IR 05000387/2014009
| ML14216A216 | |
| Person / Time | |
|---|---|
| Site: | Susquehanna  |
| Issue date: | 08/01/2014 |
| From: | Bower F L Reactor Projects Region 1 Branch 4 |
| To: | Rausch T S Susquehanna |
| bower, fl | |
| References | |
| IR-14-009 | |
| Download: ML14216A216 (42) | |
Text
August 1, 2014
Mr. Timothy Senior Vice President and Chief Nuclear Officer PPL Susquehanna, LLC 769 Salem Boulevard Berwick, PA 18603-0467
SUBJECT: SUSQUEHANNA STEAM ELECTRIC STATION NRC PROBLEM IDENTIFICATION AND RESOLUTION INSPECTION REPORT AND NOTICE OF VIOLATION 05000387/2014009 AND 05000388/2014009
Dear Mr. Rausch:
On June 20, 2014, the U. S. Nuclear Regulatory Commission (NRC) completed an inspection at your Susquehanna Steam Electric Station (SSES), Units 1 and 2. The enclosed report documents the inspection results discussed on June 20, 2014, with Mr. Jon Franke and other members of your staff. This inspection examined activities conducted under your licenses as they relate to identification conditions of your licenses. Within these areas, the inspection involved examination of selected procedures and representative records, observations of activities, and interviews with personnel. Based on the samples selected for review, the inspectors concluded that although PPL Susquehanna, LLC (PPL) had developed adequate program procedures for identifying, evaluating, and resolving problems; however, there were several continuing weaknesses Specifically, the inspectors determined that PPL did not consistently prioritize and evaluate issues commensurate with the safety significance of the identified problem, as described in the documented weaknesses in evaluations of operability. In addition, based on the samples reviewed, the inspectors concluded that corrective actions for identified deficiencies were not always complete and adequate with several weaknesses noted in the areas of efficacy and timeliness. Of note, the inspectors identified issues with corrective actions to address the sample of NRC non-cited violations and findings since the last biennial problem identification and resolution inspection. One violation of very low safety significance (Green) is cited in the enclosed Notice of Violation (Notice) and the circumstances surrounding it are described in the subject inspection report. The violation was evaluated in accordance with the NRC Enforcement Policy. The current http://www.nrc.gov/about-nrc/regulatory/enforcement/enforcement-pol.html). This violation is being cited in the Notice because all of the criteria specified in Section 2.3.2.a of the NRC Enforcement Policy for a non-cited violation were not satisfied. Specifically, PPL failed to restore compliance within a reasonable amount of time after the issue was discussed in a formal exit meeting on January 24, 2014 and documented in NRC Inspection Report 05000387;388/2013005 on February 14, 2014. You are required to respond to this letter and should follow the instructions specified in the enclosed Notice when preparing your response. If you have additional information that you believe the NRC should consider, you may provide it in your response to the Notice. The NRC review of your response to the Notice will also determine whether enforcement action is necessary to ensure compliance with regulatory requirements. Also, this report documents three NRC-identified findings of very low safety significance (Green). The inspectors determined that each of these findings also involved a violation of NRC requirements. However, because of the very low safety significance and because they were entered into your corrective action program, the NRC is treating these findings as non-cited violations, consistent with Section 2.3.2 of the NRC Enforcement Policy. If you contest these non-cited violations, you should provide a response within 30 days of the date of this inspection report, with the basis for your denial, to the Nuclear Regulatory Commission, ATTN: Document Control Desk, Washington, DC 20555-0001, with copies to the Regional Administrator, Region I; the Director, Office of Enforcement, United States Nuclear Regulatory Commission, Washington, DC 20555-0001; and the NRC Resident Inspector at the Susquehanna Steam Electric 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 I, and the NRC Resident Inspector at Susquehanna Steam Electric Station. 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 (PARS) component of the http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).
Sincerely,/RA/ Fred L. Bower, III, Chief Reactor Projects Branch 4 Division of Reactor Projects Docket Nos.: 50-387; 50-388 License Nos.: NPF-14, NPF-22
Enclosure:
Inspection Report 05000387/2014009 and 05000388/2014009
w/Attachment:
Supplementary Information cc w/encl: Distribution via ListServ
SUMMARY OF FINDINGS
IR 05000387/2014009, 05000388/2014009, 06/02/2014 06/20/2014; Susquehanna Steam Electric Station, Units 1 and 2; Identification and Resolution of Problems. The inspectors identified four findings in the areas of Effectiveness of Problem Identification, Effectiveness of Prioritization and Evaluation of Issues, and Effectiveness of Corrective Actions. This NRC team inspection was performed by two resident inspectors and two regional inspectors. The inspectors identified four findings of very low safety significance (Green) during this inspection and classified these findings as one cited violation and three non-cited violations. The significance of most findings is indicated by their color (i.e., greater than Green, or Green, White, Yellow, Red) and determined using Inspect-cutting aspects are determined using IMC -of NRC requirements are disposinuclear power reactors is described in NUREG- Problem Identification and Resolution (PI&R) The inspectors concluded that PPL Susquehanna, LLC (PPL) was generally effective in identifying, evaluating, and resolving problems. PPL personnel identified problems and entered them into the corrective action program at a low threshold. However, the inspectors noted several examples of missed identification of conditions adverse to quality during the onsite weeks of inspection and throughout the two year period. The inspectors identified one violation for the failure to identify and correct significant piping corrosion. The inspectors concluded that, although PPL Susquehanna, LLC (PPL) had developed adequate program procedures for identifying, evaluating, and resolving problems; there were several continuing weaknesses assocorrective action program. Specifically, based on the samples reviewed, the inspectors concluded that PPL did not consistently prioritize and evaluate issues commensurate with the safety significance of the identified problem, as described in the documented weaknesses in evaluations of operability. The inspectors identified two violations and two documented observations in this area. Specifically, the inspectors identified programmatic weaknesses in the timely completion of operability evaluations and the failure to identify and correct the effects of excessive vibrations and water hammer events in a safety related system. In addition, the inspectors noted that causal analyses did not always appropriately consider the extent of condition or previous occurrences of the issue, such as the documented examples for alarms during High Pressure Coolant Injection (HPCI) surveillance testing and corrective actions for emergency operating procedure deviations. Based on the sample reviewed, the inspectors determined that PPL had several weaknesses in the areas of efficacy and timeliness of corrective actions. Of note, the inspectors identified issues with corrective actions to address the sample of NRC non-cited violations, and findings since the last biennial problem identification and resolution inspection. The inspectors identified one violation for the continuing failure to restore compliance for a degraded condition related to EAL implementation.
The inspectors concluded that PPL adequately identified, reviewed, and applied relevant industry operating experience to Susquehanna operations. In addition, based on those items -assessments and audits were adequate. Based on the limited interviews the inspectors conducted over the course of the inspection, observations of plant activities, and reviews of individual corrective action program and employee concerns program issues, the inspectors did not identify any indications that site personnel were unwilling to raise safety issues nor did they identify any conditions that could The inspectors took action to ensure that the scope of this problem identification and resolution inspection did not overlap the upcoming 95002 inspection at Susquehanna, currently scheduled for July 2014. The limited review of safety culture was performed in accordance with Inspection Procedure 71152 requirements, and the inspectors did not review any of the root or apparent causes related to the affected performance indicators subject to further 95002 inspection.
Cornerstone: Mitigating Systems
- Green.
The inspectors identified a Green non-cited violation (NCV) of 10 CFR Part 50, corrective actions for a condition adverse to quality involving the emergency service water (ESW) and residual heat removal service water (RHRSW) systems. Specifically, PPL did not take timely and appropriate corrective actions to address carbon steel pipe wall thinning on the B ESW and B RHRSW discharge piping on the lower level of the ESW pump house. PPL completed immediate corrective actions including cleaning the affected piping, conducting ultrasonic testing (UT) thickness testing of the affected piping, calculating acceptance criteria for the UT tests (minimum wall thickness), and calculating a degradation rate of the piping given worst case historical corrosion and water in the environment. Additional actions included initiation of multiple condition reports (CR) to enter the issues into the corrective action program (CR-2014-18803, CR-2014-18945, CR-2014-18932), and plans to add the piping to the PPL Pipe Corrosion Program (PCP) for trending and future examination consideration. The finding is more than minor because if left uncorrected, the performance deficiency had the potential to lead to a more significant safety concern. Specifically, the wetting and associated external corrosion of the piping without appropriate monitoring could adversely impact the structural integrity of the B RHRSW and ESW headers. In addition, the finding is similar to the example 3.i in Inspection Manual Chapter (IMC) 0612 Appassess whether the actual wall thickness met minimum structural integrity requirements. deficiency affected the Mitigating Systems Cornerstone. Using IMC 0609, Appendix A, ings At-issued June 19, 2012, the inspectors determined that this finding is of very low safety significance (Green) because the finding does not represent an actual loss of function of one or more non-Tech Spec Trains of equipment designated as high safety-significant inspectors determined that this finding had a human performance cross-cutting aspect related to Consistent Process because PPL did not use their decision making process consistently to re-evaluate decisions to ensure they remained appropriate when previous decisions were called into question. Specifically, despite repeated identification of pipe wetting conditions and observations of worsening corrosion, plant personnel did not re-evaluate structural integrity. Additionally, plant personnel used an inconsistent approach in dealing with the issue, as was demonstrated by the difference in treatment to prevent corrosion on the A train of the RHRSW and ESW systems. [H.13] (Section 4OA2.1.c(1)).
- Green.
The inspectors identified a Green NCV of 10 CFR 50, Appendix B, Criterion V, ocument initial operability determinations in a timely manner in accordance with station procedures. Specifically, station personnel failed to complete and document initial operability determinations in a timely manner, consistent with PPL procedure NDAP-QA-In response to this issue, PPL issued Operations Directive 14-01 to reiterate the expectation that operations complete the initial operability screening within eight hours or the end of shift, whichever is shorter, as delineated in NDAP-QA-0703. Additionally, the station continues to conduct Periodic Operability Review Meetings to review a sample of operability determinations for consistency with NDAP-QA-0703. The station entered this issue into the corrective action program as condition reports 2014-18806 and 2014-19008 for further evaluation. This finding is more than minor because if left uncorrected, the continued performance of untimely initial operability determinations could become a more significant safety concern. Specifically, the failure to assess operability in a timely manner can lead to exceeding technical specification allowed completion times and required actions, up to and including required plant shutdowns. Additionally, this issue is similar to items 3.j time the deficiency has existed, combined with the number of examples identified during the inspection, the inspectors considered this issue to be programmatic. In accordance spectors determined this performance deficiency for Findings At-issued June 19, 2012, the inspectors determined that this finding is of very low safety because the performance deficiency did not result in the loss of operability or functionality of any structure, system, or component. Additionally, the inspectors did not identify any instances where an untimely initial operability screening resulted in exceeding a TS allowed outage time. The inspectors determined that this finding had a Human Performance cross-cutting aspect related to change management. In this case, PPL revised procedure NDAP-QA-0703 in March 2013 to change the guidance on timeliness without executing a change management plan to determine if the organization would be able to adhere to the more restrictive guidelines given that other corrective actions were in place to increase the required documentation for an initial operability determination. The inspectors determined that this finding had a human performance cross-cutting aspect related to
Change Management. In this case, PPL revised procedure NDAP-QA-0703, in March 2013, to change the guidance on timeliness without executing a change management plan to determine if the organization would be able to adhere to the more restrictive guidelines given that other corrective actions were in place to increase the required documentation for an initial operability determination. [H.3] (Section 4OA2.1.c(2)).
- Green.
The inspectors identified a Green NCV of 10 CFR Part 50, Appendix B, Criterion e measures to promptly correct an identified condition adverse to quality associated with the Emergency Service Water (ESW) supply lines to the 1C, 1D, 2C, and 2D Residual Heat Removal (RHR) pump motor oil coolers. PPL entered these conditions into their CAP as CR-2014-20129 and CR-2014-20129, that the ESW and RHR systems will perform their required safety functions and compensatory measures are in place to limit and monitor the pipe vibration, the inspectors determined that the noncompliance does not present an immediate safety concern. The finding is more than minor because it was associated with the equipment performance attribute of the Mitigating Systems cornerstone and adversely affected the cornerstone objective of ensuring the reliability of systems that respond to initiating events to prevent undesirable consequences. Additionally, it was similar to example opportunities to perform engineering evaluations on this condition and later evaluation determined that safety-related equipment was adversely affected. Specifically, no engineering evaluations were performed from 2009 through 2012, and post-2012 engineering evaluations did not fully bound the condition. Analysis performed after NRC identification resulted in additional evaluation and compensatory actions being implemented under CR 2014-determined this performance deficiency affected the Mitigating Systems Cornerstone. -Systems Screissued June 19, 2012, the inspectors determined that this finding is of very low safety significance (Green) since question A.1 was answered systems, but the ESW and RHR systems maintained operability. The inspectors determined that this finding had a human performance cross-cutting aspect related to Conservative Bias because PPL failed to use decision making-practices that emphasized prudent choices over those that are simply allowable. Specifically, PPL was relying on a leak-before-break assumption to support the continued operability of the safety related piping to the RHR pump motor oil coolers without sufficient priority to correct the condition adverse to quality. [H.14] (Section 4OA2.1.c(3)).
Cornerstone: Emergency Preparedness
- Green.
The inspectors identified a Green cited violatfailure to follow and maintain an emergency plan that meets the requirements of the planning standards in 10 CFR 50.47(b), in that, since October 2003, PPL did not follow and maintain a standard emergency classification and action level scheme. Specifically, PPL did not take timely corrective actions to provide an adequate means to measure temperature in nine out of 21 areas, where reactor building temperatures are considered for the fission product barrier degradation emergency action levels (EALs). As a result, Area Emergency would be declared in a degraded manner. The violation is being cited because PPL has failed to restore compliance or demonstrate objective evidence of plans to restore compliance at the first opportunity in a reasonable period of time following discussion in a formal exit meeting on January 24, 2014 and documented in NRC Inspection Report 05000387;388/2013005 on February 14, 2014. The finding is more than minor because it is associated with the Facilities and Equipment attribute of the emergency preparedness cornerstone, and adversely affected the cornerstone objective of ensuring that a licensee is capable of implementing adequate measures to protect the health and safety of the public in the event of a radiological emergency. Specifically, the continuing lack of installed temperature instrumentation or any other compensatory measures and the reliance on personnel dispatched to take temperature readings were insufficient to ensure a timely and accurate EAL classification could be made. Using IMC 0609, Appendix B, is of very low safety significance (Green) because the finding was determined to be an example of an ineffective EAL initiating condition, such that a Site Area Emergency would be declared in a degraded manner. The inspectors determined that this finding had a problem identification and resolution cross-cutting aspect related to Resolution because PPL did not take corrective actions in a timely manner nor did they take appropriate interim corrective actions to mitigate the issues while more fundamental causes are being assessed. Specifically, PPL had no corrective actions planned or taken to address the degraded EALs until NRC approval of their new EAL scheme, currently scheduled to be implemented no earlier than December 2015. [P.3] (Section 4OA2.1.c(4)).
REPORT DETAILS
OTHER ACTIVITIES (OA)
4OA2 Problem Identification and Resolution
This inspection constitutes one biennial sample of problem identification and resolution as defined by Inspection Procedure 71152. All documents reviewed during this inspection are listed in the Attachment to this report.
.1 Assessment of Corrective Action Program Effectiveness
a. Inspection Scope
(CAP) at Susquehanna. To assess the effectiveness of the CAP, the inspectors reviewed performance in three primary areas: problem identification, prioritization and evaluation of issues, and corrective action implementation. The inspectors compared performance in these areas to the requirements and standards contained in 10 CFR 50, -QA-0702, -pectors considered risk insights from the condition reports selected across the seven were condition reports (CRs) that documented for a selective sample of NRC-identified non-cited violations (NCVs) and findings that had been identified since the last biennial problem identification and resolution (PI&R) inspection completed in July 2012. Additionally, the inspectors attended Corrective Action Review Board (CARB) and Management Review Committee (MRC) meetings. The inspectors selected items from the following functional areas for review: engineering, operations, maintenance, emergency preparedness, radiation protection, chemistry, physical security, and oversight programs.
(1) Effectiveness of Problem Identification In addition to the items described above, the inspectors reviewed system health reports, a sample of completed corrective and preventative maintenance work orders, completed surveillance test procedures, operator logs, and periodic trend reports. The inspectors also completed field walkdowns of various systems on site, such as residual heat removal service water (RHRSW), emergency service water (ESW), and residual heat removal (RHR). Additionally, the inspectors reviewed a sample of CRs written to document issues identified through internal self-assessments, audits, emergency preparedness drills, and the operating experience program. The inspectors completed this review to verify that PPL entered conditions adverse to quality into their CAP as appropriate.
(2) Effectiveness of Prioritization and Evaluation of Issues The inspectors reviewed the evaluation and prioritization of a sample of CRs issued since the last NRC biennial PI&R inspection completed in July 2012. The inspectors also reviewed CRs that were assigned lower levels of significance that did not include formal cause evaluations to ensure that they were properly classifireview included the appropriateness of the assigned significance, the scope and depth of the causal analysis, and the timeliness of resolution. The inspectors assessed whether the evaluations identified likely causes for the issues and developed appropriate corrective actions to address the identified causes. Further, the inspectors reviewed equipment operability determinations, reportability assessments, and extent-of-condition reviews for selected problems to verify these processes adequately addressed equipment operability, reporting of issues to the NRC, and the extent of the issues. (3) Effectiveness of Corrective Actions review and, in some cases, field walkdowns to determine whether the actions addressed the identified causes of the problems. The inspectors also reviewed CRs for adverse trends and repetitive problems to determine whether corrective actions were effective in addressing the broader issimplementing corrective actions and effectiveness in precluding recurrence for significant conditions adverse to quality. The inspectors also reviewed a sample of CRs associated with selected NCVs and findings to verify that PPL personnel properly evaluated and resolved these issues. In addition, the inspectors expanded the corrective action review to five years to evaluate PPL actions related to RHR system issues. b. Assessment (1) Effectiveness of Problem Identification Based on the selected samples, plant walkdowns, and interviews of site personnel in multiple functional areas, the inspectors determined that PPL identified problems and entered them into the CAP at a low threshold. For example, PPL staff initiated over 20,000 CRs during the two year period of review (August 2012 through May 2014). However, the inspectors noted the following examples of missed identification of conditions adverse to quality throughout the two year period of review. In addition, the inspectors identified a weakness in the identification and evaluation of corrosion issues of the RHRSW and ESW systems, as described in the finding documented in Section 4OA2.1c(1). The inspectors concluded that PPL missed opportunities to correct these adverse conditions.
1. Failure to initiate AR or CR for Feedwater Control Issues. In IR 2013007, the NRC documented a self-an action request (AR) or CR after determining that ICS digital feedwater (FW) valve control needed to be placed in Manual Valve Control mode prior to de-energizing the 3A motor operated valve (MOV) in order to prevent a loss of all FW flow. This issue went unaddressed and subsequently on December 19, 2012, Unit 2 scrammed on low reactor pressure vessel water level when operators, while attempting to open the pump FW valve controls in automatic causing a loss of all normal FW. (FIN 2013007-03) 2. Inadequate Emergency Operating Procedures (EOP) for ATWS Scenario. In IR as recommended by the EOP guidelines, and EOP guidance is insufficient to ensure of deficiencies identified during evaluated simulator scenarios was inadequate to identify that guidance in the EOP basis document was insufficient to ensure that operators maintained level in the anticipated transient without scram (ATWS) band during the duration of a rapid depressurization. (NCV 2013004-01) Resolution of this issue is also discussed further as an observation in Section 4OA2.1.b(2) of this report. 3. Failure to Identify a RSPS Weakness During an EP Drill. In IR 2012005, the NRC identified a Green NCV associated with emergency preparedness planning standard 10 CFR 50.47(b)(14) and the requirements of Section lV.F.2.g of 10 CFR 50, Appendix E. Specifically, PPL staff did not identify a performance weakness related to an RSPS during their critique following the full-scale emergency preparedness drill. (NCV 2012005-03) 4. Inadequate Procedures for Acts of Nature. In IR 2012004, the NRC identified a procedures to respond proactively to acts of nature. PPL did not identify that the Off Normal procedure was inadequate during: the 2011 periodic procedural review; or, the documentation of inspector observations in May 2012 as part of CR 1579977. (NCV 2012004-01) (2) Effectiveness of Prioritization and Evaluation of Issues Based on the samples reviewed, the inspectors concluded that PPL did not consistently prioritize and evaluate issues commensurate with the safety significance of the identified problem, as described in the documented weaknesses in evaluations of operability.
The inspectors identified two violations and two documented observations in this area. Specifically, the inspectors identified programmatic weaknesses in the timely completion of operability evaluations documented in Section 4OA2.1.c(2) and the failure to identify and correct the effects of excessive vibrations and water hammer events in a safety related system as documented in Section 4OA2.1.c(3). In addition, the inspectors noted that causal analyses did not always appropriately consider the extent of condition or previous occurrences of the issue, such as the documented examples for lube oil level alarms during High Pressure Coolant Injection (HPCI) surveillance testing and corrective actions for emergency operating procedure deviations. Also documented below are several additional examples of ineffective prioritization or evaluation that occurred during the two year period.
(a) Inspection Observations The inspectors identified two documented observations for weaknesses in the prioritization and evaluation of issues:
Station personnel presented the apparent cause evaluation associated with CR 1745775 to the CARB on February 12, 2014. The CARB did not approve the condition, ensure all deviations are clearly evaluated, and a conclusion has been the apparent cause evaluation to the CARB on April 2, 2014, and this was -The final version of the apparent cause evaluation references DI-1675582 as the extent of condition action with a status of complete even though the extent of condition directed by the CARB was not performed. PPL entered this issue into the CAP as CR 2014-19403. The inspectors identified that the extent of condition to ensure all EPG deviations were reevaluated was not performed. The inspectors independently screened this issue in accordance with IMC 0612, xamples of Minor in the process of updating their emergency operating procedures to the Boiling Water Reactor Owners Group EPGs, Revision 3. This revision will remove all of the deviations, with the exception of those related to plant-specific equipment, from the emergency operating procedures. PPL is tracking the emergency operating procedure revision under AR-1731628.
2. HPCI Lube Oil Level Alarm Repetitive Issues Without Thorough Evaluation During performance of the Unit 2 HPCI Quarterly Flow Surveillance (SO-252-002) on March 29, 2014, the HPCI turbine oil tank HI-LO level alarm reflashed several times. PPL generated CR 2014-10144 to document the condition, and indicated that prior to the start of the surveillance run, oil level was slightly higher than midscale. The CR also stated that, during the run, the level was observed at the LO level on the indicator and Maintenance needed to add oil to prevent the alarm condition during future HPCI system operation. PPL performed an initial operability determination and concluded that HPCI was operable based on the fact that there was no oil leakage noted during system operation, operators observed normal oil pressures during the run, and the fact that operators noted
the reservoir oil level was just above the minimum mark with the system in service. The requested action was to add additional oil to provide margin to the alarm point in service. On April 1, 2014, the CR screening team classified this with no further action since oil had been added to the system under work order (PCWO) 1796933. PCWO 1796933 indicated that as found oil level in the reservoir was mid-level. About 2 gallons of oil was added and final level went On June 6, 2014, the Unit 2 HPCI Quarterly Flow Surveillance was performed and again the HPCI turbine oil tank HI-LO level alarm reflashed several times. The HI-LO alarm locked in as the operability run progressed. There was no visible indication of oil leakage and lube oil parameters were normal during the run. PPL initiated CR 2014-19076 to document the condition and again performed an initial operability determination that based HPCI operability on oil level indicating at the lower end of the acceptable level in the sight glass. Again, the CR requested maintenance to add oil and also indicated there is a known calibration issue with the level switch that provides this alarm function, which may be a contributor to this repeat issue. Operations requested a prompt operability determination (POD) to address this issue. Through the POD evaluation PPL determined that the marks on the sight glass did not correspond to the HI-LO alarms during operation, and concluded that the HI-LO level alarm was actually indicating a HI level alarm during the previous two surveillances. The inspectors thorough, in that, information supporting that the LO level alarm and not the HI level alarm was alarming was readily available in HPCI operating procedures and design basis documentation, but PPL did not review this information until the POD process prompted its review. The inspectors independently screened this issue in accordance with IMC 0612, evaluating the condition of the HPCI lube oil system did not result in a degradation of the safety function of the system. PPL generated CR 2014-18863 and CR 2014-20333 to further evaluate the issue. (b) Period Observations The NRC has previously documented specific examples of ineffective prioritization or evaluation of issues over the two year period of review such as: 1. Inaccurate Performance Indicator (PI) Data Submitted. In IR 2013002, the NRC identified a Green finding related to implementation of NDAP-QA-with Complications (USwC) performance indicator (PI) for the period of October 2012 through December 2012. Specifically, PPL did not report the Unit 2 reactor scram, which occurred on December 16, 2012, in this PI because PPL did not properly evaluate the scram in accordance with NEI 99-02 guidance. (NCV 2013004-02)
2. Transient Combustibles Stored Without Proper Evaluation. In IR 2013002, the NRC identified a Green NCV of Unit 2 Operating License Condition 2.C.(3) when PPL stored transient combustibles in restricted areas (red zone) without an evaluation by the site fire protection group. (NCV 2013002-01) 3. Inadequate Operability Determination for Failed Synchroscope Switch. In IR 2013003, the NRC identified a Green NCV of 10 CFR 50, Appendix B, an inadequate operability determination for a synchroscope switch failure that rendered offsite power and all four emergency diesel generators (EDG) inoperable. This resulted in PPL being in violation of Unit 1 TSs 3.8.1, 3.8.2, and 3.0.3, and Unit 2 TSs 3.6.4.1 and 3.8.2. An inadequate evaluation was conducted when PPL initially entered the synchroscope failure into CAP as a operability review was required. (NCV 2013003-01) 5. Failure to Report Common Cause Inoperability of Independent Trains. In IR 2012005, the NRC identified a SL IV NCV of 10 CFR 50.73 (a)(2)(vii) for PPL staff not submitting an LER within 60 days of discovery of a common cause inoperability of two independent trains of RPS electrical power monitoring. 1571200, which tracked the reportability follow-up determination, was closed on September 5, 2012. PPL personnel had determined that the event was not reportable because it did not result in a loss of safety function or condition prohibited by plant TSs, but did not complete an evaluation for a potential common cause failure mechanism in a timely fashion. (NCV 2012005-02) 6. Failure to Demonstrate Effective Preventive Maintenance. In IR 2012005, the NRC identified a Green NCV of 10 CFR 50.65(a)(2) for PPL staff not demonstrating the performance of the Unit 2 125 VDC system was being effectively controlled through appropriate preventive maintenance. PPL staff did not thoroughly evaluate the Unit 2 125 VDC system functional failure such that the resolution addressed the cause, to include proper classification. Specifically, cause evaluation (ACE) identified and addressed 125 VDC system procedural deficiencies. However, the ACE did not consider the procedural deficiencies in the maintenance preventable functional failure (MPFF) questions. (NCV 2012005-01) (3) Effectiveness of Corrective Actions Based on the sample reviewed, the inspectors determined that PPL had several weaknesses in the areas of efficacy and timeliness of corrective actions. Of note, the inspectors identified issues with corrective actions to address the sample of NRC non-cited violations, and findings since the last biennial problem identification and resolution inspection. The inspectors identified one violation (Section 4OA2.1.c(4)) for the continuing failure to restore compliance for a degraded condition related to EAL implementation.
(a) Inspection Observations In addition, the inspectors noted weaknesses in implementation of corrective actions for a previously identified NRC NCV (2013004-02). For example, on June 6, 2014, the nuclear safety risk category did not acknowledge medium operational safety risk required for a Yellow risk work window which included overlap of the RHR service water-RHR crosstie valve diagnostic while the E EDG was unavailable for substitution. Lack of rigor in procedural adherence and documentation of the Attachment F risk assessment worksheet was demonstrative of a failure to fully address lessons learned from the July 2013, 10 CFR 50.65(a)(4) violation. This issue is minor because appropriate risk management actions were taken, and PPL took efforts to minimize the duration of the yellow risk profile by reducing the scope of the diagnostic work. (b) Period Observations The NRC has previously documented specific examples of ineffective corrective actions over the two year period of review such as: 1. Failure to Take Appropriate Compensatory Actions for Failing to Meet Emergency Plan Requirements. In IR 2013004, the NRC identified a Green finding and an associated NCV of 10 CFR 50.54(q) for failing to follow and maintain an emergency plan that meets the requirements of emergency planning standard 10 CFR 50.47(b)(4). Specifically, PPL failed to take timely corrective actions to restore a degraded flood alarm in accordance with station procedures. The alarm was out-of-service from December 21, 2012 until September 23, 2013 without adequate compensatory measures in place. (NCV 2013004-03) 2. Inadequate Procedure Leads to Exceeding Technical Specifications (TS) Reactor Vessel Heatup Rate. In IR 2013003, the NRC identified a Green NCV of 10 CFR 50, procedure for monitoring adherence to pressure and temperature requirements during plant heatup and cooldown did not adequately incorporate the acceptance criteria for heatup rate specified in the plant TSs and TS bases. The inspectors noted that during a previous plant startup in June 2012, inspectors questioned whether procedure SO-200-011 adequately incorporated the heatup rate limits presconcerns and actions were taken in September 2012 to clarify the procedure. Inspectors determined that the actions taken in 2012 were inadequate to correct the deficient procedure. (NCV 2013003-03) 3. Unacceptable Preconditioning of Unit 2 Turbine Control Valve (TCV) Fast Closure Function. In IR 2013003, the NRC identified a Green NCV of 10 CFR 50, Appendix oning by performing corrective maintenance prior to recording the as-found time response for the Unit 2 TCV fast closure function. During review of performance history associated with pressure switch, PSL-C72-2N005C, inspectors identified that unacceptable preconditioning occurred that masked the as-found condition. Although degraded performance was identified during previous testing, PPL did not take timely and effective corrective actions to ensure the required maintenance did not unacceptably precondition the 24-month surveillance test. (NCV 2013003-02)
c. Findings
(1) Inadequate Corrective Action for Degraded Emergency Service Water (ESW) and Residual Heat Removal Service Water (RHRSW) Piping
Introduction.
The inspectors identified a Green NCV of 10 CFR Part 50, Appendix B, for a condition adverse to quality involving the ESW and RHRSW systems. Specifically, PPL personnel did not take timely and appropriate corrective actions to address carbon steel pipe wall thinning on the B ESW and B RHRSW discharge piping on the lower level of the ESW pump house.
Description.
On June 4, 2014, the inspectors observed corrosion on the B ESW and B RHRSW discharge headers in the lower elevation of the ESW pump house. The corrosion included non-adherent and non-superficial pieces of rust varying in size and thickness. The inspectors noted that the worst case of corrosion on the B ESW piping had occurred directly below an electrical box which showed evidence of groundwater leakage. The inspectors observed that the A trains of ESW and RHRSW piping in another area of the ESW pump house, were fully coated, unlike the B trains. Through interviews with site personnel, the inspectors confirmed that the uncoated RHRSW and ESW piping in the lower elevation of the pump house is subjected to water exposure. In addition to evidence of leakage via the electrical box, during a follow-up walkdown performed on June 17, 2014, site personnel accompanying the NRC also noted that condensation is common on the piping in this location, particularly during the winter.
The inspectors noted that the 2010 NRC component design basis inspection team had identified groundwater entering the lower elevation of the ESW pump house and collecting on the underside of the common discharge line of the B and D ESW pumps in 2010 (CR 1308498; NRC IR 20010007). An evaluation for CR 1308498, written in 2010 nt of the pump house is relatively warm year-round. When cool pond water is pumped though each of the pipes, of the identified condition, PPL performed an ultrasonic examination (UT) of the ESW piping (corrosion on the RHRSW piping was not recorded at that time). Because the piping UT results on the ESW line revealed that piping was still above nominal thickness, 0.385 inches, PPL did not assess the rate of degradation. In 2011, action requests were initiated to clean the rust off of the B RHRSW and B ESW piping and to coat the piping and pipe supports (ARs 1320400; 1320413; 1320417). A work order was also opened in 2011 to seal a penetration to prevent groundwater in-leakage through the electrical box above the ESW line (PCWO 1505054). On January 25, 2013, PPL initiated CR 1664318, to document that a field unit supervisor had walked down the lower level of the ESW pump house B division and had noted the electrical box dripping water onto the ESW piping, causing corrosion. Corrosion was noted on the RHRSW piping as well. It was also noted that other locations that were not directly below the electrical box were also found to be wet and rusting. The prompt operability assessment stated that the water on the piping was not a result of a leak from within the ESW system, and that the if the ESW piping did leak, its operability could be bounded by previous operability assessments performed on the B emergency diesel generator ESW piping which had exhibited pinhole leaks.
The Inspectors learned that a UT of the most affected area of the ESW piping, located below the electrical box, had not been performed since 2010. In addition, there were no UT records for the RHRSW piping. During 2012, PPL performed guided wave UTs for information purposes only, which demonstrated decreases in wall thickness. The inspectors also observed that the piping on the B trains had not been cleaned or coated. The inspectors questioned PPL regarding the status of any corrective actions to address the piping corrosion or to monitor the piping for integrity, based on the wet conditions in the pump house lower level, the documented historical corrosion, and observed significant corrosion present at the time of the inspection.
The work order to repair the groundwater in-leakage through the electrical box above the ESW line (PCWO 1505054, initiated December 14, 2011) was scheduled for July 2014. The work order to clean and coat the B RHRSW line (PCWO 1320738, initiated November 3, 2010) was scheduled for September 2014. The work order (PCWO 1325373, initiated November 17, 2010) to clean and coat the B ESW line, the area most vulnerable to the groundwater in-leakage and the most corroded area, was currently still in a planning phase (remained unscheduled). In addition, there were no actions to assess the structural integrity of the piping and determine the minimum wall thickness requirements. When PPL documented CR 2014-2014 piping corrosion observation, the CR referenced the nomi as the piping minimal wall thickness. Subsequent to questioning, PPL performed a calculation on June 6, 2014 (AR 2014-19095) to determine the minimum wall thickness for the piping, which resulted in and RHRSW piping, respectively. On June 7, 2014, PPL cleaned the affected areas of the ESW and RHRSW piping to the extent possible (the largest remaining pit measured approximately 1/50th of an inch) and performed UTs on the most significantly corroded areas of the RHRSW and ESW piping (PCWOs 1817490 and 1817487). The UT results showed the lowest wall thickness reading to have been The inspector questioned PPL as to whether a degradation rate had been calculated based on the change in wall thickness between the 2010 and 2014 UT examinations. On June 18, 2014, PPL calculated that, in the worst case, given present wetting conditions, the piping would see 29 mils per year of degradation on a localized area on the underside of the ESW pipe. Also, on June 18, 2014, PPL performed further calculations which reduced conservatisms in the minimum wall thickness, to show the Therefore, the inspectors considered this a condition adverse to quality because the conditions of the piping continued to degrade, unmonitored by any licensee program,
Analysis.
The inspectors determined that PPL did not take adequate corrective actions for an adverse condition associated with the B ESW and RHRSW piping was a Specifically, PPL did not take timely and appropriate corrective actions to assess the corrosion, address wetting conditions, and perform an appropriate operability determination that included assessing the piping degradation rate and calculating the minimum wall thickness to ensure that structural integrity requirements were maintained. The finding was determined to be more than minor because if left uncorrected, the performance deficiency had the potential to lead to a more significant safety concern. Specifically, the wetting and associated external corrosion of the piping, without appropriate monitoring, could adversely impact the structural integrity of the B RHRSW and ESW headers. In addition, the finding is similar to the example 3.i in IMC 0612, material condition of the piping, which did not meet the previously stated required wall thickness, PPL performed calculations to assess whether the actual wall thickness met minimum structural integrity requirements.
ce deficiency affected the Mitigating Systems Cornerstone. Using IMC 0609, Appendix A, -issued June 19, 2012, the inspectors determined that this finding is of very low safety significance (Green) because the finding does not represent an actual loss of function of one or more non-Tech Spec Trains of equipment designated as high safety-significant in The inspectors determined that this finding had a human performance cross-cutting aspect related to Consistent Process because PPL did not use their decision making process consistently to re-evaluate decisions to ensure they remained appropriate when previous decisions were called into question. Specifically, despite repeated identification of pipe wetting conditions and observations of worsening corrosion, plant personnel did not re-evaluate structural integrity. Additionally, plant personnel used an inconsistent approach in dealing with the issue, as was demonstrated by the difference in treatment to prevent corrosion on the A train of the RHRSW and ESW systems. [H.13]
Enforcement.
uires, in part, that measures shall be established to assure that conditions adverse to quality, such as deficiencies, defective material, and non-conformances are promptly identified and corrected. Contrary to the above, PPL staff did not promptly correct the degraded condition of the B RHRSW and B ESW piping from November 2010 to June 2014.
PPL completed immediate corrective actions including cleaning the affected piping, conducting UT thickness testing of the affected piping, calculating acceptance criteria for the UT tests (minimum wall thickness), and calculating a degradation rate of the piping given worst case historical corrosion and water in the environment. Additional actions included the initiation of multiple CRs to enter the issues into the CAP (CR 2014-18803, CR 2014-18945, CR 2014-18932), and planning to add the piping to the PPL Pipe Corrosion Program (PCP) for trending and future examination consideration. This violation is being treated as an NCV, consistent with Section 2.3.2 of the Enforcement Policy. (NCV 05000387;388/2014009-01, Inadequate Corrective Action for Corroded ESW and RHRSW Piping)
(2) Failure to Conduct Timely Initial Operability Determination
Introduction.
The inspectors identified a Green NCV of 10 CFR 50, Appendix B, document initial operability determinations in a timely manner in accordance with station procedures. Specifically, station personnel failed to complete and document initial operability determinations in a timely manner, consistent with PPL procedure NDAP-QA-
Description.
Per PPL procedure LS-Revision 0, after an individual initiates a condition report for a deficiency, it undergoes a supervisory review, and the supervisor then routes the condition report to the main control room for an initial operability screening by operations shift management. PPL procedure NDAP-QA-complete this initial operability screening. Section 2 of NDAP-QA-0703 requires that when degraded or non-conforming conditions are identified, equipment operability must be assessed for impact on continued safe plant operation. Guidance for timeliness of this operability screening is provided in Section 6.1.9, which states, in part, that the initial operability screening should be completed within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or the end of shift, whichever comes first. Additionally, Attachment C to this procedure reinforces this expectation and states, in part, the initial operability assessment should be made as soon as possible after the condition is discovered, and shall be within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or end of shift, whichever is shorter. In addition to timeliness requirements, NDAP-QA-0703, Section 6.1.6 requires that the initial operability screening be documented in the CAP.
Determinations and Functionality Assessments for Conditions Adverse to Quality or Safetydetermination be completed without delay and must not be postponed for results of detailed evaluations.
The inspectors noted multiple occasions where PPL did not complete and document immediate operability determinations in a timely manner. Specific examples include: On May 16, 2013, PPL issued condition report 1704558 because reactor protection system limit switches on the main stop valves would not return to the trip position while manipulating the switch arms. Station personnel did not document the initial operability screening until May 31, 2013.
On October 30, 2013, PPL issued condition report 2013-02230 due to a low oil level in the Unit 1 reactor core isolation cooling system outboard bearing. After the NRC resident inspectors questioned the status of the issue, the station completed the initial operability screening on the condition on November 8, 2013.
On November 6, 2013, PPL issued condition report 2013-03009 based on a deficiency identified by the NRC resident inspectors related to a missing seal plug resident inspectors questioned the status of the deficiency, station personnel completed the initial operability screening on this issue on November 15, 2013.
In addition to the examples above, the inspectors reviewed the screening meeting documentation of the initial operability review did not occur within the expectations discussed in NDAP-QA-0703.
the expectations for timeliness. Of those 49 condition reports, 36 had the initial operability review documented greater than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after the condition report had been initiated. the expectation for timeliness. Of those 50 condition reports, 44 had the initial operability review documented greater than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after the condition report had been initiated. Of the 75 condition reports in screening for the June 6 report, 57 did not meet the expectation for timeliness. Of those 57 condition reports, 32 had the initial operability review documented greater than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after the condition report had been initiated.
April 30, 2014. Items in this backlog included a snapshot of the total number of condition reports in initiate, supervisor review, or operability review workflow status when the report was printed for that day (i.e., potentially degraded conditions that have not yet received an initial operability determination). From April 30 through May 27, 2014, the backlog of items that fell into these categories ranged anywhere from 55 to 208 condition reports. The inspectors determined that PPL had multiple opportunities to address this issue prior to this inspection.
In March 2013, PPL revised NDAP-QA-0703 to change the guidance on timeliness of initial operability determinations from 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> to a more restrictive eight hours or the end of shift, whichever comes first. This was completed without executing a change management plan to determine if the organization would be able to adhere to the more restrictive guidelines given that other corrective actions were in place to increase the required documentation for an initial operability determination. implementation of the operability determination process, including issues with timeliness of initial operability determinations. PPL documented this trend in condition report 1704034, and performed a Level 3 evaluation on the issue. The cause evaluation noted that timeliness is addressed in NDAP-QA--an enhancement action on June 20, 2013 to communicate the expectation that operators have NDAP-QA-0703 in-hand when performing operability determinations. At the time of this inspection, this action was not yet complete and had a due date of July 18, 2014. In Octoboperations which included a review of operability determinations. This audit resulted in one condition report (2013-02357) specifically related to timeliness of initial operability determ On June 6, 2014, PPL issued Operations Directive 14-01 to reiterate the expectation that operations complete the initial operability screening within eight hours or the end of shift, whichever is shorter, as delineated in NDAP-QA-0703. The directive further specifies that if plant conditions do not allow this requirement to be met, the station shall generate a condition report to document the issue.
Analysis.
The inspectors determined that failure to complete and document an initial operability screening in accordance with station procedures was a performance deficiency is more than minor because if left uncorrected, the continued performance of untimely initial operability determinations could become a more significant safety concern. Specifically, the failure to assess operability in a timely manner can lead to exceeding technical specification allowed completion times and required actions, up to and including required plant shutdowns. Additionally, this issue is similar to items 3.j and the deficiency has existed, combined with the number of examples identified during the inspection, the inspectors considered this issue to be programmatic.
deficiency affected the Mitigating Systems Cornerstone. Using IMC 0609, Appendix A, -issued June 19, 2012, the inspectors determined that this finding is of very low safety because the performance deficiency did not result in the loss of operability or functionality of any structure, system, or component. Additionally, the inspectors did not identify any instances where an untimely initial operability screening resulted in exceeding a TS allowed outage time. The inspectors determined that this finding had a human performance cross-cutting aspect related to Change Management. In this case, PPL revised procedure NDAP-QA-0703, in March 2013, to change the guidance on timeliness without executing a change management plan to determine if the organization would be able to adhere to the more restrictive guidelines given that other corrective actions were in place to increase the required documentation for an initial operability determination. [H.3]
Enforcement.
10 CFR Part 50, Appendix B, Cridocumented procedures of a type appropriate to the circumstances and shall be accomplished in accordance with these procedures. Contrary to this requirement, from May 24, 2013 through June 6, 2014, PPL failed to accomplish activities affecting quality in accordance with prescribed procedures. Specifically, station personnel failed to complete and document initial operability determinations in a timely manner, consistent with PPL procedure NDAP-QA-Directive 14-01 to reiterate the expectation that operations complete the initial operability screening within eight hours or the end of shift, whichever is shorter, as delineated in NDAP-QA-0703. Additionally, the station continues to conduct Periodic Operability Review Meetings to review a sample of operability determinations for consistency with NDAP-QA-0703. The station entered this issue into the corrective action program as condition reports 2014-18806 and 2014-19008 for further evaluation. This violation is being treated as a non-cited violation, consistent with Section 2.3.2 of the Enforcement Policy. (NCV 05000387;388/2014009-02, Failure to Conduct Timely Initial Operability Determinations) (3) Failure to Correct Condition Adverse to Quality Related to Fatigue Stress in ESW Supply Lines to RHR Pump Motor Oil Cooler
Introduction.
The inspectors identified a Green NCV of 10 CFR Part 50, Appendix B, correct an identified condition adverse to quality associated with the Emergency Service Water (ESW) supply lines to the 1C, 1D, 2C, and 2D Residual Heat Removal (RHR) pump motor oil coolers.
Description-tie piping for Unit 1 and 2 C and D RHR pump motor oil coolers under Engineering Change (EC) 739040. The piping was installed with long threaded rod type hangers that provided support in the vertical plane, but do not prevent motion in the horizontal plane. EC 739040 also installed check valves in each supply line to prevent a failure of one ESW division from affecting the other.
From April 30, 2009 through 2014, inspectors identified seven CRs that described shaking and banging noises on Unit 1 and/or Unit 2 ESW supply piping to the C and/or D RHR motor oil coolers when ESW pumps were started and stopped or when Residual Heat Removal Service Water (RHRSW) was in operation without ESW in service. The inspectors reviewed the following CRs: CR 1140371, CR 1140829, CR 1140944, CR 1542115, CR 1563884, CR 1717214, and CR 2014-10859. Several of these CRs were repetitive in nature and closed to analysis and actions for CR 1542115. PPL initiated CR 1542115 on March 10, 2012, which identified a concern with pipe to the 1D RHR pump motor oil cooler when ESW pumps were started. PPL completed the evaluation on May 4, 2012, and concluded that further investigation and long term corrective actions were prudent to preclude undue cyclic stress/fatigue on the piping in question but that the piping was operable with no degraded condition. PPL revised CR 1542115 on January 31, 2013, to add: 1) one additional corrective action (AR/WO-1666287) for performing dye penetrant exams on the motor oil cooler supply lines to 1P202C; and, 2) two enhancement actions; one to replace the springs in the eight affected check valves (AR/WO-1666288) and a second to track the installation of the springs and generate other actions to evaluate the effectiveness of the change (EWR-1666356). The inspectors reviewed the status of the listed corrective actions for the associated CRs. Nondestructive examination (NDE) inspections assigned under CR-1542115 under PCWO-1666288 were assigned to PCWO-1675073. In review of PCWO-1675073, it was discovered that the stated NDE was performed on one weld (SPHBC139-2) on November 11, 2013 but not on another (SPHRC103-3) due to the need for scaffolding and the weld being painted with thick green paint. The inspectors questioned the status of NDE on SPHRC103-3. PPL wrote CR 2014-19089 and on June 7, 2014, NDE was performed on SPHRC103-3. When inspectors questioned if liquid penetrant surface exam NDE methods were appropriate for identification of fatigue cracking, PPL wrote CR 2014-19988 and determined it was not appropriate since fatigue cracking would occur on the inner diameter of the piping which would not be detected by liquid penetrant exams.
PPL initiated CR 2014-20129 to document this issue and performed a POD to address the current operability of the system and potential unanalyzed failure modes. The POD assessed the effects on the Ultimate Heat Sink (UHS), ESW, and the surrounding areas in the RHR pump rooms where the welds are located and determined ESW and the UHS would remain operable in the event of a weld failure. Two compensatory actions were initiated under this POD: 1) do not unnecessarily operate RHRSW without ESW in operation; and, 2) any time RHRSW or ESW is placed in service, the ESW crosstie lines to 1C, 1D, 2C, and 2D RHR motor oil coolers shall be walked down at least once per shift and within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after securing the last RHRSW pump to confirm no leakage.
On June 19, 2014, additional data on the ESW supply line to the 1C RHR pump motor oil cooler was obtained to support the ESW vibration POD under AR 2014-20505. The evaluation of the data resulted in carbon steel pipe stresses which exceed the code allowable fatigue stresses identified in the ASME Boiler Pressure Vessel Code,Section III, 1971 Edition and ASME OM-S/G-2003, Standards and Guides for Operation and Maintenance of Nuclear Power Plants. The conclusion of this evaluation evaluation conducted in CR-2014-20129 concluded that the ESW and RHR systems will perform their required safety functions and compensatory measures are in place to limit and monitor the pipe vibration; therefore, the inspectors determined that the noncompliance does not present an immediate safety concern.
Analysis.
The inspectors determined that the failure to take measures to promptly correct an identified condition adverse to quality associated with the ESW supply lines to the 1C, 1D, 2C, and 2D RHR pump motor oil coolers was a performance deficiency bility to foresee and correct. The inspectors determined that the performance deficiency was more than minor because it was associated with the equipment performance attribute of the Mitigating Systems cornerstone and adversely affected the cornerstone objective of ensuring the reliability of systems that respond to initiating events to prevent undesirable consequences. Additionally, it was similar to several opportunities to perform engineering evaluations on this condition and later evaluation determined that safety-related equipment was adversely affected. Specifically, no engineering evaluations were performed from 2009 through 2012, and post-2012 engineering evaluations did not fully bound the condition. Analysis performed after NRC identification resulted in additional evaluation and compensatory actions being implemented under CR 2014-20129. 4, deficiency affected the Mitigating Systems Cornerstone. Using IMC 0609, Appendix A, for Findings At-issued June 19, 2012, the inspectors determined that this finding is of very low safety affected the qualification of the ESW and RHR systems, but the ESW and RHR systems maintained operability.
The inspectors determined that this finding had a human performance cross-cutting aspect related to Conservative Bias because PPL failed to use decision making-practices that emphasized prudent choices over those that are simply allowable. Specifically, PPL was relying on a leak-before-break assumption to support the continued operability of the safety related piping to the RHR pump motor oil coolers without sufficient priority to correct the condition adverse to quality. [H.14] Enforcementin part, measures shall be established to assure that conditions adverse to quality, such as deficiencies and nonconformances are promptly identified and corrected. Contrary to the above, since April 30, 2009, PPL had not established measures to assure a condition adverse to quality had been corrected. Specifically, PPL had not taken measures to eliminate pipe vibration and water hammer that are causing fatigue stress in the ESW supply lines to the 1C, 1D, 2C, and 2D RHR pump motor oil coolers during various system alignments. PPL entered these conditions into their CAP as CR-2014-201conducted in CR-2014-20129, that the ESW and RHR systems will perform their required safety functions and compensatory measures are in place to limit and monitor the pipe vibration, the inspectors determined that the noncompliance does not present an immediate safety concern. This violation is being treated as an NCV, consistent with as CR-2014-21114. (NCV 05000387;388/2014009-03, Failure to Correct Condition Adverse to Quality Related to Fatigue Stress in ESW Supply Lines to RHR Pump Motor Oil Cooler) (4) Failure to Take Action to Restore Degraded Emergency Action Level (EAL) Scheme
Introduction.
The inspectors identified a Green cited violation of 10 CFR 50.54(q)(2) for the planning standards in 10 CFR 50.47(b), in that, since October 2003, PPL did not follow and maintain a standard emergency classification and action level scheme. Specifically, PPL did not take timely corrective actions to provide an adequate means to measure temperature in nine out of 21 areas, where reactor building temperatures are considered for the fission product barrier degradation emergency action levels (EALs). such that a Site Area Emergency would be declared in a degraded manner.
Description.
In 2012, during a review of Operating Experience (OE) related to inadequate instrumentation to support EAL declarations, inspectors questioned whether installed instrumentation to measure reactor building temperatures was required to support entry into the fission product barrier EAL. Specifically, 9 of the 21 areas that areas exceed maximum normal and maximum safe temperature limits. Absent installed temperature instrumentation, operator action is required to measure temperature locally. PPL stated that this was consistent with industry practice and consistent with assumptions made durifrom the NUREG-0654 EAL scheme to the NEI 99-01, Revision 4 EAL scheme in 2003. Specifically, PPL asserted that the table recognized that not all EOP criteria have installed instrumentation. For the areas that do not have installed temperature indication, PPL staff stated that they would rely on local temperatures taken manually by operators. The inspectors disagreed with this approach and opened URI 05000387;388/2012002-Nuclear Security and Incident Response (NSIR). Upon further review, in a July 2013 discussion with PPL, NSIR approach to rely on local temperature readings taken by operators. NSIR stated that a timely assessment and classification or declaration. The lack of installed temperature indication had the potential to impact declaration of all four emergency classifications, however; due to the redundancy within the fission product barrier matrix, the inspectors determined that it was reasonable that a General Emergency would be declared in a timely manner. The inspectors determined that the lack of installed instrumentation could result in untimely declarations of a Site Area Emergency, Alert, or Unusual Event. This would result in these classifications being declared in a degraded manner. The inspectors documented NCV 05000387; 388/2013005-04, Inadequate Instrumentation to Implement EALs for Fission Product Barrier Degradation in 2013 to close the URI. This violation was treated as an NCV, consistent with Section 2.3.2 of the Enforcement Policy and PPL entered this issue into their CAP as CR 1727229 and CR 2014-05421.
During the biennial Problem Identification and Resolution inspection, the inspectors selected NCV 05000387;388/2013005-04 for follow up review and determined that the evaluation performed to determine a need for compensatory measures due to the lack of temperature indication in response to CR 1727229 was deficient. Specifically, the evaluation stated that the current approach had been submitted to the NRC and had implemented. In addition, PPL asserted that the current approach provides a more thorough evaluation of possible primary system leakage than would be possible if only those areas with installed temperature indication had been included in the EAL scheme/table. As a result, PPL concluded there was no need to implement interim compensatory measures for those areas of the plant that do not have installed temperature indication and are considered for EAL entry. who, working in consultation with agency experts in NSIR, determined in inspection report 2013005 that the EAL scheme as written was not sufficient to provide timely listed three enarea temperatures; (2) incorporation of this information into plant operating procedures; and (3) obtain additional heat guns to be maintained in select plant areas to facilitate measurements. None of these enhancements were complete at the time of the biennial Problem Identification and Resolution inspection in June 2014. Permanent proposed correctscheme to NEI 99-01 Revision 6, which is subject to NRC review and approval and is projected to be completed in December 2015, nearly 4 years from the time of initial issue identification. These permanent actions and the causal evaluation which supports them were still waiting for corrective action review board (CARB) approval at the time of the inspection. The violation is being cited because PPL has failed to restore compliance or demonstrate objective evidence of plans to restore compliance at the first opportunity and in a reasonable period of time following discussion in a formal exit meeting on January 24, 2014 and documented in NRC Inspection Report 05000387;388/2013005 on February 14, 2014.
Analysis.
The inspectors determined that PPL did not take timely and effective corrective actions by not providing an adequate means to measure reactor building temperatures, which are required to support entry into the fission product barrier matrix and to make emergency classifications. The inspectors determined that this issue was The inspectors determined that the performance deficiency is more than minor because it is associated with the Facilities and Equipment attribute of the emergency preparedness cornerstone, and adversely affected the cornerstone objective of ensuring that a licensee is capable of implementing adequate measures to protect the health and safety of the public in the event of a radiological emergency. Specifically, the continuing lack of installed temperature instrumentation or any other compensatory measures and the reliance on personnel dispatched to take temperature readings were insufficient to ensure a timely and accurate EAL declaration could be made.
significance (Green) because the finding was determined to be an example of an ineffective EAL initiating condition, such that a Site Area Emergency would be declared in a degraded manner. The inspectors determined that the cause of the finding had a cross cutting aspect in problem identification and resolution because PPL did not take corrective actions in a timely manner nor did they take appropriate interim corrective actions to mitigate the issues while more fundamental causes were being assessed. Specifically, PPL had no corrective actions planned or taken to address the degraded EALs until NRC approval of their new EAL scheme that was scheduled to be implemented no earlier than December 2015. [P.3]
Enforcement.
10 CFR 50.54(q)(2) states, in part, that a licensee shall follow and maintain the effectiveness of an emergency plan that meets the requirements in Appendix E to this Part and, for power reactor licensees, the planning standards in 10 CFR 50.47(b). 10 CFR 50.47(b)(4) requires, in part, that a standard emergency classification and action level scheme is in use by the licensee, the bases of which include facility system and effluent parameters. Contrary to the above, since October 2003, PPL did not follow and maintain a standard emergency classification and action level scheme. Specifically, PPL did not take timely corrective actions to provide an adequate means to measure temperature in nine out of 21 areas, where reactor building temperature is considered for the fission product barrier degradation and is used for emclassify an emergency such that a Site Area Emergency would be declared in a degraded manner.
ete until PPL implements NEI 99-01 Revision 6, which is subject to NRC review and approval and is projected to be completed in December 2015, nearly 4 years from the time of initial issue identification and nearly twelve years since the issue first existed. Because PPL failed to restore compliance with NRC requirements within a reasonable time after the issue was discussed in a formal exit meeting on January 24, 2014 and documented in NRC Inspection Report 05000387;388/2013005 on February 14, 2014, this violation is being treated as a cited violation, consistent with the NRC Enforcement Policy, Section 2.3.2, which states, in part, that a cited violation will be considered if the licensee fails to restore compliance within a reasonable time after a violation is identified. This is a violation of 10 CFR 50.54(q)(2) and 10 CFR 50.47(b)(4). A Notice of Violation is attached. (NOV 05000387;388/2014009-04, Failure to Take Action to Restore Degraded Emergency Action Level Scheme).
.2 Assessment of the Use of Operating Experience
a. Inspection Scope
The inspectors reviewed a sample of CRs associated with review of industry operating experience to determine whether PPL appropriately evaluated the operating experience information for applicability to Susquehanna and had taken appropriate actions, when warranted. The inspectors also reviewed evaluations of operating experience documents associated with a sample of NRC generic communications to ensure that PPL adequately considered the underlying problems associated with the issues for resolution via their CAP. In addition, the inspectors observed various plant activities to determine if the station considered industry operating experience during the performance of routine and infrequently performed activities.
b. Assessment The inspectors determined that for the sample of issues reviewed, PPL appropriately considered industry operating experience information for applicability, and used the information for corrective and preventive actions to identify and prevent similar issues when appropriate. The inspectors determined that operating experience was appropriately applied and lessons learned were communicated and incorporated into plant operations and procedures when applicable.
The NRC has previously documented examples of weaknesses in the use of operating experience over the two year period of review such as: 1. Failure to Verify Adequacy Design of Molded Case Circuit Breakers (MCCB). In IR 2013010-01, the NRC identified a Green finding involving an NCV of 10 CFR Part erify or check the adequacy of design of MCCBs as described in NRC Information Notice (IN) 93--related degradation of molded case circuit breakers and to provide sources of information on MCCB periodic testing and preventive maintenance. (NCV 2013010-01)
2. Inadequate Procedure to Control Reactor Coolant Heatup Rate. In IR 2013003, the NRC documented a Green, self-revealing NCV of 10 CFR 50 Appendix B, Criterion procedures shall include appropriate quantitative or qualitative acceptance criteria for determining that important activities have been satisfactorily accomplished. failed to ensure that water properties (pressure and temperature) in the suction piping were controlled to ensure a water hammer event would not happen when establishing a low pressure injection lineup. As a result, a water hammer occurred in the piping and caused the suction relief valve to fail open. Similar issues were discussed in NRC IN 2010-ausing Residual Heat determined that OP-249-002 adequately addressed the concerns discussed in the IN. Inspectors determined that the recommendations in the IN had not been adequately incorporated into the OP-249-experience was inadequate. (NCV 2013004-04) 3. Reactor Scram due to Loss of Integrated Control System (ICS). In IR 2013011, a Green self-revealing finding was documented for the failure to evaluate operating experience for the ICS when Unit 2 lost control of reactor vessel level on November 9, 2012, requiring insertion of a manual scram. The cause of the loss of level control was the lockup of one of the two ICS network switches due to a data storm, a condition which had been described in various OE communications from April 2007 through September 2012. (NCV 2013011-01)
c. Findings
No findings were identified.
.3 Assessment of Self-Assessments and Audits
a. Inspection Scope
The inspectors reviewed a sample of audits, including the most recent audit of the CAP, departmental self-assessments, and assessments performed by independent organizations. Inspectors performed these reviews to determine if PPL entered problems identified through these assessments into the CAP, when appropriate, and whether PPL initiated corrective actions to address identified deficiencies. The inspectors evaluated the effectiveness of the audits and assessments by comparing audit and assessment results against self-revealing and NRC-identified observations made during the inspection.
b. Assessment The inspectors concluded that self-assessments, audits, and other internal PPL assessments were adequate, critical, and effective in identifying issues. The inspectors observed that personnel knowledgeable in the subject usually completed these audits and self-assessments in a methodical manner. PPL completed these audits and self-assessments to a sufficient depth to identify issues which were then entered into the corrective action program for evaluation.
The NRC has previously documented examples of weaknesses in the performance of self-assessments and audits such as: 1. Inadequate Procedure Guidance for Flooding in Emergency Core Cooling System (ECCS) Room. In IR 2013005, the NRC identified a Green NCV of TS 5.4.1, -000--169-actions directed in the procedures could complicate an internal flooding event and directed operators to enter a potentially flooded room to assess the extent and source of the flooding; an action which could render multiple trains of ECCS requiring periodic verification that event driven procedures are technically and functionally correct, the periodic review completed in April 2013 failed to identify that actions specified in the procedure could invalidate the flood design. (NCV 2013005-01)
c. Findings
No findings were identified.
.4 Assessment of Safety Conscious Work Environment
a. Inspection Scope
The inspectors interviewed individuals from the Operations, Maintenance, Security, Engineering, Radiation Protection, Chemistry, and Nuclear Oversight departments, via individual interviews, to evaluate their willingness to raise nuclear safety issues. Specifically, the inspectors interviewed personnel to determine whether they were hesitant to raise safety concerns to their management and/or the NRC. The inspectors selected the individuals randomly based on availability from the various departments on site. The inspectors also interviewed the station Employee Concerns Program coordinators and the General Work Environment Coordinator to determine what actions are implemented to ensure employees were aware of the program and its availability with regards to raising safety concerns. The inspectors reviewed the Employee Concerns Program files to ensure that PPL entered issues into the CAP when appropriate. For this inspection area in particular, the inspectors ensured the PI&R inspection scope did not overlap the upcoming 95002 inspection at Susquehanna, scheduled for July 2014. This limited review of safety culture was performed in accordance with Inspection Procedure 71152 requirements. b. Assessment During the limited interviews conducted, PPL staff expressed a willingness to use the CAP to identify plant issues and deficiencies and stated that they were willing to raise safety issues. The inspectors noted that no one interviewed stated that they personally experienced or were aware of a situation in which an individual had been retaliated against for raising a safety issue. All persons interviewed demonstrated an adequate knowledge of the CAP and the Employee Concerns Program. Based on these limited interviews, the inspectors concluded that there was no evidence of an unacceptable safety conscious work environment and no significant challenges to the free flow of information.
c. Findings
No findings were identified.
4OA6 Meetings, Including Exit
On June 20, 2014, the inspectors presented the inspection results to Mr. Jon Franke, Site Vice President and other members of the Susquehanna staff. The inspectors verified that no proprietary information was retained by the inspectors or documented in this report.
ATTACHMENT:
SUPPLEMENTARY INFORMATION
KEY POINTS OF CONTACT
- A. Jardine, Operations Director
- D. Deretz, Manager of Programs Engineering
- S. Yaros, General Work Environment Coordinator
- I. Missien, Supply Chain
- T. Case, Engineering
- D. Crispell, Employee Concerns
- R. Hoffert, Employee Concerns
- P. Brady, Design Engineering
- R. Brown, Operations Discipline Scheduler
- W. Demler, Operations Discipline Scheduler
- D. Fries, Supervisor Security Programs
- K. Klass, Emergency Operating Procedure Coordinator
- K. Kluk, Maintenance Rule Coordinator
- M. Radvansky, Design Engineering
- M. Robinson, System Engineer
- M. Ryberg, Operations Engineering Support
- M. Thorpe-Kavanaugh, Nuclear Oversight Operations Assessor
- T. Walters, System Engineer
- S. Peterkin, Radiation Protection
- K. Kluk, Maintenance Rule Coordinator
- T. Turner, Maintenance
- J. Rodriguez, Work Week Manager
- S. Sienkiewicz, PNC Supervisor (Engineering)
- A. Kuklis, System Engineer
- M. Hanover, Design Engineer
- M. Dziedzic, Level III ISI
- S. Muntzenberger, Engineering
- F. Habib, Piping Corrosion Program
Attachment
LIST OF ITEMS OPENED, CLOSED, DISCUSSED, AND UPDATED
Opened and Closed
- 05000387;388/2014009-01 NCV Inadequate Corrective Actions for Degraded ESW and RHRSW Piping (4OA2.1.c)
- 05000387;388/2014009-02 NCV Failure to Conduct Timely Initial Operability Determinations (4OA2.1.c)
- 05000387;388/2014009-03 NCV Failure to Correct Condition Adverse to Quality Related to Fatigue Stress in ESW Supply Lines to RHR Pump Motor Oil Cooler (4OA2.1.c)
Opened
- 05000387;388/2014009-04 NOV Failure to Take Action to Restore Degraded Emergency Action Level Scheme (4OA2.1.c)
Attachment
LIST OF DOCUMENTS REVIEWED
Section 4OA2: Problem Identification and Resolution
- Audits and Self-Assessments
- Self-Assessment
- 1704822, Prep for 2013 NRC EP Program Inspection Self-Assessment
- 1339438, NRC/FEMA Readiness Self-Assessment 2013-04299, Pre-PIR Focused Self-Assessment, February 2014
- AR 1344373, 2012 Security and Fitness for Duty/Access Authorization Audit NOS Audit
- 1519921, Operations Audit Report AR- AR-of Hope Creek Radiation Protection Procedures Use and Revision
- Actions to meet the requirements of CRA1434446 reads as follows:
- Conduct a focused self-assessment as part of the effectiveness review of
- ACT-06-CR-2013-04801 /
- DI-2014- Self-Assessment Number
- NCE-01-02, Configuration Management of ESSW Pumphouse area
- 55, July 1
- 11, 2001 Duane Arnold Maintenance Benchmark,
- ACT-06-CR-2013-04801/DI-2014-03405, Report Date April 9, 2014 Maintenance Performance Assessment Report Rev 6, 1st Quarter 2014 dated April 7, 2014 First Quarter 2014 Performance Assessment Report, PPL Susquehanna Station, dated April 29,
- 2014
Condition Reports
(* indicates that condition report was generated as a result of this inspection)
- ACT 1383037
- ACT 1593322
- ACT 1599412
- ACT 1708885
- CR 1140371
- CR 1140829
- CR 1496655
- CR 1532763
- CR 1538286
- CR 1541882
- CR 1541904
- CR 1541932
- CR 1542115
- CR 1543454
- CR 1562326
- CR 1563884
- CR 1578871
- CR 1590009
- CR 1596633
- CR 1602339
- CR 1604926
- CR 1605366
- CR 1610982
- CR 1614207
- CR 1616448
- CR 1616456
- CR 1616525
- CR 1616535
- CR 1628452
- CR 1628452
- CR 1634113
- CR 1638800
- CR 1641555
- CR 1641556
- CR 1642297
- CR 1643158
- CR 1643229
- CR 1647145
- CR 1648380
- CR 1648380
- CR 1659720
- CR 1661848
- CR 1662640
- CR 1664318
- CR 1664390
- CR 1664721
- CR 1666158
- CR 1667817
- CR 1668524
- CR 1668529
- CR 1669664
- CR 1670117
- CR 1671968
- CR 1675741
- CR 1675885
- CR 1676150
- CR 1681032
- CR 1681578
- CR 1700407
- CR 1703293
- CR 1704034
- CR 1704558
- CR 1717212
- Attachment
- CR 1717214
- CR 1719605
- CR 1721928
- CR 1721929
- CR 1723620
- CR 1731212
- CR 1734446
- CR 1736823
- CR 1738906
- CR 1739098
- CR 1739135
- CR 1743680
- CR 1745775
- CR 1748386
- CR 1750661
- CR 1753485
- CR 2013-01857
- CR 2013-02357
- CR 2013-02519
- CR 2013-03323
- CR 2013-03327
- CR 2013-04008
- CR 2013-04827
- CR 2013-07306
- CR 2013-07307
- CR 2014-03561
- CR 2014-03562
- CR 2014-03720
- CR 2014-03750
- CR 2014-04128
- CR 2014-04334
- CR 2014-04427
- CR 2014-05280
- CR 2014-05285
- CR 2014-05421
- CR 2014-06074
- CR 2014-06257
- CR 2014-06356
- CR 2014-06455
- CR 2014-06949
- CR 2014-06956
- CR 2014-07916
- CR 2014-08307
- CR 2014-09041
- CR 2014-09386
- CR 2014-09947
- CR 2014-09955
- CR 2014-10017
- CR 2014-10859
- CR 2014-12699
- CR 2014-13427
- CR 2014-13566
- CR 2014-14655
- CR 2014-15985
- CR 2014-17950
- CR 2014-17998
- CR 2014-18004
- CR 2014-18679*
- CR 2014-18685*
- CR 2014-18687*
- CR 2014-18803*
- CR 2014-18804*
- CR 2014-18806*
- CR 2014-18863*
- CR 2014-18932
- CR 2014-18932*
- CR 2014-18945
- CR 2014-18945*
- CR 2014-19008*
- CR 2014-19076*
- CR 2014-19086*
- CR 2014-19089*
- CR 2014-19090
- CR 2014-19105*
- CR 2014-19403*
- CR 2014-19762
- CR 2014-19981*
- CR 2014-19988*
- CR 2014-19991*
- CR 2014-20057*
- CR 2014-20129*
- CR 2014-20218*
- CR1140944
- DI 1675582
- DI 2013-02355
- DI 2014-09963
- DI 2014-10022
Drawings
- E106216, Common P&ID Emergency Service Water, Sheet 1, Revision 50 E106216, Common P&ID Emergency Service Water, Sheet 4, Revision 4 E106216, Unit 1 P&ID Emergency Service Water System A Loop, Sheet 2, Revision 53 E106216, Unit 1 P&ID Emergency Service Water System B Loop, Sheet 3, Revision 23 E106255, M-150, Revision 34, RCIC Turbine - Pump E162640, Unit 2 P&ID Emergency Service Water System A Loop, Sheet 1, Revision 45 E162640, Unit 2 P&ID Emergency Service Water System B Loop, Sheet 2, Revision 7 M-112 P&ID RHRSW Revision 52 M-2112 P&ID RHRSW Revision 29
Operating Experience
- NRC
- IN 2013-14, Potential Design Deficiency in Motor Operated Valve Control Circuitry Part 21 No. 2014-19-00
- CR-1742444,
- CR-1200895
- Attachment Non-Cited Violations and Findings
- NCV 2013004-03, Inadequate and Untimely Actions to Address a Failed Instrument Necessary for Diagnosis of Emergency Conditions
- NCV 2013005-04, Inadequate Instrumentation to Implement EALs for Fission Product Barrier Degradation
- NCV 2013003-01, Inadequate Operability Assessment of Synchroscope Switch
- NCV 2013004-01, Inadequate Procedural Guidance for Maintaining Reactor Pressure Vessel
- NCV 2013403-01, Security Finding
- FIN 2012004-01, Inadequate Troubleshooting results in Loss of Secondary Containment and Protected Equipment
- NCV 2012005-04, Improper Stress Intensification Factor Results in Not Identifying ASME Limits for Pipe Stress Being Exceeded
- EOC-RPT Time Response Test
- NCV 2013005-03,
- Missed Technical Specification Surveillance for Secondary Containment
- Drawdown Testing
Procedures
- CH-042-001, Revision 43, Circulating Water
- EO-000-113, Level/Power Control, Revision 13 ERPM E1924-01, Replace Filter Cap/Circuit Boards/Float and Equalize Pots (1D613)
- LS-120, Issue Identification and Screening Process, Revision 0
- LS-125, Corrective Action Program, Revision 1
- LS-125-1003, Apparent Cause Evaluation Manual, Revision 0
- LS-125-1004, Effectiveness Review Manual Revision 0
- NASI-00-800, Employee Concerns Program Conduct of Operations, Revision 8
- NDAP-00-0024, Winter Operation Preparations, Revision 23
- NDAP-00-0109, Employee Concerns Program, Revision 16
- NDAP-00-0708, Corrective Action Review Board, Revision 16
- NDAP-00-0709, Work Environment, Revision 3
- NDAP-00-0752, Cause Analysis, Revision 21
- NDAP-00-0780, Management Review Committee, Revision 6
- NDAP-00-0784, SSES Safety Culture Monitoring, Revision 2
- NDAP-00-1913, Seasonal Readiness, Revision 0
- NDAP-QA-0029, Procedure and Work Instruction Use and Adherence, Revision 24
- NDAP-QA-0413, Implementation of the Maintenance Rule, Revision 12
- NDAP-QA-0702, Action Request and Condition Report Process, Revision 18
- NDAP-QA-0703, Operability Assessments and Requests for Enforcement Discretion,
- Revision 24
- NDAP-QA-0720, Station Report Matrix and Reportability Evaluation Guidance, Revision 22
- NDAP-QA-1902, Revision 15, Integrated Risk Management
- NSEP-AD-0413D, Maintenance Rule Performance Monitoring, Revision 1
- NSEP-AD-0413E, Maintenance Rule
- Dispositioning Between (a)(1) and (a)(2), Revision 0
- OI-AD-095, Operations Directives, Revision 1
- OP-102-001, 125VDC System, Revision 24
- OP-152-001, HPCI System, Revision 55
- OP-202-001, 125VDC System, Revision 21
- Attachment RHR Service Water
- OP-116-001, Revision 45, dated April 10, 2014
- SI-SO-001, Duties and Responsibilities of the Security Shift Supervisor, Revision 25
- SI-SO-002, Duties and Responsibilities of the Alarm Station Operators, Revision 29
- SM-202-610 125 VDC Battery Service Discharge Test and 2D613
- Battery Charger Capability Test, Revision 22
- SP-HBC-139-1, 1 inch HBC Line From
- SP-HBC-139-2, ESW from 3 inch
- SP-HBC-239-2, ESW from 4 inch
- Revision 10
- SP-HBC-239-4, ESW from 3 inch
- Revision 13
Work Orders
- AR 2014-00131
- AR 2014-06293
- AR 2014-10025
- AR 2014-16107
- AR 2014-19095*
- AR 2014-20173
- AR 2014-20173*
- AR 2014-20505
- AR 1491410 PCWO
- 1320735 PCWO
- 1320738 PCWO
- 1325373 PCWO
- 1434638 PCWO
- 1496680 PCWO
- 1505054 PCWO
- 1669500 PCWO
- 1669512 PCWO
- 1669514 PCWO
- 1669516 PCWO
- 1669517 PCWO
- 1669518 PCWO
- 1669519 PCWO 1669520PCWO
- 1675073 PCWO
- 1695078 PCWO
- 1700829 PCWO
- 1700831 PCWO
- 1750534 PCWO
- 1785618 PCWO
- 388734
- PCWO-1666288
Miscellaneous
- Site Safety Culture Assessment
- Key Questions by Department Site Safety Culture Assessment
- April 2014 Battery Equalizing Log for 1D610 Daily Leadership Alignment Package June 4, 2014 Daily Screening Report for June 3, 2014 Daily Screening Report for June 4, 2014 Daily Screening Report for June 6, 2014 Drawing Number FF103195, Sheet 801, Revision 9
- Attachment
- EC-004-1002, LOCA Timeline Development for Plant Voltage Studies, Revision 7
- EC-005-0505, K11A/K11B Relay Failure Impacts on 480V Class 1E Systems during Unit 1 Design Basis Accidents, Revision 0 MRC Package for June 4, 2014
- NDAP-00-0024, Winter Operation Preparations, Revision 20, Completed 11/4/2013 Operations Directive 12-07, Revision 1 Operations Directive 12-07, Revision 2 Operations Directive 12-07, Revision 3 Operations Directive 13-02, Revision 0 Operations Directive 14-01, Revision 0 Periodic Operability Review Meeting Worksheets, dated 8/2/2013, 10/25/2013, 11/08/2013, 11/15/2013, 1/11/2014, 1/17/2014, 2/21/2014, 3/7/2014, 3/21/2014, 3/28/2014, 4/4/2014, 4/11/2014, 4/25/2014, 5/2/2014, 5/9/2014, and 5/16/2014 Susquehanna Steam Electric Station Updated Final Safety Analysis Report System Health Scorecard (Rev 3, 01/02/2014) System 149, RHR Year Per 2013-3 and 2014-1 May 30, 2014 SSES Maintenance Rule Expert Panel Meeting Minutes, Meeting Number 2014-
- 0530 10CFR20.1101(c) radiation protection program reviews for 2012 and 2013 1Q14 Performance Assessment Report, dated April 29, 2014 Structural Integrity Associates, Inc. Report No. 1200776.401, Revision 0, December 2012 SSES Calculation Sheet
- AR-2014-19095, Revision 0, dated June 6, 2014 for ESW and RHRSW Wall Thickness Calculation Job No. 8856, ASME
- SA-106 GrB Piping Class HRC, No. 3 dated November 23, 1983 M-199 Piping Class Sheets, Line Index and Standards Form
- NDE-UT-014-1, Rev. 0, Ultrasonic Thickness Data System 054, per PCWO
- 1309904,dated October 7, 2010 Form
- NDE-UT-014-1, Rev. 0, Ultrasonic Thickness Data System 154A, per PCWO
- 1817487, dated June 7, 2014 Form
- NDE-UT-014-1, Rev. 0, Ultrasonic Thickness Data System 116A, per PCWO
- PLI-95338, June 5, 2013 Maintenance Rule Basis Document
- System 49, System Information RHR Risk Management Actions Planning Sheet, WO#905318 dated June 6, 2014 RLWO
- 1801380, HV112F075B RHRSW Crosstie Perform Quiklook Test
- 2014 Daily Station Schedule, Activity ID NTV01014H1, June 1-8, 2014 ERisk Management WO#905318 DigiChem Multiple System/Parameter Search, circ water, November 2012 Maintenance Rule (a)(2) At Risk Systems, May 30, 2014 Maintenance Rule Expert Panel Meeting Minutes, Meeting Number 2014-0530 10CFR20.1101(c) reviews for 2009-2013
- EWR-1641937
- DBD014, Residual Heat Removal System, Revision 4
- Attachment
LIST OF ACRONYMS
- PPL [[]]
- LLC [[]]