Text

IR 05000338-12-007 & 05000339-12-007, 05/21/2012 - 08/15/2012; North Anna Power Station - NRC Component Design Bases Inspection
	ML12269A465
Person / Time
Site:	North Anna
Issue date:	09/25/2012
From:	Nease R L; NRC/RGN-II/DRS/EB1
To:	Heacock D A; Virginia Electric & Power Co (VEPCO)
References
	IR-12-007
	Download: ML12269A465 (51)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION REGION II 245 PEACHTREE CENTER AVENUE NE, SUITE 1200 ATLANTA, GEORGIA 30303-1257 September 25, 2012

Mr. David President and Chief Nuclear Officer Virginia Electric and Power Company Dominion Nuclear Innsbrook Technical Center 5000 Dominion Boulevard

Glen Allen, VA 23060-6711 SUBJECT: NORTH ANNA POWER STATION

- NRC COMPONENT DESIGN BASES INSPECTION - INSPECTION REPORT 05000338/2012007 AND 05000339/2012007

Dear Mr. Heacock:

On, August 15, 2012, U. S. Nuclear Regulatory Commission (NRC) completed an inspection at your North Anna Power Station, Units 1 and 2. The enclosed inspection report documents the inspection results, which were discussed on August 15, 2012, with Mr. Oppenhimer and other members of your staff.

The inspection examined activities conducted under your license as they relate to safety and compliance with the Commission's rules and regulations and with the conditions of your licenses. The team reviewed selected procedures and records, observed activities, and interviewed personnel.

This report documents five NRC identified findings of very low safety significance (Green), which were determined to involve violations of NRC requirements. The NRC is treating these violations as non-cited violations consistent 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 20555-001; with copies to the Regional Administrator Region II; the Director, Office of Enforcement, United States Nuclear Regulatory Commission, Washington, DC 20555-0001; and the NRC Resident Inspector at North Anna. Further, 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 II, and the NRC Resident Inspector at North Anna. The information you provide will be considered in accordance with Inspection Manual Chapter 0305.

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 NRC's document system (ADAMS). ADAMS is accessible from the NRC Web site at http://www.nrc.gov/reading-rm/adams.html (the Public Electronic Reading Room).

Sincerely,

/RA/

Rebecca L. Nease, Chief Engineering Branch 1

Division of Reactor Safety

Docket No. 50-338 and 50-339 License No. NPF-4 and NPF-7

Enclosure:

Inspection Report 05000338/2012007 and 05000339/2012007,w/Attachment:

Supplemental Information

cc: (See page 3)

_________________________

X SUNSI REVIEW COMPLETE G FORM 665 ATTACHED OFFICE RII:DRS RII:DRS RII:DCP RII:DRS RII:DRS CONTRACTOR CONTRACTOR SIGNATURE VIA EMAIL VIA EMAIL VIA EMAIL VIA EMAIL VIA EMAIL VIA EMAIL VIA EMAIL NAME FANNER ALEN PHEHER SCHAAF SU T.C. TTINKEL GSKINNER DATE 9/6/2012 9/5/2012 9/5/2012 9/6/2012 9/5/2012 9/5/2012 9/5/2012 E-MAIL COPY? YES NO YES NO YES NO YES NO YES NO YES NO YES NO OFFICE RII:DRS RII:DRP RII:DRS SIGNATURE RA RA RA NAME JEARGLE GMCCOY RNEASE DATE 9/7/2012 9/15/2012 9/25/2012 9/ /2012 9/ /2012 9/ /2012 9/ /2012 E-MAIL COPY? YES NO YES NO YES NO YES NO YES NO YES NO YES NO cc: Mr. Gerald T. Bischof Site Vice President North Anna Power Station Virginia Electric & Power Company Electronic Mail Distribution

Fred Mladen Director, Station Safety & Licensing Virginia Electric and Power Company Electronic Mail Distribution

Michael Crist

Plant Manager North Anna Power Station Virginia Electric & Power Company Electronic Mail Distribution

Lillian M. Cuoco, Esq. Senior Counsel Dominion Resources Services, Inc.

Electronic Mail Distribution

Tom Huber Director, Nuclear Licensing & Operations Support Inssbrook Technical Center Electronic Mail Distribution

Virginia State Corporation Commission Division of Energy Regulation P.O. Box 1197

Richmond, VA 23209

Attorney General Supreme Court Building 900 East Main Street Richmond, VA 23219

Senior Resident Inspector

North Anna Power Station U.S. Nuclear Regulatory Commission P.O. Box 490

Mineral, VA 23117

Donald R. Taylor Licensing Supervisor North Anna Power Station P. O. Box 402

Mineral, VA 23117-0402

Michael M. Cline Director Virginia Department of Emergency Services Management Electronic Mail Distribution

Executive Vice President Old Dominion Electric Cooperative Electronic Mail Distribution County Administrator Louisa County P.O. Box 160

Louisa, VA 23093 Doug Smith President (Public Correspondence Only)

Lake Anna Civil Association Electronic Mail Distribution

Letter to David from Rebecca L. Nease dated September 25, 2012.

SUBJECT: NORTH ANNA POWER STATION

- NRC COMPONENT DESIGN BASES INSPECTION - INSPECTION REPORT 05000338, 339/2012007 Distribution:

G. McCoy S. Ninh, RII DRP G. Kolcum, RII DRP R. Clagg, RII DRP RIDSNRRDIRS PUBLIC RidsNrrPMNorthAnna Resource Enclosure U.S. NUCLEAR REGULATORY COMMISSION

REGION II

Docket Nos: 05000338, 05000339

License Nos: NPF-4 & NPF-7

Report Nos: 05000338/2012007 and 05000339/2012007

Licensee: Virginia Electric and Power Company (VEPCO)

Facility: North Anna Power Station, Units 1 & 2

Location: 1022 Haley Drive Mineral, Virginia 23117

Dates: May 21 - August 15, 2012

Inspectors: Jason Eargle, Senior Reactor Inspector (Lead) Patrick Heher, Senior Construction Project Inspector Alejandro Alen, Reactor Inspector Rodney Fanner, Reactor Inspector Kenneth Schaaf, Operations Engineer T.C. Su, Reactor Inspector (Training)

George Skinner, Accompanying Personnel Terry Tinkel, Accompanying Personnel

Approved by: Rebecca Nease, Chief Engineering Branch 1 Division of Reactor Safety Enclosure

SUMMARY OF FINDINGS

IR 05000338, 339/2012007; 05/21/2012 - 08/15/2012; North Anna Power Station, Units 1 & 2; Component Design Bases Inspection.

This inspection was conducted by a team of six Nuclear Regulatory Commission (NRC) inspectors from Region II, and two NRC contract personnel. Five Green non-cited violations (NCV) were identified. The significance of most findings is indicated by their color (Green, White, Yellow, Red) using the NRC Inspection Manual Chapter (IMC) 0609, "Significance Determination Process," (SDP). Findings for which the SDP does not apply may be Green or be assigned a severity level after NRC management review. The NRC's program for overseeing the safe operation of commercial nuclear power reactors is described in NUREG-1649, "Reactor Oversight Process," (ROP) Revision 4, dated December 2006.

NRC identified and Self-Revealing Findings

Cornerstone: Mitigating Systems

Green.

The team identified a non-cited violation of 10 CFR 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings" for the licensee's failure to develop an adequate test procedure which demonstrated that the quench spray and outside recirculation spray pumps' discharge check valves were capable of performing their design basis function. The licensee entered this issue into their corrective action program as condition report 479661.

The licensee's failure to develop an adequate test procedure which demonstrated that the quench spray and outside recirculation spray pumps' discharge check valves were capable of performing their design bases functions was a performance deficiency. This performance deficiency was more than minor because it was associated with the procedure quality attribute of the mitigating system cornerstone and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems to respond to initiating events to prevent undesirable consequences. Specifically, the failure to measure the torque required to cycle the check valves and compare these with established limits could result in the failure to detect degraded valve performance and prevent it from performing as designed. In accordance with Nuclear Regulatory Commission Inspection Manual Chapter 0609.04, "Initial Screening and Characterization of Findings", the team conducted a Phase 1 Significance Determination Process screening and determined the finding to be of very low safety significance (Green) because it was not a design deficiency, did not represent the loss of a system safety function, did not result in exceeding a Technical Specification allowed outage time, and did not screen as potentially risk-significant due to a seismic, flooding, or severe weather initiating event. The team identified a cross-cutting aspect in the decision making component of the human performance area H.1(b). [Section 1R21.2.3]

Green.

The team identified a non-cited violation of 10 CFR Part 50, Appendix B, Criterion III, "Design Control," for the licensee's failure to implement design control measures involving two examples. In the first example, the licensee failed to translate the updated final safety analyses report single failure design bases criteria into the service water (SW) air system specifications. In the second example, the licensee failed to verify the SW air system receiver capacity was adequate to support its design basis function. The licensee entered these issues into their corrective action program as condition reports 477213, 478531, 478957, and 478137.

The licensee's failure to establish design control measures to translate the updated final safety analyses report single failure design basis criteria into SW air system specifications and failure to verify or check the adequacy of the SW air receiver capacity was a performance deficiency. The performance deficiency was determined to be more than minor because it was associated with the Design Control attribute of the Mit igating Systems Cornerstone and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, if the screen wash system was required to mitigate the effects of a severe weather initiating event, the performance deficiency could have resulted in a common mode failure of t he SW system. In accordance with NRC IMC 0609.04, "Initial Screening and Characterization of Findings," the team conducted a Phase 1 Significance Determination Process screening and determined that a Phase 3 assessment was required because the finding screened as potentially risk-significant due to a severe weather initiating event which could plug the SW traveling screens requiring the screen wash function. A bounding Significance Determination Process Phase 3 analysis was performed by a regional senior risk analyst which determined the performance deficiency was a Green finding of very low safety significance. The finding was reviewed for cross-cutting aspects and none were identified since the performance deficiency was not indicative of current licensee performance. [Section 1R21.2.9]

Green.

The team identified a non-cited violation of 10 CFR Part 50, Appendix B, Criterion XI, "Test Control," for the licensee's failure to test the Service Water (SW) air subsystem capability to perform its design bases function. Specifically, the licensee was not testing the air receiver inlet valves' (1-SW-343 and 1-SW-105), or system integrity to ensure the system's capability to maintain header pressure without crediting the non-safety related air compressors. The licensee entered this issue into their corrective action program as condition report 478568.

The licensee's failure to test the safety related SW air system's capability to maintain adequate header pressure when the SW air compressors are not available was a performance deficiency. 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 to ensure the availability, reliability and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, the failure to perform testing of the SW air system resulted in a lack of reasonable assurance of the system's capability to maintain adequate header pressure and could have resulted in a premature or complete loss of the screen wash system. If the screen wash system was required to mitigate the effects of a severe weather initiating event, the performance deficiency could have resulted in a common mode failure of the SW system. In accordance with Nuclear Regulatory Commission Inspection Manual Chapter 0609.04, "Initial Screening and Characterization of Findings," the team conducted a Phase 1 Significance

Determination Process screening and determined that a Phase 3 assessment was required because the finding screened as potentially risk-significant due to a severe weather initiating event which could plug the SW travelling screens requiring the screen wash function. A bounding Significance Determination Process Phase 3 analysis was performed by a regional senior risk analyst which determined the performance deficiency was a Green finding of very low safety significance. The finding was reviewed for cross-cutting aspects and none were identified since the performance deficiency was not indicative of current licensee performance. [Section 1R21.2.9]

Green.

The team identified a non-cited violation of 10 CFR Part 50, Appendix B, Criterion III, "Design Control," for the licensee's failure to verify the adequacy of thermal overload relay settings for motor operated valves and continuous duty motors. The licensee entered this issue into their corrective action program as condition reports 479217, 479281, 479535, 479552, and 480755.

The licensee's failure to verify or check the adequacy of thermal overload relay settings for motor operated valves and continuous duty motors was a performance deficiency. The performance deficiency was determined to be more than minor because it was associated with the Design Control attribute of the Mitigating Systems Cornerstone and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, there was reasonable doubt as to whether safety related motors would continue to operate without tripping during design basis conditions. In accordance with Nuclear Regulatory Commission Inspection Manual Chapter 0609.04, "Initial Screening and Characterization of Findings", the team conducted a Phase 1 Significance Determination Process screening and determined the finding to be of very low safety significance (Green) because it was a design deficiency confirmed not to have resulted in the loss of operability or functionality. The team identified a crosscutting aspect in the corrective action program component of the problem identification and resolution area P.1(c). [Section 1R21.3]

Green.

The team identified a non-cited violation of 10 CFR Part 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings," involving two examples. In the first example, the licensee failed to ensure that appropriate acceptance criteria was included in procedures for testing motor control center thermal overload relays. In the second example, the licensee failed to ensure that testing was accomplished in accordance with the procedures. The licensee entered these issues into their corrective action program as condition reports 479217, 479281, 479535, 479552, and 480755.

The licensee's failure to ensure that appropriate criteria was included in procedures for testing motor control center thermal overload relays, and the failure to ensure that testing was accomplished in accordance with the procedures was a performance deficiency. The performance deficiency was determined to be more than minor because it was associated with the Procedure Quality attribute of the Mitigating Systems Cornerstone and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, there was reasonable doubt as to whether safety related motors would continue to operate without tripping during design basis conditions. In accordance with Nuclear Regulatory Commission Inspection Manual Chapter 0609.04, "Initial Screening and Characterization of Findings," the team conducted a Phase 1 Significance Determination Process screening and determined the finding to be of very low safety significance (Green) because it was not a design deficiency, did not represent the loss of a system safety function, did not result in exceeding a TS allowed outage time, and did not screen as potentially risk-significant due to a seismic, flooding, or severe weather initiating event. The team identified a crosscutting aspect in the work practices component of the human performance area H.4(b). [Section 1R21.3]

=

Licensee-Identified Violations===

None

REPORT DETAILS

REACTOR SAFETY

Cornerstones: Initiating Events, Mitigating Systems, Barrier Integrity

1R21 Component Design Bases Inspection

Main article: IP 71111.21

.1 Inspection Sample Selection Process

The team selected risk significant components and related operator actions for review using information contained in the licensee's probabilistic risk assessment. In general, this included components and operator actions th at had a risk achievement worth factor greater than 1.3 or Birnbaum value greater than 1 X10

-6. The sample included 14 components, including two associated with containment large early release frequency, and six operating experience items.

The team performed a margin assessment and a detailed review of the selected risk-significant components and operator actions to verify that the design bases had been correctly implemented and maintained. Where possible, this margin was determined by the review of the design basis and Updated Final Safety Analysis Report (UFSAR)response times associated with operator actions. This margin assessment also considered original design issues, margin reductions due to modifications, or margin reductions identified as a result of material condition issues. Equipment reliability issues were also considered in the selection of components for a detailed review. These reliability issues included items related to failed performance test results, significant corrective action, repeated maintenance, maintenance rule status, Regulatory Issue Summary 05-020 (formerly Generic Letter 91-18) conditions, NRC resident inspector input regarding problem equipment, system health reports, industry operating experience, and licensee problem equipment lists. Consideration was also given to the uniqueness and complexity of the design, operating experience, and the available defense-in-depth margins. An overall summary of the reviews performed and the specific inspection findings identified is included in the following sections of the report.

.2 Component Reviews

Description:

Units 1 and 2 QS and ORS systems hav e check valves 1/2-QS-11, 1/2-QS-19, 1/2-RS-18, and 1/2-RS-27 on the pumps' discharge. These valves have both open and close safety-related functions. The valves open to provide the flow paths from the QS and ORS pumps to the respective spray ring header, and close to prevent back leakage and maintain containment integrity when the pumps are not running during design bases events. The check valves are located inside containment and are of the swing type with a weight-loaded balance arm design, which attaches weight-loaded levers (balance arms) on either side the valve's hinge pin (external to the valve body). The balance arms are installed at an angle that assists the close function of the valves.

The licensee used procedures, 1-PT-66.1, "Weight-Loaded Check Valves," Rev 17 and 2-PT-66.1, "Weight-Loaded Check Valves," Rev 16, to demonstrate the opening and closure functions of the check valves. The open function of the check valves is verified by having two operators pull on each side of the balance arms (mechanically exercising) to confirm the valves cycle through its full travel motion. Typically, the open function of check valves is verified under minimum design bases flow conditions to ensure the valves will perform their intended function, how ever, these valves are not part of the pumps' test-loop flowpath and their open function is verified by mechanical exercitation. The team identified the following deficiencies in the test procedure:

The team noted that the American Society of Mechanical Engineers Operation and Maintenance Code (code that establishes the in-service test requirements for mechanical components used in nuclear power plants) requires, for check valves that are mechanically exercised, measuring the force(s) or torque(s) needed to cycle the valve's disc to fulfill its safety function (subsection ISTC-5220 "Check Valves"). Further, it states that the acceptance criteria shall be established by the licensee and shall detect, in part, binding of the disc throughout its full travel. The current test procedures did not establish limits nor measure the forces or torques required by the operators to successfully exercise the valves throughout its full motion of travel.

The team also noted the licensee had used anot her test procedure 1/2-PT-211.3, "Valve In-Service Inspection for 1/2-QS-11, 1/2-QS-19, 1/2-RS-18, and 1/2-RS-27," in conjunction with 1/2-PT-66.1 up until August 2009, when it was superseded. This procedure provided instructions to measure the torques required to manually exercise the check valves and compare them with established limits, which met the Code requirements. On August 5, 2009, the licensee eliminated the use of 1/2-PT-211.3 on the assumption that 1/2-PT-66.1 met the same in-service test requirements, however, the licensee had no technical basis or evaluation that supported this assumption. The team concluded that the procedure for the QS and ORS discharge check valves was inadequate because verification of valve disc cycling without measuring the required torques could result in the failure to detect degraded valve performance and prevent it from supporting the design flow rates assumed in the safety analyses. This issue was entered into the licensee's corrective action program (CAP) as condition report (CR)

479661.

The licensee performed operability determination (OD) 000175, to review the work order history of 1/2-PT-211.3 back to 1994 (including most recent results prior to removal of the procedure). The review results indicated satisfactory valve performance with no evidence of negative trends. This provided reasonable assurance that, at the time of the inspection, the function of the check valves was not degraded.

Analysis:

The licensee's failure to develop an adequate test procedure which demonstrated that the QS and ORS pumps' discharge check valves were capable of performing their design bases functions was a performance deficiency. This performance deficiency was more than minor because it was associated with the procedure quality attribute of the mitigating system cornerstone and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems to respond to initiating events to prevent undesirable consequences. Specifically, the failure to measure the torque required to cycle the check valves and compare these with established limits could result in the failure to detect degraded valve performance and prevent it from performing as designed. In accordance with Nuclear Regulatory Commission (NRC) Inspection Manual Chapter (IMC) 0609.04, "Initial Screening and Characterization of Findings," the team conducted a Phase 1 Significance Determination Process (SDP) screening, and determined the finding to be of very low safety significance (Green) because it was not a design deficiency, did not represent the loss of

a system safety function, did not result in exceeding a TS allowed outage time, and did not screen as potentially risk-significant due to a seismic, flooding, or severe weather initiating event. The team identified a cross-cutting aspect in the decision making component of the human performance area because the licensee failed to verify the validity of the assumption that procedure 1/2-PT-66.1 satisfied the same test requirements as the superseded procedure, 1/2-PT-211.3. H.1(b).

Enforcement:

Appendix B of 10 CFR Part 50, Criterion V, requires, in part, that activities affecting quality shall be prescribed by documented instructions, procedures, or drawings, of a type appropriate to the circumstances. Contrary to the above, since August 2009, the licensee failed to provide a procedure appropriate to the circumstances for testing the QS and ORS pump's discharge check valves.

Specifically, the failure to measure the torques required to cycle the check valves and compare these with established limits could result in the failure to detect degraded valve performance and prevent the valves from performing as designed. Because this violation was determined to be of very low safety significance and has been entered into the licensee's CAP as CR 479661, it is being treated as an NCV consistent with Section 2.3.2 of the NRC Enforcement Policy: NCV 05000338 & 339/2012007-01, "Failure to Develop an Adequate Procedure to Test the Quench Spray and Outside Recirculation Spray Pump

Discharge Check Valves."

.2.4 High Head Safety Injection/Charging Pumps (2-CH-P-1A/B/C)

a. Inspection Scope

The team reviewed the plant's TS, UFSAR, SDBDs, electrical drawings, and P&IDs to establish an overall understanding of the design bases of the Unit 2 High Head Safety Injection/Charging Pumps. Design calculations (i.e., short-circuit analyses, NPSH, vortex formation and prevention, and minimum pump performance requirements versus system total dynamic head) were reviewed to verify that the design bases and design assumptions had been appropriately translated into these documents. Modifications were reviewed to verify that the subject modifications did not degrade the component's performance capability and were appropriately incorporated into relevant drawings and procedures. Component walkdowns were conducted to verify that the installed configurations would support their design bases functions under accident conditions and had been maintained to be consistent with design assumptions. Test procedures and recent test results were reviewed against design bases documents to verify that acceptance criteria for tested parameters were supported by calculations or other engineering documents and that individual tests and analyses served to validate component operation under accident conditions. Operating procedures and alarm response procedures were reviewed to verify that component operation and alignments were consistent with design and licensing bases assumptions. Vendor documentation, preventive and corrective maintenance history, and corrective action system documents were reviewed in order to verify that potential degradation was monitored or prevented and that component replacement was consistent with inservice/equipment qualification life. The protective relaying schemes and calculations were reviewed to verify that the motor was adequately protected and verify that it was not susceptible to spurious tripping. The control circuits were reviewed to verify that the appropriate design requirements had been translated into the controls and interlocks for the pumps.

b. Findings

No findings were identified.

.2.5 Unit 2 Emergency Diesel Generator (EDG) Jacket Cooling Water System

a. Inspection Scope

The team reviewed the plant's TS, UFSAR, SDBDs, and P&IDs to establish an overall understanding of the design bases of the Unit 2 EDG jacket cooling water system. In the absence of analytical analyses supporting parameter requirements, purchase specifications and test studies performed by the manufacturer were reviewed in order to verify the system would adequately remove heat from the EDG under accident conditions. Modifications were reviewed to verify that the subject modifications did not degrade the component's performance capability and were appropriately incorporated into relevant drawings and procedures. Component walkdowns were conducted to verify that the installed configurations would support their design bases functions under accident conditions and had been maintained to be consistent with design assumptions.

Operating and maintenance procedures in preparation for cold and warm weather conditions were reviewed to verify that system alignments and cooling medium properties were consistent with design and licensing bases assumptions. Test procedures and cooling parameters trending data results were reviewed against design basis documents to verify that acceptance criteria for tested parameters were supported by calculations or other engineering documents and that individual tests and analyses served to validate component operation under accident conditions. Vendor documentation, system health reports, preventive and corrective maintenance history, and corrective action system documents were reviewed in order to verify that potential degradation was monitored or prevented and that component replacement was consistent with inservice/equipment qualification life.

b. Findings

No findings were identified.

.2.6 Alternate Alternating Current (AAC) Diesel

a. Inspection Scope

The team reviewed the plant TS, Technical Requirements Manual, UFSAR, SDBDs, electrical drawings, and P&IDs to establish an overall understanding of the design bases of the air start, fuel oil, heat removal systems, and electrical systems of the AAC Diesel Generator (DG). Design calculations (i.e., fuel oil day tank volume, and electrical loading) were reviewed to verify the design bases and design assumptions had been appropriately translated into these documents. Component walkdowns were conducted to verify that the installed configurations would support their design bases functions under accident conditions and had been maintained to be consistent with design assumptions. Operating procedures were reviewed to verify that component operation and alignment were consistent with design and licensing bases assumptions. Test procedures and results were reviewed against design basis documents to verify that acceptance criteria for tested parameters were supported by calculations or other engineering documents and that individual tests and/or analyses served to validate component operation under accident/event conditions. Vendor documentation, system health reports, preventive and corrective maintenance history, and corrective action system documents were reviewed in order to verify that potential degradation was monitored or prevented and the component replacement was consistent with inservice/equipment qualification life. Maintenance rule information was reviewed to verify that the component was properly scoped, and that appropriate preventive maintenance was being performed to justify current MR status. Completed alignment procedures were reviewed to verify elementary schematic positions were consistent with control switch development drawings and the AAC design requirements. A walkthrough of the procedure to place the AAC DG in parallel with the various transfer busses was performed, and various operations of the AAC DG on the plant reference simulator were reviewed to verify that required operator actions could be completed within specified times.

b. Findings

No findings were identified.

.2.7 Unit 1 Pressurizer Power Operated Relief Valves (1-RC-PCV-1456 and 1-RC-PCV-

1455C)

a. Inspection Scope

The team reviewed the plant TS, UFSAR, SDBDs, and P&IDs to establish an overall understanding of the design bases of the Unit 1 pressurizer power operated relief valves.

Design calculations (i.e. valve stem thrust, air operated valve (AOV) actuator capability, and accumulator sizing) were reviewed to verify the design bases and design assumptions had been appropriately translated into these documents. Operating procedures were reviewed to verify that component operation and alignment were consistent with design and licensing bases assumptions. Test procedures and results were reviewed against design basis documents to verify that acceptance criteria for tested parameters were supported by calculations or other engineering documents and that individual tests and/or analyses served to validate component operation under accident/event conditions. Vendor doc umentation, preventive and corrective maintenance history, and corrective action system documents were reviewed in order to verify that potential degradation was monitored or prevented and the component replacement was consistent with inservice/equipment qualification life. Walkdowns of the main control room were completed to verify the adequacy of the indicators and control switches used to operate the valves.

b. Findings

No findings were identified.

.2.8 Unit 2 Low Head Safety Injection Pumps (2-SI-P-1A and 2-SI-P-1B)

a. Inspection Scope

The team reviewed the plant TS, UFSAR, SDBDs, electrical drawings, and P&IDs to establish an overall understanding of the design bases of the Unit 2 LHSI pumps.

Design calculations (i.e., short-circuit analyses, NPSH, vortexing, and system head loss) were reviewed to verify the design bases and design assumptions had been appropriately translated into these documents. Operating procedures were reviewed to verify that component operation and alignment were consistent with design and licensing bases assumptions. Test procedures and results were reviewed against design basis documents to verify that acceptance criteria for tested parameters were supported by calculations or other engineering documents and that individual tests and/or analyses served to validate component operation under accident/event conditions. Vendor documentation, preventive and corrective maintenance history, and corrective action system documents were reviewed in order to verify that potential degradation was monitored or prevented and the component replacement was consistent with inservice/equipment qualification life. Component walkdowns were conducted to verify that the installed configurations would support their design bases functions under accident conditions and had been maintained to be consistent with design assumptions. The protective relaying schemes and calculations were reviewed to verify that the motor was adequately protected and verify that it was not susceptible to spurious tripping. The control circuits were reviewed to verify that the appropriate design requirements had been translated into the controls and interlocks for the pumps.

b. Findings

No findings were identified.

.2.9 Unit 1 and 2 Service Water (SW) Screen Wash Subsystem including Screen Wash Pump 1-SW-P-2, Screen Wash Strainer 1-SW-S-3, and Traveling Screen 1-SW-S-1A

a. Inspection Scope

The team reviewed the plant TS, UFSAR, SDBDs, electrical drawings, and P&IDs to establish an overall understanding of the design bases of the Unit 1 and 2 SW Screen Wash Subsystem. Design calculations (i.e., NPSH) were reviewed to verify the design bases and design assumptions had been appropriately translated into these documents.

Operating procedures were reviewed to verify that component operation and alignment were consistent with design and licensing bases assumptions. Test procedures and results were reviewed against design basis documents to verify that acceptance criteria for tested parameters were supported by calculations or other engineering documents and that individual tests and/or analyses served to validate component operation under accident/event conditions. Vendor documentation, system health reports, preventive and corrective maintenance history, and corrective action system documents were reviewed in order to verify that potential degradation was monitored or prevented and the component replacement was consistent with inservice/equipment qualification life. Maintenance rule information was reviewed to verify that the component was properly scoped, and that appropriate preventive maintenance was being performed to justify current maintenance rule status. Component walkdowns were conducted to verify that the installed configurations would support their design bases functions under accident conditions and had been maintained to be consistent with design assumptions. A walkdown of selected procedures was performed with plant operators to verify the adequacy and timeliness of operator actions to provide an alternate method of washing the SW traveling screens.

b.1 Findings

Introduction:

The team identified a Green NCV of 10 CFR Part 50, Appendix B, Criterion III, "Design Control," for the licensee's failure to implement design control measures involving two examples. In the first example, the licensee failed to translate the UFSAR single failure design bases criteria into the SW air system specifications. In the second example, the licensee failed to verify the SW air system receiver capacity was adequate to support its design basis function.

Description:

The team identified two examples of a violation of 10 CFR Part 50, Appendix B, Criterion III, "Design Control:"

Example 1: Failure to translate the UFSAR single failure design bases criteria into the SW air system specifications North Anna's Units 1 and 2 SW system has a safety-related screen wash subsystem with the function to wash the SW traveling water screens that filter the reservoir water before it enters the SW pumps' suction bay s. The SW system has four pumps, and each has a dedicated traveling screen and suction bay. The screen wash system consists of two pumps that take suction from its associated unit SW pump suction bay. The pumps discharge into a common header that supplies four lines, with each line leading to one of four spray nozzles used to wash the screens. Water to the spray nozzle is isolated by AOVs (1-SW-TV-100A/B and 2-SW-TV-200A/B) that requires air to open. The air is provided by the SW air subsystem, which also provides air to the traveling water screen differential level instrumentation. The level instrumentation controls automatic operation of the screen wash system and feeds a differential level alarm in the main control room.

The team noted that UFSAR Section 9.2.1.1, stated, "The SW system is design to support a design-bases-accident, while remaining capable of withstanding a single active component failure without requiring operator action." The team also noted that the SW air system supply header is common to all screen wash system AOVs and that a single failure of any one of multiple SW air subsystem components (i.e. check valves and solenoid valves throughout the system) would result in the failure of the air system.

As a result of the team's observations, the licensee initiated CR 477213 and 478531 and determined that a single active failure of multiple components in the SW air system could result in a failure of the SW screen wash system. The licensee performed OD 000484 and determined that a loss of air pressure would be alarmed in the main control room and the associated alarm response procedure (1-AR-K-G5, Rev 2) called for swapping service water pumps in the event of a clogged screen. The licensee also indicated that operating procedure, 0-OP-49.9, "Use of FP-P-2 to Wash Service Water Screens", Rev 0, provided instructions to manually wash the traveling screens using a combination of fire hoses and the non-safety related diesel-driven fire pump located adjacent to the screens inside the service water pump house.

The team noted the following regarding the ARP and OP:

(1) no direct means were available to determine if the screens were clogged;

(2) indications of a debris-loaded reservoir and cavitation of the SW pumps would be the only means of determining if a screen was clogged (this could be too late to prevent pump damage);

(3) swapping to a different SW pump will not preclude eventual clogging of its screen; and

(4) procedure 0-OP-49.9 was not referenced in the ARP. The licensee revised the initial OD and modified procedure 1-AR-K-G5 to include operator actions to rotate and inspect the traveling screens for debris, to use procedure 0-OP-49.9 to wash debris from the traveling screens, and to monitor SW system parameters for evidence of reduced flow and the SW reservoir for an increase in debris. The team determined that a severe weather initiating event of high wind conditions (i.e. tornado) that deposits sufficient debris in the reservoir coincident with a loss of SW air (due to a single active failure) could have resulted in a common mode failure of the SW system.

Example 2: Failure to verify or check the adequacy of the SW air receiver capacity The team requested the licensee's calculation or analysis that verified the capacity of the SW air receiver tank (1-SW-TK-2) was sufficient to support a specific design bases mission time. The licensee was unable to locate a sizing calculation and could not provide additional design bases information with regards to the SW air system mission

time. During normal operations the SW air system is maintained pressurized by two non-safety-related air compressors, which cannot be credited to maintain SW air system header pressure during an accident. The team noted that while the licensee was not able to identify any documented mission time for the SW screen wash system specifically, the FSAR stated that the SW reservoir is adequate to provide sufficient cooling for at least 30 days. The team determined that the accumulators would not have sufficient capacity to ensure that the performance deficiency would not challenge the ability of the SW screen wash system to support the mission time of the ultimate heat sink. As in example #1, the loss of the SW air system would render the screen wash system non-functional. The inadequate sizing of the SW screen wash system air receiver and loss of SW screen wash during a severe weather initiating event could represent a common mode failure vulnerability of the SW system. The licensee entered this issue into their corrective action program as CR 478137 and used OD 000484 as a basis for SW system operability.

Analysis:

The licensee's failure to establish design control measures to translate the UFSAR single failure design basis criteria into SW air system specifications and failure to verify or check the adequacy of the SW air receiver capacity was a performance deficiency. The performance deficiency was determined to be more than minor because it was associated with the Design Control attribute of the Mitigating Systems Cornerstone and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, if the screen wash system was required to mitigate the effects of a severe weather initiating event, the performance deficiencies could have resulted in a common mode failure of the SW system. In accordance with NRC IMC 0609.04, "Initial Screening and Characterization of Findings," the team conducted a Phase 1 SDP screening and determined that a phase 3 assessment was required because the finding screened as potentially risk-significant due to a severe weather initiating event which could plug the SW travelling screens requiring the screen wash function.

A bounding SDP Phase 3 analysis was performed by a regional senior risk analyst (SRA) using the latest North Anna Standardized Plant Analyses Risk model. An

initiating event assessment was run for a weather-related loss of offsite power with loss of all SW traveling screens and circulating water (CW) due to debris plugging from severe weather storm debris. The failure probability of the SW screen wash system was set at 1E-1 and no recovery of SW was assumed. The severe weather initiator with potential for generating storm debris was set at 1E-4/year. The dominant sequence was a severe weather condition which was assumed to cause debris loading of the reservoir and plug the SW traveling screens and cause a loss of CW as well as a weather-related loss of offsite power. The sequence progressed to a loss of reactor coolant pump seal integrity leading to a small loss of coolant accident, with subsequent failure of decay heat removal leading to core damage. The increase in core damage frequency due to the performance deficiency was less than 1E-6/year, a Green finding of very low safety significance. The finding was reviewed for cross-cutting aspects and none were identified since the performance deficiency was not indicative of current licensee

performance.

Enforcement:

10 CFR 50, Appendix B, Criterion III, "Design Control," requires, in part, that "measures shall be established to assure that the design bases are correctly translated into specifications", and that "measures shall provide for verifying or checking the adequacy of design". Contrary to the above, since initial plant operation, the licensee failed to establish design control measures to 1) assure the single failure design basis criteria, as stated in the UFSAR, was correctly translated into design specifications of the SW air system, and 2) verify the adequacy of the SW air receiver capacity to ensure its capability of supporting the system's design basis function. Because this violation was determined to be of very low safety significance (Green) and has been entered into the licensee's CAP as CRs 477213, 478137, 478531, and 478957 it is being treated as an NCV consistent with Section 2.3.2 of the NRC Enforcement Policy: NCV 05000338, 339/2012007-02, "Failure To Implement Design Control Measures For The

Service Water Air Subsystem."

b.2 Findings

Introduction:

The team identified a green NCV of 10 CFR Part 50, Appendix B, Criterion XI, "Test Control," for the licensee's failure to test the SW air subsystem capability to perform its design bases function. Specifically, the licensee was not testing the air receiver inlet valves (1-SW-343 and 1-SW-105), or system integrity to ensure the system's capability to maintain header pressure without crediting the non-safety related air compressors.

Description:

North Anna's Units 1 and 2 SW system has a, safety-related, screen wash subsystem with the function to wash the SW traveling water screens which filter the reservoir water before it enters the SW pumps' suction bays. The SW air system is provided to support operation of the screen wash system. Specifically, the SW air system supplies air to the air operated valves (1-SW-TV-100A/B and 2-SW-TV-200A/B) that isolate the screen wash water flowpath to the spray nozzles that backwash the screens. These valves are spring closed and require air to open. If they failed to open, no safety-related means of washing the screens would be available. The SW air system consists of two air compressors, two air dryers, one air tank receiver, and associated valves, piping, and fittings. The SW air syst em is safety-related, except for the compressor and dryer portion of the system. A check valve (1-SW-343) and a solenoid valve (1-SW-105), installed in parallel at the inlet of the air receiver, provide the safety-related/non safety-related interface of the system. These valves were designed to close and maintain adequate header pressure without being recharged by the air compressors.

While reviewing the tests performed on the SW air system the team identified that the licensee was not performing any testing of system integrity with the compressors isolated.

This would be required to determine the performance capabilities of valves 1-SW-343 and 1-SW-105 to isolate and maintain system pressure, in addition to providing assurance of the system pressure boundary integrity. The inspectors determined the lack of testing resulted in a lack of reasonable assurance that the system could perform its design function of supporting screen wash system capability. Additionally, the team determined that the SW reservoir system could be vulnerable to debris loading during severe weather events. As a result of the teams observations the licensee initiated CR 478568 to determine the test requirements needed to demonstrate the system's capability of performing its design bases function.

The licensee performed OD 000484 and determined that a loss of air pressure would be alarmed in the main control room and the associated alarm response procedure (1-AR-K-G5, Rev 2) called for swapping service water pumps in the event of a clogged screen.

The licensee also indicated that it had an operating procedure, 0-OP-49.9, "Use of FP-P-2 to Wash Service Water Screens", Rev 0, that provided instructions to manually wash the traveling screens using a combination of fire hoses and the non-safety related diesel-driven fire pump located adjacent to the screens inside the SW pump house.

The team noted the following regarding the ARP and OP:

(1) no direct means were available to determine if the screens were clogged;

(2) indications of a debris-loaded reservoir and cavitation of the SW pumps would be the only means of determining if a screen was clogged (this could be too late to prevent pump damage);

(3) swapping to a different SW pump will not preclude eventual clogging of its screen; and

No findings were identified.

.2.14 480V Buses 2H, 2H1, 2J, and 2J1

a. Inspection Scope

The team reviewed the plant TS, UFSAR, SDBDs, electrical drawings, and electrical standards to establish an overall understanding of the design bases of the 2H, 2H1, 2J and 2J1 480V Buses. Design calculations (i.e. bus loading calculations, degraded voltage setpoint calculations) were reviewed to verify that the design bases and design assumptions had been appropriately translated into these documents. Component walkdowns were conducted to verify that the installed configurations would support their design bases functions under accident conditions and had been maintained to be consistent with design assumptions. The degraded voltage protection scheme and overcurrent protection scheme were reviewed to verify their ability to meet the design and licensing bases assumptions Vendor documentation, system health reports, and

corrective action system documents were reviewed in order to verify that potential degradation was monitored or prevented.

b. Findings

No findings were identified.

.3 Corrective Actions

a. Inspection Scope

The team reviewed four issues identified during previous CDBIs to assess the effectiveness of the licensee's corrective actions. The issues that received a detailed review by the team included:

NCV05000338/2009007-01, Failure to Perform Periodic TOL Testing on Unit 1

CR358489, MOV Spreadsheet Requires Control Enhancements

CR358933, GL 89-10 MOV Calculation Methodology

CR358809, EDG Tornado Calculation Error b.1 Findings

Introduction:

The team identified a Green NCV of 10 CFR Part 50, Appendix B, Criterion III, "Design Control," for the licensee's failure to verify the adequacy of thermal overload (TOL) relay settings for motor operated valves (MOVs) and continuous duty motors.

Description:

The team identified examples of design control issues involving TOL settings for continuous duty motors, and TOL settings for MOVs. Each will be discussed separately below.

TOL settings for continuous duty motors: The team requested the design calculation or other verified information that documented the settings or the adequacy of the design of the TOLs for continuous duty motors. The licensee provided Engineering Transmittal CEE 01-0013, which was performed to provide a quantitative analysis of the TOL settings for continuous duty motors for lower operating voltages. Additionally, the licensee stated that actual TOL settings were recorded in various work orders associated with routine motor control center scheduled maintenance. The team noted that the Engineering Transmittal only evaluated the overcurrent protection for bus 2H and was not intended to document the design for the entire station, or to be maintained in current state. This concern was partially addressed when the licensee performed reevaluations as a result of CR 463721 (written to investigate whether North Anna was susceptible to TOL setting deficiencies found during a recent CDBI at Surry).

The team observed that the re-evaluations done as a result of CR 463721 were incomplete because they did not evaluate motors for tripping when subjected to voltage afforded by the loss of voltage relays, and did not evaluate the potential for increased current under maximum load conditions. Additionally, the team observed that the licensee used a non-conservative current multiplier to account for voltage afforded by the degraded voltage relays for motors with a 1.0 service factor. Based on these observations, the team determined that the licensee's design control measures to verify the adequacy of the design of the TOLs for continuous duty motors was inadequate. In response to the team's concerns, the licensee issued CRs 479535, 479552, 479658, 480754, initiated apparent cause evaluation (ACE) 019183, and performed additional evaluations to provide reasonable assurance of operability pending resolution.

TOL settings for MOVs: The team determined that Calculations EE-0557 and EE-0506 for MOV TOL sizing did not adequately address the potential for tripping of TOLs at the onset of an accident under degraded voltage conditions, and did not take into account tolerances associated with relay tripping characteristics. The licensee is committed to Regulatory Guide (RG) 1.106, Revision 1, "Thermal Overload Protection For Electric Motors On Motor-Operated Valves." This RG specified methods acceptable to the NRC staff to ensure, that TOLs would not needlessly trip, thus preventing the MOVs from performing their safety-related functions. The RG allowed the licensee to either bypass the TOLs during a design basis event or leave the TOLs in the MOV circuits continuously, provided that they were sized properly and periodically tested. The licensee chose to leave the TOLs in the MOV circuits continuously and prepared Calculations EE-0557 and EE-0506 for sizing the TOLs. The team noted that these calculations did not evaluate whether the TOLs could trip if voltage was too low to start the MOVs at the onset of an accident. If the MOVs stalled, they could draw locked rotor current for the duration of the degraded voltage time delay (9 seconds maximum) before the safety buses were transferred to the emergency diesel generators. In addition, the calculation did not consider the effect of the tolerances on TOL tripping times. These were specified in vendor manual NA-VTM-000-59-K408-F0003 as 105% to 115% of trip setting for long term minimum tripping current, and +/- 20% of expected tripping time for higher currents. In response to the team's concerns, the licensee initiated CRs 479281 and 479664, and performed evaluations for sever al MOVs to determine whether they would be susceptible to spurious tripping, considering the factors identified by the team. Based on these preliminary evaluations, the licensee concluded that the MOVs would either not stall based on minimum bus volt age afforded by the undervoltage scheme, or would not trip within the maximum time delays of the undervoltage protection scheme before transfer of the safety buses to the emergency diesel generators, thereby providing reasonable assurance of operability.

Analysis:

The team determined that the failure to verify or check the adequacy of thermal overload relay settings for MOVs and continuous duty motors was a performance deficiency. The performance deficiency was determined to be more than minor because it was associated with the Design Control attribute of the Mitigating Systems Cornerstone and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, there was reasonable doubt whether safety related motors would continue to operate without tripping during design basis conditions. In accordance with NRC IMC 0609.04, "Initial Screening and Characterization of Findings", the team conducted a Phase 1 SDP screening and determined the finding to be of very low safety significance (Green) because it was a design deficiency confirmed not to have resulted in the loss of operability or functionality. The team identified a crosscutting aspect in the corrective action program component of the problem identification and resolution area because the licensee failed to thoroughly evaluate the problem when similar issues were identified when North Anna performed corrective actions as a result of a finding on the 2011 Surry CDBI P.1(c).

Enforcement:

10 CFR 50, Appendix B, Criterion III, "Design Control," requires, in part, that design control measures provide for verifying or checking the adequacy of design, such as by the performance of design reviews, by the use of alternate or simplified calculational methods, or by the performance of a suitable testing program. Contrary to the above, since February 2012, the licensee's design control measures failed to verify the adequacy of the design of TOL settings for continuous duty motors and MOVs. Because this violation was determined to be of very low safety significance (Green) and has been entered into the licensee's CAP as CRs 479664, 479658, 479535, 479552, 480754, and 480755 it is being treated as an NCV consistent with Section 2.3.2 of the NRC Enforcement Policy: NCV 05000338, 339/2012007-04, "Inadequate Design Control

Measures for Thermal Overload Relays."

b.2 Findings

Introduction:

The team identified a Green NCV of 10 CFR Part 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings

," involving two examples. In the first example, the licensee failed to ensure that appropriate acceptance criteria was included in procedures for testing motor control center TOL relays. In the second example, the licensee failed to ensure that testing was accomplished in accordance with the procedures.

Description:

The team identified two examples of procedural violations:

Example 1: Inadequate Criteria in Therm al Overload Relay (TOL) Test Procedures:

Test methods and criteria for TOLs are provided in preventive maintenance procedure 0-EPM-0307-01, "Testing of Thermal Overloads," and corrective maintenance procedure 0-ECM-0307-01, "Replacement of Thermal Overload Devices." The procedures provide for two types of tests for TOLs; a trip avoidance test based on full load current, and a trip time test at 300% of full load current.

For continuous duty motors, the procedures direct the test crew to calculate the required test currents by multiplying the nameplate full load current by either 1.19 for motors with service factors of 1.15 and above, and by 1.07 for motors with service factors below 1.15. These multipliers were based on guidance in engineering standard STD-EEN-0011, "Standard for Protective Device Settings," and were intended to account for increased current during degraded voltage conditions. The team noted that since current increases proportionally with a decrease in voltage, a multiplier of 1.07 was not adequate to account for the minimum voltage typically allowed for running motors, 90% of rated voltage. The team further noted that calculation EE-0373, "4160V Degraded Voltage and Loss of Voltage Relay Safety Limits," identified that some motors could be subjected to voltage as low as 84%, which would result in even larger increases in motor running current, so that even if a TOL relay passed the full load current test, it could still trip under postulated degraded voltage or maximum load conditions. In response to this concern, the licensee initiated CRs 479535, 479552, and 480755, and performed an evaluation of 8 safety related motors with a service factor of 1.0 for which the 1.07 multiplier had been applied when determining the TOL settings. Although two travelling screen wash motors were determined to be "close in margin" and warranting consideration as margin management issues, all were found to be acceptable (i.e., not likely to trip).

The team also noted that the time delay acceptance criteria for the 300% current test did not agree with the characteristic curves provided for some TOLs in vendor manual NA-VTM-000-59-K408-F0003, which stipulated a tripping time tolerance of +/-20% of the curve values. For example, the tripping time acceptance criteria for the Z00-10 type relay given in procedure 0-ECM-0307-01 was 16 to 38 seconds whereas the expected tripping time based on the curve in the vendor manual was approximately 23 to 34 seconds. The team was concerned that test results outside the expected +/-20% tolerance provided by the vendor would indicate a malfunctioning relay and that the wide range of tripping time variation allowed in the procedure could result in spurious tripping under maximum load or degraded voltage conditions, and had not been accounted for in design calculations. In response to the team's concerns, the licensee initiated CR479281and evaluated test results for several MOVs to determine whether they could trip faster than expected, as determined in the design calculations. The licensee concluded that three MOV circuits would trip faster than determined in the calculations, but were still acceptable from an operability standpoint.

Example 2: Procedure Compliance The team determined that the 300% current tripping time test result for the charging pump suction from the refueling water storage tank isolation valve (CH-MOV-1115B), reported in work order 59102073031 performed on 8/12/10 was outside the acceptance band of the maintenance procedure, but the result was marked "SAT" (satisfactory).

The valve is required to open during safety injection and to close during accident recovery. Procedure 0-ECM-0307-01, "R eplacement of Thermal Overload Devices," Rev. 23 required a tripping time of 16 to 90 seconds for the Z00 type relay, but the actual test time was 13.4 seconds. This was below the procedure criteria of 16 seconds which was non-conservative with respect to spurious tripping vulnerability. As noted above, the tripping time criteria in maintenance procedures was also non-conservative but the failure to meet even this criteria raised concerns regarding the susceptibility of the MOV to spurious tripping under design basis conditions, such as degraded voltage that could cause the MOV to stall while the degraded voltage relay timed out for 9 seconds maximum. In response to this concern, the licensee initiated CR 479217, ACE 019179, and OD 000487 to evaluate this condition. The OD determined that, based on preliminary torque calculations, the MOV was not likely to stall and draw locked rotor current, even at the very low voltage afforded by the Loss of Voltage relays. The licensee therefore determined that the MOV was degraded but operable and required replacement of the relay to restore full qualification.

Analysis:

The licensee's failure to ensure that appropriate criteria was included in procedures for testing motor control center TOL relays, and the failure to ensure that testing was accomplished in accordance with the procedures was a performance deficiency. The performance deficiency was determined to be more than minor because it was associated with the Procedure Quality attribute of the Mitigating Systems Cornerstone and adversely affected the cornerstone objective to ensure the availability, reliability, and capability of systems that respond to initiating events to prevent undesirable consequences. Specifically, there was reasonable doubt as to whether safety related motors would continue to operate without tripping during design basis conditions. In accordance with NRC IMC 0609.04, "Initial Screening and Characterization of Findings," the team conducted a Phase 1 SDP screening and determined the finding to be of very low safety significance (Green) because it was not a design deficiency, did not represent the loss of a system safety function, did not result in exceeding a TS allowed outage time, and did not screen as potentially risk-significant due to a seismic, flooding, or severe weather initiating event. The team identified a crosscutting aspect in the work practices component of the Human Performance area, because the licensee did not define and effectively communicate expectations regarding procedural compliance and personnel did not follow procedures H.4(b).

Enforcement:

10 CFR 50, Appendix B, Criterion V, "Instructions, Procedures, and Drawings," requires, in part, that activities affecting quality shall be prescribed by documented instructions, procedures, or drawings, of a type appropriate to the circumstances and shall be accomplished in accordance with these instructions, procedures, or drawings, and that instruction procedures, or drawings shall include appropriate quantitative or qualitative acceptance criteria for determining that important activities have been satisfactorily accomplished.

Contrary to the above, since August 2010, the licensee failed to ensure that appropriate acceptance criteria was included in procedures for testing motor control center TOL relays, and failed to ensure that testing was accomplished in accordance with the procedures. Because this violation was determined to be of very low safety significance (Green) and has been entered into the licensee's CAP as CRs 479217, 479281, 479535, 479552, and 480755, this violation is being treated as an NCV, consistent with Section 2.3.2 of the NRC Enforcement Policy:

NCV 05000338, 339/2012007-05, "Inadequate Procedures and Procedure Compliance For Thermal Overload Relay Testing."

.4 Operating Experience (Six Samples)

a. Inspection Scope

The team reviewed six operating experience issues for applicability at North Anna Power Station. The team performed an independent review for these issues and where applicable, assessed the licensee's evaluation and dispositioning of each item. The issues that received a detailed review by the team included:

NRC Regulatory Issue Summary 2000-005, "Resolution of Generic Safety Issue 165, Spring-Actuated Safety and Relief Valve Reliability"

NRC Information Notice 2006-22, "New Ultra-Low-Sulfur Diesel Fuel Oil Could Adversely Impact Diesel Engine Performance"

NSAL-09-8, "Presence of Vapor in Emergency Core Cooling System/Residual Heat Removal System in Modes 3 and 4 Loss-of-Coolant Accident Conditions"

NRC Information Notice 87-08, "Degraded Motor Leads in Limitorque DC Motor Operators"

NRC Information Notice 97.21, "Availability of Alternate AC Power Source Designated for Station Blackout Event"

NRC Information Notice 2009-10, "Transformer Failures - Recent Operating Experience"

b. Findings

No findings were identified.

OTHER ACTIVITIES

4OA6 Meetings, Including Exit

On August 15, 2012, the team presented the inspection results to Mr. Oppenhimer and other members of the licensee's staff. Proprietary information that was reviewed during the inspection was returned to the licensee or destroyed in accordance with prescribed controls.

ATTACHMENT:

SUPPLEMENTAL INFORMATION

KEY POINTS OF CONTACT

Licensee personnel

G. Bischof, Site Vice President

M. Crist, Plant Manager

D. Taylor, Supervisor, Station Licensing

J. Leberstien, Technical Consultant Licensing

R. Garver, Manager, Design Engineering

M. Oppenhimer, Manager, System & Component Engineering

NRC personnel

R. Nease, Chief, Engineering Branch Chief 1, Division of Reactor Safety, Region II

G. McCoy, Chief, Project Branch 5, Division of Reactor Project, Region II

J. Eargle, Senior Reactor Inspector, Division of Reactor Safety, Region II

G. Kolcum, Senior Resident Inspector, Division of Reactor Projects, North Anna Resident Office

R. Clagg, Resident Inspector, Division of Reactor Projects, North Anna Resident Office

LIST OF ITEMS

OPENED, CLOSED AND DISCUSSED

Opened and Closed

05000338, 339/2012007-01 NCV Failure to Develop an Adequate Procedure to

Test the Quench Spray and Outside

Recirculation Spray Pump Discharge Check

Valves (Section 1R21.2.3)

05000338, 339/2012007-02 NCV Failure To Implement Design Control Measures

For The Service Water Air System (Section

1R21.2.9)

05000338, 339/2012007-03 NCV Inadequate Testing of the SW Air System (Section 1R21.2.9)

05000338, 339/2012007-04 NCV Inadequate Design Control Measures for

Thermal Overload Relays (Section 1R21.3)

05000338, 339/2012007-05 NCV Inadequate Procedures and Procedure

Compliance For Thermal Overload Relay

Testing (Section 1R21.3)

LIST OF DOCUMENTS REVIEWED

Licensing Documents

TS, Current TRM, Current

UFSAR, Current

SER and Supplements

Calculations

11715/12050-163N, SW Pump NPSH, Rev. 0

1-PT-212.10, Inservice Inspection Calculation Basis, Unit 1, Rev. 0

59-01-PT-211.3-00, Valve Inservice Inspection for 1-QS-11, 1-QS-19, 1-RS-19, 1-RS-27, 3/21/96 59-01-PT-64.1.1, 1-RS-P-2A, A Outside Recirculation Spray Pump, Rev. 4 59-01-PT-64.1.2, 1-RS-P-2B, B Outside Recirculation Spray Pump, Rev. 4 59-01-PT-64.8, Flow Test of the Inside Recirculation Spray Pumps, Rev. 5

59-02-PT-138, 2-SI-P-1A and 1B Comprehensive Pump Testing, Rev. 3

59-02-PT-138.3-06, Combined Charging Pump 1A, 1B, & 1C Head Curve Verification and HHSI Branch Flow Verification, Unit 2, Rev. 6 59-02-PT-14.1-06, Charging Pump 2-CH-P-1A, Rev. 6 59-02-PT-57.1B, ECCS LHSI Pump 2-SI-P-1B, Rev. 2

CEE-97-021, Engineering Transmittal Adequacy of Voltage for Diesel Generator Breaker Close Coil North Anna Units 1 & 2, Rev. 0

CM-AA-ETE-101, Engineering Technical Evaluation (ETEs), Rev. 0

CME-99-0041, Determination of the P requirements and design basis for the QS and ORS weight loaded containment isolation check valves, Rev. 0

EE-0008, North Anna Voltage Profiles, Rev. 2

EE-0009, Addendum D, 125VDC System Analysis-New Unit 1 Duty Cycles and SBO Cases for Units 1 and 2, Rev. 1

EE-0025, North Anna Station Electrical Load List, Rev. 3

EE-0057, DC Equipment Sizing, Rev. 1

EE-0361, Relay Settings for Safety Buses 2H & 2J (coordination, protection, setpoint, relay , 4160V), Rev. 1

EE-0361, Relay Settings for Safety Buses 2H & 2J (coordination, protection, setpoint, relay , 4160V), Rev. 3

EE-0364, Relay Settings for the Protection of Bus 2H, Rev. 1

EE-0365, Relay Settings for the Protection of Bus 2J, Rev. 1

EE-0373, 4160V Degraded Voltage and Loss of Voltage Relay Safety Limits, Rev. 1

EE-0385, 4160V Undervoltage Relays, Types SLV and NGV CSA, Rev. 1

EE-0395,

SR 480V Load Center Coordination, Rev. 2

EE-0500, Motor Terminal Voltage for Motor-Operated Valves, Rev. 3

EE-0845, 4160V and 480V Emergency Buses - Voltage Drops to Switchgear DC 0- Control Circuit Components, Rev. 0

EE-364, Relay Settings for the protection of Bus 2H, Rev. 1

EE-500, Motor Terminal Voltage for Motor-Operated Valves, Rev. 3

EE-506, Size and Setting Calculation for

GL 89-1 0 Scope Motor Operated Valves (MOVs ), Rev. 0

EE-557, Evaluation of TOL's for North Anna Unit 1

GL 89-10 MOV's, Rev. 0

ET-CME-05-0030, SW, QS, LHSI, ORS and IRS Pump Design Inputs to the NAF Containment Analysis Gothic Model, Rev. 1

Attachment

ET-N-09-0047, Justification for Continued Operation with 20 bolt hole Actuator Diaphragms Installed in Masoneilan Model 38 Size 18L Special Actuators, Rev. 2

ME-0105, Technical Report: EDG Room High Temperature Operation Study, Rev. 0

ME-0170, AFW pump flowrate at PCV 'Fail-Open', Rev. 2

ME-0194, Adequacy of the Backup Air Tanks 1/2-IA-TK-4D/E/F/G/H, Rev. 0

ME-0290, Revised NPSHA Calculation per DCPs 90-13 & 93-011, Rev. 0, Add. A

ME-0305, SW Pump Available NPSH during First Hour After DBA, Rev. 0

ME-0305, SW Pump NPSH, App. B, Rev. 0

ME-0410, SBO Diesel Day Tank Level vs. Usable Fuel, Rev 1

ME-0417, Minimum Delivered HHSI Flow for LO

CA Analysis and

PT-138.1,

PT-138.3A/B/C, and

PT-14.4 Flow Test Acceptance Criteria, North Anna 1 & 2, Rev. 4

ME-0466, Pressurizer PORVS Minimum Accumulator Tank Pressure for 120 Strokes in Modes

4, 5, & 6, Rev. 1

ME-0493, Outside Recirculation Spray Pumps (1/2-RS-P-2A & 2B) Design Flow and Total Dynamic Head, Rev. 1

ME-0522, Inside Recirculation Spray Pump Design Flow and TDH, Rev. 1

ME-0579, Minimum Delivered (Design Basis) AFW Flow and Acceptance Criteria for AFW Pump Operability Verification Testing, Rev. 4

ME-0584, Maximum AFW Pump Flow and NPSH Analysis, Rev. 0

ME-0623, System Level Calculation for Category 1 Air Operated Valves, Rev. 0

ME-0628, Minimum Delivered LHSI Flow for LB LOCA Analysis and Acceptance Criteria for LHSI Pump Operability Verification Testing - NA 1 & 2, Rev. 1

ME-0628, Minimum Delivered LHSI Flow for LB LOCA Analysis and Acceptance Criteria for LHSI Pump Operability Verification Testing - NA 1 & 2, Add. A, Rev. 1

ME-0629, Minimum and Maximum Low Head and High Head Safety Injection System Flow Determination for Containment Analysis Input- NA 1& 2, Rev. 2

ME-0659, Evaluation of Category 1 AOVs to perform their Design Bases Function, Rev. 0

NA-CALC-MEC-ME-0120, No Title, Rev. 0, Add. 4

NA-CALC-MEC-ME-0417, Minimum Delivered HHSI Flow for LOCA Analysis and

PT-138.3A/B/C, and -14.4 Flow Test Acceptance Criteria, North Anna 1 & 2, Rev. 4

NA-CALC-MEC-ME-0417, Minimum Delivered HHSI Flow for LOCA Analysis and

PT-138.1, -138.3A/B/C, and -14.4 Flow Test Acceptance Criteria, North Anna Units 1 & 2, Rev. 4 Add.

A

NA-CALC-MEC-ME-0623, AOV, DP, Differential Pressure, Rev. 0

NA-CALC-MEC-ME-0659, Evaluation of Category 1 AOVs to perform their Design Basis Function, Rev. 0

NA-CALC-MEC-SE-0218, Dynamic Head Corrections for Data Collected in 1&2-PT-14.4 and

138.1 and Related Procedures, Rev. 1

NA-CALC-NFL-SM-1042, PSA Service Water (SW) System Analysis, North Anna Power Station, Units 1 & 2, Rev. 0

NA-CALC-PSS-CE-1109, Pipe Stress Analysis of PSARV Piping for DBE and SMA Spectra with Revised Natural Frequency/Stiffness for Valves 1-RC-PCV-1455C and 1-RC-PCV-1456, Rev. 0

NA-CALC-STR-CD-1436, Seismic Qualification of Pressure Control Valves for USI A-46 and IPEEE, Rev. 0

NA-CALC-ZZZ-12050-DC-38-001, SW Pump House, SW Pumps, Screen Wash Pump Anchorage, Rev. 0

NA-CALC-ZZZ-ME-0290, Evaluation of air entrainment into RWST LHSI suction nozzles, Rev. 0

Add. B

NA-CALC-ZZZ-ME-0290, NPSHA to Charging Pumps, Rev. 0

Attachment

NA-CALC-ZZZ-ME-0290, Revised NPSHA Calculation per

DCP 90-13 & 93-011, Rev. 0, Add. A

NA-CALC-ZZZ-ME-062, SW Reservoir Performance Analysis, Rev. 0

NAN2-34325-AR-001, Hydraulic Performance of Replacement Containment Sump Strainers North Anna 2 Power Station, Rev. 0 Add 0

NAN2-34325-TR-001, Reduced-Scale Testing for North Anna 1 and 2 Replacement Sump Strainers, Att. 1, Rev. 2

NAN2-34325-TR-003, Rig 89 Multi-loop Chemical Effects Testing for Replacement Containment Sump Strainers- Complete Report for North Anna Units 1 & 2, Rev. 1 N-CALC-000-ME-3051, JOG Calculation of Required Thrust Settings for MOV 1-RC-MOV-1536, Rev. 1

SM-1513, North Anna GOTHIC Analysis of NPSH Available for LHSI and RS Pumps, Rev. 1, Add. 0

SM-1513, North Anna GOTHIC Analysis of NPSH Available for LHSI and RS Pumps, Rev. 1, Add. B

SM-1513, North Anna GOTHIC Analysis of NPSH Available for the LHSI and RS Pumps, Rev. 1

SM-1516, North Anna MSLB Containment Response with GOTHIC, Rev. 0

SUR2-34325-AR-003, Hydraulic Performance of the Partial Installation Replacement Containment Sump Strainers, Rev. 1

Drawings

1101156-11715-FE-1A, Main One Line Diagram North Anna Power Station Units 1&2, Rev. 0

11715/12050/6.43-37A, 3" Forged Bolted Bonnet Motor Operated Gate Valve (Velan), Rev. A

11715-1.16-204A, Klockner Moeller Tripping Characteristics for Field Testing Type Z2 Overload Relays, 3/3/75

11715-1.16-205A, Klockner Moeller Tripping Characteristics for Field Testing Type Z4 Overload Relays, 3/3/75

11715-12050-7.83-20, Control Valve 20,000 Series, Rev. D

11715-2.45-14A, Johnston Pump Performance Curve (Screen Wash Pumps), Rev. 0

11715-ECI-105QA, SW Lines SW Pump House, Units 1 and 2, Rev. 1 11715-ESK-11D, Elementary Diagram Loss of Reserve Station Power Sheet 1 North Anna Power Station - Unit 1, Rev. 9 11715-ESK-11E, Elementary Diagram Loss of Reserve Station Power Sheet 2 North Anna Power Station - Unit 1, Rev. 9 11715-ESK-11P, Elementary Diagram Loss of Reserve Station Power Sheet 3 North Anna Power Station - Unit 1, Rev. 3 11715-ESK-3A, Control Switch Contact Diagram Sheet 1 North Anna Power Station Virginia Electric & Power Co., Rev. 5 11715-ESK-3E, Control Switch Contact Diagram Sheet 5 North Anna Power Station Virginia Electric & Power Co., Rev. 10 11715-ESK-3N, Control Switch Contact Diagrams Sheet 13 North Anna Power Station Unit No. 1 Virginia Electric and Power Company, Rev. 8 11715-ESK-5AA, Elementary Diagram - 4160V Ckts Auxiliary Steam Generator Feedwater Pump 1-FW-P-3A North Anna Power Station - Unit 1, Rev. 22 11715-ESK-5AW, Elementary Diagram 4160V Ckts Recirculation Spray Pump (Outside Cont.) 1-RS-P-2A North Anna Power Station - Unit 1, Rev. 24 11715-ESK-5AX, Elementary Diagram 4160V Ckts Recirculation Spray Pump (Outside Cont.) 1-RS-P-2B North Anna Power Station - Unit 1, Rev. 20 11715-ESK-6S, Elementary Diagram - 480V Ckts Recirc Spray Pump (Inside Cont) 1-RS-P-1A North Anna Power Station - Unit 1, Rev. 23

Attachment 11715-ESK-6T, Elementary Diagram - 480V Ckts Recirc Spray Pump (Inside Cont) 1-RS-P-1B North Anna Power Station - Unit 1, Rev. 21 11715-FB-24L, Ventilation and Air Conditioning Service Building (Sheet 1), Rev. 16 11715-FE-1AF, 480V One Line Diagram Emergency Busses 1H, 1H1, 1J, &1J1 North Anna Power Station, Rev.15 11715-FE-1BB, One Line Diagram Electrical Distribution System North Anna Power Station Units 1 & 2, Rev. 44 11715-FE-1BG, One Line Diagram Electrical Distribution System, Station Blackout System North Anna Power Station, Rev. 2 11715-FE-1C, 4160V One Line Diagram - Sh. 2 Bus 1C Intake Structure Bus 1G and Transfer Bus F North Anna Power Station, Rev. 25 11715-FE-1D, 4160V One Line Diagram - Sh. 3 Emergency Bus 1H and 1J , Rev. 20 11715-FE-1E, 125 VDC One Line Diagram North Anna Power Station, Rev. 29

11715-FE-1E, 125 VDC One Line Diagram North Anna Power Station, Rev. 30 11715-FE-21AV, Elementary Diagram 4160V Breaker 0-AAC-BKR-05L2 Bus 0L to Bus 0M Tie Station Blackout System North Anna Power Station, Rev. 1 11715-FE-21BA, Elementary Diagram 4160V Breaker 0-AAC-BKR-05M1 AAC Output Breaker Station Blackout System North Anna Power Station, Rev. 1 11715-FE-21BB, Elementary Diagram 4160V Breaker 0-AAC-BKR-05M2 Bus 0M to Bus F Tie Breaker Station Blackout System North Anna Power Station, Rev. 3 11715-FE-21BF, Elementary Diagram 4160V Bus 0M Protective Relaying Station Blackout System North Anna Power Station, Rev. 8 11715-FE-21BL, Elementary Diagram AAC System Synchronizing Station Blackout System North Anna Power Station, Rev. 1 11715-FE-21BN, Elementary Diagram Breaker 0-AAC-BKR-15F5 Bus to 0M to Transfer Bus F Tie Breaker Station Blackout North Anna Power Station, Rev. 2 11715-FE-21BP, Elementary Diagram F Transfer Bus Station Blackout System North Anna Power Station, Rev. 0 11715-FE-21K, D.C. Elementary Diagram 4160V Bus 3 Bkr 15D1, Bus E Bkr 15E1, Bus F Bkr 15F1, and Bus 1G Bkr 15G10 North Anna Power Station - Unit 1, Rev. 23 11715-FE-21L, D.C. Diag 4160V Norm Buses A,B,C & Transf Buses D, E, & F Undervoltage North Anna Power Station - Unit 1, Rev. 18 11715-FE-21M-24, DC Elementary Diagram 4160V Normal Supply Buses Bkr 15D3, 15E3, 15F3, and 15F4, Rev. 21 11715-FE-21N, D.C. Elementary Diagram Reserve Station Service Pilot Wire Relaying North Anna Power Station - Units 1 & 2, Rev. 9 11715-FE-21P, D.C. Elementary Diagram Reserve Station Service Transformer Protection North Anna Power Station Units 1 & 2, Rev. 9 11715-FM-074A, Feedwater System (Sheet 1 and 3), Rev. 53 and 43 11715-FM-078A, Flow/Valve Operating Numbers Diagram Service Water System Unit 1, Sheet of 5, Rev. 38 11715-FM-078A, Service Water System North Anna Power Station Units 1 & 2, Sheet 1 of 5, Rev. 64 11715-FM-079B, Flow/Valve Operating Numbers Diagram Component Cooling Water System North Anna Power Station Unit 1 Virginia Power, Sheet 2 of 5, Rev. 26 11715-FM-079B, Flow/Valve Operating Numbers Diagram Component Cooling Water System North Anna Power Station Unit 1 Virginia Power, Sheet 3 of 5, Rev. 27 11715-FM-079B, Flow/Valve Operating Numbers Diagram Component Cooling Water System North Anna Power Station Unit 1 Virginia Power, Sheet 4 of 5, Rev. 29

Attachment 11715-FM-082A, Compressed Air System (Sheet 1), Rev. 16 11715-FM-091A, Containment Quench and Recirculation Spray Subsystem (Sheet 1-4), Rev.

11715-FM-091A, Flow/Valve Operating Numbers Diagr am Cont Quench & Recirc Spray Sub Sys North Anna Power Station Unit 1 Virginia Power, Sheet 3 of 4, Rev. 27 11715-FM-093B, Flow/Valve Operating Diagram for RCS, Unit 1, Sheet 1 of 3, Rev. 27

11715-FM-103B, Auxiliary Boiler System (Sheet 1), Rev. 1

11715-FM-103D, Fuel Oil - Station Blackout (Sheet 1), Rev. 2

11715-FM-113A, Starting Air - Station Blackout (Sheet 1), Rev. 10 11715-FM-113C, Cooling Water - Station Blackout (Sheet 1), Rev. 1 11715-FM-86D, Fuel Oil - Station Blackout Building (Sheet 1), Rev. 0

11715-FP-4D, Containment RS and LHSI pump piping SH 3 - North Anna, Rev. 17

11715-LSK-27-12F, Cont Depressurization Actuation and Reset Train B, Rev. 6

11715-LSK-27-12G, Containment Depressurization Actuated Devices, Rev. 8 11715-PSSK-105QA.12, SW Lines SW Pump House, Rev. 1

2050-1.16-153B, Klockner Moeller Motor Control Center 2J1-1A Layout , Rev. 1

2050-1.16-155A, Klockner Moeller Motor Control Center 2J1-2S Layout Sh. 1, Rev. 3

2050-1.16-156A, Klockner Moeller Motor Control Center 2J1-2S Layout Sh. 2, Rev. 3 12050-1.16-78A, Klockner Moeller Motor Control Center 2J1-3 Layout Sh. 1, Rev. 1 12050-ESK-11R-1, Elementary Diagram Emergency Bus "2J" Undervoltage Circuit Testing North Anna Power Station - Unit 2, Rev. 9 12050-ESK-5AL, Elementary Diagram - 4160V Ckts Charging Pump 2-CH-P-1A North Anna Power Station - Unit 2, Rev. 19 12050-ESK-5AN, Elementary Diagram - 4160V Ckts Charging Pump 2-CH-P-1C Sheet 1 North Anna Power Station - Unit 2, Rev. 21 12050-ESK-5AY, Elementary Diagram - 4160V Ckts Low Head Safety Injection Pump 2-SI-P-1A North Anna Power Station - Unit 2, Rev. 7 12050-FE-1A, Main One Line Diagram North Anna Power Station - Unit 2, Rev. 22

2050-FE-1AF, 480V One Line Diagram Emergency Busses 2H, 2H1, 2J, & 2J1, Rev. 11

2050-FE-1D, 4160V One Line Diagram - Sh. 3 Emergency Bus 2H & 2J, Rev. 11 12050-FE-1E, 125 VDC Oneline Diagram North Anna Power Station - Unit 2, Rev. 28 12050-FE-1N, 480V One Line Diagram Emergency MCC 2H1-2N & S Cable Tunnel, Rev. 41

2050-FE-1P, 480V One Line Diagram Emergency MCC2J1-2 Cable Tunnel, Rev. 39

2050-FE-1Q, 480V One Line Diagram Emer MCC 2H1-1, 2H1-4, & 2J1-1 Emer

Swgr

Rm, Rev. 27 12050-FE-1R, 480V One Line Diagram, Emer MCC2H1-3, 2J1-3 Ser WPP Hse & Emer MCC2H1-1A & 2J1-1A Gen Rms 2H & 2J, Rev. 24 12050-FE-21A, A.C. Elementary Diagram Generator and Mn. Transformers, Rev. 26

2050-FE-21E, 4160V Elementary Diagram Emergency Buses 2H &2J Emer Generators 2H &

2J Swgr Met & Rel , Rev. 0 12050-FE-21G, DC Elementary Diagram 4160V - Bus 2A, Bkrs 25A1 & 25A2 Bus 2B, Bkrs 25B1 & 25B2, Rev. 20 12050-FE-21T , D.C. Elementary Diag. 4160V Emer. Bus "2H" & Intake Structure Bus "2G" Undervoltage, Rev. 25 12050-FE-21U, DC Elementary Diagram 4160V Emer Bus "2J" Undervoltage, Rev. 22

2050-FE-ESK-5AL, Elementary Diagram - 4160V CKTS Charging Pump 2-CH-P-1A, Rev. 19

2050-FE-ESK-5AM, Elementary Diagram - 4160V CKTS Charging Pump 2-CH-P-1B, Rev. 11 12050-FE-ESK-5AN, Elementary Diagram - 4160V CKTS Charging Pump 2-CH-P-1C, Rev. 21 12050-FE-ESK-5AY, Elementary Diagram - 4160V CKTS Low Head Safety Injection Pump 2-SI-P-1A, Rev. 7

Attachment 12050-FE-ESK-5AZ, Elementary Diagram - 4160V CKTS Low Head Safety Injection Pump 2-SI-P-1B, Rev. 6 12050-FM-095B, Chemical and Volume Control System North Anna, Unit 2, Sheet 2/2, Rev. 47 12050-FM-096A, Diagram Safety Injection System, Unit 2, Rev. 35 12050-FM-107B, Emergency Diesel Lube Oil System (Sheet 1), Rev. 4

2050-FM-107C, Emergency Diesel Coolant System (Sheet 1), Rev. 4

8Q-8411, Schematic - Coolant - Virginia Electric Power Co, Rev. 5

8Q-8413, Schematic - Fuel - Virginia Electric Power Co, Rev. 6

8Q-8414, Schematic - Compressed Air - Virginia Electric Power Co, Rev. 7 B-19049, Min Flow Orifice Assembly (for recirc), Rev. 0

F-25-2APK86X1-K, General Arrangement (LHSI Pump), Rev. 11

H-4254, Screen Wash Pump, Rev. D

J-286-N, Assembly (HHSI Pump), Rev. 1

Procedures

NA-PROC59-000-1-OP-49.5, Service Water Air System, Rev. 4 0-AP-10, Loss of Electrical Power, Rev. 58 0-AP-10, Loss of Electrical Power, Rev. 73 0-ECM-0302-03, Closing Coil Testing for Medium Voltage Switchgear Breakers (ITE 5HK250), Rev. 5 0-ECM-0307-01, Replacement of Thermal Overload Devices, Rev. 28 0-ECM-1414-01, PdMA Offline Testing of Low Voltage Motors, Rev. 2 0-ECM-1414-02, PdMA Offline Testing of Medium (Between 1kv and 5kv) Voltage Motors, Rev.

0-ECM-1414-04, PdMA Online Testing of Medium (Between 1kV and 5kV) Voltage Motors, Rev.

0-EPM-0302-03, BBC/ITE 4160-Volt Type 5HK Breaker 9-Year Inspection, Rev. 32 0-EPM-0304-01, Testing/replacing 480-Volt Breaker Assemblies, Rev. 69 0-EPM-0307-01, Testing of Thermal Overloads, Rev. 29

0-EPM-2401-01, 4160/480 VAC Transformer Inspection, Rev. 8

0-GOP-223, Performance Verification of SWPH Instrument Air System, Rev. 0

0-GOP-4, EDG Cold Weather Operations, Rev. 53 0-GOP-4.2, Extreme Cold Weather Operations, Rev. 34 0-GOP-5.5, EDG Hot Weather Operations, Rev. 12 0-MOP-6.94, 0-AAC-DG-0M, Alternate AC Diesel Generator (SBO Diesel), Rev. 30 0-OP-26.9, 4160-Volt Breaker Operation, Rev. 21 0-OP-49.9, Use of 1-FP-P-2 To Wash Service Water Screens, Rev. 0 0-OP-49.9, Use of 1-FP-P-2 To Wash Service Water Screens, Rev. 1

0-OP-6.3, Operation of the SBO Diesel (Non-SBO Event) on F Transfer Bus, Rev. 21

0-OP-6.4, Operation of the SBO Diesel (SBO Event), Rev. 16 0-PT-82.11, Quarterly Test of 0-AAC-DG-0M, Alternate AC Diesel Generator (SBO Diesel), on D Transfer Bus, Rev. 24 0-PT-82.11, Quarterly Test of 0-AAC-DG-OM, Alternate AC Diesel Generator (SBO Diesel), on D Transfer Bus, Rev. 15

0-PT-82.12, Quarterly Test of 0-AAC-DG-OM, Alternate AC Diesel Generator (SBO Diesel), on E Transfer Bus, Rev. 24 0-PT-82.13, Quarterly Test of 0-AAC-DG-OM, Alternate AC Diesel Generator (SBO Diesel), on

F Transfer Bus, Rev. 23 1-AR-C-C4, RCP 1A-B-C Therm Barr CC Hi/Lo Flow, Rev. 1

1-AR-C-D4, RCP 1A-B-C Therm Barr CC Hi Temp, Rev. 1

Attachment 1-AR-C-G6, RCP 1A-B-C Labyth Seal Lo Flow, Rev. 4 1-AR-C-G7, RCP 1A-B-C Seal Leak Hi Flow, Rev. 2

1-AR-H-A3, Vital Bus 1-III Inverter Trouble, Rev. 3 1-AR-H-B3, Battery Chgr. 1-III Trouble, Rev. 4;

1-AR-H-H7, 4kv Xfer Bus 1F UV, Rev. 1

1-AR-H-H8, 4KV Bus 1G UV, Rev. 2;

1-AR-J-A2, RWST LO Level, Rev. 0

1-AR-K-G5, SW PP HSE Air Compressor Trouble, Rev. 2

1-E-2, Faulted Steam Generator Isolation, Rev. 12 1-E-3, Steam Generator Tube Rupture, Rev. 26 1-ECA-0.0, Loss of All AC Power, Rev. 25

1-ECA-0.1, Loss of All AC Power Recovery Without SI Required, Rev. 16

1-ECA-0.2, Loss of All AC Power Recovery With SI Required, Rev. 15

1-ES-1.1, SI Termination, Rev. 21

1-ES-1.2, Post-LOCA Cooldown and Depressurization, Rev. 20 1-FPMP-2.7, Loss Prevention Fire Protection Maintenance Attachment 1, Fire Protection

1-ICP-RC-P-1444, Pressurizer Pressure Control (1-RC-P-1444), Rev. 18

1-LOG-4, Unit 1 Control Board (Modes 1-4), Rev. 98

1-MOP-5.01, Removal and Return to Service of "A" Reactor Coolant Pump and Associated CC

Lines, Rev. 20 1-MOP-5.02, Removal and Return to Service of "B" Reactor Coolant Pump and Associated CC

Lines, Rev. 18 1-MOP-5.03, Removal and Return to Service of "C" Reactor Coolant Pump and Associated CC

Lines, Rev. 19 1-OP-1A, Pre-Start-Up Checkoff List, Rev. 19 1-OP-26.1, Transferring 4160-Volt Busses, Rev. 25 1-OP-26A, Breaker Checklist, Rev. 58

1-OP-49.2, Service Water Traveling Water Screens and Wash Pumps, Unit 1, Rev. 19

1-OP-5.2, Reactor Coolant Pump Startup and Shutdown, Rev. 39

1-OP-51.1, Component Cooling System, Rev. 30 1-OP-7.10, Operation of Casing Cooling Subsystem of the Recirc Spray System, Rev. 33 1-OP-7.6A, Valve Check-off, Inside Recirc Spray, Rev. 5

1-OP-8.1, Chemical and Volume Control System, Rev. 53

1-PT-160, RCS Cycle/Transient Log Review, Unit 1, Rev. 9

1-PT-210.20, Valve Inservice Performance Test for Seat Tightness 1-RC-PCV-1455C and 1-RC-PCV-1456, Rev. 5 1-PT-211.3, Valve In-service Inspection for 1-QS-11, 1-QS-19, 1-RS-18, and 1-RS-27, Rev. 8

1-PT-212.14, Valve In-service Inspection (Backup Air Supply for AFW Valves), Rev. 11

1-PT-212.15, Valve In-service Inspection, Rev. 9-P1

1-PT-36.40, Response-Time Test of RWST Level < 60% Function, Rev. 1

1-PT-48, Visual Inspection of Reactor Coolant Pressure Boundary Components, Rev. 20 1-PT-64.1.1, Outside Recirculation Spray Pump 1-RS-P-2A, Rev. 27 1-PT-64.8, Flow Test of the Inside Recirculation Spray Pumps, Rev. 29

1-PT-66.1, Weight Loaded Check Valves, Rev. 17

1-PT-66.3, Containment Depressurization Actuation Operational Test, Rev. 46

1-PT-66.3, Containment Depressurization Actuation Operational Test, Rev. 47

1-PT-75.4, Service Water Screen Wash Pump (1-SW-P-2), Rev. 13 1-PT-87.1H, Station Battery 1-I Service Test, Rev. 14 1-PT-88.1H, Station Battery 1-I Modified Performance Test, Rev. 12

2-AP-17, Shutdown LOCA, Rev. 22

2-AP-49, Loss of Normal Charging, Rev. 16

Attachment 2-AR-16, Emergency Diesel 2H - Local, Rev. 23 2-AR-B-B7, CH PP 1A Gearbox Cooler Inlet Lo Flow, Rev. 2

2-AR-B-C8, CH PP 1B Gearbox Cooler Inlet Lo Flow, Rev. 2 2-AR-B-E8, CH PP 1C Gearbox Cooler Inlet Lo Flow, Rev. 2 2-AR-C-B6,

CH-P-1A-B-C Lube Oil Hi Temp, Rev. 1

2-AR-F-F5, AAC System Trouble, Rev. 4;

2-AR-F-F6, AAC Diesel Generator Trip, Rev. 4,

2-AR-F-G5, AAC Diesel Generator Running, Rev. 1

2-AR-H-G1, 2-EI-CB-21H Annunciator G1, Rev. 1 2-E-0, Reactor Trip or Safety Injection, Rev. 47 2-E-1, Loss of Reactor or Secondary Coolant, Rev. 23

2-FPMP-2.1, Attachment 1, Fire Protection Equipment Data Sheet, Rev. 6

2-LOG-6F, Unit 2 Safeguards Log, Rev. 111

2-OP-6.1A, Valve Check-off - 2H Diesel Engine Cooling Water, Rev. 8 2-OP-7.1A, Valve Check-off, Low head, Rev. 17 2-PT-138.1, HHSI Flow Balance, Rev. 14

2-PT-57.4, Safety Injection Operational Test, Rev. 55

2-PT-66.1, Weight Loaded Check Valves, Rev. 16

2-PT-66.3, Containment Depressurization Actuation Operational Test, Rev. 44 2-PT-83.1, Simulated Loss of Offsite Power (LOOP) and ESF Actuation - H Bus, Rev.60 2-PT-83.2, Simulated Loss of Offsite Power (LOOP) and ESF Actuation - J Bus, Rev. 60

2-PT-83.4.1, Degraded Voltage/Loss of Voltage and CDA Operational Test of CRDM Fans, Rev. 6

CHAP-0105, Auxiliary Cooling Water System Chemistry Control Program (North Anna), Rev. 14 1-E-2, Faulted Steam Generator Isolation, Rev. 12

ER-AA-IST-100, ASME IST Program - General Requirements, Rev. 1

ER-AA-IST-103, ASME IST Program - Inservice Testing of Pressure Relief Devices, Rev. 1

MMP-C-RC-1, Disassembly, Inspection, Repair and Re-assembly of Reactor Coolant Pump, Rev. 17

PI-AA-100-1007, Operating Experience Program, Rev. 9

Completed Procedures

0-PT-82.12, Quarterly Test of 0-AAC-DG-OM, Alternate AC Diesel Generator (SBO Diesel), on E Transfer Bus, 1/26/2012 0-PT-82.12, Quarterly Test of 0-AAC-DG-OM, Alternate AC Diesel Generator (SBO Diesel), on F Transfer Bus, 11/23/2011 1-LOG-12, Emergency Diesel Generator LOG (Operating), 1/6/2012, 1/31/12, 3/1/2012 1-PT-212.10, Valve Inservice Inspection (1-RC-PCV-1456), Rev 17, completed 9/12/11

1-PT-212.11, Valve Inservice Inspection (1-RC-PCV-1455C), Rev 17, completed 9/12/11 1-PT-212.29, Valve Inservice Inspection (1-RC-PCV-1455C) NDT Protection Response Time Test, Rev 9, completed 8/24/11 1-PT-212.30, Valve Inservice Inspection (1-RC-PCV-1456) NDT Protection Response Time Test, Rev 9, completed 8/24/11

1-PT-215.7, Valve Inservice Inspection (Leak Test of N2 to PORV Reserve Tank Check Valves and Exercise of PORV with Reserve Tank), Rev. 7, completed 4/18/12

1-PT-64.1.1, Outside Recirculation Spray Pump 1-RS-P-2A, 3/26/09, 10/6/10, 9/11/11, 3/30/12

1-PT-64.1.2, Outside Recirculation Spray Pump 1-RS-P-2B, 3/26/09, 10/6/10, 9/11/11, 3/30/12 1-PT-64.8, Flow Test of the Inside Recirculation Spray Pumps, 10/04/2010 - 10/09/2010 1-PT-64.8, Flow Test of the Inside Recirculation Spray Pumps, 3/24/2009 - 3/28/2009

1-PT-66.1, Weight Loaded Check Valves, 4/23/12

1-PT-71.2Q, 1-FW-P-3A, 'A' Motor-driven AFW Pump and Valve Test, 9/22/11, 4/24/12

Attachment 1-PT-71.2Q.1, 1-FW-P-3A, A Motor-driven AFW Pump IST Comprehensive Pump Test and Valve Testing, 1/12/12 1-PT-71.3Q, 1-FW-P-3B, 'B' Motor-driven AFW Pump and Valve Test, 10/27/11, 1/24/12, 4/24/12 2-PT-138, Valve Inservice Inspection LHSI System Functional Verification, Unit 2, Rev. 36, completed 4/15/10 2-PT-138, Valve Inservice Inspection LHSI System Functional Verification, Unit 2, Rev. 36, completed 10/9/11 2-PT-138.1, HHSI Flow Balance, 5/25/2006 2-PT-138.1, HHSI Flow Balance, 9/28/2005 2-PT-138.3A, Combined Charging Pump "1A" Head Curve Verification and HHSI Branch Flow Verification, Unit 2, Rev. 12, completed10/2/08.

2-PT-14.1, Charging Pump 2-CH-P-1A, Unit 2, Rev. 48, completed 1/12/12

2-PT-14.1, Charging Pump 2-CH-P-1A, Unit 2, Rev. 48, completed 4/3/12 2-PT-57.1A,

ECCS-LHSI Pump (2-SI-P-1A), Unit 2, Rev 60, completed 9/5/11 2-PT-57.1A,

ECCS-LHSI Pump (2-SI-P-1A), Unit 2, Rev 60, completed 10/29/11

2-PT-57.1A,

ECCS-LHSI Pump (2-SI-P-1A), Unit 2, Rev 60, completed 2/2/12

2-PT-57.1B,

ECCS-LHSI Pump (2-SI-P-1B), Unit 2, Rev 59, completed 11/10/11

2-PT-57.1B,

ECCS-LHSI Pump (2-SI-P-1B), Unit 2, Rev 59, completed 12/14/11 2-PT-57.1B,

ECCS-LHSI Pump (2-SI-P-1B), Unit 2, Rev 59, completed 2/16/12 2-PT-82H, 2H Emergency Diesel Generator Slow Start Test, 1/6/2012, 1/31/12, 3/1/2012

Completed Work Orders

00431229-01, Repair/Replace O-Ring for 00-BFO-FL-1A

00770063-01, 0-PT-82.20, AAC Diesel Battery Capacity Test

00788686 01, 2-RC-P-1A Thermal Barrier CC Outlet Header Flow XMTR

008022359, Offline Testing of Large Motors 4160V

00802359-05, 02-CH-P-1A-MOTOR Offline Testing of Large Motors 4160V

0080235916, Offline Testing of Large Motors 4160V

35317101, 6 month PM to inspect 1A SW air compressor and after cooler 59080104501, PORV AOV Diaphragm Replacement

59080112201, 01-RS-P-2B-Motor

59101606819, IPM/01-CC-F-116A (Cal Flow Loop)

59101606826, IPM/01-CC-F-116C (Cal Flow Loop)

59101606832, IPM/3REF/02-CC-F-216B (Calibrate Flow Loop)

59101651640, Offline Testing of Large Motors 4160V 59101651652, Offline Testing of Large Motors 4160V 59101700971, 02-CH-P-1A-MOTOR Offline Testing of Large Motors 4160V

59101746142, 02-EP-

BKR-25B1-CKTBRK Test Bus Fast Transfer Time

59101897372, Replace air regulator on 01 -FW-PCV-159B valve positioner

59101902984, 01-RS-P-1B-Motor

59101902992, 01-RS-P-1A-Motor 59101903578, Response-Time Test of RWST Level < 60% Function,

59101954630, 02-EP-BKR-25B1-CKTBRK Perform 9 Year PM

59101955222, Functional Test and Replace Vacuum Breaker

59101970135, 01-RS-P-2A-Motor

59102037252, 02-CH-P-1B-MOTOR Offline Testing of Large Motors 4160V 59102169961, inspection and repair of strainer 1-SW-S-3

59102197202, 01-RS-P-1A-Motor

59102200653, 01-RS-P-2B-Motor

59102200657, 01-RS-P-2A-Motor Attachment

59102202153, 01-RS-P-1B-Motor 59102224154, Response-Time Test of RWST Level < 60% Function

59102247478, 02-EP-BKR-25B1-CKTBRK Relay Testing

PM 59102272107, 02-CH-P-1B-MOTOR Offline Testing of Large Motors 4160V

59102294141, 01-RS-P-2B-Motor

59102294151, 01-RS-P-2A-Motor

59102356010, PORV 01-RC-PCV-1456 Failed Stroke Time 1-PT-212.10

59102365608, 02-CH-P-1B-MOTOR Online PdMA Test for DC

NA-09-00101

59102365619, Offline Testing of Large Motors 4160V 59102365736, Work Order to Online PdMA Test 2-SI-P-1A for DC

NA-09-00101 59102365736, Offline Testing of Large Motors 4160V

59102365771, 02-CH-P-1A-MOTOR Online PdMA Test for DC

NA-09-00101

Corrective Action Documents

CA135042, Possible degrading trend noted in Unit 1 IRS pump performance CA153045, MOV Analysis Guideline revised to verify uncorrected thrust setpoints prior to Test Plan creation CA153512, Evaluation determined no changes were required

CA179104, CA to Engineering to develop and implement a long term repair plan CA215573, (due 20 days) to evaluate past operability for issues associated with CA227677, CA to Engineering to perform an in depth reviews of these TOL relays

CR 358933,

GL 89-10 calculation methodology with respect to applying a locked rotor amp (LRA) derate in the MOV sizing calculation requires review

CR 363999, 2-CH-P-1A flow rate near reference value during 2-PT-14.

CR 387916, PORV 1456 failed to open with keyswitch in open

CR 442482, PORV 1-RC-PCV-1456 failed stroke time test in 1-PT-212.10

CR 442850, PORV 1-RC-PCV-1456 failed stroke time test in 1-PT-212.10

CR 448838, 2-CH-P-1A flow characteristics different than reference values during 2-PT-14

CR 466757, Air leak on air receiver drain valve 1-SW-344.

CR323470, Programmatic WR to Eddy Current test Unit 1 diesel coolers

CR328709, PORV 1-RC-PCV-1455C went closed with the control switch in "OPEN".

CR328950, 1-FW-PCV-159B sluggish

CR332781, A possible degrading trend noted in Unit 1 IRS pump performance

CR340382, oil needs to be added to 2-CH-P-1B speed increaser

CR345142, Oil low in 2-CH-P-1B motor bearing

CR346436, broken shear pin in 1/2 -SW-S-3 strainer motor

CR350468, 1-RS-P-2B Lower motor reservoir oil appears to be slightly red

CR351665, 1-RS-P-2B has higher than normal particle count

CR358489, NRC identified lack of formal control for MOV Program data verification

CR358801, Diesel Room Ambient Temperature monitor, 11/19/2009

CR361933, Installation problem report for

DCP 07-131

CR362011, Sample Oil on IB and OB Bearing for 2-CH-P-1B

CR362700, no indication of 1-SW-S-3 and 2-SW-S-3 rotation

CR363393, 2-ch-p-1b outboard motor bearing oil level at minimum

CR371775, 2-CH-P-1B outboard motor bearing needs oil addition

CR376581, 2-SI-MOV-2867A did not open during 2-PT-138C

CR378627, 2-CH-P-1B, OB motor low motor oil level

CR378748, 2-CH-P-1B outboard bearing oil leak

CR380383, 2-CH-P-1B outboard motor requires oil addition

CR384505, 2-CH-P-1B outboard motor oil level at minimum

CR385641, U-2 'B' charging pump needs oil Attachment

CR386192, Disconnect and raise 1-RS-P-1A & B to support Containment liner plug inspection

CR386345, 2-CH-P-1B Speed Increaser oil level at 1/4% of level indicator

CR393611, 2-CH-P-1B motor bearing needs oil added

CR395346, 1-RS-P-1A&B Pump can vertical joints bolts showing signs of corrosion

CR395475, 2-CH-P-1B, 'B' Charging Pump outboard motor needs oil

CR396697, Document the creation of

DCU 10-816

CR396748, Bottom bolt missing on 01-RS-P-1A

CR396906, Bottom bolt missing on 1-RS-P-1B pump can

CR396925, Document the creation of

DCU 10-819

CR398151, 2-CH-P-1B outboard motor requires oil addition

CR399741, 2-CH-P-1B Outboard Motor needs oil

CR399923, 2-CH-P-1B speed increase needs oil

CR401922, A finding was issued for failure to have an adequate setpoint for 4160 UV relay

CR406832, 2-CH-P-1B's motor outboard level is at 1/4

CR408501, 2-CH-P-1B outboard motor bearing oil level is low

CR416963, 2-CH-P-1B Outboard motor bearing oil level is currently right at minimum spec

CR421935, Test data used to re-baseline U1 & U2 IRS Pumps IST limits may be incorrect

CR429091, 2-CH-P-1B outboard motor oil level low (slightly above 1/4)

CR429788, Outboard motor oil level low

CR431299, 2-CH-P-1B outboard motor bearing oil level

CR439210, 2J 4160 Volt relay drops

CR439440, Bus potential light not lit on 1H 480V Bus

CR439952, 2H EDG Jacket Cooling Temperature Low

CR441608, Minor Work Order for Unit 1 motor oil samples

CR441817, Reinstall RO for JCW pump 1-EG-P-7J

CR441818, Reinstall RO for JCW pump 2-EG-P-7J

CR442191, EP System Post Seismic Internal Inspections

CR443251, Post Seismic Inspections During 2J Dead Bus

CR445763, Bus potential light not lit on 1-EE-SS-04

CR447213, As-built U2 RS piping supports not in accordance with design documents

CR447397, Programmatic WR to rebuild 2H EDG coolant water pump 2-EG-P-7H

CR449417, Bus potential light not lit for 2H1 480V bus

CR449803, 2-CH-P-1B Motor outboard bearing oil level low

CR451475, 2-CH-P-1B Motor Outboard Oil Sightglass low level

CR453247, 2-CH-P-1B motor outboard bearing oil level low

CR454564, 2-CH-P-1B motor bearing needs oil

CR455557, Non-conservative NPSH required value used in calculation

SM-1513

CR456541, Outboard motor oil level is equal to a 1/4 in sightglass

CR457197, Need to add oil to 2-CH-P-1B O/B motor bearing

CR458373, U-2 'B' Charging pump outboard motor bearing needs oil

CR462402, SBO Diesel Generator expansion tanks TCVs are leaking by

CR463554, Parts found degraded on spare breaker, 2/21/12oned the assumption in thermal overload settings

CR463721, Surry's CDBI quest

CR465525, AFW Pressure Control Valve Posi tioner has Minor Instrument Air Leak

CR465702, Degraded part found during 9 year inspection

CR465795, 1-FW-PCV-159B has 3/8" fitting leak at tee on top of valve bonnet

CR466074, While performing 9 yr. P.M. on breaker UTC#5900118565 multiple parts degraded

CR466075, While performing 9 yr. P.M. on breaker UTC#5900118566 multiple parts degraded

CR466241, 2-CH-P-1B motor outboard bearing oil level is low

CR467246, While performing 9 yr. refurb multiple parts found degraded Attachment

CR468180, U2 'B' Charging Pump motor outboard bearing needs oil addition

CR468416, 1-PT-64.1.2 vibration data obtained on 1-RS-P-2B

CR468645, Boric Acid Accumulation on 2-SI-P-1A Shaft Seal

CR470235, 1J 4160 Bus Inspection noted several Load Side Disconnects Degraded

CR470344, 1H EDG Jacket Cooling temperature higher than other operable EDGs

CR470871, Degraded parts found degraded on spare breaker

OD 000283, Operability Assessment for

CR 330898

OD 000284, Operability Assessment for CR 330898

PI N-1998-2433_3, SW air, relief valve lifted starting both compressors and yielded an alarm PI N-2003-3416_2,1-SW-S-1B traveling screen breaker failed to close PI N-2005-2667_4, SW air compressors failed to start

PI N-2005-5469_6, SW air out of calibration pres switch Pl N-1998-2517_3, SW air compressor discharge relief valves improperly set

Modifications

DC 00-102, SW Pump House Instrument Air Compressor & Dryer Replacement/ NAPS/ Unit 1, Rev. 1, 6/18/03

DCP 02-147, Charging Pump Seal Upgrade/NAPS/Units 1 & 2, Rev. 0, 4/15/03

DCP- 92-012-3, Station Blackout Diesel Generator Tie-In to NAPS/Unit 1 and 2, 3/2/1994

DCP 99-142, Charging Pump Minimum Flow Recirc Orifice Replacement/NAPS/Units 1 & 2, Rev. 0, 3/20/2001

ET-NAF-07-0047, Changes to the NA Containment Analysis and LOCA Alternate Source Term Analyses for reduced RS pump flow rates, Rev. 0

ET-SE-99-023, Lowering the stand-by jacket coolant water temperatures, Rev. 1

NA-06-00119, Replace Unit Substation Transformers 2A1/2A2/2H & 2H1, 8/12/08

NA-10-00146, Replace Unit Substation Transformers 2J, 2J1, and 2C2, 3/8/11

Miscellaneous

0-BCW-R-1A: AAC Aftercooler/Oil Cooler Radiator -Specification Sheet (S/N 92B5111) 0-BCW-R-1B: AAC Jacket Water Radiator -Specification Sheet (S/N 92B5112) 0-BFO-CLR-1: AAC Fuel Oil Cooler - Specification Sheet (S/N 92C748) 0-GOP-5.8 Attachment 1 LCO

TR3.8.3. Tracking Log ID 12563.

2-NE012911-01, Curves for Pump 2-CH-P-1C, 12/6/99

59-1096-00003, Revised Pump Curves for Upgraded LHSI Pumps, Rev. 6

59-C112-00001, 3600 Series Engines, Rev. 16

59-F328-00001, Traveling Screen Outside Drive, Model 45A, Rev. 3 59-I145-00005, Indoor & Outdoor Dry & Cast Transformers 112 1/2 through 10/000 kVA, Rev. 3 59-J321-00005, Service Water Screen Wash Pumps, Rev. 4

59-K408-F0003, Z TOL's EMP Thermistor Tripping Units, Rev. 1

59-M747-00001, Masoneilan Spring-Diaphragm Actuator, Rev. 9

59-M747-00005, Masoneilan 20000 Series Control Valves, Rev. 5 59-P208-00001, Charging Safety Injection Pump, Rev. 25 59-W893-00002, Large AC Motors - Life-line D Horizontal Induction Motor, Frames 5000, 5800, 6800, Drip-off, Weather Protected Type I Sleeve or Rolling Bearings, Rev. 6 ASME OM Code, 2004 Edition

ASME OMb Code-2003 Code Cases, Code Case

OMN-8

CAP Search Report for 480V Unit Substations - last 3 years, 5/24/11 CAP Search Report for Unit Substation Transformers - last 3 years, 5/23/11 Cat DEACŽ (Diesel Engine Antifreeze Coolant) Concentract MSDS, Rev. 2

Certified Witness Test Performance Curves for NA Unit 2 LHSI Pumps, Ingersoll-Rand Test Curve Nos. N-472 and N-473

Attachment

CME 99-0020, Response to Surry

CTS-4551, Resolution of Inside Recirculation Spray Pump Reverse Flow Design Deficiency 1/2-RS-P-1A&1B, North Anna and Surry Power Stations, Rev. 0 Comprehensive Test D/P Trend Data for past 5 years for the LHSI pumps Email Y.K. Chervenski to J.B. McHale, For Comments -NAPS TOLs from CDBI, 6/15/12 ET

CEE 01-0013, INPO SOER 99-1 Review; Recommendation #4Review Overcurrent Trip Device Setpoints North Anna Power Station Unit 1 and 2, Rev. 0 ET N-03-0144, Curves for Pump 2-CH-P-1A, 12/19/02

ETE-CME-2012-0013, Evaluation of Velocity Required to Fully Open NAPS Check Valves 1-RS-18, 1-RS-27, 1-QS-11, 1-QS-19, 2-RS-20, 2-RS-30, 2-QS-11, and 2-QS-22 to support statements in

IOD 000175, Rev. 0

ET-N-00-039, Permanent change to allow lowering the stand-by jacket coolant water temperatures for 1-EE-EG-2H, 2J, Rev. 1

ET-N-06-0043, Evaluation of Emergency Diesel G

enerator Ambient Room Temperatures, Rev.

ET-N-07-0014, Evaluation for the use of Ultra-Low-Sulfur Diesel Fuel Associated with the North Anna Emergency Diesel Generators, Rev. 0

ET-N-08-0101, Evaluation of Penray Companies, Inc. Corrosion Inhibitor for use in the Station NS Emergency Diesel Generator Coolant Water System, Rev. 0

ET-SE-97-116, Revision of Outside Recirculation Pump PTs, Rev. 0

ET-SE-99-023, Lowering the stand-by jacket coolant water temperatures, Rev. 1

EWR 86-331, Is it necessary to put Glycol in Diesels during Winter, 10/27/1986

Fairbanks Morse Owners' Group Recommended Maintenance for Opposed Piston Diesel Engines in Nuclear Standby Service, 10-Year Maintenance Recommendations, Rev. 1

(August 19, 2005) GENERAL INSTRUMENT DATA for 00-BSA-PS-1-IBISSW, SBO Start Air Tank Pressure Switch, Rev. 0 GENERAL INSTRUMENT DATA for 00-BSA-PS-3-IBISSW, SBO Air Compressor Pressure Switch, Rev. 0 IEEE Standard 279-1971, Criteria for Protection Systems for Nuclear Power Generating Stations Information Notice 91-85, Potential Failures of Thermostatic Valves for Diesel Generator Jacket Cooling Water, Rev .1 Institute of Electrical and Electronic Engineers (IEEE) Standard 450, IEEE Recommended Practice for Maintenance, Testing, and Replacement of Large Lead Storage Batteries for Generating Stations and Substations, 1980 Instrumentation Setpoint Document:00-BFO-LS-2, Fuel Oil Transfer Pump 1-BLO-P-1 Control Switch Job Performance Measure Evaluation (N1667) Place the station blackout diesel generator in service to supply an emergency bus, 05/08/2012

Job Performance Measure Evaluation (N1671) Prepare the station blackout diesel generator for loading following an automatic start, 05/08/2012 Letter dated Apr 4, 1980, Confirmatory Order Letter

NAS-5475, Auxiliary Feedwater System, SWEC, May 1, 1973 License Document: 'Analysis and System Modification for Recirculation Spray Pumps Net Positive Suction Head', Docket Nos. 50-338/50-339, 9/16/1977 List of Preventative Maintenance: ORS Pumps 1-RS-2A/B

Maintenance Rule Function

AAC-1: Blackout Diesel Maintenance Rule Function ID RS001, Recirculation Spray References, 5/19/2006 (Last Modified Date)

Attachment Maintenance Rule Function ID RS002, The RS System maintains containment pressure at values less than its design pressure, 2/28/2012 (Last Modified Date)

Maintenance Rule Function ID RS003, The RS System minimizes containment leakage by rapidly cooling and de-pressurizing the containment to sub-atmospheric conditions and maintaining the containment at sub-atmospheric conditions, 12/11/2007 (Last Modified

Date) Maintenance Rule Function ID RS004, The RS System provides iodine-removal capability (by absorbing the airborne iodine and transferring it to the sump), 5/19/2006 (Last Modified

Date) Maintenance Rule Function ID RS005, The RS System provides containment isolation capability, 5/19/2006 (Last Modified Date)

Maintenance Rule Function ID RS006, The RS System removes heat via RSHX for long term core cooling, 12/11/2007 (Last Modified Date)

Maintenance Rule Function ID RS007, The RS System maintains system integrity outside containment to limit offsite dose

IAW 10CFR100 limits and onsite control room dose IAW

GDC-19, 5/19/2006 (Last Modified Date)

Maintenance Rule Function ID RS008, The RS System casing cooling system provides adequate NPSH to ORS pump, 5/19/2006 (Last Modified Date)

Maintenance Rule Function ID RS009, The RS System provides Reg. 1.97 instrumentation (SR only), 5/19/2006 (Last Modified Date)

Maintenance Rule Function ID RS010, The RS System provides the means to cool and maintain the temperature of the water in the casing cooling tank, 6/18/2008 (Last Modified Date)

Memorandum to Mr. J. R. Hayes, Evaluation of Cross-Connected SI Accumulators, North Anna Power Station Units 1 and 2, 5/15/1996

Module

NCRODP-38-NA, Reactor Coolant System, 12/14/2011 Module

NCRODP-51-NA, Component Cooling System, 04/04/2011

MRE014314, MRE: WO needed to shim 10"-RS-409-153A-Q2 at pipe support 2-RS-R-409.9 MRE014315, MRE: WO needed to shim 10"-RS-410-153A-Q2 at pipe support 2-RS-R-410.44 MRE014316, MRE: WO needed to adjust 4"-RS-415-153A-Q2 at pipe support 2-RS-R-415.61

MS 3.2.1.9-1D, Maintenance and Surveillance Medium-Voltage Switchgear Equipment, D N1PVI4,

NAPS-1ST-BAS

IS-INTERVAL 4

NA Letter 00-541, Virginia Electric and Power Company North Anna Power Station Units 1 & 2 Inoperable Station Blackout Diesel Generator Special Report NA Letter 88-414, Virginia Electric and Power Company Surry Power Station Units 1 and 2 North Anna Power Station Units 1 and 2 Response to 10

CFR 50.63: Loss of All Alternating Current Power NA Letter dated December 6, 1991, Station Blackout Rule/Proposed Diesel Generator Additions - North Anna Power Station, Units No. 1 and No. 2 (NA-1&2) (TAC Nos. M68572 and

M68573)

NAP-0048, Alternate AC Diesel Generator Sets North Anna Power Station, Rev.0

NAP-0048, AAC Specification, Appendix A, Rev. 0 NAPS Cognos System Health Reports for RS System, 1

st

QTR 2010 NAPS Cognos System Health Reports for RS System, 2

nd

QTR 2009 NAPS Cognos System Health Reports for RS System, 3

rd

QTR 2009 NAPS Cognos System Health Reports for RS System, 4

th

QTR 2009

NAPS Emergency diesel Generator Unavailability Hours (Computer Printout) NAPS SystemIQ Health Reports for RS System, 1

st

QTR 2011 NAPS SystemIQ Health Reports for RS System, 1

st

QTR 2012 NAPS SystemIQ Health Reports for RS System, 2

nd

QTR 2010 NAPS SystemIQ Health Reports for RS System, 2

nd

QTR 2011

Attachment NAPS SystemIQ Health Reports for RS System, 3

rd

QTR 2010 NAPS SystemIQ Health Reports for RS System, 4

th

QTR 2010 NAPS SystemIQ Health Reports for RS System, 4

th

QTR 2011 NAPS U1 Operations Narrative Log, Sunday, November 13, 2011.

NAPS UFSAR 15.4 Condition IV - Limiting Faults, Rev. 47.03

NAPS-IST-Basis-Interval 4: Test Requirement for 1-FW-PCV-159A&B

NAS-0044, Specification for RS Pumps for NAPS, Rev 4

NA-SPEC-000-NAS-0098, Service Water Pumps and Screen Wash Pumps, Rev. 3

NA-SPEC-000-NAS-0129, SW Traveling Water Screens, Rev. 3

NA-SPEC-000-NAS-0159, SW Traveling Water Screen Wash Strainers, Rev. 4

NCRODP-13-NA, Service Water System

NCRODP-18-NA, Basic Electrical Distribution

NCRODP-35-NA, Vital and Emergency Electrical Distribution System

NCRODP-41-NA, Chemical and Volume Control System

NCRODP-54-NA, Recirculation Spray System

NCRODP-55-NA, Station Diesel Generator Systems

NCRODP-55-NA, Station Diesel Generator Systems, 8/30/10

NE-GL-0014, Nuclear Engineering Guideline MOV Diagnostic Test Analysis, Rev. 10

North Anna's Regulatory Correspondence Distribution List for NRC Regulatory Issue Summary 2000-05: Resolution of Generic Safety Issue

165, Spring-Actuated Safety and Relief Valve Reliability, 3/21/2000 N-PMTE-2009-0134, PM evaluation for SBO

Expansion Tank Vacuum Breaker, 00-BCW-VACB-1 NRC Audit Report for North Anna Power Station, Report on Results of Staff Audit of Corrective Actions to Address Generic Letter 2004-02 (TAC Nos. MC4696, MC4697), 11/15/2007

NRC Letter to VEPCO, North Anna Nuclear Power Station Units 1 and 2 - Protection from Degraded Grid Conditions / Interaction of Offsite and Onsite Power Systems, 3/20/79 NRC Letter to VEPCO, Request for Additional Information, 6/25/80

NRC Letter to VEPCO, Request for Additional Information, 7/28/78

OE Evaluation Response - N-1997-4045-E1,

IN 91-85,R1: Potential failures of TCVs or Diesel Generator Jacket Cooling Water , February 27, 1997

OE Evaluation Response for IE Circular No. 80-11, Emergency Generator Diesel Failures, 8/8/1990 OE Evaluation Response for

IN 91-85, Rev 1, Potential Failures of Thermostatic Control Valves or Diesel Generator Jacket Cooling Water, 2/27/1997 OEE000706, OPEX002247:

IN 2009-10 Transform er Failures-Recent Operating Experience, 10/23/09 OPEX000134:

IN 06-22, New Ultra-Low-Sulfur Diesel Fuel Oil Could Adversely Impact Diesel Engine Performance, 11/2/2006 ORS Pump 1-RS-2A Differential Pressure Trend Data (Range: 10/07/03 - 3/30/12)

ORS Pump 1-RS-2B Differential Pressure Trend Data (Range: 3/26/02 - 3/30/12) Penray Product Bulletin for Pencool 3000 Cooling System Treatment (Part No's.

300016,

300064,

300005 & 300055) PM/Surveillance Overview Report, North Anna Power Station, 5/07/2012

PORV IST Evaluation and Basis, Excerpts from

NAPS-IST-BASIS-INTERVAL 4, p. 130

QDR-N-4.2/QDR-S-4.2, Review Package of Electrical Equipment for North Anna Power Station Units 1 & 2 and Surry Power Station Units 1 & 2 Quarterly Test D/P Trend Data for past 2 years for the LHSI pumps RE504803, Actuator Diaphragm Replacement

RE505510, Change oil in speed increaser 2-CH-P-1A

RE506268, Sample 2-CH-P-1A Motor Oil dated 6/4/12.

Attachment RE506269, Change oil in speed increaser 2-CH-P-1A RE507621, Upper Bearing Oil Sample for 2.SI-P-1B Pump Motor

RE507629, Upper Bearing Oil Sample for 2-SI-P-1A Pump Motor RE514019, 2 year PM to inspect and clean strainer RE518386, grease motor bearings on SW pump motor 1-SW-P-2

RE519993, Inspect/Refurbish Pressurizer PORV

RE520278, Perform SOV Replacement PM for 01-RC-SOV-1455C-1

RE521244, IPM/01-AOV Diagnostic Testing

RE522849, 9 year PM to replace actuator diaphragm 1-SW-TV-100A RE524586, MPM Replacement of AMOT Valve (10YR Frequency) RE96239, Sample 2-CH-P-1A High Speed

RTE ID: P-NANN-303582, Delete PMs that PTs Perform The Same Function

SDBD-NAPS-AFW, System Design Bases Document for the AFW System, Rev. 12

SDBD-NAPS-CC, System Design Basis Docu ment for Component Cooling Water System, North Anna Power Station, Rev. 12

SDBD-NAPS-CH, System Design Basis Document for Chemical and Volume Control - System, Rev. 10

SDBD-NAPS-CH, System Design Basis Docum ent for Chemical and Volume Control System, North Anna Power Station, Rev. 11

SDBD-NAPS-EG, Design Bases Document for EDG System, Rev .16

SDBD-NAPS-RC, System Design Basis Document for RCS, Rev. 12

SDBD-NAPS-RS, System Design Basis Document for Recirculation Spray System, North Anna Power Station, Rev. 16

SDBD-NAPS-SI, System Design Basis Document for Safety Injection System, Rev. 20

SDBD-NAPS-SW, Service Water System Design Basis Document, Rev. 15

STD-EEN-0011, Standard for Protective Device Settings, Rev. 7

SUR2-34325-AR-003, Hydraulic Performance of the Partial Installation Replacement Containment Sump Strainers, Rev. 1 SW System Health Report for period 4.2011

System Health Report - Auxiliary Feedwater System, Q1/2/4-2011, Q1-2012 System Health Report - Emergency Diesel Generators, Q1/2/3/4-2011, Q1-2012 System Health Report - Recirculation Spray System, Q4-2011, Q1-2012

System Health Report - SBO Diesel and Support Systems, Q4-2011, Q1-2012 Test Curve

TC-7613, NPSHr Test Data for Model 24QXC Pump (Service Water), Rev. 1, 11/17/95 Trend Data Sheet PORV 1-RC-PCV-1456 last 10 tests for 1-PT-212.10. Vendor Manual No. 59-B731-00001, Installation, Operation, Maintenance Instructions for Bingham Pump Types VCR/VTR, Rev. 6 Vendor Manual No. 59-W893-00044, Model W-11009-A1 Controlled Leakage Seal Reactor Coolant Pump, Rev. 9 Vendor Pump Curve, Ingersoll-Rand N-472 (for LHSI 2-SI-P-1A), 8/10/72 Vendor Pump Curve, Ingersoll-Rand N-473 (for LHSI 2-SI-P-1B), 8/10/72 VEPCO Letter to NRC, Compliance With Position 1, 10/24/18

VEPCO Letter to NRC, Request for Additional Information Electrical Distribution System Voltages North Anna Power Station - Unit 1, 8/20/80 VEPCO Letter to NRC, Response to Staff Positions on Degraded Electrical Grid Conditions, 1/12/79 Vibration History Report for 1-RS-P-2B (Range: 3/26/2009 - 3/30/2012)

VTM 59-B731-00001, Installation, Operation, Maintenance Instructions for Bingham Pump Types VCR/VTR, Rev. 6

VTM 59-C112-00001, 3600 Series Engines, Rev. 16

Attachment

VTM 59-F173-00002, Fairbanks Morse Opposed Piston Engines Instructions 3800TD8-1/8 Model Diesel Stationary, Rev. 47

VTM 59-F264-00002, Fisher ED and EAD easy-e Valves,

CL 125 through CL600. Rev. 8

VTM 59-F600-00001, Three-way Thermostatic Valve, Rev. 2

VTM-000-59-S825-00001 (PT-002), Revision 1, DWG: 72-XC-20,

SH-001 (10" valve outline drawing) Westinghouse Letter to Virginia Power, Surry Power Station Units 1 and 2, Reactor Coolant Pump Thermal Barrier Evaluation, 6/15/1989 Westinghouse Product Update P-007, Seal Housings, Ring Clamp, and Thermal Barrier to Main Flange Cap Screws Upgrade, Rev. 2

Work Order Overview Report 480V Switchgear - last 3 years, 5/24/12

Work Order Overview Report 4kV Switchgear- last 3 years, 5/23/11

Work Order Overview Report for U-2 Unit Substation Transformers - last 3 years, 5/23/11

Work Order Overview Report for U-2 Unit Substations - last 3 years, 5/23/12

Corrective Action Documents Initiated Due to CDBI Activity

ACE019179, ACE to Maint For TOL Not Meeting Acceptance Criteria In 0-ECM-0307-01

ACE019183, ACE to Inns-Eng To Address TOL Concerns

CR 476229, Loose Thumb Screws On Cabinets

CR 476426, Calc

ME-0909 Graph Y-Axis Description Incorrect

CR 476436, UFSAR Table 9.2-4 Data Missing For SW Screen Wash Pumps

CR 476571, During CDBI NRC Inspector Questioned Battery Discharge Test Stoppage Guidance

CR 477213, Potential Design Deficiency Of The SW Air Sub-System

CR 478531, CR Did Not Address Potential Single Active Failure Of SW Air System

CR 478564, 0-PT-82.13 (SBO EDG PT) Was Run Times Consecutively Instead Of Being Rotated

CR 478953, Evaluate If The UFSAR Needs To Be updated To Evaluate A Discrepancy In Wording

CR 479584, Evaluate 0-OP-6.4 Required Actions As Time Critical Actions

CR476620, 0-BCW-REJ-3, Control Rod Clearance Is Inconsistent

CR477848, Screen Wash Pump, No NPSHa Calculation for SW Screen Wash Pumps

CR477868, minor dry boric acid on 2-SI-MOV-2885D packing gland found during

NRC CDBI

walkdown

CR478137, No Design Basis and No Sizing Calculation for SW Air Receiver

CR478568, No testing On SW Air Check Valve 1-SW-343

CR478627, Incorrect AOV Model Number for PORVs 1455C/1456

CR478957, Evaluate Past Operability of SW system and subsystems

CR479217, TOL Did Not Meet Acceptance Criteria In 0-ECM-0307-01

CR479281, 300% Trip Time Testing Acceptance Criteria Range For TOLs May Be Too Wide

CR479321, NRC Was Not Notified Of Change In Assumption For GDC17 Degraded Voltage Analysis

CR479535, Thermal Overload Settings Per Design Standard May Be Inadequate

CR479552,

STD-EEN-001 Does Not Explicitly Address Motor TOL Sizing During Pump Run Out

CR479658, Ineffective Review Of 2011 Surry NRC CDBI Issue On TOL Settings (CR

46721/CA227677)

CR479661, CDBI Identified Concern With IST of QS and ORS Pumps Discharge Check Valve Testing

CR479664, MOV TOL Calculations Do Not Address The Survivability Of MOVs Under Degraded Grid Conditions Attachment

CR479690, Minimum Equipment Terminal Voltage D

oes Not Comply With Station Licensing Basis

CR480754, Design Documentation For Klockner TOLs

CR480755, RAI For 2012 CDBI Question 188.1 OD000175, 1/2-PT-66.1, Weight-Loaded Check Valves, Does Not Satisfy ASME Requirements

OD000484, SW Air System Not Single Active Failure Proof

OD000487, TOL Did Not Meet Acceptance Criteria During Performance Of WO #59102073031 OD000489, Degraded Voltage Relay Nonconforming Condition

IR 05000338/2012007

Text

Dear Mr. Heacock:

REGION II

SUMMARY OF FINDINGS

Cornerstone: Mitigating Systems

=

REPORT DETAILS

REACTOR SAFETY

1R21 Component Design Bases Inspection

.1 Inspection Sample Selection Process

.2 Component Reviews

.2.1 Thermal Barrier Heat Exchanger (1-RC-P-1A/B/C)

a. Inspection Scope

b. Findings

.2.2 Inside Recirculation Spray (IRS) Pumps (1-RS-P-1A and 1-RS-P-1B)

a. Inspection Scope

b. Findings

.2.3 Outside Recirculation Spray (ORS) Pumps (1-RS-P-2A and 1-RS-P-2B)

a. Inspection Scope

b. Findings

Introduction:

Description:

Analysis:

Enforcement:

.2.4 High Head Safety Injection/Charging Pumps (2-CH-P-1A/B/C)

a. Inspection Scope

b. Findings

.2.5 Unit 2 Emergency Diesel Generator (EDG) Jacket Cooling Water System

a. Inspection Scope

b. Findings

.2.6 Alternate Alternating Current (AAC) Diesel

a. Inspection Scope

b. Findings

.2.7 Unit 1 Pressurizer Power Operated Relief Valves (1-RC-PCV-1456 and 1-RC-PCV-

a. Inspection Scope

b. Findings

.2.8 Unit 2 Low Head Safety Injection Pumps (2-SI-P-1A and 2-SI-P-1B)

a. Inspection Scope

b. Findings

.2.9 Unit 1 and 2 Service Water (SW) Screen Wash Subsystem including Screen Wash Pump 1-SW-P-2, Screen Wash Strainer 1-SW-S-3, and Traveling Screen 1-SW-S-1A

a. Inspection Scope

Introduction:

Description:

Analysis:

Enforcement:

Introduction:

Description:

Analysis:

Enforcement:

.2.10 Motor Driven Auxiliary Feedwater Pressure Control Valves (1-FW-PCV-159A/B)

a. Inspection Scope

b. Findings

.2.11 125Vdc Vital Batteries Unit 1 and Unit 2

a. Inspection Scope

b. Findings

.2.12 4160V Buses 2H and 2J

a. Inspection Scope

b. Findings

.2.13 4160V to 480V Substation Transformers 2H and 2J

a. Inspection Scope

b. Findings

.2.14 480V Buses 2H, 2H1, 2J, and 2J1

a. Inspection Scope

b. Findings

.3 Corrective Actions

a. Inspection Scope

Introduction:

Description:

Analysis:

Enforcement:

Introduction:

Description:

Analysis:

Enforcement:

.4 Operating Experience (Six Samples)

a. Inspection Scope

b. Findings

OTHER ACTIVITIES

4OA6 Meetings, Including Exit