IR 05000272/2011009: Difference between revisions
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The inspectors selected items from the following functional areas for review: engineering, operations, maintenance, emergency preparedness, radiation protection, chemistry and physical security.(1) Effectiveness of Problem ldentification 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 the service water, emergency diesel generator, safety injection and auxiliary feedwater systems.Additionally, the inspectors reviewed a sample of notifications 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 PSEG entered conditions adverse to quality into their corrective action program as apProPriate. | The inspectors selected items from the following functional areas for review: engineering, operations, maintenance, emergency preparedness, radiation protection, chemistry and physical security.(1) Effectiveness of Problem ldentification 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 the service water, emergency diesel generator, safety injection and auxiliary feedwater systems.Additionally, the inspectors reviewed a sample of notifications 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 PSEG entered conditions adverse to quality into their corrective action program as apProPriate. | ||
: (2) Effectiveness of Prioritization and Evaluation of lssues The inspectors reviewed the evaluation and prioritization of a sample of notifications issued since the last NRC biennial Problem ldentification and Resolution inspection completed in June 20A9. The inspectors also reviewed notifications that were assigned lower levels of significance that did not include formal cause evaluations to ensure that Enclosure 5 they were properly classified. | |||
(2) Effectiveness of Prioritization and Evaluation of lssues The inspectors reviewed the evaluation and prioritization of a sample of notifications issued since the last NRC biennial Problem ldentification and Resolution inspection completed in June 20A9. The inspectors also reviewed notifications that were assigned lower levels of significance that did not include formal cause evaluations to ensure that Enclosure 5 they were properly classified. | |||
The inspectors' review included the appropriateness of the assigned significance, the scope and depth of the causal analysis, and the timeliness of resolution. | The inspectors' review 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. The inspectors also verified that, when necessary, issue evaluations addressed equipment operability, NRC reporting requirements, and other areas potentially affected by the identified performance deficiencies. | The inspectors assessed whether the evaluations identified likely causes for the issues and developed appropriate corrective actions to address the identified causes. The inspectors also verified that, when necessary, issue evaluations addressed equipment operability, NRC reporting requirements, and other areas potentially affected by the identified performance deficiencies. | ||
: (3) Effectiveness of Corrective Actions The inspectors reviewed PSEG's completed corrective actions through documentation review and, in some cases, field walkdowns to determine whether the actions addressed the identified causes of the problems. | |||
The inspectors also reviewed notifications for adverse trends and repetitive problems to determine whether corrective actions were effective in addressing the broader issues. The inspectors reviewed PSEG's timeliness in implementing corrective actions and effectiveness in precluding recurrence for significant conditions adverse to quality. The inspectors also reviewed a sample of notifications associated with selected non-cited violations and findings to verify that PSEG personnel properly evaluatbd and resolved these issues. ln addition, the inspectors expanded the corrective action review to five years to evaluate PSEG actions related to service water and circulating water grassing, control air system moisture, control room chillers, safety injection pump bearings, and residual heat removal system oil leaks.b. Assessment | |||
: (1) Effectiveness of Problem ldentification PSEG staff at Salem initiated approximately 11,800 notifications between June 2009 and May 2011. For this inspection, as part of the scope described above, the inspectors reviewed the documentation associated with approximately 150 of these notifications. | |||
The inspectors also reviewed notifications for adverse trends and repetitive problems to determine whether corrective actions were effective in addressing the broader issues. The inspectors reviewed PSEG's timeliness in implementing corrective actions and effectiveness in precluding recurrence for significant conditions adverse to quality. The inspectors also reviewed a sample of notifications associated with selected non-cited violations and findings to verify that PSEG personnel properly evaluatbd and resolved these issues. ln addition, the inspectors expanded the corrective action review to five years to evaluate PSEG actions related to service water and circulating water grassing, control air system moisture, control room chillers, safety injection pump bearings, and residual heat removal system oil leaks.b. Assessment (1) Effectiveness of Problem ldentification PSEG staff at Salem initiated approximately 11,800 notifications between June 2009 and May 2011. For this inspection, as part of the scope described above, the inspectors reviewed the documentation associated with approximately 150 of these notifications. | |||
Based on the samples selected for review, the inspectors determined that PSEG identified problems and entered them into the corrective action program at a low threshold. | Based on the samples selected for review, the inspectors determined that PSEG identified problems and entered them into the corrective action program at a low threshold. | ||
The inspectors observed supervisors at the plan-of-the-day, station ownership committee, and management review committee meetings appropriately questioning and challenging notifications to ensure clarification of the issues that allowed for appropriate assignments for follow-up actions. The inspectors also concluded that PSEG trended equipment and programmatic issues at a low level, and appropriately documented problems identified through trending in the site's corrective action program.The inspectors determined that, when appropriate, in response to inspector observations during this inspection, PSEG personnel promptly initiated notifications and took immediate action to address the issues of concern. In addition, based on the scope of issues reviewed by the inspectors, the inspectors did not identify concerns that were not appropriately entered into the corrective action program for evaluation and resolution. | The inspectors observed supervisors at the plan-of-the-day, station ownership committee, and management review committee meetings appropriately questioning and challenging notifications to ensure clarification of the issues that allowed for appropriate assignments for follow-up actions. The inspectors also concluded that PSEG trended equipment and programmatic issues at a low level, and appropriately documented problems identified through trending in the site's corrective action program.The inspectors determined that, when appropriate, in response to inspector observations during this inspection, PSEG personnel promptly initiated notifications and took immediate action to address the issues of concern. In addition, based on the scope of issues reviewed by the inspectors, the inspectors did not identify concerns that were not appropriately entered into the corrective action program for evaluation and resolution. | ||
: (2) Effectiveness of Pdoritization and Evaluation of lssues The inspectors determined that, in general, PSEG appropriately prioritized and evaluated issues commensurate with the safety significance of the identified problem.Enclosure 6 PSEG screened notifications for operability and reportability, categorized the notifications by significance, and assigned actions to the appropriate department for evaluation and resolution. | |||
(2) Effectiveness of Pdoritization and Evaluation of lssues The inspectors determined that, in general, PSEG appropriately prioritized and evaluated issues commensurate with the safety significance of the identified problem.Enclosure 6 PSEG screened notifications for operability and reportability, categorized the notifications by significance, and assigned actions to the appropriate department for evaluation and resolution. | |||
The notification screening process considered human performance issues, radiological safety concerns, repetitiveness, adverse trends, and potential impact on the safety conscious work environment. | The notification screening process considered human performance issues, radiological safety concerns, repetitiveness, adverse trends, and potential impact on the safety conscious work environment. | ||
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The inspectors concluded, based on the samples reviewed, that corrective actions for identified deficiencies were typically timely and adequately implemented and that for significant conditions adverse to quality, PSEG identified actions to prevent recurrence and performed in-depth effectiveness reviews to verify that implemented corrective actions were effective. | The inspectors concluded, based on the samples reviewed, that corrective actions for identified deficiencies were typically timely and adequately implemented and that for significant conditions adverse to quality, PSEG identified actions to prevent recurrence and performed in-depth effectiveness reviews to verify that implemented corrective actions were effective. | ||
However, in one case, as a result of a review of PSEG's corrective actions for repetitive trips of service water strainers during periods of high river water grass since 2006, the inspectors identified one example of more than minor significance where PSEG did not implement timely corrective actions. This finding is documented below.c. Findinqs (1) Untimelv Completion of Corrective Actions Results in No. 11 Service Water Strainer Trip Due To Grassinq lntroduction. | However, in one case, as a result of a review of PSEG's corrective actions for repetitive trips of service water strainers during periods of high river water grass since 2006, the inspectors identified one example of more than minor significance where PSEG did not implement timely corrective actions. This finding is documented below.c. Findinqs | ||
: (1) Untimelv Completion of Corrective Actions Results in No. 11 Service Water Strainer Trip Due To Grassinq lntroduction. | |||
The inspectors identified a self-revealing apparent violation of 10 CFR 50, Appendix B, Criterion XVl, "Corrective Action," because the 11 service water strainer overloads tripped on February 9, 2Q11, due to binding of the strainer rotating drum, which rendered the 11 service water pump inoperable and unavailable. | The inspectors identified a self-revealing apparent violation of 10 CFR 50, Appendix B, Criterion XVl, "Corrective Action," because the 11 service water strainer overloads tripped on February 9, 2Q11, due to binding of the strainer rotating drum, which rendered the 11 service water pump inoperable and unavailable. | ||
The binding occurred because PSEG did not complete timely corrective actions for a condition adverse to quality identified following an April 4,2010, 11 service water strainer trip.Specifically, PSEG did not repair excessive grooves on the strainer body wear surface by taking the actions specified in the corrective action program in January 2011. The grooves caused river grass to become trapped between the rotating strainer drum and body wear surface, which eventually bound and tripped the strainer overloads. | The binding occurred because PSEG did not complete timely corrective actions for a condition adverse to quality identified following an April 4,2010, 11 service water strainer trip.Specifically, PSEG did not repair excessive grooves on the strainer body wear surface by taking the actions specified in the corrective action program in January 2011. The grooves caused river grass to become trapped between the rotating strainer drum and body wear surface, which eventually bound and tripped the strainer overloads. | ||
=====Description.===== | =====Description.===== |
Revision as of 13:38, 18 September 2018
ML112450416 | |
Person / Time | |
---|---|
Site: | Salem ![]() |
Issue date: | 09/02/2011 |
From: | Burritt A L Reactor Projects Branch 3 |
To: | Joyce T P Public Service Enterprise Group |
Burritt A L RGN-I/DRP/PB3/610-337-5069 | |
References | |
IR-11-009 | |
Download: ML112450416 (20) | |
Text
UNITED STATES NUCLEAR REGU LATORY COMMISSION REGION I 475 ALLENDALE ROAD KING OF PRUSSIA, PENNSYLVANIA 19406-1415 September 2, TOLL Mr. Thomas P. JoYce President and Chief Nuclear Officer PSEG Nuclear LLC - N09 P.O. Box 236 Hancock's Bridge, NJ 08038 suBJECT: SALEM NUCLEAR GENERATING STATION, UNIT NOS] ]-4\D 2 -NRc pROBLEM tDENlFtCnrtON AND RESOLUTION INSPECTION REPORT o5ooo272t2o1 1 oO9 AND 0500031 1 /201 1 009
Dear Mr. Joyce:
on July 21,2011, the U. S. Nuclear Regulatory commis.sion (NRC) completed an inspection at your Salem ttuctearbenerating StatiollUnit Nos. 1 and 2. The enclosed report documents the inspection results disiussed
- itn ur. carl Fricker and other members of your staff during an exit*"Liing on July 21 and with Mr. Fricker during a telephone call on September 2'This inspection examined activities conducted under your license as they relate to identification and resolution of proui"r" and compliance with the iommission's rules and regulations and conditions of your license. 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 PSEG was generally effective in identifying, evaruating, and resorving probrems.
psEG personnel identified problems and entered them into the corrective action prolrar at a low threshold'
PSEG prioritized and evaluated issues commensurate with the safet/significance of the problems and corrective actions were generally implemented in a timely manner'However, the inspection identified one self-revealing finding for not completing timely corrective actions to repair "*."..iu" grooves discovered on tlre body wear surface.for the 11 service water strainer.
This issue resulted in an 11 service water strainer trip that rendered the 11 service water pumt rop"raur" and unavailable and was determined to potentially have.greater than very low safe[y sijnificance.
The safety significance determination process analysis for this issue was not 6or-pr"t"o at time of inspecti6n report issuance.
Although the finding has potential safety significance, it did not represent an immediate safety concern because it did not represent a complete loss of service walLisystem operability on Unit 1. At the time, five out of the six Unit 1 service water pumps remained operable and available' In accordance with 10 CFR 2.390 of the NRC's "Rules of Practice," a copy of this letter, its enclosure, and your response (if any) will be available electronically for public inspection in the NRC Public Document Room or from the Publicly Available Records (PARS) component of the NRC's document system (ADAMS). ADAMS is accessible from the NRC website at http://www.nrc.qov/readinq-rm/adams.html (the Public Electronic Reading Room).
Sincerely,n -//-- ) {J, {1-I i.,L//t{t fU 1/'l Arthur L. Burritt, Chief Projects Branch 3 Division of Reactor Projects Docket Nos: 50-272;50-311 License Nos: DPR-70; DPR-75
Enclosure:
Inspection Report 0500027212011009 and 05000311/2011009
w/Attachment:
Supplemental I nformation cc w/encl: Distribution via ListServ
SUMMARY OF FINDINGS
lR 0500027212011009, 0500031 112011009i 0612712011 - 0711512011;
Salem Nuclear Generating Station, Unit Nos. 1 and 2; Biennial Baseline Inspection of Problem ldentification and Resolution.
The inspectors identified one finding in the area of implementation of corrective actions.This NRC team inspection was performed by three regional inspectors and one resident inspector.
The inspectors identified one finding of very low safety significance (Green) during this inspection and classified the finding as an NCV. The significance of most findings is indicated by their color (Green, White, Yellow, Red) using NRC Inspection Manual Chapter (lMC) 0609, "Significance Determination Process" (SDP). Findings for which the SDP does not apply may be Green or assigned a severity level after NRC management review. Cross-cutting aspects associated with findings are determined using IMC 0310, "Components Within the Cross-Cutting Areas." The NRC's program for overseeing the safe operation of commercial nuclear power reactors is described in NUREG-1649, "Reactor Oversight Process," Revision 4, dated December 2006.Problem ldentification and Resolution The inspectors concluded that PSEG was generally effective in identifying, evaluating, and resolving problems.
PSEG personnel identified problems, entered them into the corrective action program at a low threshold, and prioritized issues commensurate with their safety significance.
ln most cases, PSEG appropriately screened issues for operability and reportability, and performed causal analyses that appropriately considered extent of condition and cause, generic issues, and previous occurrences.
The inspectors also determined that PSEG typically implemented corrective actions to address identified problems in a timely manner. However, for one issue reviewed by the inspectors, the corrective actions completed by PSEG were not timely and the inspectors determined that this was a violation of NRC requirements, in the area of corrective action implementation.
The inspectors concluded that, in general, PSEG adequately identified, reviewed, and applied relevant industry operating experience to Salem operations and identified appropriate corrective actions. ln addition, based on those items selected for review, the inspectors determined that PSEG self-assessments and audits were thorough and appropriately used the corrective action program to initiate corrective actions for identified issues.With respect to safety conscious work environment, based on interviews and reviews of the corrective action program and the employees concerns program (ECP) the inspectors did not identify conditions that negatively impacted the site's safety conscious work environment and determined that site personnel were willing to raise safety issues through multiple means.
Cornerstone: Initiating
Events TBD. The inspectors identified a self-revealing apparent violation of 10 CFR 50, Appendix B, Criterion XVl, "Corrective Action," because the 11 service water strainer overloads tripped on February 9,2011, due to binding of the strainer rotating drum, which rendered the 't 1 service water strainer pump inoperable and unavailable.
The binding occurred because PSEG did not complete timely corrective actions for a condition adverse to quality identified following an April 4,2010,11 service water strainer trip. Specifically, PSEG did not repair excessive grooves identified on the 11 service water strainer body wear surface by taking the actions specified in their corrective action program in January 2011. As a result, the grooves caused river grass to become trapped between the rotating strainer drum and the body wear surface, which eventually bound and tripped the strainer overloads.
As corrective action, before the next spring grassing season, PSEG will temporarily fill in the grooves on the 11 service water strainer body wear surface and then trend the body wear ring condition for future replacement with a monel wear ring. PSEG entered this issue into the corrective action program as 20523166.This performance deficiency was more than minor because it was associated with the equipment performance attribute of the initiating events and mitigating systems cornerstones.
The finding affected the cornerstones'
objectives to limit the likelihood of those events that could upset plant stability and challenge critical safety functions during power operations and to ensure the availability and reliability of systems that respond to initiating events to prevent undesirable consequences.
Specifically, not promptly correcting the excessive grooving identified on that strainer's body wear ring degraded the availability and reliability of the 11 service water train. The significance of this finding is designated as To Be Determined (TBD)untit a regional senior reactor analyst completes a Phase 3 analysis, in accordance with IMC 0609, Appendix A, "Determining the Significance of Reactor Inspection Findings for At-Power Situations" (lMC 06094). Phase 1 screened the finding to Phase 2 because the inspectors concluded that the finding contributed to both the likelihood of a reactor trip and the likelihood that mitigating systems would not have been available.
This conclusion was based upon the increased chance of a loss of service water given one train being removed for strainer repairs and the loss of redundancy in the service water system to cool mitigating equipment over the assumed 53 hour6.134259e-4 days <br />0.0147 hours <br />8.763227e-5 weeks <br />2.01665e-5 months <br /> exposure period. The Phase 3 analysis was required because the Salem Pre-solved Risk-lnformed Inspection Notebook does not address the loss of one train of service water. This finding has a cross-cutting aspect in the area of problem identification and resolution, corrective action program, because PSEG did not take appropriate corrective actions to address a safety issue in a timely manner, commensurate with the safety-significance and complexity tP.1(d)1.
Specifically, PSEG did not implement timely actions to repair excessive grooves identified in the 11 service water strainer body wear ring in January 2011 because work controldocuments were not correctly coded in July 2010. (4OA2.1c(3))
4
REPORT DETAILS
4. OTHER ACTTVITIES (OA)4OA2 Problem ldentification and Resolution (711528)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 Proqram Effectiveness
a. Inspection Scope
The inspectors reviewed the procedures that described PSEG's corrective action program at Salem. To assess the effectiveness of the corrective action program, 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, Appendix B, Criterion XVl, "Corrective Action," and PSEG procedure LS-AA-125, "Corrective Action Program Procedure." For each of these areas, the inspectors considered risk insights from the station's risk analysis and reviewed notifications selected across the seven cornerstones of safety in the NRC's Reactor Oversight Process. Included in this sample were notifications that documented PSEGs evaluation and corrective actions for a selective sample of NRC-identified non-cited violations and findings that had been identified since the last biennial problem identification and resolution inspection completed in June 2009. Additionally, the inspectors attended plan-ofthe-day, station ownership committee, and management review committee meetings.
The inspectors selected items from the following functional areas for review: engineering, operations, maintenance, emergency preparedness, radiation protection, chemistry and physical security.(1) Effectiveness of Problem ldentification 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 the service water, emergency diesel generator, safety injection and auxiliary feedwater systems.Additionally, the inspectors reviewed a sample of notifications 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 PSEG entered conditions adverse to quality into their corrective action program as apProPriate.
- (2) Effectiveness of Prioritization and Evaluation of lssues The inspectors reviewed the evaluation and prioritization of a sample of notifications issued since the last NRC biennial Problem ldentification and Resolution inspection completed in June 20A9. The inspectors also reviewed notifications that were assigned lower levels of significance that did not include formal cause evaluations to ensure that Enclosure 5 they were properly classified.
The inspectors' review 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. The inspectors also verified that, when necessary, issue evaluations addressed equipment operability, NRC reporting requirements, and other areas potentially affected by the identified performance deficiencies.
- (3) Effectiveness of Corrective Actions The inspectors reviewed PSEG's completed corrective actions through documentation review and, in some cases, field walkdowns to determine whether the actions addressed the identified causes of the problems.
The inspectors also reviewed notifications for adverse trends and repetitive problems to determine whether corrective actions were effective in addressing the broader issues. The inspectors reviewed PSEG's timeliness in implementing corrective actions and effectiveness in precluding recurrence for significant conditions adverse to quality. The inspectors also reviewed a sample of notifications associated with selected non-cited violations and findings to verify that PSEG personnel properly evaluatbd and resolved these issues. ln addition, the inspectors expanded the corrective action review to five years to evaluate PSEG actions related to service water and circulating water grassing, control air system moisture, control room chillers, safety injection pump bearings, and residual heat removal system oil leaks.b. Assessment
- (1) Effectiveness of Problem ldentification PSEG staff at Salem initiated approximately 11,800 notifications between June 2009 and May 2011. For this inspection, as part of the scope described above, the inspectors reviewed the documentation associated with approximately 150 of these notifications.
Based on the samples selected for review, the inspectors determined that PSEG identified problems and entered them into the corrective action program at a low threshold.
The inspectors observed supervisors at the plan-of-the-day, station ownership committee, and management review committee meetings appropriately questioning and challenging notifications to ensure clarification of the issues that allowed for appropriate assignments for follow-up actions. The inspectors also concluded that PSEG trended equipment and programmatic issues at a low level, and appropriately documented problems identified through trending in the site's corrective action program.The inspectors determined that, when appropriate, in response to inspector observations during this inspection, PSEG personnel promptly initiated notifications and took immediate action to address the issues of concern. In addition, based on the scope of issues reviewed by the inspectors, the inspectors did not identify concerns that were not appropriately entered into the corrective action program for evaluation and resolution.
- (2) Effectiveness of Pdoritization and Evaluation of lssues The inspectors determined that, in general, PSEG appropriately prioritized and evaluated issues commensurate with the safety significance of the identified problem.Enclosure 6 PSEG screened notifications for operability and reportability, categorized the notifications by significance, and assigned actions to the appropriate department for evaluation and resolution.
The notification screening process considered human performance issues, radiological safety concerns, repetitiveness, adverse trends, and potential impact on the safety conscious work environment.
Items reviewed by the inspectors during the inspection were categorized for evaluation and resolution commensurate with the significance of the issues. Guidance provided by PSEG procedure LS-AA-120, "lssue ldentification and Screening Process," for categorization appeared sufficient to ensure consistent implementation based on the sample of notifications reviewed by the inspectors.
ln general, issues were appropriately screened and prioritized commensurate with their safety significance.
The inspectors reviewed 15 root cause analyses,26 apparent cause analyses,6 common cause evaluations and approximately 20 work group evaluations.
For the evaluations reviewed, the inspectors noted that PSEG's evaluations were generally thorough.
Operability and reportability determinations were generally documented when conditions warranted and in most cases, the evaluations supported the conclusion.
Causal analyses appropriately considered the extent of condition or problem, generic issues, and previous occurrences of the issue.(3) Effectiveness of Corrective Actions The inspectors reviewed notification disposition documentation and verification of corrective action implementation through reviews of implementing orders and discussions with personnel involved for over 150 PSEG notifications.
The inspectors concluded, based on the samples reviewed, that corrective actions for identified deficiencies were typically timely and adequately implemented and that for significant conditions adverse to quality, PSEG identified actions to prevent recurrence and performed in-depth effectiveness reviews to verify that implemented corrective actions were effective.
However, in one case, as a result of a review of PSEG's corrective actions for repetitive trips of service water strainers during periods of high river water grass since 2006, the inspectors identified one example of more than minor significance where PSEG did not implement timely corrective actions. This finding is documented below.c. Findinqs
- (1) Untimelv Completion of Corrective Actions Results in No. 11 Service Water Strainer Trip Due To Grassinq lntroduction.
The inspectors identified a self-revealing apparent violation of 10 CFR 50, Appendix B, Criterion XVl, "Corrective Action," because the 11 service water strainer overloads tripped on February 9, 2Q11, due to binding of the strainer rotating drum, which rendered the 11 service water pump inoperable and unavailable.
The binding occurred because PSEG did not complete timely corrective actions for a condition adverse to quality identified following an April 4,2010, 11 service water strainer trip.Specifically, PSEG did not repair excessive grooves on the strainer body wear surface by taking the actions specified in the corrective action program in January 2011. The grooves caused river grass to become trapped between the rotating strainer drum and body wear surface, which eventually bound and tripped the strainer overloads.
Description.
The Salem service water system is designed to supply cooling water to safety-related equipment under all credible environmental and weather-related conditions.
The system consists of six pumps divided into two redundant trains, three pumps each. The pumps take suction from the Delaware River through trash racks and traveling screens designed to protect the pumps from river debris, while each pump discharges through an automatic self-cleaning strainer designed to protect the system's heat exchangers from tube blockage.On February 9,2011, the 1 1 service water strainer thermal overloads tripped due to binding caused by river grass that wedged between the strainer drum and body.Tripping of a service water strainer due to binding makes the associated service water pump inoperable.
PSEG determined that the cause of the binding was not installing a previously approved strainer design change intended to improve the service water strainers resistance to grass binding.Each service water strainer assembly consists of a vertical mounted conical shaped drum with 1104 strainer media elements.
The strainer drum rotates inside the strainer body with 0.015 to 0.063 inches of clearance between the drum and body to ensure the drum rotates freely. This clearance also allows a small amount of flow to bypass the strainer elements.
Because this bypass flow results in river debris reaching and potentially fouling system safety- related heat exchangers, it is important to minimize it by maintaining the clearance between the drum and body small. In 2000, due to repetitive heat exchanger fouling and strainer binding issues caused by this bypass flow, PSEG modified the design of the bottom of the service water strainer drum with a wear ring that included an embedded rubber o-ring that decreased the clearance between the drum and the body.After this design change, PSEG determined that, due to the silt entrained in the river water, even the small amount of bypass flow around the newly installed o-ring caused wear on the stralner drum and body. This wear over time increased the size of the gap between the drum and body and caused grooves on the body wear surface around the o-ring. The increasing gap, if not monitored and managed, caused higher bypass flow that both allowed grass and debris to bypass the strainer elements and drew grass and debris into the gap where it accumulated due to the tight clearances and o-ring wear grooves on the strainer body wear surface. The accumulation of grass in this area was not cleared during strainer backwash cycles and when it built up, caused increased friction between the drum and body. This increased the amount of current needed to rotate the strainer drum and eventually caused the thermal overload to trip due to the higher current. This was what caused the 1 1 strainer to trip on February 9, 2011.PSEG determined that maintaining the strainer bodies was critical to preventing excessive bypass flow that could lead to grass accumulation and accelerated strainer wear. PSEG controls the gap between the strainer drum and body to within the vendor recommendations by performing preventative maintenance to inspect and adjust the service water strainer clearances every six months. Adjustments to the strainer during performance of this preventative maintenance were completed based upon the system engineer's reviews of the gap measurements and wear grooves. In addition, to further control the gap, PSEG performed the industry standard, every six year, service water strainer internal inspections every three years due to the harsh river water conditions at Salem. In the early 2000s, due to excessive wear grooves that were developing on the strainer body wear surfaces from the o-ring, PSEG issued a design change to modify the strainer bodies to include a monel wear ring. The intent of the design change was that Enclosure 8 the new wear ring material would increase the hardness of the wear surface increasing the wear surfaces durability and wear resistance and reducing the frequency of wear ring repairs. This modification was not installed on the 11 strainer at the time of the February 9,2011, trip.PSEG identified, during its cause evaluation for the February 2011 trip, that a similar trip of the 11 service water strainer had occurred one year earlier on April 4,2010. The apparent cause evaluation for that trip determined the cause of the trip was untimely replacement of the 11 service water strainer body wear ring. The 11 service water strainer body configuration at the time of the April 2010 and February 201 1 trips was the configuration provided by the 1993 strainer replacement project. Because the monel wear ring was not installed, without interim corrective action, over time, due to the o-ring an excessive groove developed on the strainer body, which increased the susceptibility of the strainer to grass clogging.
The groove on the 11 strainer body wear surface was a condition adverse to quality that PSEG identified in April 2010. At the time of the April 2010 trip, the groove was approximately 180 mils deep and 375 mils wide and by February 2011, due to no corrective actions being completed, the groove width increased to 500 mils with no increase in depth. After the April 2010 11 service water trip, PSEG determined that, in addition to the 11 strainer, five other strainers did not have the monel wear ring design change (14, 16,23,24, and 26) installed.
As documented in order 70109406, PSEG's corrective action for the April 2010 1 1 service water strainer trip was to develop and schedule the replacement plan for the six strainers that did not have the monel wear ring installed.
This corrective action was documented as completed based on scheduling the work orders for the body replacement for all six strainers.
The 1 1 strainer work was scheduled to be completed in January 2011. However, due to limited resources, the work was re-scheduled to January 2012. PSEG determined that the rescheduling was allowed to occur because the work was not properly coded as a plant health committee significant issue or as a grassing readiness priority in accordance with WC-AA-101-1002, "On-line Work Schedule Process." As a result, the identified condition adverse to quality was not promptly corrected and the 1 1 service water strainer tripped on February 9, 2011, due to grass binding, making the 11 service water pump inoperable and unavailable for 53 hours6.134259e-4 days <br />0.0147 hours <br />8.763227e-5 weeks <br />2.01665e-5 months <br />.To address the performance deficiency, PSEG scheduled an interim design change for the 11 service water strainer to plasma spray the body wear ring before the next spring grassing season in January 2012. The plasma spray process will temporarily re-fill the groove in the strainer body wear ring. PSEG will then trend the 11 strainer body wear ring condition for future replacement with the monel wear ring. The monel wear ring design change on the 11 service water strainer is currently scheduled to be completed in April 2013.PSEGs cause evaluation for the February 2011 strainer trip also identified four other strainers (14, 16,23, and 26) that still did not have the monel wear ring design change installed.
Before the next spring grassing season, PSEG will either install the monel wear ring design change or complete temporary repairs if excessive grooving (greater than 0.125 inches deep) exists on the body wear surfaces for these strainers.
PSEG will then monitor the strainers condition until the permanent repairs can be completed.
In addition to the strainer repairs, PSEG revised service water system abnormal operating procedures to require operators to place the intake traveling screens in manual and the Enclosure I strainers in continuous blowdown operation during heavy grassing periods. This resulted in no strainer trips caused by grassing during the April 2011 grass peak.Analvsis.
The inspectors concluded that not completing timely repairs for excessive grooves identified on the 11 service water strainer body wear surface after the April 4, 2010, strainer trip was a performance deficiency.
The untimely corrective actions resulted in the February 9,2011, 11 service water strainer trip. This performance deficiency was more than minor because it was associated with the equipment performance attribute of the initiating events and mitigating systems cornerstones.
The finding affected the cornerstones' objectives to limit the likelihood of those events that could upset plant stability and challenge critical safety functions during power operations and to ensure the availability and reliability of systems that respond to initiating events to prevent undesirable consequences.
Specifically, not completing timely corrective actions for excessive grooving identified on 11 strainer's body wear ring in January 2011 degraded the availability and reliability of the 1 1 service water pump.The significance of this finding is designated as To Be Determined (TBD) until a regional senior reactor analyst completes a Phase 3 analysis, in accordance with IMC 0609, Appendix A, "Determining the Significance of Reactor Inspection Findings for At-Power Situations." Phase 1 screened the finding to Phase 2 because the inspectors concluded that the finding contributed to both the likelihood of a reactor trip and the likelihood that mitigating systems would not have been available.
This conclusion was based upon the increased chance of a loss of service water given one train being removed for strainer repairs and the loss of redundancy in the service water system to cool mitigating equipment over the assumed 53 hour6.134259e-4 days <br />0.0147 hours <br />8.763227e-5 weeks <br />2.01665e-5 months <br /> exposure period. The Phase 3 analysis was required because the Salem Pre-solved Risk-lnformed Inspection Notebook does not address the loss of one train of service water. The Phase 3 analysis was not completed at the time of inspection report issuance.
The analysis will be completed following determination of the proper assumptions for the increase in the loss of service water event frequency and the increase in the common cause failure probability, given the performance deficiency.
This finding has a cross-cutting aspect in the area of problem identification and resolution, corrective action program, because PSEG did not take appropriate corrective actions to address a safety issue in a timely manner, commensurate with the safety-significance and complexity tP.1(d)1.
Specifically, PSEG did not implement timely actions to repair excessive grooves identified in the 11 service water strainer body wear ring in January 2011 because work control documents were not correctly coded in July 2010.Enforcement.
10 CFR 50, Appendix B, Criterion XVl, "Corrective Action," requires, in part, that measures shall be established to assure that conditions adverse to quality, such as failures, malfunctions, deficiencies, deviations, defective material and equipment, and non-conformances are promptly identified and corrected.
Contrary to the above, in July 2010, PSEG did not establish adequate measures to assure that a condition adverse to quality identified on the 11 service water strainer was promptly corrected.
Specifically, because work control documents were not correctly coded in July 2010, PSEG did not repair excessive grooves identified on the 1 1 service water strainer body wear ring in January 2011. As a result, on February 9,2011, the 1 1 service water strainer overloads tripped due to binding of the strainer rotating drum.PSEG entered the issue into the corrective action program as NOTF 20523166.Pending completion of the safety significance determination process analysis for this Enclosure
.2 10 issue, the finding was identified
as an apparent violation. (AV 0500027213112011009-01, Untimely Completion of Corrective Actions Results in No. 11 Service Water Strainer Trip Due To Grassing)Assessment of the Use of Operatinq Experience lnspection Scope The inspectors reviewed a sample of notifications associated with review of industry operating experience to verify that PSEG appropriately evaluated the operating experience information for applicability to Salem 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 Salem adequately considered the underlying problems associated with the issues for resolution via their corrective action program.Assessment The inspectors determined that PSEG 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 inspectors also observed that industry operating experience was routinely discussed and considered during the conduct of Plan-of-the-Day meetings and pre-job briefs.Findinqs No findings were identified.
Assessment of Self-Assessments and Audits Inspection Scope The inspectors reviewed a sample of audits, including the most recent audit of the corrective action program, departmental self-assessments, and assessments performed by independent organizations.
Inspectors performed these reviews to determine if PSEG entered problems identified through these assessments into the corrective action program, when appropriate, and whether PSEG 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.
Assessment The inspectors concluded that self-assessments, audits, and other internal PSEG assessments were generally critical, thorough, and effective in identifying issues. The inspectors observed that PSEG personnel knowledgeable in the subject completed these audits and self-assessments in a methodical manner. PSEG completed these audits and self-assessments to a sufficient depth to identify issues which were then entered into the corrective action program for evaluation.
In general, the station a.c..3 b.Enclosure 11 implemented corrective actions associated with the identified issues commensurate with their safety significance.
c. Findinqs No findings were identified.
.4 Assessment
of Safetv Conscious Work Environment (SCWE)a. Inspection Scope During interviews with station personnel, the inspectors assessed the safety conscious work environment at Salem. Specifically, the inspectors interviewed personnel to determine whether they were hesitant to raise safety concerns to their management and/or the NRC. The inspectors reviewed implementation of the site employee concerns program (ECP). Specifically, the inspectors reviewed the site procedure for conducting ECP investigations and reviewed a sample of ECP files to assess the program's effectiveness at addressing potential safety issues and to verify that PSEG entered issues into the corrective action program when appropriate.
The inspectors also reviewed the results of the contractor-performed January 201 1 Nuclear Safety Culture Assessment and PSEG's December 2009 Nuclear Safety Culture Principles Self-Assessment.
The review included a discussion of the corrective actions identified by PSEG to address issues uncovered during the assessments.
b. Assessment Based on interviews and reviews of the corrective action program and the ECP, the inspectors determined that site personnel were willing to identify and raise safety issues.All persons interviewed demonstrated an adequate knowledge of the avenues available for raising safety concerns including the corrective action program and ECP. The inspectors also determined that the results of the nuclear safety culture surveys conducted in December 2009 and January 2011 provided PSEG insights into the safety culture of the site workforce.
c. Findinqs No findings were identified.
4OAO Meetinqs.
Includinq Exit On July 21,2011, the inspectors presented the inspection results to Mr. C. Fricker, Salem Site Vice President, and other members of the Salem staff. The inspectors verified that no proprietary information was retained by the inspectors or documented in this report.On September 2, 2011, during a telephone call with Mr. C. Fricker, the inspectors discussed the status of the phase 3 significance determination process analysis for the finding related to untimely completion of corrective actions for 11 SW strainer.
At that time the inspectors informed Mr. Fricker that the report would document the significance 12 of the finding as TBD pending determination of the proper assumptions for the increase in the loss of service water event frequency and the increase in the common cause failure probability relative to the performance deficiency.
ATTACHMENT:
SU PPLEMENTAL I N FORMATI ON Enclosure A-1
=SUPPLEMENTAL
INFORMATION=
KEY POINTS OF CONTAGT
Licensee Personnel
- C. Fricker, Site Vice President
- L. Wagner, Plant Manager
- M. Bruecks, Director Security
- R. DeSanctis, Director Maintenance
- J. Garecht, Director Operations
- L. Rajkowski, Director Engineering
- M. Headrick, Manager Employee Concerns
- J. Kandasamy, Manager Regulatory
Assurance
- J. Stavely, Manager Nuclear Oversight
- S. Taylor, Manager Radiation
Protection
- M. Wagner, Performance
lmprovement
Manage r
- J. Arena, Performance
lmprovement
Support
- H. Berrick, Regulatory
Compliance
- T. Cachaza, Performance
lmprovement
Support
- E. Villar, Regulatory
Compliance
- J. Arena, Performance
lmprovement
Support LIST OF ITEMS OPENED, CLOSED, DISCUSSED, AND UPDATED Opened and Closed 0500027 2, 31 1 I 201 1 009-0 1 Untimely Completion
of Corrective
Actions Results in No. 11 Service Water Strainer Trip Due To Grassing LIST OF DOCUMENTS
REVIEWED Section 4OA2: Problem ldentification
and Resolution
Audits and Self-Assessments
70095327, Boric Acid Corrosion
Control Functional
Area Self-Assessment (FASA), 04116109 70096371, Contamination
Control Self-Assessment, 09/03/09 70098506, 2009 Maintenance
Resource Management
FASA, 07i13/09 70106832, Salem Emergency
Preparedness
and its lmplementing
Procedure
Self-Assessment, 04t3012010
801 01 252, Emergency
Preparedness
Audit, 0411412010
8A102024, Engineering
Programs and Station Blackout Audit, 08111110 80103001, Security Plan, FFD, Access Authorization, and PADS Audit, 02102111 70118428,2011
Problem ldentification
and Resolution
FASA, 03104111 70098602.
Nuclear Safety Culture Principles
Self Assessment.
2111109 80103804, Corrective
Action Program Audit Report, 05/18/201
70109034, Component
Design Bases lnspection
FASA, 09115110 7 0092328, Adverse Co ndition Mon itori ng Effectiveness, 09/1 8/09 Attachment
Condition
Reports 20417280 20417626 20425928 20435006 20443188 20457965 20462560 20483570 20491 696 20494419 20505378 20512712 20367060 20324061 20419661 20267714 20388347 20397713 20413128 20419423 20498433 20505452 20505453 20451912 20358322 20354920 20367060 20324061 Cause Evaluations
70051392 70077526 70092295 70122711 70124648 70124565 70111159 70115587 70121626 70122719 70123045 7Q107468 70079931 70078030 70048918 70074694 70112680 701 19080 20267714 20388347 20397713 20413128 20419423 20498433 20505452 20505453 20451912 20187133 20262270 20277684 20284783 20294705 20330790 20330961 20332776 20339102 20347302 20356908 20361 055 20361 91 6 20366420 20379814 20382427 20382938 20383151 20386825 70120414 70122605 70112239 70103430 70100173 700451 33 70094482 70070964 70071995 70087882 700941 38 70096332 70096759 70098506 70102030 70104321 70110664 701 10650 A-2 20406749 20407953 20409949 20418071 20428645 204301 69 20433213 20439278 20439815 20440514 20451211 20452701 20452998 20454116 24464750 20465141 20467120 20469515 20470602 20472533 20472897 20457056 20476809 20476813 20476814 20476815 20476816 20476817 701 1 0851 70112123 70112241 70112630 70114571 70115067 70115200 70115231 70116446 7A116452 74117931 70119028 70119029 70119042 70119150 70119153 70119155 70119723 20479582 20483408 20482161 20483619 20487750 20487842 24490787 20494178 20495260 20495818 20495922 20499967 20504540 20504544 2Q504911 20505092 20449195 20422673 20501675 20506984 20508494 20510374 20097981 20205100 20227288 202640Q9 20254414 20451940 70120053 70120420 70120534 70120414 70120882 70121613 70121619 70121621 70122004 70122594 70122739 70123710 70122874 701 051 1 I 701 05604 70110652 70115842 70115228 20446414 20445647 2051 0037 2051 0035 20510034 20509262 205091 84 20508042 20507968 20510255 20448538 20448540 20405289 20506132 20505836 20505720 20502800 20301686 20501037 20499642 20506137 20451229 20434554 20465672 20419661 20401134 20478887 20437047 70116493 701 06673 701 03591 70112241 70112239 70111625 70111537 70109827 70106627 70106293 70090887 70118218 70120968 70109406 70066657 Attachment
Drawinos 205200, Unit 1 Control Air - Turbine Building, Sh.1, Revislon 51 205243, Unit 1 Control Air - Auxiliary
Building, Sh. 1, Revision 47 205247, Unit 1 Control Air - Reactor Control & Penetration
Area, Sh. 1, Revision 49 205332, Unit 2 Residual Heat Removal Pl&D, Sh. 1, Revision 36 604495, Units 1&2 Control Air Yard Area - Station Blackout, Revision 2 Operatinq
Experience
70109152, Post Tritium Report 70109718, 1'1A Circ Water Pump Casing Cracked 70109788, NRC lnformation
Notice 2010-04 70119956, NRC lnformation
Notice 2010-20 70078424,Intake
Cooling Water Blockage Corrective
Action Effectiveness
Review 7 01 23625, I nconsistent
I m plementation
of Operating
Experience
Proced u re 70118713, Operating
Experience
Review From CDBI Self Assessment
70123261, Service Water Piping lssues 70109106, Auxiliary
Feed Pump Actuation NCVs and Findinqs0500027212009003-02, Inadequate
maintenance
of the 13 AFW pump governor 0500031 1/2009003-01, lmproper MR scoping of the service water intake structure
sump system O5OOO272l3112AO9O07-01, Failure to establish
goals and monitor for (a)(1) service water system 0500031 1/2009005-01, Unit 2 Degradation
of Shutdown Cooling Caused by Failure ot 22RH18 0500031112009005-02, Inadequate
Maintenance
of the 22 CCHX Service Water Outlet Butterfly Valve 05000272131
12010002-01, Chillers Inoperability
Exceeds TS AOT 050A0272131
/201 0003-02, 21 SGFP Trip 05000272131112010005-01, 13 TDAFW pump trip mechanism 05A00272131112011007-01 , Inadequate
Calculations
for Degraded Voltage Relay Set Point 05000272131112011007-02, Failure to Perform a TS Required Battery Performance
Test 05000272131112009403-01, Failure to Detect Penetration
or Attempted
Penetration
at the Protected
Area Boundary 0500027 21 31 1 l 2009403-02, I nadeq uate Protected
Area E ntry Sea rch 05000272131112011007-03, Failure to ldentify and Correct A Condition
Adverse to Quatity Affecting
CREACS Expansion
Joints LERS OISOOOZZZ\2Ol0-001-0, Automatic
Start of the 1C Emergency
Diesel Generator (EDG)O5OOO272\2O1O-002-\
Missed Containment
Spray Valve Surveillance
Per Technical Specification 4.0.5 O5OOO27 2120 1 0-004-0, Tech n ical Specif ication 3. 0. 4. b Non-Com pliance 0500027212008-002-0, Automatic Reactor Trip Due to Main Power Transformer
Bushing Failure Procedures
LS-AA-115, Operating
Experience
Program, Revision 12 LS-AA-1 15-1001, Manual for Processing
OE1 Documents, Revision 1 LS-AA-115-1002, Manualfor
Processing
OE2 Documents, Revision 0 LS-AA-115-1003, Manualfor
Processing
OE3 Documents, Revision 0 LS-AA-1 15-1004, Manual for Processing
OE4 Documents, Revision 0 ER-AA-3130-1005, Maintenance
Rule Dispositioning
between (a)(1) and (aX2), Revision 7 Attachment
ER-AA-310, lmplementation
of the Maintenance
Rule, Revision 8 LS-AA-120, lssue ldentification
and Screening
Process, Revision 10 LS-AA-125, Corrective
Action Program (CAP) Procedure, Revision 13 LS-AA-1 25-1002, Common Cause Analysis Manual, Revision 7 LS-AA-125-1003, Apparent Cause Evaluation
Manual, Revision 11 LS-AA-125-1004, Effectiveness
Review Manual, Revision 4 LS-AA-1 26, Self-Assessment
Program, Revision 9 LS-AA-126-1
001, Focused Area Self-Assessments, Revision 5 LS-AA-1 26-1 005, Check-ln Self-Assessments, Revision 4 S
- C. lC-Tl.CA-000't, Control Air Dryers Preventative
Maintenance, Revision 3 SC.MD-PM.AF-0007, 13 and 23 Auxiliary
Terry Turbine Linkage Inspection
and Lubrication, Revision 2 WC-AA-106, Work Screening
and Processing, Revision 11 LS-AA-125-1001, Root Cause Evaluation
Manual, Revision 8 LS-AA-125-1005, Coding and Analysis Manual, Revision 6 LS-AA-125-1006, Department
and Station Roll-up Meetings (DRUM SRUM), Revision 2 LS-AA-125-F1, Salem/Hope
Creek MRC Evaluation
and Effectiveness
Checklist
and Grading Sheet. Revision 2 LS-AA-125-F2, Salem/Hope
Creek Long Term Corrective
Action Request (LTCA)LS-AA-125-F4, Work Group Evaluation (WGE)LS-AA-1 26-1002, Management
Observation
of Activities, Revision 2 Maintenance
Work Orders 60060469 60080965 60083302 60084441 6008661 5 60080388 30164377 30076957 30174943 30117617 30184482 30189127 50127727 50127830 501 38541 501 39495 501 39801 501 40351 50141282 40026546 30188428 301 92058 30192351 301 931 95 301 9321 0 301 86321 60091 71 6 60087672 60087673 60087602 301 86829 60086708 301 76991 30190777 30079595 60078098 60093560 60083756 60085587 600891 50 30182608 60089757 60083368 Completed
Surveillances
S1.OP-ST.DG-002, 1B Diesel Generator
Surveillance
Test, Completed
06113111 S1 .OP-ST.DG-0014, 1C Diesel Generator
Endurance
Run, Completed
03/16/1 1 52.OP-ST.DG-004, 21 Fuel Oil Transfer System Operability
Test, Completed
06/13i11 S2.OP-ST.DG-0019,2A
Diesel Generator
Hot Restart Test, Completed
21Q4111 52.OP-ST.DG-004, 21 Fuel Oil Transfer System Operability
Test, Completed
07111111 S1.OP-ST.AF-0003, Inservice
Testing - 13 Auxiliary
Pump, 06130111 S1.OP-ST.AF-0004, Inservice
Testing - Auxiliary
Valves, 06113111 S1.OP-ST.AF-0008, Auxiliary
Valve Verification
Modes 1-3,06120111
2.OP-ST.AF-0003, Inservice
Testing - 23 Auxiliary
Pump, 05106111 52.OP-ST.AF-0006, lnservice
Testing - Auxiliary
Valves, 05124111 52.OP-ST.AF-0009, Plant Systems - Auxiliary
Feedwater, 0510411 1 Attachment
Miscellaneous
Station Air System Health Report- 2no Quarter 2011 Unit 1 Auxiliary
System Health Report- 2no Quarler 2011 Unit 2 Auxiliary
System Health Report - 2no Quarter 2Q11 Unit 1 Residual Heat Removal System Health Report - 2no Quarter 2011 Unit 2 Residual Heat Removal System Health Report - 2no Quarter 2Q11 Salem ControlAir
Quality Test Results, September, 2009 to June 2011 Emergency
Preparedness
Training Drill Critique Report (S11-02), 0512512011
Order 80102809, Provide Range for Oil Levels in RHR Pump Motor Oil Reservoirs, 1111912010
CMP-1SW-7
"#13 Containment
Fan Coil Unit Service Water Outlet Check Valves to the Service Water Discharge
Header CM Plan (Unit 1)ADAMS CFR ECP tMc NCV NRC PARS PSEG SCWE SDP SPAR LIST OF AGRONYMS Agency-wide
Documents
Access and Management
System Code of Federal Regulations
Employee Concerns Program Inspection
Manual Chapter Non-Cited
Violation Nuclear Regulatory
Commission
Publicly Available
Records System PSEG Nuclear LLC Safety Conscious
Work Environment
Significance
Determination
Process Standardized
Plant Analysis Risk Attachment