clinton Power Station's evaluation of issues entered into the CAP. Operating Experience (OE) was appropriately screened and disseminated. Audits and self-assessments were determined to be performed at an appropriate level to identify deficiencies, although there were a few instances where station audits had the opportunity

, but failed to identify issues that were later found by the NRC inspection team. On the basis of interviews conducted during the inspection, workers at the site expressed freedom to enter safety concerns into the CAP.

Based on the results of this inspection, three NRC-identified finding s of very low safety significance were identified. One of the findings identified during this inspection was related to the accuracy of an evaluation performed for an operability determination. The second Green finding identified during this inspection was related to an inadequate evaluation that led to a failure to maintain a quality record. The third finding identified during this inspection was related to a failure to measure the effectiveness of Corrective Actions to Prevent Recurrence (CAPRs) as required by station procedures.

The finding s involved violation s of NRC requirements. However, because of their very low safety significance, and because the issues were entered into your corrective action program, the NRC is treating the issues as n on-cited violation s (NCVs) in accordance with Section 2.3.2 of the NRC Enforcement Policy. If you contest the subject or severity of the s e NCV s, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the U.S. Nuclear Regulatory Commission, ATTN: Document Control Desk, Washington, DC 20555-0001, with a copy to the Regional Administrator, U.S. Nuclear Regulatory Commission

- Region III, 2443 Warrenville Road, Suite 210, Lisle, IL 60532

-4352; the Director, Office of Enforcement, U.S. Nuclear Regulatory Commission, Washington, DC 20555

-0001; and the Resident Inspector Office at the Clinton Power Station. In addition, if you disagree with the cross

-cutting aspect assigned to any finding in this report, you should provide a response within 30 days of the date of this inspection report, with the basis for your disagreement, to the Regional Administrator, Region III, and the NRC Resident Inspector at the Clinton Power Station.

In accordance with 10 CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter, its enclosure, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records System (PARS) component of NRC's document system (ADAMS). ADAMS is accessible from the NRC Website at http://www.nrc.gov/reading

-rm/adams.html (the Public Electronic Reading Room).

Sincerely,/RA/

Mark A. Ring, Chief Branch 1 Division of Reactor Projects Docket No. 50

-461 License No. NPF

-62

Enclosure:

Inspection Report 05000 461/20 11008;

w/Attachment:

Supplemental Information cc w/encl:

Distribution via ListServ

Enclosure U.S. NUCLEAR REGULATORY COMMISSION REGION III Docket No:

50-561 License N o: NPF-62 Report No:

05000 461/20 11008 Licensee: Exelon Generation Company, LLC Facility: Clinton Power Station Location: Clinton, IL Dates: May 16 through June 3, 2011 Inspectors:

R. Orlikowski, Project Engineer (Team Lead)

A. Dahbur, Senior Reactor Inspector D. Lords, Resident Inspector, Clinton Power Station A. Shaikh, Reactor Inspector S. Mischke, Illinois Emergency Management Agency Approved by:

Mark A. Ring, Chief Branch 1 Division of Reactor Projects Enclosure

SUMMARY OF FINDINGS

IR 05000 461/20 11008, Clinton Power Station;

Identification and Resolution of Problems.

This inspection was conducted by three region-based inspectors, the NRC Resident Inspector at the Clinton Power Station, and the onsite Illinois Emergency Management Agency (IEMA) inspector. Three Green finding s were identified by the inspectors. The findings were considered non-cited violation s (NCV s) of NRC regulations. The significance of most findings is indicated by their color (Green, White, Yellow, Red) using Inspection Manual Chapter (IMC) 0609, "Significance Determination Process" (SDP). Findings for which the SDP does not apply may be Green or be assigned a severity level after NRC 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.

On the basis of the sample s selected for review, the team concluded that implementation of the corrective action program (CAP) at Clinton Power Station was generally effective, although there has been a degradation in Clinton's CAP over the past two years. The licensee had a low threshold for identifying problems and entering them in the CAP. Items entered into the CAP were screened and prioritized in a timely manner using established criteria and were generally implemented in a timely manner commensurate with their safety significance. However, t he inspectors identified degradation in the licensee's evaluation of issues entered into the CAP. Specifically, there were several instances where the corrective actions associated with Action Requests (ARs) were not adequate or not appropriate for the circumstances. Additionally, the inspectors identified multiple instances where Effectiveness Reviews (EFRs) were not performed to assess the effectiveness of Corrective Actions to Prevent Recurrence (CAPR s). The team noted that the licensee reviewed operating experience for applicability to station activities. Audits and self-assessments were usually performed at an appropriate level to identify deficiencies, although there were a few instances where station audits had the opportunity

, but failed to identify issues that were later found by the NRC inspection team.

On the basis of interviews conducted during the inspection, workers at the site expressed freedom to enter safety concerns into the CAP.

Identification and Resolution of Problems A.

Cornerstone: Mitigating Systems

N RC-Identified and Self-Revealed Findings GreenThe inspectors determined that this finding was more than minor because it was associated with the Mitigating Systems Cornerstone attribute of design control and . The inspectors identified a finding of very low safety significance with an associated NCV of 10 CFR Part 50, Appendix B, Criterion III, "Design Control," related to calculational errors found in the licensee's operability determination. Specifically, on four separate operability determinations

, the licensee failed to account for the cable resistance when determining the maximum allowable contact resistance associated with the second level undervoltage (UV) relays for the 4.16 kV Buses. The licensee entered this violation into its CAP as Action Requests (ARs) 1226340 and 1224313 and performed a preliminary calculation which determined that the error reduced the available margin in the circuit resistance but did not change the overall conclusions for the past operability calls made for the four different occasions.

adversely affected the cornerstone objective of ensuring availability and reliability o f systems that respond to initiating events to prevent undesirable consequences. This finding was of very low safety significance (Green) because the licensee was able to demonstrate that the operability calls that were previously made relating to the sec ond level UV relays were still valid and acceptable. The inspectors concluded that this finding affected the cross-cutting aspect of human performance. Specifically, the licensee failed to use conservative assumptions in decision making related to immediate operability determinations of condition s adverse to quality

. [IMC 0310 H.1(b) (Section 4OA2.1.b(2)(1)) GreenThe inspectors determined the finding was more than minor because, if left uncorrected, failure to maintain a quality record as evidence of an activity affecting quality of safety-related equipment due to inappropriate disposition of CAs pertaining to missing/lost quality records could become a more significant safety concern

. This finding was of very low safety significance because this finding did not represent an actual loss of any safety function of the Mitigation Systems. The inspectors concluded that this finding affected the cross-cutting aspect of human performance. Specifically, the licensee did not ensure complete, accurate and up-to-date design documentation and work packages. [IMC 0310 P.1(d) (Section 4OA2.1.b(2)(2)) . The inspectors identified a finding of very low safety significance with an associated NCV of 10 CFR Part 50, Appendix B, Criterion XVII

, "Quality Assurance Records." Specifically, the licensee failed to maintain a quality record documenting a nondestructive examination (NDE) of a safety-related spreader beam lifting device. After losing the original NDE report, the licensee's corrective action (CA) was to recreate the report from memory and maintain the recreated report as the quality record. Upon review and questioning from the NRC, the licensee was able to locate the missing NDE report in the records archive.

This issue was entered into the licensee's CAP as AR 1223723.

Cornerstone: Initiating Events

GreenThe finding was of more than minor significance because it was similar to Example 4a in IMC 0612, "Power Inspection Reports," Appendix E, "Examples of Minor Issues," in that

, the licensee routinely failed to perform EFR evaluations on similar CAs related to significant conditions adverse to quality. The finding was a licensee performance deficiency of very low safety significance due to answering 'no' to all questions under the Initiating Events Cornerstone column of IMC 0609 Attachment 4, "Phase 1

- Initial Screening and Characterization of Findings." The inspectors concluded that this finding affected the cross-cutting aspect of problem identification and resolution. Specifically, the licensee failed to thoroughly evaluate problems to include conducting EFRs of CA s to ensure that problems were resolved.

[IMC 0310 P.1(c) (Section 4OA2.1.b(3)(1)) . The inspectors identified a finding of very low safety significance with an associated NCV of 10 CFR 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings." The licensee failed to perform an effectiveness review (EFR) to ensure that CAs taken to prevent recurrence of a significant condition adverse to quality were actually effective to preclude repetition. The licensee entered this violation into its CAP as ARs 1221616, 1221661, and 1223806 to investigate the cause and to identify appropriate CAs.

B. No violations of significance were identified.

=

Licensee-Identified Violations===

4. OTHER ACTIVITIES

REPORT DETAILS

4OA2 Problem Identification and ResolutionThe activities documented in sections

.1 through .4 constitute

d one biennial sample of problem identification and resolution as defined in Inspection Procdure (IP) 71152.

(71152B)

.1 a. Assessment of the Corrective Action

Program Effectiveness The inspectors reviewed the licensee's CAP implementing procedures and attended CA P meetings to assess the implementation of the CAP by site personnel.

Inspection Scope The inspectors reviewed risk and safety

-significant issues in the licensee's CAP since the last NRC Problem Identification and Resolution (PI&R) inspection in April 20 09. The selection of issues ensured an adequate review across NRC cornerstones. The inspectors used issues identified through NRC generic communications, department self-assessment s, licensee audits, operating experience (OE) reports, and NRC documented findings as sources to select issues. Additionally, the inspectors reviewed issue reports generated as a result of facility personnel's performance in daily plant activities. In addition, the inspectors reviewed A Rs and a selection of completed investigations from the licensee's various investigation methods, which included root cause, apparent cause, equipment apparent cause, common cause, and quick human performance investigations.

The inspectors selected one high risk system

, the Emergency Diesel Generator System, to review in detail. The inspectors' review was to determine whether the licensee staff were properly monitoring and evaluating the performance of this system through effective implementation of station monitoring programs. This five year review on the Emergency Diesel Generator System was undertaken to assess the licensee staff's efforts in monitoring for system degradation due to aging aspects.

During the reviews, the inspectors determined whether the licensee staff's actions were in compliance with the facility's CAP and 10 CFR Part 50, Appendix B requirements. Specifically, the inspectors determined if licensee personnel were identifying plant issues at the proper threshold, entering the plant issues into the station's CA P in a timely manner, and assigning the appropriate prioritization for resolution of the issues. The inspectors also determined whether the licensee staff assigned the appropriate investigation method to ensure the proper determination of root, apparent, and contributing causes. The inspectors also evaluated the timeliness and effectiveness of CAs for selected issue reports, completed investigations, and NRC findings, including NCVs.

b. (1) Assessment Issues were generally being identified at a low threshold, evaluated appropriately, and corrected in the CAP. Workers were familiar with the CAP and felt comfortable raising Effectiveness of Problem Identification

5 Enclosure concerns. This was evident by the large number of CAP items generated annually

which were reasonably distributed across the various departments. A shared, computerized database was used for creating individual reports and for subsequent management of the processes of issue evaluation and response. These processes included determining the issue

's significance, addressing such matters as regulatory compliance and reporting, and assigning any actions deemed necessary or appropriate.

The inspector s determined that the station was generally effective at trending low level issues to prevent larger issues from developing. The licensee also used the CAP to document instances w here previous CAs were ineffective or were inappropriately closed.

As a result of an observation from the 2009 PI&R Inspection that found deficiencies in security officers

' knowledge on initiating Issue Requests, the inspectors specifically asked security officers if they had received some form of training or instruction on entering issues into the licensee's computer

-based CAP. All security officers interviewed responded that training/instruction had been provided. Additionally, the officers stated that there was a laminated instruction card available at each computer workstation with step

-by-step instructions on how to initiate issue reports.

The inspector s noted that since the 2009 PI&R Inspection, the Security organization had generated approximately 2,100 Issue/Action Reports. From these 2,100 issues , 11 trend IRs were initiated. By comparison, the Training organization generated approximately 750 IRs and 13 trend IRs during the same period. The Training Department is about one fourth the size of the Security Department. Although the Security Department meets the requirements for quarterly trending (LS

-AA-125-1005), the inspector felt that, based on numbers alone, the Security organization should be identifying/initiating more trend IRs. It may be prudent for all departments to examine their trending program to ensure trends or potential trends are being identified.

Observation During review of work order (WO) 01277109 Task ID 1, "Replace Grounded 'B' RR

[Reactor Recirculation]

Pump Motor," referenced from action AR 00988866, "RR B Motor Change Out Spreader Beam NDE INSP Report Missing," the inspectors identified that contrary to WO 01277109 guidance, the licensee had inappropriately marked

'N/A' [Not Applicable]

on step 4.2 of Task ID 1 and step 4.3 of Task ID 14 in WO 01277109. These procedure steps required inspection and supervisory oversight of rigging devices and should not have been marked 'N/A'. However, an earlier procedure step had accomplished the same function.

Failure to Follow Work Order Instructions The inspectors determined that the licensee's failure to follow instructions in Step 4.2 of Task ID 1 and Step 4.3 of Task ID 14 in WO 01277109 is a violation of Title 10 CFR 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings," which requires, in part, that activities affecting quality be performed in accordance with instructions, procedures, and drawings appropriate to the circumstance. Instructions, procedures or drawings shall include appropriate quantitative or qualitative acceptance criteria for determining that important activities have been satisfactorily accomplished.

The licensee subsequently addressed this issue of failure to follow WO instructions in the CAP as AR 1223512, "(NRC Identified) Issue Identified with WO Documentation."

6 Enclosure This failure to comply with the requirements of Title 10 CF R 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings," constitutes a violation of minor significance that is not subject to enforcement action in accordance with the NRC's Enforcement Policy.

No findings were identified.

Findings (2) The inspectors concluded that the station was generally effective at prioritizing issues commensurate with their safety significance. The inspectors observed that the majority of issues identified were of low-level and were either closed to trend, closed to actions taken, or characterized at a level appropriate for a condition evaluation. Issues were being appropriately screened by both the Station Oversight Committee (SOC) and Management Review Committee (MRC). There were no items in the operations, engineering, or maintenance backlogs that were risk

-significant, individually or collectively.

Effectiveness of Prioritization and Evaluation of Issues The inspectors concluded that the station's evaluation of issues was not always thorough and there ha d been degradation in this area of Clinton Power Station's CAP. Specifically, there were several instances where the CAs associated with ARs were not adequate or not appropriate for the circumstances. This was evidenced by two minor violations and two finding s identified during this inspection.

Observations During review of AR No. 0092284, "NDE Inspection for Strongback Is Not Identified," the inspectors identified that the licensee's CA to resolve this AR was to revise Exelon procedure MA

-AA-716-021, "Periodic Inspection of Rigging Equipment." The inspectors verified that procedure MA

-AA-716-021(revision 2) was indeed revised to identify the special lifting device inspection requirements of ANSI N14.6

-1978Property "ANSI code" (as page type) with input value "ANSI N14.6</br></br>-1978" contains invalid characters or is incomplete and therefore can cause unexpected results during a query or annotation process., "American National Standard for Special Lifting Devices for Shipping Containers Weighing 10,000 Pounds (4500 kg) or More for Nuclear Materials." However, subsequent to this revision, the licensee made another revision to procedure MA

-AA-716-021 (revision 3), which essentially removed ANSI N14.6

-1978Property "ANSI code" (as page type) with input value "ANSI N14.6</br></br>-1978" contains invalid characters or is incomplete and therefore can cause unexpected results during a query or annotation process. requirements for periodic inspection of special lifting devices from the procedure. The licensee maintain ed that upon evaluation at the time of revising MA

-A A-716-021, Rev. 2, the licensee determined that the special lifting device periodic inspection requirements as described in ANSI N

-14.6-1978 would be more appropriately captured in equipment specific documents such as Preventative Maintenance Requests (PMR Qs) and vendor specific work orders. Upon review of these special lifting device (equipment specific) documents, the inspectors identified that the licensee had not adequately included the ANSI N14.6 requirements into these documents. Specifically, the inspection requirements and periodicity of inspection of special lifting devices was not adequately addressed in these equipment specific documents.

Failure to Adequately Maintain Regulatory Requirements in Design Basis Procedures and Instructions

7 Enclosure The inspectors determined that the licensee's failure to have adequate procedures/documents for inspection of special lifting devices per ANSI Code N14.6-1978 is a violation of Title 10 CFR 50, Appendix B, Criterion III, "Design Control," which requires, in part, that measures shall be established to assure that applicable regulatory requirements and the design basis, as defined in 10 CFR 50.2 and as specified in the license application, for those structures, systems, and components to which this appendix applies are correctly translated into specifications, drawings, procedures, and instructions.

The licensee generated AR 1224057 , "Submit Service Requests to revise PMRQs 156877 & 156886 to be Consistent with the Requirements from ANSI N14.6. Document Service Request Approval and PMRQ Changes Results as Closure, and Create Additional Actions as Required

," to revise the equipment specific documents, such that they adequately capture the appropriate ANSI N14.6 requirements for periodic inspection of special lifting devices.

This failure to comply with the requirements of Title 10 CFR 50, Appendix B, Criterion III, "Design Control," constitutes a violation of minor significance that is not subject to enforcement action in accordance with the NRC's Enforcement Policy.

The inspectors identified a minor violation of 10 CFR Part 50, Appendix B, Criterion III, "Design Control," for the licensee's failure to demonstrate by calculation that the Technical Specifications (TS) upper voltage limits for the emergency diesel generator (EDG) surveillance test s were adequate to support operability of all safety-related loads. Specifically, the licensee failed to provide adequate evaluation for AR 670088670088"Non-Conservative TS for 4.16 kV Vital Bus Voltage," initiated in 2007 during a Component Design Basis Inspection (CDBI) self-assessment. The self

-assessment raised a concern regarding the upper limit for the 4.16 kV safety-related bus voltage of 4580 volts as being non-conservative. The maximum analytical limit in the design calculation was 4454 volts due to potential overvoltage on the 120 volt components. The AR evaluation concluded that the current administrative limit of 4300 volts in the surveillance procedures was adequate to limit the safety-related bus voltages to ensure their safety function. However, the inspectors determined that the licensee's evaluation failed to correctly address the concern regarding the non

-conservative TS voltage limits. The current design basis analysis did not support the TS upper voltage limit (4580 volts) for the safety-related buses. The licensee entered this issue into their CAP as AR 1226340 , "Maximum Steady State Voltage for TS 3.8.1 Nonconservative

." Failure to Demonstrate by Calculation Operability of Safety-Related Loads When Powered from the EDGs This failure to comply with 10 CFR Part 50, Appendix B, Criterion III, "Design Control," constitutes a violation of minor significance that is not subject to enforcement action in accordance with the NRC

=s Enforcement Policy.

(1) Findings Introduction

The inspectors identified a finding of very low safety significance (Green) with an associated NCV of 10 CFR 50, Appendix B, Criterion III, "Design Control," for the licensee's failure to account for the cable resistance in immediate operability Failure to Account for Cable Resistance in Operability Determinations

8 Enclosure determinations. Specifically, on four different occasions, the licensee failed to account for the cable resistance when determining the maximum allowable circuit resistance to ensure that adequate minimum voltage was available for the trip coils associated with the 4.16 KV buses.

Description

On the following four different occasions, during the performance of CPS 9333.20 and CPS 9333.30, "4.16 kV Degraded Voltage Trip Functional Test," for Division I and Division II respectively, contact resistance for the undervoltage (UV) relays w as found unacceptable. UV relays 227X1

-21A1-2 and 227X1

-21B1-2 were found to have higher than expected resistance readings across the closed contacts used to trip the Reserve Auxiliary Transformer (RAT) Feed Breaker upon initiation of a degraded voltage signal.

Typically, closed contact readings should read significantly less than 1 ohm.

During the performance of CPS 9333.30 on May 14, 2009, contacts between 4 and 5 on relay 227X1

-21B1-2 read approximately 3.6 ohms. Immediate operability determined that the trip coil was operable and would perform its function.

This issue was documented in AR 919673919673

During the performance of CPS 9333.30 on July 15, 2009, contact between 4 and 5 on relay 227X1

-21B1-2 again showed higher contact readings; anywhere from 14 to 48 ohms. Immediate operability determined that the trip coil was inoperable and subsequently, the associated emergency diesel generator was also declared inoperable. This issue was documented in AR 947824947824

During the performance of 9333.20 on July 30, 2009, contact between 11 and 20 on relay 227X1

-21A1-2 read approximately 2.43 ohms. Immediate operability determined that the trip coil was operable. This issue was documented in AR 947581947581

During the performance of CPS 9333.30 on December 17, 2009, contacts between 4 and 5 on relay 227X1

-21B1-2 again showed higher contact resistance readings of 19.4 ohms across the contacts. Immediate operability determined that the trip coil was inoperable. This issue was documented in AR 1006888.

The operability determination in all four occasions listed above was based on a simplified calculation showing that as long as the resistance between the contacts was less than 13.1 ohms, then adequate voltage of greater than 70 Vdc would be available for the trip coil to perform its function in a worst case scenario. The inspectors noticed that this acceptance criterion for the maximum contact resistance was not listed in the surveillance procedure CPS 9333.20 or CPS 9333.30. The inspectors also noticed that the equation used in the simplified calculation that determined the maximum acceptable resistance between the contacts did not account for the cable resistance for the control cables associated with the trip coil control circuitry. Subsequent to the inspector identification of this deficiency, the licensee identified the length of the cables associated with these affected circuits as a total of 860 feet and 1114 feet for Division I and II respectively. The licensee recalculated the maximum acceptable resistance value using the cable length/resistance and determined that the original calculated value of 13.1 ohms was reduced by 2.07 ohms and 2.7 ohms for Division I and II respectively.

9 Enclosure The inspectors determined that the new calculated values for the maximum resistance between the contact would not have changed the past operability determinations for the above four occasions. In addition, the licensee's two Equipment Apparent Cause Evaluations (EACEs), which were performed for AR 947581947581and AR 1006888, also determined that the apparent cause of the high contact resistance readings was due to the improper measuring technique and not actual degraded relay contact.

Analysis:

The inspectors determined that the failure to account for the cable resistance in four different operability determinations was a performance deficiency warranting a significance evaluation. The performance deficiency was determined to be more t han minor because the finding was associated with the Mitigating Systems Cornerstone attribute of design control and adversely affected the cornerstone objective of ensuring the availability of systems that respond to initiating events to prevent undesirable consequences. Specifically

, on two of the four immediate operability determinations, the licensee failed to ensure that adequate voltage would be available for the trip coils when the contact resistance for the second level under

-voltage relays was reading higher than expected. The inspectors performed a Phase 1 SDP review of this finding using the guidance provided in IMC 0609, Attachment 0609.04, "Phase 1

- Initial Screening and Characterization of Findings." In accordance with Table 4a, "Characterization Worksheet for IE, MS, and BI Cornerstones," the inspectors determined that this finding was a design deficiency confirmed not to result in loss of operability or functionality. Specifically, the licensee was able to demonstrate that the operability calls that were previously made, when the operability of the second level under

-voltage relays was in question, were still acceptable when the cable resistance was added.

The inspectors concluded that this finding affected the cross

-cutting aspect of human performance, Decision Making. Specifically, the licensee failed to use conservative assumptions in decision making affecting the operability of the second level under

-voltage relays when conditions adverse to quality were identified. (IMC 0310 H.1(b)).

Cross-Cutting Aspects Enforcement

Title 10 CFR Part 50, Appendix B, Criterion III, "Design Control," requires, in part, that measures shall be established to assure that applicable regulatory requirements and the design basis are correctly translated into specifications, drawings, procedures, and instructions.

Contrary to the above, in 2009, on four d ifferent occasions, the licensee failed to ensure that applicable regulatory requirements and design basis related to second level UV relay circuits were correctly translated into calculations used in immediate operability determinations. Specifically, the licensee failed to ensure that the cable resistance was accounted for when determining the maximum allowable circuit resistance to ensure that adequate minimum voltage was available for trip coils associated with the 4.16 kV buses. Because this violation was of very low safety significance and it was entered into the licensee's CAP as AR 01223508, this violation is being treated as an NCV, consistent with Section 2.3.2 of the NRC Enforcement Policy.

(NCV 05000461/2011008

-01, Failure to Account for Cable Resistance in Operability Determinations

). The licensee entered this into their CAP as AR s 1226340 and 1224313.

10 Enclosure (2) Failure to Maintain a Quality Record as Evidence of an Activity Affecting Quality of Safety-Related Equipment Due to Inappropriate Corrective Actions The inspectors identified a finding of very low safety significance and a NCV of 10 CFR 50, Appendix B, Criterion XVII , "Quality Assurance Records," for the licensee's failure to maintain sufficient quality records that provide evidence of activities affecting quality of safety-related equipment.

Introduction During review of AR 00988866 , "RR 'B' Motor Change out Spreader Beam NDE INSP Report Missing," the inspectors identified that the licensee did not have in their completed work order documents the NDE report that is required to qualify the spreader beam used to lift the reactor recirculation motor during the change out process in the drywell. The NDE of the critical welds of the spreader beam, which is considered a special lifting device

, is required by ANSI N14.6

-1978Property "ANSI code" (as page type) with input value "ANSI N14.6</br></br>-1978" contains invalid characters or is incomplete and therefore can cause unexpected results during a query or annotation process., "American National Standard for Special Lifting Devices for Shipping Containers Weighing 10,000 Pounds (4500 kg) or More for Nuclear Materials," prior to each use.

Description AR 00988866 dated November 4, 2009

, states that the NDE was performed on the spreader beam prior to use in lifting the reactor recirculation 'B' motor, however no record of the NDE existed in the completed work order documents. The licensee proposed three recommended actions in A R 00988866 as resolution of this CR: 1) Personnel who were involved should search their working areas to locate the missing NDE inspection report, 2) Duplicate report may be generated based on recollection of the inspection, 3)

Perform NDE inspection for the used spreader beam again and document the results per this AR (if #1 and #2 are not feasible). On November 23, 2009 , the missing NDE report was recreated based on recollection from memory of the individual who conducted the examination and approved by licensee corporate NDE.

Upon review and further questioning from the inspectors, the licensee attempted to find the missing original NDE report. After extensive searching, the licensee did find the missing original NDE report dated October 18, 2009, which differed in certain parameters from the recreated NDE report dated November 23, 2009.

The inspectors determined that the licensee's failure to maintain a quality record documenting an NDE on safety-related equipment due to inappropriate CA s is a performance deficiency that impacted the Mitigation Systems Cornerstone.

Analysis The inspectors determined that this performance deficiency was more than minor because, if left uncorrected, failure to maintain a quality record as evidence of an activity affecting quality of safety-related equipment due to inappropriate disposition of CA s pertaining to missing/lost quality records

, could become a more significant safety concern. Absent NRC identification, the licensee would deem it acceptable practice to recreate from memory, quality records of activities that affect quality of safety-related equipment in lieu of more appropriate CAs available to the licensee.

The inspectors completed a significance determination, in accordance with IMC 0609, "Significance Determination Process," Attachment 0609.04, "Phase 1

- Initial Screening 11 Enclosure and Characterization of Findings," Table 4a for the Mitigation Systems Cornerstone. Based on answering 'no' to each of the Phase 1 screening questions identified in the Mitigation Systems Cornerstone column of Table 4a, the finding was determined to be of very low safety significance. Specifically, this finding did not represent an actual loss of any safety function of the Mitigation Systems.

This finding has a cross

-cutting aspect in the area of Human Performance, Resources because the licensee did not ensure complete, accurate and up

-to-date design documentation, procedures, and work packages, and correct labeling of components. (IMC 0310 P.1(d

)) Cross-Cutting Aspects Title 10 CFR 50, Appendix B, Criterion XVII, "Quality Assurance Records," requires, in part, that sufficient records shall be maintained to furnish evidence of activities affecting quality. The records shall include at least the following:

Operating logs and the results of reviews, inspections, tests, audits, monitoring of work performance, and materials analyses. The records shall also include closely

-related data such as qualifications of personnel, procedures, and equipment.

Inspection and test records shall, as a minimum, identify the inspector or data recorder, the type of observation, the results, the acceptability, and the action taken in connection with any deficiencies noted.

Records shall be identifiable and retrievable.

Consistent with applicable regulatory requirements, the applicant shall establish requirements concerning record retention, such as duration, location, and assigned responsibility.

Enforcement Contrary to the above requirements, on November 23, 2009 , during resolution of AR 00988866 , "RR B Motor Change out Spreader Beam NDE INSP Report Missing," the licensee approved a decision to recreate from recollection of memory the missing NDE report and

, therefore , failed to maintain a sufficient quality record providing evidence of the NDE.

Failure to maintain a sufficient record that provides evidence of the NDE affecting quality of the safety-related spreader beam was a violation of 10 CFR 50, Appendix B, Criterion XVII. Because this violation was of very low safety significance and was entered int o the CAP , this violation is being treated as a n NCV consistent with Section VI.A.1 of the NRC Enforcement Policy.

(NCV 05000461/2011008

-02 Failure to Maintain Quality Record as Evidence of Activity Affecting Quality of Safety-Related Equipment). The licensee entered this issue into the CAP as AR 1223723.

(3) The effectiveness of corrective actions for the items reviewed by the inspectors was generally appropriate for the identified issues. Over the two year period encompassed by the inspection, the inspectors identified no significant examples where problems recurred.

The inspectors did identify one weakness associated with the station's use of EFRs to evaluate Corrective Actions to Prevent Recurrence (CAPR). While reviewing Root Cause Evaluations performed since the last biennial PI&R inspection in 2009, the inspectors identified six examples where Clinton Power Station failed to perform EFRs as required by the station's CAP procedures.

Effectiveness of Corrective Actions

12 Enclosure (1) Findings Failure to Perform Effectiveness Review Inspectors identified a finding of very low safety significance with an associated NCV of 10 CFR 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings." The licensee failed to perform an EFR to ensure that CAs taken to prevent recurrence of a significant condition adverse to quality were actually effective to preclude repetition.

Introduction Inspectors performed a review of the licensee's CAP with a focus, in particular, on how significant conditions adverse to quality are addressed. Exelon procedure LS

-AA-120, "Issue Identification and Screening Process," defines a significant condition adverse to quality to include "severe operating abnormalities or large deviations from expected plant performance of safe ty-related structures, systems, or components; [and] "events" such as described in the plant Technical Specifications." 10 CFR 50 Appendix B Criteria XVI requires, in part, that "In the case of significant conditions adverse to quality the measures shall ensure that the cause of the condition is determined and CA taken to preclude repetition." LS

-AA-125, Revision 15, "Corrective Action Program Procedure," Step 1.3 states that "significant conditions adverse to quality and conditions adverse to quality are resolved through direct action, the implementation of CAPRs and Corrective Actions (CAs)."

Discussion Inspectors then focused their review upon how the licensee identifies CAPRs to resolve significant conditions adverse to quality. The licensee's method to accomplish this was through its highest level of investigation, a Root Cause

Analysis.

During a general review of the licensee's Root Cause Reports completed within the previous two years, inspectors identified six examples where the licensee failed to follow it s processes for correcting significant conditions adverse to quality

.

On October 23, 2009

, the licensee completed Root Cause Report (RCR) 972235, "Valve Packing Failure inside Drywell Resulted in Plant Shutdown Due to Increasing Unidentified Leakage Rate." The conclusion of the licensee's report was that there were two root causes for the plant shutdown event: 1) That the 1E51F063 valve stem was off center with the stuffing b ox with the potential to cause packing side loading and accelerated loss of packing load, and 2) Inadequate work instruction did not require the packing in 1E51F063 to be torqued to the as

-left value from the original installation. The investigation also identified two CAPRs, one to address each root cause identified. Licensee procedure LS

-AA-125-1001, "Root Cause Analysis Manual," Revision 8, Attachment 12 identifies the attributes of a CAPR; specifically, "CAPRs are intended to address the root cause(s)in a manner to prevent recurrence, therefore, CAPRs should have the following attributes: specific, measurable, accountable, reasonable, timely, effective, reviewable, actionable, linked to a root cause, [etc]." RCR 972235 was approved by the licensee with the EFR portion blank, other than the statement that "An Effectiveness Review to address the effectiveness of the Root Cause CA is not necessary. The root cause is limited to a single valve, 1E51F063, with an off center stem to stuffing box condition.

The work order to investigate and correct the condition is sufficient assurance the condition is corrected and will no longer cause accelerated loss of packing load." This statement addresses only one of the two identified root causes 13 Enclosure and also appears contrary to the licensee's procedural guidance that a CAPR should be measurable and reviewable. After questions from inspectors, the licensee determined that its MRC had approved this RCR with comments to be incorporated, one of which was to add EFRs for the CAPRs. This action was later closed without initiating any EFR.

Further review by inspectors identified five additional examples where the licensee failed to follow their procedures with respect to CAPRs and EFRs.

1. RCR 979700, "1B33C001B: RR B Trip - Resulting in Reactor Scram," identified a Special Plant Condition as a CAPR which included the instruction to generate additional actions as needed and include the identified Root Cause, Extent of Condition/Cause, CAPRs, and EFR. No EFR was ever created.

2. RCR 1017724, "Contract Employee Contaminated in Drywell," identified one root cause, one CAPR, and did include one EFR. However, this EFR was performed to address a separate CA and not the CAPR which was identified.

3. RCR 1023530, "Gate Seal Leakage during Containment Isolation Valve System Functional Test," identified two root causes and two CAPRs. An EFR was assigned to the first CAPR and none was assigned to the second. However, on April 19, 2011

, AR 1204691 was written by the licensee's Nuclear Oversight (NOS) organization which identified this omission of a required EFR.

In this AR, NOS stated that "

failing to create and document individual EFRs could result in not identifying whether a single CAPR effectively resolved an identified cause." At the time of inspection the RCR was provided in final form to inspectors with no correction made for this identification from NOS.

4. RCR 1147568, "Re

-Evaluation Exam Provided Did Not Meet Expectations," identified one root cause and two CAPRs. The licensee assigned two EFRs to one of the CAPRs, however the EFR was marked "N/A" for the other CAPR which was identified.

5. RCR 1157980, "WANO Identified Area for Improvement for Relays and Power Supplies," identified two root causes, one CAPR and assigned two EFRs to be completed. However, these two EFRs were assigned to CAs and not the identified CAPR. Notably, in the EFR section of this report a preface was added which stated "There is no specific EFR action for the CAPR," and "no specific effectiveness criteria can be developed.

Therefore no specific EFR action is to be completed.

This was reviewed with and approved by MRC."

The inspectors determined that the licensee's failure to perform EFR s which verify that CAs taken for significant conditions adverse to quality successfully prevent their reoccurrence was a performance deficiency warranting a significance evaluation. The finding was of more than minor significance because it was similar to Example 4a in IMC 0612, "Power Inspection Reports," Appendix E, "Examples of Minor Issues," in that the licensee routinely failed to perform EFR evaluations of CAs taken to prevent recurrence of significant conditions adverse to quality. The inspectors performed a Phase 1 SDP review of this finding using the guidance provided in IMC 0609, Attachment 0609.04, "Phase 1

- Initial Screening and Characterization of Findings." Analysis 14 Enclosure In accordance with Table 4a, "Characterization Worksheet for IE [Initiating Events], MS [Mitigating Systems], and BI [Barrier Integrity] Cornerstones

," the inspectors determined that this finding was a licensee performance deficiency of very low safety significance (Green) due to answering 'no' to all questions under the Initiating Events Cornerstone column.

Inspectors concluded that this finding affected the cross

-cutting aspect of problem identification and resolution. Specifically, the licensee's CAP did not thoroughly evaluate problems to include, for significant problems, conducting EFRs of CAs to ensure that problems are resolved. (IMC 0310 P.1(c)) Cross-Cutting Aspects 10 CFR 50, Appendix B, Criteria V, "Instructions, Procedures, and Drawings," requires, in part, that activities affecting quality shall be prescribed by documented instructions, procedures, or drawings, of a type appropriate to the circumstances and shall be accomplished in accordance with these instructions, procedures, or drawings. Licensee procedure LS

-AA-125, "Corrective Action Program Procedure," Step 1.3 states that "significant conditions adverse to quality and conditions adverse to quality are resolved through direct action, the implementation of Corrective Actions to Prevent Recurrence and Corrective Actions." Step 4.4.8 of this procedure states "Perform Effectiveness Reviews in accordance with LS

-AA-125-1004, Effectiveness Review Manual." Revisions 4 and 5 of LS

-AA-125-1004, "Effectiveness Review Manual," in effect during this time period of review, contain requirements that "all CAPRs are to be evaluated in the EFR" and to "Initiate Attachment 1, 'Individual Effectiveness Review' for each of the CAPRs identified."

Enforcement Contrary to the above, on the six separate occasions previously described, the licensee failed to perform EFR s in accordance with its procedures to verify that CAs taken for significant conditions adverse to quality successfully prevent ed their reoccurrence

. Because of the very low safety significance, this violation is being treated as a n NCV consistent with Section 2.3.2 of the NRC Enforcement Policy (NCV 05000461/201 1 00 8-0 3 , Failure to Perform Effectiveness Review

). The licensee entered this violation into its CAP as ARs 01221616, 01221661, and 01223806.

.2 a. Assessment of the Use of Operating Experience

(OE) The inspectors reviewed the licensee's implementation of the facility's OE program. Specifically, the inspectors reviewed implementing operating experience program procedures, attended CAP meetings to observe the use of OE information, and completed evaluations of OE issues and events. The inspectors' review was to determine whether the licensee was effectively integrating OE experience into the performance of daily activities, whether evaluations of issues were proper and conducted by qualified personnel, whether the licensee's program was sufficient to prevent future occurrences of previous industry events, and whether the licensee effectively used the information in developing departmental assessments and facility audits. The inspectors also assessed if CAs, as a result of OE experience, were identified and implemented in an effective and timely manner.

Inspection Scope

15 Enclosure b. In general, OE was effectively used at the station. The inspectors observed that OE was discussed as part of the daily station and pre-job briefings. Industry OE was effectively disseminated across the various plant departments and no issues were identified during the inspectors' review of licensee OE evaluations. During interviews, several licensee personnel commented favorably on the use of OE in their daily activities.

Assessment No findings were identified.

Findings

.3 a. Assessment of Self

-Assessments and Audits The inspectors assessed the licensee staff's ability to identify and enter issues into the CA program, prioritize and evaluate issues, and implement effective CAs, through efforts from departmental assessments and audits.

Inspection Scope b. The inspector s concluded that self

-assessments, NOS audits, and other assessments were typically effective at identifying most issues. The inspector s concluded that these audits and self

-assessments were generally completed in a methodical manner by personnel knowledgeable in the subject area.

Corrective Actions associated with the identified issues were implemented commensurate with their safety significance.

Assessment There were a few issues identified by the inspectors that were not identified during station self-assessments and/o r audits. NOS previously identified one of the RCE's that did not include EFRs for the CAPRs. However, NOS did not identify the other five instances where EFRs were not included to review CAPRs. Additionally, as preparation for this inspection, an assessment team comprised of Clinton employees along with one Quad Cities and one Robinson Nuclear Plant employee performed a focused self assessment (FASA) on Clinton's CAP. The FASA identified no strengths, 19 recommendations, and 21 standards deficiencies.

However, the FASA did not identify any of the issues and weaknesses that were identified by the NRC inspection team. Additionally, the FASA did not identify the decline in performance of Clinton's CAP that was identified by the NRC inspection team.

No findings were identified.

Findings

.4 a. Assessment of Safety

-Conscious Work Environment The inspectors assessed the licensee's safety-conscious work environment (SCWE) through reviews of the facility's employee concerns program (ECP)implementing procedures, discussions with ECP coordinators, interviews with personnel from various Inspection Scope

16 Enclosure departments, and reviews of issue reports. The inspectors also reviewed the results of licensee safety culture surveys.

b. The inspectors determined that the plant staff were aware of the importance of having a strong SCWE and expressed a willingness to raise safety issues. No one interviewed had experienced retaliation for safety issues raised or knew of anyone who had failed to raise issues. All persons interviewed had an adequate knowledge of the CAP process.

These results were similar with the findings of the licensee's safety culture surveys.

Based on these limited interviews, the inspectors concluded that there was no evidence of an unacceptable SCWE.

Assessment The inspectors determined that the ECP process was being effectively implemented. The inspectors noted that the licensee had appropriately investigated and taken constructive actions to address potential cases of harassment and intimidation for raising issues.

No findings were identified.

Findings

4OA6

.1 Management Meetings

On June 3, 2011, the inspectors presented the inspection results to Mr. B. K. Taber, and other members of the licensee staff. The licensee acknowledged the issues presented. The inspectors confirmed that none of the potential report input discussed was considered proprietary.

Exit Meeting Summary

ATTACHMENT:

SUPPLEMENTAL INFORMATION

Attachment

SUPPLEMENTAL INFORMATION KEY POINTS OF CONTAC

T

W. Knoll, Site Vice President

Licensee

B. K. Taber, Plant Manager

A. Khanifar, Site Engineering Director

S. A. Gackstetter, Training Director

S. J. Fatora, Maintenance Director

R. E. Zacholski, Nuclear Oversight Manager (Acting)

B. W. Davis, Regulatory Assurance Manager

R. S. Frantz, Regulatory Assurance

K. Brown, Regulatory Assurance

J. M. Stovall, Radiation Protection Manager

T. P. Veitch, Chemistry Manager

J. E. Cunningham, Security Manager

T. R. Stoner, Outage Manager

R. A. Schenck, Manager Site Project Manager

D. J. Kemper, Sr. Manager Plant Engineering

C. D. Dunn, Shift Operations Superintendant

Nuclear Regulatory Commission

Mark

A. Ring, Chief, Branch 1, Division of Reactor Projects

LIST OF ITEMS OPENED, CLOSED AND DISCUSS

ED Opened and Closed

05000461/2011008

-01 NCV Failure to Account for Cable Resistance in Operability Determinations

(4OA2.1.b(2)(1)

05000461/2011008

-02 NCV Failure to Maintain a Quality Record As Evidence of an Activity Affecting Quality of Safety-related Equipment Due to

Inappropriate Corrective Actions

(4OA2.1.b(2)(2)

05000461/2011008

-03 NCV Failure to Perform Effectiveness Review (4OA2.1.b(3)(1)

Discussed None.

Attachment

LIST OF DOCUMENTS REVIEWED 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.

PLANT PROCEDURES

Number Description or Title

CPS 9333.20

Date or Revision Division I 4.16

kV Bus Undervoltage Relay (Degraded Voltage) Functional Test

December 9, 2009

CPS 9333.30

Division II 4.16

kV Degraded Voltage Trip

- Functional Test

December 9, 2009

PMRQ 159638

-05 Perform Voltage Measurement at 1PL12JB

PMRQ 158714

-08 Perform Voltage Measurement at 1PL12JA

HPP-1342-10 Procedure for Onsite Handling and Installation of Cask Pit Racks for the Clinton Nuclear Plant

Revision 1

MA-AA-716-022 Control of Heavy Loads Program

Revision 8

MA-CL-716-022-1001 Handling of Heavy Loads

Revision 0F

WC-AA-111 Predefine Process

Revision 3

EC 376454 R/0

Design Considerations Summary

ANSI N14.6

-1978Property "ANSI code" (as page type) with input value "ANSI N14.6</br></br>-1978" contains invalid characters or is incomplete and therefore can cause unexpected results during a query or annotation process. American National Standard for Special Lifting Devices for Shipping Containers Weighing 10,000 Pounds (4500 kg) or More for Nuclear Materials

February 15, 1978 MA-AA-716-021 Exelon Procedure; Rigging and Lifting Program

Revision 17

CPS 8106.03

Crane Inspection, Maintenance, and Testing (Including Special Lifts)

Revision 22e

MA-CL-716-021-1001 Periodic Inspection of Rigging Equipment

Revision 2

MA-CL-716-021-1001 Periodic Inspection of Rigging Equipment

Revision 3

LS-AA-120 Issue Identification and Screening Process

LS-AA-125 Corrective Action Program Procedure

Revision 15

LS-AA-125-1001 Root Cause Analysis Manual

LS-AA-125-1003 Apparent Cause Evaluation Manual

LS-AA-125-1004 Effectiveness Review Manual

LS-AA-126-1001 Focused Area Self

-Assessments

ANSI/ANS 56.8

-2002Property "ANSI code" (as page type) with input value "ANSI/ANS 56.8</br></br>-2002" contains invalid characters or is incomplete and therefore can cause unexpected results during a query or annotation process. Containment System Leakage Testing Requirements

NEI 94-01 Industry Guideline for Implementing Performance

-based Option of 10 CFR Part 50, Appendix J

Regulatory Guide 1.163 Performance

-Based Containment Leak

-Test Program

Attachment

PLANT PROCEDURES

Number Description or Title

CPS 1305.01

Date or Revision Primary Containment Leakage Rate Testing Program CPS 1305.01F001

Type 'B' Local Leak Rate Summary Sheet

CPS 9861.04

MSIV Local Leak Rate Test (MC

-5,6,7,8) CPS 9861.04D002

MSIV B Local Leak Rate Test Data Sheet (1MC

-8) EI-AA-101-1001 Employee Concerns Program Process

Revision 10

EI-AA-101 Employee Concerns Program

Revision 9

RP-AA-203-1001 Personnel Exposure Investigations

Revision 6

HU-AA-1004-101 Procedure Use and Adherence

Revision 4

RP-AA-301 Radiological Air Sampling Program

Revision 4

RP-AA-350 Personnel Contamination Monitoring, Decontamination, and Reporting

Revision 9

CORRECTIVE ACTION PROGRAM DOCUMENTS REVIEWED Number Description or Title

AR 0067088

Non-Conservative TS for 4.16

kV Vital Bus Voltage

AR 00947824

Division II Higher than Expected Ohmic Value on Second Level UV Relay AR 00947581

Higher than Expected Ohmic Value on Second Level UV Relay

AR 0100688

High Ohmic Value on Second UV Relay

AR 00919673

Higher than Expected Ohmic Value on Second Level UV Relay

AR 00970557

Issue with Auto Start of Division 3 Diesel Following Manual Stop

AR 01155992

Division I DG 16 Cylinder Engine Heat Exchanger

Coolant Leak

AR 00904590

UFSAR Statement Regarding Shunt Tripped Loads Incorrect

AR 01214578

Division II Diesel Generator Tripped During 9080.02

AR 00977050

NRC Information Notice 2009

-16 Spurious Relay Actuations Cause Loss of Power

AR 00953437

NRC Information Notice 2009

-10 Transformer Failures Recent Operating Experience

AR 01031112

NRC Information Notice Failure of MOVs Due to Degraded Stem Lubricant EACE 947581

Higher than Expected Ohmic Value on Second Level UV Relay

EACE 1006888

High Ohmic Value on Second UV Relay

EACE 985349

Division I EDG did not go to rated Speed and Voltage During Monthly

Surveillance Testing

EACE 969157

Incorrect Installation of K

-8A and K-32 Relays in 1E22S001B

ACE 1113608

Evaluated Division II EDG Quick Start Time

RCI 916815

-09 RCIC Tripped During Startup

RCI 1157980

-10 WANO Identified Area for Improvement for Relays and Power Supplies

01032794-02 1DG01KA/B

- Diesel Generators Fuel Oil Consumption, Revision 0

970557-02 Issue with Auto Start of Division 3 Diesel Following Manual Stop

670088-02 Non-Conservative TS for 4.16

kV Vital Bus Voltage

Attachment

CORRECTIVE ACTION PROGRAM DOCUMENTS REVIEWED Number Description or Title

AR 01152745

Key Calculation Review Issue in an Instrument Calculation

AR 01158094

Fuel Handling Components Not Matching Design Configuration

AR 01152397

1DG02KE Replace DIV 3 EDG Governor Hydraulic Lines

AR 01151739

W/O Tasks for ASME Work Not Routed to ISI for Review/Approval

AR 01155992

1DG12AA: DIV 1 DG 16 CYL Engine Heat Exchanger Coolant Leak

AR 01155146

Inspection Results from 0TF01B

-6" Boroscope

AR 01155313

Requesting Cantera to Reclassify CAT "D" Weld to CAT "A"

AR 01167888

Equivalency EC for H2 Igniter Did Not Identify Calc Impact

AR 01163955

CISI Work Order Closed Without Completing All Work

AR 01169808

NDE Did Not Perform UT for Accumulated Air on LPCS and LPCIA AR 01176939

Flow Accelerated Corrosion Program Rated Yellow

AR 01183047

Non Conservative Analysis of Hanger Support Plate

AR 01197929

Excessive External Corrosion on Valve 1W0305

AR 00909586

Vibration Aging Not Performed Per Approved Test Procedure AR 00925421

Safety-related ASME SEC. III Bolting vs. Quality Level 1

AR 00922844

NDE Inspection for Strongback is Not Identified

AR 00929815

FW Heater Shell Thickness Acceptance Criteria Based on INAPP

AR 00950308

Nonsafety O-Rings Installed in Safety-related/EQ Valves

AR 00954857

Potential Buried Line Leak Identified at NW Corner of TB

AR 00953213

Pipe 1WS11D below Acceptance Criteria for Wall Thickness

AR 00952602

Perform NDE Inspection of 1SXC3A

AR 00952609

Perform NDE Inspection of 1SXB9A

AR 00952621

Perform NDE Inspection of 1SXJ4A

AR 00952631

1WS09AA: Perform MT on Pipe to Evaluate Extent of Cracking

AR 00988866

RR B Motor Change out Spreader Beam NDE Inspection Report Missing AR 01016954

Main Condenser Tube Bundle Supports Have Erosion Damage

AR 01023478

0SY09EA, MOD4508, Replacement Part Not Like for Like

AR 01082774

NRC CDBI Calculation Used Incorrect Cooling Capacity

AR 01014784

Leakage from Insulation at 6" Condenser Nozzle

AR 01019707

Minor Imperfections Discovered During NDE of MSIV Poppet

AR 01001385

Need Code Minimum Thickness Requirements for UTS

AR 01015209

South Main Condenser Waterboxes Have Patches of Corrosion

AR 01015184

Significant Rust on Both South CW Waterbox Expansion Joints

AR 01015202

Valves 1CD098B and

D are Badly Corroded

AR 01020386

C1R12 - 1FP48S Nozzles Eliminated Without Site ENG Approval

AR 01020871

Potential NRC NCV for Weld Accessibility for Examination

AR 01020881

NRC Observation of NDE Activities in C1R12

AR 01017558

Degraded Coatings/Rust

on Liner Plates Inside Containment

AR 01017544

Floor Coating Degraded Inside Drywell Near AZ 325, EL 723

AR 01062663

OE30955 - Clinton Could Have Vulnerabilities for Exposed Pipe

AR 01103870

0WS51-8" Piping Wall Thickness below Screening Criteria

Attachment

CORRECTIVE ACTION PROGRAM DOCUMENTS REVIEWED Number Description or Title

AR 01107529 UT of 1SX93EA Finds 1 Location below the Calculated MIN

AR 01025446

1B21-F032B Fails LLRT Not Identified

AR 00947143

1WS45AA: Degraded Trend on WS Pipe Wall Thickness

AR 0106221

Alert Alarm Trend 1RIXPR023

AR 01039946

Non Low Carbon Welding Filler Material Needs Removed

ACE 1032794 Calculation 01DO06 Contained Non

-Conservative Inputs

CCA 1164913 Potential Trend

- Chemical Control

ACE 1026020 Issues Identified During C1R12 Drywell Close

-Out EACE 00951748 MCR Alarmed On SA Header Pressure Drop Due to a Failed Air Dryer Purge Check Valve

RCI 972235 Valve Packing Failure Inside Drywell Resulted in Plant Shutdown Due to Increasing Unidentified Leakage Rate

ACE 01024981 Restraining Device Placed on 1CW01PB Failed

AR 01224057

NRC Indentified Issues with PMRQ

AR 01021241 Late Scope Addition Of 1B21F022C AR 01148122 Bypassed QV

Hold Point

AR 00910239 Newly Rebuilt Compensator Found With Damaged O

-rings AR 00949402 1E51N501 Procedure Deficiency 9432.49 AR 00969157 1E22S001B-K8A F or DIV III D.G. Incorrect Installation

AR 01016173 1B33F067B

- Discovered Cracked Limitorque Housing

AR 01016831 Multiple Eng. Issues With Perm Shielding Mod

AR 01024981 Restraining Device Placed on

1CW01PB Failed AR 01048311 CCP 1SA01D: Dryer Inlet And

Purge Valves Open At Same Time

AR 01069590 1AP75E1F: Inadvertent

Loss o f 1VX04CB AR 01179979 Potential Trend On Rad Monitor Failures

AR 00907001 Procedure Adherence Fundamental As A Maint Focus Area

AR 01095255 CCA For Online Maintenance/Work Week Adverse Trend

AR 01066830 Review Of Human Performance Actions on Declining Performance

AR 01150089 ODCM Table 3.9.2-1 Item 1.F Deleted Without Updating 9432.42 AR 01152747 1SX027B 1VY006 System Test Cannot Be Completed In Full

AR 01159237 1SM001A: No HBC Lubrication Inspection Port

AR 01160216 Found Voltage Discrepancy

In App B For 9080.21 And 9080.22 AR 01165412 PMRQ Scope Change Could Have Lead To Missed

PMT AR 01172939 Gaps Identified During EFR

For Part Segregation Walkdowns

AR 01173198 Transmitter Installed Upside Down

AR 01182519 1DG12AA Packing Leak On DIV. 1 EDG Heat Exchanger

AR 01191512 1DG006C: Valve Failed As Found Pressure Test

AR 01035683 1GC01PB: Corrective Action Not Performed

AR 01122813 1DG01KA: Fuel Leak Discovered During Maint PMT AR 01120781 1DG01KA16:

Unable To Perform Section Of 8207.09 For Diesel

AR 01143877 Unexpected Readings On Voltage And Ripple For Temp P/S AR 00972235 Drywell Pressure Rise/Floor Drain Leak Rate AR 01194749 Division 1 DG Slow Start Time

AR 00925961 TDRFP 1B Unloaded When Placing TDRFP 1A In Service

AR 00922711 Data Missed In Operating Logs For 9080.03 DIV 3 DG Run

Attachment

CORRECTIVE ACTION PROGRAM DOCUMENTS REVIEWED Number Description or Title

AR 00925880 RAT Tripped AR 00939875 Secondary Containment LCO Action Not Entered When Required

AR 00938683 LCO Action Not Previously Identified

AR 00948468 1E12F064A: RHR[Residual Heat Removal]

A Min Flow F064A Failed To Stroke Shut

AR 00959835 9000.02D001 SURVEILLANCE REQUIREMENTS

AR 00974412 Missed Opportunity To Identify TS Actions For Bypassed Rod

AR 01013399 C1R12 LL NRC Resident Observation Regarding FP Behaviors AR 01017904 Double Blade Guide Removed With Rod Inserted

AR 01113608 DIV 2 EDG Quick-Start Time > 9080.02 STEP 9.1.6 Criteria AR 01159858 Perform Reactivity Management

CCA AR 00958957 Perform CCA On Documented Gaps Within Operations

AR 01075686 Perform Reactivity Management

CCA AR 01092787 Adverse Trend In Fire Protection Barrier Impairment Process

AR 01152838 1DG01KB DIV 2 DG Oil Leak Needs Revisited

AR 01157160 CPS 3506.01 Needs Revised For Fuel Oil Sampling Criteria

AR 01173770 Inadequate Risk Perception Displayed By Crew D Supervision

AR 00926130 HPCS INOP due to DIV 4 DC Voltage Low

AR 00934528 Entered Abnormal Reactor Flow Offnormal

AR 00939898 Potential Adverse Trend In Operations Work Control

AR 00946058 Fuel Pool Cooling PMRQs Past Late Date Due To Failed 1FC004A AR 00946549 1FC004A Continued To Stroke Open After Full Open Indication

AR 00959329 IR s Routinely Routed To OPS Not Per LS-AA-120 AR 00964540 NRC Identified Disposition IR Not Properly Documented

AR 01023864 Backup Bottle For Upper Pool Gates Cannot Be Verified

AR 01042194 IR Action Not Timely

AR 01104238 Ineffective Implementation Of

Corrective Actions

RCR 917094 Perform A Root Cause Analysis on EHC Pump Quality Resolution

RCR 972235 Valve Packing Failure Inside Drywell Resulted in Plant Shutdown

RCR 979700 1B33C001B: RR B Trip

- Resulting in Reactor Scram

RCR 1017724 Contract Employee Contaminated in Drywell

RCR 1021241 Late Identification of Work Scope for 1B21F022C, Inboard Main Steam Line C Isolation Valve

RCR 1023530 Gate Seal Leakage During Containment Isolation Valve System Functional Test

RCR 1147568 Re-Evaluation Exam Provided Did Not Meet Expectations

RCR 1157980 WANO Identified Area for Improvement for Relays and Power Supplies

EACE 490449

A' Electro

-Hydraulic Control System Pump Erratic Pressure Control

ACE 802707

1EH01PB Has Pencil Size Leak From Compensator

ACE 910239

Recurrence of Inadequately Refurbished EHC Pump Compensators

EACE 1017464

Investigate Failure of 'B' MSIVs

AR 8027078027071EH01PB Has Pencil Size Leak From Compensator

AR 9007009007001EH01S: Declining Main EHC Header Pressure Trend

AR 9051679051671EH01PA Pump Pressure Erratic During Pump Jog

AR 9082629082621EH01PA Pressure Oscillating 1400

- 1500 psig AR 910239910239Newly Rebuilt Compensator Found With Damaged Orings

Attachment

CORRECTIVE ACTION PROGRAM DOCUMENTS REVIEWED Number Description or Title

AR 9145899145891EH01S: EHC Pump Test Results & Findings at Vendor Facility

AR 917094917094Perform a Root Cause Analysis on EHC Pump Quality Resolution

AR 927530927530Results of Effectiveness Review for AR 490449490449AR 950746 1EH01PA: Main EHC Pump A Discharge Pressure Lowering

AR 9507539507531EH01S: Main EH Pump Discharge Filter DP Increasing Trend

AR 9831389831381EH01PA: Main EHC Pump A Making Occasional Abnormal Noise

AR 9936859936851EH01PA: EH Pump A Discharge Pressure Degrading

AR 9939749939741EH01PA: Pressure Compensator Needs Adjustment

AR 994192994192EH 'B' Pump Local Discharge Pressure Gauge Reading Low

AR 9977119977111EH01FB: EH Pump 'B' Discharge Pressure Has Decreasing Trend

AR 1020527 NOS ID MSIV LLRT Test Data Anomalies

AR 1021798 EHC 'A' Pump (1EH01PA) Not Operating Properly

AR 1056553 Received PPC Alarm on EH

-DA201 Main EHC Pressure

AR 1060386 1EH01PA: Unexpected Low Pressure Main EHC (PPC Alarm)

AR 1160255 Steam Bypass EHC 'B' Pump Oscillating Pressure

AR 1165585 SB EHC Pump 'B' Oscillating Pressure

AR 1179468 Inadequate Response to NER NC

-10-036 AR 1188640 Low Discha

rge Pressure 1EH01PB During Weekly Jog AR 1193664 1C85D002PB: Bypass EHC Skid Pressure Oscillating

AR 1198169 EHC Pump Repair/Overhaul by Pump OEM to Reduce Problems

AR 1204691 NOS ID Root Cause Report Does Not Contain EFR or EFRS

AR 1211557 1H13-U703: Spurious Halon Alarms are a Distraction

AR 1017464 1B21F028A: 9861.04 LLRT on MSL A, B, and C Test Failure

AR 1059673 NOS ID MSIV As

-Found Results Re

-Evaluate Reportability

AR 1099320 CA 1033113

-03 Extension Paperwork

AR 1207467

Potential Creep Away from Meeting Regulatory Requirements

AR 1207487

Depth of Investigation for NRC Findings and Violations

AR 1090813

Possible Gap ID'd During SOER 02

-04 Effectiveness Review

AR 0792128

Potential Degrading Trend in Human Performance

AR 1046015

NOS ID Security Program Performance Rated Yellow

AR 1050574

NOS ID Elevation of Operations of Automatic Vehicle Barriers

AR 1185699

Identified Trend un Human Error Prevention Fundamental

AR 1089919

RP 2 nd Quarter HU Events

CCA 905077

Negative Trend in Human Performance Events in 2009

AR 0989128 Potential Low Level Internal Contamination

AR 1017853

Individual Contaminated in RT Hold Pump Room

AR 1167779

Identified Trend with Errors made by Security Supervision

AR 1099410

Security: Evaluate for CCA in Security Declining HU

CCA 913798 Trng-Potential Trend

-Clock Reset

CCA 937393 Trng - Potential Trend Training Records Issues

CCA 1089222 Trng - Check-In Assess I

D'd Deficiency In DTC

Performance

CCA 1125966 Clinton Training Dept Performance Common Cause Analysis

CCA 1167605 Trng-Potential Trend ID'd During NTD

Qtrly C&A CCA 915153 Increase In HU

Events Tracking I

R CCA 965371 Potential Trend

-Security Regulation Violations

CCA 1037104 Security Identified Organizational Issues Requiring C

CA

Attachment

CORRECTIVE ACTION PROGRAM DOCUMENTS REVIEWED Number Description or Title

CCA 1167779 Identified Trend With Errors Made By Security Supervision

CCA 1120908 Trend IR: IR's Associated With Weapons And Ammunition

CCA 1051723 Security - Adverse Trend In Firearms Qualifications

CCA 1185699 Identified Trend In Human Error Prevention Fundamental

CCA 1185701 Identified Trend With Physical Security Fundamental

RCE 1101545 Trng- 5 Of 6 ILT

Students Failed Comp Exam #2

ACE 935792 Trng - Final Exam Failures

ACE 1077324 Trng- Unqualified Instructor Performed Evaluation

ACE 1108724 Trng - Ineffective CA On Trng Records Quality

ACE 1122532 Trng: Consequential Exam Security Event While Performing J

PM ACE 1021622 Questions Regarding Search At Unitech Laundry Facility

ACE 1041649 Inadvertent

AVB Manipulation

ACE 1052555 Potential Inattentive Security Officer ACE 1077623 Violation Of Work Hour Rules (WHR

) CCA 969936

Trng - Analysis Of Exam Failures For A Common Cause

IR 924558 Trng: F ASA Deficiency For Training Request Action Response

IR 937396 Trng - Peat Missing Disposition To Recommended Actions

IR 944094 Controlled Copy Number Not Marked On Controlled Copy Binder

IR 954980 Trng - C RC Meeting Cancelled Due To Illness

IR 967010 Trng - Ops Procedures Reference A Superseded Procedure

IR 978652 Trng Clearance Writer/Preparer T

PE Template Error

IR 996224 Trng: Critical Task Wording Needs Improved

IR 1007200 Trng - Scenario Critical Step Enhancement

IR 1019320 Broken Tabs On 1

E 31-R551 Recorder

IR 1020492 HPCS Test Prep Switches

IR 1023625 C1 R12 Ll - Perform Auto Act/Isol Tests At Front Of Outage IR 1026054 Trng Component Changed In Employee's L

MS History Panel

IR 1036041 Trng - One E P Quiz Question Had Two Possible Answers

IR 1067400 Trng Chemistry Training Reschedule

IR 1083426 N TD - Category 2 Parts Found At Maint. Learning Center

IR 1093396 M RC Rejected NTD

C CA On Question Quality

IR 1095615 Trng - Instructor Late For Class

IR 1152017 Contin Training ID

Potential CPOS Bus Damage Vulnerability

IR 1178145 O IO - Benchmarking Accrediting Board Chairman Feedback

IR 1190426 Trng-P CRA- Cps 4004.01 Loss Of I

A IR 908802 Security PIDS Zone Is Locked On

IR 911659 Detect Lane M

SO At Risk Of Inattentiveness At Nonpeak Times

IR 920462 1JB05-STI-2: S TI02 Alarm Point Locked On

IR 922993 P Z 18/19 Malfunction Locked On

IR 930689 Gate Will Not Close IR 936894 BRE #1 Interior Folding Wall Table Disconnected From The Wall

IR 954911 NSSS BOP Training Needed

IR 970224 Brake And Signal Light Out

IR 992652 Security X

-Ray #3 Inoperable

IR 1005909 Enhancement For Intake At Screenhouse

IR 00939150 789' Ctmt Level 2 Personal Contamination Event

Attachment

CORRECTIVE ACTION PROGRAM DOCUMENTS REVIEWED Number Description or Title

IR 01012816 Level 1 PCE

2010-01 IR 01020244 Reforecast Of C1R12 Exposure Goal And Stretch Goals

IR 00968090 Potential Adverse Trend Identified

IR 01147953 USAR Table Needs Updated

IR 01158522 Procedure Change Needed For Cps 3822.07 C002

IR 01172431 IR Not Written For Ed Dose Alarm

IR 00923067 Reoccurring

Loss Of Power

IR 01039689 Inadequate Closure Of E

FR IR 01039691 Inadequate Closure Of E

FR IR 01083224 Water Backing Up In Floor Drains

OPERATING EXPERIENCE

Number Description or Title

910219 TRNG-CPS 3304.04 Requires Revision Per OpEx 25417 - OIO 1099404 Enhancement To SOER 02

-4 (Davis-Besse) Continuing Training

27685 EMD SOER 98

-2 Training ID'D Unnecessary Work Performed

1102960 Security OpEx: Oyster Creek Schedule Concerns

- OIO 1149784 OpEx Review: OE 32446 Security Drill SGI/Sensitive [Sic] Documents

AUDITS, ASSESSMENTS, SELF-ASSESSMENTS, AND EVALUATIONS

Number Description or Title

CL-2009-E-013 Revision 50.59 Evaluation

- Deferral of Division 3 DG

Fuel Oil Storage Tank Cleaning to September 2009 and a 25% Interval Extension to Regulatory Guide 1.137 10 Year FOST Cleaning Frequency for all

Division EDGs

Revision 0

CL-2010-S-029 50.59 Review

- Temporary Modification to Lift Input from A10 Device to A11 Device for the Division I Diesel Generator

Revision 0

CL-2009-S-054 50.59 Review

- Division III DG Auto Start Immediately Following LOOP

[Loss of Offsite Power] After Manual Stop

Revision 0

CL-2009-S-004 50.59 Review

- Replacement of the Existing A3 Speed Relay Switch Assembly for the Division I EDG Revision 0

Report No. C1R12

-

078 Liquid Penetrant Examination Report for Weld

CRDH-210% January 24, 2010

ER-AA-335-003 Magnetic Particle Examination

Revision 3

ER-AA-335-004 Magnetic Particle Examination

Revision 4

RM-AA-101 Records Management Program

Revision 8 LS-AA-110 Commitment Management

Revision 7

Self Assessment (SA) 887965-02 Operations Burden Aggregate Process

Attachment

AUDITS, ASSESSMENTS, SELF-ASSESSMENTS, AND EVALUATIONS

Number Description or Title

SA 1056012-03 Revision Pre-NRC PI&R Inspection FASA

SA 1147578-21 MCR Deficiency & B Priority Work Process

NOSA-CPS-10-06 Training & Staffing (AR# 995676)

June 8, 2010

NOSA-CPS-10-07 FFD, Access Authorization & Corporate Security (AR# 995688)

August 20, 2010

AR 699108699108Ops Training Objectives 1, 2, 3, 4, 5, 6 FASA June 2, 2009

AR 861208861208Safeguards Control FASA

April 30, 2009

AR 860982860982Equip Performance Testing & Maint & OCA FASA

August 4, 2009

AR 904733904733Training - Admin & Records Check

-In Report September 22, 2009

AR 1106585 Training - Technical Human Performance Check

-In Report January 5, 2011

AR 1071455 DTC Roles & Responsibilities Check

-In Report March 10, 2011

AR 1011842 Firearms Practice & Range Check

-In Report December 21, 2010

AR 1132993 Turnover & Briefings Check

-In Report March 16, 2011

QHPI 971566 Trg - Consequential Exam Security Event

QHPI 993075 Trng: Improper Instructor Use Of HU Tools During JPM

s QHPI 1013316 NEIT Consequential Exam Security Event

QHPI 909344 Handgun Fell From Holster During Arming Process QHPI 941815 Security First Aid Injury Elevated To OSHA

Recordable

QHPI 1041285 Dropped Handgun

QHPI 1089400 AVB Inappropriately Lowered

QHPI 1099266 Security Officer On Post Without Contingency Equipment QHPI 1140526 Security Training

- Loss Of Exam Control

FASA 1056012

-03 Pre-NRC PI&R Inspection FASA

976693-02 Check-In Self-Assessment: Site safety Culture

861223-02 Check-In Self-Assessment: Safety Culture Procedure Implementation

WORK ORDERS AND DRAWINGS Number Description or Title Work Order (WO) 01277109 Revision Replace Grounded 'B' RR Pump Motor

WO 00336929 /PMRQ 156877

MM Inspect System Dryer/Separator Strongback

WO 00014659 /PMRQ 156886

MM Inspect Strongback Carousel Hoists, Tensioners

Training Request

2010-02-0013A Chemistry CRC

- The use of Fixatives

Revision 0

Training Request Chemistry CRC

- The use of Gel Fixatives

Revision 0

Attachment

WORK ORDERS AND DRAWINGS Number Description or Title 2010-02-0012A Revision CONDITION REPORTS GENERATED

DURING INSPECTION

Number Description or Title

AR 1223508 Computation Error in IR 919673 AR 1217584 Closure of IR 670088 Action 04 not Clearly Documented

AR 1223723 NRC PI&R: WO 988866

-99 Has Two NDE Exams for Same Item

AR 1223512 NRC Identified Issue With WO Documentation

AR 1221646 NRC PI&R: Root Cause 972235 Does Not Have EFR As Required

AR 1221661 NRC PI&R: Root Cause 979700 Does Not Have EFR As Required

AR 1223806 NRC PI&R EFRs Not Identified As Required

AR 1224527 NRC PI&R: As

-Found LRT For Each MSIV Not Performed In C1R12

AR 1223723

NRC PI&R:

Inaccuracies in Reproduced Document

AR 1223508

1AP9EH227X1 NRC PI&R Issue

- Computation Error in IR 919673

AR 1226340

Maximum Steady State Voltage for TS 3.8.1 Nonconservative

AR 1224313

TS 3.8.1 Design Basis/Licensing Basis Inconsistency

AR 1225436

Inaccurate Information Provided to NRC in License Amendment

AR 1224057

(NRC Identified) Issue Identified with PMRQ

Attachment

LIST OF ACRONYMS USE

D ADAMS Agencywide Document Access Management System

AR Action Request

ASME American Society of Mechanical Engineers

CA Corrective Action

CAP Corrective Action Program

CAPR Corrective Action to Prevent Recurrence

CDBI Component Design Basis Inspection

CPS Clinton Power Station

CFR Code of Federal Regulations

DC Direct Current

DG Diesel Generator DRP Division of Reactor Projects

EACE Equipment Apparent Cause Evaluation

ECP Employee Concerns Program

EDG Emergency Diesel Generator

EFR Effectiveness Review

FASA Focused Area Self Assessment

FSAR Final Safety Analysis Report

IEMA Illinois Emergency Management Agency

IMC Inspection Manual Chapter

IP Inspection Procedure

IR Inspection Report

ISI Inservice Inspection

kV Kilovolt LCO Limiting Condition for Operation

LLRT Local Leak Rate Testing

LOOP Loss of Offsite Power

MRC Management Review Committee MSIV Main Steam Isolation Valve

MSL Main Steam Line

N/A Not Applicable

NCV Non-Cited Violation

NDE Nondestructive Examination

NOS Nuclear Oversight

NRC U.S. Nuclear Regulatory Commission

OE Operating Experience

PARS Publicly Available Records

System PI&R Problem Identification and Resolution

PMRQ Preventative Maintenance Request

RAT Reserve Auxiliary Transformer

RCR Root Cause Report

RFP Reactor Feed Pump

RHR Residual Heat Removal

RR Reactor Recirculation

SCWE Safety-Conscious Work Environment

SDP Significance Determination Process

SOC Station Oversight Committee

TS Technical Specification

UV Undervoltage

Attachment

Vdc Volts Direct Current

WO Work Order

M. Pacilio

-2- If you contest the subject or severity of the

s e NCV s, you should provide a response

within 30 days of the date of this inspection report, with the basis for your denial, to the U.S. Nuclear

Regulatory Commission, ATTN: Document Control Desk, Washington, DC

20555-0001, with a copy to the Regional Administrator, U.S. Nuclear Regulatory Commission

- Region III, 2443 Warrenville Road, Suite 210, Lisle, IL 60532

-4352; the Director, Office of Enforcement,

U.S. Nuclear Regulatory Commission, Washington, DC 20555

-0001; and the Resident Inspector Office at the Clinton Power Station. In addition, if you disagree with the cross

-cutting aspect assigned to any finding in this report, you should provide a response within 30 days of the date

of this inspection report, with the basis for your disagreement, to the Regional Administrator, Region III, and the NRC Resident Inspector at

the Clinton Power Station.

In accordance with

CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter, its enclosure, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records System (PARS) component of NRC's document system (ADAMS). ADAMS is accessible from the NRC Website at http://www.nrc.gov/reading

-rm/adams.html

(the Public Electronic Reading Room).

Sincerely, /RA/

Mark

A. Ring, Chief

Branch 1 Division of Reactor Projects

Docket No. 50

-461 License No. NPF

-62 Enclosure:

Inspection Report 05000

461/20 11008; w/Attachment: Supplemental Information

cc w/encl:

Distribution via ListServ

DISTRIBUTION

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DOCUMENT NAME: G:\DRPIII\1-SECY\1-WORK IN PROGRESS

\CLINTON BIENNIAL PIR 2011.DOCX

Publicly Available

Non-Publicly Available

Sensitive Non-Sensitive To receive a copy of this document, indicate in the concurrence box "C" = Copy without attach/encl

"E" = Copy with attach/encl "N" = No copy

OFFICE RIII E RIII E RIII RIII NAME MRing for ROrlikowski

MRing:cs DATE 0 7/08/11 0 7/08/11 OFFICIAL RECORD COPY

Letter to M. Pacilio from M. Ring dated

July 8, 2011

SUBJECT: CLINTON POWER STATION NRC PROBLEM IDENTIFICATION AND RESOLUTION INSPECTION REPORT 05000461/2011008

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