Text

Submittal of Updated Safety Analysis Report (Usar), Revision 29
	ML16084A005
Person / Time
Site:	Wolf Creek
Issue date:	03/10/2016
From:	Heflin A; Wolf Creek
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
Shared Package
ML16084A004	List: WM 16-0005, Submittal of Updated Safety Analysis Report (Usar), Revision 29;
References
	WM 16-0005
	Download: ML16084A005 (123)
	v • d • e

Adam C. Heflin President, Chief Executive Officer and Chief Nuclear Officer March 10, 2016 WM 16-0005 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555

Subject:

Docket No. 50-482: Revision 29 of the Wolf Creek Generating Station Updated Safety Analysis Report Gentlemen:

Pursuant to the updating requirements of 10 CFR 50.71(e), Wolf Creek Nuclear Operating Corporation (WCNOC) is providing its Updated Safety Analysis Report (USAR), Revision 29.

This submittal satisfies the Final Safety Analysis Report (FSAR) updating requirements of the aforementioned regulation. Per the requirement of 10 CFR 54.37(b), there are no newly identified systems, structures, and components that are subject to an aging management review or evaluation of time-limited aging analyses.

Attachment I to this letter provides information relative to changes in regulatory commitments.

This information is provided in accordance with the guidance of Nuclear Energy Institute (NEI) 99-04, "Guidelines for Managing NRC Commitment Changes," Revision 0, July 1999.

Attachment II to this letter describes specific technical changes that have been processed since issuance of the USAR, Revision 28. In addition to these technical changes, editorial changes have been made and are included in Revision 29.

Attachment Ill to this letter provides a discussion of changes made in Revisions 59 through 62 of the Technical Requirements Manual (TRM).

Enclosure I to this letter provides the CD-ROM submittal of the Wolf Creek Generating Station (WCGS) USAR, Revision 29. This submittal satisfies the Final Safety Analysis Report updating requirements of 10 CFR 50. 71 (e)(4). Chapter 2: Site Characteristics; Chapter 3: Design of Structures, Components, Equipment, and Systems; Chapter 8: Electric Power; Chapter 9:

Auxiliary Systems; and Chapter 12: Radiation Protection, are considered sensitive unclassified information and therefore warrant withholding under 10 CFR 2.390.

P.O. Box 411 I Burlington, KS 66839 I Phone: (620) 364-8831 An Equal Opportunity Employer M/F/HCNET

WM 16-0005 Page 2 of 4 Enclosure II to this letter provides a CD-ROM containing the station-controlled drawings that are considered incorporated by reference into the USAR. According to the guidance of NEI 98-03, Revision 1, "Guidelines for Updating Final Safety Analysis Reports," Revision 1, June 1999, the USAR figures that are identical to controlled drawings were relocated from the USAR in Revision 17. Enclosure II is considered sensitive unclassified information and therefore warrants withholding under 10 CFR 2.390. 11 to this letter provides a CD-ROM containing the USAR Fire Hazards Analysis and Quality Program Manual both of which are incorporated by reference into the USAR. The USAR Fire Hazards Analysis is considered sensitive unclassified information and therefore warrants withholding under 10 CFR 2.390.

Enclosure IV to this letter provides a CD-ROM containing EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II. Information from USAR Table 3.11 (B)-1, Plant Environmental Normal Conditions; USAR Table 3.11 (B)-2, Environmental Qualification Parameters for SNUPPS NUREG-0588 (LOCA, MSLB and HELB);

USAR Table 3.11 (B)-3, Identification of Safety-Related Equipment and Components:

Equipment Qualification; USAR Table 3.11 (B)-4, Containment Worst Case Radiation Levels (MRADs); USAR Table 3.11 (B)-5, Containment Spray Requirements; USAR Table 3.11-(B)-8, Exemptions from NUREG-0588 Qualification; USAR Table 3.11 (B)-10, Equipment Added for NUREG-0737; and USAR Figures 3.11 (B)-1 through 3.11 (8)-49, was relocated from the USAR into EQSD-1 and EQSD-11 in Revision 28 and is incorporated by reference into the USAR.

Enclosure IV is considered sensitive unclassified information and therefore warrants withholding under 10 CFR 2.390.

Enclosure V to this letter provides those changes made to the WCGS Unit 1 TRM (Revision 59 through 62) and includes a List of Effective Pages. The WCGS TRM is incorporated by reference into the USAR.

This letter contains no commitments. WCNOC has historically submitted updates to the USAR on March 11 of each year to coincide with the date of issuance of the WCGS operating license and to comply with the requirements of 10 CFR 50.71(e)(4). WCNOC considers that submittals made prior to or on March 11 satisfy the requirements of 10 CFR 50.71 (e)(4).

If you have any questions concerning this matter, please contact me at (620) 364-4000, or Cynthia R. Hafenstine at (620) 364-4204.

Sincerely,

~~

ACH/rlt Attachment I - Regulatory Commitment Management System (RCMS) Changes Attachment II - USAR Changes Processed Since Revision 28 Attachment Ill - Revisions 59 through 62 to the Technical Requirements Manual Enclosure I - CD-ROM containing Updated Safety Analysis Report, Revision 29 Enclosure II - CD-ROM containing Updated Safety Analysis Report Controlled Figure Drawings

WM 16-0005 Page 3 of 4 Enclosure Ill - CD-ROM containing Updated Safety Analysis Report Fire Hazards Analysis and Quality Program Manual Enclosure IV - CD-ROM containing Updated Safety Analysis Report EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II Enclosure V - Technical Requirements Manual Replacement Pages and List of Effective Pages cc: M. L. Dapas (NRC), w/a, w/e C. F. Lyon (NRC), w/a, w/e

_N. H. Taylor (NRC), w/a, w/e Senior Resident Inspector (NRC), w/a, w/e

WM 16-0005 Page 4 of 4 STATE OF KANSAS )

} SS COUNTY OF COFFEY }

Adam C. Heflin, of lawful age, being first duly sworn upon oath says that he is President, Chief Executive Officer and Chief Nuclear Officer of Wolf Creek Nuclear Operating Corporation; that he has read the foregoing document and knows the contents thereof; that he has executed the same for and on behalf of said Corporation with full power and authority to do so; and that the facts therein stated are true and correct to the best of his knowledge, information and belief.

By~1-+--=-~..,,..~,__,.:;...._~~~~~~~

Adam . Heflin President, Chief Ex cutive Officer and Chief Nuclear Officer SUBSCRIBED and sworn to before me this lD+I{ day of r1a-r~ '2016.

RHONDA L. TIEMEYER Notary Public My Appointment Expires January 11, 2018 . '.

Expiration Date ao~

~ .

'I, ().D '~

Attachment I to WM 16-0005 Page 1 of 4 Attachment I to WM 16-0005 Regulatory Commitment Management System (RCMS) Changes

Attachment I to WM 16-0005 Page 2 of 4 Commitment Changes Commitment No. RCMS 1987-207 from letter WM 87-0305, dated November 11, 1987 Commitment

Description:

A Preventative Maintenance (PM) procedure is being modified to inspect the bolts and lubricate the doors gears semi-annually for this and similar doors.

Change to Commitment: The frequency of the PM was extended from semi-annually to "maintained on a specified frequency." This will change the performed frequency timeframe from every six months to every 18 months.

Justification: The review of PMs, work order histories from 2012 to current, and testimonies of Maintenance Technicians have indicated satisfactory results have been obtained for PM performed. In Accordance with INPO AP-913, Section 3.4.1, PM frequencies may be adjusted based on ~tation equipment operating experience. Decreasing the frequency will still meet the intent of the commitment and meet the guidance provided in INPO AP-913.

Commitment No. RCMS 1994-250 from WO 94-0220, dated December 30, 1994 Commitment

Description:

Incident Investigation Team (llT) leaders to Investigation Coordinators (ICs) will be trained on the llT procedure. The training will focus on the administrative requirements established in Instruction Al 288-003, "Incident Investigation Team," and the preferred investigative techniques. Training is scheduled to commence in February 1995 and will be available on an ongoing basis as needed to enhance and maintain personnel understanding and abilities. If an llT is initiated prior to the commencement of training in February 1995, then the team leader and the ICs will be trained at the beginning of the llT.

Change to Commitment: This commitment has been closed and archived.

Justification: This commitment was created in rei;;ponse to NOV 9413-01. The immediate actions described in the commitment were satisfied in 1995. This commitment was to be ongoing to prevent reoccurrence. Due to changes that have occurred in the station and industry, this commitment is outdated and no longer necessary to achieve compliance.

Commitment No. RCMS 1994-251 from letter WO 94-0220, dated December 30, 1994 Commitment

Description:

Procedure AP 34E-001, "Self Assessment Process," has been divided into two separate sections to provide clear administrative guidance on 1) llTs (Instruction Al 288-003, "Incident Investigation Team"); and 2) Other Types of Self Assessments (Procedure AP 28D-001, "Self-Assessment"). The new administrative instruction for llTs will establish, as an llT Team member, an Investigative Coordinator (IC) position assignment. The ICs responsibilities will include ensuring that the administrative requirements of this procedure are adhered to by the llT. This separation of procedural requirements for llTs and other types of self-assessments is consistent with past WCNOC practice and will more appropriately focus personnel attention on which requirements are applicable to which types of assessments. These procedures have been approved.

Attachment I to WM 16-0005 Page 3 of 4 Change to Commitment: This commitment has been closed and archived.

Justification: This commitment was written to achieve compliance, and prevent reoccurrence.

Due to changes that have occurred in the station and industry, this commitment is outdated and no longer necessary to achieve compliance.

Commitment No. RCMS 1996-156 from letter WM 96-0081, dated July 31, 1996 Commitment

Description:

Separately the corrective action procedures were revised to require independent reviewers or the individual who perform the root cause analysis to be trained in root cause techniques.

Change to Commitment: This commitment has been closed and archived.

Justification: This commitment was made in response to Enforcement Action 96-124, Violation l.C, to minimize the recurrence of a known condition adverse to quality. Due to a change in plant and industry standards, this commitment is no longer the most effective way to minimize recurrence, and is unnecessary.

Commitment No. RCMS 2012-457 from letter WM 12-0023, dated August 2, 2012 Commitment

Description:

Wolf Creek Nuclear Operating Corporation (WCNOC) will mitigate adverse effects of column closure water hammer in the ESW system to within acceptable design parameters. {Transferred from 2013-478} ESW Water Hammer: WCNOC will install the modification to mitigate water hammer during the Mid-Cycle Outage. Commitment revised by letter WM 14-0011 to "Install a modification to mitigate the adverse effects of column closure water hammer in the ESW System."

Change to Commitment: This commitment has been satisfied. The commitment has been changed to closed and archived.

Justification: This commitment was created in response to Notice of Violation EA-12-135 for failure to take corrective actions to prevent the reoccurrence of water hammer events and system leaks. Based on the completion of the modification work orders (WO) 14-390646-068 and 14-390647-079) and the declaration of operability of both "A" and "B" trains by Operations, it has been determined that compliance has been achieved and the commitment is satisfied.

Commitment No. RCMS 2014-496 from letter WM 14-0013, dated May 8, 2014 Commitment

Description:

WCNOC commits to ensuring the reliability of the four containment coolers in the future by, in order of preference, either replacing the tube bundles with new based on material availability, inspection of the tube bundles, or testing of the existing tube bundles. These actions will be completed prior to restart from Refueling Outage 20.

Attachment I to WM 16-0005 Page 4 of 4 Change to Commitment: This commitment has been satisfied. The commitment has been closed and archived.

Justification: Both "A" and "B" trains of the containment coolers were declared operable per Technical Specification 3.6.6 by Operations due to the completion of Work Orders (WO) 14-388658-036 and WO 14-388659-067, respectively, and the acceptance of Design Change Packages (DCP) 14732 and DCP 14003, respectively.

1 to WM 16-0005 Page 1 of 10 Attachment II to WM 16-0005 USAR Changes Processed Since Revision 28

Attachment II to WM 16-0005 Page 2 of 10 USAR Change Request Description 15-003 REVISE THE USAR TO UPDATE THE STATEMENT THAT NO STEAM GENERATOR TUBE FLUID-ELASTIC VIBRATION WILL OCCUR DURING STEADY STATE CONDITIONS AS WELL AS DURING OPERATING TRANSIENTS. AN ANALYSIS TO DETERMINE IF STEAM GENERATOR TUBES ARE SUBJECT TO POSSIBLE FATIGUE FAILURE DURING THEIR LIFETIME, AS DESCRIBED IN WCAP-17990-P, "WOLF CREEK U-BEND VIBRATION AND FATIGUE ASSESSMENT," IDENTIFIED SEVENTEEN (17) TUBES THAT MAY BE SUBJECT TO FATIGUE FAILURE BASED ON THE PINNED AND NON-OCCLUDED CASE. THE 17 TUBES WERE PLUGGED DURING REFUEL 20.

Page: 5.4-23 15-004 REVISE THE USAR TO REFLECT THE RESTRICTION OF FLOW FROM THE SAFETY RELATED PORTION TO THE NON-SAFETY RELATED PORTION OF THE COMPONENT COOLING WATER (CCW) SYSTEM BY INSTALLING SAFETY RELATED FLOW RESTRICTION DEVICES BETWEEN THEM.

Page: 9.2-17 Page: 9.2-16 Page: 9.2-14 Table: 9.2-13 Sheet: 2 Table: 9.2-9 Sheet: 2 Table: 9.2-10 Sheet: 2 Table: 9.2-11 Sheet: 2 15-005 REVISE THE USAR TO REFLECT THE REMOVAL OF THE BLADDER FROM THE WASTE EVAPORATOR CONDENSATE TANK.

Page: 11.2-8 Page: 11.2-7 Figure: 11.1A-1 15-006 REVISE THE USAR TO REFLECT THE ABANDONMENT OF PASS IN PLACE.

ALL PIPING IS CUT AND CAPPED AS CLOSE TO THE PASS WET PANEL AS POSSIBLE AND ALL ELECTRICAL POWER AND EXTERNAL ELECTRICAL CONNECTIONS TO AND FROM THE PASS WERE REMOVED. (AMENDMENT NO. 137)

Page: 12.2-3 Page: 8.1-15 Page: 18.3-12 Page: 18.3-11 Table: 6.2.4-1 Table: 6.2.4-1 Sheet: 2 Table: 9.2-9 Sheet: 2 Table: 9.2-10 Sheet: 2 Table: 9.2-11 Sheet: 2 Figure: 6.2.4-1 Sheet: 42 Figure: 6.2.4-1 Sheet: 42b Figure: 6.2.4-1 Sheet: 45a Figure: 6.2.4-1 Sheet: 67 Figure: 6.2.4-1 Sheet: 69 Figure: 6.2.4-1 Sheet: 70 Figure: 6.2.4-1 Sheet: 71

Attachment II to WM 16-0005 Page 3of10 USAR Change Request ,Description 15-007 REVISE THE USAR TO REFLECT THAT CYCLE 21 FRESH FUEL (REGION 23)

WILL INCLUDE DESIGNS FOR THE STANDARDIZED DEBRIS FILTER BOTTOM NOZZLE (SDFBN); ROBUST PROTECTIVE GRID (RPG), AND COMBINATION BOTTOM GRID NOT PREVIOUSLY USED AT WOLF CREEK GENERATING STATION. SOFTWARE FOR CYCLE 21 RELOAD CORE HAS CHANGED FROM PHOENIX-P/ANC8 TO NEXUS/PARAGON/ANC9.

Page: 4.2-14 Page: 4.2-12 Page: 4.2-11 Page: 4.2-13 Page: 4.2-18 Page: 4.2-20 Page: 4.3-35 Page: 4.3-36 Page: 4.3-37 Page: 4.3-38 Page: 4.3-39 Page: 15.0-1 Page: 4.1-2 Page: 15.0-20 Page: 4.1-4 Page: 4.2-15 Page: 4.2-16 Page: 4.2-17 Page: 4.2-19 Page: 4.2-21 Page: 4.2-22 Page: 4.2-23 Page: 4.2-24 Page: 4.2-25 Page: 4.2-26 Page: 4.2-27 Page: 4.2-28 Page: 15.0-15 Table: 4.1-1 Sheet: 4 Table: 4.1-2 Sheet: 4 Table: 15.0-2 Sheet: 2 Table: 15.0-2 Sheet: 3 Figure: 4.2-2F 15-008 REVISE THE USAR TO REFLECT REVISED FLOODING CALCULATIONS.

CALCULATIONS WERE REVISED AS A RESULT OF CONDITION REPORTS 26050 AND 27904.

Table: 3.6-6 Table: 3.6-6 Sheet: 2 Table: 38-1 Sheet 26 15-009 REVISE THE USAR TO REFLECT MAINTENANCE OF THE WATER SEAL ASSOCIATED WITH ALL THREE CONDENSER EXPANSION JOINTS DRY EXCEPT FOR POST MAINTENANCE TESTING FOLLOWING NEW JOINT INSTALLATION AND IN TIMES WHEN AN EXPANSION JOINTS VACUUM SEAL HAS BEEN BREACHED.

Page: 10.4-4 Page: 10.4-2 15-010 REVISE THE USAR TO REFLECT THE TIE IN OF A WIND FARM INTO THE LACYGNE 345 Kv LINE.

Page: 8.2-10 Page: 8.2-6 Page: 8.2-3 Figure: 8.2-1 Figure: 8.2-5 15-011 REVISE THE USAR TO REFLECT THE INSTALLATION OF TEMPORARY MODIFICATION ORDER (TMO) 15-015-EM-OO WHICH INSTALLED A LINE CRIMP KILL ON A PORTION OF THE SAFETY INJECTION SYSTEM TEST LINE SUBSYSTEM, WHICH BLOCKS A PORTION OF THE TEST LINE PIPING. THE LINE CRIMP IS INSTALLED TO STOP LEAKAGE OF NITROGENATED WATER OUT OF THE "A" ACCUMULATOR THROUGH VALVE EPHV8879A. THE TMO WILL BE REMOVED NO LATER THAN PLANT STARTUP AT THE END OF REFUEL 21(FALL2016).

Page: 6.3-39 1 to WM 16-0005 Page 4of10

.USAR Change Request Description 15-012 REVISE THE USAR TO ADD THE BIOGRAPHY FOR S. A. BELL BECAUSE HE IS NOW A QUALIFIED SHIFT MANAGER.

Page: 13.1-19 15-013 REVISE THE USAR TO INCORPORATE CHANGES RESULTING FROM AMENDED NRC FEDERAL REGULATIONS PUBLISHED IN THE FEDERAL REGISTER VOL 79, PAGES 65776 THROUGH 65814, ON NOVEMBER 5, 2014. REGULATIONS 50.54, 50.55, AND 50.55a WERE CHANGED.

Page: 3A-36 Page: 3A-60 Page: 3A-63 Table: 1.3-4 Sheet: 19 Table: 1.3-4 Sheet: 20 Table: 1 .3-4 Sheet: 16 Table: 1.3-4 Sheet: 17 Table: 1.3-4 Sheet: 18 15-014 REVISE THE USAR TO DELETE COMMITMENT WHICH REQUIRES A ONE TIME INSPECTION OF DIESEL FIRE PUMP OIL TANK THAT IS TO BE PERFORMED BETWEEN 10 AND 2 YEARS PRIOR TO THE PERIOD OF EXTENDED OPERATION. CHANGE PACKAGE 13923 INSTALLED A NEW DIESEL FIRE PUMP FUEL OIL TANK.

Page: 18A-9 Page: 18A-10 15-015 REVISE THE USAR TO REFLECT THE REMOVAL OF THE DRY TUNNEL SUMP VOLUME IN SECTION 5.2.5.2.3. THE SUMP IS OPERATED WITH LEVEL ON-SCALE.

Page: 5.2-42 15-016 REVISE THE USAR TO UPDATE INFORMATION FOR CONTAINMENT AIR COOLERS A, B, AND C COIL REPLACEMENT. INFORMATION UPDATED INCLUDES THE MINIMUM CAPACITY FOR AIR-SIDE FLOW RATE THROUGH FAN IN DESIGN BASIS ACCIDENT CONDITIONS, AND DUTY BTU/HR FOR NORMAL CONDITIONS.

Table: 6.2.1-3 Sheet: 2 Table: 6.2.2-2 Sheet: 2 Table: 6.2.2-2 Sheet: 4 15-017 REVISE THE USAR TO REFLECT THE REPLACEMENT OF CONTAINMENT AIR COOLER "D" WITH A STAINLESS STEEL COOLER.

Table: 6.2.1-57C Figure: 6.2.1-15 1 to WM 16-0005 Page 5of10 USAR Change Request Description 15-018 REVISE THE USAR TO REFLECT THAT THE HYDROGEN RECOMBINERS ARE NO LONGER TESTED AND THE UNITS POWER SUPPLY BREAKERS ARE MAINTAINED IN THE OFF POSITION. PLANT PROCEDURES HAVE BEEN CHANGED ACCORDINGLY. LICENSE AMENDMENT REQUEST 157 DELETED THE TECHNICAL SPECIFICATION REQUIREMENT FOR THE HYDROGEN RECOMBINERS.

Page: 6.2-87 Page: 6.2-82 Page: 6.2-75 Page: 6.1-2 15-019 REVISE THE USAR, CHAPTER 3.11(B) AND 3.0 FIGURE TABLE OF CONTENTS TO CLARIFY THE CONNECTION BETWEEN THE USAR AND EQSD-1 (EQUIPMENT QUALIFICATION DESIGN BASIS DOCUMENT. SOME 3.11(B)

TABLES AND FIGURES WERE MOVED TO EQSD-1 IN REVISION 28 OF THE USAR.

Page: 3.11 (B)-17 Page: 3.11 (B)-15 Page: 3.11 (B)-4 15-020 REVISE THE USAR TO REFLECT REVISIONS TO CALCULATIONS AN-06-017, REV 1, AND AN-14-001, REV 0. AN-06-017 UPDATES THE REACTIVITY FEEDBACK IN THE STEAM LINE BREAK ACCIDENT ANALYSIS. AN-14-001 HAS BEEN ISSUED FOR CYCLE 21 AND RECALCULATED THE MINUMUM DNBR TO OCCUR AT 149.6 SECONDS.

Page: 15.1-16 Table: 15.1-1 Sheet: 2 Figure: 15.1-20a Figure: 15.1-20 Figure: 15.1-19 Figure: 15.1-18 Figure: 15.1-17 Figure: 15.1-16 Figure: 15.1-15 Figure: 15.1-11 a 15-021 REVISE THE USAR TO INCLUDE TEMPORARY SCAFFOLDING MATERIAL IN TABLE 1.7-4. THIS SCAFFOLDING MATERIAL IS SUPPORTING CAMERAS TO MINIMIZE WORKER EXPOSURES AS PART OF THE ALARA PROGRAM.

Table: 1.7-4 Sheet: 5 15-022 REVISE THE USAR TO UPDATE TABLE 1.7-4 WITH SCAFFOLD THAT WILL REMAIN IN THE PLANT THROUGHOUT THE NEXT USAR UPDATE CYCLE.

Table: 1.7-4 Sheet: 4 Table: 1.7-4 Sheet: 3 Table: 1.7-4 Sheet: 1 Table: 1.7-4 Sheet: 2 15-023 REVISE THE USAR TO REFLECT THAT INSTALLATION OF CANOPY SEAL CLAMP ASSEMBLIES ARE AUTHORIZED AT ANY CANOPY SEAL LOCATION.

Page: 5.2-36

Attachment II to WM 16-0005 Page 6 of 10 USAR Change Request Description 15-024 REVISE THE USAR TO INCORPORATE LICENSE AMENDMENT REQUEST NO.

214, REVISE THE FIRE PROTECTION PROGRAM RELATED TO ALTERNATIVE SHUTDOWN CAPABILITY.

Page: 9.58-0 Table: 9.5E-1 Sheet: 27 Table: 9.5E-1 Sheet: 26 Table: 1.6-4 Sheet: 2 15-025 REVISE THE USAR TO INCORPORATE LICENSE AMENDMENT REQUEST (LAR) NO. 213, REVISE TECHNICAL SPECIFICATION 5.6.5, "CORE OPERATING LIMITS REPORT (COLR)," TO ADD ASTRUM TO THE LIST OF ANALYTICAL METHODS.

Page: 6.2-40 Page: 6.2-41 Page: 6.2-97 Page: 15.6-19 Page: 15.6-20 Page: 15.6-21 Page: 15.6-22 Page: 15.6-23 Page: 15.6-24 Page: 15.6-25 Page: 15.6-26 Page: 15.6-27 Page: 15.6-35 Page: 15.6-36 Page: 15.6-32 Page: 15.6-29 Page: 15.6-38 Page: 15.6-37 Page: 15.6-34 Page: 15.6-33 Page: 15:6-28 Page: 15.6-31 Page: 15.6-30 Page: 15.6-39 Table: 15.6-10 Sheet: 2 Table: 15.6-13 Table: 15.6-11 Table: 15.6-98 Table: 15.6-10 Table: 15.6-9 Table: 6.2.1-66 Sheet: 2 Table: 6.2.1-66 Sheet: 1 Table: 6.2.1-65 Table: 6.2.1-64 Table: 6.2.1-63 Sheet: 5 Table: 6.2.1-63 Sheet: 4 Table: 6.2.1-63 Sheet: 3 Table: 6.2.1-63 Sheet: 2 Table: 6.2.1-63 Sheet: 1 Figure: 15.6-128 Figure: 15.6-5 Figure: 15.6-13 Figure: 15.6-121 Figure: 15.6-12H Figure: 15.6-12G Figure: 15.6-12F Figure: 15.6-12E Figure: 15.6-15 Figure: 15.6-12C Figure: 15.6-16 Figure: 15.6-12A Figure: 15.6-11 Figure: 15.6-1 O Figure: 15.6-9 Figure: 15.6-8 Figure: 15.6-7 Figure: 15.6-4 Figure: 15.6-120 Figure: 15.6-24A Figure: 6.2.1-86 Figure: 6.2.1-87 Figure: 15.6-30 Figure: 15.6-29 Figure: 15.6-28 Figure: 15.6-27 Figure: 15.6-26 Figure: 15.6-14 Figure: 15.6-248 Figure: 15.6-12 Figure: 15.6-23 Figure: 15.6-22 Figure: 15.6-21 Figure: 15.6-20 Figure: 15.6-19 Figure: 15.6-18 Figure: 15.6-17 Figure: 15.6-25

Attachment II to WM 16-0005 Page 7of10 USAR Change Request Description 15-026 REVISE THE USAR TO ADD ACTIONS IMPLEMENTED TO DATE TO COMPLY WITH NRC ORDERS EA 12-049 AND EA 12-051. THIS USAR CHANGE DESCRIBES THE WOLF CREEK RESPONSE TO BEYOND-DESIGN-BASIS EXTERNAL EVENT FUKUSHIMA RELATED REQUIRED ACTIONS.

Page: 10.4-48 Page: 9.1-28 Page: 30-3 Page: 30-2 Page: 30-1 15-027 REVISE THE USAR TO REFLECT THE ADDITION OF THE ESSENTIAL SERVICE WATER (ESW) COLUMN CLOSURE WATER HAMMER TOWER. THIS UPDATE INCLUDES DISCUSSION-OF THE ESW VERTICAL LOOP CHASE STRUCTURE AND LOOP CHASE PIPING AND COMPONENTS.

Page: 3.8-76 _Page: 1.2-7 Page: 1.4-12 Page: 3.8-70 Page: 3.4-2 Page: 3.5-16 Page: 3.5-17 Page: 3.7(8)-1 Page: 3.7(8)-4 Page: 3.8-60 Page: 3.8-63 Page: 3.8-65 Page: 1.1-2 Page: 3.8-72 Page: 3.8-71 Page: 3A-23 Page: 3A-40 Page: 3C-2 Page: 9.2-11 Page: 9.2-6 Page: 9.2-7 Page: 9.2-8 Page: 9.2-9 Page: 9.2-10 Page: 9.4-94 Table: 3.3-1 Table: 3.7(8)-7E Table: 3.7(8)-70 Table: 3.7(8)-7C Table: 3.7(8)-78 Table: 3.7(8)-7A Table: 3.9(8)-16 Sheet: 17 Table: 3.7(8)-3 Table: 3.5-2 Table: 1.1-1 Sheet: 2 Table: 3.4-1 Table: 3.7(8)-7H Table: 3.2-1 Sheet: 3 NOTES Table: 3.2-1 Sheet: 21 Table: 3.2-1 Sheet: 20 Table: 3.2-1 Sheet: 6 Table: 2.5-54 Table: 2.5-53 Table: 2.5-52 Table: 1.3-2 Sheet: 3 Table: 3.4-2 Table: 3.7(8)-7Q Table: 3.7(8)-7A8 Table: 3.7(8)-7Z Table: 3.7(8)-7Y Table: 3.7(8)-7X Table: 3.7(8)-7W Table: 3.7(8)-7V Table: 3.7(8)-7U Table: 3.7(8)-7T Table: 3.7(8)-7F Table: 3.7(8)-7R Table: 3.7(8)-7G Table: 3.7(8)-7P Table: 3.7(8)-70 Table: 3.7(8)-7N Table: 3.7(8)-7M Table: 3.7(8)-7L Table: 3.7(8)-7K Table: 3.7(8)-7J Table: 3.7(8)-71 Table: 3.7(8)-7M Table: 3.7(8)-7S Figure: 3.8-102 Figure: 2.4-3 Sheet: 1 Figure: 2.5-59 Figure: 2.5-106i Figure: 3.5-1 Figure: 3.5-2 Figure: 3.8-84 Figure: 3.8-99 Figure: 2.3-20 Figure: 3.8-101 Figure: 3.8-120 Figure: 3.8-103 Figure: 3.8-103 Sheet: 2 Figure: 3.8-104 Figure: 3.8-104 Sheet: 2 Figure: 3.8-116 Figure: 3.8-118 Figure: 3.8-119 Figure: 3.8-100

Attachment II to WM 16-0005 Page 8 of 10 USAR Change Request Description 15-028 REVISE THE USAR TO REFLECT THE TRAINING STANDARD PASSING CRITERIA TO 80 PERCENT OR GREATER. THIS CRITERIA WAS ESTABLISHED BY THE JOINT TRAINING CRITERIA.

Page: 13.2-10 15-029 REVISE THE USAR TO RELECT A CHANGE TO USAR SUPPLEMENT A1.26 FOR EXAMINATION OF MANHOLES IN THE PERIOD OF EXTENDED OPERATION. CURRENTLY A1.26 STATES THAT ALL ELECTRICAL MANHOLES WILL BE INSPECTED AT LEAST ONCE EVERY TWO YEARS.

PLANT DATA FOR ELECTRICAL MANHOLES WITH SUMP PUMPS DEMONSTRATES THAT AN INSPECTION FREQUENCY OF AT LEAST ONCE EVERY FIVE YEARS IS APPROPRIATE. THE PROPOSED CHANGE IS TO DISTINGUISH THE DIFFERENCE BETWEEN ELECTRICAL MANHOLES WITH AND WITHOUT SUMP PUMPS.

Page: 18A-16 Page: 18A-15 15-030 REVISE THE USAR TO REFLECT THE REPLACEMENT OF THE OBSOLETE WESTINGHOUSE INVERTERS THAT NORMALLY FEED THE 120 VAC VITAL BUSES. FOUR NEW 120 VAC SAFETY RELATED INVERTERS ARE EQUIPPED WITH AN INTEGRAL CONSTANT VOLTAGE TRANSFORMER CAPABLE OF ACTING AS THE ALTERNATE SOURCE FOR THE VITAL BUS WHEN ITS INVERTER SECTION IS INOPERABLE.

Page: 8.3-43 Page: 8.3-37 Page: 8.3-21 Page: 8.1-26 Page: 8.1-25 Page: 7.7-30 Table: 8.3-4 Sheet: 30 Table: 7.4-6 Sheet: 38 Table: 8.3-1 Table: 8.3-1 Sheet: 2 Table: 8.3-4 Sheet: 2 Table: 8.3-4 Sheet: 27 Table: 7.4-6 Sheet: 35 Table: 8.3-4 Sheet: 29 Table: 3.10(N)-1 Table: 8.3-4 Sheet: 31 Table: 8.3-4 Sheet: 32 Table: 8.3-4 Sheet: 33 Table: 8.3-4 Sheet: 34 Table: 8.3-4 Sheet: 35 Table: 7.4-6 Sheet: 34 Table: 8.3-4 Sheet: 28 1 to WM 16-0005 Page 9of10 USAR Change Request Description 15-031 REVISE THE USAR TO MAKE EDITORIAL CHANGES SUCH AS GRAMMAR AND SPELLING CORRECTIONS, PROPER IMPLEMENTATION OF PREVIOUSLY INCORPORATED CHANGES, UPDATE CHAPTER 13 DUE TO LEADERSHIP REALIGNMENT, DEPARTURES AND NEW HIRES.

Page: 6.4-8 Page: 3.5-10 Page: 3.5-14 Page: 3.5-16 Page: 3.6-22 Page: 3.9(8)-21 Page: 4.4-34 Page: 6.2-32 Page: 6.2-36 Page: 18A-20 Page: 6.3-22 Page: TOC Page: 11 .4-8 Page: 13.1-5 Page: 13.1-13 Page: 13.1-14 Page: 13.1-21 Page: 18A-5 Page: 18A.1-43 Page: 18A-18 Page: 5.2-5 Page: 6.2-79 Table: 3.2-3 Sheet: 3 Table: 7.2-3 Table: 9.2-3 Table: 9.2-3 Sheet: 2 Table: 3.2-3 Sheet: 5 Table: 11.5-3 Figure: 6.2.4-1 Sheet: 67 Figure: 6.2.4-1 Sheet: 45a Figure: 13.1-1 Figure: 6.5-5 16-001 REVISE THE USAR TO UPDATE TABLES 9.2-9, SHEET 2, AND TABLE 9.2-10, SHEET 2, TO REFLECT THE OBSERVED VALUE OF CCW FLOW RATE TO THE NON-VITAL PRIMARY SAMPLING SYSTEM COOLERS DUE TO THE COMPONENT COOLING WATER SYSTEM DUE TO MODIFICATION 13540.

Figure: 9.2-9 Sheet: 2 Figure: 9.2-10 Sheet: 2 16-002 REVISE THE USAR TO REFLECT INSTRUMENT UNCERTAINITY THAT HAD NOT BEEN ADDRESSED IN THE CONTAINMENT PRESSURE-TEMPERATURE CALCULATIONS. THE LOSS OF COOLANT ACCIDENT AND MAIN STEAM LINE BREAK LIMITING CASES WERE RE-RUN WITH A 10 DEGREE F ALLOWANCE FOR INSTRUMENT UNCERTAINITY TO VERIFY PRESSURE AMO TEMPERATURE LIMITS WERE NOT EXCEEDED. THE CHANGE ALSO REFLECTS A TIME DELAY FOR CREDITING THE CONTAINMENT COOLERS FROM 70 SECONDS TO 250 SECONDS TO ALLOW FOR A POTENTIAL WATER HAMMER MITIGATION MODIFICATION.

Page: 6.2-39 Page: 6.2-38 Page: 6.2-14 Page: 6.2-9 Page: 6.2-8 Table: 6.2.1-60 Table: 6.2.1-59 Table: 6.2.1-58 Table: 6.2.1-9 Sheet: 2 Table: 6.2.1-9 Table: 6.2.1-8 Table: 6.2.1-6 Table: 6.2.1-5 Table: 6.2.1-3 Sheet: 2 Table: 6.2.1-2 Figure: 6.2.1-84 Figure: 6.2.1-83 Figure: 6.2.1-82 Figure: 6.2.1-81 Figure: 6.2.1-25 Figure: 6.2.1-23 Figure: 6.2.1-21 Figure: 6.2.1-19 Figure: 6.2.1-17 Figure: 6.2.1-13 Figure: 6.2.1-7 Figure: 6.2.1-1 1 to WM 16-0005 Page 10of10 USAR Change Request Description 16-003 REVISE THE USAR TO REFLECT TWO NEW SHIFT MANAGERS. ERIC CARLSON AND ERIC MARTINSON ARE BEING ADDED.

Page: 13.1-20 Page: 13.1-19 16-004 REVISE THE USAR TO REFLECT THE ESSENTIAL SERVICE WATER VERTICAL LOOP CHASE IMPACT ON THE OILY WASTE SYSTEM.

Page: 9.3-21 16-005 REVISE THE USAR TO CORRECT TABLE 9.2-3, AUXILIARY FEEDWATER PUMP ROOM COOLER FLOW FROM 100 PGM WHILE IN ACCIDENT CONDITION TO 128 GPM. TUBE MATERIAL IS ALSO BEING CORRECTED.

Table: 9.2-2 Table: 9.2-3 Table: 9.2-4 Table: 9.4-8 Sheet: 6 Table: 9.4-8 Sheet: 7 Table: 9.4-8 Sheet: 8 16-006 REVISE THE USAR TO ADD P.C. MOORE AS OPERATIONS SUPERINTENDENT.

Page: 13.1-19 Page: 13.1-18 Page: 13.1-17 11 to WM 16-0005 Page 1 of 5 Attachment Ill to WM 16-0005 Revisions 59 through 62 to the Technical Requirements Manual

Attachment Ill to WM 16-0005 Page 2 of 5 REVISIONS TO THE TECHNICAL REQUIREMENTS MANUAL {TRM)

1. Technical Requirements Manual (TRM) Table TR 5.2.1-1, footnote (a) was revised to reflect the correct Section 5.2 Technical Specification (TS). Specifically, footnote (a) refers to 5.2.2f. and the correct reference is 5.2.2e. Footnote (a) pertains to the qualifications of the STA (Shift Technical Advisor) that are required by TS 5.2.2e ..

Additionally, T.S 5.2.2f. does not exist.

2. Technical Requirement (TR) 3.4.17, "Structural Integrity," Bases pages B 3.4.17-1, B 3.4.17-3, B 3.4.17-7, and B 3.4.17-9 were revised to refer to NRC Inspection Manual Chapter 0326 instead of Regulatory Issue Summary (RIS) 2005-20. NRC Inspection Manual Chapter (IMC) 0326, "Operability Determinations & Functionality Assessments for Conditions Adverse to Quality or Safety," was issued in January 2014 and replaced the Inspection Manual Part 9900 Technical Guidance that was issued by RIS 2005-20. A review of the description of changes associated with IMC 0326 determined that there were no substantive changes to the guidance in Appendix C.10, C.11 and C.12 which was the guidance used for TRB 3.4.17.

3. The TR 3.7.24, TR Bases wording was revised from:

"An electrical penetration room cooler can be capable of providing cooling even though it may be nonfunctional (e.g. Essential Service Water System is inoperable but service water is available to the room cooler)."

to:

"If the associated Essential Service Water train is unavailable or inoperable, and service water is available as a cooling medium to the electrical penetration room cooler, the room cooler is considered capable of providing cooling."

Condition Report (CR) 86691 identified that the above TR Bases wording resulted in an entry into Required Action C.1 with a 7 day Completion Time as it appeared to the control room crew that the statement required the electrical penetration room cooler to be nonfunctional when ESW is inoperable. The wording was revised to provide clarification consistent with the engineering disposition for configuration change package (CCP) 09816. Additionally, the TR 3.7.24 Bases was revised to refer to NRC Inspection Manual Chapter 0326 instead of RIS 2005-20.

4. TR 3.8.1, "Offsite Power System - Transmission Network," and the associated Bases were revised to reflect a modification that splits the LaCygne 345kV transmission line into the Wavery-LaCygne 345 kv transmission line. Westar Energy notified WCNOC that the Southwest Power Pool has issued a directive to install a Wind Farm (approximately 200MW) that will be tied into the LaCygne 345kV Line approximately 5 miles from WCGS.

The work involves installation of the Waverly Switching Station that splits the LaCygne 345kV line into two line segments, a Wolf Creek to Waverly Switching Station 345kV Line and a Waverly Switching Station to LaCygne 345kV Line as well as adding an approximate 5 miles of 345kV Transmission line from the Waverly Switching Station to the Waverly Collector Sub (tie in point for the Wind Farm). The configuration of the Waverly Switching Station is a ring bus design.

Attachment Ill to WM 16-0005 Page 3 of 5

5. TR 3.3.15, "Source Range Neutron Flux," and associated Bases was revised to delete the requirement for a CHANNEL OPERATIONAL TEST (TSR 3.3.15.2) in MODES 3, 4, and 5 with the Rod Control System not capable of rod withdrawal and all control rods fully inserted.

Prior to the conversion to the Improved Technical Specifications (Amendment No. 123, the Current Technical Specifications, Function 6.b (Source Range, Neutron Flux Shutdown) .Mode of Applicability was 3, 4, 5 and did not differentiate as to whether the Rod Control System was capable or incapable of rod withdrawal or one or more rods not fully inserted. The Improved Standard Technical Specifications (ISTS) (NUREG-1431, Rev 1, and TSTF-135) did not include requirements for Source Range Neutron Flux in MODE 3, 4, 5 with the Rod Control System incapable of rod withdrawal. During the conversion to the ITS, Description of Change (DOC) 1-38-R was applied to this function to relocate the Source Range Neutron Flux monitoring function (i.e., Rod Control System incapable of rod withdrawal) to the TRM. When these requirements were relocated, the existing surveillance requirements were relocated as well.

TR 3.3.15 required two channels of Source Range Neutron Flux to be FUNCTIONAL to ensure the capability to monitor core neutron levels and provide indication of reactivity changes in MODES 3, 4, and 5 with the Rod Control System not capable of rod withdrawal and all control rods fully inserted. The specification included three surveillance requirements, a CHANNEL CHECK (TSR 3.3.15.1 ), a CHANNEL OPERATIONAL TEST (TSR 3.3.15.2), and a CHANNEL CALIBRATION (TSR 3.3.15.3). The CHANNEL OPERATIONAL TEST (TSR 3.3.15.2) is satisfied by procedures STS IC-231 and STS IC-232. The purpose of a CHANNEL OPERATIONAL TEST is to verify and adjust, as necessary, alarm, interlock, and trip setpoints required for channel OPERABILITY such that the setpoints are within the necessary range and accuracy. For the purpose of monitoring core neutron levels, there are no required alarm, interlock or trip setpoints. As such, the requirement to a CHANNEL OPERATIONAL TEST of the source range monitors in MODES 3, 4, and 5 with the Rod Control System not capable of rod withdrawal and all control rods fully inserted is not necessary since the source range monitors are only required for monitoring.

Additionally, TSR 3.3.15.2 specifically excluded the Gammametrics source range instruments because they do not have any required alarm, interlock or trip setpoints.

Technical Specification 3.9.3, "Nuclear Instrumentation," requires two source range neutron flux monitors to be OPERABLE in MODE 6 to provide a signal to alert the operator to unexpected changes in core reactivity such as an improperly loaded fuel assembly. This specification only requires a CHANNEL CHECK and CHANNEL CALIBRATION. There is not a CHANNEL OPERATIONAL TEST surveillance requirement.

Attachment Ill to WM 16-0005 Page 4 of 5

6. The TR 3.3.19 Bases, References Section, was revised to reference Addendum 4 to WCAP-12472-P-A, "BEACON Core Monitoring and Operations Support System." The BEACON Power Distribution Monitoring System software was updated from BEACON Version 6 to BEACON Version 7 which incorporates the methodology of WCAP-12472-P-A, Addendum 4. The BEACON Power Distribution Monitoring System is used for periodic measurement of the core power distribution to confirm operation within design limit, and periodic calibration of the excore detectors. The update of the BEACON PDMS software from BEACON Version 6 to BEACON Version 7 is consistent with the NRC approved WCAP-12472-P-A, Addendum 4.

7. TR 3.3.16, "Explosive Gas Monitoring Instrumentation" and associated TR Bases were revised to include a new Condition to restore a required nonfunctional channel to FUNCTIONAL status in 30 days. This results in the re-lettering of existing Conditions B and C. Existing Condition D is deleted and Condition F is revised as the default for Conditions B, C, D or E. Table TR 3.3.16-1 Note (b) was revised to clarify that number of required channels is only applicable to the recombiner aligned to the waste gas flowpath.

Condition G is deleted to eliminate the submittal of a Special Report. The minimum set of conditions required by law to be reported to the NRC are contained in the Code Of Federal Regulations (10 CFR 50.73, 10 CFR 50.72, 10 CFR 73, etc.). This TRM special report is not required by the CFRs, and there is no regulatory basis for this special report.

There are no Technical Specification actions, regulation, license condition, order, or commitment that requires this TRM special report. NRC Office Letter 807, "Contror of Licensing Basis for Operating Reactors," notes in its description of the TRM that "some relocated TS provisions included special reporting requirements and the determination that the special reports were not required was inherent in the staffs findings that the provisions could be relocated." This clearly indicates the regulatory acceptability of the elimination of this special report from the TRM. Based on the above, this TRM special report is only an administrative requirement and therefore it is deleted.

CR 93034 questioned the need for a separate Condition for restoring a nonfunctional channel to FUNCTIONAL status. Revision 3 to the TRM occurred in conjunction with the conversion to ITS. The TRM and associated Bases were reformatted to be consistent with the ITS. A review of the TRM prior to being reformatted was conducted to determine if the reformatting encompassed the original requirements. The changes were made consistent with the requirements that existed prior to Revision 3 of the TRM.

8. TR Bases page B 3. 7.13-1 was revised to reflect that a loss of offsite power does not have to be assumed coincident with a single failure when the unit is shutdown (i.e.,

MODES 5 and 6 and during movement of irradiated fuel assemblies). This is consistent with the license amendment request submitted by letter WO 11-0008 and Amendment No.

200 and USAR Section 3.1.2.

Attachment Ill to WM 16-0005 Page 5 of 5

9. TR 3.6.1 Bases, Required Actions A.1 and A.2 and B.1 and B.2 were revised to refer to the Containment lnservice Inspection Program Plan (WCRE-22) for guidance on use of ASME Form OAR-1 for reporting containment vessel abnormal degradation instead of referring to Code Case N-532. When a licensee uses a Code Case initially in the Interval, 10 CFR 50.55a requires that the most recent version of the Code Case approved by reference be implemented. Code Case N-532 is utilized for the Summary Report required by IWA-6000. Code Case N-532-5 is the most recent version approved in Regulatory Guide 1.147 and is utilized in conjunction with the ISi and Repair and Replacement Programs. In lieu of referencing the specific revision of the Code Case in TR 3.6.1 Bases, the Containment lnservice Inspection Program Plan (WCRE-22) is being referenced as Section 3.1.1 specifies Code Cases being utilized and lists Code Case N-532-5.

10. TRM page B 3.4.17-8 was revised to change the reference from 10 CFR 50.55a(a)(3) to 10 CFR 50.55a(z). On November 5, 2014, the NRC published in Federal Register Vol.

79, No. 214, pages 65776 through 65814, a revision to 10 CFR 50.55a. This revision resulted in the relocation of alternative provisions from 10 CFR 50.55a(a)(3) to 10 CFR 50.55a(z). *

11. TR Bases page B 3.4.17-1 is revised to refer to NRC Inspection Manual Chapter 0326 instead of RIS 2005-20. Revision 59 revised pages in TR B 3.4.17 to refer to NRC Inspection Manual Chapter 0326 instead of RIS 2005-20. The change to page B 3.4.17-1 was overlooked.

12. TRM Section TR 3.7.20, "Snubbers", and associated Bases were revised to address changes required due to the Snubber Program implementing the ASME OM Code, Subsection ISTA and ISTD, for snubber visual examinations and functional testing during the 4th 10-Year lnservice Testing Interval. Previously, the Snubber Program utilized a Relief Request to use the TRM alone to control the Snubber Program. The changes that were made to the TRM are to make the TRM consistent with the requirements of the ASME OM Code. Additional detail is also located in WCOP-02, "Snubber Examination, Testing, and Service Life Monitoring Program Plan - Fourth 10-Year lnservice Testing Interval," and Procedure AP 29A-006, "Snubber Program". Also, TR 3.7.20 Conditions B and C and Table TR 3.7.20-5 were revised to address Condition Report 95302 concerning the use of "No Mode" for the Applicable Modes for LCO 3.0.8 Applicability for certain Snubber locations. This revision replaced "No Mode" with "Non TS" since the affected snubber locations are attached to piping that is not associated with a Technical Specification.

Enclosure I to WM 16-0005 Page 1 of 2 Enclosure I to WM 16-0005 CD-ROM containing Updated Safety Analysis Report, Revision 29

Enclosure I to WM 16-0005 Page 2 of 2 Subject Enclosed is the CD-ROM submittal of the Wolf Creek Generating Station Updated Safety Analysis Report (WCGS USAR), Revision 29. In accordance with 10 CFR 2.390, WCGS USAR Chapters 2, 3, 8, 9, and 12 contain sensitive unclassified information and therefore warrant withholding.

Contact Name Lucille Stone Mailing Address Wolf Creek Nuclear Operating Corporation P.O. Box 411 Burlington, KS 66839 E-Mail Address lurocke@wcnoc.com Phone Number 620-364-8831 ext. 4898 Document Components:

The CD-ROM labeled "Wolf Creek Generating Station Updated Safety Analysis Report, Rev.29" contains the following files:

001_USAR.pdf 268 KB, sensitive unclassified information 002_USARC01.pdf 889 KB, publicly available 003_USARC02.0.pdf 34. 7 MB, sensitive unclassified information 004_USARC02 Figures.pdf 36.0 MB, sensitive unclassified information 005_USARC03.pdf 16.6 MB, sensitive unclassified information 006_USARC04.pdf 2.34 MB, publicly available 007_USARC05.pdf 2.40 MB, publicly available 008_USARC06.pdf 11.5 MB, publicly available 009_USARC07.pdf 1.85 MB, publicly available 01 O_USARC08.pdf 1.87 MB, sensitive unclassified information 011_USARC09.pdf 4.53 MB, sensitive unclassified information 012_USARC10.pdf 1.43 MB, publicly available 013_USARC11.pdf 1.01 MB, publicly available 014_USARC12.pdf 814 KB, sensitive unclassified information 015_USARC13.pdf 951 KB, publicly available 016_USARC14.pdf 376 KB, publicly available 017_USARC15.pdf 6.28 MB, publicly available 018_USARC16.pdf 56 KB, publicly available 019_USARC17.pdf 64 KB, publicly available 020_USARC18.pdf 1.15 MB, publicly available 021_USARNRCQ.pdf 348 KB, publicly available 022_USAR Rev. 29-loep.pdf 401 KB, publicly available 1 to WM 16-0005 Page 1 of 2 Enclosure II to WM 16-0005 CD-ROM containing Updated Safety Analysis Report Controlled Figure Drawings

Enclosure II to WM 16-0005 Page 2 of 2 Subject Enclosed is the CD-ROM submittal of the Wolf Creek Generating Station Updated Safety Analysis Report (WCGS USAR) controlled figure drawings that are considered incorporated by reference into the WCGS USAR. In accordance with 10 CFR 2.390, this enclosure is considered sensitive unclassified information and therefore warrants withholding.

Contact Name Lucille Stone Mailing Address Wolf Creek Nuclear Operating Corporation P.O. Box 411 Burlington, KS 66839 E-Mail Address lurocke@wcnoc.com Phone Number 620-364-8831 ext. 4898 Document Components:

The CD-ROM labeled "WCGS Updated Safety Analysis Report, Rev.29 Controlled Figure Drawings Only" contains the following files:

001_Chapter 1.pdf 15.4 MB, sensitive unclassified information 002_Chapter 2.pdf 4.87 MB, sensitive unclassified information 003_Chapter 5.pdf 1.56 MB, sensitive unclassified information 004_Chapter 6.pdf 3.56 MB, sensitive unclassified information 005_Chapter 7.pdf 1.21 MB; sensitive unclassified information 006_Chapter 8.pdf 2.48 MB, sensitive unclassified information 007_Chapter 9.pdf 25.6 MB, sensitive unclassified information 008_Chapter 10.pdf 9.40 MB, sensitive unclassified information 009_Chapter 11.pdf 4.11 MB, sensitive unclassified information 010_Chapter 12.pdf 1.16 MB, sensitive unclassified information 011_Chapter 18.pdf 178 KB, sensitive unclassified information 11 to WM 16-0005 Page 1 of 2 Enclosure 111 to WM 16-0005 CD-ROM containing Updated Safety Analysis Report Fire Hazards Analysis and Quality Program Manual 11 to WM 16-0005 Page 2 of 2 Subject Enclosed is the CD-ROM submittal of the Wolf Creek Generating Station Updated Safety Analysis Report Fire Hazards Analysis and Wolf Creek Quality Program Manual (WCQPM),

both of which are considered incorporated by reference into the WCGS USAR. In accordance with 10 CFR 2.390, the WCGS USAR Fire Hazards Analysis is considered sensitive unclassified information and therefore warrants withholding.

Contact Name Lucille Stone Mailing Address Wolf Creek Nuclear Operating Corporation P.O. Box 411 Burlington, KS 66839 E-Mail Address lurocke@wcnoc.com Phone Number 620-364-8831 ext. 4898 Document Components:

The CD-ROM labeled "WCGS USAR Fire Hazards Analysis & Quality Program Manual" contains the following files:

001_WCQPM Rev 10A.pdf 276 KB, publicly available 002_E-1 F9900 Rev 9.pdf 3.03 MB, sensitive unclassified information 003_E-1 F9905 Rev 6.pdf 1.42 MB, sensitive unclassified information 004_E-1 F9910 Rev 14.pdf 20.8 MB, sensitive unclassified information 005_E-1 F9915 Rev 8.pdf 1.43 MB, sensitive unclassified information 006_XX-E-013 Rev 4.pdf 3.72 MB, sensitive unclassified information 007_XX-E-013 Rev 4_CN001.pdf 595 KB, sensitive unclassified information 008_XX-E-013 Rev 4_CN 002.pdf 440 KB, sensitive unclassified information 009_XX-E-013 Rev 4_CN 003.pdf 541 KB, sensitive unclassified information 010_M-663-00017A W05 1 to B1-98.pd 23.7 MB, sensitive unclassified information 011_M-663-00017A W05 B1-99 to B2-40.pdf 31.7 MB, sensitive unclassified information 012_M-663-00017A W05 B2-41 to B6-2.pdf 49.5 MB, sensitive unclassified information 013_M-663-00017A W05 B6-3 to B7-79.pdf 28.3 MB, sensitive unclassified information 014_M-663-00017A W05 B7-80 to B8-147.pdf 45.3 MB, sensitive unclassified information 015_M-663-00017A W05 B8-148 to B13-25.pdf 33.9 MB, sensitive unclassified information 016_M-663-00017A W05 B13-26 to G1A-63.pdf 42.7 MB, sensitive unclassified information 017_M-663-00017A W05 G1A-64 to G1A-123.pdf 17.0 MB, sensitive unclassified information 018_M-663-00017A W05 G1A-124 to G2A-3.pdf 15.7 MB, sensitive unclassified information 019_M-663-00017A W05 G2B-1 to G2B79.pdf 18.8 MB, sensitive unclassified information 020_M-663-00017A W05 Att G3 to G3D-26.pdf 22.0 MB, sensitive unclassified information 021_M-663-00017A W05 G3D-27 to G4D-19.pdf 20.6 MB, sensitive unclassified information 022_M-663-00017A W05 Att G5 to Att H.pdf 20.0 MB, sensitive unclassified information

Enclosure IV to WM 16-0005 Page 1 of 2 Enclosure IV to WM 16-0005 CD-ROM Containing Updated Safety Analysis Report EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II

Enclosure IV to WM 16-0005 Page 2 of 2 Subject Enclosed is the CD-ROM submittal of the Wolf Creek Generating Station Updated Safety Analysis Report EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II, both of which are considered incorporated by reference into the WCGS USAR. In accordance with 10 CFR 2.390, the WCGS EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II, is considered sensitive unclassified information and therefore warrants withholding.

Contact Name Lucille Stone Mailing Address Wolf Creek Nuclear Operating Corporation P.O. Box 411 Burlington, KS 66839 E-Mail Address lurocke@wcnoc.com Phone Number 620-364-8831 ext. 4898 Document Components:

The CD-ROM labeled "EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II" contains the following files:

001_EQSD-I Rev 9.pdf 13.5 MB, sensitive unclassified information 002_EQSD-ll Rev 27.pdf 1.30 KB, sensitive unclassified information

Enclosure V to WM 16-0005 Page 1 of 1 Enclosure V to WM 16-0005 Technical Requirements Manual Replacement Pages and List of Effective Pages (49 Pages)

TECH REQUIREMENTS MANUAL REVISION: 62 TECHNICAL REQUIREMENTS MANUAL Wolf Creek Generating Station, Unit 1 Summary of _Revision 62: Released: DC12 10/26/2015

1. TR B 3.6.1 Required Actions A.1 and A.2 and B.1 and B.2 are being revised to refer to the Containment lnservice Inspection Program Plan (WCRE-22) for guidance on use of ASME Form OAR-1 for reporting containment vessel abnormal degradation instead of referring to Code Case N-532. In lieu of referencing the specific revision of the Code Case in TR B 3.6.1, the Containment lnservice Inspection Program Plan (WCRE-22) is being referenced*as Section 3.1.1 specifies Code Cases being utilized and lists Code Case N-532-5.

2. TRM page B 3.4.17-8 is revises the reference to 10 CFR 50.55a(a)(3) to 10 CFR 50.55a(z). On November 5, 2014, the NRC published in Federal Register Vol. 79, No. 214, pages 65776 through 65814, a revision to 10 CFR 50.55a. This revision resulted in the relocation of alternative provisions from 10 CPR 50.55a(a)(3) to 10 CFR 50.55a(z).

3. TR Bases page B 3.4.17-1 is revised to refer to NRC Inspection Manual Chapter 0326 instead of RIS 2005-20.

4. TRM Section TR 3.7.20, "Snubbers", and associated Bases are being revised to address changes required due to the Snubber Program implementing the ASME OM Code, Subsection ISTA and ISTD, for snubber visual examinations and functional testing during the 4th 10-Year lnservice Testing Interval.

Previously, the Snubber Program utilized a Relief Request to use the TRM alone to control the Snubber Program. The changes that are being made to the TRM are to make the TRM consistent with the requirements of the ASME OM Code. Additional detail will also be located in WCOP-02, "Snubber Examination, Testing, and Service Life Monitoring Program Plan - Fourth 10-Year lnservice Testing Interval," and Procedure AP 29A-006, "Snubber Program." Also, TR 3.7.20 Conditions Band C and Table TR 3:7.20-5 is being revised to address Condition Report 95302 concerning the use of "No Mode" for the Applicable Modes for LCO 3.0.8 Applicability for certain Snubber locations. This revision has replaced "No Mode" with "Non TS" since the affected snubber locations are attached to piping that is not associated with a Technical Specification.

TABLE OF CONTENTS TR3.7 PLANT SYSTEMS (continued) ............................................................ .

TR 3.7.21 Sealed Source Contamination .......................................................3.7-29 TR 3.7.22 Area Temperature Monitoring ........................................................3.7-32 TR 3.7.23 Intentionally Blank ..........................................................................

TR 3.7.24 Electrical Penetration Room Coolers ............................................. 3.7-35 TR3.8 ELECTRICAL POWER SYSTEMS ....................................................... .

TR 3.8.1 Offsite Power System-Transmission Network ............................3.8-1 TR 3.8.2 Intentionally Blank ................................................................... .

TR 3.8.3 Intentionally Blank ................................................................... .

TR 3.8.4 Intentionally Blank ....................................................................

TR 3.8.5 Intentionally Blank ....................................................................

TR 3.8.6 Intentionally Blank ....................................................................

TR 3.8.7 Intentionally Blank ................................................................... .

TR 3.8.8 Intentionally Blank ................................................................... .

TR 3.8.9 Intentionally Blank ................................................................... .

TR 3.8.10 Intentionally Blank ................................................................... .

TR 3.8.11 Containment Penetration Conductor Overcurrent Protective Devices ...................................................................3.8-2 TR3.9 REFUELING OPERATIONS ................................................................. .

TR 3.9.1 Intentionally Blank ....................................................................

TR 3.9.2 Intentionally Blank .......................*...........................*................

TR_3.9.3 Intentionally Blank ...............................................................*....

TR 3.9.4 Intentionally Blank ................................................................... .

TR 3.9.5 Intentionally Blank ................................................................... .

TR 3.9.6 Intentionally Blank ................................................................... .

TR 3.9.7 Refueling Pool Water Level ...........................................................3.9-1 TR 3.9.8 Intentionally Blank ................................................................... .

TR 3.9.9 Refueling Machine ***************************************************~*********************3.9-2 TR 3.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING TR 3.10.1 Liquid Holdup Tanks ......................................................................3.10-1 TR 3.10.2 Waste Gas Holdup System - Explosive Gas Mixture .................... 3.10-3 TR 3.10.3 Gas Storage Tanks ........................................................................3.10-5 TR 3.11 NOT USED TR4.0 NOT USED TR5.0 ADMINISTRATIVE TR5.1 Intentionally Blank ................................................................... .

TR5.2 Organization ...................................................................................5.0-1 TR5.3 Intentionally Blank ................................................................... .

TR 5.4 Intentionally Blank ................................................................... .

TR5.5 Programs ......................................................*.................................5.0-3 TR5.6 Reporting Requirements ................................................................5.0-6 TR5.7 Intentionally Blank ....................................................................

TR5.8 Training ..........................................................................................5.0-7 Wolf Creek - Unit 1 iii Revision 62

Source Range Neutron Flux TR 3.3.15 TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.15.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months TSR 3.3.15.2 Not Used.

TSR 3.3.15.3 ---------NOTE--------------

Neutron detectors may be excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 18 months Wolf Creek - Unit 1 - TRM 3.3-23 Revision 60

Explosive Gas Monitoring Instrumentation TR 3.3.16 3.3 INSTRUMENTATION 3.3.16 Explosive Gas Monitoring Instrumentation TR 3.3.16 The Waste Gas Holdup System explosive gas monitoring instrumentation channels in Table TR 3.3.16-1 shall be FUNCTIONAL with Alarm/Trip setpoints set to ensure the limits of TR 3.10.2 are not exceeded.

APPLICABILITY: During Waste Gas Holdup System operation.

ACTIONS

NOTE------------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A One or more explosive A.1 Declare affected Immediately monitoring instrumentation channel(s) nonfunctional.

channels with Alarm/Trip setpoint less conservative than required.

B. Any required channel B.1 Restore required channel 30 days nonfunctional. to FUNCTIONAL status.

c. Required Hydrogen C.1 Suspend oxygen supply to Immediately Monitor channel the recombiner.

nonfunctional.

D. Required Outlet Oxygen D.1 Analyze grab samples Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Monitor channel during addition of waste nonfunctional. gas.

(continued)

Wolf Creek - Unit 1 - TRM 3.3-24 Revision 61

Explosive Gas Monitoring Instrumentation TR 3.3.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Both required Oxygen E.1 Suspend oxygen supply to Immediately Monitor channels the recombiner.

nonfunctional.

AND OR E.2 Analyze grab sample Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Required Inlet Oxygen during additions of waste during degassing Monitor channel and Inlet gas. operations Hydrogen Monitor channel nonfunctional. OR Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months during other operations F. Required Action and F.1 Suspend operation of Immediately associated Completion Waste Gas Holdup Time of Condition 8, C, D, System.

or E not met.

TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.16.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months TSR 3.3."16.2 Perform COT. 31 days (continued)

Wolf Creek - Unit 1 - TRM 3.3-25 Revision 61

Explosive Gas Monitoring Instrumentation TR 3.3.16 TECHNICAL SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.3.16.3 Perform CHANNEL CALIBRATION. 92 days Wolf Creek- Unit 1 - TRM 3.3-26 Revision 51 I

Explosive Gas Monitoring Instrumentation TR 3.3.16 Table TR 3.3.16-1 Explosive Gas Monitoring Instrumentation TECHNICAL REQUIRED SURVEILLANCE INSTRUMENT CHANNELS (bl REQUIREMENTS

1. Hydrogen Monitor <al 1 TSR 3.3.16.1 TSR 3.3.16.2 TSR 3.3.16.3

2. Inlet Oxygen Monitor 1 TSR 3.3.16.1 TSR 3.3.16.2 TSR 3.3.16.3

3. Outlet Oxygen Monitor 1 TSR 3.3.16.1 TSR 3.3.16.2 TSR 3.3.16.3 (a) Either the Inlet Hydrogen Monitor or the Outlet Hydrogen Monitor.

(b) The number of required channels is only applicable to the recombiner aligned to the waste gas flowpath.

Wolf Creek - Unit 1 - TRM 3.3-27 Revision 61

Reactivity Control and Power Distribution Alarms TR 3.3.17 3.3 INSTRUMENTATION 3.3.17 Reactivity Control and Power Distribution Alarms

TR 3.3.17 The following annunciator alarms shall be FUNCTIONAL:

a. AXIAL FLUX DIFFERENCE (AFD);

b. Rod Insertion Limit;

c. Rod Position Deviation; and

d. QUADRANT POWER TILT RATIO (QPTR).

APPLICABILITY: According to Table TR 3.3.17-1.

ACTION$.

=.-----NOTE-------------------------------------------

Separate Condition entry is allowed for each alarm.

CONDITION REQUIRED ACTION COMPLETION TIME A. AFD Alarm is A.1 Perform Technical . Once per hour nonfunctional. Specification Surveillance Requirement (SR) 3.2.3.1.

8. Rod Insertion Limit Alarm 8.1 Perform Technical Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months nonfunctional. Specification SR 3.1.6.2.

C. Rod Position Deviation C.1 Perform Technical Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Alarm nonfunctional. Specification SR 3.1.4.1.

(continued)

Wolf Creek - Unit 1 TRM 3.3-28 Revision 55

Snubbers TR 3.7.20

3. 7 PLANT SYSTEMS 3.7.20 Snubbers TR 3.7.20 Snubbers listed in Table TR 3.7.20-5 shall be FUNCTIONAL.

APPLICABILITY: According to Table TR 3.7.20-5.

ACTIONS

NOTE------------------------------------------------

Separate Condition entry is allowed for each affected snubber.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more non-LCO A.1 Declare the TS supported Immediately 3.0.8 applicable snubber(s) system inoperable and nonfunctional. declare the affected LCO(s) not met.

(continued)

WoWCraek-Unlt1-TRM 3.7-9 Revision 50

Snubbers TR 3.7.20 ACTION (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more LCO 3.0.8 8.1 Restore the snubber(s) to Consistent with TS applicable snubber(s) FUNCTIONAL status. LCO 3.0.8 nonfunctional.

OR B.2 Declare the TS supported Prior to expiration system inoperable and of TS LCO 3.0.8 declare the affected Completion Time LCO(s) not met.

C. One or more non-TS C.1 Restore the snubber to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months snubber nonfunctional. FUNCTIONAL status.

TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.20.1 Perform visual inspections of each required snubber In accordance with in accordance with Table TR 3.7.20-2. Table TR 3.7.20-3 (continued)

Wolf Creek - Unit 1 - TRM 3.7-10 Revision 62

Snubbers TR 3.7.20 TECHNICAL SURVEILLANC.E REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TSR 3.7.20.2 --------~------------------NOTE------------------------------

This surveillance shall begin no earlier than 60 days before a scheduled refueling outage.

Perform a functional test on a represent~tive sample Once each of each type of snubber in accordance with Table TR refueling 3.7.20-4.

TSR 3.7.20.3 Verify that the service life of mechanical snubbers is In accordance with not exceeded in accordance with Snubber Service Snubber Service Life Program. Life Program TSR 3.7.20.4 Perform an inspection of all required snubbers Within 6 months attached to sections of systems that have following the event experienced an unexpected potentially damaging transient in accordance with Table TR 3.7.20-1.

Wolf Creek - Unit 1 - TRM 3.7-11 Revision 62

Snubbers TR 3.7.20 Table TR 3.7.20-1 Transient Event Inspection

1. An inspection shall be performed of all snubbers attached to sections of systems that have experienced unexpected, potentially damaging transients as determined from a review of operational data and a visual inspection of the systems within 6 months following such an event.

2. In addition to satisfying the visual inspection acceptance criteria, freedom-of-motion of mechanical snubbers shall be verified using at least one of the following:

a) Manually induced snubber movement; or b) Evaluation of in-place snubber piston setting; or c) Stroking the mechanical snubber through its full range of travel.

Wolf Creek- Unit 1 - TRM 3.7-12 Revision 50 I

Snubbers TR3.7.20 Table TR 3.7.20-2 Visual Inspections

1. Schedule

a. Snubbers are categorized as inaccessible or accessible during reactor operation.

Each of these categories (inaccessible and accessible) may be inspected independently according to the schedule determined by Table TR 3.7.20-3.

b. The visual inspection interval for each type of snubber shall be determined based upon the criteria provided in Table TR 3.7.20-3.

2. Acceptance Criteria

a. Visual inspections shall verify that:

1) There are no visible indications of damage or impaired FUNCTIONALITY,

2) Attachments tO the foundation or.supporting structure are functionaCand *.

3) Fasteners for attachment of the snubber to the component and to the snubber anchorage are functional.

b. Snubbers which appear inoperable as a result of visual inspections shall be classified as unacceptable and may be reclassified acceptable for the purpose of establishing the next visual inspection interval, provided that:

1) The cause of the rejection is clearly established and remedied for that particular snubber and for other snubbers, irrespective of type, that may be generically susceptible; and

2) The affected snubber is functionally tested in the as-found condition and determined FUNCTIONAL per Table TR 3.7.20-4, section 4.

3) A review and evaluation shall be performed and documented to determine system OPERABILITY/FUNCTIONALITY with an unacceptable snubber. If OPERABILITY/FUNCTIONALITY can not be justified, the system shall be declared inoperable and the applicable Technical Specification LCO or Technical Requirements Manual TR shall be considered not met.

Wolf Creek - Unit 1 - TRM 3.7-13 Revision 62

Snubbers TR 3.7.20 Table TR 3.7.20-3 (Page 1 of 2)

Snubber Visual Inspection Interval NUMBER OF UNACCEPTABLE SNUBBERS POPULATION COLUMN A COLUMN 8 COLUMN C OR CATEGORY<a> EXTEND INTERVAL(b(cH9> REPEAT REDUCE TO 2/3 INTERVAL(b)(d)(e) INTERVAL(b)(e)(f) 1 0 0 1 80 0 0 2 100 0 1 4 150 0 3 8 200 2 5 13 300 5 12 25 400 8 18 36 500 12 24 48 750 20 40 78

~ 1000 29 56 109 (a) Interpolation between population or category sizes and the number of unacceptable snubbers is permissible.

The next lower integer shall be used when interpolation results in a fraction.

(b)* The basic interval shall be the normal fuel cycle up to 24 months. The examination interval may be as great as twice, the same, or as small as fractions of the previous interval as required by the following Notes. The examination interval may vary

+/-25% of the current interval.

(c) If the number of unacceptable snubbers is equal to or less than the number in Column A, then the next examination interval may be increased to twice the previous examination interval, not to exceed 48 months. In that case, the next examination according to the previous interval may be skipped.

(d) If the number of unacceptable snubbers exceeds the number in Column A, but is equal to or less than the number in Column B, then the next visual examination shall be conducted at the same interval a.$ the previous interval.

Wolf Creek - Unit 1 - TRM 3.7-14 Revision 62

Snubbers TR 3.7.20 Table TR 3.7.20-3 (Page 2 of 2)

Snubber Visual Inspection Interval (e) If the number of unacceptable snubbers exceeds the number in Column B, but is equal to or less than the number in Column C, then the next examination interval shall be decreased to two-thirds of the previous examination interval or, in accordance with the interpolation between Columns B and C, in proportion to the exact number of unacceptable snubbers.

(f) If the number *of unacceptable snubbers exceeds the number in Column C, then the next examination interval shall be decreased to two-thirds of the previous interval.

(g) The visual inspection interval may be extended in accordance with Code Case OMN-13.

Wolf Creek- Unit 1 -TRM 3.7-15 Revision 62

- snubbers TR 3.7.20 Table TR 3.7.20-4 (Page 1 of 2)

Functional Tests

1. A representative sample of snubbers of each type shall be tested using the following sample plan.

a. At least 10% of the total. of each type of snubber shall be functionally tested either in-place or .in a bench test. For each snubber of a type that does not meet the functional test acceptance criteria of section 4 of this Table, an additional 5%

of that type of snubber shall be functionally tested from the Defined Test Plan Groups (DTPG) or Failure Mode Group (FMG) until ho more failures are found or until all snubbers of that type have been functionally tested.

2. If during the functional testing, additional testing is required due to failure of snubbers, the unacceptable snubbers may be categorized into failure mode group(s). A failure mode group shall include all unacceptable snubbers that have a given failure mode and all other snubbers subject to that same failure mode. Once a failure mode group has been established, it can be separated for continued testing apart from the general population of snubbers. Testing in the failure mode group shall be based on the number of unacceptable snubbers and shall continue in accordance with the sample plan selected for the type or until all snubbers in the failure mode group have been tested.

Any additional unacceptable snubbers found in the failure mode group shall be counted for continued testing only for that test failure mode group. In the event that a snubber(s) becomes included in more than one test failure mode group, it shall be counted in each failure mode group and shall be subject to the corrective action of each test failure mode group.

3. Testing equipment failure during functional testing may invalidate that day's. testing and allow that day's testing to resume anew at a later time provided all snubbers tested with the failed equipment during the day of equipment failure are re-tested. The representative sample selected for the functional test sample plans shall be representative of each type and reviewed before beginning the testing. The review shall ensure, as far as practicable, that they are representative of the various configurations, operating environments, range of size, and capacity of snubbers of each type. Snubbers placed iq the same _location as snubbers which failed the previous functional test shall be re-tested at the time of the next functional test but shall not be included in the sample plan.

4. Functional Test Acceptance Criteria The snubber functional test shall verify that:

a. Activation (restraining action) is achieved within the specified range in both tension and compression; (continued)

Wolf Creek - Unit 1 - TRM 3.7-16 Revision 62

Snubbers TR 3.7.20 Table TR 3.7.20-4 (Page 2 of2)

Functional Tests

b. For mechanical snubbers, the force required to initiate or maintain motion of the snubber is within the specified range in both directions of travel.

Testing methods may be used to measure parameters indirectly or parameters other than those specified if those results can be correlated to the specified parameters through established methods.

5. Functional Test Failure Analysis

a. An engineering evaluation shall be made on each required snubber which fails to meet the functional test acceptance criteria to determine the cause of the failure.

The results of this evaluation shall be used, if applicable, in selecting snubbers to be tested in an effort to determine the FUNCTIONALITY of other snubbers irrespective of type which may be subject to the same failure mode.

b. When a required snubber is found nonfunctional, an engineering evaluation shall be performed on the component(s) to which the inoperable snubber is attached.

The purpose of this engineering evaluation shall be to determine if the component(s) to which the nonfunctional snubber is attached is adversely affected by the nonfunctionality of the snubber (i.e. whether the component remains capable of performing its required function).

c. When a required snubber being functionally tested either fails to lock up or fails to move, i.e., frozen-in-place, the cause of this failure will be evaluated. If this failure is determined to be caused by manufacturer or a design deficiency, all snubbers of the same type subject to the same defect shall be functionally, tested. These additional snubbers shall be tested independent of those initially chosen to be inspected during the present interval.

6. Functional Testing of Repaired and Replaced Snubbers Snubbers which have failed to meet either the visual inspection or the functional test acceptance criteria shall be repaired or replaced. Replacement snubbers and snubbers which have repairs which might affect the functional test results shall be tested to meet the functional test criteria before installation in the unit. Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service, and the freedom-of-motion test must have been performed within 12 months prior to being installed in the plant.

Wolf Creek - Unit 1 - TRM 3.7-17 Revision 62 I

Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 1 of 11)

Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABIUTY<a>

AB01 R001251 1,2,3,4,5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AB01 R003252 1,2,3,4,5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AB01 R014145 1, 2, 3, 4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AB01 R036145<bl 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AB01R504145 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB01 R508145 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB01R512145 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB01R516145 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08C510145 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08C524145 1,2,3,4, 5 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s*-

AB08C532145 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08C534145 1,2,3,4,5 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s*

AB08R510145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R512145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R514145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R515145 1,2, 3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R516145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R517145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R518145 1, 2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R520145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R522145 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R523145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R524145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R525145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R526145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R527145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R528145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)

(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable

- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable

- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-18 Revision 62

Snubbers TR 3.7.20 Table TR 3.7.20..:5 (Page 2of11)

Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY<al AB08R529145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R530145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R531145 . 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R532145(bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R533145(bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AE04R014252(bl 1,2, 3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R017242 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R018242 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R019251 (bl 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R021241 1,2,3,4, 5 N/A for Modes: 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R022241 1,2,3,4,5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R501145(bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AE04R502145(bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AE05R017242(bl 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE05R028241 (bl 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE05R501145<bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AE05R502145(bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AL02R009135 1, 2, 3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AL02R010135 1, 2, 3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AL03R005135 1,2,3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AL03R011135 1, 2, 3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 8801 R004231 1, 2, 3 N/A 8802R002261 1, 2, 3 N/A 8802R005261 1, 2, 3 NIA (continued)

(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable

- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable

- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek- Unit 1 - TRM 3.7-19 Revision 62

Snubbers TR 3.7.20 Table TR 3.7.20_.5 (Page 3of11)

Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY(al BB02R008261 1, 2, 3 NIA BB02R010251 1,2,3 NIA BB02R012261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB02R014261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB02R015261 (bl 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB02R016261 (bl 1,2,3 NIA BB02R021261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB02R025261 (bl 1,2,3 NIA BB02R027261 1, 2, 3 NIA BB02R034261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB03C017231-* 1,2,3,4,5,6 NIA for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6

~ BB03R005242 Non TS NIA BB03R008231 1,2,3,4,5,6 NIA for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 BB03R016251 (bl 1,2,3 NIA BB03R024231(bl 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB03R025231 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB03R030231 (bl 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6

BB04R001232 1, 2, 3 NIA BB04R00.5241 1, 2, 3 NIA BB04R017261 1, 2, 3 NIA BB04R026261 1, 2, 3 NIA (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC- TS LCO 3.0.8.b is applicable
- NIA - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not rnet as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-20 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 4of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY(a>
BB04R044232 1, 2, 3 N/A BB09R509231 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BB12R508232 Non TS N/A BB13R520241 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BB13R521241 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB 13R522241 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R523261 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R524261 (bl 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R525261 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R526261(bl 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R527261 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R528261 (b) 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R531261 1, 2, 3, 4, 5,_6 N/A for Modes 1-4 * .. .- ...-.::
~ *l 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB 13R544241 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB16R001232 Non TS N/A BG01 R006124(b) 1,2,3,4, 5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG01R014132 Non TS NIA I BG01R018134 1,2,3,4,5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG02R015111 1,2,3,4,5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG02R016111(bl 1,2,3,4, 5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG02R017121 1,2, 3,4, 5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG03R018133 1, 2, 3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG05C532131 Non TS N/A BG05R014132 Non TS. N/A BG05R019132 Non TS N/A BG09R515133 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG09R519133 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG09R530133(bl 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG09R531133(bl 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG09R532133(b) 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-21 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 5of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY(a>
BG09R533133 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG15R009132 Non TS N/A BG16R005112 1,2,3,4,5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG16R006112 Non TS N/A BG17R510112 Non TS N/A BG17R514112 Non TS N/A BG17R517122(b) Non TS N/A BG17R518122(b) Non TS N/A BG20C51 0142(b) Non TS N/A BG21R011231 1,2,3,4, 5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BG21R013231 1,2,3,4,5,6 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BG21 R017231 1,2,3,4, 5,6 NIA for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 BG21R018231 1,2,3,4,5,6 N/A for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 BG21 R020231 1,2,3,4,5,6 NIA for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 BG21 R023242(c) 1,2,3,4, 5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG21 R024242(c) 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG22R004232(b) Non TS N/A BG22R006232 Non TS N/A BG22R025231 (cl 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG23COO 1232(b) 1, 2,3,4, 5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG23R007231 1, 2,3,4, 5,6 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BG23R011231(b) 1,2,3,4,5,6 N/A for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers (c) 3 snubbers Wolf Creek - Unit 1 - TRM 3.7-22 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 6of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY<a>
BG24R003261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BG24R005261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BG24R014231 1,2,3,4,5,6 NIA for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 BG25R504231 Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG26C511242 Non TS NIA BG26R503242 Non TS NIA BG26R505242 Non TS NIA BG26R507242 Non TS NIA BL03R002232Cb> Non TS NIA BL03R003232 Non TS NIA BM01 C015231 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM01 C020231 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM01C023231 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM02C017232 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM02C020232 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM02R003232Cb> 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM02R012232 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM02R014232 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5
BM02R016232Cb>. 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM17R509231 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- NIA - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-23 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 7of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY<a>
BM17R516251 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM17R519231 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BM18C504252 1,2,3,4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM18C508232 1, 2, 3, 4, *5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM18R502252 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM18R506232 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM18R513232<bl 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BM19R503232<bl 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM19R514232 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BM19R515232 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BM20R507231 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM20R511231 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BN01R010123<c> Non TS NIA BN01 R011123<c> Non TS NIA BN02C010021 (bl Non TS NIA EC04R002611 (bl Non TS NIA EC04R011611<bl Non TS NIA EC04R022611 (bl Non TS NIA EC04R023611 (bl Non TS NIA EC04R033611 (bl Non TS NIA
"(continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- NIA - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers (c) 3 snubbers Wolf Creek - Unit 1 - TRM 3.7-24 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 8of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY(al EC04R034611 Non TS N/A EC04R038611 Non TS N/A EC06R504621 (bl Non TS N/A EF03R016142 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF03R019122 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF03R022124 1, 2, 3,4 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s:
EF03R023112(b) 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF03R032144(bl 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF03R034112(bl 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF05R018111 1, 2, 3, 4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF05R028143 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF06R016114(b) 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF14R003341
1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EG03R013141(bl 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EG03R014141 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EG04R011131<bl 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EG07R009134 1,2, 3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG07R026134 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG07R027134 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG07R02S 134 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG08R013151(bl Non TS NIA EG11 R005231 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG11R501241 Non TS N/A EG14R004232 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG15R002232(bl 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG24R018111 (bl 1,2,3,4, 5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EJ01 R020132(b) 1,2,3,4,5,6
72hours EJ01 R022132(bl 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek- Unit 1 - TRM 3.7-25 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 9of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY<a>
EJ02R020131 Cb) 1,2,3,4, 5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EJ02R024131 1,2,3,4,5,6 72 .hours EJ02R035123 1,2,3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ03C007111 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ03R006131Cb> 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ03R015111 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ03R511111 1, 2, 3, 4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ03R512123 Non TS N/A EJ04C018231 1,2,3,4,5,6 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 EJ04C020231 1,2,3,4, 5,6 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 EJ04C022231 1,2,3,4, 5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 EJ04R002232 1,2, 3,4,5,6 N/A for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 EJ04R012231 1,2,3,4, 5,6 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 EJ04R020232 1,2, 3,4,5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ07R502231 1,2,3,4, 5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EM01C013112 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM01 R011111 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM01 R017112Cb> 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM01R018112Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM01 R028112 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM01 R032111 Cb> 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM03R022231 1,2,3,4 N/A EM03R025231 1,2,3 N/A EM04C006231 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM03R024231 1, 2, 3 N/A (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- NIA - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-26 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 10of11)
Snubber List SNUBBER ID .
APPLICABLE MODES LCO 3.0.8 APPLICABILITY<a>
EM04C007231 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM05R001231 1, 2, 3 N/A EM05R010231 1, 2, 3 N/A EM05R011231 1, 2, 3 N/A EM06R504133Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM08R512112Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM08R513112 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM11 R501231 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM11 R502231 1,2,3,4,5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EM 11 R504231 Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM 11 R505231 Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM 11 R509231 (b) 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EM12R013232 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM12R029232Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM12R501232Cb> 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EM12R502232 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EN01 R007112Cb> 1,2,3,4 N/A EN02R007123<d> 1,2,3,4 N/A EN05R007241 Cb> 1,2,3,4 N/A EN05R017241 Cb) 1,2, 3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EP01C005231 1,2,3,4 N/A EP01 R005231 1,2,3,4 N/A EP01 R010231 1,2,3,4 N/A EP01R013231 1,2,3,4 N/A EP01 R016231 1,2,3,4 N/A EP02R001232 1,2,3,4 N/A EP02R008232 1,2, 3,4 N/A EP02R009232 1,2,3,4 NIA EP05R502232Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers (d) 4 snubbers Wolf Creek - Unit 1 - TRM 3.7-27 Revision 62
Snubbers TR3.7.20 Table TR 3.7.20-5 (Page 11 of 11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY(a>
EP05R503242(bl . 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EP05R505242 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EP08R506242 Non TS N/A
EP08R508242 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months FC01 R024145 1, 2, 3 N/A GN01R010252 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GN01R013231
1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GN01 R014252 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GN02R007252(b) 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GS02R506133 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GS03R506232 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GS04R501134 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GS04R503251 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months HB24R016231 1,2,3,4 N/A HB24R017231 1,2,3,4 N/A HB30R506251
Non TS N/A HE04C532111 Non TS NIA KA43C540231 Non TS N/A' KA43C541231
Non TS N/A KJ01R001511(b) 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months KJ01 R002511(b). 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months KJ01 R003511 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months KJ01 R004511 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LF05R002231 (b) Non TS N/A
LF09R004251 Non TS N/A SJ01 R502134(b) 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months SJ03R504133 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
-12 hours - Snubber supports multiple trains of SSC- TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-28 Revision -62
Sealed Source Contamination TR 3.7.21 3.7 PLANT SYSTEMS 3.7.21 Sealed Source Contamination TR 3.7.21 Removable contamination shall be < 0.005 µCi for each sealed source containing radioactive material:
a. > 100 µCi of beta and/or gamma emitting material; or
b. > 5 µCi of alpha emitting material.
APPLICABILITY: At all times.
ACTIONS

NOTE--------------------------------------_.:.__ _

Separate Condition entry is allowed for each sealed source. . .
CONDITION REQUIRED ACTION COMPLETION TIME A. ------------NOTE--------------- A.1 Remove sealed source Immediately Required Action A.3 must from use.
be completed whenever this Condition is entered. AND A.2.1 Initiate action to Immediately Sealed source decontaminate and repair contamination not within the sealed source.
limits.
OR A.2.2 Initiate action to dispose Immediately of sealed source in accordance with NRC regulations.
AND (continued)
Wolf Creek - Unit 1 - TRM 3.7-29 Revision 62 I
Sealed Source Contamination TR 3.7.21 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Initiate Condition Report 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to submit an NRC Special Report within next 12 months.
TECHNICAL SURVEILLANCE REQUIREMENTS

NOTES--------------------------------------------------

1. Tests for leakage and/or contamination shall be performed by the licensee or other persons specifically authorized by the NRC or an Agreement State.
2. The test method shall have a detection sensitivity of~ 0.005 µCi per test sample.
SURVEILLANCE FREQUENCY TSR 3.7.21.1 -=-------------------------NOTE-----------------------
Startup sources and fission detectors previously subjected to core flux are excluded.
Perform leakage and/or contamination testing for 184 days each sealed source that is in use containing radioactive material with a half-life > 30 days and in any form other than gas, excluding H3 .
(continued)
Wolf Creek - Unit 1 - TRM 3.7-30 Revision 62 I
Sealed Source Contamination TR 3.7.21 TECHNICAL SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY TSR 3.7.21.2 ------------------------NOTE-----------------------
Only required if not performed within the previous 184 days.
Perform leakage and/or contamination testing for Prior to use or each sealed source and fission detector that is stored transfer to another and not in use. licensee TSR 3.7.21.3 Perform leakage and/or contamination testing for Prior to use each sealed source or fission detector transferred without a certificate indicating the last test date.
TSR 3.7.21.4 Perform leakage and/or contamination testing for Once within 31 each sealed startup source and fission detector. days prior to being subjected to core flux Once within 31 days prior to installation in the core following repair or maintenance Wolf Creek- Unit 1 - TRM 3.7-31 Revision 62 I
Area Temperature Monitoring TR 3.7.22
3. 7 PLANT SYSTEMS 3.7.22 Area Temperature Monitoring TR 3.7.22 Area temperatures specified in Table TR 3.7.22-1 shall be within allowable temperature limit.
APPLICABILITY: At all times.
ACTIONS

N 0 TE----------------------------------------------------------

Se parate Condition entry is allowed for each temperature area.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required area A.1 Initiate Condition Report. Immediately temperatures not within allowable limit. AND A.2 Restore area 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature(s) to within allowable limit.
TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.22.1 Verify the required area temperatures specified in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Table TR 3.7.22-1 are within allowable limit.
Wolf Creek - Unit 1 - TRM 3.7-32 Revision 62 I
Area Temperature Monitoring TR 3.7.22 Table TR 3.7.22-1 (page 1 of 2)
Area Temperature Monitoring ALLOWABLE AREA TEMPERATURE (OF)
1. Essential Service Water Pump Room A :;; 119
2. Essential Service Water Pump Room B :;; 119
3. Auxiliary Feedwater Pump Room A :;; 119
4. Auxiliary Feedwater Pump Room B :;; 119
5. Turbine Driven Auxiliary Feedwater Pump Room :;; 147
6. Engineered Safety Feature Switchgear Room I :;; 87
7. Engineered Safety Feature Switchgear Room II :;; 87
8. Switchgear Room. No. 1 :;; 87
9. Switchgear Room No. 3 :;; 87
10. Switchgear Room No. 2 :;; 87
11. Switchgear Room No. 4 :;; 87
12. Battery Room No. 1 :;; 87
13. Battery Room-No. 3 :;; 87
14. Battery Room No. 2 :;; 87
15. Battery Room No. 4 :;; 87
16. Residual Heat Removal Pump Room A :;; 119
17. Residual Heat Removal Pump Room B :;; 119
18. Containment Spray Pump Room A :;; 119
19. Containment Spray Pump Room B :;; 119
20. Safety Injection Pump Room A :;; 119
21. Safety Injection Pump Room B :;; 119 (continued)
Wolf Creek- Unit 1 -TRM 3.7-33 Revision 62 I
Area Temperature Monitoring TR 3.7.22 Table TR 3.7.22-1 (page 2 of 2)
Area Temperature Monitoring ALLOWABLE AREA TEMPERATURE (OF)
22. Centrifugal Charging Pump Room A :<;; 119
23. Centrifugal Charging Pump Room B :<;; 119
24. Electrical Penetration Room A :<;; 101
25. Electrical Penetration Room B :<;; 101
26. Component Cooling Water Room A :<;; 119
27. Component Cooling Water Room B :<;; 119
28. Diesel Generator Room A :<;; 119
29. Diesel Generator Room B :<;; 119
30. Control Room :<;; 84 Wolf Creek - Unit 1 - TRM 3.7-34 Revision 62 I
Electrical Penetration Room Coolers TR 3.7.24
3. 7 PLANT SYSTEMS 3.7.24 Electrical Penetration Room Coolers TR 3.7.24 One electrical penetration room cooler shall be FUNCTIONAL for each electrical penetration room.
APPLICABILITY: At all times.
ACTIONS

NOTE-------------------------------------------------------

Separate Condition entry is allowed for each electrical penetration room cooler.
CONDITION REQUIRED ACTION COMPLETION TIME A. One electrical penetration A.1 De-energize the fan motor 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months room cooler nonfunctional of the associated room and not capable of cooler.
providing cooling.
AND A.2 Perform TSR 3.7.22.1 for 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the affected electrical penetration room. AND Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when most recently obtained room temperature exceeds 90°F
8. Required Action and 8.1 Initiate Condition Report. Immediately associated Completion Time of Condition A not met.
(continued)
Wolf Creek - Unit 1 - TRM 3.7-35 Revision 62 I
Electrical Penetration Room Coolers TR 3.7.24 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. One electrical penetration C.1 Restore electrical 7 days room cooler nonfunctional penetration room cooler to in MODE 1, 2, 3, and 4. FUNCTIONAL status.
D. One electrical penetration D.1 Restore electrical 30 days room cooler nonfunctional penetration room cooler to in MODE 5, 6, and FUNCTIONAL status.
defueled.
E. Required Actions and E.1 Initiate Condition Report. Immediately associated Completion Time of Condition C or D not met.
TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Not applicable.
Wolf Creek - Unit 1 - TRM 3.7-36 Revision 62 I
Offsite Power System- Transmission Network TR 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 Offsite Power System - Transmission Network TR 3.8.1 The following 345 kV lines connecting the unit switchyard to the offsite transmission network shall be FUNCTIONAL:
a. Wolf Creek - Waverly - LaCygne 345 kV line
b. Wolf Creek - Rose Hill 345 kV line
c. Wolf Creek - Benton 345 kV line APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One 345 kV line A.1 Verify two 345 kV lines 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months nonfunctional. are FUNCTIONAL.
B. Two 345 kV lines B.1 Enter Condition A of Immediately nonfunctional. Technical Specification LCO 3.8.1 for an inoperable offsite circuit.
TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.8.1.1 Verify correct indicated breaker alignment and power 7 days availability for each 345 kV line.
Wolf Creek - Unit 1 - TRM 3.8-1 Revision 60
Containment Penetration Conductor Overcurrent Protective Devices TR 3.8.11 3.8 ELECTRICAL POWER SYSTEMS 3.8.11 Containment Penetration Conductor Overcurrent Protective Devices TR 3.8.11 All containment penetration conductor overcurrent protective devices shall be FUNCTIONAL.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS

N 0 TE---------------------------------------------------------------

S epara te Condition entry is allowed for each overcurrent protective device.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more containment A.1.1.1 Deenergize the circuit(s) 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months penetration conductor by tripping the associated overcurrent protective backup circuit breaker.
devices nonfunctional.
A.1.1.2 Verify the backup circuit Once per 7 days breaker to be tripped.
A.1.2.1 De energize the circuits(s) 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months by racking out, locking open, or removing the nonfunctional circuit breaker or protective device.
(continued)
Wolf Creek - Unit 1 - TRM 3.8-2 Revision 4 7 I
Organization TR5.2 TR 5.0 ADMINISTRATIVE CONTROLS TR 5.2 Organization 5.2.1 Unit Staff The unit staff organization shall include the following:
a. Each on duty shift shall be composed of at least the minimum shift crew composition shown in Table TR 5.2.1-1. Table TR 5.2.1-1 identifies the minimum shift crew compliment to meet Technical Specification 5.2.2 requirements as well as staffing to plant operational requirements and staffing for a radiological emergency response. The shift crew composition may be one less than the minimum requirements of Table TR 5.2.1-1 for a period of time not to exceed two hours in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements. This provision does not permit any shift crew position to be unmanned upon shift change due to an oncoming crew member being late 'or absent. ** * * * * * ,,
b. A site Fire Brigade of at least 5 members shall be maintained onsite at all times, with an allowance to accommodate an unexpected absence(s) not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , provided immediate action is taken to fill the position(s). This provision does not permit any shift crew position to be unmanned upon shift change due to an oncoming shift crew member being late or absent. The Fire Brigade shall not include the Shift Manager, and the two other members of the minimum shift crew necessary for safe shutdown of the. Unit and any personnel required for other essential function during a fire emergency.
WoWCreek-Unlt1-TRM 5.0-1 Revision 51
Organization
TR5.2 Table TR 5.2.1-1 (page 1of1)
Minimum Shift Crew Composition NUMBER OF INDIVIDUALS REQUIRED TO FILL POSITION Technical Specification Requirements Plant Operational Requirements POSITION MODE 1, 2, 3, or4 MODE 5 or6 At All Times SM 1 1(b) 1 CRS 1 None 1 RO 2 1 2 NSO 2 1 5(c)(d)
STA 1(a) None 1(e)
CHM None None 2 HP 1 1 3 ENS Communicator None None 1 Offsite Communicator None None 1
. SM Shift Manager with a Senior Operator license on Unit 1 CRS Control Room Supervisor with a Senior Operator license on Unit 1 RO Individual with an Operator license on Unit 1 NSO Nuclear Station Operator STA Shift Technical Advisor (Shift Engineer)
CHM Chemistry Personnel HP Health Physics Personnel (a) This position shall be manned in MODES 1, 2, 3, and 4 unless the Shift Manager or the individual with a Senior Operator license meets the qualifications as required by Technical Specification 5.2.2e.
(b) One individual with a Senior Operator license, either Shift Manager or Control Room Supervisor.
(c) Individual may be a RO.
(d) One individual is designated to perform OFN KC-016/0FN KC-017, Att. E.
(e) This position shall be manned in MODES 1, 2, 3, and 4. In MODES 5 and 6, this position is not required to be filled by an individual qualified as a STA.
Wolf Creek - Unit 1 - TRM 5.0-2 Revision 59
-~ -* ~ LIST OF EFFECTIVE PAGES - TECHNICAL REQUIREMENT MANUAL PAGE< 1> REVISION NO. <2> CHANGE DOCUMENT 3
<> DATE EFFECTIVE/
4 IMPLEMENTED < >
TAB - Title Page TRM Title Page TAB- Table of Contents 43 ORR 10-3738 12/28/10 ii 35 ORR 08-0727 8/28/08 iii 54 ORR 15-2006 10/26/15 TAB-1.0 USE AND APPLICATION 1.0-1 41 ORR 10-1702 10/1/10 1.0-2 41 ORR 10-1702 10/1/10 TAB-3.0 APPLICABILTY 3.0-1 41 ORR 10-1702 10/1/10 3.0-2 41 ORR 10-1702 10/1/10 3.0-3 41 ORR 10-1702 10/1/10 3.0-4 20 ORR 04-1410 10/7/04
TAB - 3.1 REACTIVITY CONTROL SYSTEMS 3.1-1 41 ORR 10-1702 101111 o*
3.1-2 3. ORR 99-1581 12/18/99~..
3.1-3 34 ORR 08-0256 3/11/08 3.1-4 34 ORR 08-256 3/11108 3.1-5 41 ORR 10-1702 10/1/10 3.1-6 37 ORR 09-0287 3/20/09 3.1-7 41 ORR 10-1702 10/1/10 3.1-8 41 ORR 10-1702 10/1/10 3.1-9 11 ORR 02-0412 4/5/02 3.1.10 48 ORR 12-0266 2/2/12 TAB - 3.3 INSTRUMENTATION 3.3-1 41 ORR 10-1702 10/1/10 3.3-2 41 ORR 10-1702 10/1/10 3.3-3 23 ORR 05-0708 4/20/05 3.3-4 41 ORR 10-1702 10/1/10 3.3-5 41 ORR 10-1702 10/1/10 3.3-6 23 ORR 05-0708 4/20/05 3.3-7 23 ORR 05-0708 4/20/05 3.3-8 43 ORR 10-3738 . 12/28/10 3.3-9 41 ORR 10-1702 10/1/10 3.3-10 41 ORR 10-1702 10/1/10 3.3-11 39 ORR 09-1775 10/28/09 3.3-12 39 ORR 09-1775 10/28/09 3.3-13 39 ORR 09-1775 10/28/09 3.3-14 49 ORR 12-0673 4/10/12 3.3-15 39 ORR 09-1775 10/28/09 3.3-16 39 ORR 09-1775 10/28/09 3.3-17 41 ORR 10-1702 10/1/10 3.3-18 39 ORR 09-1775 10/28/09 3.3-19 51 ORR 13-0371 2/26/13 3.3-20 51 ORR 13-0371 2/26/13 3.3-21 51 ORR 13-0371 2/26/13 3.3-22 51 ORR 13-0371 2/26/13 Wolf Creek - Unit 1 Revision62
LIST OF EFFECTIVE PAGES,- TECHNICAL REQUIREMENT MANUAL PAGE<1l REVISION NO. <2l CHANGE DOCUMENT <3l DATE EFFECTIVE/
IMPLEMENTED <4l TAB- 3.3 INSTRUMENTATION (continued) 3.3-23 60 DRR 15-0529 3/26/15 3.3-24 61 DRR 15-0824 4/28/15 3.3-25 61 DRR 15-0824 4/28/15 3.3-26 51 DRR 13-0371 2/26/13 3.3-27 61 DRR 15-0824 4/28/15 3.3-28 55 DRR 14-0344 2/27/14 3.3-29 51 DRR 13-0371 2/26/13 3.3-30 56 DRR 14-1570 7/1/14 3.3-31 51 DRR 13-0371 2/26/13 3.3-32 51 DRR 13-0371 2/26/13 3.3-33 51 DRR 13-0371 2/26/13 3.3-34 51 DRR 13-0371 2/26/13 3.3-35 51 DRR 13-0371 2/26/13 3.3-36 51 DRR 13-0371 2/26/13 3.3-37 51 DRR 13-0371 2/26/13 TAB - 3.4 REACTOR COOLANT SYSTEM (RCS) 3k1 ~ DRR 09-0287 3/20/09 3.4-2 3 - DRR 99-1581 12/18/99 3.4-3 41 - DRR 10-1702 10/1/10 3.4-4 41 DRR 10-1702 10/1/10 3.4-5 3 DRR 99-1581 12/18/99 3.4-6 33 DRR 07-1554 9/28/07 3.4-7 33 DRR 07-1554 9/28/07 3.4-8 41 DRR 10-1702 10/1/10 3.4-9 41 DRR 10-1702 10/1/10 3.4-10 35 DRR 08-0729 8/28/08 TAB-3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5-1 41 DRR 10-1702 10/1/10 TAB - 3.6 CONTAINMENT SYSTEMS 3.6-1 17 DRR 04-0452 5/26/04 3.6-2 37 DRR 09-0287 3/20/09 3.6-3 17 DRR 04-0452 5/26/04 TAB - 3. 7 PLANT SYSTEMS 3.7-1 57 DRR 14-1878 9/30/14 3.7-2 28 DRR 06-1349 7/24/06 3.7-3 52 DRR 13-0658 3/28/13 3.7-4 41 DRR 10-1702 10/1/10 3.7-5 41 DRR 10-1702 10/1/10 3.7-6 41 DRR 10-1702 10/1/10 3.7-7 26 DRR 06-0050 2/28/06 3.7-8 37 DRR 09-0287 3/20/09 3.7-9 50 DRR 12-1537 8/30/12 3.7-10 62 DRR 15-2006 10/26/15 3.7-11 62 DRR 15-2006 10/26/15 3.7-12 50 DRR 12-1537 8/30/12 Wolf Creek - Unit 1 ii Revision62
LIST OF EFFECTIVE PAGES -TECHNICAL REQUIREMENT MANUAL* ' *;,.;.. . -
PAGE( 1l REVISION NO. (2l CHANGE DOCUMENT (3l DATE EFFECTIVE/
IMPLEMENTED (4l TAB- 3.7 PLANT SYSTEMS (continued) 3.7-13 62 ORR 15-2006 10/26/15 3.7-14 62 ORR 15-2006 10/26/15 3.7-15 62 ORR 15-2006 10/26/15 3.7-16 62 ORR 15-2006 10/26/15 3.7-17 62 ORR 15-2006 10/26/15 3.7-18 62 ORR 15-2006 10/26/15 3.7-19 62 ORR 15-2006 10/26/15 3.7-20 62 ORR 15-2006 10/26/15 3.7-21 62 ORR 15-2006 10/26/15 3.7-22 62 ORR 15-2006 10/26/15 3.7-23 62 ORR 15-2006 10/26/15 3.7-24 62 ORR 15-2006 10/26/15 3.7-25 62 ORR 15-2006 10/26/15 3.7-26 62 ORR 15-2006 10/26/15 3.7-27 62 ORR 15-2006 10/26/15 3.7-28 62 ORR 15-2006 10/26/15 3.7-29 62 ORR 15-2006 10/26/15 3.7-30 62 ORR 15-2006 10/26/15 3.7-31 . .. . 62 . ORR 15~2006 10/26/15.
3.7-32 62 ORR 15-2006 10/26/15 3.7-33 62 ORR 15-2006 10/26/15 3.7-34 62 ORR 15-2006 10/26/15 3.7-35 62 ORR 15-2006 10/26/15 3.7-36 62 ORR 15-2006 10/26/15 TAB - 3.8 ELECTRICAL POWER SYSTEMS 3.8-1 60 ORR 15-0529 3/26/15 3.8-2 47 ORR 11-2404 11/16/11 3.8-3 47 ORR 11-2404 11/16/11 3.8-4 47 ORR 11-2404 11/16/11 3.8-5 47 ORR 11-2404 11/16/11 TAB- 3.9 REFUELING OPERATIONS 3.9-1 3 ORR 99-1581 12/18/99 3.9-2 41 ORR 10-1702 10/1/10 3.9-3 41 ORR 10-1702 10/1/10 .
TAB - 3.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING 3.10-1 3 DRR99-1581 12/18/99
3. 10-2 37 ORR 09-0287 3/20/09 3.10-3 37 ORR 09-0287 3/20/09 3.10-4 3 DRR99-1581 12/18/99 3.10-5 37 ORR 09-0287 3/20/09 3.10-6 3 DRR99-1581 12/18/99 Wolf Creek - Unit 1 iii Revision62
LIST OF EFFECTIVE PAGES - TECHNICAL REQUIREMENT MANUAL PAGE<1> REVISION NO. <2> CHANGE DOCUMENT <>
3 DATE EFFECTIVE/
IMPLEMENTED <4>
TAB - 5.0 ADMINISTRATIVE CONTROLS 5.0-1 51 ORR 13-0371 2/26/13 5.0-2 59 ORR 15-0112 2/10/15 5.0-3 24 DRR 05-1376 6/28/05 5.0-4 41 ORR 10-1702 10/1/10 5.0-5 17 ORR 04-0452 9/28/05 5.0-6 25 ORR 05-1996 2/16/05 5.0-7 16 ORR 03-1498 11/4/03 Note 1 The page number is listed on the center of the bottom of each page.
Note 2 The revision number is listed in the lower right hand corner of each page. The Revision number will be page specific.
Note 3 The change document will be the document requesting the change. Therefore, the change document should be a ORR number in accordance with AP 26A-002.
Note 4 The date effective or implemented is the date the Technical Requirement pages are to be issued by Document Control.
Wolf Creek - Unit 1 iv Revision62
. Source* Range Neutron Flux TR B 3.3.15 BASES APPLICABILITY rods not fully inserted are addressed in Technical Specification 3.3.1, * *
(continued) "RTS Instrumentation." The requirements for the NIS source range detectors in MODE 6 are addressed in Technical Specification 3.9.3, "Nuclear Instrumentation."
ACTIONS Condition A applies to one nonfunctional required source range channel in MODE 3, 4, or 5 with the Rod Control System not capable of rod withdrawal and all control rods are fully inserted. With one of the required source range channels nonfunctional, 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months is allowed to restore it to a FUNCTIONAL status. The allowance of 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months to restore the channel to FUNCTIONAL status is consistent with the Completion Times of Technical Specification 3.3.1, Condition K.
If the nonfunctional required source range channel cannot be returned to a FUNCTIONAL status, 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is allowed to suspend all operations involving positive reactivity changes. Once the ACTIONS are completed, the core is in a more stable condition.
C.1 and C.2 Condition C applies to two nonfunctional required Source Range Neutron Flux channels when in MODE 3, 4, or 5 with the Rod Control System not capable of rod withdrawal and all control rods fully inserted. With the unit in this Condition, the NIS source range only performs monitoring functions. With both required source range channels nonfunctional, operations involving positive reactivity changes is immediately suspended. The immediate Completion Time is consistent with the required times for actions to be performed without delay and in a controlled manner. Also, verification of SOM within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter is required with no core reactivity monitoring capability. One hour allows the operator adequate time to determine SDM.
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Source Range Neutron Flux TR B 3.3.15 BASES TECHNICAL TSR 3.3.15.1 SURVEILLANCE REQUIREMENTS Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure, thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the unit staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.
The Frequency is based on operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the TR required channels.
TSR 3.3.15.2 Not used.
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Explosive Gas Monitoring Instrumentation ...
TR B 3.3.16 B 3.3 INSTRUMENTATION TR B 3.3.16 Explosive Gas Monitoring Instrumentation BASES BACKGROUND The explosive gas monitoring instrumentation is designed to facilitate automatic operation and remote control of the Waste Gas Holdup System and to provide continuous indication of system parameters (Ref. 1). This TR and TR 3.10.2, 'Waste Gas Holdup System - Explosive Gas Mixture,"
is provided to ensure that the concentration of potentially explosive gas mixtures contained in the Waste Gas Holdup System is maintained below the flammability limits of hydrogen and oxygen. Automatic control features are included in the system to prevent the hydrogen and oxygen concentrations from reaching these flammability limits. These automatic control features include isolation of the source of hydrogen and/or oxygen. Maintaining the concentration of hydrogen and oxygen below their flammability limits provides assurance that the releases of radioactive materials will be controlled in conformance with the requirements of General Design Criterion 60 of Appendix A to 10 .CFR Part 50 (Ref. 2).
Technical Specification 5.5.12, "Explosive Gas and Storage Tank Radioactivity Monitoring," requires limits for concentration of hydrogen and oxygen in the Waste Gas Holdup System and a Surveillance program to ensure the limits are maintained (Ref. 4).
APPLICABLE The requirements limiting the concentration of potentially explosive gas SAFETY ANALYSES mixtures in the Waste Gas Holdup System ensures that these concentrations will be maintained below the mixture flammability limit.
This requirement is designed to preclude inadvertent radioactivity releases from the Waste Gas Holdup System due to tank failure from a waste gas explosion.
TR TR 3.3.16 is provided to ensure the FUNCTIONALITY of instrumentation for monitoring the concentration of oxygen and hydrogen in the Waste Gas Holdup System. The concentration of oxygen and hydrogen are maintained below flammability limits to guard against the rupture of the Waste Gas Holdup System and the release of radioactive material.
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Explosive Gas Monitoring Instrumentation TR B 3.3.16 BASES APPLICABILITY The explosive gas monitoring instrumentation is required FUNCTIONAL during Waste Gas Holdup System operation. During periods when the Waste Gas Holdup System is not in operation, the concentration of oxygen and hydrogen is assumed stable such that continuous monitoring is not required.
The Waste Gas Holdup System operation is defined as the input of gas into the Waste Gas Holdup System or when a Waste Gas Recombiner is in operation. This includes "degassing operation" which is defined as the operation of switching from a H2 Blanket to a N2 Blanket (or vice versa) in the Volume Control Tank while in MODES 3, 4 and 5. If the Waste Gas Holdup System has no inputs and the recombiners are not running, then the system is not in operation. Recirculation of the waste gas within the system is not defined as operation for the purposes of this TR (Ref. 3).
ACTIONS A Note has been added to the ACTIONS to clarify the application of Completion Time rules. The Conditions of this Requirement may be entered independently for each instrument. The Completion Time(s) for the nonfunctional instrument will be tracked separately for each channel starting from the time the Condition was entered for that channel.
With one or more explosive gas monitoring instrumentation channels with
- the Alarmffrip setpoint set less conservative than required, immediately *
declare the affected channel(s) nonfunctional. The appropriate Condition shall be entered based on declaring the affected channel(s) nonfunctional. The immediate Completion Time is consistent with the required times for actions to be performed without delay and in a controlled manner.
With any required channel nonfunctional, action must be taken to restore FUNCTIONAL status in 30 days. The 30 day Completion Time is based on operating experience and the other Conditions/Required Actions that prevent the hydrogen and oxygen concentrations from reaching flammability limits.
With less than one Hydrogen Monitor channel per recombiner FUNCTIONAL during Waste Gas Holdup System operations, the operator Wolf Creek - Unit 1 - TRM B 3.3.16-2 Revision 61
Explosive Gas Monitoring Instrumentation TR B 3.3.16 BASES ACTIONS C.1 (continued) is directed to immediately suspend the supply of oxygen to the affected recombiner(s). Without the ability to determine the hydrogen content of the waste gas stream during recombiner operation, the operator is unable to calculate whether flammable conditions exist within the system. The immediate Completion Time is consistent with the required times for actions to be performed without delay and in a controlled manner.
With less than one required Outlet Oxygen Monitor channel per recombiner FUNCTIONAL during Waste Gas Holdup System operations, the operator is directed to verify the oxygen concentration utilizing grab samples at a frequency of once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . This is acceptable since the required Inlet Oxygen Monitor is still FUNCTIONAL. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time is adequate based upon operational experience. .~
E.1 and E.2 With both the required Inlet and Outlet Oxygen Monitor channels per recombiner nonfunctional during Waste Gas Holdup System operations or the required Inlet Oxygen Monitor channel and Inlet Hydrogen Monitor channel on the same recombiner nonfunctional during Waste Gas Holdup System operation, the operator is required to suspend oxygen supply to the affected recombiner immediately. The immediate Completion Time is consistent with the required times for actions to be performed without delay and in a controlled manner.
In addition to the suspension of the supply of oxygen, both the concentration of oxygen and hydrogen are to be determined based upon grab samples once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months during degassing operations or once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months during other waste gas operations.
Without the ability to determine the resultant oxygen concentration following passage of the waste gas stream through the recombiner, the operator is unable to determine whether or not flammable limits are being approached. To therefore reduce the probability of reaching flammability limits, in this hydrogen rich environment, the addition of oxygen is suspended.
Recombining and degassing operations are allowed to continue provided grab samples are taken and analyzed to provide assurance that flammable limits of TR 3.10.2 are not exceeded.
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Explosive Gas Monitoring Instrumentation TR B 3.3.16 BASES ACTIONS F.1 (continued)
If Required Actions and associated Completion Times of Condition B, C, D or E are not met, operation of the Waste Gas Holdup System is immediately suspended. The immediate Completion Time is consistent with the required times for actions to be performed without delay and in a controlled manner.
TECHNICAL TSR 3.3.16.1 SURVEILLANCE REQUIREMENTS Performance of the CHANNEL CHECK once every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ensures that a gross instrumentation failure has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including isolation, indication, and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. If the channels are within the criteria, it is an indication that the channels are FUNCTIONAL.
The Frequency is based on operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the TR required channels.
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Power Distribution Monitoring System (PDMS)
TR B 3.3.19 B 3.3 INSTRUMENTATION TR B 3.3.19 Power Distribution Monitoring System (PDMS)
BASES BACKGROUND The Power Distribution Monitoring System (PDMS) generates a continuous measurement of the core power distribution using the methodology documented in Reference 1. The measured core power distribution is used to determine the most limiting core peaking factors, FN&l and Fa(Z). The most limiting measured core peaking factor values are used to verify that the reactor is operating within"the design limits.
The PDMS requires information on current plant and core conditions in order to determine the core power distribution using the core peaking factor measurement and measurement uncertainty methodology described in Reference 1. Addendum 4 to WCAP-12472-P-A provides an updated thermocouple uncertainty analysis process and affirmation of the continued use of the NRC approved Westinghouse design model methodology, currently PHOENIX-P/ANC, PARAGON/ANG and NEXUS/ANG. The core and plant condition information is used as~input.
to the continuous core power distribution measurement software that continuously and automatically determines the current core peaking factor values.
In order for the PDMS to accurately determine the peaking factor values, the core power distribution measurement software requires accurate information about the current reactor power level, average reactor vessel inlet temperature, control bank positions, the Power Range Detector calibrated voltage values, and measured temperatures from Core Exit Thermocouples (T/C).
APPLICABLE The PDMS is used for periodic measurement of the core power SAFETY ANALYSIS distribution to confirm operation within design limit, and periodic calibration of the excore detectors. This system does not initiate any
. automatic protection action. The PDMS is not assumed to be FUNCTIONAL to mitigate the consequences of a OBA or transient (Reference 2).
TR The TR requires the PDMS to be FUNCTIONAL with the minimum required channels shown in Table TR 3.3.19-1. The PDMS is FUNCTIONAL when the required channel inputs are available, the calibration data set is valid, and the reactor power level is at least 25% of RTP. The PDMS must be calibrated above 25% RTP to assure the accuracy of the calibration data set which can be generated from the incore flux map, core exit thermocouples, and the other input channels.
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Power Distribution Monitoring System (PDMS)
TR B 3.3.19 BASES TR Below 25% RTP, the PDMS is nonfunctional, since the calculated power (continued) distribution is of reduced accuracy, and may not be used to demonstrate compliance with the LCO limits.
This ensures that the measured plant and core condition information input to the core power distribution measurement software with the PDMS FUNCTIONAL is adequate to accurately calculate the core peaking factors. The peaking factor calculations include measurement uncertainty that bounds the actual measurement uncertainty of a FUNCTIONAL
PDMS.
APPLICABILITY The PDMS must be FUNCTIONAL in MODE 1 with THERMAL POWER
~ 25% when it is used for recalibration of the Excore Neutron Flux Detection System, or monitoring of QPTR, or measurement of FN6H or F0 (Z).
ACTIONS A nonfunctional PDMS cannot be used for recalibration of the Excore Neutron Flux Detection System, or monitoring of QPTR, or measurement of FN6H or F0 (Z). Required Action A.1 requires the immediate suspension of the use of the PDMS for these activities if the system is nonfunctional.
TECHNICAL TSR 3.3.19.1 SURVEILLANCE REQUIREMENTS Performance of a CHANNEL CHECK at a frequency of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ensures that a gross instrumentation failure has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument' drift in one of the channels. A CHANNEL CHECK will detect gross channel failure; thus it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
The Frequency is based on the need to establish that the required inputs to the PDMS are valid when using the PDMS to obtain a core power distribution measurement to be used to confirm that the reactor is operating within design limits.
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Power Distribution Monitoring System (PDMS)
TR 3.3.19 BASES TECHNICAL TSR 3.3.19.2 SURVEILLANCE REQUIREMENTS Upon initial plant startup following refueling, the PDMS uses a calibration (continued) data set calculated by the core designer for the new core.
An incore flux map for PDMS calibration may be obtained above 25%
RTP. The initial calibration data set generated in each operating cycle must utilize incore flux measurements from at least 75% of the incore thimbles, with at least two incore thimbles in each core quadrant.
Subsequent to the initial calibration, the calibration data set can be updated using incore flux measurements from at least 50% of the incore thimbles, with at least two incore thimbles in each core quadrant. The incore flux measurements in combination with inputs from the Table TR 3.3.19-1 channels are used to generate the updated calibration data set, including the nodal calibration factors and the thermocoupl~ mixing factors.
Following the initial calibration, the Frequency is 31 EFPD with minimum
core exit thermocouple coverage, or when the minimum core exit * .
thermocouple coverage is available for the PDMS calibration. The minimum thermocouple coverage consists of at least 17 thermocouples with a minimum of two per core quadrant.
Following the initial calibration, the Frequency is 180 EFPD when the optimum core exit thermocouple coverage. is available for the PDMS calibration. The optimum thermocouple coverage consists of at least 17 thermocouples with a minimum of two per core quadrant, distributed such all interior fuel assemblies (coverage of fuel assemblies with a face along the baffle is not required) are within a chess knight's move of a thermocouple.
TSR 3.3.19.3 A CHANNEL CALIBRATION is performed every 18 months, or approximately at every refueling. CHANNEL CALIBRATION is a complete check of the instrument loop, including the sensor. The test verifies that the channel responds to a measured parameter with the necessary range and accuracy. This SR is modified with a Note stating that neutron detectors are excluded from the CHANNEL CALIBRATION.
The CHANNEL CALIBRATION forthe power range neutron detectors consists of a normalization of the detectors based on a power calorimetric and flux map performed above 15% RTP. The Frequency is based on operating experience and consistency with the typical industry refueling cycle.
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Power Distribution Monitoring System (PDMS)
TR 3.3.19 BASES TECHNICAL TSR 3.3.19.4 SURVEILLANCE REQUIREMENTS Verfication that the Digital Rod Position Indication (DRPI) agrees with the (continued) demand position ensures that the DRPI and demand position indication is operating correctly. Refer to the corresponding Bases for Technical Specification 3.1. 7 for a discussion of SR 3.1. 7 .1.
REFERENCES 1. WCAP-12472-P-A, "BEACON Core Monitoring and Operations Support System," August 1994 (including Addendum 4, September 2012).
2. Amendment No. 188, July 23, 2010.
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Structural Integrity TR B 3.4.17 B 3.4 REACTOR COOLANT SYSTEM TR B 3.4.17 Structural Integrity BASES BACKGROUND The quality group classification for each water- and steam- containing pressure component is shown in USAR Table 3.2-1 (Ref. 1). The components are classified according to their safety significance as dictated by service and functional requirements and by the consequences of their failure .. The quality group classifications and code requirements
*for the quality of plant process systems meet the intent of Regulator)'
Guides (RG) 1.26 and 1.143.
The design, fabrication, inspection, and testing requirements of each classification provide the required degree of conservatism in assuring component pressure integrity and OPERABILITY/FUNCTIONALITY.
The Code requirements applicable to each quality group classification are identified in USAR Table 3.2-2. The quality group classifications and the interfaces between classifications in a system having components of different classifications are indicated on the piping and instrumentation diagram or flow diagram of that system.
In accordance with 10 CFR 50.55a(g), structural integrity must be maintained in conformance with ASME Code Section XI for those components that are subject to Code requirements. Depending on the type of deficiency, structural integrity can be determined by meeting applicable ASME Section Ill requirements,Section XI acceptance standards,Section XI IWB-3600 analytical evaluation procedures, or applicable NRC approved ASME Code Cases. NRC Inspection Manual Chapter 0326 (Ref. 2), Appendix C, Section C.1 O (Piping and Pipe Support Requirements), C.11 (Flaw Evaluation), and C.12 (Operational Leakage From ASME Code Class 1, 2, and 3 Components) contain specific NRC guidance and acceptable evaluation procedures that can be used to determine structural integrity and OPERABILITY for ASME Code Class 1, 2, and 3 components. The guidance from Inspection Manual Chapter 0326 is summarized below.
NRC Inspection Manual Chapter 0326 Guidance - Flaw Evaluation The NRC staff accepts ASME Code Case N-513 (and later versions of the Case as approved by RG 1.147), "Evaluation Criteria for Temporary Acceptance of Flaws in Moderate Energy Class 2 or 3 piping Section XI, Division 1," (Ref. 4) as an acceptable alternative to the ASME Code requirements for evaluating the structural integrity for flaws identified in moderate-energy piping.
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Structural Integrity TR B 3.4.17 BASES.
BACKGROUND RG 1.147, "lnservice Inspection Code Case Acceptability, ASME (continued) Section XI, Division 1" endorses code cases, some with conditions. Refer to RG 1.147 for the latest revision accepted by the NRC and any specific conditions associated with the code case. ASME Section XI Code Cases have a specified applicability consisting of an edition and addenda of Section XI or a range of editions and addenda of Section XI.Section XI requires Code Cases to be applicable to the Section XI edition and addenda specified in the lnservice Inspection Program.
In addition, the NRC issued Generic Letter (GL) 90-05, "Guidance for Performing Temporary Non-Code Repair of ASME Code Class 1, 2, and 3 Piping," (Ref. 3) which permits licensees to consider either the "through-wall flaw" or the "wall thinning" flaw evaluation approach when assessing the structural integrity of moderate energy piping with identified flaws that are not through-wall. If the flaw is found acceptable by the "through-wall flaw" approach, a temporary non-code repair may be made following NRC staff review and approval of the evaluation. A non-code repair is a repair not in compliance with the construction code or ASME Section XI. (Refer to GL 90-05 for further guidance on non-code repairs.) Compensatory actions may be implemented without NRC staff review and approval, provided the compensatory action does not involve a noncode repair to the piping system or supports and the compensatory action can be implemented in accordance with 10 CFR 50.59. If the flaw is found acceptable by the "wall thinning" approach, immediate repair of the flaw is not required; but WCNOC should comply with the guideline for flaw repair and monitoring. Whenever a flaw does not meet ASME Code or construction code acceptance standards or the requirements of an NRC endorsed ASME code case, a relief request is required. The relief request needs to be submitted in a timely manner after completing the OPERABILITY determination process documentation.
The NRC staff accepts the ASME Code, construction code, GL 90-05, ASME Code Case N-513 (and later versions of the Case as approved in RG 1.147), and any other applicable NRC-approved ASME Code Case criteria for conclusively establishing that a TS-required ASME Code Class 2 or 3 piping system that contains a flaw has adequate structural integrity and is, therefore in a degraded but operable condition. ASME Code Cases which describe methods, criteria, or requirements different from the ASME Code referenced in 10 CFR 50.55a cannot be used to evaluate the acceptability of a flaw without prior NRC Wolf Creek- Unit 1 -TRM B 3.4.17-2 Revision 35
Structural Integrity TR B 3.4.17 BASES BACKGROUND review and approval unless the ASME Code Cases are endorsed (continued) in the applicable regulatory guides.
The table below summarizes the methods available which are acceptable to the NRC staff for evaluating structural integrity of flaws found in boiling or pressurized water-cooled nuclear power facilities in TS-required components (including supports) classified as ASME Code Class 1, Class 2, and Class 3.
Methods Available to Evaluate Structural Integrity Code ASME Code NRC Approved Code Case N- GL 90-05 Class/Energy Section XI/ Alternative 513 Construction Code e.g. RG approved Code Case Class 1/HE x x Class 2/HE x x Class 2/ME x x x Class 3/HE x x *-x Class 3/ME x x x x Operational Leakage from ASME Code Class 1. 2. and 3 Components The regulations require that the structural integrity of ASME Code Class 1, 2, and 3 components be maintained in accordance with the ASME Section XI Code or construction code acceptance standards. If a leak is discovered in a Class 1, 2, or 3 component while conducting an inservice inspection, maintenance activity, or during facility operation, any corrective measures to repair or replace the leaking component must be performed in accordance with IWA-4000 of Section XI. The NRC staff expects that components be restored to ASME Section XI Code or construction code acceptance standards by the end of the next refueling outage.
To evaluate the structural integrity of the leaking component, the criteria in Section XI of the ASME Code, the construction code, or any applicable ASME Code Case approved by the NRC may be used. In addition, the structural integrity of Class 3 piping may be evaluated by using the criteria of paragraph C.3.a of Enclosure 1 to GL 90-05. If the flaw meets the GL 90-05 criteria, the piping is degraded but OPERABLE. However, relief from ASME Code requirements is needed even if the structural integrity is found acceptable when applying GL 90-05. Whenever a flaw is through-wall in an ASME Code component when evaluated using Wolf Creek - Unit 1 - TRM B 3.4.17-3 Revision 59
Structural Integrity TR B 3.4.17 BASES BACKGROUND GL 90-05, a relief request needs to be submitted in a timely (continued) manner after completing the OPERABILITY determination process documentation and prior to implementing a non-code repair activity to the SSC.
Alternatively, the structural integrity of leaking Class 2 or Class 3 moderate-energy piping may be evaluated using the criteria of ASME Code Case N-513 (and later versions of the Case as approved in RG 1.147) or any other applicable NRC approved ASME Code Case, as indicated in the above table. If the flaw in the. leaking component has adequate structural integrity in accordance with criteria of an ASME Code Case acceptable to the NRC staff, the piping can be deemed degraded but operable and continued temporary service of the degraded piping is permitted.
A relief request is not necessary when evaluated in accordance with an NRC approved code case as endorsed by the code case regulatory guide, and the evaluation results demonstrate adequate structural integrity.
Components with these flaws must be restored to ASME Code or construction code requirements through repair/replacement activity or meet requirements acceptable to the NRC, as approved in a relief request or ASME Code Case approved under the RGs prior to the completion of the next scheduled refueling outage.
Other compensatory actions may be taken, provided these compensatory actions are within the limitations of 10 CFR 50.59.
The NRC staff does not consider through-wall conditions in components to be in accordance with the intent of the ASME Code or construction code and, therefore, would not meet Code requirements, even though the component may demonstrate adequate structural integrity. Thus, unless a through-wall flaw is evaluated and found acceptable using an applicable and endorsed Code Case, in which all provisions are met, including any
. additional requirements or limitations imposed by the RG endorsing-the Code Case, a relief requestis necessary.
If the decision is to control the leakage and maintain structural integrity by mechanical clamping means, the requirements of ASME Code Case N-523 (or later versions of the Case as approved in RG 1.147), "Mechanical Clamping Devices for Class 2 and 3 Pipihg Section XI, Division 1," may be followed, because the NRC staff endorses this Code Case in RG 1.147. (This Code Case and later versions of the Case were subsequently WoWCreek-Unlt1-TRM B 3.4.17-4 Revision 35
Structural Integrity TR B 3.4.17 BASES TR expectation of OPERABILITY. (Refer to TR subsection on Immediate (continued) OPERABILITY Determinations for additional guidance.) In performing the prompt OPERABILITY determination, the determination must evaluate the structural integrity of the leaking component using the actual geometry of the through-wall flaw characterized or bounded with volumetric examination methods._ It may be possible to use visual methods to determine the exterior dimension(s) and orientation of a through-wall flaw in a leaking component if the degradation is active on the outside of the component. However, if the degradation is active from the inside of the component, even though the outside surface breaking dimension of a through-wall flaw may be small, the length and extent of the flaw inside the component wall may be quite long and potentially result in inadequate structural integrity of the component. For non-TS SSCs, an assessment of FUNCTIONALITY shall be performed to determine if structural integrity is maintained. For non-TS SSCs that support a TS SSC, the FUNCTIONALITY may impact the OPERABLITY of the TS SSC. If the non-TS SSC is nonfunctional, an immediate OPERABILITY determination shall be performed on the supported TS SSC.
The ASME Code classifies heat exchangers as "components." For Class 1, 2, and 3 heat exchangers (including room coolers), the heat exchanger tubing is part of the heat exchanger component and cannot be considered to be piping for purposes of applying the NRC Inspection Manual Chapter 0326 guidance. Until NRC approval for evaluating structural integrity of heat exchanger tubes is obtained, upon identification that a room cooler -
leak (i.e., a through-wall flaw) is in the tubing, structural integrity cannot be acceptably determined and the TS-required component must be declared inoperable. If a non-TS room cooler supports a TS SSC, then the FUNCTIONALITY of the room cooler must be determined. The FUNCTIONALITY of the room cooler may impact the OPERABILITY of the supported TS SSC. The associated Essential Service Water (ESW)
System, may still be OPERABLE as long as the ESW System functions to remove post accident heat loads.
Immediate OPERABILITY Determination Guidance In order to determine if the TS-required component is OPERABLE under an immediate OPERABILITY determination, the degradation mechanism must be discernable from visual examination (such as external corrosion or wear), or there must be substantial operating experience with the identified degradation mechanism in the affected system. In addition, detailed non-destructive examination data may be necessary to Wolf Creek - Unit 1 - TRM B 3.4.17-7 Revision 59
...... -sfructural Integrity TR B 3.4.17 BASES TR determine a component is OPERABLE under an immediate (continued) OPERABILITY determination. If detailed non-destructive examination is necessary and the examination cannot be completed within the time frame normally expected for an immediate OPERABILITY determination, the component should be declared inoperable and the appropriate TS Condition/Required Action entered.
APPLICABILITY The structural integrity of the ASME Code Class 1, 2, and 3 components is required during MODES 1, 2, 3, 4, 5, and 6. This TR applies whenever Code Class 1, 2, or 3 components are OPERABLE or FUNCTIONAL, not just during the performance of inservice inspection examinations.
ACTIONS A.1 and A.2 Condition A applies to one or more degraded or nonconforming ASME Code Class 1, 2, or 3 component(s) for which structural integrity is not maintained. Required Action A.1 requires action be initiated to determine OPERABILITY or FUNCTIONALITY for the affected component(s). If the affected component is a TS SSC, an immediate OPERABILITY determination shall be performed. If the affected component is a non-TS SSC, a FUNCTIONALITY determination shall be performed. If the non-TS SSC is nonfunctional, an immediate OPERABILITY determination shall be performed on the supported TS SSC.
The immediate Completion Time is consistent with the required times for action.s. to be performed without delay and in a controlled manner.
TECHNICAL TSR 3.4.17.1 SURVEILLANCE REQUIREMENTS 'TSR 3.4.17.1 requires performing inservice inspections of ASME Section XI Code Class 1, 2, and 3 components in accordance with the lnservice
Inspection Program described in TR 5.5.6, "lnservice Inspection Program."
lnservice inspection of ASME Code Class 1, 2, and 3 components are performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda, as required by 10 CFR 50.55a(g), to ensure that the structural integrity of these components will be maintained at an acceptable level throughout the life of the plant.
Exception to these requirements apply where relief has been granted by the Commission pursuant to 10 CFR 50.55a(z) and (g)(6)(i). The surveillance intervals specified in Section XI of the ASME Code apply.
Wolf Creek- Unit 1 - TRM B 3.4.17-8 Revision 62
Structural Integrity TR B 3.4.17 BASES TECHNICAL During design and construction, components of the Reactor Coolant SURVEILLANCE System were designed to provide access to permit inservice inspection in REQUIREMENTS accordance with Section XI of the ASME Boiler and Pressure Vessel (continued) Code, 1974 Edition and Addenda through Summer 1975.
REFERENCES 1. USAR, Section 3.2.2.
2. NRC Inspection Manual Chapter 0326, "Operability Determinations & Functionality Assessments for Conditions Adverse to Quality or Safety."
3. Generic Letter 90-05, "Guidance for Performing Temporary Non-Code Repair of ASME Code Class 1, 2, and 3 Piping," June 15, 1990; and August 16, 1990, NRR letter by J.E. Richardson, "Follow-up on Generic Letter 90-05 Regarding Guidance for Performing Temporary Non-Code Repair of ASME Code Class 1, 2, and 3 Piping," (letter 90-02380).
4. Code Case N-513 (and later versions of the Case as approved by RG 1.147), "Evaluation Criteria for Temporary Acceptance of Flaws in Class 2 and 3 Piping."
Wolf Creek- Unit 1 - TRM B 3.4.17-9 Revision 59
Containment Vessel Structural Integrity TR B 3.6.1 B 3.6 CONTAINMENT SYSTEMS TR B 3.6.1 Containment Vessel Structural Integrity BASES BACKGROUND The containment consists of a prestressed, reinforced concrete, cylindrical structure with a hemispherical dome. The Post-tensioning System used for the shell and dome of the containment employs tendons.
Each tendon consists of 170 one quarter..:inch high strength steel wires and anchoring components. The prestressing load is transferred, by cold formed button heads on the ends of the individual wires through stressing washers, to steel bearing plates embedded in the structure. The ultimate strength of each tendon is approximately 1000 tons. The unbonded tendons are installed in tendon ducts and tensioned in a predetermined sequence. The tendon ducts consist of galvanized, spiral wrapped, semi-rigid corrugated steel tubing. After tensioning, a petroleum based corrosion inhibitor is pumped into the duct.
The Post-tensioning System is divided into two tendon groups. One group consists of 86 inverted U-shaped tendons which extend through the-full height of the cylindrical wall over the dome. They are anchored at the bottom of the base slab through the ceiling of the tendon access gallery.
The other tendon group consists of 165 tendons forming the circumferential (hoop) tendons. Three buttresses located 120 degrees apart extend the full vertical height of the containment. The hoop tendons are anchored to one buttress, extend through the next, and are anchored to the third buttress. Thus, each hoop tendon extends around 240 degrees of the containment building (Ref. 1).
The containment OPERABILITY requirements are provided in Technical Specifications 3.6.1, "Containment," 5.5.6, "Containment Tendon.
Surveillance Program," and 5.5.16, "Containment Leakage Rate Testing Program," (Refs. 2 and 3). Reference 4 describes further details on the performance of containment tendon surveillances.
Technical Specification 5.5.6 requires the Containment Tendon Surveillance Program, *and its inspection frequencies and acceptance criteria, to be in accordance with Section XI, Subsection IWL (Ref. 5) of the ASME Boiler and Pressure Vessel Code and applicable addenda as required by 10 CFR 50.55a, except where an exemption or relief has been authorized by the NRC.Section XI requires the preparation of a Containment lnservice Inspection Program Plan (Ref. 6) that identifies the applicable Edition and Addenda of Section XI and integratesSection XI requirements, regulatory requirements, commitments, and relief or exemption requests, if any.
Wolf Creek - Unit 1 - TRM B 3.6.1-1 Revision 62
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Containment Vessel Sfrudural Integrity TR B 3.6.1 BASES APPLICABLE The safety design basis for the containment is that the containment must SAFETY ANALYSIS withstand the pressures and temperatures of the limiting DBA without exceeding the design leakage rate. An integral part of the containment's ability to perform its safety function depends on the FUNCTIONALITY of the containment tendons. Failure of the containment tendons may result in the inability of containment to withstand the effects ofa high energy line break. Therefore, the inspection and surveillance of tendon parameters are required to assure the OPERABILITY of containment.
These requirements ensure that the structural integrity of the containment will be maintained in accordance with safety analysis requirements for the life of the facility. Structural integrity is required to ensure that the containment is maintained OPERABLE. Refer to the Applicable Safety Analyses Section of Technical Specification 3.6.1 Bases. The measurement of containment tendon lift-off force, the tensile tests of the tendon wires or strands, the visual examination of tendons, anchorages and exposed exterior surfaces of the containment, along with the Containment Leakage Rate Testing Program is sufficient to demonstrate this capability. **
TR This TR provides controls to ensure appropriate evaluations are performed upon the discovery of conditions which indicates an abnormal degradation of the containment vessel. An abnormal degradation of the containment vessel does not necessarily result in an inoperable containment.
If at anytime during the evaluation of a degraded condition it is determined that the containment vessel will not be able to perform its specified safety function, the containment must be immediately declared inoperable per the requirements of Technical Specifications. LCO 3.6.1 and LCO 3.0.2.
APPLICABILITY In MODES 1, 2, 3, and 4, a DBA could cause a release of radioactive material into containment. In MODES 5 and 6, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES. Therefore, in support of containment's OPERABILITY requirements, only MODES 1, 2, 3, and 4 are applicable for the OPERABILITY of the containment vessel.
Wo~Creek-Unlt1-TRM B 3.6.1-2 Revision 41
Containment Vessel Structural Integrity TR B 3.6.1 BASES ACTIONS A.1 and A.2 As required by Section XI, IWL-3220, when the average of all measured tendon forces (including the measured forces in two tendons located adjacent to any tendon with measured forces between 90% and 95% of the predicted force) is less than the minimum required prestress specified at the anchorage for that type of tendon, an engineering evaluation is required to be performed. The engineering evaluation is performed to justify the continued OPERABILITY of containment by determining the acceptability of the containment vessel without repair of the degraded condition.
The Completion Time of Required Action A.1 is based upon operating experience and the relatively low probability of an event requiring the containment to withstand the effects of a DBA during the time period.
ASME Code Section XI, Subsection IWL (IWL-3300), requires an engineering evaluation be performed for items with examination results that do not meet the acceptance standards of IWL-3200. The engineering evaluation shall include the following:
a. the cause of the condition that does not meet the acceptance standards;
b. the acceptability of the concrete containment without repair of the item;
c. whether or not repair/replacement is required and if required, the extent, method, and completion date for the repair/replacement activity; and
d. extent, nature, and frequency of additional examinations.
The Completion Time of Required Action A.2 is based on the requirements of ASME Code,Section XI, IWA-6000. IWA-6000 requires that an lnservice Inspection (ISi) Summary Report be prepared afthe * -
completion of the inservice inspection each refueling outage. The ISi Summary Report is required to be submitted to the NRC within 90 days of completion of the refueling outage. The Containment lnservice Inspection Program Plan (Ref. 6) provides the guidelines for use of Form OAR-1 for reporting containment vessel abnormal degradation.
Wolf Creek- Unit 1 - TRM B 3.6.1-3 Revision 62
Containment Vessel Structural Integrity TR B 3.6.1 BASES ACTIONS B.1 and B.2 When containment vessel abnormal degradation has occurred for reasons other than Condition A, an engineering evaluation is required to be performed. The engineering evaluation is performed to justify the continued OPERABILITY of containment by determining the acceptability of the containment vessel without repair of the degraded condition.
The Completion Time of Required Action B.1 is based upon operating experience and the relatively low probability of an event requiring containment to withstand the effects of a OBA during the time period.
ASME Code Section XI, Subsection IWL (IWL-3300), requires an engineering evaluation be performed for items with examination results that do not meet the acceptance standards of IWL-3200. The engineering evaluation shall include the following:
a. the cause of the condition that does not meet the acceptance standards;
b. the acceptability of the concrete containment without repair of the item;
c. whether or not repair/replacement is required and if required, the extent, method, and completion date for the repair/replacement activity; and
d. extent, nature, and frequency of additional examinations.
The Completion Time of Required Action B.2 is based on the requirements of ASME Code,Section XI, IWA-6000. IWA-6000 requires that an lnservice Inspection (ISi) Summary Report be prepared at the completion of the inservice inspection each refueling outage. The ISi Summary Report is required to be submitted to the NRC within 90 days of completion of the. refueling outage. The Containment lnservice Inspection Program Plan (Ref. 6) provides the guidelines for use of ASME Form OAR-1 for reporting containment vessel abnormal degradation.
Wolf Creek - Unit 1 - TRM B 3.6.1-4 Revision 62
Containment Vessel Structural Integrity TR B 3.6.1 BASES REFERENCES 1. USAR, Section 3.8.1.1 and Section 6.2.
2. Technical Specification 3.6.1 and associated Bases.
3. Technical Specifications 5.5.6 and 5.5.16.
4. Specification 16577-C-158(0), "Technical Specification for Containment Tendon Surveillance."
5. . . ASME Boiler*and Pressure Vessel Code Section XI, Subsection IWL.
6. WCRE-22, "Containment lnservice Inspection Program Plan Wolf Creek Generating Station Interval 2."
Wolf Creek - Unit 1 - TRM B 3.6.1-7 Revision 62
EES for Crane Operation - Fuel Building TR B 3.7.13 B 3.7 PLANT SYSTEMS TR B 3.7.13 Emergency Exhaust System (EES) for Crane Operation - Fuel Building BASES BACKGROUND A description of the EES is provided in the Bases for Technical Specification 3.7.13, "Emergency Exhaust System," (Ref. 1).
APPLICABLE The EES has a design function to filter radioactive particles which have SAFETY ANALYSES been released as a result of a fuel handling accident. The OPERABILITY of the EES with respect to a fuel handling accident is addressed by Technical Specification 3.7.13 (Ref. 1). The dose consequences of dropping of a light load (i.e, load ::;; 2250 pounds) into the spent fuel pool storage area, which may result in partial damage to one or more irradiated fuel assembly(s) is less than the dose consequences of a fuel handling accident. Therefore, since the potential for damage exists which would result in the release of radioactive material, it is necessary for operational requirements to be in place to protect against the inadvertent release of radioactive materials to the environment. Heavy loads (i.e.,
loads in excess of 2250 pounds), with the exception of the spent fuel transfer gates, are prevented from being moved over fuel assemblies in the spent fuel storage facility by crane travel interlocks and physical stops. FUNCTIONALITY requirements for crane travel interlocks and physical stops are specified in TR 3.7.17, "Crane Travel - Spent Fuel Storage Facility," (Ref. 2).
TR Two independent and redundant trains of the EES are required to be FUNCTIONAL to ensure that at least one train is available, assuming a single failure that disables the other train. Total system failure could result in the atmospheric release from the fuel building. Such a release is not expected to exceed the guideline limits of 10 CFR 100 for the situation addressed by this TR.
The EES is considered FUNCTIONAL when the individual components necessary to control releases from the fuel building are FUNCTIONAL in both trains. An EES train is considered FUNCTIONAL when its associated:
a. Fan is FUNCTIONAL;
b. HEPA filter and charcoal adsorber are not excessively restricting flow, and are capable of performing their filtration function; and Wolf Creek - Unit 1 - TRM B 3.7.13-1 Revision 61
EES for Crane Operation - Fuel Building TR B 3.7.13 BASES TR c. Heater, ductwork, and dampers are FUNCTIONAL, and air (continued) circulation can be maintained.
In addition, the fuel building boundary must be maintained, including the integrity of the walls, floors, ceilings, ductwork, and access doors.
The TR is modified by a Note allowing the fuel building boundary to be opened intermittently under administrative controls. For entry and exit through doors, the administrative control of the opening is performed by the person(s) entering or exiting the area. For other openings, these controls consist of stationing a dedicated individual at the opening who is in continuous communication with the control room. This individual will have a method to rapidly close the opening when a need for fuel building isolation is indicated.
APPLICABILITY During crane or auxiliary hoist operation with load over the fuel storage areas when irradiated fuel is stored in the spent fuel pool, the EES is required to be FUNCTIONAL in the fuel building ventilation isolation signal (FBVIS) mode of operation to mitigate the consequences of an event as a result of the dropping of a load on to or into a fuel storage area. However, no OBA or transient assumes the EES to be FUNCTIONAL during crane operation with load over the fuel storage areas (Ref. 3). During crane or auxiliary hoist operation with no loads or when there is no irradiated fuel in the spent fuel storage pool, the EES is not required to be FUNCTIONAL in the FBVIS mode since the potential of radioactive release due to dropping a load on an irradiated fuel assembly is unlikely.
ACTIONS With one EES train nonfunctional, the FUNCTIONAL EES train may be placed in the FBVIS mode. This action ensures that this remaining train is FUNCTIONAL, that no failures that would prevent automatic actuation
-_ will occur, and that ariy active failure will be readily detected.
The Required Action has been modified by a Note to ensure that only the Required Action and associated Completion Time of Condition Bare required if both EES trains are nonfunctional due to a nonfunctional fuel building boundary. With both EES trains nonfunctional, a FUNCTIONAL EES train is not available to operate in the FBVIS mode. Required Action B.1 is the appropriate remedial action. The exception does not affect tracking the Completion Time from the initial entry into Condition A; only the requirement to comply with the Required Action.
WoWCreek-Unlt1-TRM B 3.7.13-2 Revision 41
Snubbers TR B 3.7.20 B 3. 7 PLANT SYSTEMS TR B 3. 7 .20 Snubbers BASES BACKGROUND Component standard supports, are those metal supports which are designed to transmit loads from the pressure-retaining boundary of the component to the building structure. Although classified as component standard supports, snubbers require special consideration due to their unique function. Snubbers are designed to provide no transmission of force during normal plant operations, but function as a rigid support when subjected to dynamic transient loadings. Therefore, snubbers are chosen in lieu of rigid supports where restricting thermal growth during normal operation would induce excessive stresses in the piping nozzles or other equipment. The location and size of the snubbers are determined by stress analysis. Depending on the design classification of the particular piping, different combinations of load conditions are established. These conditions combine loading during normal operation, seismic loading and loading due to plant accidents/transients to four different loading sets.
These loading sets are designated as: normal, upset, emergency;"and faulted condition. The actual loading included in each of the four conditions, depends on the design classification of the piping. The calculated stresses in the piping and other equipment, for each of the four conditions, must be in conformance with established design limits.
Supports for pressure-retaining components are designed in accordance with the rules of the ASME Boiler and Pressure Vessel Code, Section Ill, Division 1 {Ref. 1). The combination of loadings for each support, including the appropriate stress levels, meet the criteria of Regulatory Guide 1.124, "Design Limits and Loading Combinations for Class 1 Linear-Type Component Supports" {Ref. 2), and Regulatory Guide 1.130, "Design Limits and Loading Combinations for Class 1 Plate-and -Shell-Type Component Supports" {Ref. 3).
Snubbers are classified and grouped by design and manufacturer but not by size. For example, mechanical snubbers utilizing the same design features of the 2-kip, 10.;.kip, and 100-kip capacity manufactured by Company "A" are of the same type. The same design mechanical snubbers manufactured by Company "B" for the purposes of this Technical Requirements would be of a different type. Snubbers may also be classified and grouped by their inaccessibility or accessibility for the purpose of visual inspection. Therefore, each snubber type may be grouped for inspection in accordance with accessibility.
WoWCreek-Unlt1-TRM B 3.7.20-1 Revision 4
Snubbers TR B 3.7.20 BASES BACKGROUND A list of individual snubbers with detailed information regarding the (continued) snubber's location, size and system(s) which it affects is available at the plant in accordance with Section 50.71(c) of 10 CFR Part 50. The accessibility of each snubber is determined and approved by the Plant Safety Review Committee. The determination is based upon the existing radiation levels and the expected time to perform a visual inspection in each snubber location as well as other factors associated with accessibility during plant operations (e.g., temperature, atmosphere, location etc.), and the recommendations of Regulatory Guides 8.8 and 8.1 O (Refs. 7 and 8). The addition or deletion of any mechanical snubber is performed in accordance with Section 50.59 of 10 CFR Part 50.
The Snubber Service Life Program is administered through TR 5.5.5.
The service life of a snubber is established via manufacturer input and information through consideration of the snubber service conditions and associated installation and maintenance records (newly installed snubber, seal replaced, spring replaced, in high radiation area, in high temperature area, etc.). The requirement to monitor the snubber service life is included to ensure that the snubbers periodically undergo a performance evaluation in view of their age and operating conditions. These records will provide the basis for future consideration of snubber service life.
APPLICABLE Technical Specification (TS) LCO 3.0.8 establishes conditions under SAFETY ANALYSES which systems are considered to remain capable of performing their intended safety function when associated snubbers are not capable of providing their associated support function(s). The TS LCO states that supported system(s) are not required to be considered inoperable solely due to one or more snubbers not capable of performing their associated support function(s). This is appropriate because a limited length of time is allowed for maintenance, testing, or repair of one or more snubbers not capable of performing their associated support function(s) and appropriate compensatory measures are specified in the snubber requirements, which are located outside of the TS under licensee control.
Pipe* and equipment supports, in general, are not directly considered in designing the accident sequences for theoretical hazard evaluations.
Further, various Probabilistic Risk Assessment (PRA) studies have indicated that snubbers are not of prime importance in a risk significant sequence (Refs. 4 and 5). Therefore, the function of the snubbers is not essential in mitigating the consequences of a DBA or transient (Refs. 6 and 9).
TR 3.7.20 applies to the snubbers listed in Table TR3.7.20.5, which provides a listing of plant snubbers installed on safety related systems, or that could adversely affect a safety related system due to being Wolf Creek - Unit 1 - TRM B 3.7.20-2 Revision 62
Snubbers TR B 3.7.20 BASES APPLICABLE nonfunctional. There are no non-safety related snubbers or snubbers SAFETY ANALYSES installed on non-safety related systems that could adversely affect a (continued) safety related system due to being nonfunctional.
TR This TR requires that the snubbers listed in Table TR 3.7.20-5 be FUNCTIONAL. Table TR 3.7.20-5 is a listing of snubbers installed on safety related systems. There are no snubbers that are utilized on non-safety related systems that could adversely effect a safety related system due to being nonfunctional.
APPLICABILITY FUNCTIONALITY requirements for the required snubbers listed in Table TR 3.7.20-5 are determined based on the MODES in which the system(s) supported by each snubber, and any other safety related system(s) that could be adversely affected by nonfunctionality of the required snubber, are required by TS to be OPERABLE. FUNCTIONALITY requirements are specified in Table TR 3.7.20-?. -
ACTIONS A Note has been added to the ACTIONS to clarify the application of Completion Time rules. The Conditions of this Technical Requirement may be entered independently for each affected snubber. The Completion Time( s) of the nonfunctional snubber will be tracked separately for each affected system starting from the time the Condition was entered for that snubber.
Condition A applies when one or more snubber(s) listed in Table TR 3.7.20-5 that are non-TS LCO 3.0.8 applicable are nonfunctional (e.g.,
removed from the attached system or otherwise not capable of performing their design function). The snubber list in Table TR 3.7.20-5 is annotated to identify snubbers that are TS LCO 3.0.8 applicable, TS LCO 3.0.8 provides an allowance under which systems are not considered to be inoperable solely due to one or more snubbers not being capable of performing their associated support function(s). The design function of the snubber must be considered in order to determine if a snubber is TS LCO 3.0.8 applicable.
a) If the design function of the snubber is to react to only seismic loads, the snubber is TS LCO 3.0.8 applicable.
WoWCreek-Unlt1-TRM B 3.7.20-3 Revision 50
Snubbers TR B 3.7.20 BASES ACTIONS A.1 (continued) b) If the design function of the snubber includes both seismic loads and non-seismic loads, any TS systems that are supported by the nonfunctional snubber, or that could be adversely affected, must be able to remain OPERABLE if subjected to the non-seismic loads with the snubber removed or otherwise nonfunctional. If the supported TS system will remain OPERABLE when subjected to non-seismic loads, the snubber is LCO 3.0.8 applicable.
When one or more non-TS LCO 3.0.8 snubber(s) are nonfunctional, the TS supported system or component is immediately declared inoperable and the applicable TS LCO(s) are declared not met and applicable Conditions/Required Actions entered.
B.1 and B.2 Condition B applies when one or more TS LCO 3.0.8 applicable snubbers listed in Table TR 3.7.20-5 are removed from the attached system or the required snubber(s) are nonfunctional or otherwise not capable of performing their support function while in place. The list of snubbers in Table TR 3.7.20-5 is annotated to identify snubbers that are TS LCO 3.0.8 applicable.
Required Action B.1 directs that nonfunctional snubber(s) be restored to FUNTIONAL status consistent with the Completion Times of TS LCO 3.0.8.
In the event that the nonfunctional snubber(s) can not be restored within the TS LCO 3.0.8 allowed time and are unable to perform their associated support function, Required Action B.2 specifies that the affected supported system TS system(s) must be declared inoperable and the applicable TS LCO(s) declared not met and associated Conditions/Required Actions entered prior to expiration of the LCO 3.0.8 Completion Time in accordance with TS LCO 3.0.2.
When a snubber is to be rendered incapable of performing its related support function for testing or maintenance or is discovered to be nonfunctional, it must be determined whether any TS system(s) require the affected snubber(s) for system OPERABILITY, and whether the plant is in a MODE or specified condition in the Applicability that requires the supported TS system(s) to be OPERABLE.
Wolf Creek - Unit 1 - TRM B 3.7.20-4 Revision 62
Snubbers TR B 3.7.20 BASES ACTIONS B.1 and B.2 (continued)
TS LCO 3.0.8 provides an allowance under which systems are not considered to be inoperable solely due to one or more snubbers not capable of performing their associated support function(s). The system may be declared OPERABLE while utilizing TS LCO 3.0.8. The following are applicable for utilizing LCO 3.0.8:
a. Determine whether a TS system is rendered inoperable by a nonfunctional snubber.
(1) If it is determined that the supported TS system(s) do not require the snubber(s) to be FUNCTIONAL in order to support OPERABILITY of the system(s) LCO 3.0.8 is not needed.
(2) If the LCO(s) associated with any supported TS system(s) are not currently applicable (i.e., the plant is not in a MODE
or other specified condition in *the Applicability of the' LCO),
LCO 3.0.8 is not needed.
(3) If the support TS system(s) are inoperable for reasons other than snubbers, LCO 3.0.8 cannot be used.
(4) If the design function of the snubber includes only non-seismic loads (e.g., thrust loads, blowdown loads, water-hammer loads, steam-hammer loads, LOCA loads, and pipe rupture loads), TS LCO 3.0.8 cannot be applied to the TS systems supported by the nonfunctional snubber.
However, a nonfunctional snubber in this situation does not result in inoperability of the supported TS system(s) if it can be confirmed that the snubber is not needed for OPERABILITY of the TS system(s).
b. . Determine the design basis of the nonfunctional snubber. When a snubber is to be rendered nonfunctional for testing or maintenance or is discovered to be nonfunctional, the design function of the snubber must be determined in order to determine if LCO 3.0.8 may be used.
(1) If the design function of the snubber is to react to only seismic loads, LCO 3.0.8 may be applied.
Wolf Creek - Unit 1 - TRM B 3.7.20-5 Revision 62
Snubbers TR B 3.7.20 BASES ACTIONS B.1 and B.2 (continued)
(2) If the design function of the snubber includes both seismic loads and non-seismic loads, any TS systems supported by the nonfunctional snubber must be able to remain OPERABLE if subjected to the non-seismic loads with the snubber removed. If the supported TS system will remain OPERABLE when subjected to non-seismic loads, LCO 3.0.8 may be applied.
(3) If the design function of the snubber includes only non-seismic loads (e.g., thrust loads, blowdown loads, water-hammer loads, steam-hammer loads, LOCA loads, and pipe rupture loads), TS LCO 3.0.8 cannot be applied to the TS systems supported by the nonfunctional snubber.
However, a nonfunctional snubber in this situation does not result in inoperability of the supported TS system(s) if it can be confirmed that the snubber is not needed for OPERABILITY of the TS systeni(s).
c. When LCO 3.0.8.a is used, at least one train of the Auxiliary Feedwater (AFW) System not associated with the nonfunctional snubber must be OPERABLE.
d. When LCO 3.0.8.b is used, at least one train of the AFW System not associated with the nonfunctional snubber must be OPERABLE. If the nonfunctional snubber(s) supports all trains of the AFW System or if the AFW System becomes inoperable due to an emergent condition, some alternative means of core cooling must be available.
e. The LCO 3.0.8 requirement to assess and manage risk is met by programs to comply with the requirements of paragraph (a)(4) of the Maintenance Rule, 10 CFR 50.65, to assess and manage risk resulting from maintenance activities. LCO 3.0.8 should be .
considered with respect to other plant maintenance activities, and integrated into the existing Maintenance Rule process to the extent possible so that maintenance on any unaffected train or subsystem is properly controlled, and emergent issue properly addressed. The risk assessment need not be quantified, but may be a qualitative awareness of the vulnerability of systems and components when one or more snubbers are not able to perform their associated support function.
Wolf Creek - Unit 1 - TRM B 3.7.20-6 Revision 62
Snubbers TR B 3.7.20 BASES ACTIONS 8.1 and 8.2 (continued)
f. A record of the implementation of any applicable Tier 2 restrictions, and the associated plant configuration, shall be available on a recoverable basis for NRC inspection.
Condition C applies when one or more non-TS snubbers listed in Table TR 3.7.20-5 are removed from the attached system or the required snubber(s) are nonfunctional or otherwise not capable of performing their support function while in place. The list of snubbers in-Table TR 3.7.20-5 is annotated to identify non-TS snubbers. If one or more non-TS snubber is nonfunctional, action must be taken to restore the snubber to FUNCTIONAL status in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .
The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time is consistent with TS LCO 3.0.8.a and is reasonable based on the low probability of a seismic event concurrent with an event that would require operation of the supported system occurring while the snubber(s) are not capable of performing their associated support function.
TECHNICAL Surveillance Testing is performed in accordance with the applicable SURVEILLANCE requirements of ASME OM Code and Subsection ISTD, "Preservice and REQUIREMENTS lnservice Examination and Testing of Dynamic Restraints (Snubbers) in Light-Water Reactor Nuclear Power Plants" (Ref. 11 ).
The Snubber Program complies with the requirements of 10 CFR 50.55a(b)(3)(v) for snubber visual examination and functional testing as documented in WCOP-29, "Snubber Examination, Testing, and Service Life Monitoring Program Plan - Fourth 10-Year lnservice Testing Interval," (Ref. 12).
Exemptions from the surveillance program for individual snubbers may be
I granted by the Commission if a justifiable basis for exemption is presented. Snubbers so exempted shall be listed in the list of individual snubbers indicating the extent of the exemptions.
Wolf Creek - Unit 1 - TRM B 3.7.20-7 Revision 62
Snubbers TR B 3.7.20 BASES TECHNICAL In order to establish the inspection frequency for each type of snubber on SURVEILLANCE a safety related system, it was assumed that the frequency of snubber REQUIREMENTS failures and initiating events is constant with time and that the failure of (continued) any snubber could cause the system to be unprotected and to result in failure during an assumed initiating event. Inspections performed before that interval has elapsed may be used as a new reference point to determine the next inspection. However, the results of such early inspections performed before the original required time interval has elapsed (nominal time less 25%) may not be used to lengthen the required inspection interval. Any inspection whose results require a shorter inspection interval will override the previous schedule.
TSR 3.7.20.1 TSR 3. 7 .20.1 comprises a visual inspection of the snubbers listed in Table TR 3.7.20-5. A pre-fuel load visual inspection and functional test has been performed on each snubber using the acceptance criteria listed in Table TR 3.7.20-2. The baseline takes into account that the snubbers have experienced thermal cycling and normal operating service as a result of previous hot functional testing. The initial inservice inspection has been performed on the snubbers prior to completion of the first refueling outage. The Frequency of subsequent surveillances depends on the number of snubbers found nonfunctional from each previous inspection as provided in Table TR 3.7.20-3 and the lnservice Inspection Program as described .in TR 5.5.6.
The acceptance criteria and corrective actions are listed in Table TR 3.7.20-2.
The visual inspections are designed to detect obvious indications of nonfunctionality of the snubbers. Removal of insulation or direct contact with the snubbers is not required initially. However, suspected causes of nonfunctionality are to be investigated and all snubbers of the same type and all snubbers subjected to the same failure mode are to be inspected more frequently.
The visual inspection frequency is based upon maintaining a constant level of snubber protection during an earthquake or severe transient and the number of unacceptable snubbers found during the previous inspection. As a result, the required inspection intervals vary inversely with the number of nonfunctional snubbers found during an inspection. If Wolf Creek - Unit 1 - TRM B 3.7.20-8 Revision 62
Snubbers TR B 3.7.20 BASES TECHNICAL. TSR3.7.20.1 (continued)
SURVEILLANCE REQUIREMENTS a snubber fails the visual acceptance criteria, the snubber is declared unacceptable and cannot be declared FUNCTIONAL via functional testing. However, if the cause of rejection is understood and remedied for that type of snubber and for any other type of snubbers that may be generically susceptible and FUNCTIONALITY verified by testing, that snubber may be reclassified acceptable for the purpose of establishing the next surveillance interval.
Code Case OMN-13, which allows the extension of the visual inspection interval in Table TR 3.7.20-3, is approved for use in Regulatory Guide 1.192 (Ref. 10). The visual inspection interval may be extended in accordance with Code Case OMN-13 once the prerequisites of the code case have been satisfied.
Snubbers may be categorized according to accessibility as noted in the Notes to Table TR 3.7.20-3. The accessibility of each snubber is.
determined ba_sed on radiation level as well as other factors such as temperature, atmosphere, location, etc. The recommendations of Regulatory Guide 8.8, "Information Relevant to Maintaining Occupational Radiation Exposure as Low a Practicable," (Ref. 7) and Regulatory Guide 8.10, "Operation Philosophy for Maintaining Occupational Radiation Exposure as Low as Practicable," (Ref. 8) are considered in planning and implementing the visual inspection program.
Since the visual inspections are augmented by a functional testing program, the visual inspection need not be a hands on inspection, but shall require visual scrutiny sufficient to assure that fasteners or mountings for connecting the snubbers to supports or foundations have no visible bolts, pins or fasteners missing, or other visible signs of physical damage such as cracking or loosening.
TSR 3.7.20.2 This TSR is modified by a Note which restricts the performance of this TSR to 60 days prior to and during a scheduled refueling outage.
TSR 3.7.20.2 comprises the functional testing of snubbers listed in Table TR 3.7.20-5 as described in Table TR 3.7.20-4. The sample plan (10%)
is being used for each of the four Defined Test Plan Groups (DTPG's).
Snubber functional testing is performed to the requirements of Table TR 3.7.20-4 and performed prior to the completion of each refueling outage. The once each refueling Frequency, in conjunction with the Note, is based on the need to perform this surveillance under the conditions that apply just prior to or during a unit refueling outage.
Wolf Creek - Unit 1 - TRM B 3.7.20-9 Revision 62
snubbers TR B 3.7.20 BASES TECHNICAL TSR 3. 7 .20.3 SURVEILLANCE REQUIREMENTS This TSR addresses the monitoring of the service life of the snubbers in (continued) accordance with the Snubber Service Life Program described in TR 5.5.5.
The requirement to monitor the snubber service life is included to ensure that the snubbers periodically undergo a performance evaluation in view of their age and operating conditions.
TSR 3.7.20.4 If the plant has experienced an unexpected, potentially damaging snubber transient, an inspection per Table TR 3.7.20-1 is performed on all snubbers attached to sections of systems that have experienced the transient. The potential impact of the transient is assessed by reviewing operating data and by visually inspecting the associated system. In addition to the visual inspection, the freedom-of-motion of the mechanical snubber(s) is verified per Table TR 3.7.20-1.
An unexpected potentially damaging snubber transient is an event that was outside the design basis of the SSC and could have affected the snubber(s) attached to the SSC. Specifically, this is an event that could have resulted in physical evidence of damage to a SSC outside the design basis for that SSC. The physical evidence should show leakage at nozzles and/or piping welds, damage to supports or insulation, twisted or rotated clamps and/or struts, or excessive pipe movements.
The determination concerning whether or not an unexpected potentially damaging snubber transient event has occurred will be made following a preliminary walkdown of the affected section of system by Quality Control personnel. Based upon the results of this walkdown, a determination will be made by Engineering and/or Operations personnel concerning whether or not the event should be considered an unexpected potentially damaging snubber transient event requiring entry into Condition C and performance of TSR 3. 7.20.4.
The Completion Time of 6 months has been assigned based upon industry practice.
Wolf Creek - Unit 1 - TRM B 3.7.20-10 Revision 62 I
Snubbers TR B 3.7.20 BASES REFERENCES 1. ASME Boiler and Pressure Vessel Code, Section Ill and XI.
2. Regulatory Guide 1.124, "Design Limits and Loading Combinations for Class 1 Linear-Type Component Supports,"
Revision 1, January 1978.
3. Regulatory Guide 1.130, "Design Limits and Loading Combinations for Class 1 Plate-and Shell-Type Component Supports," Revision 1, October 1978.
4. "Zion Probabilistic Safety Study", Commonwealth Edison Company, September 1981.
5. "Millstone Unit 3 Probabilistic Safety Study," North-East Utilities Company, August 1983.
6. NRC Staff Review of Nuclear Steam Supply System Vendor Owners Groups' Application of the Commission's Interim Policy Statement Criteria to Standard Technical Specifications.
Attachment to letter dated May 1988 from T. E. Murley, NRC to W.
S. Wilgus, Chairman the B&W Owners Group.
7. Regulatory Guide 8.8, "Information Relevant to Maintaining Occupational Radiation Exposure as Low as Practicable."
8. Regulatory Guide 8.10, "Operating Philosophy for Maintaining Occupational Radiation Exposure as Low as Practicable."
9. WCAP-11618, "MERITS Program-Phase 11, Task 5, Criteria Application," including Addendum 1 dated April, 1989, Section 3.7.9.
10. Regulatory Guide 1.192, "Operation and Maintenance Code Case Applicability, ASME OM Code."
11. ASME OM Code, Subsection ISTA and ISTD.
12. WCOP-29, "Snubber Examination, Testing, and Service Life Monitoring Program Plan - Fourth 10-Year lnservice Testing Interval."
Wolf Creek - Unit 1 - TRM B 3.7.20-11 Revision 62
Electrical Penetration Room Coolers TR B 3.7.24 B 3. 7 PLANT SYSTEMS TR~ 3.7.24 Electrical Penetration Room Coolers BASES BACKGROUND The penetration room coolers provide a suitable ambient temperature for the safety related equipment located in the electrical penetration rooms.
Room coolers SGL 15A and SGL 15B are located in rooms 1410 and 1409, respectively, on elevation 2026' of the Auxiliary Building.
Normally, safety related room coolers would not be taken out of service during normal plant operation, without also taking actions in accordance with existing Technical Specifications of the supported equipment. An evaluation (Ref. 1) has shown that loss of the penetration room coolers (SGL 15A/B) will not degrade the performance of the supported equipment in the associated penetration room. NRC Inspection Manual Chapter 0326 (Ref. 2), Appendix C, Section C.09 (Support System Operability) provides guidance allowing licensees to make determinations as to which support equipment is required under various conditions.
APPLICABLE The engineering design function of the penetration room coolers is to SAFETY ANALYSES provide a suitable ambient temperature for the safety related equipment located in the electrical penetration rooms. The maximum normal operating temperature for these rooms is identified in USAR Table 3.11 (B)-1 (Ref. 3) as 104°F. The design basis accident (OBA) room temperature is 106°F per USAR Table 3.11 (B)-2 (Ref. 3). The Area Temperature Monitoring Technical Requirements (TR 3.7.22) allowable temperature is~ 101°F. Typically, during normal plant operation, these rooms are found to stay at ambient temperatures in the range of 60°F to near 100°F.
TR One electrical penetration room cooler is required to be FUNCTIONAL in each electrical penetration room to ensure adequate cooling during normal operation.
An electrical penetration room cooler is considered to be FUNCTIONAL when the individual components necessary to maintain its associated electrical penetration room temperatures within acceptable limits are FUNCTIONAL.
Wolf Creek - Unit 1 - TRM B 3.7.24-1 Revision 60
Electrical Penetration Room Coolers TR B 3.7.24 BASES TR If the associated essential service water train is unavailable or (continued} inoperable and service water is available as a cooling medium to the electrical penetration room cooler, the room cooler is considered capable of providing cooling. A cooler may also be considered capable of providing cooling if restoration can be made by an operator in the Control Room or a dedicated operator stationed locally for the purpose of restoring the cooler. Restoration must be uncomplicated, covered by written procedure, must not require diagnosis or repair, and must be part of a pre-job brief on the test.
APPLICABILITY Since the environmental qualification of equipment is not MODE dependent, electrical penetration room cooler FUNCTIONALITY addressed by this TR is required at all times.
ACTIONS A Note modifies the ACTIONS to clarify the application of the Completion Time rules. The Conditions of this requirement may be entered independently for each electrical penetration room cooler. The Completion Times(s) of each electrical penetration room cooler will be tracked separately for each room cooler starting from the time the Condition was entered for that room cooler.
With an electrical penetration room cooler nonfunctional and not capable of providing cooling, action must be taken to de-energize the fan motor of the associated room cooler within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . De-energizing the motor reduces equipment heat gain to the room. The Completion Time of 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to de-energize the fan motor is acceptable based on operating experience and the temperature in the affected rooms is not expected to significantly increase within this period of time.
With an electrical penetration room cooler nonfunctional and not capable of being restored to service, the temperature in the associated electrical penetration room must be monitored to determine if a degraded condition exists. Thus, Required Action A.2 requires an initial check on temperatures by completing TSR 3.7.22.1 within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the most recently obtained room temperature exceeds 90°F to ensure the equipment room remains within allowable Wolf Creek - Unit 1 - TRM B 3.7.24-2 Revision 60
Electrical Penetration Room Coolers TR B 3.7.24 BASES ACTIONS A.2 (continued) limits (101°F). If the electrical penetration room temperature remains
~ 90°F, performance of TSR 3. 7 .22.1 every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient to ensure room temperature does not exceed 101°F. The initial Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is acceptable based on the expected heat-up rate of the rooms.
If the Required Actions and associated Completion Time for Condition A are not met, a Condition Report (CR) should be initiated immediately for addressing why the Required Actions were not performed and determining whether or not a degraded or nonconforming condition exists.
If equipment in the affected area(s) is degraded or nonconforming, determine if the equipment in the affected area(s) is OPERABLE/FUNCTIONAL, as applicable, by evaluating the effects of the out-of-limit temperature(s) on the equipment. The immediate Completion Time is consistent for actions to be performed without delay and in a controlled manner.
Table TR B 3.7.24-1 provides a list of the Technical Specifications and Technical Requirements which are applicable if the Required Actions and associated Completion Times of Condition A are not taken or the compensatory actions cannot maintain adequate temperatures to ensure OPERABILITY/FUNCTIONALITY.
When one electrical penetration room cooler is nonfunctional in MODE 1, 2, 3, or 4, action must be taken to restore the electrical penetration room cooler to FUNCTIONAL status in 7 days. The 7-day Completion Time is based on the low probability of an event requiring the components in the electrical penetration rooms to operate to mitigate*a OBA.
When one electrical penetration room cooler is nonfunctional in MODE 5, 6, or defueled, action must be taken to restore the electrical penetration room cooler to FUNCTIONAL status in 30 days. The 30-day Completion Time is based on the heat input to the electrical penetration rooms from a design basis LOCA or main steam line break is of minimal significance.
Wolf Creek - Unit 1 - TRM B 3.7.24.,3 Revision 60
Electrical Periefration Room Coolers TR B 3.7.24 BASES ACTIONS E.1 (continued)
If Required Action C.1 or D.1 cannot be performed within the associated Completion Time, Required Action E.1 requires initiation of a Condition Report (CR) immediately. The CR should provide an accurate description of the problem, the Required Action and associated Completion Time not complied with. The intent of the Required Action is to utilize the corrective action program to assure prompt attention and adequate management oversight to minimize the time of technical requirement noncompliance and/or nonfunctionality of the electrical penetration room cooler.
TECHNICAL None.
SURVEILLANCE REQUIREMENTS REFERENCES 1. CCP-09816, Rev. 0, "Inoperable Electrical Penetration Room Cooler (SGL 15A/B)."
2. NRG Inspection Manual Chapter 0326, "Operability Determinations & Functionality Assessments for Conditions Adverse to Quality or Safety."
3. USAR Table 3.11 (B).
Wolf Creek - Unit 1 - TRM B 3.7.24-4 Revision 60
ii-:
Offsite Power System - Transmission Network TR B 3.8.1 B 3.8 ELECTRICAL POWER SYSTEMS TR B 3.8.1 Offsite Power System - Transmission Network BASES BACKGROUND General Design Criterion (GDC) 17 (Ref. 1), "Electric power system," of Appendix A to 10 CFR 50 requires, in part, that an onsite electric power system and an offsite electric power system shall be provided to permit functioning of structures, systems, and components important to safety.
GDC 17 further specifies that electric power from the transmission network to the onsite electrical distribution system shall be supplied by two physically independent circuits (not necessarily on separate rights of way) designed and located so as to minimize to the extent practical the likelihood of their simultaneous failure under operating and postulated accident and environmental conditions. A switchyard common to both circuits is acceptable.
There are three 345 kV lines connecting the unit switchyard to the offsite transmission network. The three lines are:
a. Wolf Creek - Waverly - LaCygne 345 kV line
b. Wolf Creek - Rose Hill 345 kV line
c. Wolf Creek - Benton 345 kV line The above 345 kV lines do not share common rights-of-way, do not have any crossovers, and are not in close proximity of one another, except in the immediate vicinity of the unit switchyard. If any one of the three 345 kV lines faulted, the breakers located at the unit switchyard would trip, deenergizing the line. Any one 345 kV transmission line can carry the total engineered safety features (ESF) load required for safe shutdown.
Any transmission line may be aligned by controlled switching to feed either of the two ESF transformers. Having at least two FUNCTIONAL 345 kV transmission lines will minimize the probability of losing electric power from the offsite transmission network.
Offsite power is supplied to the unit switchyard from the offsite transmission network. From the switchyard, two electrically and physically separated circuits (offsite circuits) provide AC power, through the ESF transformers, to the 4.16 kV ESF buses. The OPERABILITY of the offsite circuits and diesel generators are addressed in limiting condition for operation (LCO) 3.8.1, "AC Sources - Operating." A detailed description of the offsite power network and the offsite circuits to the Class 1E ESF buses is found in the USAR, Chapter 8 (Ref. 2).
Wolf Creek - Unit 1 - TRM B 3.8.1-1 Revision 60
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Offsite Power System - Transmission Network TR B 3.8.1 BASES APPLICABLE The offsite transmission network is designed to provide sufficient SAFETY ANALYSES capacity, capability, redundancy, and reliability to ensure the availability of necessary power to offsite circuits and Class 1E Electrical Power System so that the fuel, Reactor Coolant System, and containment design limits are not exceeded.
TR TR 3.8.1 requires three 345 kV transmission lines connecting the unit switchyard to the offsite transmission network be FUNCTIONAL. This provision minimizes the probability of losing electric power from the offsite transmission network as a result of, or coincident with, the loss of power generated by the unit.
A 345 kV transmission line is considered FUNCTIONAL when the transmission line is connected to the unit switchyard and capable of supplying power. The Wolf Creek - Waverly - LaCygne 345 kV line is sectioned into two line sections; the Wolf Creek to Waverly Switching Station 345 kV line and the Waverly Switching Station to LaCygne 345 kV line. The Wolf Creek - Waverly - LaCygne 345 kV line is considered FUNCTIONAL when both line sections are energized through both a Wolf Creek and a LaCygne 345 kV breaker and tied together through at least one 345 kV breaker in the Waverly Switching Station.
APPLICABILITY The FUNCTIONALITY of the 345 kV transmission lines is required in MODES 1, 2, 3, and 4.
ACTIONS When one 345 kV line is nonfunctional (e.g., loss of one 345 kV line),
action shall be taken within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to verify two 345 kV lines are FUNCTIONAL. Procedure OFN AF-025, "Unit Limitations," may be utilized for verifying the two 345 kV lines are capable of supplying power.
A Condition Report should be initiated when this Condition is entered for trending the reliability of the offsite transmission network.
With two 345 kV lines nonfunctional, immediate entry into Condition A of Technical Specification LCO 3.8.1, "AC Sources - Operating," is required.
The offsite circuit energizing NB01 is considered inoperable when the East 345 kV bus is only energized from the offsite transmission network through the 345-50 and 345-60 main generator breakers. For this configuration, switchyard breakers 345-120 and 345-90 OR 345-120 and 345-80 are open.
Wolf Creek - Unit 1 - TRM B 3.8.1-2 Revision 60
Offsite Power System - Transmission Network TR B 3.8.1 BASES ACTIONS 8.1 (continued)
The immediate Completion Time is consistent with the required time for actions to be performed without delay and in a controlled manner.
TECHNICAL TSR 3.8.1.1 SURVEILLANCE REQUIREMENTS This SR ensures proper circuit continuity for the offsite transmission network supply to the WCGS switchyard. The breaker alignment verifies correct breaker position to ensur~ _that the WCGS switchyard is connected to the offsite transmission network. Power availability is verified by contacting the Transmission System Operator (TSO) and verifying the lines are connected at the remote end and the absence of actual or predicted switchyard voltage degraded conditions. The 7 day Frequency is adequate since breaker position is not likely to change without operator awareness.
REFERENCES 1. 10 CFR 50, Appendix A, GDC 17.
2. USAR, Chapter 8.
Wolf Creek - Unit 1 - TRM B 3.8.1-3 Revision 60 I
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IMPLEMENTED (4l TAB -Table of Contents 43 ORR 10-3738 12/28/10 ii 25 ORR 05-1996 9/28/05 iii 54 ORR 13-2529 10/25/13 TAB - B 3.0 APPLICABILTY B 3.0-1 41 ORR 10-1702 10/1/10 B 3.0-2 41 ORR 10-1702 10/1/10 B 3.0-3 41 ORR 10-1702 10/1/10 B 3.0-4 41 ORR 10-1702 10/1/10 B 3.0-5 41 ORR 10-1702 10/1/10 B 3.0-6 41 ORR 10-1702 10/1/10 B 3.0-7 41 ORR 10-1702 10/1/10 B 3.0-8 41 ORR 10-1702 10/1/10 B 3.0-9 41 ORR 10-1702 10/1/10 B 3.0-10 41 ORR 10-1702 10/1/10 B 3.0-11 41 ORR 10-1702 10/1/10 B 3.0-12 41 ORR 10-1702 10/1/10 B 3.0-13 41 DRR 10-1702 10/1/10 B 3.0-14 20 ORR 04-1410 1017/04 TAB - B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.7-1 41 ORR 10-1702 10/1/10 B3.1.7-2 41 ORR 10-1702 10/1/10 B 3.1.7-3 3 ORR 99-1581 12/18/99 B3.1.8-1 41 ORR 10-1702 10/1/10 B 3.1.8-2 41 ORR 10-1702 10/1/10 B 3.1.9-1 15 DRR 03-0861 7/10/03 B 3.1.9-2 41 ORR 10-1702 10/1/10 B 3.1.9-3 41 DRR 10-1702 10/1/10 B 3.1.9-4 41 ORR 10-1702 10/1/10 B 3.1.9-5 41 ORR 10-1702 10/1/10 B 3.1.9-6 55 ORR 14-0344 2/27/14 B 3.1.9-7 28 ORR 06-1349 7/24/06 B 3.1.9-8 3 ORR 99-1581 12/18/99 B 3.1.10-1 41 ORR 10-1702 10/1/10 B 3.1.10-2 49 ORR 12-0674 4/10/12 B 3.1.10-3 48 ORR 12-0266 2/2/12 B 3.1.10-4. 55 ORR 14-0344 2/27/14 B 3.1.10-5 48 ORR 12-0266 2/2/12 TAB- B 3.3 INSTRUMENTATION B 3.3.3-1 41 ORR 10-1702 10/1/10 B 3.3.3-2 41 ORR 10-1702 10/1/10 B 3.3.3-3 41 ORR 10-1702 10/1/10 B 3.3.3-4 41 ORR 10-1702 10/1/10 B 3.3.3-5 41 ORR 10-1702 10/1/10 B 3.3.3-6 28 DRR 06-1349 7124106 B 3.3.9-1 41 DRR 10-1702 10/1/10 B 3.3.9-2 41 ORR 10-1702 10/1/10 B 3.3.9-3 41 DRR 10-1702 10/1/10 Wolf Creek - Unit 1 Revision62
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TAB- B 3.3 INSTRUMENTATION (continued) 8 3.3.9-4 8 DRR 01-0475 5/1/01 B 3.3.10-1 3 DRR 99-1581 12/18/99 83.3.10-2 41 DRR 10-1702 10/1/10 B 3.3.10-3 41 DRR 10-1702 10/1/10 83.3.11-1 41 DRR 10-1702 10/1/10 83.3.11-2 41 DRR 10-1702 10/1/10 B 3.3.11-3 41 DRR 10-1702 10/1/10 B 3.3.11-4 41 DRR 10-1702 10/1/10 B 3.3.11-5 39 DRR 09-1775 10/28/09 83.3.12-1 41 DRR 10-1702 10/1/10 B 3.3.12-2 37 DRR 09-0287 3/20/09 B 3.3.12-3 19 DRR 04-1019 9/1/04 83.3.13-1 41 DRR 10-1702 10/1/10 B 3.3.13-2 41 DRR 10-1702 10/1/10 B 3.3.13-3 41 DRR 10-1702 10/1/10 B 3.3:13-4 3 DRR 99-1581 12/18/99 B 3.3.14-1 51 DRR 13-0371 2/26/13 B 3.3.14-2 51 DRR 13-0371 2/26/13 B 3.3.14-3 53** DRR 13-1518 6/26/13 ..
B 3.3.14-4 53 DRR 13-1518 6/26/13 83.3.14-5 51 DRR 13-0371 2/26/13 B 3.3.14-6 53 DRR 13-1518 6/26/13 83.3.14-7 51 DRR 13-0371 2/26/13 83.3.14-8 51 DRR 13-0371 2/26/13 83.3.14-9 51 DRR 13-0371 2/26/13 83.3.14~10 51 DRR 13-0371 2/26/13 B 3.3.14-11 51 DRR 13-0371 2/26/13 B 3.3.15-1 45 DRR 11-0662 3/21/11 B 3.3.15-2 45 DRR 11-0662 3/21/11 B 3.3.15-3 46 DRR 11-0725 4/11/11 B 3.3.15-4 60 DRR 15-0529 3/26/15 B 3.3.15-5 45 DRR 11-0662 3/21/11 83.3.16-1 41 DRR 10-1702 10/1/10 83.3.16-2 61 DRR 15-0824 4/28/15 B 3.3.16-3 61 DRR 15-0824 4/28/15 B 3.3.16-4 61 DRR 15-0824 4/28/15 B 3.3.16-5 41 DRR 10-1702 10/1/10 83.3.17-1 19 DRR 04-1019 9/1/04 83.3.17-2 41 DRR 10-1702 10/1/10 83.3.17-3 41 DRR 10-1702 10/1/10 83.3.17-4 41 DRR 10-1702 10/1/10 B 3.3.17-5 3 DRR 99-1581 12/18/99 B 3.3.18-1 14 DRR 02-1459 2/12/03 83.3.18-2 41 DRR 10-1702 10/1/10 B 3.3.18-3 49 DRR 12-0673 4/10/12 B 3.3.18-4 49 DRR 12-0673 4/10/12 B 3.3.18-5 49 DRR 12-0673 4/10/12 B 3.3.18-6 49 DRR 12-0673 4/10/12 B 3.3.18-7 49 DRR 12-0673 4/10/12 B 3.3 ..19-1 61 DRR 15-0824 4/28/15 B 3.3.19-2 61 DRR 15-0824 4/28/15 Wolf Creek - Unit 1 ii Revision62
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TAB- B 3.3 INSTRUMENTATION (continued)
B 3.3.19-3 61 DRR 15-0824 4/28/15 B 3.3.19-4 61 DRR 15-0824 4/28/15 TAB - B 3.4 REACTOR COOLANT SYSTEM (RCS)
B 3.4.3-1 10 DRR 02-0122 2128102 B 3.4.3-2 10 DRR 02-0122 2/28/02 B 3.4.3-3 41 DRR 10-1702 10/1/10 B 3.4.3-4 31 DRR 007-0657 5/1/07 TAB- B 3.4 REACTOR COOLANT SYSTEM (RCS) (continued)
B 3.4.10-1 41 DRR 10-1702 10/1/10 B 3.4.10-2 41 DRR 10-1702 10/1/10 B 3.4.16-1 3 DRR 99-1581 12/18/99 B 3.4.16-2 41 DRR 10-1702 10/1/10 B 3.4.16-3 33 DRR 07-1554 9/28/07 B3.4.17-1 62 DRR15-2006 10/26/15 B 3.4.17-2 35 DRR 08-0729 8/28/08 B3.4.17-3 59 DRR15-0112 2/10/15 i3 3.4.17-4 35 DRR 08-0729 8/28/08 B 3.4.17-5 41 DRR 10-1702 10/1/10 B 3.4.17-6 41 DRR 10-1702 10/1/10 B 3.4.17-7 59 DRR 15-0112 2/10/15 B 3.4.17-8 62 DRR 15-2006 10/26/15 B 3.4.17-9 59 DRR 15-0112 2/10/15 B3.4.18-1 3 DRR99-1581 12/18/99 B 3.4.18-2 41 DRR 10-1702 10/1/10 B 3.4.18-3 41 DRR 10-1702 10/1/10 TAB- B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)
B3.5.1-1 3 DRR99-1581 12/18/99 B 3.5.1-2 41 DRR 10-1702 10/1/10 B 3.5.1-3 3 DRR 99-1581 12/18/99 TAB- B 3.6 CONTAINMENT SYSTEMS B 3.6.1-1 62 DRR 15-2006 10/26/15 B 3.6.1-2 41 DRR 10-1702 10/1/10 B 3.6.1-3 62 DRR 15-2006 10/26/15 B 3.6.1-4 62 DRR 15-2006 10/26/15 B 3.6.1-5 37 DRR 09-0287 3/20/09 B 3.6.1-6 17 DRR 04-0452 5/26/04 B3.6.1-7 62 DRR 15-2006 10/26/15 TAB - B 3. 7 PLANT SYSTEMS B 3.7.7-1 57 DRR 14-1878 9/30/14 B 3.7.7-2 57 DRR 14-1878 9/30/14 B 3.7.7-3 58 DRR 14-2330 11/6/14 B 3.7.7-4 8 DRR 01-0475 5/1/01 B 3.7.8-1 41 DRR 10-1702 10/1/10 Wolf Creek - Unit 1 iii Revision62
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IMPLEMENTED <4>
TAB- B 3.7 PLANT SYSTEMS (continued)
B 3.7.8-2 52 ORR 13-0658 3/28/13 B 3.7.8-3 52 ORR 13-0658 3/28/13 B3.7.13-1 61 ORR 15-0824 4/28/15 B 3.7.13-2 41 ORR 10-1702 10/1/10 B 3.7.13-3 41 ORR 10-1702 10/1/10 B 3.7.17-1 26 ORR 06-0050 2/28/06 B 3.7.17-2 41 ORR 10-1702 10/1/10 B 3.7.17-3 26 ORR 06-0050 2/28/06 B 3.7.19-1 5 ORR 00-0958 8/17/00 B 3.7.19-2 37 ORR 09-0287 3/20/09 B 3.7.19-3 5 ORR 00-0958 12/18/99 B 3.7.20-1 3 ORR 99-1581 12/18/99 B 3.7.20-2 62 ORR 15-2006 10/26/15 B 3.7.20-3 50 ORR 12-1537 8/30/12 B 3.7.20-4 62 ORR 15-2006 10/26/15 B 3.7.20-5 62 ORR 15-2006 10/26/15 B 3.7.20-6 62 ORR 15-2006 10/26/15 B 3.7.20-7 62 ORR 15-2006 10/26/15 B 3.7.20-8 62 ORR 15-2006 10/26/15 B 3.7.20-9 62 ORR 15-2006 10/26/15 B 3.7.20-10 62 ORR 15-2006 10/26/15 B 3.7.20-11 62 ORR 15-2006 10/26/15 B 3.7.21-1 3 ORR 99-1581 12/18/99 B 3.7.21-2 37 ORR 09-0287 3/20/09 B 3.7.21-3 3 ORR 99-1581 12/18/99 B 3.7.21-4 3 ORR 99-1581 12/18/99 B 3.7.22-1 3 ORR 99-1581 12/18/99 B 3.7.22-2 41 ORR 10-1702 10/1/10 B 3.7.22-3 49 ORR 12-064 4/10/12 B 3.7.24-1 60 ORR 15-0529 3/26/15 B 3.7.24-2 60 ORR 15-0529 3/26/15 B 3.7.24-3 60 DRR15-0529 3/26/15 B 3.7.24-4 60 ORR 15-0529 3/26/15 B 3.7.24.5 37 ORR 09-0287 3/20/09 B 3.7.24-6 21 ORR 04-1535 12/1/04 TAB - B 3.8 ELECTRICAL POWER SYSTEMS B3.8.1-1 60 ORR 15-0529 3/26/15 B 3.8.1-2 60 ORR 15-0529 3/26/15 B3.8.1-3 60 ORR 15-0529 3/26/15 B 3.8.11-1 3 ORR 99-1581 12/18/99 B 3.8.11-2 41 ORR 10-1702 10/1/10 B 3.8.11-3 41 ORR 10-1702 10/1/10 B 3.8.11-4 54 ORR 13-2529 10/25/13 B3.8.11-5 41 ORR 10-1702 10/1/10 B 3.8.11-6 41 ORR 10-1702 10/1/10 TAB- B 3.9 REFUELING OPERATIONS Wolf Creek - Unit 1 iv Revision62
LIST OF EFFECTIVE PAGES - TECHNICAL REQUIREMENT MANUAL..-BASES PAGE( 1> REVISION NO. (Zl *CHANGE DOCUMENT~ DATE EFFECTIVE/
IMPLEMENTED (4l B 3.9.7-1 3 DRR 99-1581 12/18/99 B 3.9.7-2 3 DRR 99-1581 12/18/99 B 3.9.9-1 41 DRR 10-1702 10/1/10 B 3.9.9-2 41 DRR 10-1702 10/1/10 B 3.9.9-3 17 DRR 04-0452 5/26/04 TAB- B 3.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING B 3.10.1-1 3 DRR 99-1581 12/18/99 83.10.1-2 37 DRR09-0287 3/20/09 83.10.1-3 3 DRR99-1581 12/18/99 83.10.2-1 3 DRR99-1581 12/18/99 B 3.10.2-2 37 DRR 09-0287 3/20/09 B 3.10.2-3 41 DRR 10-1702 10/1/10 B 3.10.3-1 3 DRR 99-1581 12/18/99 B 3.10.3-2 37 DRR 09-0287 3/20/09 B 3.10.3-3 37 DRR 09-0287 3/20/09 83.10.3-4 3 DRR99-1581 12/18/99 Note 1 The page number is listed on the center of the_bottom of each page.
Note 2 The revision number is listed in the lower right hand corner of each page. The Revision number will be page specific.
Note 3 The change document will be the document requesting the change. Therefore, the change document should be a ORR number in accordance with AP 26A-002.
Note 4 The date effective or implemented is the date the Technical Requirement Bases pages are issued by Document Control.
Wolf Creek- Unit 1 v Revision62
Adam C. Heflin President, Chief Executive Officer and Chief Nuclear Officer March 10, 2016 WM 16-0005 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555
Subject:
Docket No. 50-482: Revision 29 of the Wolf Creek Generating Station Updated Safety Analysis Report Gentlemen:
Pursuant to the updating requirements of 10 CFR 50.71(e), Wolf Creek Nuclear Operating Corporation (WCNOC) is providing its Updated Safety Analysis Report (USAR), Revision 29.
This submittal satisfies the Final Safety Analysis Report (FSAR) updating requirements of the aforementioned regulation. Per the requirement of 10 CFR 54.37(b), there are no newly identified systems, structures, and components that are subject to an aging management review or evaluation of time-limited aging analyses.
Attachment I to this letter provides information relative to changes in regulatory commitments.
This information is provided in accordance with the guidance of Nuclear Energy Institute (NEI) 99-04, "Guidelines for Managing NRC Commitment Changes," Revision 0, July 1999.
Attachment II to this letter describes specific technical changes that have been processed since issuance of the USAR, Revision 28. In addition to these technical changes, editorial changes have been made and are included in Revision 29.
Attachment Ill to this letter provides a discussion of changes made in Revisions 59 through 62 of the Technical Requirements Manual (TRM).
Enclosure I to this letter provides the CD-ROM submittal of the Wolf Creek Generating Station (WCGS) USAR, Revision 29. This submittal satisfies the Final Safety Analysis Report updating requirements of 10 CFR 50. 71 (e)(4). Chapter 2: Site Characteristics; Chapter 3: Design of Structures, Components, Equipment, and Systems; Chapter 8: Electric Power; Chapter 9:
Auxiliary Systems; and Chapter 12: Radiation Protection, are considered sensitive unclassified information and therefore warrant withholding under 10 CFR 2.390.
P.O. Box 411 I Burlington, KS 66839 I Phone: (620) 364-8831 An Equal Opportunity Employer M/F/HCNET
WM 16-0005 Page 2 of 4 Enclosure II to this letter provides a CD-ROM containing the station-controlled drawings that are considered incorporated by reference into the USAR. According to the guidance of NEI 98-03, Revision 1, "Guidelines for Updating Final Safety Analysis Reports," Revision 1, June 1999, the USAR figures that are identical to controlled drawings were relocated from the USAR in Revision 17. Enclosure II is considered sensitive unclassified information and therefore warrants withholding under 10 CFR 2.390. 11 to this letter provides a CD-ROM containing the USAR Fire Hazards Analysis and Quality Program Manual both of which are incorporated by reference into the USAR. The USAR Fire Hazards Analysis is considered sensitive unclassified information and therefore warrants withholding under 10 CFR 2.390.
Enclosure IV to this letter provides a CD-ROM containing EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II. Information from USAR Table 3.11 (B)-1, Plant Environmental Normal Conditions; USAR Table 3.11 (B)-2, Environmental Qualification Parameters for SNUPPS NUREG-0588 (LOCA, MSLB and HELB);
USAR Table 3.11 (B)-3, Identification of Safety-Related Equipment and Components:
Equipment Qualification; USAR Table 3.11 (B)-4, Containment Worst Case Radiation Levels (MRADs); USAR Table 3.11 (B)-5, Containment Spray Requirements; USAR Table 3.11-(B)-8, Exemptions from NUREG-0588 Qualification; USAR Table 3.11 (B)-10, Equipment Added for NUREG-0737; and USAR Figures 3.11 (B)-1 through 3.11 (8)-49, was relocated from the USAR into EQSD-1 and EQSD-11 in Revision 28 and is incorporated by reference into the USAR.
Enclosure IV is considered sensitive unclassified information and therefore warrants withholding under 10 CFR 2.390.
Enclosure V to this letter provides those changes made to the WCGS Unit 1 TRM (Revision 59 through 62) and includes a List of Effective Pages. The WCGS TRM is incorporated by reference into the USAR.
This letter contains no commitments. WCNOC has historically submitted updates to the USAR on March 11 of each year to coincide with the date of issuance of the WCGS operating license and to comply with the requirements of 10 CFR 50.71(e)(4). WCNOC considers that submittals made prior to or on March 11 satisfy the requirements of 10 CFR 50.71 (e)(4).
If you have any questions concerning this matter, please contact me at (620) 364-4000, or Cynthia R. Hafenstine at (620) 364-4204.
Sincerely,
~~
ACH/rlt Attachment I - Regulatory Commitment Management System (RCMS) Changes Attachment II - USAR Changes Processed Since Revision 28 Attachment Ill - Revisions 59 through 62 to the Technical Requirements Manual Enclosure I - CD-ROM containing Updated Safety Analysis Report, Revision 29 Enclosure II - CD-ROM containing Updated Safety Analysis Report Controlled Figure Drawings
WM 16-0005 Page 3 of 4 Enclosure Ill - CD-ROM containing Updated Safety Analysis Report Fire Hazards Analysis and Quality Program Manual Enclosure IV - CD-ROM containing Updated Safety Analysis Report EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II Enclosure V - Technical Requirements Manual Replacement Pages and List of Effective Pages cc: M. L. Dapas (NRC), w/a, w/e C. F. Lyon (NRC), w/a, w/e
_N. H. Taylor (NRC), w/a, w/e Senior Resident Inspector (NRC), w/a, w/e
WM 16-0005 Page 4 of 4 STATE OF KANSAS )
} SS COUNTY OF COFFEY }
Adam C. Heflin, of lawful age, being first duly sworn upon oath says that he is President, Chief Executive Officer and Chief Nuclear Officer of Wolf Creek Nuclear Operating Corporation; that he has read the foregoing document and knows the contents thereof; that he has executed the same for and on behalf of said Corporation with full power and authority to do so; and that the facts therein stated are true and correct to the best of his knowledge, information and belief.
By~1-+--=-~..,,..~,__,.:;...._~~~~~~~
Adam . Heflin President, Chief Ex cutive Officer and Chief Nuclear Officer SUBSCRIBED and sworn to before me this lD+I{ day of r1a-r~ '2016.
RHONDA L. TIEMEYER Notary Public My Appointment Expires January 11, 2018 . '.
Expiration Date ao~
~ .
'I, ().D '~
Attachment I to WM 16-0005 Page 1 of 4 Attachment I to WM 16-0005 Regulatory Commitment Management System (RCMS) Changes
Attachment I to WM 16-0005 Page 2 of 4 Commitment Changes Commitment No. RCMS 1987-207 from letter WM 87-0305, dated November 11, 1987 Commitment
Description:
A Preventative Maintenance (PM) procedure is being modified to inspect the bolts and lubricate the doors gears semi-annually for this and similar doors.
Change to Commitment: The frequency of the PM was extended from semi-annually to "maintained on a specified frequency." This will change the performed frequency timeframe from every six months to every 18 months.
Justification: The review of PMs, work order histories from 2012 to current, and testimonies of Maintenance Technicians have indicated satisfactory results have been obtained for PM performed. In Accordance with INPO AP-913, Section 3.4.1, PM frequencies may be adjusted based on ~tation equipment operating experience. Decreasing the frequency will still meet the intent of the commitment and meet the guidance provided in INPO AP-913.
Commitment No. RCMS 1994-250 from WO 94-0220, dated December 30, 1994 Commitment
Description:
Incident Investigation Team (llT) leaders to Investigation Coordinators (ICs) will be trained on the llT procedure. The training will focus on the administrative requirements established in Instruction Al 288-003, "Incident Investigation Team," and the preferred investigative techniques. Training is scheduled to commence in February 1995 and will be available on an ongoing basis as needed to enhance and maintain personnel understanding and abilities. If an llT is initiated prior to the commencement of training in February 1995, then the team leader and the ICs will be trained at the beginning of the llT.
Change to Commitment: This commitment has been closed and archived.
Justification: This commitment was created in rei;;ponse to NOV 9413-01. The immediate actions described in the commitment were satisfied in 1995. This commitment was to be ongoing to prevent reoccurrence. Due to changes that have occurred in the station and industry, this commitment is outdated and no longer necessary to achieve compliance.
Commitment No. RCMS 1994-251 from letter WO 94-0220, dated December 30, 1994 Commitment
Description:
Procedure AP 34E-001, "Self Assessment Process," has been divided into two separate sections to provide clear administrative guidance on 1) llTs (Instruction Al 288-003, "Incident Investigation Team"); and 2) Other Types of Self Assessments (Procedure AP 28D-001, "Self-Assessment"). The new administrative instruction for llTs will establish, as an llT Team member, an Investigative Coordinator (IC) position assignment. The ICs responsibilities will include ensuring that the administrative requirements of this procedure are adhered to by the llT. This separation of procedural requirements for llTs and other types of self-assessments is consistent with past WCNOC practice and will more appropriately focus personnel attention on which requirements are applicable to which types of assessments. These procedures have been approved.
Attachment I to WM 16-0005 Page 3 of 4 Change to Commitment: This commitment has been closed and archived.
Justification: This commitment was written to achieve compliance, and prevent reoccurrence.
Due to changes that have occurred in the station and industry, this commitment is outdated and no longer necessary to achieve compliance.
Commitment No. RCMS 1996-156 from letter WM 96-0081, dated July 31, 1996 Commitment
Description:
Separately the corrective action procedures were revised to require independent reviewers or the individual who perform the root cause analysis to be trained in root cause techniques.
Change to Commitment: This commitment has been closed and archived.
Justification: This commitment was made in response to Enforcement Action 96-124, Violation l.C, to minimize the recurrence of a known condition adverse to quality. Due to a change in plant and industry standards, this commitment is no longer the most effective way to minimize recurrence, and is unnecessary.
Commitment No. RCMS 2012-457 from letter WM 12-0023, dated August 2, 2012 Commitment
Description:
Wolf Creek Nuclear Operating Corporation (WCNOC) will mitigate adverse effects of column closure water hammer in the ESW system to within acceptable design parameters. {Transferred from 2013-478} ESW Water Hammer: WCNOC will install the modification to mitigate water hammer during the Mid-Cycle Outage. Commitment revised by letter WM 14-0011 to "Install a modification to mitigate the adverse effects of column closure water hammer in the ESW System."
Change to Commitment: This commitment has been satisfied. The commitment has been changed to closed and archived.
Justification: This commitment was created in response to Notice of Violation EA-12-135 for failure to take corrective actions to prevent the reoccurrence of water hammer events and system leaks. Based on the completion of the modification work orders (WO) 14-390646-068 and 14-390647-079) and the declaration of operability of both "A" and "B" trains by Operations, it has been determined that compliance has been achieved and the commitment is satisfied.
Commitment No. RCMS 2014-496 from letter WM 14-0013, dated May 8, 2014 Commitment
Description:
WCNOC commits to ensuring the reliability of the four containment coolers in the future by, in order of preference, either replacing the tube bundles with new based on material availability, inspection of the tube bundles, or testing of the existing tube bundles. These actions will be completed prior to restart from Refueling Outage 20.
Attachment I to WM 16-0005 Page 4 of 4 Change to Commitment: This commitment has been satisfied. The commitment has been closed and archived.
Justification: Both "A" and "B" trains of the containment coolers were declared operable per Technical Specification 3.6.6 by Operations due to the completion of Work Orders (WO) 14-388658-036 and WO 14-388659-067, respectively, and the acceptance of Design Change Packages (DCP) 14732 and DCP 14003, respectively.
1 to WM 16-0005 Page 1 of 10 Attachment II to WM 16-0005 USAR Changes Processed Since Revision 28
Attachment II to WM 16-0005 Page 2 of 10 USAR Change Request Description 15-003 REVISE THE USAR TO UPDATE THE STATEMENT THAT NO STEAM GENERATOR TUBE FLUID-ELASTIC VIBRATION WILL OCCUR DURING STEADY STATE CONDITIONS AS WELL AS DURING OPERATING TRANSIENTS. AN ANALYSIS TO DETERMINE IF STEAM GENERATOR TUBES ARE SUBJECT TO POSSIBLE FATIGUE FAILURE DURING THEIR LIFETIME, AS DESCRIBED IN WCAP-17990-P, "WOLF CREEK U-BEND VIBRATION AND FATIGUE ASSESSMENT," IDENTIFIED SEVENTEEN (17) TUBES THAT MAY BE SUBJECT TO FATIGUE FAILURE BASED ON THE PINNED AND NON-OCCLUDED CASE. THE 17 TUBES WERE PLUGGED DURING REFUEL 20.
Page: 5.4-23 15-004 REVISE THE USAR TO REFLECT THE RESTRICTION OF FLOW FROM THE SAFETY RELATED PORTION TO THE NON-SAFETY RELATED PORTION OF THE COMPONENT COOLING WATER (CCW) SYSTEM BY INSTALLING SAFETY RELATED FLOW RESTRICTION DEVICES BETWEEN THEM.
Page: 9.2-17 Page: 9.2-16 Page: 9.2-14 Table: 9.2-13 Sheet: 2 Table: 9.2-9 Sheet: 2 Table: 9.2-10 Sheet: 2 Table: 9.2-11 Sheet: 2 15-005 REVISE THE USAR TO REFLECT THE REMOVAL OF THE BLADDER FROM THE WASTE EVAPORATOR CONDENSATE TANK.
Page: 11.2-8 Page: 11.2-7 Figure: 11.1A-1 15-006 REVISE THE USAR TO REFLECT THE ABANDONMENT OF PASS IN PLACE.
ALL PIPING IS CUT AND CAPPED AS CLOSE TO THE PASS WET PANEL AS POSSIBLE AND ALL ELECTRICAL POWER AND EXTERNAL ELECTRICAL CONNECTIONS TO AND FROM THE PASS WERE REMOVED. (AMENDMENT NO. 137)
Page: 12.2-3 Page: 8.1-15 Page: 18.3-12 Page: 18.3-11 Table: 6.2.4-1 Table: 6.2.4-1 Sheet: 2 Table: 9.2-9 Sheet: 2 Table: 9.2-10 Sheet: 2 Table: 9.2-11 Sheet: 2 Figure: 6.2.4-1 Sheet: 42 Figure: 6.2.4-1 Sheet: 42b Figure: 6.2.4-1 Sheet: 45a Figure: 6.2.4-1 Sheet: 67 Figure: 6.2.4-1 Sheet: 69 Figure: 6.2.4-1 Sheet: 70 Figure: 6.2.4-1 Sheet: 71
Attachment II to WM 16-0005 Page 3of10 USAR Change Request ,Description 15-007 REVISE THE USAR TO REFLECT THAT CYCLE 21 FRESH FUEL (REGION 23)
WILL INCLUDE DESIGNS FOR THE STANDARDIZED DEBRIS FILTER BOTTOM NOZZLE (SDFBN); ROBUST PROTECTIVE GRID (RPG), AND COMBINATION BOTTOM GRID NOT PREVIOUSLY USED AT WOLF CREEK GENERATING STATION. SOFTWARE FOR CYCLE 21 RELOAD CORE HAS CHANGED FROM PHOENIX-P/ANC8 TO NEXUS/PARAGON/ANC9.
Page: 4.2-14 Page: 4.2-12 Page: 4.2-11 Page: 4.2-13 Page: 4.2-18 Page: 4.2-20 Page: 4.3-35 Page: 4.3-36 Page: 4.3-37 Page: 4.3-38 Page: 4.3-39 Page: 15.0-1 Page: 4.1-2 Page: 15.0-20 Page: 4.1-4 Page: 4.2-15 Page: 4.2-16 Page: 4.2-17 Page: 4.2-19 Page: 4.2-21 Page: 4.2-22 Page: 4.2-23 Page: 4.2-24 Page: 4.2-25 Page: 4.2-26 Page: 4.2-27 Page: 4.2-28 Page: 15.0-15 Table: 4.1-1 Sheet: 4 Table: 4.1-2 Sheet: 4 Table: 15.0-2 Sheet: 2 Table: 15.0-2 Sheet: 3 Figure: 4.2-2F 15-008 REVISE THE USAR TO REFLECT REVISED FLOODING CALCULATIONS.
CALCULATIONS WERE REVISED AS A RESULT OF CONDITION REPORTS 26050 AND 27904.
Table: 3.6-6 Table: 3.6-6 Sheet: 2 Table: 38-1 Sheet 26 15-009 REVISE THE USAR TO REFLECT MAINTENANCE OF THE WATER SEAL ASSOCIATED WITH ALL THREE CONDENSER EXPANSION JOINTS DRY EXCEPT FOR POST MAINTENANCE TESTING FOLLOWING NEW JOINT INSTALLATION AND IN TIMES WHEN AN EXPANSION JOINTS VACUUM SEAL HAS BEEN BREACHED.
Page: 10.4-4 Page: 10.4-2 15-010 REVISE THE USAR TO REFLECT THE TIE IN OF A WIND FARM INTO THE LACYGNE 345 Kv LINE.
Page: 8.2-10 Page: 8.2-6 Page: 8.2-3 Figure: 8.2-1 Figure: 8.2-5 15-011 REVISE THE USAR TO REFLECT THE INSTALLATION OF TEMPORARY MODIFICATION ORDER (TMO) 15-015-EM-OO WHICH INSTALLED A LINE CRIMP KILL ON A PORTION OF THE SAFETY INJECTION SYSTEM TEST LINE SUBSYSTEM, WHICH BLOCKS A PORTION OF THE TEST LINE PIPING. THE LINE CRIMP IS INSTALLED TO STOP LEAKAGE OF NITROGENATED WATER OUT OF THE "A" ACCUMULATOR THROUGH VALVE EPHV8879A. THE TMO WILL BE REMOVED NO LATER THAN PLANT STARTUP AT THE END OF REFUEL 21(FALL2016).
Page: 6.3-39 1 to WM 16-0005 Page 4of10
.USAR Change Request Description 15-012 REVISE THE USAR TO ADD THE BIOGRAPHY FOR S. A. BELL BECAUSE HE IS NOW A QUALIFIED SHIFT MANAGER.
Page: 13.1-19 15-013 REVISE THE USAR TO INCORPORATE CHANGES RESULTING FROM AMENDED NRC FEDERAL REGULATIONS PUBLISHED IN THE FEDERAL REGISTER VOL 79, PAGES 65776 THROUGH 65814, ON NOVEMBER 5, 2014. REGULATIONS 50.54, 50.55, AND 50.55a WERE CHANGED.
Page: 3A-36 Page: 3A-60 Page: 3A-63 Table: 1.3-4 Sheet: 19 Table: 1.3-4 Sheet: 20 Table: 1 .3-4 Sheet: 16 Table: 1.3-4 Sheet: 17 Table: 1.3-4 Sheet: 18 15-014 REVISE THE USAR TO DELETE COMMITMENT WHICH REQUIRES A ONE TIME INSPECTION OF DIESEL FIRE PUMP OIL TANK THAT IS TO BE PERFORMED BETWEEN 10 AND 2 YEARS PRIOR TO THE PERIOD OF EXTENDED OPERATION. CHANGE PACKAGE 13923 INSTALLED A NEW DIESEL FIRE PUMP FUEL OIL TANK.
Page: 18A-9 Page: 18A-10 15-015 REVISE THE USAR TO REFLECT THE REMOVAL OF THE DRY TUNNEL SUMP VOLUME IN SECTION 5.2.5.2.3. THE SUMP IS OPERATED WITH LEVEL ON-SCALE.
Page: 5.2-42 15-016 REVISE THE USAR TO UPDATE INFORMATION FOR CONTAINMENT AIR COOLERS A, B, AND C COIL REPLACEMENT. INFORMATION UPDATED INCLUDES THE MINIMUM CAPACITY FOR AIR-SIDE FLOW RATE THROUGH FAN IN DESIGN BASIS ACCIDENT CONDITIONS, AND DUTY BTU/HR FOR NORMAL CONDITIONS.
Table: 6.2.1-3 Sheet: 2 Table: 6.2.2-2 Sheet: 2 Table: 6.2.2-2 Sheet: 4 15-017 REVISE THE USAR TO REFLECT THE REPLACEMENT OF CONTAINMENT AIR COOLER "D" WITH A STAINLESS STEEL COOLER.
Table: 6.2.1-57C Figure: 6.2.1-15 1 to WM 16-0005 Page 5of10 USAR Change Request Description 15-018 REVISE THE USAR TO REFLECT THAT THE HYDROGEN RECOMBINERS ARE NO LONGER TESTED AND THE UNITS POWER SUPPLY BREAKERS ARE MAINTAINED IN THE OFF POSITION. PLANT PROCEDURES HAVE BEEN CHANGED ACCORDINGLY. LICENSE AMENDMENT REQUEST 157 DELETED THE TECHNICAL SPECIFICATION REQUIREMENT FOR THE HYDROGEN RECOMBINERS.
Page: 6.2-87 Page: 6.2-82 Page: 6.2-75 Page: 6.1-2 15-019 REVISE THE USAR, CHAPTER 3.11(B) AND 3.0 FIGURE TABLE OF CONTENTS TO CLARIFY THE CONNECTION BETWEEN THE USAR AND EQSD-1 (EQUIPMENT QUALIFICATION DESIGN BASIS DOCUMENT. SOME 3.11(B)
TABLES AND FIGURES WERE MOVED TO EQSD-1 IN REVISION 28 OF THE USAR.
Page: 3.11 (B)-17 Page: 3.11 (B)-15 Page: 3.11 (B)-4 15-020 REVISE THE USAR TO REFLECT REVISIONS TO CALCULATIONS AN-06-017, REV 1, AND AN-14-001, REV 0. AN-06-017 UPDATES THE REACTIVITY FEEDBACK IN THE STEAM LINE BREAK ACCIDENT ANALYSIS. AN-14-001 HAS BEEN ISSUED FOR CYCLE 21 AND RECALCULATED THE MINUMUM DNBR TO OCCUR AT 149.6 SECONDS.
Page: 15.1-16 Table: 15.1-1 Sheet: 2 Figure: 15.1-20a Figure: 15.1-20 Figure: 15.1-19 Figure: 15.1-18 Figure: 15.1-17 Figure: 15.1-16 Figure: 15.1-15 Figure: 15.1-11 a 15-021 REVISE THE USAR TO INCLUDE TEMPORARY SCAFFOLDING MATERIAL IN TABLE 1.7-4. THIS SCAFFOLDING MATERIAL IS SUPPORTING CAMERAS TO MINIMIZE WORKER EXPOSURES AS PART OF THE ALARA PROGRAM.
Table: 1.7-4 Sheet: 5 15-022 REVISE THE USAR TO UPDATE TABLE 1.7-4 WITH SCAFFOLD THAT WILL REMAIN IN THE PLANT THROUGHOUT THE NEXT USAR UPDATE CYCLE.
Table: 1.7-4 Sheet: 4 Table: 1.7-4 Sheet: 3 Table: 1.7-4 Sheet: 1 Table: 1.7-4 Sheet: 2 15-023 REVISE THE USAR TO REFLECT THAT INSTALLATION OF CANOPY SEAL CLAMP ASSEMBLIES ARE AUTHORIZED AT ANY CANOPY SEAL LOCATION.
Page: 5.2-36
Attachment II to WM 16-0005 Page 6 of 10 USAR Change Request Description 15-024 REVISE THE USAR TO INCORPORATE LICENSE AMENDMENT REQUEST NO.
214, REVISE THE FIRE PROTECTION PROGRAM RELATED TO ALTERNATIVE SHUTDOWN CAPABILITY.
Page: 9.58-0 Table: 9.5E-1 Sheet: 27 Table: 9.5E-1 Sheet: 26 Table: 1.6-4 Sheet: 2 15-025 REVISE THE USAR TO INCORPORATE LICENSE AMENDMENT REQUEST (LAR) NO. 213, REVISE TECHNICAL SPECIFICATION 5.6.5, "CORE OPERATING LIMITS REPORT (COLR)," TO ADD ASTRUM TO THE LIST OF ANALYTICAL METHODS.
Page: 6.2-40 Page: 6.2-41 Page: 6.2-97 Page: 15.6-19 Page: 15.6-20 Page: 15.6-21 Page: 15.6-22 Page: 15.6-23 Page: 15.6-24 Page: 15.6-25 Page: 15.6-26 Page: 15.6-27 Page: 15.6-35 Page: 15.6-36 Page: 15.6-32 Page: 15.6-29 Page: 15.6-38 Page: 15.6-37 Page: 15.6-34 Page: 15.6-33 Page: 15:6-28 Page: 15.6-31 Page: 15.6-30 Page: 15.6-39 Table: 15.6-10 Sheet: 2 Table: 15.6-13 Table: 15.6-11 Table: 15.6-98 Table: 15.6-10 Table: 15.6-9 Table: 6.2.1-66 Sheet: 2 Table: 6.2.1-66 Sheet: 1 Table: 6.2.1-65 Table: 6.2.1-64 Table: 6.2.1-63 Sheet: 5 Table: 6.2.1-63 Sheet: 4 Table: 6.2.1-63 Sheet: 3 Table: 6.2.1-63 Sheet: 2 Table: 6.2.1-63 Sheet: 1 Figure: 15.6-128 Figure: 15.6-5 Figure: 15.6-13 Figure: 15.6-121 Figure: 15.6-12H Figure: 15.6-12G Figure: 15.6-12F Figure: 15.6-12E Figure: 15.6-15 Figure: 15.6-12C Figure: 15.6-16 Figure: 15.6-12A Figure: 15.6-11 Figure: 15.6-1 O Figure: 15.6-9 Figure: 15.6-8 Figure: 15.6-7 Figure: 15.6-4 Figure: 15.6-120 Figure: 15.6-24A Figure: 6.2.1-86 Figure: 6.2.1-87 Figure: 15.6-30 Figure: 15.6-29 Figure: 15.6-28 Figure: 15.6-27 Figure: 15.6-26 Figure: 15.6-14 Figure: 15.6-248 Figure: 15.6-12 Figure: 15.6-23 Figure: 15.6-22 Figure: 15.6-21 Figure: 15.6-20 Figure: 15.6-19 Figure: 15.6-18 Figure: 15.6-17 Figure: 15.6-25
Attachment II to WM 16-0005 Page 7of10 USAR Change Request Description 15-026 REVISE THE USAR TO ADD ACTIONS IMPLEMENTED TO DATE TO COMPLY WITH NRC ORDERS EA 12-049 AND EA 12-051. THIS USAR CHANGE DESCRIBES THE WOLF CREEK RESPONSE TO BEYOND-DESIGN-BASIS EXTERNAL EVENT FUKUSHIMA RELATED REQUIRED ACTIONS.
Page: 10.4-48 Page: 9.1-28 Page: 30-3 Page: 30-2 Page: 30-1 15-027 REVISE THE USAR TO REFLECT THE ADDITION OF THE ESSENTIAL SERVICE WATER (ESW) COLUMN CLOSURE WATER HAMMER TOWER. THIS UPDATE INCLUDES DISCUSSION-OF THE ESW VERTICAL LOOP CHASE STRUCTURE AND LOOP CHASE PIPING AND COMPONENTS.
Page: 3.8-76 _Page: 1.2-7 Page: 1.4-12 Page: 3.8-70 Page: 3.4-2 Page: 3.5-16 Page: 3.5-17 Page: 3.7(8)-1 Page: 3.7(8)-4 Page: 3.8-60 Page: 3.8-63 Page: 3.8-65 Page: 1.1-2 Page: 3.8-72 Page: 3.8-71 Page: 3A-23 Page: 3A-40 Page: 3C-2 Page: 9.2-11 Page: 9.2-6 Page: 9.2-7 Page: 9.2-8 Page: 9.2-9 Page: 9.2-10 Page: 9.4-94 Table: 3.3-1 Table: 3.7(8)-7E Table: 3.7(8)-70 Table: 3.7(8)-7C Table: 3.7(8)-78 Table: 3.7(8)-7A Table: 3.9(8)-16 Sheet: 17 Table: 3.7(8)-3 Table: 3.5-2 Table: 1.1-1 Sheet: 2 Table: 3.4-1 Table: 3.7(8)-7H Table: 3.2-1 Sheet: 3 NOTES Table: 3.2-1 Sheet: 21 Table: 3.2-1 Sheet: 20 Table: 3.2-1 Sheet: 6 Table: 2.5-54 Table: 2.5-53 Table: 2.5-52 Table: 1.3-2 Sheet: 3 Table: 3.4-2 Table: 3.7(8)-7Q Table: 3.7(8)-7A8 Table: 3.7(8)-7Z Table: 3.7(8)-7Y Table: 3.7(8)-7X Table: 3.7(8)-7W Table: 3.7(8)-7V Table: 3.7(8)-7U Table: 3.7(8)-7T Table: 3.7(8)-7F Table: 3.7(8)-7R Table: 3.7(8)-7G Table: 3.7(8)-7P Table: 3.7(8)-70 Table: 3.7(8)-7N Table: 3.7(8)-7M Table: 3.7(8)-7L Table: 3.7(8)-7K Table: 3.7(8)-7J Table: 3.7(8)-71 Table: 3.7(8)-7M Table: 3.7(8)-7S Figure: 3.8-102 Figure: 2.4-3 Sheet: 1 Figure: 2.5-59 Figure: 2.5-106i Figure: 3.5-1 Figure: 3.5-2 Figure: 3.8-84 Figure: 3.8-99 Figure: 2.3-20 Figure: 3.8-101 Figure: 3.8-120 Figure: 3.8-103 Figure: 3.8-103 Sheet: 2 Figure: 3.8-104 Figure: 3.8-104 Sheet: 2 Figure: 3.8-116 Figure: 3.8-118 Figure: 3.8-119 Figure: 3.8-100
Attachment II to WM 16-0005 Page 8 of 10 USAR Change Request Description 15-028 REVISE THE USAR TO REFLECT THE TRAINING STANDARD PASSING CRITERIA TO 80 PERCENT OR GREATER. THIS CRITERIA WAS ESTABLISHED BY THE JOINT TRAINING CRITERIA.
Page: 13.2-10 15-029 REVISE THE USAR TO RELECT A CHANGE TO USAR SUPPLEMENT A1.26 FOR EXAMINATION OF MANHOLES IN THE PERIOD OF EXTENDED OPERATION. CURRENTLY A1.26 STATES THAT ALL ELECTRICAL MANHOLES WILL BE INSPECTED AT LEAST ONCE EVERY TWO YEARS.
PLANT DATA FOR ELECTRICAL MANHOLES WITH SUMP PUMPS DEMONSTRATES THAT AN INSPECTION FREQUENCY OF AT LEAST ONCE EVERY FIVE YEARS IS APPROPRIATE. THE PROPOSED CHANGE IS TO DISTINGUISH THE DIFFERENCE BETWEEN ELECTRICAL MANHOLES WITH AND WITHOUT SUMP PUMPS.
Page: 18A-16 Page: 18A-15 15-030 REVISE THE USAR TO REFLECT THE REPLACEMENT OF THE OBSOLETE WESTINGHOUSE INVERTERS THAT NORMALLY FEED THE 120 VAC VITAL BUSES. FOUR NEW 120 VAC SAFETY RELATED INVERTERS ARE EQUIPPED WITH AN INTEGRAL CONSTANT VOLTAGE TRANSFORMER CAPABLE OF ACTING AS THE ALTERNATE SOURCE FOR THE VITAL BUS WHEN ITS INVERTER SECTION IS INOPERABLE.
Page: 8.3-43 Page: 8.3-37 Page: 8.3-21 Page: 8.1-26 Page: 8.1-25 Page: 7.7-30 Table: 8.3-4 Sheet: 30 Table: 7.4-6 Sheet: 38 Table: 8.3-1 Table: 8.3-1 Sheet: 2 Table: 8.3-4 Sheet: 2 Table: 8.3-4 Sheet: 27 Table: 7.4-6 Sheet: 35 Table: 8.3-4 Sheet: 29 Table: 3.10(N)-1 Table: 8.3-4 Sheet: 31 Table: 8.3-4 Sheet: 32 Table: 8.3-4 Sheet: 33 Table: 8.3-4 Sheet: 34 Table: 8.3-4 Sheet: 35 Table: 7.4-6 Sheet: 34 Table: 8.3-4 Sheet: 28 1 to WM 16-0005 Page 9of10 USAR Change Request Description 15-031 REVISE THE USAR TO MAKE EDITORIAL CHANGES SUCH AS GRAMMAR AND SPELLING CORRECTIONS, PROPER IMPLEMENTATION OF PREVIOUSLY INCORPORATED CHANGES, UPDATE CHAPTER 13 DUE TO LEADERSHIP REALIGNMENT, DEPARTURES AND NEW HIRES.
Page: 6.4-8 Page: 3.5-10 Page: 3.5-14 Page: 3.5-16 Page: 3.6-22 Page: 3.9(8)-21 Page: 4.4-34 Page: 6.2-32 Page: 6.2-36 Page: 18A-20 Page: 6.3-22 Page: TOC Page: 11 .4-8 Page: 13.1-5 Page: 13.1-13 Page: 13.1-14 Page: 13.1-21 Page: 18A-5 Page: 18A.1-43 Page: 18A-18 Page: 5.2-5 Page: 6.2-79 Table: 3.2-3 Sheet: 3 Table: 7.2-3 Table: 9.2-3 Table: 9.2-3 Sheet: 2 Table: 3.2-3 Sheet: 5 Table: 11.5-3 Figure: 6.2.4-1 Sheet: 67 Figure: 6.2.4-1 Sheet: 45a Figure: 13.1-1 Figure: 6.5-5 16-001 REVISE THE USAR TO UPDATE TABLES 9.2-9, SHEET 2, AND TABLE 9.2-10, SHEET 2, TO REFLECT THE OBSERVED VALUE OF CCW FLOW RATE TO THE NON-VITAL PRIMARY SAMPLING SYSTEM COOLERS DUE TO THE COMPONENT COOLING WATER SYSTEM DUE TO MODIFICATION 13540.
Figure: 9.2-9 Sheet: 2 Figure: 9.2-10 Sheet: 2 16-002 REVISE THE USAR TO REFLECT INSTRUMENT UNCERTAINITY THAT HAD NOT BEEN ADDRESSED IN THE CONTAINMENT PRESSURE-TEMPERATURE CALCULATIONS. THE LOSS OF COOLANT ACCIDENT AND MAIN STEAM LINE BREAK LIMITING CASES WERE RE-RUN WITH A 10 DEGREE F ALLOWANCE FOR INSTRUMENT UNCERTAINITY TO VERIFY PRESSURE AMO TEMPERATURE LIMITS WERE NOT EXCEEDED. THE CHANGE ALSO REFLECTS A TIME DELAY FOR CREDITING THE CONTAINMENT COOLERS FROM 70 SECONDS TO 250 SECONDS TO ALLOW FOR A POTENTIAL WATER HAMMER MITIGATION MODIFICATION.
Page: 6.2-39 Page: 6.2-38 Page: 6.2-14 Page: 6.2-9 Page: 6.2-8 Table: 6.2.1-60 Table: 6.2.1-59 Table: 6.2.1-58 Table: 6.2.1-9 Sheet: 2 Table: 6.2.1-9 Table: 6.2.1-8 Table: 6.2.1-6 Table: 6.2.1-5 Table: 6.2.1-3 Sheet: 2 Table: 6.2.1-2 Figure: 6.2.1-84 Figure: 6.2.1-83 Figure: 6.2.1-82 Figure: 6.2.1-81 Figure: 6.2.1-25 Figure: 6.2.1-23 Figure: 6.2.1-21 Figure: 6.2.1-19 Figure: 6.2.1-17 Figure: 6.2.1-13 Figure: 6.2.1-7 Figure: 6.2.1-1 1 to WM 16-0005 Page 10of10 USAR Change Request Description 16-003 REVISE THE USAR TO REFLECT TWO NEW SHIFT MANAGERS. ERIC CARLSON AND ERIC MARTINSON ARE BEING ADDED.
Page: 13.1-20 Page: 13.1-19 16-004 REVISE THE USAR TO REFLECT THE ESSENTIAL SERVICE WATER VERTICAL LOOP CHASE IMPACT ON THE OILY WASTE SYSTEM.
Page: 9.3-21 16-005 REVISE THE USAR TO CORRECT TABLE 9.2-3, AUXILIARY FEEDWATER PUMP ROOM COOLER FLOW FROM 100 PGM WHILE IN ACCIDENT CONDITION TO 128 GPM. TUBE MATERIAL IS ALSO BEING CORRECTED.
Table: 9.2-2 Table: 9.2-3 Table: 9.2-4 Table: 9.4-8 Sheet: 6 Table: 9.4-8 Sheet: 7 Table: 9.4-8 Sheet: 8 16-006 REVISE THE USAR TO ADD P.C. MOORE AS OPERATIONS SUPERINTENDENT.
Page: 13.1-19 Page: 13.1-18 Page: 13.1-17 11 to WM 16-0005 Page 1 of 5 Attachment Ill to WM 16-0005 Revisions 59 through 62 to the Technical Requirements Manual
Attachment Ill to WM 16-0005 Page 2 of 5 REVISIONS TO THE TECHNICAL REQUIREMENTS MANUAL {TRM)
1. Technical Requirements Manual (TRM) Table TR 5.2.1-1, footnote (a) was revised to reflect the correct Section 5.2 Technical Specification (TS). Specifically, footnote (a) refers to 5.2.2f. and the correct reference is 5.2.2e. Footnote (a) pertains to the qualifications of the STA (Shift Technical Advisor) that are required by TS 5.2.2e ..
Additionally, T.S 5.2.2f. does not exist.
2. Technical Requirement (TR) 3.4.17, "Structural Integrity," Bases pages B 3.4.17-1, B 3.4.17-3, B 3.4.17-7, and B 3.4.17-9 were revised to refer to NRC Inspection Manual Chapter 0326 instead of Regulatory Issue Summary (RIS) 2005-20. NRC Inspection Manual Chapter (IMC) 0326, "Operability Determinations & Functionality Assessments for Conditions Adverse to Quality or Safety," was issued in January 2014 and replaced the Inspection Manual Part 9900 Technical Guidance that was issued by RIS 2005-20. A review of the description of changes associated with IMC 0326 determined that there were no substantive changes to the guidance in Appendix C.10, C.11 and C.12 which was the guidance used for TRB 3.4.17.
3. The TR 3.7.24, TR Bases wording was revised from:
"An electrical penetration room cooler can be capable of providing cooling even though it may be nonfunctional (e.g. Essential Service Water System is inoperable but service water is available to the room cooler)."
to:
"If the associated Essential Service Water train is unavailable or inoperable, and service water is available as a cooling medium to the electrical penetration room cooler, the room cooler is considered capable of providing cooling."
Condition Report (CR) 86691 identified that the above TR Bases wording resulted in an entry into Required Action C.1 with a 7 day Completion Time as it appeared to the control room crew that the statement required the electrical penetration room cooler to be nonfunctional when ESW is inoperable. The wording was revised to provide clarification consistent with the engineering disposition for configuration change package (CCP) 09816. Additionally, the TR 3.7.24 Bases was revised to refer to NRC Inspection Manual Chapter 0326 instead of RIS 2005-20.
4. TR 3.8.1, "Offsite Power System - Transmission Network," and the associated Bases were revised to reflect a modification that splits the LaCygne 345kV transmission line into the Wavery-LaCygne 345 kv transmission line. Westar Energy notified WCNOC that the Southwest Power Pool has issued a directive to install a Wind Farm (approximately 200MW) that will be tied into the LaCygne 345kV Line approximately 5 miles from WCGS.
The work involves installation of the Waverly Switching Station that splits the LaCygne 345kV line into two line segments, a Wolf Creek to Waverly Switching Station 345kV Line and a Waverly Switching Station to LaCygne 345kV Line as well as adding an approximate 5 miles of 345kV Transmission line from the Waverly Switching Station to the Waverly Collector Sub (tie in point for the Wind Farm). The configuration of the Waverly Switching Station is a ring bus design.
Attachment Ill to WM 16-0005 Page 3 of 5
5. TR 3.3.15, "Source Range Neutron Flux," and associated Bases was revised to delete the requirement for a CHANNEL OPERATIONAL TEST (TSR 3.3.15.2) in MODES 3, 4, and 5 with the Rod Control System not capable of rod withdrawal and all control rods fully inserted.
Prior to the conversion to the Improved Technical Specifications (Amendment No. 123, the Current Technical Specifications, Function 6.b (Source Range, Neutron Flux Shutdown) .Mode of Applicability was 3, 4, 5 and did not differentiate as to whether the Rod Control System was capable or incapable of rod withdrawal or one or more rods not fully inserted. The Improved Standard Technical Specifications (ISTS) (NUREG-1431, Rev 1, and TSTF-135) did not include requirements for Source Range Neutron Flux in MODE 3, 4, 5 with the Rod Control System incapable of rod withdrawal. During the conversion to the ITS, Description of Change (DOC) 1-38-R was applied to this function to relocate the Source Range Neutron Flux monitoring function (i.e., Rod Control System incapable of rod withdrawal) to the TRM. When these requirements were relocated, the existing surveillance requirements were relocated as well.
TR 3.3.15 required two channels of Source Range Neutron Flux to be FUNCTIONAL to ensure the capability to monitor core neutron levels and provide indication of reactivity changes in MODES 3, 4, and 5 with the Rod Control System not capable of rod withdrawal and all control rods fully inserted. The specification included three surveillance requirements, a CHANNEL CHECK (TSR 3.3.15.1 ), a CHANNEL OPERATIONAL TEST (TSR 3.3.15.2), and a CHANNEL CALIBRATION (TSR 3.3.15.3). The CHANNEL OPERATIONAL TEST (TSR 3.3.15.2) is satisfied by procedures STS IC-231 and STS IC-232. The purpose of a CHANNEL OPERATIONAL TEST is to verify and adjust, as necessary, alarm, interlock, and trip setpoints required for channel OPERABILITY such that the setpoints are within the necessary range and accuracy. For the purpose of monitoring core neutron levels, there are no required alarm, interlock or trip setpoints. As such, the requirement to a CHANNEL OPERATIONAL TEST of the source range monitors in MODES 3, 4, and 5 with the Rod Control System not capable of rod withdrawal and all control rods fully inserted is not necessary since the source range monitors are only required for monitoring.
Additionally, TSR 3.3.15.2 specifically excluded the Gammametrics source range instruments because they do not have any required alarm, interlock or trip setpoints.
Technical Specification 3.9.3, "Nuclear Instrumentation," requires two source range neutron flux monitors to be OPERABLE in MODE 6 to provide a signal to alert the operator to unexpected changes in core reactivity such as an improperly loaded fuel assembly. This specification only requires a CHANNEL CHECK and CHANNEL CALIBRATION. There is not a CHANNEL OPERATIONAL TEST surveillance requirement.
Attachment Ill to WM 16-0005 Page 4 of 5
6. The TR 3.3.19 Bases, References Section, was revised to reference Addendum 4 to WCAP-12472-P-A, "BEACON Core Monitoring and Operations Support System." The BEACON Power Distribution Monitoring System software was updated from BEACON Version 6 to BEACON Version 7 which incorporates the methodology of WCAP-12472-P-A, Addendum 4. The BEACON Power Distribution Monitoring System is used for periodic measurement of the core power distribution to confirm operation within design limit, and periodic calibration of the excore detectors. The update of the BEACON PDMS software from BEACON Version 6 to BEACON Version 7 is consistent with the NRC approved WCAP-12472-P-A, Addendum 4.
7. TR 3.3.16, "Explosive Gas Monitoring Instrumentation" and associated TR Bases were revised to include a new Condition to restore a required nonfunctional channel to FUNCTIONAL status in 30 days. This results in the re-lettering of existing Conditions B and C. Existing Condition D is deleted and Condition F is revised as the default for Conditions B, C, D or E. Table TR 3.3.16-1 Note (b) was revised to clarify that number of required channels is only applicable to the recombiner aligned to the waste gas flowpath.
Condition G is deleted to eliminate the submittal of a Special Report. The minimum set of conditions required by law to be reported to the NRC are contained in the Code Of Federal Regulations (10 CFR 50.73, 10 CFR 50.72, 10 CFR 73, etc.). This TRM special report is not required by the CFRs, and there is no regulatory basis for this special report.
There are no Technical Specification actions, regulation, license condition, order, or commitment that requires this TRM special report. NRC Office Letter 807, "Contror of Licensing Basis for Operating Reactors," notes in its description of the TRM that "some relocated TS provisions included special reporting requirements and the determination that the special reports were not required was inherent in the staffs findings that the provisions could be relocated." This clearly indicates the regulatory acceptability of the elimination of this special report from the TRM. Based on the above, this TRM special report is only an administrative requirement and therefore it is deleted.
CR 93034 questioned the need for a separate Condition for restoring a nonfunctional channel to FUNCTIONAL status. Revision 3 to the TRM occurred in conjunction with the conversion to ITS. The TRM and associated Bases were reformatted to be consistent with the ITS. A review of the TRM prior to being reformatted was conducted to determine if the reformatting encompassed the original requirements. The changes were made consistent with the requirements that existed prior to Revision 3 of the TRM.
8. TR Bases page B 3. 7.13-1 was revised to reflect that a loss of offsite power does not have to be assumed coincident with a single failure when the unit is shutdown (i.e.,
MODES 5 and 6 and during movement of irradiated fuel assemblies). This is consistent with the license amendment request submitted by letter WO 11-0008 and Amendment No.
200 and USAR Section 3.1.2.
Attachment Ill to WM 16-0005 Page 5 of 5
9. TR 3.6.1 Bases, Required Actions A.1 and A.2 and B.1 and B.2 were revised to refer to the Containment lnservice Inspection Program Plan (WCRE-22) for guidance on use of ASME Form OAR-1 for reporting containment vessel abnormal degradation instead of referring to Code Case N-532. When a licensee uses a Code Case initially in the Interval, 10 CFR 50.55a requires that the most recent version of the Code Case approved by reference be implemented. Code Case N-532 is utilized for the Summary Report required by IWA-6000. Code Case N-532-5 is the most recent version approved in Regulatory Guide 1.147 and is utilized in conjunction with the ISi and Repair and Replacement Programs. In lieu of referencing the specific revision of the Code Case in TR 3.6.1 Bases, the Containment lnservice Inspection Program Plan (WCRE-22) is being referenced as Section 3.1.1 specifies Code Cases being utilized and lists Code Case N-532-5.
10. TRM page B 3.4.17-8 was revised to change the reference from 10 CFR 50.55a(a)(3) to 10 CFR 50.55a(z). On November 5, 2014, the NRC published in Federal Register Vol.
79, No. 214, pages 65776 through 65814, a revision to 10 CFR 50.55a. This revision resulted in the relocation of alternative provisions from 10 CFR 50.55a(a)(3) to 10 CFR 50.55a(z). *
11. TR Bases page B 3.4.17-1 is revised to refer to NRC Inspection Manual Chapter 0326 instead of RIS 2005-20. Revision 59 revised pages in TR B 3.4.17 to refer to NRC Inspection Manual Chapter 0326 instead of RIS 2005-20. The change to page B 3.4.17-1 was overlooked.
12. TRM Section TR 3.7.20, "Snubbers", and associated Bases were revised to address changes required due to the Snubber Program implementing the ASME OM Code, Subsection ISTA and ISTD, for snubber visual examinations and functional testing during the 4th 10-Year lnservice Testing Interval. Previously, the Snubber Program utilized a Relief Request to use the TRM alone to control the Snubber Program. The changes that were made to the TRM are to make the TRM consistent with the requirements of the ASME OM Code. Additional detail is also located in WCOP-02, "Snubber Examination, Testing, and Service Life Monitoring Program Plan - Fourth 10-Year lnservice Testing Interval," and Procedure AP 29A-006, "Snubber Program". Also, TR 3.7.20 Conditions B and C and Table TR 3.7.20-5 were revised to address Condition Report 95302 concerning the use of "No Mode" for the Applicable Modes for LCO 3.0.8 Applicability for certain Snubber locations. This revision replaced "No Mode" with "Non TS" since the affected snubber locations are attached to piping that is not associated with a Technical Specification.
Enclosure I to WM 16-0005 Page 1 of 2 Enclosure I to WM 16-0005 CD-ROM containing Updated Safety Analysis Report, Revision 29
Enclosure I to WM 16-0005 Page 2 of 2 Subject Enclosed is the CD-ROM submittal of the Wolf Creek Generating Station Updated Safety Analysis Report (WCGS USAR), Revision 29. In accordance with 10 CFR 2.390, WCGS USAR Chapters 2, 3, 8, 9, and 12 contain sensitive unclassified information and therefore warrant withholding.
Contact Name Lucille Stone Mailing Address Wolf Creek Nuclear Operating Corporation P.O. Box 411 Burlington, KS 66839 E-Mail Address lurocke@wcnoc.com Phone Number 620-364-8831 ext. 4898 Document Components:
The CD-ROM labeled "Wolf Creek Generating Station Updated Safety Analysis Report, Rev.29" contains the following files:
001_USAR.pdf 268 KB, sensitive unclassified information 002_USARC01.pdf 889 KB, publicly available 003_USARC02.0.pdf 34. 7 MB, sensitive unclassified information 004_USARC02 Figures.pdf 36.0 MB, sensitive unclassified information 005_USARC03.pdf 16.6 MB, sensitive unclassified information 006_USARC04.pdf 2.34 MB, publicly available 007_USARC05.pdf 2.40 MB, publicly available 008_USARC06.pdf 11.5 MB, publicly available 009_USARC07.pdf 1.85 MB, publicly available 01 O_USARC08.pdf 1.87 MB, sensitive unclassified information 011_USARC09.pdf 4.53 MB, sensitive unclassified information 012_USARC10.pdf 1.43 MB, publicly available 013_USARC11.pdf 1.01 MB, publicly available 014_USARC12.pdf 814 KB, sensitive unclassified information 015_USARC13.pdf 951 KB, publicly available 016_USARC14.pdf 376 KB, publicly available 017_USARC15.pdf 6.28 MB, publicly available 018_USARC16.pdf 56 KB, publicly available 019_USARC17.pdf 64 KB, publicly available 020_USARC18.pdf 1.15 MB, publicly available 021_USARNRCQ.pdf 348 KB, publicly available 022_USAR Rev. 29-loep.pdf 401 KB, publicly available 1 to WM 16-0005 Page 1 of 2 Enclosure II to WM 16-0005 CD-ROM containing Updated Safety Analysis Report Controlled Figure Drawings
Enclosure II to WM 16-0005 Page 2 of 2 Subject Enclosed is the CD-ROM submittal of the Wolf Creek Generating Station Updated Safety Analysis Report (WCGS USAR) controlled figure drawings that are considered incorporated by reference into the WCGS USAR. In accordance with 10 CFR 2.390, this enclosure is considered sensitive unclassified information and therefore warrants withholding.
Contact Name Lucille Stone Mailing Address Wolf Creek Nuclear Operating Corporation P.O. Box 411 Burlington, KS 66839 E-Mail Address lurocke@wcnoc.com Phone Number 620-364-8831 ext. 4898 Document Components:
The CD-ROM labeled "WCGS Updated Safety Analysis Report, Rev.29 Controlled Figure Drawings Only" contains the following files:
001_Chapter 1.pdf 15.4 MB, sensitive unclassified information 002_Chapter 2.pdf 4.87 MB, sensitive unclassified information 003_Chapter 5.pdf 1.56 MB, sensitive unclassified information 004_Chapter 6.pdf 3.56 MB, sensitive unclassified information 005_Chapter 7.pdf 1.21 MB; sensitive unclassified information 006_Chapter 8.pdf 2.48 MB, sensitive unclassified information 007_Chapter 9.pdf 25.6 MB, sensitive unclassified information 008_Chapter 10.pdf 9.40 MB, sensitive unclassified information 009_Chapter 11.pdf 4.11 MB, sensitive unclassified information 010_Chapter 12.pdf 1.16 MB, sensitive unclassified information 011_Chapter 18.pdf 178 KB, sensitive unclassified information 11 to WM 16-0005 Page 1 of 2 Enclosure 111 to WM 16-0005 CD-ROM containing Updated Safety Analysis Report Fire Hazards Analysis and Quality Program Manual 11 to WM 16-0005 Page 2 of 2 Subject Enclosed is the CD-ROM submittal of the Wolf Creek Generating Station Updated Safety Analysis Report Fire Hazards Analysis and Wolf Creek Quality Program Manual (WCQPM),
both of which are considered incorporated by reference into the WCGS USAR. In accordance with 10 CFR 2.390, the WCGS USAR Fire Hazards Analysis is considered sensitive unclassified information and therefore warrants withholding.
Contact Name Lucille Stone Mailing Address Wolf Creek Nuclear Operating Corporation P.O. Box 411 Burlington, KS 66839 E-Mail Address lurocke@wcnoc.com Phone Number 620-364-8831 ext. 4898 Document Components:
The CD-ROM labeled "WCGS USAR Fire Hazards Analysis & Quality Program Manual" contains the following files:
001_WCQPM Rev 10A.pdf 276 KB, publicly available 002_E-1 F9900 Rev 9.pdf 3.03 MB, sensitive unclassified information 003_E-1 F9905 Rev 6.pdf 1.42 MB, sensitive unclassified information 004_E-1 F9910 Rev 14.pdf 20.8 MB, sensitive unclassified information 005_E-1 F9915 Rev 8.pdf 1.43 MB, sensitive unclassified information 006_XX-E-013 Rev 4.pdf 3.72 MB, sensitive unclassified information 007_XX-E-013 Rev 4_CN001.pdf 595 KB, sensitive unclassified information 008_XX-E-013 Rev 4_CN 002.pdf 440 KB, sensitive unclassified information 009_XX-E-013 Rev 4_CN 003.pdf 541 KB, sensitive unclassified information 010_M-663-00017A W05 1 to B1-98.pd 23.7 MB, sensitive unclassified information 011_M-663-00017A W05 B1-99 to B2-40.pdf 31.7 MB, sensitive unclassified information 012_M-663-00017A W05 B2-41 to B6-2.pdf 49.5 MB, sensitive unclassified information 013_M-663-00017A W05 B6-3 to B7-79.pdf 28.3 MB, sensitive unclassified information 014_M-663-00017A W05 B7-80 to B8-147.pdf 45.3 MB, sensitive unclassified information 015_M-663-00017A W05 B8-148 to B13-25.pdf 33.9 MB, sensitive unclassified information 016_M-663-00017A W05 B13-26 to G1A-63.pdf 42.7 MB, sensitive unclassified information 017_M-663-00017A W05 G1A-64 to G1A-123.pdf 17.0 MB, sensitive unclassified information 018_M-663-00017A W05 G1A-124 to G2A-3.pdf 15.7 MB, sensitive unclassified information 019_M-663-00017A W05 G2B-1 to G2B79.pdf 18.8 MB, sensitive unclassified information 020_M-663-00017A W05 Att G3 to G3D-26.pdf 22.0 MB, sensitive unclassified information 021_M-663-00017A W05 G3D-27 to G4D-19.pdf 20.6 MB, sensitive unclassified information 022_M-663-00017A W05 Att G5 to Att H.pdf 20.0 MB, sensitive unclassified information
Enclosure IV to WM 16-0005 Page 1 of 2 Enclosure IV to WM 16-0005 CD-ROM Containing Updated Safety Analysis Report EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II
Enclosure IV to WM 16-0005 Page 2 of 2 Subject Enclosed is the CD-ROM submittal of the Wolf Creek Generating Station Updated Safety Analysis Report EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II, both of which are considered incorporated by reference into the WCGS USAR. In accordance with 10 CFR 2.390, the WCGS EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II, is considered sensitive unclassified information and therefore warrants withholding.
Contact Name Lucille Stone Mailing Address Wolf Creek Nuclear Operating Corporation P.O. Box 411 Burlington, KS 66839 E-Mail Address lurocke@wcnoc.com Phone Number 620-364-8831 ext. 4898 Document Components:
The CD-ROM labeled "EQSD-1, EQ Summary Document Section I Program Description, and EQSD-11, EQ Master List Section II" contains the following files:
001_EQSD-I Rev 9.pdf 13.5 MB, sensitive unclassified information 002_EQSD-ll Rev 27.pdf 1.30 KB, sensitive unclassified information
Enclosure V to WM 16-0005 Page 1 of 1 Enclosure V to WM 16-0005 Technical Requirements Manual Replacement Pages and List of Effective Pages (49 Pages)
TECH REQUIREMENTS MANUAL REVISION: 62 TECHNICAL REQUIREMENTS MANUAL Wolf Creek Generating Station, Unit 1 Summary of _Revision 62: Released: DC12 10/26/2015
1. TR B 3.6.1 Required Actions A.1 and A.2 and B.1 and B.2 are being revised to refer to the Containment lnservice Inspection Program Plan (WCRE-22) for guidance on use of ASME Form OAR-1 for reporting containment vessel abnormal degradation instead of referring to Code Case N-532. In lieu of referencing the specific revision of the Code Case in TR B 3.6.1, the Containment lnservice Inspection Program Plan (WCRE-22) is being referenced*as Section 3.1.1 specifies Code Cases being utilized and lists Code Case N-532-5.
2. TRM page B 3.4.17-8 is revises the reference to 10 CFR 50.55a(a)(3) to 10 CFR 50.55a(z). On November 5, 2014, the NRC published in Federal Register Vol. 79, No. 214, pages 65776 through 65814, a revision to 10 CFR 50.55a. This revision resulted in the relocation of alternative provisions from 10 CPR 50.55a(a)(3) to 10 CFR 50.55a(z).
3. TR Bases page B 3.4.17-1 is revised to refer to NRC Inspection Manual Chapter 0326 instead of RIS 2005-20.
4. TRM Section TR 3.7.20, "Snubbers", and associated Bases are being revised to address changes required due to the Snubber Program implementing the ASME OM Code, Subsection ISTA and ISTD, for snubber visual examinations and functional testing during the 4th 10-Year lnservice Testing Interval.
Previously, the Snubber Program utilized a Relief Request to use the TRM alone to control the Snubber Program. The changes that are being made to the TRM are to make the TRM consistent with the requirements of the ASME OM Code. Additional detail will also be located in WCOP-02, "Snubber Examination, Testing, and Service Life Monitoring Program Plan - Fourth 10-Year lnservice Testing Interval," and Procedure AP 29A-006, "Snubber Program." Also, TR 3.7.20 Conditions Band C and Table TR 3:7.20-5 is being revised to address Condition Report 95302 concerning the use of "No Mode" for the Applicable Modes for LCO 3.0.8 Applicability for certain Snubber locations. This revision has replaced "No Mode" with "Non TS" since the affected snubber locations are attached to piping that is not associated with a Technical Specification.
TABLE OF CONTENTS TR3.7 PLANT SYSTEMS (continued) ............................................................ .
TR 3.7.21 Sealed Source Contamination .......................................................3.7-29 TR 3.7.22 Area Temperature Monitoring ........................................................3.7-32 TR 3.7.23 Intentionally Blank ..........................................................................
TR 3.7.24 Electrical Penetration Room Coolers ............................................. 3.7-35 TR3.8 ELECTRICAL POWER SYSTEMS ....................................................... .
TR 3.8.1 Offsite Power System-Transmission Network ............................3.8-1 TR 3.8.2 Intentionally Blank ................................................................... .
TR 3.8.3 Intentionally Blank ................................................................... .
TR 3.8.4 Intentionally Blank ....................................................................
TR 3.8.5 Intentionally Blank ....................................................................
TR 3.8.6 Intentionally Blank ....................................................................
TR 3.8.7 Intentionally Blank ................................................................... .
TR 3.8.8 Intentionally Blank ................................................................... .
TR 3.8.9 Intentionally Blank ................................................................... .
TR 3.8.10 Intentionally Blank ................................................................... .
TR 3.8.11 Containment Penetration Conductor Overcurrent Protective Devices ...................................................................3.8-2 TR3.9 REFUELING OPERATIONS ................................................................. .
TR 3.9.1 Intentionally Blank ....................................................................
TR 3.9.2 Intentionally Blank .......................*...........................*................
TR_3.9.3 Intentionally Blank ...............................................................*....
TR 3.9.4 Intentionally Blank ................................................................... .
TR 3.9.5 Intentionally Blank ................................................................... .
TR 3.9.6 Intentionally Blank ................................................................... .
TR 3.9.7 Refueling Pool Water Level ...........................................................3.9-1 TR 3.9.8 Intentionally Blank ................................................................... .
TR 3.9.9 Refueling Machine ***************************************************~*********************3.9-2 TR 3.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING TR 3.10.1 Liquid Holdup Tanks ......................................................................3.10-1 TR 3.10.2 Waste Gas Holdup System - Explosive Gas Mixture .................... 3.10-3 TR 3.10.3 Gas Storage Tanks ........................................................................3.10-5 TR 3.11 NOT USED TR4.0 NOT USED TR5.0 ADMINISTRATIVE TR5.1 Intentionally Blank ................................................................... .
TR5.2 Organization ...................................................................................5.0-1 TR5.3 Intentionally Blank ................................................................... .
TR 5.4 Intentionally Blank ................................................................... .
TR5.5 Programs ......................................................*.................................5.0-3 TR5.6 Reporting Requirements ................................................................5.0-6 TR5.7 Intentionally Blank ....................................................................
TR5.8 Training ..........................................................................................5.0-7 Wolf Creek - Unit 1 iii Revision 62
Source Range Neutron Flux TR 3.3.15 TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.15.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months TSR 3.3.15.2 Not Used.
TSR 3.3.15.3 ---------NOTE--------------
Neutron detectors may be excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION. 18 months Wolf Creek - Unit 1 - TRM 3.3-23 Revision 60
Explosive Gas Monitoring Instrumentation TR 3.3.16 3.3 INSTRUMENTATION 3.3.16 Explosive Gas Monitoring Instrumentation TR 3.3.16 The Waste Gas Holdup System explosive gas monitoring instrumentation channels in Table TR 3.3.16-1 shall be FUNCTIONAL with Alarm/Trip setpoints set to ensure the limits of TR 3.10.2 are not exceeded.
APPLICABILITY: During Waste Gas Holdup System operation.
ACTIONS

NOTE------------------------------------------

Separate Condition entry is allowed for each channel.
CONDITION REQUIRED ACTION COMPLETION TIME A One or more explosive A.1 Declare affected Immediately monitoring instrumentation channel(s) nonfunctional.
channels with Alarm/Trip setpoint less conservative than required.
B. Any required channel B.1 Restore required channel 30 days nonfunctional. to FUNCTIONAL status.
c. Required Hydrogen C.1 Suspend oxygen supply to Immediately Monitor channel the recombiner.
nonfunctional.
D. Required Outlet Oxygen D.1 Analyze grab samples Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Monitor channel during addition of waste nonfunctional. gas.
(continued)
Wolf Creek - Unit 1 - TRM 3.3-24 Revision 61
Explosive Gas Monitoring Instrumentation TR 3.3.16 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E. Both required Oxygen E.1 Suspend oxygen supply to Immediately Monitor channels the recombiner.
nonfunctional.
AND OR E.2 Analyze grab sample Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Required Inlet Oxygen during additions of waste during degassing Monitor channel and Inlet gas. operations Hydrogen Monitor channel nonfunctional. OR Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months during other operations F. Required Action and F.1 Suspend operation of Immediately associated Completion Waste Gas Holdup Time of Condition 8, C, D, System.
or E not met.
TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.16.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months TSR 3.3."16.2 Perform COT. 31 days (continued)
Wolf Creek - Unit 1 - TRM 3.3-25 Revision 61
Explosive Gas Monitoring Instrumentation TR 3.3.16 TECHNICAL SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY TSR 3.3.16.3 Perform CHANNEL CALIBRATION. 92 days Wolf Creek- Unit 1 - TRM 3.3-26 Revision 51 I
Explosive Gas Monitoring Instrumentation TR 3.3.16 Table TR 3.3.16-1 Explosive Gas Monitoring Instrumentation TECHNICAL REQUIRED SURVEILLANCE INSTRUMENT CHANNELS (bl REQUIREMENTS
1. Hydrogen Monitor <al 1 TSR 3.3.16.1 TSR 3.3.16.2 TSR 3.3.16.3
2. Inlet Oxygen Monitor 1 TSR 3.3.16.1 TSR 3.3.16.2 TSR 3.3.16.3
3. Outlet Oxygen Monitor 1 TSR 3.3.16.1 TSR 3.3.16.2 TSR 3.3.16.3 (a) Either the Inlet Hydrogen Monitor or the Outlet Hydrogen Monitor.
(b) The number of required channels is only applicable to the recombiner aligned to the waste gas flowpath.
Wolf Creek - Unit 1 - TRM 3.3-27 Revision 61
Reactivity Control and Power Distribution Alarms TR 3.3.17 3.3 INSTRUMENTATION 3.3.17 Reactivity Control and Power Distribution Alarms
TR 3.3.17 The following annunciator alarms shall be FUNCTIONAL:
a. AXIAL FLUX DIFFERENCE (AFD);
b. Rod Insertion Limit;
c. Rod Position Deviation; and
d. QUADRANT POWER TILT RATIO (QPTR).
APPLICABILITY: According to Table TR 3.3.17-1.
ACTION$.

=.-----NOTE-------------------------------------------

Separate Condition entry is allowed for each alarm.
CONDITION REQUIRED ACTION COMPLETION TIME A. AFD Alarm is A.1 Perform Technical . Once per hour nonfunctional. Specification Surveillance Requirement (SR) 3.2.3.1.
8. Rod Insertion Limit Alarm 8.1 Perform Technical Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months nonfunctional. Specification SR 3.1.6.2.
C. Rod Position Deviation C.1 Perform Technical Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Alarm nonfunctional. Specification SR 3.1.4.1.
(continued)
Wolf Creek - Unit 1 TRM 3.3-28 Revision 55
Snubbers TR 3.7.20
3. 7 PLANT SYSTEMS 3.7.20 Snubbers TR 3.7.20 Snubbers listed in Table TR 3.7.20-5 shall be FUNCTIONAL.
APPLICABILITY: According to Table TR 3.7.20-5.
ACTIONS

NOTE------------------------------------------------

Separate Condition entry is allowed for each affected snubber.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more non-LCO A.1 Declare the TS supported Immediately 3.0.8 applicable snubber(s) system inoperable and nonfunctional. declare the affected LCO(s) not met.
(continued)
WoWCraek-Unlt1-TRM 3.7-9 Revision 50
Snubbers TR 3.7.20 ACTION (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. One or more LCO 3.0.8 8.1 Restore the snubber(s) to Consistent with TS applicable snubber(s) FUNCTIONAL status. LCO 3.0.8 nonfunctional.
OR B.2 Declare the TS supported Prior to expiration system inoperable and of TS LCO 3.0.8 declare the affected Completion Time LCO(s) not met.
C. One or more non-TS C.1 Restore the snubber to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months snubber nonfunctional. FUNCTIONAL status.
TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.20.1 Perform visual inspections of each required snubber In accordance with in accordance with Table TR 3.7.20-2. Table TR 3.7.20-3 (continued)
Wolf Creek - Unit 1 - TRM 3.7-10 Revision 62
Snubbers TR 3.7.20 TECHNICAL SURVEILLANC.E REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY TSR 3.7.20.2 --------~------------------NOTE------------------------------
This surveillance shall begin no earlier than 60 days before a scheduled refueling outage.
Perform a functional test on a represent~tive sample Once each of each type of snubber in accordance with Table TR refueling 3.7.20-4.
TSR 3.7.20.3 Verify that the service life of mechanical snubbers is In accordance with not exceeded in accordance with Snubber Service Snubber Service Life Program. Life Program TSR 3.7.20.4 Perform an inspection of all required snubbers Within 6 months attached to sections of systems that have following the event experienced an unexpected potentially damaging transient in accordance with Table TR 3.7.20-1.
Wolf Creek - Unit 1 - TRM 3.7-11 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-1 Transient Event Inspection
1. An inspection shall be performed of all snubbers attached to sections of systems that have experienced unexpected, potentially damaging transients as determined from a review of operational data and a visual inspection of the systems within 6 months following such an event.
2. In addition to satisfying the visual inspection acceptance criteria, freedom-of-motion of mechanical snubbers shall be verified using at least one of the following:
a) Manually induced snubber movement; or b) Evaluation of in-place snubber piston setting; or c) Stroking the mechanical snubber through its full range of travel.
Wolf Creek- Unit 1 - TRM 3.7-12 Revision 50 I
Snubbers TR3.7.20 Table TR 3.7.20-2 Visual Inspections
1. Schedule
a. Snubbers are categorized as inaccessible or accessible during reactor operation.
Each of these categories (inaccessible and accessible) may be inspected independently according to the schedule determined by Table TR 3.7.20-3.
b. The visual inspection interval for each type of snubber shall be determined based upon the criteria provided in Table TR 3.7.20-3.
2. Acceptance Criteria
a. Visual inspections shall verify that:
1) There are no visible indications of damage or impaired FUNCTIONALITY,
2) Attachments tO the foundation or.supporting structure are functionaCand *.
3) Fasteners for attachment of the snubber to the component and to the snubber anchorage are functional.
b. Snubbers which appear inoperable as a result of visual inspections shall be classified as unacceptable and may be reclassified acceptable for the purpose of establishing the next visual inspection interval, provided that:
1) The cause of the rejection is clearly established and remedied for that particular snubber and for other snubbers, irrespective of type, that may be generically susceptible; and
2) The affected snubber is functionally tested in the as-found condition and determined FUNCTIONAL per Table TR 3.7.20-4, section 4.
3) A review and evaluation shall be performed and documented to determine system OPERABILITY/FUNCTIONALITY with an unacceptable snubber. If OPERABILITY/FUNCTIONALITY can not be justified, the system shall be declared inoperable and the applicable Technical Specification LCO or Technical Requirements Manual TR shall be considered not met.
Wolf Creek - Unit 1 - TRM 3.7-13 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-3 (Page 1 of 2)
Snubber Visual Inspection Interval NUMBER OF UNACCEPTABLE SNUBBERS POPULATION COLUMN A COLUMN 8 COLUMN C OR CATEGORY<a> EXTEND INTERVAL(b(cH9> REPEAT REDUCE TO 2/3 INTERVAL(b)(d)(e) INTERVAL(b)(e)(f) 1 0 0 1 80 0 0 2 100 0 1 4 150 0 3 8 200 2 5 13 300 5 12 25 400 8 18 36 500 12 24 48 750 20 40 78
~ 1000 29 56 109 (a) Interpolation between population or category sizes and the number of unacceptable snubbers is permissible.
The next lower integer shall be used when interpolation results in a fraction.
(b)* The basic interval shall be the normal fuel cycle up to 24 months. The examination interval may be as great as twice, the same, or as small as fractions of the previous interval as required by the following Notes. The examination interval may vary
+/-25% of the current interval.
(c) If the number of unacceptable snubbers is equal to or less than the number in Column A, then the next examination interval may be increased to twice the previous examination interval, not to exceed 48 months. In that case, the next examination according to the previous interval may be skipped.
(d) If the number of unacceptable snubbers exceeds the number in Column A, but is equal to or less than the number in Column B, then the next visual examination shall be conducted at the same interval a.$ the previous interval.
Wolf Creek - Unit 1 - TRM 3.7-14 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-3 (Page 2 of 2)
Snubber Visual Inspection Interval (e) If the number of unacceptable snubbers exceeds the number in Column B, but is equal to or less than the number in Column C, then the next examination interval shall be decreased to two-thirds of the previous examination interval or, in accordance with the interpolation between Columns B and C, in proportion to the exact number of unacceptable snubbers.
(f) If the number *of unacceptable snubbers exceeds the number in Column C, then the next examination interval shall be decreased to two-thirds of the previous interval.
(g) The visual inspection interval may be extended in accordance with Code Case OMN-13.
Wolf Creek- Unit 1 -TRM 3.7-15 Revision 62
snubbers TR 3.7.20 Table TR 3.7.20-4 (Page 1 of 2)
Functional Tests
1. A representative sample of snubbers of each type shall be tested using the following sample plan.
a. At least 10% of the total. of each type of snubber shall be functionally tested either in-place or .in a bench test. For each snubber of a type that does not meet the functional test acceptance criteria of section 4 of this Table, an additional 5%
of that type of snubber shall be functionally tested from the Defined Test Plan Groups (DTPG) or Failure Mode Group (FMG) until ho more failures are found or until all snubbers of that type have been functionally tested.
2. If during the functional testing, additional testing is required due to failure of snubbers, the unacceptable snubbers may be categorized into failure mode group(s). A failure mode group shall include all unacceptable snubbers that have a given failure mode and all other snubbers subject to that same failure mode. Once a failure mode group has been established, it can be separated for continued testing apart from the general population of snubbers. Testing in the failure mode group shall be based on the number of unacceptable snubbers and shall continue in accordance with the sample plan selected for the type or until all snubbers in the failure mode group have been tested.
Any additional unacceptable snubbers found in the failure mode group shall be counted for continued testing only for that test failure mode group. In the event that a snubber(s) becomes included in more than one test failure mode group, it shall be counted in each failure mode group and shall be subject to the corrective action of each test failure mode group.
3. Testing equipment failure during functional testing may invalidate that day's. testing and allow that day's testing to resume anew at a later time provided all snubbers tested with the failed equipment during the day of equipment failure are re-tested. The representative sample selected for the functional test sample plans shall be representative of each type and reviewed before beginning the testing. The review shall ensure, as far as practicable, that they are representative of the various configurations, operating environments, range of size, and capacity of snubbers of each type. Snubbers placed iq the same _location as snubbers which failed the previous functional test shall be re-tested at the time of the next functional test but shall not be included in the sample plan.
4. Functional Test Acceptance Criteria The snubber functional test shall verify that:
a. Activation (restraining action) is achieved within the specified range in both tension and compression; (continued)
Wolf Creek - Unit 1 - TRM 3.7-16 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-4 (Page 2 of2)
Functional Tests
b. For mechanical snubbers, the force required to initiate or maintain motion of the snubber is within the specified range in both directions of travel.
Testing methods may be used to measure parameters indirectly or parameters other than those specified if those results can be correlated to the specified parameters through established methods.
5. Functional Test Failure Analysis
a. An engineering evaluation shall be made on each required snubber which fails to meet the functional test acceptance criteria to determine the cause of the failure.
The results of this evaluation shall be used, if applicable, in selecting snubbers to be tested in an effort to determine the FUNCTIONALITY of other snubbers irrespective of type which may be subject to the same failure mode.
b. When a required snubber is found nonfunctional, an engineering evaluation shall be performed on the component(s) to which the inoperable snubber is attached.
The purpose of this engineering evaluation shall be to determine if the component(s) to which the nonfunctional snubber is attached is adversely affected by the nonfunctionality of the snubber (i.e. whether the component remains capable of performing its required function).
c. When a required snubber being functionally tested either fails to lock up or fails to move, i.e., frozen-in-place, the cause of this failure will be evaluated. If this failure is determined to be caused by manufacturer or a design deficiency, all snubbers of the same type subject to the same defect shall be functionally, tested. These additional snubbers shall be tested independent of those initially chosen to be inspected during the present interval.
6. Functional Testing of Repaired and Replaced Snubbers Snubbers which have failed to meet either the visual inspection or the functional test acceptance criteria shall be repaired or replaced. Replacement snubbers and snubbers which have repairs which might affect the functional test results shall be tested to meet the functional test criteria before installation in the unit. Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service, and the freedom-of-motion test must have been performed within 12 months prior to being installed in the plant.
Wolf Creek - Unit 1 - TRM 3.7-17 Revision 62 I
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 1 of 11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABIUTY<a>
AB01 R001251 1,2,3,4,5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AB01 R003252 1,2,3,4,5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AB01 R014145 1, 2, 3, 4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AB01 R036145<bl 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AB01R504145 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB01 R508145 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB01R512145 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB01R516145 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08C510145 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08C524145 1,2,3,4, 5 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s*-
AB08C532145 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08C534145 1,2,3,4,5 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s*
AB08R510145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R512145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R514145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R515145 1,2, 3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R516145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R517145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R518145 1, 2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R520145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R522145 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R523145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R524145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R525145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R526145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R527145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R528145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-18 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20..:5 (Page 2of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY<al AB08R529145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R530145 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R531145 . 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R532145(bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AB08R533145(bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AE04R014252(bl 1,2, 3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R017242 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R018242 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R019251 (bl 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R021241 1,2,3,4, 5 N/A for Modes: 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R022241 1,2,3,4,5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE04R501145(bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AE04R502145(bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AE05R017242(bl 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE05R028241 (bl 1,2,3,4, 5 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 AE05R501145<bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AE05R502145(bl 1,2,3,4, 5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AL02R009135 1, 2, 3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AL02R010135 1, 2, 3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AL03R005135 1,2,3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AL03R011135 1, 2, 3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 8801 R004231 1, 2, 3 N/A 8802R002261 1, 2, 3 N/A 8802R005261 1, 2, 3 NIA (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek- Unit 1 - TRM 3.7-19 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20_.5 (Page 3of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY(al BB02R008261 1, 2, 3 NIA BB02R010251 1,2,3 NIA BB02R012261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB02R014261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB02R015261 (bl 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB02R016261 (bl 1,2,3 NIA BB02R021261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB02R025261 (bl 1,2,3 NIA BB02R027261 1, 2, 3 NIA BB02R034261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB03C017231-* 1,2,3,4,5,6 NIA for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6
~ BB03R005242 Non TS NIA BB03R008231 1,2,3,4,5,6 NIA for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 BB03R016251 (bl 1,2,3 NIA BB03R024231(bl 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB03R025231 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB03R030231 (bl 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6
BB04R001232 1, 2, 3 NIA BB04R00.5241 1, 2, 3 NIA BB04R017261 1, 2, 3 NIA BB04R026261 1, 2, 3 NIA (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC- TS LCO 3.0.8.b is applicable
- NIA - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not rnet as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-20 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 4of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY(a>
BB04R044232 1, 2, 3 N/A BB09R509231 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BB12R508232 Non TS N/A BB13R520241 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BB13R521241 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB 13R522241 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R523261 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R524261 (bl 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R525261 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R526261(bl 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R527261 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R528261 (b) 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB13R531261 1, 2, 3, 4, 5,_6 N/A for Modes 1-4 * .. .- ...-.::
~ *l 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BB 13R544241 1, 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BB16R001232 Non TS N/A BG01 R006124(b) 1,2,3,4, 5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG01R014132 Non TS NIA I BG01R018134 1,2,3,4,5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG02R015111 1,2,3,4,5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG02R016111(bl 1,2,3,4, 5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG02R017121 1,2, 3,4, 5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG03R018133 1, 2, 3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG05C532131 Non TS N/A BG05R014132 Non TS. N/A BG05R019132 Non TS N/A BG09R515133 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG09R519133 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG09R530133(bl 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG09R531133(bl 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG09R532133(b) 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-21 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 5of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY(a>
BG09R533133 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG15R009132 Non TS N/A BG16R005112 1,2,3,4,5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months BG16R006112 Non TS N/A BG17R510112 Non TS N/A BG17R514112 Non TS N/A BG17R517122(b) Non TS N/A BG17R518122(b) Non TS N/A BG20C51 0142(b) Non TS N/A BG21R011231 1,2,3,4, 5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BG21R013231 1,2,3,4,5,6 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BG21 R017231 1,2,3,4, 5,6 NIA for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 BG21R018231 1,2,3,4,5,6 N/A for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 BG21 R020231 1,2,3,4,5,6 NIA for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 BG21 R023242(c) 1,2,3,4, 5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG21 R024242(c) 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG22R004232(b) Non TS N/A BG22R006232 Non TS N/A BG22R025231 (cl 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG23COO 1232(b) 1, 2,3,4, 5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG23R007231 1, 2,3,4, 5,6 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BG23R011231(b) 1,2,3,4,5,6 N/A for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers (c) 3 snubbers Wolf Creek - Unit 1 - TRM 3.7-22 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 6of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY<a>
BG24R003261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BG24R005261 1,2,3,4,5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 BG24R014231 1,2,3,4,5,6 NIA for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 BG25R504231 Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BG26C511242 Non TS NIA BG26R503242 Non TS NIA BG26R505242 Non TS NIA BG26R507242 Non TS NIA BL03R002232Cb> Non TS NIA BL03R003232 Non TS NIA BM01 C015231 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM01 C020231 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM01C023231 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM02C017232 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM02C020232 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM02R003232Cb> 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM02R012232 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM02R014232 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5
BM02R016232Cb>. 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM17R509231 1, 2, 3, 4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- NIA - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-23 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 7of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY<a>
BM17R516251 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM17R519231 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BM18C504252 1,2,3,4, 5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM18C508232 1, 2, 3, 4, *5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM18R502252 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM18R506232 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM18R513232<bl 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BM19R503232<bl 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM19R514232 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BM19R515232 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months BM20R507231 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BM20R511231 1,2,3,4,5 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 BN01R010123<c> Non TS NIA BN01 R011123<c> Non TS NIA BN02C010021 (bl Non TS NIA EC04R002611 (bl Non TS NIA EC04R011611<bl Non TS NIA EC04R022611 (bl Non TS NIA EC04R023611 (bl Non TS NIA EC04R033611 (bl Non TS NIA
"(continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- NIA - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers (c) 3 snubbers Wolf Creek - Unit 1 - TRM 3.7-24 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 8of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY(al EC04R034611 Non TS N/A EC04R038611 Non TS N/A EC06R504621 (bl Non TS N/A EF03R016142 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF03R019122 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF03R022124 1, 2, 3,4 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s:
EF03R023112(b) 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF03R032144(bl 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF03R034112(bl 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF05R018111 1, 2, 3, 4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF05R028143 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF06R016114(b) 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EF14R003341
1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EG03R013141(bl 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EG03R014141 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EG04R011131<bl 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EG07R009134 1,2, 3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG07R026134 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG07R027134 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG07R02S 134 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG08R013151(bl Non TS NIA EG11 R005231 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG11R501241 Non TS N/A EG14R004232 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG15R002232(bl 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EG24R018111 (bl 1,2,3,4, 5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EJ01 R020132(b) 1,2,3,4,5,6
72hours EJ01 R022132(bl 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek- Unit 1 - TRM 3.7-25 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 9of11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY<a>
EJ02R020131 Cb) 1,2,3,4, 5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EJ02R024131 1,2,3,4,5,6 72 .hours EJ02R035123 1,2,3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ03C007111 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ03R006131Cb> 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ03R015111 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ03R511111 1, 2, 3, 4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ03R512123 Non TS N/A EJ04C018231 1,2,3,4,5,6 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 EJ04C020231 1,2,3,4, 5,6 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 EJ04C022231 1,2,3,4, 5,6 NIA for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 EJ04R002232 1,2, 3,4,5,6 N/A for Modes 1-4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Mode 5 and 6 EJ04R012231 1,2,3,4, 5,6 N/A for Modes 1-4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for Mode 5 and 6 EJ04R020232 1,2, 3,4,5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EJ07R502231 1,2,3,4, 5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EM01C013112 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM01 R011111 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM01 R017112Cb> 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM01R018112Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM01 R028112 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM01 R032111 Cb> 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM03R022231 1,2,3,4 N/A EM03R025231 1,2,3 N/A EM04C006231 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM03R024231 1, 2, 3 N/A (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- NIA - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-26 Revision 62
Snubbers TR 3.7.20 Table TR 3.7.20-5 (Page 10of11)
Snubber List SNUBBER ID .
APPLICABLE MODES LCO 3.0.8 APPLICABILITY<a>
EM04C007231 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM05R001231 1, 2, 3 N/A EM05R010231 1, 2, 3 N/A EM05R011231 1, 2, 3 N/A EM06R504133Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM08R512112Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM08R513112 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM11 R501231 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM11 R502231 1,2,3,4,5,6 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EM 11 R504231 Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM 11 R505231 Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM 11 R509231 (b) 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EM12R013232 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM12R029232Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EM12R501232Cb> 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EM12R502232 1,2,3,4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months EN01 R007112Cb> 1,2,3,4 N/A EN02R007123<d> 1,2,3,4 N/A EN05R007241 Cb> 1,2,3,4 N/A EN05R017241 Cb) 1,2, 3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EP01C005231 1,2,3,4 N/A EP01 R005231 1,2,3,4 N/A EP01 R010231 1,2,3,4 N/A EP01R013231 1,2,3,4 N/A EP01 R016231 1,2,3,4 N/A EP02R001232 1,2,3,4 N/A EP02R008232 1,2, 3,4 N/A EP02R009232 1,2,3,4 NIA EP05R502232Cb> 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)
(a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
- 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months - Snubber supports multiple trains of SSC - TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers (d) 4 snubbers Wolf Creek - Unit 1 - TRM 3.7-27 Revision 62
Snubbers TR3.7.20 Table TR 3.7.20-5 (Page 11 of 11)
Snubber List SNUBBER ID APPLICABLE MODES LCO 3.0.8 APPLICABILITY(a>
EP05R503242(bl . 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EP05R505242 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EP08R506242 Non TS N/A
EP08R508242 1,2,3,4,5 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months FC01 R024145 1, 2, 3 N/A GN01R010252 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GN01R013231
1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GN01 R014252 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GN02R007252(b) 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GS02R506133 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GS03R506232 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GS04R501134 1,2,3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months GS04R503251 1, 2, 3 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months HB24R016231 1,2,3,4 N/A HB24R017231 1,2,3,4 N/A HB30R506251
Non TS N/A HE04C532111 Non TS NIA KA43C540231 Non TS N/A' KA43C541231
Non TS N/A KJ01R001511(b) 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months KJ01 R002511(b). 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months KJ01 R003511 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months KJ01 R004511 1,2,3,4,5,6 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LF05R002231 (b) Non TS N/A
LF09R004251 Non TS N/A SJ01 R502134(b) 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months SJ03R504133 1,2,3,4 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (a) - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months - Snubber supports single train of SSC - TS LCO 3.0.8.a is applicable
-12 hours - Snubber supports multiple trains of SSC- TS LCO 3.0.8.b is applicable
- N/A - LCO 3.0.8 is not applicable for the snubber, declare the supported SSC TS LCO not met as applicable (b) 2 snubbers Wolf Creek - Unit 1 - TRM 3.7-28 Revision -62
Sealed Source Contamination TR 3.7.21 3.7 PLANT SYSTEMS 3.7.21 Sealed Source Contamination TR 3.7.21 Removable contamination shall be < 0.005 µCi for each sealed source containing radioactive material:
a. > 100 µCi of beta and/or gamma emitting material; or
b. > 5 µCi of alpha emitting material.
APPLICABILITY: At all times.
ACTIONS

NOTE--------------------------------------_.:.__ _

Separate Condition entry is allowed for each sealed source. . .
CONDITION REQUIRED ACTION COMPLETION TIME A. ------------NOTE--------------- A.1 Remove sealed source Immediately Required Action A.3 must from use.
be completed whenever this Condition is entered. AND A.2.1 Initiate action to Immediately Sealed source decontaminate and repair contamination not within the sealed source.
limits.
OR A.2.2 Initiate action to dispose Immediately of sealed source in accordance with NRC regulations.
AND (continued)
Wolf Creek - Unit 1 - TRM 3.7-29 Revision 62 I
Sealed Source Contamination TR 3.7.21 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Initiate Condition Report 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to submit an NRC Special Report within next 12 months.
TECHNICAL SURVEILLANCE REQUIREMENTS

NOTES--------------------------------------------------

1. Tests for leakage and/or contamination shall be performed by the licensee or other persons specifically authorized by the NRC or an Agreement State.
2. The test method shall have a detection sensitivity of~ 0.005 µCi per test sample.
SURVEILLANCE FREQUENCY TSR 3.7.21.1 -=-------------------------NOTE-----------------------
Startup sources and fission detectors previously subjected to core flux are excluded.
Perform leakage and/or contamination testing for 184 days each sealed source that is in use containing radioactive material with a half-life > 30 days and in any form other than gas, excluding H3 .
(continued)
Wolf Creek - Unit 1 - TRM 3.7-30 Revision 62 I
Sealed Source Contamination TR 3.7.21 TECHNICAL SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY TSR 3.7.21.2 ------------------------NOTE-----------------------
Only required if not performed within the previous 184 days.
Perform leakage and/or contamination testing for Prior to use or each sealed source and fission detector that is stored transfer to another and not in use. licensee TSR 3.7.21.3 Perform leakage and/or contamination testing for Prior to use each sealed source or fission detector transferred without a certificate indicating the last test date.
TSR 3.7.21.4 Perform leakage and/or contamination testing for Once within 31 each sealed startup source and fission detector. days prior to being subjected to core flux Once within 31 days prior to installation in the core following repair or maintenance Wolf Creek- Unit 1 - TRM 3.7-31 Revision 62 I
Area Temperature Monitoring TR 3.7.22
3. 7 PLANT SYSTEMS 3.7.22 Area Temperature Monitoring TR 3.7.22 Area temperatures specified in Table TR 3.7.22-1 shall be within allowable temperature limit.
APPLICABILITY: At all times.
ACTIONS

N 0 TE----------------------------------------------------------

Se parate Condition entry is allowed for each temperature area.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required area A.1 Initiate Condition Report. Immediately temperatures not within allowable limit. AND A.2 Restore area 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature(s) to within allowable limit.
TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.22.1 Verify the required area temperatures specified in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Table TR 3.7.22-1 are within allowable limit.
Wolf Creek - Unit 1 - TRM 3.7-32 Revision 62 I
Area Temperature Monitoring TR 3.7.22 Table TR 3.7.22-1 (page 1 of 2)
Area Temperature Monitoring ALLOWABLE AREA TEMPERATURE (OF)
1. Essential Service Water Pump Room A :;; 119
2. Essential Service Water Pump Room B :;; 119
3. Auxiliary Feedwater Pump Room A :;; 119
4. Auxiliary Feedwater Pump Room B :;; 119
5. Turbine Driven Auxiliary Feedwater Pump Room :;; 147
6. Engineered Safety Feature Switchgear Room I :;; 87
7. Engineered Safety Feature Switchgear Room II :;; 87
8. Switchgear Room. No. 1 :;; 87
9. Switchgear Room No. 3 :;; 87
10. Switchgear Room No. 2 :;; 87
11. Switchgear Room No. 4 :;; 87
12. Battery Room No. 1 :;; 87
13. Battery Room-No. 3 :;; 87
14. Battery Room No. 2 :;; 87
15. Battery Room No. 4 :;; 87
16. Residual Heat Removal Pump Room A :;; 119
17. Residual Heat Removal Pump Room B :;; 119
18. Containment Spray Pump Room A :;; 119
19. Containment Spray Pump Room B :;; 119
20. Safety Injection Pump Room A :;; 119
21. Safety Injection Pump Room B :;; 119 (continued)
Wolf Creek- Unit 1 -TRM 3.7-33 Revision 62 I
Area Temperature Monitoring TR 3.7.22 Table TR 3.7.22-1 (page 2 of 2)
Area Temperature Monitoring ALLOWABLE AREA TEMPERATURE (OF)
22. Centrifugal Charging Pump Room A :<;; 119
23. Centrifugal Charging Pump Room B :<;; 119
24. Electrical Penetration Room A :<;; 101
25. Electrical Penetration Room B :<;; 101
26. Component Cooling Water Room A :<;; 119
27. Component Cooling Water Room B :<;; 119
28. Diesel Generator Room A :<;; 119
29. Diesel Generator Room B :<;; 119
30. Control Room :<;; 84 Wolf Creek - Unit 1 - TRM 3.7-34 Revision 62 I
Electrical Penetration Room Coolers TR 3.7.24
3. 7 PLANT SYSTEMS 3.7.24 Electrical Penetration Room Coolers TR 3.7.24 One electrical penetration room cooler shall be FUNCTIONAL for each electrical penetration room.
APPLICABILITY: At all times.
ACTIONS

NOTE-------------------------------------------------------

Separate Condition entry is allowed for each electrical penetration room cooler.
CONDITION REQUIRED ACTION COMPLETION TIME A. One electrical penetration A.1 De-energize the fan motor 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months room cooler nonfunctional of the associated room and not capable of cooler.
providing cooling.
AND A.2 Perform TSR 3.7.22.1 for 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the affected electrical penetration room. AND Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when most recently obtained room temperature exceeds 90°F
8. Required Action and 8.1 Initiate Condition Report. Immediately associated Completion Time of Condition A not met.
(continued)
Wolf Creek - Unit 1 - TRM 3.7-35 Revision 62 I
Electrical Penetration Room Coolers TR 3.7.24 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. One electrical penetration C.1 Restore electrical 7 days room cooler nonfunctional penetration room cooler to in MODE 1, 2, 3, and 4. FUNCTIONAL status.
D. One electrical penetration D.1 Restore electrical 30 days room cooler nonfunctional penetration room cooler to in MODE 5, 6, and FUNCTIONAL status.
defueled.
E. Required Actions and E.1 Initiate Condition Report. Immediately associated Completion Time of Condition C or D not met.
TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Not applicable.
Wolf Creek - Unit 1 - TRM 3.7-36 Revision 62 I
Offsite Power System- Transmission Network TR 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 Offsite Power System - Transmission Network TR 3.8.1 The following 345 kV lines connecting the unit switchyard to the offsite transmission network shall be FUNCTIONAL:
a. Wolf Creek - Waverly - LaCygne 345 kV line
b. Wolf Creek - Rose Hill 345 kV line
c. Wolf Creek - Benton 345 kV line APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One 345 kV line A.1 Verify two 345 kV lines 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months nonfunctional. are FUNCTIONAL.
B. Two 345 kV lines B.1 Enter Condition A of Immediately nonfunctional. Technical Specification LCO 3.8.1 for an inoperable offsite circuit.
TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.8.1.1 Verify correct indicated breaker alignment and power 7 days availability for each 345 kV line.
Wolf Creek - Unit 1 - TRM 3.8-1 Revision 60
Containment Penetration Conductor Overcurrent Protective Devices TR 3.8.11 3.8 ELECTRICAL POWER SYSTEMS 3.8.11 Containment Penetration Conductor Overcurrent Protective Devices TR 3.8.11 All containment penetration conductor overcurrent protective devices shall be FUNCTIONAL.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS

N 0 TE---------------------------------------------------------------

S epara te Condition entry is allowed for each overcurrent protective device.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more containment A.1.1.1 Deenergize the circuit(s) 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months penetration conductor by tripping the associated overcurrent protective backup circuit breaker.
devices nonfunctional.
A.1.1.2 Verify the backup circuit Once per 7 days breaker to be tripped.
A.1.2.1 De energize the circuits(s) 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months by racking out, locking open, or removing the nonfunctional circuit breaker or protective device.
(continued)
Wolf Creek - Unit 1 - TRM 3.8-2 Revision 4 7 I
Organization TR5.2 TR 5.0 ADMINISTRATIVE CONTROLS TR 5.2 Organization 5.2.1 Unit Staff The unit staff organization shall include the following:
a. Each on duty shift shall be composed of at least the minimum shift crew composition shown in Table TR 5.2.1-1. Table TR 5.2.1-1 identifies the minimum shift crew compliment to meet Technical Specification 5.2.2 requirements as well as staffing to plant operational requirements and staffing for a radiological emergency response. The shift crew composition may be one less than the minimum requirements of Table TR 5.2.1-1 for a period of time not to exceed two hours in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements. This provision does not permit any shift crew position to be unmanned upon shift change due to an oncoming crew member being late 'or absent. ** * * * * * ,,
b. A site Fire Brigade of at least 5 members shall be maintained onsite at all times, with an allowance to accommodate an unexpected absence(s) not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , provided immediate action is taken to fill the position(s). This provision does not permit any shift crew position to be unmanned upon shift change due to an oncoming shift crew member being late or absent. The Fire Brigade shall not include the Shift Manager, and the two other members of the minimum shift crew necessary for safe shutdown of the. Unit and any personnel required for other essential function during a fire emergency.
WoWCreek-Unlt1-TRM 5.0-1 Revision 51
Organization
TR5.2 Table TR 5.2.1-1 (page 1of1)
Minimum Shift Crew Composition NUMBER OF INDIVIDUALS REQUIRED TO FILL POSITION Technical Specification Requirements Plant Operational Requirements POSITION MODE 1, 2, 3, or4 MODE 5 or6 At All Times SM 1 1(b) 1 CRS 1 None 1 RO 2 1 2 NSO 2 1 5(c)(d)
STA 1(a) None 1(e)
CHM None None 2 HP 1 1 3 ENS Communicator None None 1 Offsite Communicator None None 1
. SM Shift Manager with a Senior Operator license on Unit 1 CRS Control Room Supervisor with a Senior Operator license on Unit 1 RO Individual with an Operator license on Unit 1 NSO Nuclear Station Operator STA Shift Technical Advisor (Shift Engineer)
CHM Chemistry Personnel HP Health Physics Personnel (a) This position shall be manned in MODES 1, 2, 3, and 4 unless the Shift Manager or the individual with a Senior Operator license meets the qualifications as required by Technical Specification 5.2.2e.
(b) One individual with a Senior Operator license, either Shift Manager or Control Room Supervisor.
(c) Individual may be a RO.
(d) One individual is designated to perform OFN KC-016/0FN KC-017, Att. E.
(e) This position shall be manned in MODES 1, 2, 3, and 4. In MODES 5 and 6, this position is not required to be filled by an individual qualified as a STA.
Wolf Creek - Unit 1 - TRM 5.0-2 Revision 59
-~ -* ~ LIST OF EFFECTIVE PAGES - TECHNICAL REQUIREMENT MANUAL PAGE< 1> REVISION NO. <2> CHANGE DOCUMENT 3
<> DATE EFFECTIVE/
4 IMPLEMENTED < >
TAB - Title Page TRM Title Page TAB- Table of Contents 43 ORR 10-3738 12/28/10 ii 35 ORR 08-0727 8/28/08 iii 54 ORR 15-2006 10/26/15 TAB-1.0 USE AND APPLICATION 1.0-1 41 ORR 10-1702 10/1/10 1.0-2 41 ORR 10-1702 10/1/10 TAB-3.0 APPLICABILTY 3.0-1 41 ORR 10-1702 10/1/10 3.0-2 41 ORR 10-1702 10/1/10 3.0-3 41 ORR 10-1702 10/1/10 3.0-4 20 ORR 04-1410 10/7/04
TAB - 3.1 REACTIVITY CONTROL SYSTEMS 3.1-1 41 ORR 10-1702 101111 o*
3.1-2 3. ORR 99-1581 12/18/99~..
3.1-3 34 ORR 08-0256 3/11/08 3.1-4 34 ORR 08-256 3/11108 3.1-5 41 ORR 10-1702 10/1/10 3.1-6 37 ORR 09-0287 3/20/09 3.1-7 41 ORR 10-1702 10/1/10 3.1-8 41 ORR 10-1702 10/1/10 3.1-9 11 ORR 02-0412 4/5/02 3.1.10 48 ORR 12-0266 2/2/12 TAB - 3.3 INSTRUMENTATION 3.3-1 41 ORR 10-1702 10/1/10 3.3-2 41 ORR 10-1702 10/1/10 3.3-3 23 ORR 05-0708 4/20/05 3.3-4 41 ORR 10-1702 10/1/10 3.3-5 41 ORR 10-1702 10/1/10 3.3-6 23 ORR 05-0708 4/20/05 3.3-7 23 ORR 05-0708 4/20/05 3.3-8 43 ORR 10-3738 . 12/28/10 3.3-9 41 ORR 10-1702 10/1/10 3.3-10 41 ORR 10-1702 10/1/10 3.3-11 39 ORR 09-1775 10/28/09 3.3-12 39 ORR 09-1775 10/28/09 3.3-13 39 ORR 09-1775 10/28/09 3.3-14 49 ORR 12-0673 4/10/12 3.3-15 39 ORR 09-1775 10/28/09 3.3-16 39 ORR 09-1775 10/28/09 3.3-17 41 ORR 10-1702 10/1/10 3.3-18 39 ORR 09-1775 10/28/09 3.3-19 51 ORR 13-0371 2/26/13 3.3-20 51 ORR 13-0371 2/26/13 3.3-21 51 ORR 13-0371 2/26/13 3.3-22 51 ORR 13-0371 2/26/13 Wolf Creek - Unit 1 Revision62
LIST OF EFFECTIVE PAGES,- TECHNICAL REQUIREMENT MANUAL PAGE<1l REVISION NO. <2l CHANGE DOCUMENT <3l DATE EFFECTIVE/
IMPLEMENTED <4l TAB- 3.3 INSTRUMENTATION (continued) 3.3-23 60 DRR 15-0529 3/26/15 3.3-24 61 DRR 15-0824 4/28/15 3.3-25 61 DRR 15-0824 4/28/15 3.3-26 51 DRR 13-0371 2/26/13 3.3-27 61 DRR 15-0824 4/28/15 3.3-28 55 DRR 14-0344 2/27/14 3.3-29 51 DRR 13-0371 2/26/13 3.3-30 56 DRR 14-1570 7/1/14 3.3-31 51 DRR 13-0371 2/26/13 3.3-32 51 DRR 13-0371 2/26/13 3.3-33 51 DRR 13-0371 2/26/13 3.3-34 51 DRR 13-0371 2/26/13 3.3-35 51 DRR 13-0371 2/26/13 3.3-36 51 DRR 13-0371 2/26/13 3.3-37 51 DRR 13-0371 2/26/13 TAB - 3.4 REACTOR COOLANT SYSTEM (RCS) 3k1 ~ DRR 09-0287 3/20/09 3.4-2 3 - DRR 99-1581 12/18/99 3.4-3 41 - DRR 10-1702 10/1/10 3.4-4 41 DRR 10-1702 10/1/10 3.4-5 3 DRR 99-1581 12/18/99 3.4-6 33 DRR 07-1554 9/28/07 3.4-7 33 DRR 07-1554 9/28/07 3.4-8 41 DRR 10-1702 10/1/10 3.4-9 41 DRR 10-1702 10/1/10 3.4-10 35 DRR 08-0729 8/28/08 TAB-3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5-1 41 DRR 10-1702 10/1/10 TAB - 3.6 CONTAINMENT SYSTEMS 3.6-1 17 DRR 04-0452 5/26/04 3.6-2 37 DRR 09-0287 3/20/09 3.6-3 17 DRR 04-0452 5/26/04 TAB - 3. 7 PLANT SYSTEMS 3.7-1 57 DRR 14-1878 9/30/14 3.7-2 28 DRR 06-1349 7/24/06 3.7-3 52 DRR 13-0658 3/28/13 3.7-4 41 DRR 10-1702 10/1/10 3.7-5 41 DRR 10-1702 10/1/10 3.7-6 41 DRR 10-1702 10/1/10 3.7-7 26 DRR 06-0050 2/28/06 3.7-8 37 DRR 09-0287 3/20/09 3.7-9 50 DRR 12-1537 8/30/12 3.7-10 62 DRR 15-2006 10/26/15 3.7-11 62 DRR 15-2006 10/26/15 3.7-12 50 DRR 12-1537 8/30/12 Wolf Creek - Unit 1 ii Revision62
LIST OF EFFECTIVE PAGES -TECHNICAL REQUIREMENT MANUAL* ' *;,.;.. . -
PAGE( 1l REVISION NO. (2l CHANGE DOCUMENT (3l DATE EFFECTIVE/
IMPLEMENTED (4l TAB- 3.7 PLANT SYSTEMS (continued) 3.7-13 62 ORR 15-2006 10/26/15 3.7-14 62 ORR 15-2006 10/26/15 3.7-15 62 ORR 15-2006 10/26/15 3.7-16 62 ORR 15-2006 10/26/15 3.7-17 62 ORR 15-2006 10/26/15 3.7-18 62 ORR 15-2006 10/26/15 3.7-19 62 ORR 15-2006 10/26/15 3.7-20 62 ORR 15-2006 10/26/15 3.7-21 62 ORR 15-2006 10/26/15 3.7-22 62 ORR 15-2006 10/26/15 3.7-23 62 ORR 15-2006 10/26/15 3.7-24 62 ORR 15-2006 10/26/15 3.7-25 62 ORR 15-2006 10/26/15 3.7-26 62 ORR 15-2006 10/26/15 3.7-27 62 ORR 15-2006 10/26/15 3.7-28 62 ORR 15-2006 10/26/15 3.7-29 62 ORR 15-2006 10/26/15 3.7-30 62 ORR 15-2006 10/26/15 3.7-31 . .. . 62 . ORR 15~2006 10/26/15.
3.7-32 62 ORR 15-2006 10/26/15 3.7-33 62 ORR 15-2006 10/26/15 3.7-34 62 ORR 15-2006 10/26/15 3.7-35 62 ORR 15-2006 10/26/15 3.7-36 62 ORR 15-2006 10/26/15 TAB - 3.8 ELECTRICAL POWER SYSTEMS 3.8-1 60 ORR 15-0529 3/26/15 3.8-2 47 ORR 11-2404 11/16/11 3.8-3 47 ORR 11-2404 11/16/11 3.8-4 47 ORR 11-2404 11/16/11 3.8-5 47 ORR 11-2404 11/16/11 TAB- 3.9 REFUELING OPERATIONS 3.9-1 3 ORR 99-1581 12/18/99 3.9-2 41 ORR 10-1702 10/1/10 3.9-3 41 ORR 10-1702 10/1/10 .
TAB - 3.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING 3.10-1 3 DRR99-1581 12/18/99
3. 10-2 37 ORR 09-0287 3/20/09 3.10-3 37 ORR 09-0287 3/20/09 3.10-4 3 DRR99-1581 12/18/99 3.10-5 37 ORR 09-0287 3/20/09 3.10-6 3 DRR99-1581 12/18/99 Wolf Creek - Unit 1 iii Revision62
LIST OF EFFECTIVE PAGES - TECHNICAL REQUIREMENT MANUAL PAGE<1> REVISION NO. <2> CHANGE DOCUMENT <>
3 DATE EFFECTIVE/
IMPLEMENTED <4>
TAB - 5.0 ADMINISTRATIVE CONTROLS 5.0-1 51 ORR 13-0371 2/26/13 5.0-2 59 ORR 15-0112 2/10/15 5.0-3 24 DRR 05-1376 6/28/05 5.0-4 41 ORR 10-1702 10/1/10 5.0-5 17 ORR 04-0452 9/28/05 5.0-6 25 ORR 05-1996 2/16/05 5.0-7 16 ORR 03-1498 11/4/03 Note 1 The page number is listed on the center of the bottom of each page.
Note 2 The revision number is listed in the lower right hand corner of each page. The Revision number will be page specific.
Note 3 The change document will be the document requesting the change. Therefore, the change document should be a ORR number in accordance with AP 26A-002.
Note 4 The date effective or implemented is the date the Technical Requirement pages are to be issued by Document Control.
Wolf Creek - Unit 1 iv Revision62
. Source* Range Neutron Flux TR B 3.3.15 BASES APPLICABILITY rods not fully inserted are addressed in Technical Specification 3.3.1, * *
(continued) "RTS Instrumentation." The requirements for the NIS source range detectors in MODE 6 are addressed in Technical Specification 3.9.3, "Nuclear Instrumentation."
ACTIONS Condition A applies to one nonfunctional required source range channel in MODE 3, 4, or 5 with the Rod Control System not capable of rod withdrawal and all control rods are fully inserted. With one of the required source range channels nonfunctional, 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months is allowed to restore it to a FUNCTIONAL status. The allowance of 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months to restore the channel to FUNCTIONAL status is consistent with the Completion Times of Technical Specification 3.3.1, Condition K.
If the nonfunctional required source range channel cannot be returned to a FUNCTIONAL status, 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is allowed to suspend all operations involving positive reactivity changes. Once the ACTIONS are completed, the core is in a more stable condition.
C.1 and C.2 Condition C applies to two nonfunctional required Source Range Neutron Flux channels when in MODE 3, 4, or 5 with the Rod Control System not capable of rod withdrawal and all control rods fully inserted. With the unit in this Condition, the NIS source range only performs monitoring functions. With both required source range channels nonfunctional, operations involving positive reactivity changes is immediately suspended. The immediate Completion Time is consistent with the required times for actions to be performed without delay and in a controlled manner. Also, verification of SOM within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter is required with no core reactivity monitoring capability. One hour allows the operator adequate time to determine SDM.
WoWCreek-Unlt1-TRM B 3.3.15-3 Revision 45
Source Range Neutron Flux TR B 3.3.15 BASES TECHNICAL TSR 3.3.15.1 SURVEILLANCE REQUIREMENTS Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure, thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the unit staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.
The Frequency is based on operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the TR required channels.
TSR 3.3.15.2 Not used.
Wolf Creek - Unit 1 - TRM B 3.3.15-4 Revision 60
Explosive Gas Monitoring Instrumentation ...
TR B 3.3.16 B 3.3 INSTRUMENTATION TR B 3.3.16 Explosive Gas Monitoring Instrumentation BASES BACKGROUND The explosive gas monitoring instrumentation is designed to facilitate automatic operation and remote control of the Waste Gas Holdup System and to provide continuous indication of system parameters (Ref. 1). This TR and TR 3.10.2, 'Waste Gas Holdup System - Explosive Gas Mixture,"
is provided to ensure that the concentration of potentially explosive gas mixtures contained in the Waste Gas Holdup System is maintained below the flammability limits of hydrogen and oxygen. Automatic control features are included in the system to prevent the hydrogen and oxygen concentrations from reaching these flammability limits. These automatic control features include isolation of the source of hydrogen and/or oxygen. Maintaining the concentration of hydrogen and oxygen below their flammability limits provides assurance that the releases of radioactive materials will be controlled in conformance with the requirements of General Design Criterion 60 of Appendix A to 10 .CFR Part 50 (Ref. 2).
Technical Specification 5.5.12, "Explosive Gas and Storage Tank Radioactivity Monitoring," requires limits for concentration of hydrogen and oxygen in the Waste Gas Holdup System and a Surveillance program to ensure the limits are maintained (Ref. 4).
APPLICABLE The requirements limiting the concentration of potentially explosive gas SAFETY ANALYSES mixtures in the Waste Gas Holdup System ensures that these concentrations will be maintained below the mixture flammability limit.
This requirement is designed to preclude inadvertent radioactivity releases from the Waste Gas Holdup System due to tank failure from a waste gas explosion.
TR TR 3.3.16 is provided to ensure the FUNCTIONALITY of instrumentation for monitoring the concentration of oxygen and hydrogen in the Waste Gas Holdup System. The concentration of oxygen and hydrogen are maintained below flammability limits to guard against the rupture of the Waste Gas Holdup System and the release of radioactive material.
Wolf Creek - Unit 1 - TRM B 3.3.16-1 Revision 41
Explosive Gas Monitoring Instrumentation TR B 3.3.16 BASES APPLICABILITY The explosive gas monitoring instrumentation is required FUNCTIONAL during Waste Gas Holdup System operation. During periods when the Waste Gas Holdup System is not in operation, the concentration of oxygen and hydrogen is assumed stable such that continuous monitoring is not required.
The Waste Gas Holdup System operation is defined as the input of gas into the Waste Gas Holdup System or when a Waste Gas Recombiner is in operation. This includes "degassing operation" which is defined as the operation of switching from a H2 Blanket to a N2 Blanket (or vice versa) in the Volume Control Tank while in MODES 3, 4 and 5. If the Waste Gas Holdup System has no inputs and the recombiners are not running, then the system is not in operation. Recirculation of the waste gas within the system is not defined as operation for the purposes of this TR (Ref. 3).
ACTIONS A Note has been added to the ACTIONS to clarify the application of Completion Time rules. The Conditions of this Requirement may be entered independently for each instrument. The Completion Time(s) for the nonfunctional instrument will be tracked separately for each channel starting from the time the Condition was entered for that channel.
With one or more explosive gas monitoring instrumentation channels with
- the Alarmffrip setpoint set less conservative than required, immediately *
declare the affected channel(s) nonfunctional. The appropriate Condition shall be entered based on declaring the affected channel(s) nonfunctional. The immediate Completion Time is consistent with the required times for actions to be performed without delay and in a controlled manner.
With any required channel nonfunctional, action must be taken to restore FUNCTIONAL status in 30 days. The 30 day Completion Time is based on operating experience and the other Conditions/Required Actions that prevent the hydrogen and oxygen concentrations from reaching flammability limits.
With less than one Hydrogen Monitor channel per recombiner FUNCTIONAL during Waste Gas Holdup System operations, the operator Wolf Creek - Unit 1 - TRM B 3.3.16-2 Revision 61
Explosive Gas Monitoring Instrumentation TR B 3.3.16 BASES ACTIONS C.1 (continued) is directed to immediately suspend the supply of oxygen to the affected recombiner(s). Without the ability to determine the hydrogen content of the waste gas stream during recombiner operation, the operator is unable to calculate whether flammable conditions exist within the system. The immediate Completion Time is consistent with the required times for actions to be performed without delay and in a controlled manner.
With less than one required Outlet Oxygen Monitor channel per recombiner FUNCTIONAL during Waste Gas Holdup System operations, the operator is directed to verify the oxygen concentration utilizing grab samples at a frequency of once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . This is acceptable since the required Inlet Oxygen Monitor is still FUNCTIONAL. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time is adequate based upon operational experience. .~
E.1 and E.2 With both the required Inlet and Outlet Oxygen Monitor channels per recombiner nonfunctional during Waste Gas Holdup System operations or the required Inlet Oxygen Monitor channel and Inlet Hydrogen Monitor channel on the same recombiner nonfunctional during Waste Gas Holdup System operation, the operator is required to suspend oxygen supply to the affected recombiner immediately. The immediate Completion Time is consistent with the required times for actions to be performed without delay and in a controlled manner.
In addition to the suspension of the supply of oxygen, both the concentration of oxygen and hydrogen are to be determined based upon grab samples once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months during degassing operations or once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months during other waste gas operations.
Without the ability to determine the resultant oxygen concentration following passage of the waste gas stream through the recombiner, the operator is unable to determine whether or not flammable limits are being approached. To therefore reduce the probability of reaching flammability limits, in this hydrogen rich environment, the addition of oxygen is suspended.
Recombining and degassing operations are allowed to continue provided grab samples are taken and analyzed to provide assurance that flammable limits of TR 3.10.2 are not exceeded.
Wolf Creek - Unit 1 - TRM B 3.3.16-3 Revision 61
Explosive Gas Monitoring Instrumentation TR B 3.3.16 BASES ACTIONS F.1 (continued)
If Required Actions and associated Completion Times of Condition B, C, D or E are not met, operation of the Waste Gas Holdup System is immediately suspended. The immediate Completion Time is consistent with the required times for actions to be performed without delay and in a controlled manner.
TECHNICAL TSR 3.3.16.1 SURVEILLANCE REQUIREMENTS Performance of the CHANNEL CHECK once every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ensures that a gross instrumentation failure has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including isolation, indication, and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. If the channels are within the criteria, it is an indication that the channels are FUNCTIONAL.
The Frequency is based on operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the TR required channels.
Wolf Creek- Unit 1 - TRM B 3.3.16-4 Revision 61
Power Distribution Monitoring System (PDMS)
TR B 3.3.19 B 3.3 INSTRUMENTATION TR B 3.3.19 Power Distribution Monitoring System (PDMS)
BASES BACKGROUND The Power Distribution Monitoring System (PDMS) generates a continuous measurement of the core power distribution using the methodology documented in Reference 1. The measured core power distribution is used to determine the most limiting core peaking factors, FN&l and Fa(Z). The most limiting measured core peaking factor values are used to verify that the reactor is operating within"the design limits.
The PDMS requires information on current plant and core conditions in order to determine the core power distribution using the core peaking factor measurement and measurement uncertainty methodology described in Reference 1. Addendum 4 to WCAP-12472-P-A provides an updated thermocouple uncertainty analysis process and affirmation of the continued use of the NRC approved Westinghouse design model methodology, currently PHOENIX-P/ANC, PARAGON/ANG and NEXUS/ANG. The core and plant condition information is used as~input.
to the continuous core power distribution measurement software that continuously and automatically determines the current core peaking factor values.
In order for the PDMS to accurately determine the peaking factor values, the core power distribution measurement software requires accurate information about the current reactor power level, average reactor vessel inlet temperature, control bank positions, the Power Range Detector calibrated voltage values, and measured temperatures from Core Exit Thermocouples (T/C).
APPLICABLE The PDMS is used for periodic measurement of the core power SAFETY ANALYSIS distribution to confirm operation within design limit, and periodic calibration of the excore detectors. This system does not initiate any
. automatic protection action. The PDMS is not assumed to be FUNCTIONAL to mitigate the consequences of a OBA or transient (Reference 2).
TR The TR requires the PDMS to be FUNCTIONAL with the minimum required channels shown in Table TR 3.3.19-1. The PDMS is FUNCTIONAL when the required channel inputs are available, the calibration data set is valid, and the reactor power level is at least 25% of RTP. The PDMS must be calibrated above 25% RTP to assure the accuracy of the calibration data set which can be generated from the incore flux map, core exit thermocouples, and the other input channels.
Wolf Creek - Unit 1 - TRM B 3.3.19-1 Revision 61
Power Distribution Monitoring System (PDMS)
TR B 3.3.19 BASES TR Below 25% RTP, the PDMS is nonfunctional, since the calculated power (continued) distribution is of reduced accuracy, and may not be used to demonstrate compliance with the LCO limits.
This ensures that the measured plant and core condition information input to the core power distribution measurement software with the PDMS FUNCTIONAL is adequate to accurately calculate the core peaking factors. The peaking factor calculations include measurement uncertainty that bounds the actual measurement uncertainty of a FUNCTIONAL
PDMS.
APPLICABILITY The PDMS must be FUNCTIONAL in MODE 1 with THERMAL POWER
~ 25% when it is used for recalibration of the Excore Neutron Flux Detection System, or monitoring of QPTR, or measurement of FN6H or F0 (Z).
ACTIONS A nonfunctional PDMS cannot be used for recalibration of the Excore Neutron Flux Detection System, or monitoring of QPTR, or measurement of FN6H or F0 (Z). Required Action A.1 requires the immediate suspension of the use of the PDMS for these activities if the system is nonfunctional.
TECHNICAL TSR 3.3.19.1 SURVEILLANCE REQUIREMENTS Performance of a CHANNEL CHECK at a frequency of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ensures that a gross instrumentation failure has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument' drift in one of the channels. A CHANNEL CHECK will detect gross channel failure; thus it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
The Frequency is based on the need to establish that the required inputs to the PDMS are valid when using the PDMS to obtain a core power distribution measurement to be used to confirm that the reactor is operating within design limits.
Wolf Creek- Unit 1 -TRM B 3.3.19-2 Revision 61 I
Power Distribution Monitoring System (PDMS)
TR 3.3.19 BASES TECHNICAL TSR 3.3.19.2 SURVEILLANCE REQUIREMENTS Upon initial plant startup following refueling, the PDMS uses a calibration (continued) data set calculated by the core designer for the new core.
An incore flux map for PDMS calibration may be obtained above 25%
RTP. The initial calibration data set generated in each operating cycle must utilize incore flux measurements from at least 75% of the incore thimbles, with at least two incore thimbles in each core quadrant.
Subsequent to the initial calibration, the calibration data set can be updated using incore flux measurements from at least 50% of the incore thimbles, with at least two incore thimbles in each core quadrant. The incore flux measurements in combination with inputs from the Table TR 3.3.19-1 channels are used to generate the updated calibration data set, including the nodal calibration factors and the thermocoupl~ mixing factors.
Following the initial calibration, the Frequency is 31 EFPD with minimum
core exit thermocouple coverage, or when the minimum core exit * .
thermocouple coverage is available for the PDMS calibration. The minimum thermocouple coverage consists of at least 17 thermocouples with a minimum of two per core quadrant.
Following the initial calibration, the Frequency is 180 EFPD when the optimum core exit thermocouple coverage. is available for the PDMS calibration. The optimum thermocouple coverage consists of at least 17 thermocouples with a minimum of two per core quadrant, distributed such all interior fuel assemblies (coverage of fuel assemblies with a face along the baffle is not required) are within a chess knight's move of a thermocouple.
TSR 3.3.19.3 A CHANNEL CALIBRATION is performed every 18 months, or approximately at every refueling. CHANNEL CALIBRATION is a complete check of the instrument loop, including the sensor. The test verifies that the channel responds to a measured parameter with the necessary range and accuracy. This SR is modified with a Note stating that neutron detectors are excluded from the CHANNEL CALIBRATION.
The CHANNEL CALIBRATION forthe power range neutron detectors consists of a normalization of the detectors based on a power calorimetric and flux map performed above 15% RTP. The Frequency is based on operating experience and consistency with the typical industry refueling cycle.
Wolf Creek - Unit 1 - TRM B 3.3.19-3 Revision 61
Power Distribution Monitoring System (PDMS)
TR 3.3.19 BASES TECHNICAL TSR 3.3.19.4 SURVEILLANCE REQUIREMENTS Verfication that the Digital Rod Position Indication (DRPI) agrees with the (continued) demand position ensures that the DRPI and demand position indication is operating correctly. Refer to the corresponding Bases for Technical Specification 3.1. 7 for a discussion of SR 3.1. 7 .1.
REFERENCES 1. WCAP-12472-P-A, "BEACON Core Monitoring and Operations Support System," August 1994 (including Addendum 4, September 2012).
2. Amendment No. 188, July 23, 2010.
Wolf Creek - Unit 1 - TRM B 3.3.19-4 Revision 61
Structural Integrity TR B 3.4.17 B 3.4 REACTOR COOLANT SYSTEM TR B 3.4.17 Structural Integrity BASES BACKGROUND The quality group classification for each water- and steam- containing pressure component is shown in USAR Table 3.2-1 (Ref. 1). The components are classified according to their safety significance as dictated by service and functional requirements and by the consequences of their failure .. The quality group classifications and code requirements
*for the quality of plant process systems meet the intent of Regulator)'
Guides (RG) 1.26 and 1.143.
The design, fabrication, inspection, and testing requirements of each classification provide the required degree of conservatism in assuring component pressure integrity and OPERABILITY/FUNCTIONALITY.
The Code requirements applicable to each quality group classification are identified in USAR Table 3.2-2. The quality group classifications and the interfaces between classifications in a system having components of different classifications are indicated on the piping and instrumentation diagram or flow diagram of that system.
In accordance with 10 CFR 50.55a(g), structural integrity must be maintained in conformance with ASME Code Section XI for those components that are subject to Code requirements. Depending on the type of deficiency, structural integrity can be determined by meeting applicable ASME Section Ill requirements,Section XI acceptance standards,Section XI IWB-3600 analytical evaluation procedures, or applicable NRC approved ASME Code Cases. NRC Inspection Manual Chapter 0326 (Ref. 2), Appendix C, Section C.1 O (Piping and Pipe Support Requirements), C.11 (Flaw Evaluation), and C.12 (Operational Leakage From ASME Code Class 1, 2, and 3 Components) contain specific NRC guidance and acceptable evaluation procedures that can be used to determine structural integrity and OPERABILITY for ASME Code Class 1, 2, and 3 components. The guidance from Inspection Manual Chapter 0326 is summarized below.
NRC Inspection Manual Chapter 0326 Guidance - Flaw Evaluation The NRC staff accepts ASME Code Case N-513 (and later versions of the Case as approved by RG 1.147), "Evaluation Criteria for Temporary Acceptance of Flaws in Moderate Energy Class 2 or 3 piping Section XI, Division 1," (Ref. 4) as an acceptable alternative to the ASME Code requirements for evaluating the structural integrity for flaws identified in moderate-energy piping.
Wolf Creek - Unit 1 - TRM B3.4.17-1 Revision 62
Structural Integrity TR B 3.4.17 BASES.
BACKGROUND RG 1.147, "lnservice Inspection Code Case Acceptability, ASME (continued) Section XI, Division 1" endorses code cases, some with conditions. Refer to RG 1.147 for the latest revision accepted by the NRC and any specific conditions associated with the code case. ASME Section XI Code Cases have a specified applicability consisting of an edition and addenda of Section XI or a range of editions and addenda of Section XI.Section XI requires Code Cases to be applicable to the Section XI edition and addenda specified in the lnservice Inspection Program.
In addition, the NRC issued Generic Letter (GL) 90-05, "Guidance for Performing Temporary Non-Code Repair of ASME Code Class 1, 2, and 3 Piping," (Ref. 3) which permits licensees to consider either the "through-wall flaw" or the "wall thinning" flaw evaluation approach when assessing the structural integrity of moderate energy piping with identified flaws that are not through-wall. If the flaw is found acceptable by the "through-wall flaw" approach, a temporary non-code repair may be made following NRC staff review and approval of the evaluation. A non-code repair is a repair not in compliance with the construction code or ASME Section XI. (Refer to GL 90-05 for further guidance on non-code repairs.) Compensatory actions may be implemented without NRC staff review and approval, provided the compensatory action does not involve a noncode repair to the piping system or supports and the compensatory action can be implemented in accordance with 10 CFR 50.59. If the flaw is found acceptable by the "wall thinning" approach, immediate repair of the flaw is not required; but WCNOC should comply with the guideline for flaw repair and monitoring. Whenever a flaw does not meet ASME Code or construction code acceptance standards or the requirements of an NRC endorsed ASME code case, a relief request is required. The relief request needs to be submitted in a timely manner after completing the OPERABILITY determination process documentation.
The NRC staff accepts the ASME Code, construction code, GL 90-05, ASME Code Case N-513 (and later versions of the Case as approved in RG 1.147), and any other applicable NRC-approved ASME Code Case criteria for conclusively establishing that a TS-required ASME Code Class 2 or 3 piping system that contains a flaw has adequate structural integrity and is, therefore in a degraded but operable condition. ASME Code Cases which describe methods, criteria, or requirements different from the ASME Code referenced in 10 CFR 50.55a cannot be used to evaluate the acceptability of a flaw without prior NRC Wolf Creek- Unit 1 -TRM B 3.4.17-2 Revision 35
Structural Integrity TR B 3.4.17 BASES BACKGROUND review and approval unless the ASME Code Cases are endorsed (continued) in the applicable regulatory guides.
The table below summarizes the methods available which are acceptable to the NRC staff for evaluating structural integrity of flaws found in boiling or pressurized water-cooled nuclear power facilities in TS-required components (including supports) classified as ASME Code Class 1, Class 2, and Class 3.
Methods Available to Evaluate Structural Integrity Code ASME Code NRC Approved Code Case N- GL 90-05 Class/Energy Section XI/ Alternative 513 Construction Code e.g. RG approved Code Case Class 1/HE x x Class 2/HE x x Class 2/ME x x x Class 3/HE x x *-x Class 3/ME x x x x Operational Leakage from ASME Code Class 1. 2. and 3 Components The regulations require that the structural integrity of ASME Code Class 1, 2, and 3 components be maintained in accordance with the ASME Section XI Code or construction code acceptance standards. If a leak is discovered in a Class 1, 2, or 3 component while conducting an inservice inspection, maintenance activity, or during facility operation, any corrective measures to repair or replace the leaking component must be performed in accordance with IWA-4000 of Section XI. The NRC staff expects that components be restored to ASME Section XI Code or construction code acceptance standards by the end of the next refueling outage.
To evaluate the structural integrity of the leaking component, the criteria in Section XI of the ASME Code, the construction code, or any applicable ASME Code Case approved by the NRC may be used. In addition, the structural integrity of Class 3 piping may be evaluated by using the criteria of paragraph C.3.a of Enclosure 1 to GL 90-05. If the flaw meets the GL 90-05 criteria, the piping is degraded but OPERABLE. However, relief from ASME Code requirements is needed even if the structural integrity is found acceptable when applying GL 90-05. Whenever a flaw is through-wall in an ASME Code component when evaluated using Wolf Creek - Unit 1 - TRM B 3.4.17-3 Revision 59
Structural Integrity TR B 3.4.17 BASES BACKGROUND GL 90-05, a relief request needs to be submitted in a timely (continued) manner after completing the OPERABILITY determination process documentation and prior to implementing a non-code repair activity to the SSC.
Alternatively, the structural integrity of leaking Class 2 or Class 3 moderate-energy piping may be evaluated using the criteria of ASME Code Case N-513 (and later versions of the Case as approved in RG 1.147) or any other applicable NRC approved ASME Code Case, as indicated in the above table. If the flaw in the. leaking component has adequate structural integrity in accordance with criteria of an ASME Code Case acceptable to the NRC staff, the piping can be deemed degraded but operable and continued temporary service of the degraded piping is permitted.
A relief request is not necessary when evaluated in accordance with an NRC approved code case as endorsed by the code case regulatory guide, and the evaluation results demonstrate adequate structural integrity.
Components with these flaws must be restored to ASME Code or construction code requirements through repair/replacement activity or meet requirements acceptable to the NRC, as approved in a relief request or ASME Code Case approved under the RGs prior to the completion of the next scheduled refueling outage.
Other compensatory actions may be taken, provided these compensatory actions are within the limitations of 10 CFR 50.59.
The NRC staff does not consider through-wall conditions in components to be in accordance with the intent of the ASME Code or construction code and, therefore, would not meet Code requirements, even though the component may demonstrate adequate structural integrity. Thus, unless a through-wall flaw is evaluated and found acceptable using an applicable and endorsed Code Case, in which all provisions are met, including any
. additional requirements or limitations imposed by the RG endorsing-the Code Case, a relief requestis necessary.
If the decision is to control the leakage and maintain structural integrity by mechanical clamping means, the requirements of ASME Code Case N-523 (or later versions of the Case as approved in RG 1.147), "Mechanical Clamping Devices for Class 2 and 3 Pipihg Section XI, Division 1," may be followed, because the NRC staff endorses this Code Case in RG 1.147. (This Code Case and later versions of the Case were subsequently WoWCreek-Unlt1-TRM B 3.4.17-4 Revision 35
Structural Integrity TR B 3.4.17 BASES TR expectation of OPERABILITY. (Refer to TR subsection on Immediate (continued) OPERABILITY Determinations for additional guidance.) In performing the prompt OPERABILITY determination, the determination must evaluate the structural integrity of the leaking component using the actual geometry of the through-wall flaw characterized or bounded with volumetric examination methods._ It may be possible to use visual methods to determine the exterior dimension(s) and orientation of a through-wall flaw in a leaking component if the degradation is active on the outside of the component. However, if the degradation is active from the inside of the component, even though the outside surface breaking dimension of a through-wall flaw may be small, the length and extent of the flaw inside the component wall may be quite long and potentially result in inadequate structural integrity of the component. For non-TS SSCs, an assessment of FUNCTIONALITY shall be performed to determine if structural integrity is maintained. For non-TS SSCs that support a TS SSC, the FUNCTIONALITY may impact the OPERABLITY of the TS SSC. If the non-TS SSC is nonfunctional, an immediate OPERABILITY determination shall be performed on the supported TS SSC.
The ASME Code classifies heat exchangers as "components." For Class 1, 2, and 3 heat exchangers (including room coolers), the heat exchanger tubing is part of the heat exchanger component and cannot be considered to be piping for purposes of applying the NRC Inspection Manual Chapter 0326 guidance. Until NRC approval for evaluating structural integrity of heat exchanger tubes is obtained, upon identification that a room cooler -
leak (i.e., a through-wall flaw) is in the tubing, structural integrity cannot be acceptably determined and the TS-required component must be declared inoperable. If a non-TS room cooler supports a TS SSC, then the FUNCTIONALITY of the room cooler must be determined. The FUNCTIONALITY of the room cooler may impact the OPERABILITY of the supported TS SSC. The associated Essential Service Water (ESW)
System, may still be OPERABLE as long as the ESW System functions to remove post accident heat loads.
Immediate OPERABILITY Determination Guidance In order to determine if the TS-required component is OPERABLE under an immediate OPERABILITY determination, the degradation mechanism must be discernable from visual examination (such as external corrosion or wear), or there must be substantial operating experience with the identified degradation mechanism in the affected system. In addition, detailed non-destructive examination data may be necessary to Wolf Creek - Unit 1 - TRM B 3.4.17-7 Revision 59
...... -sfructural Integrity TR B 3.4.17 BASES TR determine a component is OPERABLE under an immediate (continued) OPERABILITY determination. If detailed non-destructive examination is necessary and the examination cannot be completed within the time frame normally expected for an immediate OPERABILITY determination, the component should be declared inoperable and the appropriate TS Condition/Required Action entered.
APPLICABILITY The structural integrity of the ASME Code Class 1, 2, and 3 components is required during MODES 1, 2, 3, 4, 5, and 6. This TR applies whenever Code Class 1, 2, or 3 components are OPERABLE or FUNCTIONAL, not just during the performance of inservice inspection examinations.
ACTIONS A.1 and A.2 Condition A applies to one or more degraded or nonconforming ASME Code Class 1, 2, or 3 component(s) for which structural integrity is not maintained. Required Action A.1 requires action be initiated to determine OPERABILITY or FUNCTIONALITY for the affected component(s). If the affected component is a TS SSC, an immediate OPERABILITY determination shall be performed. If the affected component is a non-TS SSC, a FUNCTIONALITY determination shall be performed. If the non-TS SSC is nonfunctional, an immediate OPERABILITY determination shall be performed on the supported TS SSC.
The immediate Completion Time is consistent with the required times for action.s. to be performed without delay and in a controlled manner.
TECHNICAL TSR 3.4.17.1 SURVEILLANCE REQUIREMENTS 'TSR 3.4.17.1 requires performing inservice inspections of ASME Section XI Code Class 1, 2, and 3 components in accordance with the lnservice
Inspection Program described in TR 5.5.6, "lnservice Inspection Program."
lnservice inspection of ASME Code Class 1, 2, and 3 components are performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda, as required by 10 CFR 50.55a(g), to ensure that the structural integrity of these components will be maintained at an acceptable level throughout the life of the plant.
Exception to these requirements apply where relief has been granted by the Commission pursuant to 10 CFR 50.55a(z) and (g)(6)(i). The surveillance intervals specified in Section XI of the ASME Code apply.
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Structural Integrity TR B 3.4.17 BASES TECHNICAL During design and construction, components of the Reactor Coolant SURVEILLANCE System were designed to provide access to permit inservice inspection in REQUIREMENTS accordance with Section XI of the ASME Boiler and Pressure Vessel (continued) Code, 1974 Edition and Addenda through Summer 1975.
REFERENCES 1. USAR, Section 3.2.2.
2. NRC Inspection Manual Chapter 0326, "Operability Determinations & Functionality Assessments for Conditions Adverse to Quality or Safety."
3. Generic Letter 90-05, "Guidance for Performing Temporary Non-Code Repair of ASME Code Class 1, 2, and 3 Piping," June 15, 1990; and August 16, 1990, NRR letter by J.E. Richardson, "Follow-up on Generic Letter 90-05 Regarding Guidance for Performing Temporary Non-Code Repair of ASME Code Class 1, 2, and 3 Piping," (letter 90-02380).
4. Code Case N-513 (and later versions of the Case as approved by RG 1.147), "Evaluation Criteria for Temporary Acceptance of Flaws in Class 2 and 3 Piping."
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Containment Vessel Structural Integrity TR B 3.6.1 B 3.6 CONTAINMENT SYSTEMS TR B 3.6.1 Containment Vessel Structural Integrity BASES BACKGROUND The containment consists of a prestressed, reinforced concrete, cylindrical structure with a hemispherical dome. The Post-tensioning System used for the shell and dome of the containment employs tendons.
Each tendon consists of 170 one quarter..:inch high strength steel wires and anchoring components. The prestressing load is transferred, by cold formed button heads on the ends of the individual wires through stressing washers, to steel bearing plates embedded in the structure. The ultimate strength of each tendon is approximately 1000 tons. The unbonded tendons are installed in tendon ducts and tensioned in a predetermined sequence. The tendon ducts consist of galvanized, spiral wrapped, semi-rigid corrugated steel tubing. After tensioning, a petroleum based corrosion inhibitor is pumped into the duct.
The Post-tensioning System is divided into two tendon groups. One group consists of 86 inverted U-shaped tendons which extend through the-full height of the cylindrical wall over the dome. They are anchored at the bottom of the base slab through the ceiling of the tendon access gallery.
The other tendon group consists of 165 tendons forming the circumferential (hoop) tendons. Three buttresses located 120 degrees apart extend the full vertical height of the containment. The hoop tendons are anchored to one buttress, extend through the next, and are anchored to the third buttress. Thus, each hoop tendon extends around 240 degrees of the containment building (Ref. 1).
The containment OPERABILITY requirements are provided in Technical Specifications 3.6.1, "Containment," 5.5.6, "Containment Tendon.
Surveillance Program," and 5.5.16, "Containment Leakage Rate Testing Program," (Refs. 2 and 3). Reference 4 describes further details on the performance of containment tendon surveillances.
Technical Specification 5.5.6 requires the Containment Tendon Surveillance Program, *and its inspection frequencies and acceptance criteria, to be in accordance with Section XI, Subsection IWL (Ref. 5) of the ASME Boiler and Pressure Vessel Code and applicable addenda as required by 10 CFR 50.55a, except where an exemption or relief has been authorized by the NRC.Section XI requires the preparation of a Containment lnservice Inspection Program Plan (Ref. 6) that identifies the applicable Edition and Addenda of Section XI and integratesSection XI requirements, regulatory requirements, commitments, and relief or exemption requests, if any.
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. *'.; -~ .- *~
Containment Vessel Sfrudural Integrity TR B 3.6.1 BASES APPLICABLE The safety design basis for the containment is that the containment must SAFETY ANALYSIS withstand the pressures and temperatures of the limiting DBA without exceeding the design leakage rate. An integral part of the containment's ability to perform its safety function depends on the FUNCTIONALITY of the containment tendons. Failure of the containment tendons may result in the inability of containment to withstand the effects ofa high energy line break. Therefore, the inspection and surveillance of tendon parameters are required to assure the OPERABILITY of containment.
These requirements ensure that the structural integrity of the containment will be maintained in accordance with safety analysis requirements for the life of the facility. Structural integrity is required to ensure that the containment is maintained OPERABLE. Refer to the Applicable Safety Analyses Section of Technical Specification 3.6.1 Bases. The measurement of containment tendon lift-off force, the tensile tests of the tendon wires or strands, the visual examination of tendons, anchorages and exposed exterior surfaces of the containment, along with the Containment Leakage Rate Testing Program is sufficient to demonstrate this capability. **
TR This TR provides controls to ensure appropriate evaluations are performed upon the discovery of conditions which indicates an abnormal degradation of the containment vessel. An abnormal degradation of the containment vessel does not necessarily result in an inoperable containment.
If at anytime during the evaluation of a degraded condition it is determined that the containment vessel will not be able to perform its specified safety function, the containment must be immediately declared inoperable per the requirements of Technical Specifications. LCO 3.6.1 and LCO 3.0.2.
APPLICABILITY In MODES 1, 2, 3, and 4, a DBA could cause a release of radioactive material into containment. In MODES 5 and 6, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES. Therefore, in support of containment's OPERABILITY requirements, only MODES 1, 2, 3, and 4 are applicable for the OPERABILITY of the containment vessel.
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Containment Vessel Structural Integrity TR B 3.6.1 BASES ACTIONS A.1 and A.2 As required by Section XI, IWL-3220, when the average of all measured tendon forces (including the measured forces in two tendons located adjacent to any tendon with measured forces between 90% and 95% of the predicted force) is less than the minimum required prestress specified at the anchorage for that type of tendon, an engineering evaluation is required to be performed. The engineering evaluation is performed to justify the continued OPERABILITY of containment by determining the acceptability of the containment vessel without repair of the degraded condition.
The Completion Time of Required Action A.1 is based upon operating experience and the relatively low probability of an event requiring the containment to withstand the effects of a DBA during the time period.
ASME Code Section XI, Subsection IWL (IWL-3300), requires an engineering evaluation be performed for items with examination results that do not meet the acceptance standards of IWL-3200. The engineering evaluation shall include the following:
a. the cause of the condition that does not meet the acceptance standards;
b. the acceptability of the concrete containment without repair of the item;
c. whether or not repair/replacement is required and if required, the extent, method, and completion date for the repair/replacement activity; and
d. extent, nature, and frequency of additional examinations.
The Completion Time of Required Action A.2 is based on the requirements of ASME Code,Section XI, IWA-6000. IWA-6000 requires that an lnservice Inspection (ISi) Summary Report be prepared afthe * -
completion of the inservice inspection each refueling outage. The ISi Summary Report is required to be submitted to the NRC within 90 days of completion of the refueling outage. The Containment lnservice Inspection Program Plan (Ref. 6) provides the guidelines for use of Form OAR-1 for reporting containment vessel abnormal degradation.
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Containment Vessel Structural Integrity TR B 3.6.1 BASES ACTIONS B.1 and B.2 When containment vessel abnormal degradation has occurred for reasons other than Condition A, an engineering evaluation is required to be performed. The engineering evaluation is performed to justify the continued OPERABILITY of containment by determining the acceptability of the containment vessel without repair of the degraded condition.
The Completion Time of Required Action B.1 is based upon operating experience and the relatively low probability of an event requiring containment to withstand the effects of a OBA during the time period.
ASME Code Section XI, Subsection IWL (IWL-3300), requires an engineering evaluation be performed for items with examination results that do not meet the acceptance standards of IWL-3200. The engineering evaluation shall include the following:
a. the cause of the condition that does not meet the acceptance standards;
b. the acceptability of the concrete containment without repair of the item;
c. whether or not repair/replacement is required and if required, the extent, method, and completion date for the repair/replacement activity; and
d. extent, nature, and frequency of additional examinations.
The Completion Time of Required Action B.2 is based on the requirements of ASME Code,Section XI, IWA-6000. IWA-6000 requires that an lnservice Inspection (ISi) Summary Report be prepared at the completion of the inservice inspection each refueling outage. The ISi Summary Report is required to be submitted to the NRC within 90 days of completion of the. refueling outage. The Containment lnservice Inspection Program Plan (Ref. 6) provides the guidelines for use of ASME Form OAR-1 for reporting containment vessel abnormal degradation.
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Containment Vessel Structural Integrity TR B 3.6.1 BASES REFERENCES 1. USAR, Section 3.8.1.1 and Section 6.2.
2. Technical Specification 3.6.1 and associated Bases.
3. Technical Specifications 5.5.6 and 5.5.16.
4. Specification 16577-C-158(0), "Technical Specification for Containment Tendon Surveillance."
5. . . ASME Boiler*and Pressure Vessel Code Section XI, Subsection IWL.
6. WCRE-22, "Containment lnservice Inspection Program Plan Wolf Creek Generating Station Interval 2."
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EES for Crane Operation - Fuel Building TR B 3.7.13 B 3.7 PLANT SYSTEMS TR B 3.7.13 Emergency Exhaust System (EES) for Crane Operation - Fuel Building BASES BACKGROUND A description of the EES is provided in the Bases for Technical Specification 3.7.13, "Emergency Exhaust System," (Ref. 1).
APPLICABLE The EES has a design function to filter radioactive particles which have SAFETY ANALYSES been released as a result of a fuel handling accident. The OPERABILITY of the EES with respect to a fuel handling accident is addressed by Technical Specification 3.7.13 (Ref. 1). The dose consequences of dropping of a light load (i.e, load ::;; 2250 pounds) into the spent fuel pool storage area, which may result in partial damage to one or more irradiated fuel assembly(s) is less than the dose consequences of a fuel handling accident. Therefore, since the potential for damage exists which would result in the release of radioactive material, it is necessary for operational requirements to be in place to protect against the inadvertent release of radioactive materials to the environment. Heavy loads (i.e.,
loads in excess of 2250 pounds), with the exception of the spent fuel transfer gates, are prevented from being moved over fuel assemblies in the spent fuel storage facility by crane travel interlocks and physical stops. FUNCTIONALITY requirements for crane travel interlocks and physical stops are specified in TR 3.7.17, "Crane Travel - Spent Fuel Storage Facility," (Ref. 2).
TR Two independent and redundant trains of the EES are required to be FUNCTIONAL to ensure that at least one train is available, assuming a single failure that disables the other train. Total system failure could result in the atmospheric release from the fuel building. Such a release is not expected to exceed the guideline limits of 10 CFR 100 for the situation addressed by this TR.
The EES is considered FUNCTIONAL when the individual components necessary to control releases from the fuel building are FUNCTIONAL in both trains. An EES train is considered FUNCTIONAL when its associated:
a. Fan is FUNCTIONAL;
b. HEPA filter and charcoal adsorber are not excessively restricting flow, and are capable of performing their filtration function; and Wolf Creek - Unit 1 - TRM B 3.7.13-1 Revision 61
EES for Crane Operation - Fuel Building TR B 3.7.13 BASES TR c. Heater, ductwork, and dampers are FUNCTIONAL, and air (continued) circulation can be maintained.
In addition, the fuel building boundary must be maintained, including the integrity of the walls, floors, ceilings, ductwork, and access doors.
The TR is modified by a Note allowing the fuel building boundary to be opened intermittently under administrative controls. For entry and exit through doors, the administrative control of the opening is performed by the person(s) entering or exiting the area. For other openings, these controls consist of stationing a dedicated individual at the opening who is in continuous communication with the control room. This individual will have a method to rapidly close the opening when a need for fuel building isolation is indicated.
APPLICABILITY During crane or auxiliary hoist operation with load over the fuel storage areas when irradiated fuel is stored in the spent fuel pool, the EES is required to be FUNCTIONAL in the fuel building ventilation isolation signal (FBVIS) mode of operation to mitigate the consequences of an event as a result of the dropping of a load on to or into a fuel storage area. However, no OBA or transient assumes the EES to be FUNCTIONAL during crane operation with load over the fuel storage areas (Ref. 3). During crane or auxiliary hoist operation with no loads or when there is no irradiated fuel in the spent fuel storage pool, the EES is not required to be FUNCTIONAL in the FBVIS mode since the potential of radioactive release due to dropping a load on an irradiated fuel assembly is unlikely.
ACTIONS With one EES train nonfunctional, the FUNCTIONAL EES train may be placed in the FBVIS mode. This action ensures that this remaining train is FUNCTIONAL, that no failures that would prevent automatic actuation
-_ will occur, and that ariy active failure will be readily detected.
The Required Action has been modified by a Note to ensure that only the Required Action and associated Completion Time of Condition Bare required if both EES trains are nonfunctional due to a nonfunctional fuel building boundary. With both EES trains nonfunctional, a FUNCTIONAL EES train is not available to operate in the FBVIS mode. Required Action B.1 is the appropriate remedial action. The exception does not affect tracking the Completion Time from the initial entry into Condition A; only the requirement to comply with the Required Action.
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Snubbers TR B 3.7.20 B 3. 7 PLANT SYSTEMS TR B 3. 7 .20 Snubbers BASES BACKGROUND Component standard supports, are those metal supports which are designed to transmit loads from the pressure-retaining boundary of the component to the building structure. Although classified as component standard supports, snubbers require special consideration due to their unique function. Snubbers are designed to provide no transmission of force during normal plant operations, but function as a rigid support when subjected to dynamic transient loadings. Therefore, snubbers are chosen in lieu of rigid supports where restricting thermal growth during normal operation would induce excessive stresses in the piping nozzles or other equipment. The location and size of the snubbers are determined by stress analysis. Depending on the design classification of the particular piping, different combinations of load conditions are established. These conditions combine loading during normal operation, seismic loading and loading due to plant accidents/transients to four different loading sets.
These loading sets are designated as: normal, upset, emergency;"and faulted condition. The actual loading included in each of the four conditions, depends on the design classification of the piping. The calculated stresses in the piping and other equipment, for each of the four conditions, must be in conformance with established design limits.
Supports for pressure-retaining components are designed in accordance with the rules of the ASME Boiler and Pressure Vessel Code, Section Ill, Division 1 {Ref. 1). The combination of loadings for each support, including the appropriate stress levels, meet the criteria of Regulatory Guide 1.124, "Design Limits and Loading Combinations for Class 1 Linear-Type Component Supports" {Ref. 2), and Regulatory Guide 1.130, "Design Limits and Loading Combinations for Class 1 Plate-and -Shell-Type Component Supports" {Ref. 3).
Snubbers are classified and grouped by design and manufacturer but not by size. For example, mechanical snubbers utilizing the same design features of the 2-kip, 10.;.kip, and 100-kip capacity manufactured by Company "A" are of the same type. The same design mechanical snubbers manufactured by Company "B" for the purposes of this Technical Requirements would be of a different type. Snubbers may also be classified and grouped by their inaccessibility or accessibility for the purpose of visual inspection. Therefore, each snubber type may be grouped for inspection in accordance with accessibility.
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Snubbers TR B 3.7.20 BASES BACKGROUND A list of individual snubbers with detailed information regarding the (continued) snubber's location, size and system(s) which it affects is available at the plant in accordance with Section 50.71(c) of 10 CFR Part 50. The accessibility of each snubber is determined and approved by the Plant Safety Review Committee. The determination is based upon the existing radiation levels and the expected time to perform a visual inspection in each snubber location as well as other factors associated with accessibility during plant operations (e.g., temperature, atmosphere, location etc.), and the recommendations of Regulatory Guides 8.8 and 8.1 O (Refs. 7 and 8). The addition or deletion of any mechanical snubber is performed in accordance with Section 50.59 of 10 CFR Part 50.
The Snubber Service Life Program is administered through TR 5.5.5.
The service life of a snubber is established via manufacturer input and information through consideration of the snubber service conditions and associated installation and maintenance records (newly installed snubber, seal replaced, spring replaced, in high radiation area, in high temperature area, etc.). The requirement to monitor the snubber service life is included to ensure that the snubbers periodically undergo a performance evaluation in view of their age and operating conditions. These records will provide the basis for future consideration of snubber service life.
APPLICABLE Technical Specification (TS) LCO 3.0.8 establishes conditions under SAFETY ANALYSES which systems are considered to remain capable of performing their intended safety function when associated snubbers are not capable of providing their associated support function(s). The TS LCO states that supported system(s) are not required to be considered inoperable solely due to one or more snubbers not capable of performing their associated support function(s). This is appropriate because a limited length of time is allowed for maintenance, testing, or repair of one or more snubbers not capable of performing their associated support function(s) and appropriate compensatory measures are specified in the snubber requirements, which are located outside of the TS under licensee control.
Pipe* and equipment supports, in general, are not directly considered in designing the accident sequences for theoretical hazard evaluations.
Further, various Probabilistic Risk Assessment (PRA) studies have indicated that snubbers are not of prime importance in a risk significant sequence (Refs. 4 and 5). Therefore, the function of the snubbers is not essential in mitigating the consequences of a DBA or transient (Refs. 6 and 9).
TR 3.7.20 applies to the snubbers listed in Table TR3.7.20.5, which provides a listing of plant snubbers installed on safety related systems, or that could adversely affect a safety related system due to being Wolf Creek - Unit 1 - TRM B 3.7.20-2 Revision 62
Snubbers TR B 3.7.20 BASES APPLICABLE nonfunctional. There are no non-safety related snubbers or snubbers SAFETY ANALYSES installed on non-safety related systems that could adversely affect a (continued) safety related system due to being nonfunctional.
TR This TR requires that the snubbers listed in Table TR 3.7.20-5 be FUNCTIONAL. Table TR 3.7.20-5 is a listing of snubbers installed on safety related systems. There are no snubbers that are utilized on non-safety related systems that could adversely effect a safety related system due to being nonfunctional.
APPLICABILITY FUNCTIONALITY requirements for the required snubbers listed in Table TR 3.7.20-5 are determined based on the MODES in which the system(s) supported by each snubber, and any other safety related system(s) that could be adversely affected by nonfunctionality of the required snubber, are required by TS to be OPERABLE. FUNCTIONALITY requirements are specified in Table TR 3.7.20-?. -
ACTIONS A Note has been added to the ACTIONS to clarify the application of Completion Time rules. The Conditions of this Technical Requirement may be entered independently for each affected snubber. The Completion Time( s) of the nonfunctional snubber will be tracked separately for each affected system starting from the time the Condition was entered for that snubber.
Condition A applies when one or more snubber(s) listed in Table TR 3.7.20-5 that are non-TS LCO 3.0.8 applicable are nonfunctional (e.g.,
removed from the attached system or otherwise not capable of performing their design function). The snubber list in Table TR 3.7.20-5 is annotated to identify snubbers that are TS LCO 3.0.8 applicable, TS LCO 3.0.8 provides an allowance under which systems are not considered to be inoperable solely due to one or more snubbers not being capable of performing their associated support function(s). The design function of the snubber must be considered in order to determine if a snubber is TS LCO 3.0.8 applicable.
a) If the design function of the snubber is to react to only seismic loads, the snubber is TS LCO 3.0.8 applicable.
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Snubbers TR B 3.7.20 BASES ACTIONS A.1 (continued) b) If the design function of the snubber includes both seismic loads and non-seismic loads, any TS systems that are supported by the nonfunctional snubber, or that could be adversely affected, must be able to remain OPERABLE if subjected to the non-seismic loads with the snubber removed or otherwise nonfunctional. If the supported TS system will remain OPERABLE when subjected to non-seismic loads, the snubber is LCO 3.0.8 applicable.
When one or more non-TS LCO 3.0.8 snubber(s) are nonfunctional, the TS supported system or component is immediately declared inoperable and the applicable TS LCO(s) are declared not met and applicable Conditions/Required Actions entered.
B.1 and B.2 Condition B applies when one or more TS LCO 3.0.8 applicable snubbers listed in Table TR 3.7.20-5 are removed from the attached system or the required snubber(s) are nonfunctional or otherwise not capable of performing their support function while in place. The list of snubbers in Table TR 3.7.20-5 is annotated to identify snubbers that are TS LCO 3.0.8 applicable.
Required Action B.1 directs that nonfunctional snubber(s) be restored to FUNTIONAL status consistent with the Completion Times of TS LCO 3.0.8.
In the event that the nonfunctional snubber(s) can not be restored within the TS LCO 3.0.8 allowed time and are unable to perform their associated support function, Required Action B.2 specifies that the affected supported system TS system(s) must be declared inoperable and the applicable TS LCO(s) declared not met and associated Conditions/Required Actions entered prior to expiration of the LCO 3.0.8 Completion Time in accordance with TS LCO 3.0.2.
When a snubber is to be rendered incapable of performing its related support function for testing or maintenance or is discovered to be nonfunctional, it must be determined whether any TS system(s) require the affected snubber(s) for system OPERABILITY, and whether the plant is in a MODE or specified condition in the Applicability that requires the supported TS system(s) to be OPERABLE.
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Snubbers TR B 3.7.20 BASES ACTIONS B.1 and B.2 (continued)
TS LCO 3.0.8 provides an allowance under which systems are not considered to be inoperable solely due to one or more snubbers not capable of performing their associated support function(s). The system may be declared OPERABLE while utilizing TS LCO 3.0.8. The following are applicable for utilizing LCO 3.0.8:
a. Determine whether a TS system is rendered inoperable by a nonfunctional snubber.
(1) If it is determined that the supported TS system(s) do not require the snubber(s) to be FUNCTIONAL in order to support OPERABILITY of the system(s) LCO 3.0.8 is not needed.
(2) If the LCO(s) associated with any supported TS system(s) are not currently applicable (i.e., the plant is not in a MODE
or other specified condition in *the Applicability of the' LCO),
LCO 3.0.8 is not needed.
(3) If the support TS system(s) are inoperable for reasons other than snubbers, LCO 3.0.8 cannot be used.
(4) If the design function of the snubber includes only non-seismic loads (e.g., thrust loads, blowdown loads, water-hammer loads, steam-hammer loads, LOCA loads, and pipe rupture loads), TS LCO 3.0.8 cannot be applied to the TS systems supported by the nonfunctional snubber.
However, a nonfunctional snubber in this situation does not result in inoperability of the supported TS system(s) if it can be confirmed that the snubber is not needed for OPERABILITY of the TS system(s).
b. . Determine the design basis of the nonfunctional snubber. When a snubber is to be rendered nonfunctional for testing or maintenance or is discovered to be nonfunctional, the design function of the snubber must be determined in order to determine if LCO 3.0.8 may be used.
(1) If the design function of the snubber is to react to only seismic loads, LCO 3.0.8 may be applied.
Wolf Creek - Unit 1 - TRM B 3.7.20-5 Revision 62
Snubbers TR B 3.7.20 BASES ACTIONS B.1 and B.2 (continued)
(2) If the design function of the snubber includes both seismic loads and non-seismic loads, any TS systems supported by the nonfunctional snubber must be able to remain OPERABLE if subjected to the non-seismic loads with the snubber removed. If the supported TS system will remain OPERABLE when subjected to non-seismic loads, LCO 3.0.8 may be applied.
(3) If the design function of the snubber includes only non-seismic loads (e.g., thrust loads, blowdown loads, water-hammer loads, steam-hammer loads, LOCA loads, and pipe rupture loads), TS LCO 3.0.8 cannot be applied to the TS systems supported by the nonfunctional snubber.
However, a nonfunctional snubber in this situation does not result in inoperability of the supported TS system(s) if it can be confirmed that the snubber is not needed for OPERABILITY of the TS systeni(s).
c. When LCO 3.0.8.a is used, at least one train of the Auxiliary Feedwater (AFW) System not associated with the nonfunctional snubber must be OPERABLE.
d. When LCO 3.0.8.b is used, at least one train of the AFW System not associated with the nonfunctional snubber must be OPERABLE. If the nonfunctional snubber(s) supports all trains of the AFW System or if the AFW System becomes inoperable due to an emergent condition, some alternative means of core cooling must be available.
e. The LCO 3.0.8 requirement to assess and manage risk is met by programs to comply with the requirements of paragraph (a)(4) of the Maintenance Rule, 10 CFR 50.65, to assess and manage risk resulting from maintenance activities. LCO 3.0.8 should be .
considered with respect to other plant maintenance activities, and integrated into the existing Maintenance Rule process to the extent possible so that maintenance on any unaffected train or subsystem is properly controlled, and emergent issue properly addressed. The risk assessment need not be quantified, but may be a qualitative awareness of the vulnerability of systems and components when one or more snubbers are not able to perform their associated support function.
Wolf Creek - Unit 1 - TRM B 3.7.20-6 Revision 62
Snubbers TR B 3.7.20 BASES ACTIONS 8.1 and 8.2 (continued)
f. A record of the implementation of any applicable Tier 2 restrictions, and the associated plant configuration, shall be available on a recoverable basis for NRC inspection.
Condition C applies when one or more non-TS snubbers listed in Table TR 3.7.20-5 are removed from the attached system or the required snubber(s) are nonfunctional or otherwise not capable of performing their support function while in place. The list of snubbers in-Table TR 3.7.20-5 is annotated to identify non-TS snubbers. If one or more non-TS snubber is nonfunctional, action must be taken to restore the snubber to FUNCTIONAL status in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .
The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time is consistent with TS LCO 3.0.8.a and is reasonable based on the low probability of a seismic event concurrent with an event that would require operation of the supported system occurring while the snubber(s) are not capable of performing their associated support function.
TECHNICAL Surveillance Testing is performed in accordance with the applicable SURVEILLANCE requirements of ASME OM Code and Subsection ISTD, "Preservice and REQUIREMENTS lnservice Examination and Testing of Dynamic Restraints (Snubbers) in Light-Water Reactor Nuclear Power Plants" (Ref. 11 ).
The Snubber Program complies with the requirements of 10 CFR 50.55a(b)(3)(v) for snubber visual examination and functional testing as documented in WCOP-29, "Snubber Examination, Testing, and Service Life Monitoring Program Plan - Fourth 10-Year lnservice Testing Interval," (Ref. 12).
Exemptions from the surveillance program for individual snubbers may be
I granted by the Commission if a justifiable basis for exemption is presented. Snubbers so exempted shall be listed in the list of individual snubbers indicating the extent of the exemptions.
Wolf Creek - Unit 1 - TRM B 3.7.20-7 Revision 62
Snubbers TR B 3.7.20 BASES TECHNICAL In order to establish the inspection frequency for each type of snubber on SURVEILLANCE a safety related system, it was assumed that the frequency of snubber REQUIREMENTS failures and initiating events is constant with time and that the failure of (continued) any snubber could cause the system to be unprotected and to result in failure during an assumed initiating event. Inspections performed before that interval has elapsed may be used as a new reference point to determine the next inspection. However, the results of such early inspections performed before the original required time interval has elapsed (nominal time less 25%) may not be used to lengthen the required inspection interval. Any inspection whose results require a shorter inspection interval will override the previous schedule.
TSR 3.7.20.1 TSR 3. 7 .20.1 comprises a visual inspection of the snubbers listed in Table TR 3.7.20-5. A pre-fuel load visual inspection and functional test has been performed on each snubber using the acceptance criteria listed in Table TR 3.7.20-2. The baseline takes into account that the snubbers have experienced thermal cycling and normal operating service as a result of previous hot functional testing. The initial inservice inspection has been performed on the snubbers prior to completion of the first refueling outage. The Frequency of subsequent surveillances depends on the number of snubbers found nonfunctional from each previous inspection as provided in Table TR 3.7.20-3 and the lnservice Inspection Program as described .in TR 5.5.6.
The acceptance criteria and corrective actions are listed in Table TR 3.7.20-2.
The visual inspections are designed to detect obvious indications of nonfunctionality of the snubbers. Removal of insulation or direct contact with the snubbers is not required initially. However, suspected causes of nonfunctionality are to be investigated and all snubbers of the same type and all snubbers subjected to the same failure mode are to be inspected more frequently.
The visual inspection frequency is based upon maintaining a constant level of snubber protection during an earthquake or severe transient and the number of unacceptable snubbers found during the previous inspection. As a result, the required inspection intervals vary inversely with the number of nonfunctional snubbers found during an inspection. If Wolf Creek - Unit 1 - TRM B 3.7.20-8 Revision 62
Snubbers TR B 3.7.20 BASES TECHNICAL. TSR3.7.20.1 (continued)
SURVEILLANCE REQUIREMENTS a snubber fails the visual acceptance criteria, the snubber is declared unacceptable and cannot be declared FUNCTIONAL via functional testing. However, if the cause of rejection is understood and remedied for that type of snubber and for any other type of snubbers that may be generically susceptible and FUNCTIONALITY verified by testing, that snubber may be reclassified acceptable for the purpose of establishing the next surveillance interval.
Code Case OMN-13, which allows the extension of the visual inspection interval in Table TR 3.7.20-3, is approved for use in Regulatory Guide 1.192 (Ref. 10). The visual inspection interval may be extended in accordance with Code Case OMN-13 once the prerequisites of the code case have been satisfied.
Snubbers may be categorized according to accessibility as noted in the Notes to Table TR 3.7.20-3. The accessibility of each snubber is.
determined ba_sed on radiation level as well as other factors such as temperature, atmosphere, location, etc. The recommendations of Regulatory Guide 8.8, "Information Relevant to Maintaining Occupational Radiation Exposure as Low a Practicable," (Ref. 7) and Regulatory Guide 8.10, "Operation Philosophy for Maintaining Occupational Radiation Exposure as Low as Practicable," (Ref. 8) are considered in planning and implementing the visual inspection program.
Since the visual inspections are augmented by a functional testing program, the visual inspection need not be a hands on inspection, but shall require visual scrutiny sufficient to assure that fasteners or mountings for connecting the snubbers to supports or foundations have no visible bolts, pins or fasteners missing, or other visible signs of physical damage such as cracking or loosening.
TSR 3.7.20.2 This TSR is modified by a Note which restricts the performance of this TSR to 60 days prior to and during a scheduled refueling outage.
TSR 3.7.20.2 comprises the functional testing of snubbers listed in Table TR 3.7.20-5 as described in Table TR 3.7.20-4. The sample plan (10%)
is being used for each of the four Defined Test Plan Groups (DTPG's).
Snubber functional testing is performed to the requirements of Table TR 3.7.20-4 and performed prior to the completion of each refueling outage. The once each refueling Frequency, in conjunction with the Note, is based on the need to perform this surveillance under the conditions that apply just prior to or during a unit refueling outage.
Wolf Creek - Unit 1 - TRM B 3.7.20-9 Revision 62
snubbers TR B 3.7.20 BASES TECHNICAL TSR 3. 7 .20.3 SURVEILLANCE REQUIREMENTS This TSR addresses the monitoring of the service life of the snubbers in (continued) accordance with the Snubber Service Life Program described in TR 5.5.5.
The requirement to monitor the snubber service life is included to ensure that the snubbers periodically undergo a performance evaluation in view of their age and operating conditions.
TSR 3.7.20.4 If the plant has experienced an unexpected, potentially damaging snubber transient, an inspection per Table TR 3.7.20-1 is performed on all snubbers attached to sections of systems that have experienced the transient. The potential impact of the transient is assessed by reviewing operating data and by visually inspecting the associated system. In addition to the visual inspection, the freedom-of-motion of the mechanical snubber(s) is verified per Table TR 3.7.20-1.
An unexpected potentially damaging snubber transient is an event that was outside the design basis of the SSC and could have affected the snubber(s) attached to the SSC. Specifically, this is an event that could have resulted in physical evidence of damage to a SSC outside the design basis for that SSC. The physical evidence should show leakage at nozzles and/or piping welds, damage to supports or insulation, twisted or rotated clamps and/or struts, or excessive pipe movements.
The determination concerning whether or not an unexpected potentially damaging snubber transient event has occurred will be made following a preliminary walkdown of the affected section of system by Quality Control personnel. Based upon the results of this walkdown, a determination will be made by Engineering and/or Operations personnel concerning whether or not the event should be considered an unexpected potentially damaging snubber transient event requiring entry into Condition C and performance of TSR 3. 7.20.4.
The Completion Time of 6 months has been assigned based upon industry practice.
Wolf Creek - Unit 1 - TRM B 3.7.20-10 Revision 62 I
Snubbers TR B 3.7.20 BASES REFERENCES 1. ASME Boiler and Pressure Vessel Code, Section Ill and XI.
2. Regulatory Guide 1.124, "Design Limits and Loading Combinations for Class 1 Linear-Type Component Supports,"
Revision 1, January 1978.
3. Regulatory Guide 1.130, "Design Limits and Loading Combinations for Class 1 Plate-and Shell-Type Component Supports," Revision 1, October 1978.
4. "Zion Probabilistic Safety Study", Commonwealth Edison Company, September 1981.
5. "Millstone Unit 3 Probabilistic Safety Study," North-East Utilities Company, August 1983.
6. NRC Staff Review of Nuclear Steam Supply System Vendor Owners Groups' Application of the Commission's Interim Policy Statement Criteria to Standard Technical Specifications.
Attachment to letter dated May 1988 from T. E. Murley, NRC to W.
S. Wilgus, Chairman the B&W Owners Group.
7. Regulatory Guide 8.8, "Information Relevant to Maintaining Occupational Radiation Exposure as Low as Practicable."
8. Regulatory Guide 8.10, "Operating Philosophy for Maintaining Occupational Radiation Exposure as Low as Practicable."
9. WCAP-11618, "MERITS Program-Phase 11, Task 5, Criteria Application," including Addendum 1 dated April, 1989, Section 3.7.9.
10. Regulatory Guide 1.192, "Operation and Maintenance Code Case Applicability, ASME OM Code."
11. ASME OM Code, Subsection ISTA and ISTD.
12. WCOP-29, "Snubber Examination, Testing, and Service Life Monitoring Program Plan - Fourth 10-Year lnservice Testing Interval."
Wolf Creek - Unit 1 - TRM B 3.7.20-11 Revision 62
Electrical Penetration Room Coolers TR B 3.7.24 B 3. 7 PLANT SYSTEMS TR~ 3.7.24 Electrical Penetration Room Coolers BASES BACKGROUND The penetration room coolers provide a suitable ambient temperature for the safety related equipment located in the electrical penetration rooms.
Room coolers SGL 15A and SGL 15B are located in rooms 1410 and 1409, respectively, on elevation 2026' of the Auxiliary Building.
Normally, safety related room coolers would not be taken out of service during normal plant operation, without also taking actions in accordance with existing Technical Specifications of the supported equipment. An evaluation (Ref. 1) has shown that loss of the penetration room coolers (SGL 15A/B) will not degrade the performance of the supported equipment in the associated penetration room. NRC Inspection Manual Chapter 0326 (Ref. 2), Appendix C, Section C.09 (Support System Operability) provides guidance allowing licensees to make determinations as to which support equipment is required under various conditions.
APPLICABLE The engineering design function of the penetration room coolers is to SAFETY ANALYSES provide a suitable ambient temperature for the safety related equipment located in the electrical penetration rooms. The maximum normal operating temperature for these rooms is identified in USAR Table 3.11 (B)-1 (Ref. 3) as 104°F. The design basis accident (OBA) room temperature is 106°F per USAR Table 3.11 (B)-2 (Ref. 3). The Area Temperature Monitoring Technical Requirements (TR 3.7.22) allowable temperature is~ 101°F. Typically, during normal plant operation, these rooms are found to stay at ambient temperatures in the range of 60°F to near 100°F.
TR One electrical penetration room cooler is required to be FUNCTIONAL in each electrical penetration room to ensure adequate cooling during normal operation.
An electrical penetration room cooler is considered to be FUNCTIONAL when the individual components necessary to maintain its associated electrical penetration room temperatures within acceptable limits are FUNCTIONAL.
Wolf Creek - Unit 1 - TRM B 3.7.24-1 Revision 60
Electrical Penetration Room Coolers TR B 3.7.24 BASES TR If the associated essential service water train is unavailable or (continued} inoperable and service water is available as a cooling medium to the electrical penetration room cooler, the room cooler is considered capable of providing cooling. A cooler may also be considered capable of providing cooling if restoration can be made by an operator in the Control Room or a dedicated operator stationed locally for the purpose of restoring the cooler. Restoration must be uncomplicated, covered by written procedure, must not require diagnosis or repair, and must be part of a pre-job brief on the test.
APPLICABILITY Since the environmental qualification of equipment is not MODE dependent, electrical penetration room cooler FUNCTIONALITY addressed by this TR is required at all times.
ACTIONS A Note modifies the ACTIONS to clarify the application of the Completion Time rules. The Conditions of this requirement may be entered independently for each electrical penetration room cooler. The Completion Times(s) of each electrical penetration room cooler will be tracked separately for each room cooler starting from the time the Condition was entered for that room cooler.
With an electrical penetration room cooler nonfunctional and not capable of providing cooling, action must be taken to de-energize the fan motor of the associated room cooler within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . De-energizing the motor reduces equipment heat gain to the room. The Completion Time of 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to de-energize the fan motor is acceptable based on operating experience and the temperature in the affected rooms is not expected to significantly increase within this period of time.
With an electrical penetration room cooler nonfunctional and not capable of being restored to service, the temperature in the associated electrical penetration room must be monitored to determine if a degraded condition exists. Thus, Required Action A.2 requires an initial check on temperatures by completing TSR 3.7.22.1 within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the most recently obtained room temperature exceeds 90°F to ensure the equipment room remains within allowable Wolf Creek - Unit 1 - TRM B 3.7.24-2 Revision 60
Electrical Penetration Room Coolers TR B 3.7.24 BASES ACTIONS A.2 (continued) limits (101°F). If the electrical penetration room temperature remains
~ 90°F, performance of TSR 3. 7 .22.1 every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient to ensure room temperature does not exceed 101°F. The initial Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is acceptable based on the expected heat-up rate of the rooms.
If the Required Actions and associated Completion Time for Condition A are not met, a Condition Report (CR) should be initiated immediately for addressing why the Required Actions were not performed and determining whether or not a degraded or nonconforming condition exists.
If equipment in the affected area(s) is degraded or nonconforming, determine if the equipment in the affected area(s) is OPERABLE/FUNCTIONAL, as applicable, by evaluating the effects of the out-of-limit temperature(s) on the equipment. The immediate Completion Time is consistent for actions to be performed without delay and in a controlled manner.
Table TR B 3.7.24-1 provides a list of the Technical Specifications and Technical Requirements which are applicable if the Required Actions and associated Completion Times of Condition A are not taken or the compensatory actions cannot maintain adequate temperatures to ensure OPERABILITY/FUNCTIONALITY.
When one electrical penetration room cooler is nonfunctional in MODE 1, 2, 3, or 4, action must be taken to restore the electrical penetration room cooler to FUNCTIONAL status in 7 days. The 7-day Completion Time is based on the low probability of an event requiring the components in the electrical penetration rooms to operate to mitigate*a OBA.
When one electrical penetration room cooler is nonfunctional in MODE 5, 6, or defueled, action must be taken to restore the electrical penetration room cooler to FUNCTIONAL status in 30 days. The 30-day Completion Time is based on the heat input to the electrical penetration rooms from a design basis LOCA or main steam line break is of minimal significance.
Wolf Creek - Unit 1 - TRM B 3.7.24.,3 Revision 60
Electrical Periefration Room Coolers TR B 3.7.24 BASES ACTIONS E.1 (continued)
If Required Action C.1 or D.1 cannot be performed within the associated Completion Time, Required Action E.1 requires initiation of a Condition Report (CR) immediately. The CR should provide an accurate description of the problem, the Required Action and associated Completion Time not complied with. The intent of the Required Action is to utilize the corrective action program to assure prompt attention and adequate management oversight to minimize the time of technical requirement noncompliance and/or nonfunctionality of the electrical penetration room cooler.
TECHNICAL None.
SURVEILLANCE REQUIREMENTS REFERENCES 1. CCP-09816, Rev. 0, "Inoperable Electrical Penetration Room Cooler (SGL 15A/B)."
2. NRG Inspection Manual Chapter 0326, "Operability Determinations & Functionality Assessments for Conditions Adverse to Quality or Safety."
3. USAR Table 3.11 (B).
Wolf Creek - Unit 1 - TRM B 3.7.24-4 Revision 60
ii-:
Offsite Power System - Transmission Network TR B 3.8.1 B 3.8 ELECTRICAL POWER SYSTEMS TR B 3.8.1 Offsite Power System - Transmission Network BASES BACKGROUND General Design Criterion (GDC) 17 (Ref. 1), "Electric power system," of Appendix A to 10 CFR 50 requires, in part, that an onsite electric power system and an offsite electric power system shall be provided to permit functioning of structures, systems, and components important to safety.
GDC 17 further specifies that electric power from the transmission network to the onsite electrical distribution system shall be supplied by two physically independent circuits (not necessarily on separate rights of way) designed and located so as to minimize to the extent practical the likelihood of their simultaneous failure under operating and postulated accident and environmental conditions. A switchyard common to both circuits is acceptable.
There are three 345 kV lines connecting the unit switchyard to the offsite transmission network. The three lines are:
a. Wolf Creek - Waverly - LaCygne 345 kV line
b. Wolf Creek - Rose Hill 345 kV line
c. Wolf Creek - Benton 345 kV line The above 345 kV lines do not share common rights-of-way, do not have any crossovers, and are not in close proximity of one another, except in the immediate vicinity of the unit switchyard. If any one of the three 345 kV lines faulted, the breakers located at the unit switchyard would trip, deenergizing the line. Any one 345 kV transmission line can carry the total engineered safety features (ESF) load required for safe shutdown.
Any transmission line may be aligned by controlled switching to feed either of the two ESF transformers. Having at least two FUNCTIONAL 345 kV transmission lines will minimize the probability of losing electric power from the offsite transmission network.
Offsite power is supplied to the unit switchyard from the offsite transmission network. From the switchyard, two electrically and physically separated circuits (offsite circuits) provide AC power, through the ESF transformers, to the 4.16 kV ESF buses. The OPERABILITY of the offsite circuits and diesel generators are addressed in limiting condition for operation (LCO) 3.8.1, "AC Sources - Operating." A detailed description of the offsite power network and the offsite circuits to the Class 1E ESF buses is found in the USAR, Chapter 8 (Ref. 2).
Wolf Creek - Unit 1 - TRM B 3.8.1-1 Revision 60
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Offsite Power System - Transmission Network TR B 3.8.1 BASES APPLICABLE The offsite transmission network is designed to provide sufficient SAFETY ANALYSES capacity, capability, redundancy, and reliability to ensure the availability of necessary power to offsite circuits and Class 1E Electrical Power System so that the fuel, Reactor Coolant System, and containment design limits are not exceeded.
TR TR 3.8.1 requires three 345 kV transmission lines connecting the unit switchyard to the offsite transmission network be FUNCTIONAL. This provision minimizes the probability of losing electric power from the offsite transmission network as a result of, or coincident with, the loss of power generated by the unit.
A 345 kV transmission line is considered FUNCTIONAL when the transmission line is connected to the unit switchyard and capable of supplying power. The Wolf Creek - Waverly - LaCygne 345 kV line is sectioned into two line sections; the Wolf Creek to Waverly Switching Station 345 kV line and the Waverly Switching Station to LaCygne 345 kV line. The Wolf Creek - Waverly - LaCygne 345 kV line is considered FUNCTIONAL when both line sections are energized through both a Wolf Creek and a LaCygne 345 kV breaker and tied together through at least one 345 kV breaker in the Waverly Switching Station.
APPLICABILITY The FUNCTIONALITY of the 345 kV transmission lines is required in MODES 1, 2, 3, and 4.
ACTIONS When one 345 kV line is nonfunctional (e.g., loss of one 345 kV line),
action shall be taken within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to verify two 345 kV lines are FUNCTIONAL. Procedure OFN AF-025, "Unit Limitations," may be utilized for verifying the two 345 kV lines are capable of supplying power.
A Condition Report should be initiated when this Condition is entered for trending the reliability of the offsite transmission network.
With two 345 kV lines nonfunctional, immediate entry into Condition A of Technical Specification LCO 3.8.1, "AC Sources - Operating," is required.
The offsite circuit energizing NB01 is considered inoperable when the East 345 kV bus is only energized from the offsite transmission network through the 345-50 and 345-60 main generator breakers. For this configuration, switchyard breakers 345-120 and 345-90 OR 345-120 and 345-80 are open.
Wolf Creek - Unit 1 - TRM B 3.8.1-2 Revision 60
Offsite Power System - Transmission Network TR B 3.8.1 BASES ACTIONS 8.1 (continued)
The immediate Completion Time is consistent with the required time for actions to be performed without delay and in a controlled manner.
TECHNICAL TSR 3.8.1.1 SURVEILLANCE REQUIREMENTS This SR ensures proper circuit continuity for the offsite transmission network supply to the WCGS switchyard. The breaker alignment verifies correct breaker position to ensur~ _that the WCGS switchyard is connected to the offsite transmission network. Power availability is verified by contacting the Transmission System Operator (TSO) and verifying the lines are connected at the remote end and the absence of actual or predicted switchyard voltage degraded conditions. The 7 day Frequency is adequate since breaker position is not likely to change without operator awareness.
REFERENCES 1. 10 CFR 50, Appendix A, GDC 17.
2. USAR, Chapter 8.
Wolf Creek - Unit 1 - TRM B 3.8.1-3 Revision 60 I
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IMPLEMENTED (4l TAB -Table of Contents 43 ORR 10-3738 12/28/10 ii 25 ORR 05-1996 9/28/05 iii 54 ORR 13-2529 10/25/13 TAB - B 3.0 APPLICABILTY B 3.0-1 41 ORR 10-1702 10/1/10 B 3.0-2 41 ORR 10-1702 10/1/10 B 3.0-3 41 ORR 10-1702 10/1/10 B 3.0-4 41 ORR 10-1702 10/1/10 B 3.0-5 41 ORR 10-1702 10/1/10 B 3.0-6 41 ORR 10-1702 10/1/10 B 3.0-7 41 ORR 10-1702 10/1/10 B 3.0-8 41 ORR 10-1702 10/1/10 B 3.0-9 41 ORR 10-1702 10/1/10 B 3.0-10 41 ORR 10-1702 10/1/10 B 3.0-11 41 ORR 10-1702 10/1/10 B 3.0-12 41 ORR 10-1702 10/1/10 B 3.0-13 41 DRR 10-1702 10/1/10 B 3.0-14 20 ORR 04-1410 1017/04 TAB - B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.7-1 41 ORR 10-1702 10/1/10 B3.1.7-2 41 ORR 10-1702 10/1/10 B 3.1.7-3 3 ORR 99-1581 12/18/99 B3.1.8-1 41 ORR 10-1702 10/1/10 B 3.1.8-2 41 ORR 10-1702 10/1/10 B 3.1.9-1 15 DRR 03-0861 7/10/03 B 3.1.9-2 41 ORR 10-1702 10/1/10 B 3.1.9-3 41 DRR 10-1702 10/1/10 B 3.1.9-4 41 ORR 10-1702 10/1/10 B 3.1.9-5 41 ORR 10-1702 10/1/10 B 3.1.9-6 55 ORR 14-0344 2/27/14 B 3.1.9-7 28 ORR 06-1349 7/24/06 B 3.1.9-8 3 ORR 99-1581 12/18/99 B 3.1.10-1 41 ORR 10-1702 10/1/10 B 3.1.10-2 49 ORR 12-0674 4/10/12 B 3.1.10-3 48 ORR 12-0266 2/2/12 B 3.1.10-4. 55 ORR 14-0344 2/27/14 B 3.1.10-5 48 ORR 12-0266 2/2/12 TAB- B 3.3 INSTRUMENTATION B 3.3.3-1 41 ORR 10-1702 10/1/10 B 3.3.3-2 41 ORR 10-1702 10/1/10 B 3.3.3-3 41 ORR 10-1702 10/1/10 B 3.3.3-4 41 ORR 10-1702 10/1/10 B 3.3.3-5 41 ORR 10-1702 10/1/10 B 3.3.3-6 28 DRR 06-1349 7124106 B 3.3.9-1 41 DRR 10-1702 10/1/10 B 3.3.9-2 41 ORR 10-1702 10/1/10 B 3.3.9-3 41 DRR 10-1702 10/1/10 Wolf Creek - Unit 1 Revision62
LIST OF EFFECTIVE PAGES - TECHNICAL'REOUIREMENT MANUAL BASES PAGE< 1> REVISION NO. <2> 3 CHANGE DOCUMENT < > DATE EFFECTIVE/
IMPLEMENTED <4>
TAB- B 3.3 INSTRUMENTATION (continued) 8 3.3.9-4 8 DRR 01-0475 5/1/01 B 3.3.10-1 3 DRR 99-1581 12/18/99 83.3.10-2 41 DRR 10-1702 10/1/10 B 3.3.10-3 41 DRR 10-1702 10/1/10 83.3.11-1 41 DRR 10-1702 10/1/10 83.3.11-2 41 DRR 10-1702 10/1/10 B 3.3.11-3 41 DRR 10-1702 10/1/10 B 3.3.11-4 41 DRR 10-1702 10/1/10 B 3.3.11-5 39 DRR 09-1775 10/28/09 83.3.12-1 41 DRR 10-1702 10/1/10 B 3.3.12-2 37 DRR 09-0287 3/20/09 B 3.3.12-3 19 DRR 04-1019 9/1/04 83.3.13-1 41 DRR 10-1702 10/1/10 B 3.3.13-2 41 DRR 10-1702 10/1/10 B 3.3.13-3 41 DRR 10-1702 10/1/10 B 3.3:13-4 3 DRR 99-1581 12/18/99 B 3.3.14-1 51 DRR 13-0371 2/26/13 B 3.3.14-2 51 DRR 13-0371 2/26/13 B 3.3.14-3 53** DRR 13-1518 6/26/13 ..
B 3.3.14-4 53 DRR 13-1518 6/26/13 83.3.14-5 51 DRR 13-0371 2/26/13 B 3.3.14-6 53 DRR 13-1518 6/26/13 83.3.14-7 51 DRR 13-0371 2/26/13 83.3.14-8 51 DRR 13-0371 2/26/13 83.3.14-9 51 DRR 13-0371 2/26/13 83.3.14~10 51 DRR 13-0371 2/26/13 B 3.3.14-11 51 DRR 13-0371 2/26/13 B 3.3.15-1 45 DRR 11-0662 3/21/11 B 3.3.15-2 45 DRR 11-0662 3/21/11 B 3.3.15-3 46 DRR 11-0725 4/11/11 B 3.3.15-4 60 DRR 15-0529 3/26/15 B 3.3.15-5 45 DRR 11-0662 3/21/11 83.3.16-1 41 DRR 10-1702 10/1/10 83.3.16-2 61 DRR 15-0824 4/28/15 B 3.3.16-3 61 DRR 15-0824 4/28/15 B 3.3.16-4 61 DRR 15-0824 4/28/15 B 3.3.16-5 41 DRR 10-1702 10/1/10 83.3.17-1 19 DRR 04-1019 9/1/04 83.3.17-2 41 DRR 10-1702 10/1/10 83.3.17-3 41 DRR 10-1702 10/1/10 83.3.17-4 41 DRR 10-1702 10/1/10 B 3.3.17-5 3 DRR 99-1581 12/18/99 B 3.3.18-1 14 DRR 02-1459 2/12/03 83.3.18-2 41 DRR 10-1702 10/1/10 B 3.3.18-3 49 DRR 12-0673 4/10/12 B 3.3.18-4 49 DRR 12-0673 4/10/12 B 3.3.18-5 49 DRR 12-0673 4/10/12 B 3.3.18-6 49 DRR 12-0673 4/10/12 B 3.3.18-7 49 DRR 12-0673 4/10/12 B 3.3 ..19-1 61 DRR 15-0824 4/28/15 B 3.3.19-2 61 DRR 15-0824 4/28/15 Wolf Creek - Unit 1 ii Revision62
LIST OF EFFECTIVE PAGES - TECHNICAL REQUIREMENT MANUAL BASES PAGE< 1> REVISION NO. <2> CHANGE DOCUMENT <3> DATE EFFECTIVE/
IMPLEMENTED <4>
TAB- B 3.3 INSTRUMENTATION (continued)
B 3.3.19-3 61 DRR 15-0824 4/28/15 B 3.3.19-4 61 DRR 15-0824 4/28/15 TAB - B 3.4 REACTOR COOLANT SYSTEM (RCS)
B 3.4.3-1 10 DRR 02-0122 2128102 B 3.4.3-2 10 DRR 02-0122 2/28/02 B 3.4.3-3 41 DRR 10-1702 10/1/10 B 3.4.3-4 31 DRR 007-0657 5/1/07 TAB- B 3.4 REACTOR COOLANT SYSTEM (RCS) (continued)
B 3.4.10-1 41 DRR 10-1702 10/1/10 B 3.4.10-2 41 DRR 10-1702 10/1/10 B 3.4.16-1 3 DRR 99-1581 12/18/99 B 3.4.16-2 41 DRR 10-1702 10/1/10 B 3.4.16-3 33 DRR 07-1554 9/28/07 B3.4.17-1 62 DRR15-2006 10/26/15 B 3.4.17-2 35 DRR 08-0729 8/28/08 B3.4.17-3 59 DRR15-0112 2/10/15 i3 3.4.17-4 35 DRR 08-0729 8/28/08 B 3.4.17-5 41 DRR 10-1702 10/1/10 B 3.4.17-6 41 DRR 10-1702 10/1/10 B 3.4.17-7 59 DRR 15-0112 2/10/15 B 3.4.17-8 62 DRR 15-2006 10/26/15 B 3.4.17-9 59 DRR 15-0112 2/10/15 B3.4.18-1 3 DRR99-1581 12/18/99 B 3.4.18-2 41 DRR 10-1702 10/1/10 B 3.4.18-3 41 DRR 10-1702 10/1/10 TAB- B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)
B3.5.1-1 3 DRR99-1581 12/18/99 B 3.5.1-2 41 DRR 10-1702 10/1/10 B 3.5.1-3 3 DRR 99-1581 12/18/99 TAB- B 3.6 CONTAINMENT SYSTEMS B 3.6.1-1 62 DRR 15-2006 10/26/15 B 3.6.1-2 41 DRR 10-1702 10/1/10 B 3.6.1-3 62 DRR 15-2006 10/26/15 B 3.6.1-4 62 DRR 15-2006 10/26/15 B 3.6.1-5 37 DRR 09-0287 3/20/09 B 3.6.1-6 17 DRR 04-0452 5/26/04 B3.6.1-7 62 DRR 15-2006 10/26/15 TAB - B 3. 7 PLANT SYSTEMS B 3.7.7-1 57 DRR 14-1878 9/30/14 B 3.7.7-2 57 DRR 14-1878 9/30/14 B 3.7.7-3 58 DRR 14-2330 11/6/14 B 3.7.7-4 8 DRR 01-0475 5/1/01 B 3.7.8-1 41 DRR 10-1702 10/1/10 Wolf Creek - Unit 1 iii Revision62
LIST OF EFFECTIVE.PAGES - TECHNICAL REQUIREMENT MANUAL BASES ...... ~-
2 3 PAGE< 1> REVISION NO. <> CHANGE DOCUMENT <> DATE EFFECTIVE/
IMPLEMENTED <4>
TAB- B 3.7 PLANT SYSTEMS (continued)
B 3.7.8-2 52 ORR 13-0658 3/28/13 B 3.7.8-3 52 ORR 13-0658 3/28/13 B3.7.13-1 61 ORR 15-0824 4/28/15 B 3.7.13-2 41 ORR 10-1702 10/1/10 B 3.7.13-3 41 ORR 10-1702 10/1/10 B 3.7.17-1 26 ORR 06-0050 2/28/06 B 3.7.17-2 41 ORR 10-1702 10/1/10 B 3.7.17-3 26 ORR 06-0050 2/28/06 B 3.7.19-1 5 ORR 00-0958 8/17/00 B 3.7.19-2 37 ORR 09-0287 3/20/09 B 3.7.19-3 5 ORR 00-0958 12/18/99 B 3.7.20-1 3 ORR 99-1581 12/18/99 B 3.7.20-2 62 ORR 15-2006 10/26/15 B 3.7.20-3 50 ORR 12-1537 8/30/12 B 3.7.20-4 62 ORR 15-2006 10/26/15 B 3.7.20-5 62 ORR 15-2006 10/26/15 B 3.7.20-6 62 ORR 15-2006 10/26/15 B 3.7.20-7 62 ORR 15-2006 10/26/15 B 3.7.20-8 62 ORR 15-2006 10/26/15 B 3.7.20-9 62 ORR 15-2006 10/26/15 B 3.7.20-10 62 ORR 15-2006 10/26/15 B 3.7.20-11 62 ORR 15-2006 10/26/15 B 3.7.21-1 3 ORR 99-1581 12/18/99 B 3.7.21-2 37 ORR 09-0287 3/20/09 B 3.7.21-3 3 ORR 99-1581 12/18/99 B 3.7.21-4 3 ORR 99-1581 12/18/99 B 3.7.22-1 3 ORR 99-1581 12/18/99 B 3.7.22-2 41 ORR 10-1702 10/1/10 B 3.7.22-3 49 ORR 12-064 4/10/12 B 3.7.24-1 60 ORR 15-0529 3/26/15 B 3.7.24-2 60 ORR 15-0529 3/26/15 B 3.7.24-3 60 DRR15-0529 3/26/15 B 3.7.24-4 60 ORR 15-0529 3/26/15 B 3.7.24.5 37 ORR 09-0287 3/20/09 B 3.7.24-6 21 ORR 04-1535 12/1/04 TAB - B 3.8 ELECTRICAL POWER SYSTEMS B3.8.1-1 60 ORR 15-0529 3/26/15 B 3.8.1-2 60 ORR 15-0529 3/26/15 B3.8.1-3 60 ORR 15-0529 3/26/15 B 3.8.11-1 3 ORR 99-1581 12/18/99 B 3.8.11-2 41 ORR 10-1702 10/1/10 B 3.8.11-3 41 ORR 10-1702 10/1/10 B 3.8.11-4 54 ORR 13-2529 10/25/13 B3.8.11-5 41 ORR 10-1702 10/1/10 B 3.8.11-6 41 ORR 10-1702 10/1/10 TAB- B 3.9 REFUELING OPERATIONS Wolf Creek - Unit 1 iv Revision62
LIST OF EFFECTIVE PAGES - TECHNICAL REQUIREMENT MANUAL..-BASES PAGE( 1> REVISION NO. (Zl *CHANGE DOCUMENT~ DATE EFFECTIVE/
IMPLEMENTED (4l B 3.9.7-1 3 DRR 99-1581 12/18/99 B 3.9.7-2 3 DRR 99-1581 12/18/99 B 3.9.9-1 41 DRR 10-1702 10/1/10 B 3.9.9-2 41 DRR 10-1702 10/1/10 B 3.9.9-3 17 DRR 04-0452 5/26/04 TAB- B 3.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING B 3.10.1-1 3 DRR 99-1581 12/18/99 83.10.1-2 37 DRR09-0287 3/20/09 83.10.1-3 3 DRR99-1581 12/18/99 83.10.2-1 3 DRR99-1581 12/18/99 B 3.10.2-2 37 DRR 09-0287 3/20/09 B 3.10.2-3 41 DRR 10-1702 10/1/10 B 3.10.3-1 3 DRR 99-1581 12/18/99 B 3.10.3-2 37 DRR 09-0287 3/20/09 B 3.10.3-3 37 DRR 09-0287 3/20/09 83.10.3-4 3 DRR99-1581 12/18/99 Note 1 The page number is listed on the center of the_bottom of each page.
Note 2 The revision number is listed in the lower right hand corner of each page. The Revision number will be page specific.
Note 3 The change document will be the document requesting the change. Therefore, the change document should be a ORR number in accordance with AP 26A-002.
Note 4 The date effective or implemented is the date the Technical Requirement Bases pages are issued by Document Control.
Wolf Creek- Unit 1 v Revision62

WM 16-0005, Submittal of Updated Safety Analysis Report (Usar), Revision 29

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