Text

Changes to Technical Specification Bases - Revisions 57 Through 60
	ML14079A019
Person / Time
Site:	Wolf Creek
Issue date:	03/11/2014
From:	Rich Smith; Wolf Creek
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	WO 14-0024
	Download: ML14079A019 (78)
	v • d • e

WV1LF CREEK NUCLEAR OPERATING CORPORATION Russell A. Smith Site Vice President and Chief Nuclear Operating Officer March 11, 2014 WO 14-0024 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555

Subject:

Docket No. 50-482: Wolf Creek Generating Station Changes to Technical Specification Bases - Revisions 57 through 60 Gentlemen:

The Wolf Creek Generating Station (WCGS) Unit 1 Technical Specifications (TS), Section 5.5.14, "Technical Specifications (TS) Bases Control Program," provide the means for making changes to the Bases without prior Nuclear Regulatory Commission (NRC) approval.

In addition, TS Section 5.5.14 requires that changes made without NRC approval be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).

The Enclosure provides those changes made to the WCGS TS Bases (Revisions 57 through 60) under the provisions to TS Section 5.5.14 and a List of Effective Pages. This submittal reflects changes from January 1, 2013 through December 31, 2103.

This letter contains no commitments. If you have any questions concerning this matter, please contact me at (620) 364-4156, or Mr. Michael J. Westman at (620) 364-4009.

Sincerely, Russell A. Smith RAS/rlt Enclosure cc:

M. L. Dapas (NRC), w/e C. F. Lyon (NRC), w/e N. F. O'Keefe (NRC), w/e Senior Resident Inspector (NRC), w/e P.O. Box 411 / Burlington, KS 66839 / Phone: (620) 364-8831 An Equal Opportunity Employer MIF/HCNET

Enclosure to WO 14-0024 Wolf Creek Generating Station Changes to the Technical Specification Bases (41 pages)

CREVS Actuation Instrumentation B 3.3.7 B 3.3 INSTRUMENTATION B 3.3.7 Control Room Emergency Ventilation System (CREVS) Actuation Instrumentation BASES BACKGROUND The CREVS provides an enclosed control room environment from which the unit can be operated following an uncontrolled release of radioactivity.

During normal operation, the Control Building Ventilation System provides control room ventilation. Upon receipt of an actuation signal, the CREVS initiates filtered ventilation and pressurization of the control room. This system is described in the Bases for LCO 3.7.10, "Control Room Emergency Ventilation System (CREVS)."

The actuation instrumentation consists of two radiation monitors in the control room air intake and four radiation monitors in the containment purge isolation system (refer to B 3.3.6 "Containment Purge Isolation Instrumentation" Background). A high radiation signal from any of these gaseous detectors will initiate both trains of the CREVS. The Containment Purge Isolation Instrumentation, however, is not listed as a Function for CREVS because appropriate actions are taken in LCO 3.3.6.

The control room operator can also initiate CREVS trains by manual push buttons in the control room. The CREVS is also actuated by a Phase A Isolation signal and a Fuel Building Ventilation Isolation signal. The Phase A Isolation Function is discussed in LCO 3.3.2, "Engineered Safety Feature Actuation System (ESFAS) Instrumentation." The Fuel Building Ventilation Isolation is not listed as a Function for CREVS because appropriate actions are taken in LCO 3.3.8, "EES Actuation Instrumentation."

APPLICABLE SAFETY ANALYSES The control room must be kept habitable for the operators stationed there during accident recovery and post accident operations.

The CREVS acts to terminate the supply of unfiltered outside air to the control room, initiate filtration, and pressurize the control room. These actions are necessary to ensure the control room is kept habitable for the operators stationed there during accident recovery and post accident operations by minimizing the radiation exposure of control room personnel.

In MODES 1, 2, 3 and 4, the radiation monitor actuation of the CREVS is a backup for the Phase A Isolation signal actuation. This ensures initiation of the CREVS during a loss of coolant accident or steam generator tube rupture.

Wolf Creek - Unit 1 B 3.3.7-1 Revision 0

CREVS Actuation Instrumentation B 3.3.7 BASES APPLICABLE During movement of irradiated fuel assemblies, the radiation monitor SAFETYANALYSES actuation of the CREVS is the primary means to ensure control room (continued) habitability in the event of a fuel handling accident. No control room habitability mitigation is required for the waste gas decay tank rupture accident.

The CREVS actuation instrumentation satisfies Criterion 3 of 10 CFR 50.36(c)(2)(ii).

LCO The LCO requirements ensure that instrumentation necessary to initiate the CREVS is OPERABLE.

1.

Manual Initiation The LCO requires two channels OPERABLE. The operator can initiate the CREVS at any time by using either of two push buttons in the control room. This action will cause actuation of all components in the same manner as any of the automatic actuation signals.

The LCO for Manual Initiation ensures the proper amount of redundancy is maintained in the manual actuation circuitry to ensure the operator has manual initiation capability.

Each channel consists of one push button and the interconnecting wiring to the actuation logic cabinet.

2.

Automatic Actuation Logic and Actuation Relays (BOP ESFAS)

The LCO requires two trains of Actuation Logic and Relays OPERABLE to ensure that no single random failure can prevent automatic actuation of a control room ventilation isolation signal (CRVIS).

Automatic actuation logic and actuation relays consist of the same features and operate in the same manner as described for BOP ESFAS in the Bases Background for 3.3.2.

Wolf Creek - Unit 1 B 3.3.7-2 Revision 57

CREVS Actuation Instrumentation B 3.3.7 BASES LCO

3.

Control Room Radiation (continued)

The LCO specifies two required Control Room Air Gaseous Intake Radiation Monitors (GK RE-04 and -05) to ensure that the radiation monitoring instrumentation necessary to initiate a CRIVS remains OPERABLE.

For sampling systems, channel OPERABILITY involves more than OPERABILITY of channel electronics. OPERABILITY also requires correct valve lineups and sample pump operation, as well as detector OPERABILITY, since these supporting features are necessary for trip to occur under the conditions assumed by the safety analyses.

4.

Containment Isolation - Phase A Control Room Ventilation Isolation is also initiated by all Table 3.3.2-1 Functions that initiate Phase A. Therefore, the requirements are not repeated in Table 3.3.7-1. Instead, refer to LCO 3.3.2, Function 3.a, for all initiating Functions and requirements.

APPLICABILITY All CREVS Functions must be OPERABLE in MODES 1, 2, 3, and 4. The Manual Initiation, Automatic Actuation Logic and Actuation Relay (BOP ESFAS), and Control Room Radiation Functions are also required OPERABLE during movement of irradiated fuel assemblies.

ACTIONS The most common cause of channel inoperability is outright failure or drift of the bistable or process module sufficient to exceed the tolerance allowed by the unit specific calibration procedures. Typically, the drift is found to be small and results in a delay of actuation rather than a total loss of function. This determination is generally made during the performance of a COT, when the process instrumentation is set up for adjustment to bring it within specification. If the Trip Setpoint is less conservative than the tolerance specified by the calibration procedure, the channel must be declared inoperable immediately and the appropriate Condition entered.

Wolf Creek - Unit 1 B 3.3.7-3 Revision 57

CREVS Actuation Instrumentation B 3.3.7 BASES ACTIONS A Note has been added to the ACTIONS indicating that separate (continued)

Condition entry is allowed for each Function. The Conditions of this Specification may be entered independently for each Function listed in Table 3.3.7-1 in the accompanying LCO. The Completion Time(s) of the inoperable channel(s)/train(s) of a Function will be tracked separately for each Function starting from the time the Condition was entered for that Function.

Placing a CREVS train(s) in the control room ventilation isolation signal (CRVIS) mode of operation isolates the unfiltered outside air intake and unfiltered exhaust dampers, and aligns the system for recirculation of the control room air through HEPA filters and charcoal adsorbers. This mode of operation also initiates pressurization and filtered ventilation of the air supply to the control room. Further discussion of the CRVIS mode of operation may be found in the Bases for LCO 3.7.10, "Control Room Emergency Ventilation System," and in Reference 1.

A.1 Condition A applies to all CREVS Functions (i.e., the actuation logic train Functions, the radiation monitor channel Functions, and the manual channel Functions).

If one train is inoperable, or one radiation monitor channel is inoperable, 7 days are permitted to restore it to OPERABLE status. The 7 day Completion Time is the same as is allowed if one train of the mechanical portion of the system is inoperable. The basis for this Completion Time is the same as provided in LCO 3.7.10. If the channel/train cannot be restored to OPERABLE status, one CREVS train must be placed in the Control Room Ventilation Isolation Signal (CRVIS) mode of operation.

This accomplishes the actuation instrumentation Function and places the unit in a conservative mode of operation.

B.1.1. B.1.2, and B.2 Condition B applies to the failure of two CREVS actuation trains, or two manual channels. Condition B is modified by a Note stating this Condition is not applicable to Function 3. Function 3 in Table 3.3.7-1 applies to the Control Room Air Intake Radiation Monitors. The first Required Action is to place one CREVS train in the CRVIS mode of operation immediately.

This accomplishes the actuation instrumentation function that has been lost and places the unit in a conservative mode of operation. The Wolf Creek - Unit 1 B 3.3.7-4 Revision 0

CREVS Actuation Instrumentation B 3.3.7 BASES ACTIONS B.1.1, B.1.2, and B.2 (continued) applicable Conditions and Required Actions of LCO 3.7.10, must also be entered immediately for one CREVS train made inoperable by the inoperable actuation instrumentation. This ensures appropriate limits are placed upon train inoperability as discussed in the Bases for LCO 3.7.10.

Alternatively, both trains may be placed in the CRVIS mode immediately.

This ensures the CREVS function is performed even in the presence of a single failure.

C.1.1, C.1.2, and C.2 Condition C applies to the failure of both radiation monitoring channels.

The first Required Action is to enter the applicable Conditions and Required Actions of LCO 3.7.10 immediately for one CREVS train made inoperable by the inoperable actuation instrumentation. This ensures appropriate limits are placed upon train inoperability as discussed in the Bases for LCO 3.7.10. One CREVS train must also be placed in the CRVIS mode of operation within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . This accomplishes the actuation instrumentation function that has been lost and places the unit in a conservative mode of operation. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time allows for activities such as changing sample filters on the OPERABLE channel while in Condition A, which requires entry into Condition C.

Alternatively, both trains may be placed in the CRVIS mode within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

This ensures the CREVS function is performed even in the presence of a single failure.

D.1 and D.2 Condition D applies when the Required Action and associated Completion Time for Conditions A, B or C have not been met and the unit is in MODE 1, 2, 3 or 4. The unit must be brought to a MODE in which the LCO requirements are not applicable. To achieve this status, the unit must be brought to MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.

Wolf Creek - Unit 1 B 3.3.7-5 Revision 0

CREVS Actuation Instrumentation B 3.3.7 BASES ACTIONS E.1 and E.2 (continued)

Condition E applies when the Required Action and associated Completion Time for Conditions A, B or C have not been met when irradiated fuel assemblies are being moved. Movement of irradiated fuel assemblies and CORE ALTERATIONS must be suspended immediately to reduce the risk of accidents that would require CREVS actuation. This does not preclude movement of a component to a safe position.

SURVEILLANCE REQUIREMENTS A Note has been added to the SR Table to clarify that Table 3.3.7-1 determines which SRs apply to which CREVS Actuation Functions.

SR 3.3.7.1 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 a 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 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 LCO required channels.

SR 3.3.7.2 A COT is performed once every 92 days on each required channel to ensure the entire channel will perform the intended function. This test Wolf Creek - Unit 1 B 3.3.7-6 Revision 57

EES Actuation Instrumentation B 3.3.8 BASES APPLICABILITY The manual and automatic EES initiation must be OPERABLE when moving irradiated fuel assemblies in the fuel building, to ensure the EES operates to remove fission products associated with a fuel handling accident.

High radiation initiation of the FBVIS must be OPERABLE during movement of irradiated fuel assemblies in the fuel building to ensure automatic initiation of the EES when the potential for a fuel handling accident exists.

While in any MODE without fuel handling in progress, the EES instrumentation need not be OPERABLE since a fuel handling accident cannot occur.

ACTIONS The most common cause of channel inoperability is the failure or drift of the bistable or process module sufficient to exceed the tolerance allowed by unit specific calibration procedures. Typically, the drift is found to be small and results in a delay of actuation rather than a total loss of function.

This determination is generally made during the performance of a COT, when the process instrumentation is set up for adjustment to bring it within specification. If the Trip Setpoint is less conservative than the tolerance specified by the calibration procedure, the channel must be declared inoperable immediately and the appropriate Condition entered.

LCO 3.0.3 is not applicable while in MODE 5 or 6. However, since irradiated fuel assembly movement can occur in MODE 1, 2, 3, or 4, the ACTIONS have been modified by a Note stating that LCO 3.0.3 is not applicable. If moving irradiated fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operations. Entering LCO 3.0.3, while in MODE 1, 2, 3, or 4 would require the unit to be shutdown unnecessarily.

A second Note has been added to the ACTIONS to clarify the application of Completion Time rules. The Conditions of this Specification may be entered independently for each Function listed in Table 3.3.8-1 in the accompanying LCO. The Completion Time(s) of the inoperable channel(s)/train(s) of a Function will be tracked separately for each Function starting from the time the Condition was entered for that Function.

Placing a EES train(s) in the FBVIS mode of operation isolates normal air discharge from the fuel building and initiates filtered exhaust, imposing a negative pressure on the fuel building. Further discussion of the FBVIS mode of operation may be found in the Bases for LCO 3.7.13, "Emergency Exhaust System," and in Reference 3.

Wolf Creek - Unit 1 B 3.3.8-3 Revision 57

EES Actuation Instrumentation B 3.3.8 BASES ACTIONS A.1 Condition A applies to the actuation logic train function of the BOP ESFAS, the radiation monitor functions, and the manual function.

Condition A applies to the failure of a single actuation logic train, radiation monitor channel, or manual channel. If one channel or train is inoperable, a period of 7 days is allowed to restore it to OPERABLE status. If the train cannot be restored to OPERABLE status, one EES train must be placed in the FBVIS mode of operation. This accomplishes the actuation instrumentation function and places the unit in a conservative mode of operation. The 7 day Completion Time is the same as is allowed if one train of the mechanical portion of the system is inoperable. The basis for this time is the same as that provided in LCO 3.7.13.

B.1.1, B.1.2, and B.2 Condition B applies to the failure of two EES actuation logic trains, or two manual channels. The first Required Action is to place one EES train in the FBVIS mode of operation immediately. This accomplishes the actuation instrumentation function that has been lost and places the unit in a conservative mode of operation The applicable Conditions and Required Actions of LCO 3.7.13, must also be entered immediately for one EES train made inoperable by the inoperable actuation instrumentation. This ensures appropriate limits are placed on train inoperability as discussed in the Bases for LCO 3.7.13.

Alternatively, both trains may be placed in the FBVIS mode immediately.

This ensures the EES Function is performed even in the presence of a single failure.

C.1.1. C.1.2. and C.2 Condition C applies to the failure of both radiation monitoring channels.

The first Required Action is to enter the applicable Conditions and Required Actions of LCO 3.7.13 immediately for one EES train made inoperable by the inoperable actuation instrumentation. This ensures appropriate limits are placed upon train inoperability as discussed in the Bases for LCO 3.7.13. One EES train must also be placed in the FBVIS mode of operation within one hour. This accomplishes the actuation instrumentation function that has been lost and places the unit in a conservative mode of operation. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time allows for activities such as changing sample filters on the OPERABLE channel when in Condition A, which requires entry into Condition C.

Wolf Creek - Unit 1 B 3.3.8-4 Revision 57 1

SG Tube Integrity B 3.4.17 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.17 Steam Generator (SG) Tube Integrity BASES BACKGROUND Steam generator (SG) tubes are small diameter, thin walled tubes that carry primary coolant through the primary to secondary heat exchangers.

The SG tubes have a number of important safety functions. Steam generator tubes are an integral part of the reactor coolant pressure boundary (RCPB) and, as such, are relied on to maintain the primary system's pressure and inventory. The SG tubes isolate the radioactive fission products in the primary coolant from the secondary system. In addition, as part of the RCPB, the SG tubes are unique in that they act as the heat transfer surface between the primary and secondary systems to remove heat from the primary system. This Specification addresses only the RCPB integrity function of the SG. The SG heat removal function is addressed by LCO 3.4.4, "RCS Loops - MODES 1 and 2," LCO 3.4.5, "RCS Loops - MODE 3," LCO 3.4.6, "RCS Loops - MODE 4," and LCO 3.4.7, "RCS Loops - MODE 5, Loops Filled."

SG tube integrity means that the tubes are capable of performing their intended RCPB safety function consistent with the licensing basis, including applicable regulatory requirements.

Steam generator tubing is subject to a variety of degradation mechanisms. Steam generator tubes may experience tube degradation related to corrosion phenomena, such as wastage, pitting, intergranular attack, and stress corrosion cracking, along with other mechanically induced phenomena such as denting and wear. These degradation mechanisms can impair tube integrity if they are not managed effectively.

The SG performance criteria are used to manage SG tube degradation.

Specification 5.5.9, "Steam Generator (SG) Program," requires that a program be established and implemented to ensure that SG tube integrity is maintained. Pursuant to Specification 5.5.9, tube integrity is maintained when the SG performance criteria are met. There are three SG performance criteria: structural integrity, accident induced leakage, and operational LEAKAGE. The SG performance criteria are described in Specification 5.5.9. Meeting the SG performance criteria provides reasonable assurance of maintaining tube integrity at normal and accident conditions.

The processes used to meet the SG performance criteria are defined by the Steam Generator Program Guidelines (Ref. 1).

Wolf Creek - Unit 1 B 3.4.17-1 Revision 29

SG Tube Integrity B 3.4.17 BASES APPLICABLE The steam generator tube rupture (SGTR) accident is the limiting design SAFETY basis event for SG tubes and avoiding an SGTR is the basis for this ANALYSES Specification. The analysis of an SGTR event assumes a bounding primary to secondary LEAKAGE rate equal to the operational LEAKAGE rate limits in LCO 3.4.13, "RCS Operational LEAKAGE," plus the leakage rate associated with a double-ended rupture of a single tube. The accident analysis for an SGTR assumes the contaminated secondary fluid is released to the atmosphere via SG atmospheric relief valves and safety valves.

The analysis for design basis accidents and transients other than an SGTR assume the SG tubes retain their structural integrity (i.e., they are assumed not to rupture.) In these analyses, the steam discharge to the atmosphere is based on the total primary to secondary LEAKAGE from all SGs of 1 gallon per minute or is assumed to increase to 1 gallon per minute as a result of accident induced conditions. For accidents that do not involve fuel damage, the primary coolant activity level of DOSE EQUIVALENT 1-131 is assumed to be equal to the LCO 3.4.16, "RCS Specific Activity," limits. For accidents that assume fuel damage, the primary coolant activity is a function of the amount of activity released from the damaged fuel. The dose consequences of these events are within the limits of GDC 19 (Ref. 2), 10 CFR 100 (Ref. 3) or the NRC approved licensing basis (e.g., a small fraction of these limits).

Steam generator tube integrity satisfies Criterion 2 of 10 CFR 50.36(c)(2)(ii).

LCO The LCO requires that SG tube integrity be maintained. The LCO also requires that all SG tubes that satisfy the plugging criteria be plugged in accordance with the Steam Generator Program.

During a SG inspection, any inspected tube that satisfies the Steam Generator Program plugging criteria is removed from service by plugging.

If a tube was determined to satisfy the plugging criteria but was not plugged, the tube may still have tube integrity.

In the context of this Specification, a SG tube is defined as the entire length of the tube, including the tube wall, between the tube-to-tubesheet weld at the tube inlet and the tube-to-tubesheet weld at the tube outlet. A permanent alternate plugging criterion for the portion of the tube below 15.21 inches from the top of the tubesheet is specified in TS 5.5.9c.1.

(Ref. 7) The tube-to-tubesheet weld is not considered part of the tube.

Wolf Creek - Unit 1 B 3.4.17-2 Revision 58

SG Tube Integrity B 3.4.17 BASES LCO A SG tube has tube integrity when it satisfies the SG performance criteria.

(continued)

The SG performance criteria are defined in Specification 5.5.9, "Steam Generator Program," and describe acceptable SG tube performance. The Steam Generator Program also provides the evaluation process for determining conformance with the SG performance criteria.

There are three SG performance criteria: structural integrity, accident induced leakage, and operational LEAKAGE. Failure to meet any one of these criteria is considered failure to meet the LCO.

The structural integrity performance criterion provides a margin of safety against tube burst or collapse under normal and accident conditions, and ensures structural integrity of the SG tubes under all anticipated transients included in the design specification. Tube burst is defined as, "The gross structural failure of the tube wall. The condition typically corresponds to an unstable opening displacement (e.g., opening area increased in response to constant pressure) accompanied by ductile (plastic) tearing of the tube material at the ends of the degradation." Tube collapse is defined as, "For the load displacement curve for a given structure, collapse occurs at the top of the load versus displacement curve where the slope of the curve becomes zero." The structural integrity performance criterion provides guidance on assessing loads that have a significant effect on burst or collapse. In that context, the term "significant" is defined as "An accident loading condition other than differential pressure is considered significant when the addition of such loads in the assessment of the structural integrity performance criterion could cause a lower structural limit or limiting burst/collapse condition to be established." For tube integrity evaluations, except for circumferential degradation, axial thermal loads are classified as secondary loads. For circumferential degradation, the classification of axial thermal loads as primary or secondary loads will be evaluated on a case-by-case basis.

The division between primary and secondary classifications will be based on detailed analysis and/or testing.

Structural integrity requires that the primary membrane stress intensity in a tube not exceed the yield strength for all ASME Code,Section III, Service Level A (normal operating conditions) and Service Level B (upset or abnormal conditions) transients included in the design specification.

This includes safety factors and applicable design basis loads based on ASME Code,Section III, Subsection NB (Ref. 4) and Draft Regulatory Guide 1.121 (Ref. 5).

Wolf Creek - Unit 1 B 3.4.17-3 Revision 29

SG Tube Integrity B 3.4.17 BASES LCO (continued)

The accident induced leakage performance criterion ensures that the primary to secondary LEAKAGE caused by a design basis accident, other than a SGTR, is within the accident analysis assumptions. The accident analysis assumes that accident induced leakage does not exceed 1 gpm per SG. The accident induced leakage rate includes any primary to secondary LEAKAGE existing prior to the accident in addition to primary to secondary LEAKAGE induced during the accident.

The operational LEAKAGE performance criterion provides an observable indication of SG tube conditions during plant operation. The limit on operational LEAKAGE is contained in LCO 3.4.13, "RCS Operational LEAKAGE," and limits primary to secondary LEAKAGE through any one SG to 150 gallons per day. This limit is based on the assumption that a single crack leaking this amount would not propagate to an SGTR under the stress conditions of a LOCA or a main steam line break. If this amount of LEAKAGE is due to more than one crack, the cracks are very small, and the above assumption is conservative.

APPLICABILITY Steam generator tube integrity is challenged when the pressure differential across the tubes is large. Large differential pressures across SG tubes can only be experienced in MODE 1, 2, 3, or 4.

RCS conditions are far less challenging in MODES 5 and 6 than during MODES 1, 2, 3, and 4. In MODES 5 and 6, primary to secondary differential pressure is low, resulting in lower stresses and reduced potential for LEAKAGE.

ACTIONS The ACTIONS are modified by a Note clarifying that the Conditions may be entered independently for each SG tube. This is acceptable because the Required Actions provide appropriate compensatory actions for each affected SG tube. Complying with the Required Actions may allow for continued operation, and subsequent affected SG tubes are governed by subsequent Condition entry and application of associated Required Actions.

A.1 and A.2 Condition A applies if it is discovered that one or more SG tubes examined in an inservice inspection satisfy the tube plugging criteria but were not plugged in accordance with the Steam Generator Program as required by SR 3.4.17.2. An evaluation of SG tube integrity of the affected tube(s) must be made. Steam generator tube integrity is Wolf Creek - Unit 1 B 3.4.17-4 Revision 57

SG Tube Integrity B 3.4.17 BASES ACTIONS A.1 and A.2 (continued) based on meeting the SG performance criteria described in the Steam Generator Program. The SG plugging criteria define limits on SG tube degradation that allow for flaw growth between inspections while still providing assurance that the SG performance criteria will continue to be met. In order to determine if a SG tube that should have been plugged has tube integrity, an evaluation must be completed that demonstrates that the SG performance criteria will continue to be met until the next refueling outage or SG tube inspection. The tube integrity determination is based on the estimated condition of the tube at the time the situation is discovered and the estimated growth of the degradation prior to the next SG tube inspection. If it is determined that tube integrity is not being maintained, Condition B applies.

A Completion Time of 7 days is sufficient to complete the evaluation while minimizing the risk of plant operation with a SG tube that may not have tube integrity.

If the evaluation determines that the affected tube(s) have tube integrity, Required Action A.2 allows plant operation to continue until the next refueling outage or SG inspection provided the inspection interval continues to be supported by an operational assessment that reflects the affected tubes. However, the affected tube(s) must be plugged prior to entering MODE 4 following the next refueling outage or SG inspection.

This Completion Time is acceptable since operation until the next inspection is supported by the operational assessment.

B.1 and B.2 If the Required Actions and associated Completion Times of Condition A are not met or if SG tube integrity is not being maintained, the reactor must be brought to MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

The allowed Completion Times are reasonable, based on operating experience, to reach the desired plant conditions from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE SR 3.4.17.1 REQUIREMENTS During shutdown periods the SGs are inspected as required by this SR and the Steam Generator Program. NEI 97-06, Steam Generator Program Guidelines (Ref. 1), and its referenced EPRI Guidelines, establish the content of the Steam Generator Program. Use of the Steam Generator Program ensures that the inspection is appropriate and consistent with accepted industry practices.

Wolf Creek - Unit 1 B 3.4.17-5 Revision 57

SG Tube Integrity B 3.4.17 BASES SURVEILLANCE SR 3.4.17.1 (continued)

REQUIREMENTS During SG inspections a condition monitoring assessment of the SG tubes is performed. The condition monitoring assessment determines the "as found" condition of the SG tubes. The purpose of the condition monitoring assessment is to ensure that the SG performance criteria have been met for the previous operating period.

The Steam Generator Program determines the scope of the inspection and the methods used to determine whether the tubes contain flaws satisfying the tube plugging criteria. Inspection scope (i.e., which tubes or areas of tubing within the SG are to be inspected) is a function of existing and potential degradation locations. The Steam Generator Program also specifies the inspection methods to be used to find potential degradation.

Inspection methods are a function of degradation morphology, non-destructive examination (NDE) technique capabilities, and inspection locations.

The Steam Generator Program defines the Frequency of SR 3.4.17.1.

The Frequency is determined by the operational assessment and other limits in the SG examination guidelines (Ref. 6). The Steam Generator Program uses information on existing degradations and growth rates to determine an inspection Frequency that provides reasonable assurance that the tubing will meet the SG performance criteria at the next scheduled inspection. In addition, Specification 5.5.9 contains prescriptive requirements concerning inspection intervals to provide added assurance that the SG performance criteria will be met between scheduled inspections. If crack indications are found in any SG tube, the maximum inspection interval for all affect and potentially affected SGs is restricted by Specification 5.5.9 until subsequent inspections support extending the inspection interval.

SR 3.4.17.2 During a SG inspection, any inspected tube that satisfies the Steam Generator Program plugging criteria is removed from service by plugging.

The tube plugging criteria delineated in Specification 5.5.9 are intended to ensure that tubes accepted for continued service satisfy the SG performance criteria with allowance for error in the flaw size measurement and for future flaw growth. In addition, the tube plugging criteria, in conjunction with other elements of the Steam Generator Program, ensure that the SG performance criteria will continue to be met until the next inspection of the subject tube(s). Reference 1 provides guidance for performing operational assessments to verify that the tubes remaining in service will continue to meet the SG performance criteria.

Wolf Creek - Unit 1 B 3.4.17-6 Revision 57

SG Tube Integrity B 3.4.17 BASES SURVEILLANCE SR 3.4.17.2 (continued)

REQUIREMENTS The Frequency of prior to entering MODE 4 following a SG inspection ensures that the Surveillance has been completed and all tubes meeting the plugging criteria are plugged prior to subjecting the SG tubes to significant primary to secondary pressure differential.

REFERENCES

1.

NEI 97-06, "Steam Generator Program Guidelines."

2.

10 CFR 50 Appendix A, GDC 19.

3.

10 CFR 100.

4.

ASME Boiler and Pressure Vessel Code,Section III, Subsection NB.

5.

Draft Regulatory Guide 1.121, "Basis for Plugging Degraded Steam Generator Tubes," August 1976.

6.

EPRI, "Pressurized Water Reactor Steam Generator Examination Guidelines."

7.

License Amendment No. 201, December 11, 2012.

Wolf Creek - Unit 1 B 3.4.17-7 Revision 58

Containment Spray and Cooling Systems B 3.6.6 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.6.8 With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections. This SR ensures that each spray nozzle is unobstructed and provides assurance that spray coverage of the containment during an accident is not degraded. Due to the passive design of the nozzle, a confirmation of OPERABILITY following maintenance activities that can result in obstruction of spray nozzle flow is considered adequate to detect obstruction of the nozzles. Confirmation that the spray nozzles are unobstructed may be obtained by utilizing foreign material exclusion (FME) controls during maintenance, a visual inspection of the affected portions of the system, or by an air or smoke flow test following maintenance involving opening portions of the system downstream of the containment isolation valves or draining of the filled portions of the system inside containment. Maintenance that could result in nozzle blockage is generally a result of a loss of foreign material control or a flow of borated water through a nozzle. Should either of these events occur, a supervisory evaluation will be required to determine whether nozzle blockage is a possible result of the event. For the loss of FME event, an inspection or flush of the affected portions of the system should be adequate to confirm that the spray nozzles are unobstructed since water flow would be required to transport any debris to the spray nozzles. An air flow or smoke test may not be appropriate for a loss of FME event but may be appropriate for the case where borated water inadvertently flows through the nozzles.

REFERENCES

1.

10 CFR 50, Appendix A, GDC 38, GDC 39, GDC 40, GDC 41. GDC 42, and GDC 43, and GDC 50.

2.

10 CFR 50, Appendix K.

3.

USAR, Section 6.2.1.

4.

USAR, Section 6.2.2.

5.

ASME Code for Operation and Maintenance of Nuclear Power Plants.

6.

Performance Improvement Request 2002-0945.

Wolf Creek - Unit 1 B 3.6.6-9 Revision 58

AFW System B 3.7.5 BASES APPLICABLE

a.

Feedwater Line Break (FWLB);

SAFETY ANALYSES (continued)

b.

Main Steam Line Break; and

c.

Loss of MFW.

In addition, the minimum available AFW flow and system characteristics are considerations in the analysis of a small break loss of coolant accident (LOCA). The AFW System design is such that it can perform its function following an FWLB between the MFW isolation valves and containment, combined with a loss of offsite power following turbine trip, and a single active failure of one motor driven AFW pump. This results in minimum assumed flow to the intact steam generators. One motor driven AFW pump would deliver to the broken MFW header at a flow rate throttled by the motor operated "smart" discharge valve until the problem was detected, and flow terminated by the operator. Sufficient flow would be delivered to the intact steam generator by the residual flow from the affected pump plus the turbine driven AFW pump.

The BOP ESFAS automatically actuates the AFW turbine driven pump when required to ensure an adequate feedwater supply to the steam generators during loss of power. DC power operated valves are provided for each AFW line to control the AFW flow to each steam generator.

The AFW System satisfies the requirements of Criterion 3 of 10 CFR 50.36(c)(2)(ii).

LCO This LCO provides assurance that the AFW System will perform its design safety function to mitigate the consequences of accidents that could result in overpressurization of the reactor coolant pressure boundary. Three independent AFW pumps in three diverse trains are required to be OPERABLE to ensure the availability of decay heat removal capability for all events accompanied by a loss of offsite power and a single failure.

This is accomplished by powering two of the pumps from independent emergency buses. The third AFW pump is powered by a different means, a steam driven turbine supplied with steam from a source that is not isolated by closure of the MSIVs.

The AFW System is configured into three trains. The AFW System is considered OPERABLE when the components and flow paths required to provide redundant AFW flow to the steam generators are OPERABLE.

This requires that the two motor driven AFW pumps be OPERABLE in two diverse paths, each capable of automatically transferring the suction from Wolf Creek - Unit 1 B 3.7.5-3 Revision 0

AFW System B 3.7.5 BASES LCO (continued) the CST to an ESW supply and supplying AFW to two steam generators.

The turbine driven AFW pump is required to be OPERABLE with redundant steam supplies from each of two main steam lines upstream of the MSIVs, and shall be capable of automatically transferring the suction from the CST to an ESW supply and supplying AFW to any of the steam generators. The piping, valves, instrumentation, and controls in the required flow paths also are required to be OPERABLE. The inoperability of a single supply line or a single suction isolation valve from an ESW train to the turbine driven AFW pump causes a loss of redundancy in ESW supply to the pump but does not render the turbine driven AFW train inoperable. The supply line begins at the point where the ESW piping branches into two lines, one supplying the motor driven AFW pump and one supplying the turbine driven AFW pump, and ends at the suction of the turbine driven AFW pump (Ref. 3). Therefore, with one ESW train inoperable, the associated motor driven AFW train is considered inoperable; and one turbine driven AFW pump supply line is considered inoperable. However, the turbine driven AFW train is OPERABLE based on the remaining OPERABLE ESW supply line.

In order for the turbine driven AFW pump and motor driven AFW pumps to be OPERABLE while the AFW System is in automatic control or above 10% RTP, the discharge flow control valves shall be in the full open position, except when the motor driven AFW pumps discharge flow control valves are automatically throttled in response to actual AFW flow (Ref. 5). When < 10% RTP, the turbine driven AFW pump and motor driven AFW pumps remain OPERABLE with the discharge flow control valves throttled as needed to maintain steam generator levels.

The standby lineup for the turbine driven AFW steam supply lines is when the main steam supply valves, ABHV0005 and ABHV0006, are closed and OPERABLE and the warmup valves, ABHV0048 and ABHV0049, are open and OPERABLE. With a main steam supply valve and its associated warmup valve closed, the turbine driven AFW steam supply line is inoperable. The turbine driven AFW pump is inoperable when restoring a steam supply line to service if both the main steam supply valve and its associated warmup valve were closed. The turbine driven AFW pump is inoperable until the rate of condensation being drained by FCLVO010 is low enough that the valve will remain closed for at least five minutes.

The nitrogen accumulator tanks supplying the turbine driven AFW pump control valves and the steam generator atmospheric relief valves ensure an eight hour supply for the pump and valves.

Although the AFW System may be used in MODE 4 to remove decay heat, the LCO does not require the AFW System to be OPERABLE in MODE 4 since the RHR System is available for decay heat removal.

Wolf Creek - Unit 1 B 3.7.5-4 Revision 60

CREVS B 3.7.10 BASES APPLICABILITY In MODES 1, 2, 3, and 4, and during movement of irradiated fuel assemblies, the CREVS must be OPERABLE to ensure that the CRE will remain habitable during and following a DBA.

During movement of irradiated fuel assemblies, the CREVS must be OPERABLE to cope with the release from a design basis fuel handling accident.

ACTIONS A.1 When one CREVS train is inoperable for reasons other than an inoperable CRE or CBE boundary, action must be taken to restore OPERABLE status within 7 days. In this Condition, the remaining OPERABLE CREVS train is adequate to perform the CRE occupant protection function. However, the overall reliability is reduced because a failure in the OPERABLE CREVS train could result in loss of CREVS function. The 7 day Completion Time is based on the low probability of a DBA occurring during this time period, and ability of the remaining train to provide the required capability.

B.1, B.2. and B.3 If the unfiltered inleakage of potentially contaminated air past a CRE or CBE boundary credited in the accident analysis and into the CRE can result in CRE occupant radiological dose greater than the calculated dose of the licensing basis analyses of DBA consequences (allowed to be up to 5 rem whole body or its equivalent to any part of the body), or inadequate protection of CRE occupants from hazardous chemicals or smoke, the CRE or CBE boundary is inoperable. Actions must be taken to restore the CRE or CBE boundary to OPERABLE status within 90 days.

During the period that the CRE or CBE boundary is considered inoperable, action must be initiated to implement mitigating actions to lessen the effect on CRE occupants from the potential hazards of a radiological or chemical event or a challenge from smoke. Actions must be taken within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to verify that in the event of a DBA, the mitigating actions will ensure that CRE occupant radiological exposures will not exceed the calculated dose of the licensing basis analyses of DBA consequences, and that CRE occupants are protected from hazardous Wolf Creek - Unit 1 B 3.7.10-5 Revision 57

CREVS B 3.7.10 BASES ACTIONS B.1, B.2, and B.3 (continued) chemicals and smoke. These mitigating actions (i.e., actions that are taken to offset the consequences of the inoperable CBP boundary) should be preplanned for implementation upon entry into the condition, regardless of whether entry is intentional or unintentional.

The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time is reasonable based on the low probability of a DBA occurring during this time period, and the use of mitigating actions. The 90 day Completion Time is reasonable based on the determination that the mitigating actions will ensure protection of CRE occupants within analyzed limits while limiting the probability that CRE occupants will have to implement protective measures that may adversely affect their ability to control the reactor and maintain it in a safe shutdown condition in the event of a DBA. In addition, the 90 day Completion Time is a reasonable time to diagnose, plan and possibly repair, and test most conditions adversely affecting the CRE or CBE boundary.

C.1 and C.2 In MODE 1, 2, 3, or 4, if the inoperable CREVS train or the inoperable CRE or CBE boundary cannot be restored to OPERABLE status within the required Completion Time, the unit must be placed in a MODE that minimizes accident risk. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.

D.1. D.2.1. and D.2.2 During movement of irradiated fuel assemblies, if the inoperable CREVS train cannot be restored to OPERABLE status within the required Completion Time, action must be taken to immediately place the OPERABLE CREVS train in the CRVIS mode. This action ensures that the remaining train is OPERABLE, that no failures preventing automatic actuation will occur, and that any active failure would be readily detected.

Wolf Creek - Unit 1 B 3.7.10-6 Revision 57

CREVS B 3.7.10 BASES ACTIONS D.1. D.2.1, and D.2.2 (continued)

An alternative to Required Action D.1 is to immediately suspend activities that could result in a release of radioactivity that might require isolation of the CRE. This places the unit in a condition that minimizes the accident risk. This does not preclude the movement of fuel to a safe position.

E.1 and E.2 During movement of irradiated fuel assemblies, with two CREVS trains inoperable or with one or more CREVS trains inoperable due to an inoperable CRE or CBE boundary, action must be taken immediately to suspend activities that could result in a release of radioactivity that might require isolation of the CRE. This places the unit in a condition that minimizes the accident risk. This does not preclude the movement of fuel to a safe position.

F.1 If both CREVS trains are inoperable in MODE 1, 2, 3, or 4, for reasons other than an inoperable CRE and CBE boundary (i.e., Condition B), the CREVS may not be capable of performing the intended function and the unit is in a condition outside the accident analyses. Therefore, LCO 3.0.3 must be entered immediately.

SURVEILLANCE SR 3.7.10.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly. As the environment and normal operating conditions on this system are not too severe, testing each train once every month, by initiating from the control room, flow through the HEPA filters and charcoal adsorber of both the filtration and pressurization systems, provides an adequate check of this system. Monthly heater operations dry out any moisture accumulated in the charcoal from humidity in the ambient air.

Each pressurization system train must be operated for -a 10 continuous hours with the heaters energized. Each filtration system train need only be operated for > 15 minutes to demonstrate the function of the system.

The 31 day Frequency is based on the reliability of the equipment and the two train redundancy.

Wolf Creek - Unit 1 B 3.7.10-7 Revision 57

CREVS B 3.7.10 BASES SURVEILLANCE SR 3.7.10.2 REQUIREMENTS (continued)

This SR verifies that the required CREVS testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The CREVS filter tests use the procedure guidance in Regulatory Guide 1.52, Rev. 2 (Ref. 3) in accordance with the VFTP. The VFTP includes testing the performance of the HEPA filter, charcoal absorber efficiency, minimum flow rate, and the physical properties of the activated charcoal.

Specific test Frequencies and additional information are discussed in detail in the VFTP.

SR 3.7.10.3 This SR verifies that each CREVS train starts and operates on an actual or simulated CRVIS. The actuation signal includes Control Room Ventilation or High Gaseous Radioactivity. The CREVS train automatically switches on an actual or simulated CRVIS into a CRVIS mode of operation with flow through the HEPA filters and charcoal adsorber banks. The Frequency of 18 months is consistent with a typical operating cycle. Operating experience has shown that these components usually pass the Surveillance when performed at the 18 month Frequency. Therefore, the Frequency is acceptable from a reliability standpoint.

SR 3.7.10.4 This SR verifies the OPERABILITY of the CRE and CBE boundaries credited in the accident analysis by testing for unfiltered air inleakage past the credited envelope boundaries and into the CRE. The details of the testing are specified in the Control Room Envelope Habitability Program.

The CRE is considered habitable when the radiological dose to CRE occupants calculated in the licensing basis analyses of DBA consequences is no more than 5 rem whole body or its equivalent to any part of the body and the CRE occupants are protected from hazardous chemicals and smoke. For WCGS, there is no CREVS actuation for hazardous chemical releases or smoke and there are no Surveillance Requirements that verify OPERABILITY for hazardous chemicals or smoke. This SR verifies that the unfiltered air inleakage into the CRE and CBE boundaries is no greater than the flow rate assumed in the licensing basis analyses of DBA consequences. When unfiltered air inleakage is greater than the assumed flow rate, Condition B must be entered.

Required Action B.3 allows time to restore the CRE or CBE Wolf Creek - Unit I B 3.7.10-8 Revision 41

CRACS B 3.7.11 B 3.7 PLANT SYSTEMS B 3.7.11 Control Room Air Conditioning System (CRACS)

BASES BACKGROUND The CRACS provides temperature control for the control room.

The CRACS consists of two independent and redundant trains that provide cooling of recirculated control room air. Each train consists of a high efficiency prefilter, self-contained refrigeration system, centrifugal fans, instrumentation, and controls to provide for control room temperature control. The CRACS is a subsystem providing air temperature control for the control room.

The CRACS is an emergency system, which also operates during normal unit operations. A single train will provide the required temperature control to maintain the control room _< 840F. The CRACS operation in maintaining the control room temperature is discussed in the USAR, Section 9.4.1 (Ref. 1).

APPLICABLE The design basis of the CRACS is to maintain the control room SAFETY ANALYSES temperature for 30 days of continuous occupancy.

The CRACS components are arranged in redundant, safety related trains.

During normal or emergency operations, the CRACS maintains the temperature _ 840F. A single active failure of a component of the CRACS, with a loss of offsite power, does not impair the ability of the system to perform its design function. Redundant detectors and controls are provided for control room temperature control. The CRACS is designed in accordance with Seismic Category I requirements. The CRACS is capable of removing sensible and latent heat loads from the control room, which include consideration of equipment heat loads and personnel occupancy requirements, to ensure equipment OPERABILITY.

The CRACS satisfies Criterion 3 of 10 CFR 50.36(c)(2)(ii).

LCO Two independent and redundant trains of the CRACS are required to be OPERABLE to ensure that at least one is available, assuming a single failure disabling the other train. Total system failure could result in the equipment operating temperature exceeding limits in the event of an accident.

Wolf Creek - Unit 1 B 3.7.11-1 Revision 0

CRACS B 3.7.11 BASES LCO The CRACS is considered to be OPERABLE when the individual (continued) components necessary to maintain the control room temperature are OPERABLE in both trains. These components include the refrigeration compressors, heat exchangers, cooling coils, fans, and associated temperature control instrumentation. In addition, the CRACS must be OPERABLE to the extent that air circulation can be maintained. Isolation or breach of the CRACS air flow path also can render the CREVS flowpath inoperable. In these situations, LCO 3.7.10 would also be applicable.

APPLICABILITY In MODES 1, 2, 3, 4, 5, and 6, and during movement of irradiated fuel assemblies, the CRACS must be OPERABLE to ensure that the control room temperature will not exceed equipment operational requirements.

ACTIONS A.1 With one CRACS train inoperable, action must be taken to restore OPERABLE status within 30 days. In this Condition, the remaining OPERABLE CRACS train is adequate to maintain the control room temperature within limits. However, the overall reliability is reduced because a single failure in the OPERABLE CRACS train could result in loss of CRACS function. The 30 day Completion Time is based on the low probability of an event requiring control room isolation and the consideration that the remaining train can provide the required protection.

B.1 and B.2 In MODE 1, 2, 3, or 4, if the inoperable CRACS train cannot be restored to OPERABLE status within the required Completion Time, the unit must be placed in a MODE that minimizes the risk. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.

C.1, C.2.1, and C.2.2 In MODE 5 or 6, or during movement of irradiated fuel, if the inoperable CRACS train cannot be restored to OPERABLE status within the required Completion Time, the OPERABLE CRACS train must be placed in Wolf Creek - Unit 1 B 3.7.11-2 Revision 57

CRACS B 3.7.11 BASES ACTIONS C.1, C.2.1, and C.2.2 (continued) operation immediately. This action ensures that the remaining train is OPERABLE, that no failures preventing automatic actuation will occur, and that active failures will be readily detected.

An alternative to Required Action C.1 is to immediately suspend activities that present a potential for releasing radioactivity that might require isolation of the control room. This places the unit in a condition that minimizes accident risk. This does not preclude the movement of fuel to a safe position.

D.1 and D.2 In MODE 5 or 6, or during movement of irradiated fuel assemblies, with two CRACS trains inoperable, action must be taken immediately to suspend activities that could result in a release of radioactivity that might require isolation of the control room. This places the unit in a condition that minimizes risk. This does not preclude the movement of fuel to a safe position.

E.1 If both CRACS trains are inoperable in MODE 1, 2, 3, or 4, the CRACS may not be capable of performing its intended function. Therefore, LCO 3.0.3 must be entered immediately.

SURVEILLANCE SR 3.7.11.1 REQUIREMENTS This SR verifies that the heat removal capability of the CRACS air conditioning units is adequate to remove the heat load assumed in the control room during design basis accidents. This SR consists of verifying the heat removal capability of the condenser heat exchanger (either through performance testing or inspection), ensuring the proper operation of major components in the refrigeration cycle and verification of unit air Wolf Creek - Unit 1 B 3.7.11-3 Revision 57

CRACS B 3.7.11 BASES SURVEILLANCE SR 3.7.11.1 (continued)

REQUIREMENTS flow capacity. The 18 month Frequency is appropriate since significant degradation of the CRACS is slow and is not expected over this time period.

REFERENCES

1.

USAR, Section 9.4.1.

Wolf Creek - Unit 1 B 3.7.11-4 Revision 0

EES B 3.7.13 BASES LCO

a.

Fan is OPERABLE; (continued)

b.

HEPA filter and charcoal absorber are not excessively restricting flow, and are capable of performing their filtration function; and

c.

Heater, ductwork, and dampers are OPERABLE, and air circulation I can be maintained.

The LCO is modified by a Note allowing the auxiliary or 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 auxiliary building or fuel building isolation is indicated.

APPLICABILITY In MODE 1, 2, 3, or 4, the Emergency Exhaust System is required to be OPERABLE in the SIS mode of operation to provide fission product removal associated with potential radioactivity leaks during the post-LOCA recirculation phase of ECCS operation.

In MODE 5 or 6, when not moving irradiated fuel the Emergency Exhaust System is not required to be OPERABLE since the ECCS is not required to be OPERABLE.

During movement of irradiated fuel in the fuel handling area, the Emergency Exhaust System is required to be OPERABLE to support the FBVIS mode of operation to alleviate the consequences of a fuel handling accident.

The Applicability is modified by a Note. The Note clarifies the Applicability for the two safety related modes of operation of the Emergency Exhaust System, i.e., the Safety Injection Signal (SIS) mode and the Fuel Building Ventilation Isolation Signal (FBVIS) mode. The SIS mode which aligns the system to the auxiliary building is applicable when the ECCS is required to be OPERABLE. In the FBVIS mode the system is aligned to the fuel building. This mode is applicable while handling irradiated fuel in the fuel building.

Wolf Creek - Unit 1 B 3.7.13-3 Revision 42

EES B 3.7.13 BASES ACTIONS LCO 3.0.3 is not applicable while in MODE 5 or 6. However, since irradiated fuel assembly movement can occur in MODE 1, 2, 3, or 4, the ACTIONS have been modified by a Note stating that LCO 3.0.3 is not applicable. If moving irradiated fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operations. Entering LCO 3.0.3, while in MODE 1, 2, 3, or 4 would require the unit to be shutdown unnecessarily.

A.1 With one Emergency Exhaust System train inoperable, action must be taken to restore OPERABLE status within 7 days. During this period, the remaining OPERABLE train is adequate to perform the Emergency Exhaust System function. The 7 day Completion Time is based on the risk from an event occurring requiring the inoperable Emergency Exhaust System train, and the remaining Emergency Exhaust System train providing the required protection.

B.1 If the auxiliary building boundary is inoperable such that a train of the Emergency Exhaust System operating in the SIS mode cannot establish or maintain the required negative pressure, action must be taken to restore an OPERABLE auxiliary building boundary within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time is reasonable based on the low probability of a DBA occurring during this time period and the availability of the Emergency Exhaust System to provide a filtered release (albeit with potential for some unfiltered auxiliary building leakage).

C.1 and C.2 In MODE 1, 2, 3, or 4, when Required Action A.1 or B.1 cannot be completed within the associated Completion Time or when both Emergency Exhaust System trains are inoperable for reasons other than an inoperable auxiliary building boundary (i.e., Condition B), the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.

Wolf Creek - Unit 1 B 3.7.13-4 Revision 57

EES B 3.7.13 BASES ACTIONS D.1 and D.2 When Required Action A.1 cannot be completed within the associated Completion Time during movement of irradiated fuel assemblies in the fuel building, the OPERABLE Emergency Exhaust System train must be started in the FBVIS mode immediately or fuel movement suspended.

This action ensures that the remaining train is OPERABLE, that no undetected failures preventing system operation will occur, and that any active failure will be readily detected.

If the system is not placed in operation, this action requires suspension of fuel movement, which precludes a fuel handling accident. This does not preclude the movement of fuel assemblies to a safe position.

E.1 If the fuel building boundary is inoperable such that a train of the Emergency Exhaust System operating in the FBVIS mode cannot establish or maintain the required negative pressure, action must be taken to restore an OPERABLE fuel building boundary within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time is reasonable based on the low probability of a DBA occurring during this time period and the availability of the Emergency Exhaust System to provide a filtered release (albeit with potential for some unfiltered fuel building leakage).

F.1 During movement of irradiated fuel assemblies in the fuel building, when two trains of the Emergency Exhaust System are inoperable for reasons other than an inoperable fuel building boundary (i.e., Condition E), or if Required Action E.1 cannot be completed within the associated Completion Time action must be taken to place the unit in a condition in which the LCO does not apply. Action must be taken immediately to suspend movement of irradiated fuel assemblies in the fuel building. This does not preclude the movement of fuel to a safe position.

SURVEILLANCE SR 3.7.13.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly. As the environmental and normal operating conditions on this system are not severe, testing each train once every month, by initiating from the control room flow through the HEPA filters and charcoal adsorbers, provides an adequate check on this system.

Wolf Creek - Unit 1 B 3.7.13-5 Revision 57

EES B 3.7.13 BASES SURVEILLANCE SR 3.7.13.1 (continued)

REQUIREMENTS Monthly heater operation dries out any moisture accumulated in the charcoal from humidity in the ambient air. Systems with heaters must be operated for 2 10 continuous hours with the heaters energized. Operating heaters would not necessarily have the heating elements energized continuously for 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months , but will cycle depending on the temperature.

The 31 day Frequency is based on the known reliability of the equipment and the two train redundancy available. This SR can be satisfied with the Emergency Exhaust System in the SIS or FBVIS lineup during testing.

SR 3.7.13.2 This SR verifies that the required Emergency Exhaust System filter testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The Emergency Exhaust System filter tests are based on the guidance in References 6 and 7 in accordance with the VFTP. The VFTP includes testing HEPA filter performance, charcoal absorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal. Specific test frequencies and additional information are discussed in detail in the VFTP.

SR 3.7.13.3 This SR verifies that each Emergency Exhaust System train starts and operates on an actual or simulated actuation signal. The 18 month Frequency is consistent with References 6 and 7. Proper completion of this SR requires testing the system in both the SIS (auxiliary building exhaust) and the FBVIS (fuel building exhaust) modes of operation.

During emergency operations the Emergency Exhaust System will automatically start in either the SIS or FBVIS lineup depending on the initiating signal. In the SIS lineup, the fans operate with dampers aligned to exhaust from the auxiliary building and prevent unfiltered leakage. In this SIS lineup, each train is capable of maintaining the auxiliary building at a negative pressure at least 0.25 inches water gauge relative to the outside atmosphere. In the FBVIS lineup, which is initiated upon detection of high radioactivity by the fuel building exhaust gaseous radioactivity monitors, the fans operate with the dampers aligned to exhaust from the fuel building to prevent unfiltered leakage. In the FBVIS lineup, each train is capable of maintaining the fuel building at a negative pressure at least 0.25 inches water gauge relative to the outside atmosphere. Normal exhaust air from the fuel building is continuously monitored by radiation detectors. One detector output will automatically align the Emergency Exhaust System in the FBVIS mode of operation.

Wolf Creek - Unit I B 3.7.13-6 Revision 57 1

EES B 3.7.13 BASES SURVEILLANCE SR 3.7.13.3 (continued)

REQUIREMENTS This surveillance requirement demonstrates that each Emergency Exhaust System unit can be automatically started and properly configured to the FBVIS or SIS alignment, as applicable, upon receipt of an actual or simulated SIS signal and an FBVIS signal. It is not required that each Emergency Exhaust System unit be started from both actuation signals during the same surveillance test provided each actuation signal is tested independently within the 18 month test frequency.

SR 3.7.13.4 This SR verifies the integrity of the auxiliary building enclosure. The ability of the auxiliary building to maintain negative pressure with respect to potentially uncontaminated adjacent areas is periodically tested to verify proper function of the Emergency Exhaust System. During the SIS mode of operation, the Emergency Exhaust System is designed to maintain a slight negative pressure in the auxiliary building, to prevent unfiltered leakage. The Emergency Exhaust System is designed to maintain a negative pressure > 0.25 inches water gauge with respect to atmospheric pressure at a flow rate specified in the VFTP. The Frequency of 18 months is consistent with the guidance provided in NUREG-0800, Section 6.5.1 (Ref.8).

An 18 month Frequency (on a STAGGERED TEST BASIS) is consistent with Reference 9.

SR 3.7.13.5 This SR verifies the integrity of the fuel building enclosure. The ability of the fuel building to maintain negative pressure with respect to potentially uncontaminated adjacent areas is periodically tested to verify proper function of the Emergency Exhaust System. During the FBVIS mode of operation, the Emergency Exhaust System is designed to maintain a slight negative pressure in the fuel building, to prevent unfiltered leakage.

The Emergency Exhaust System is designed to maintain a negative pressure > 0.25 inches water gauge with respect to atmospheric pressure at a flow rate specified in the VFTP. The Frequency of 18 months is consistent with the guidance provided in NUREG-0800, Section 6.5.1 (Ref.8).

An 18 month Frequency (on a STAGGERED TEST BASIS) is consistent with Reference 9.

Wolf Creek - Unit 1 B 3.7.13-7 Revision 57 1

EES B 3.7.13 BASES REFERENCES

1.

USAR, Section 6.5.1.

2.

USAR, Section 9.4.2 and 9.4.3.

3.

USAR, Section 15.7.4.

4.

Regulatory Guide 1.25, Rev. 0 (Safety Guide 25).

5.

10 CFR 100.

6.

ASTM D 3803-1989.

7.

ANSI N510-1980.

8.

NUREG-0800, Section 6.5.1, Rev. 2, July 1981.

9.

Regulatory Guide 1.52 (Rev. 2).

Wolf Creek - Unit 1 B 3.7.13-8 Revision 1

AC Sources - Operating B 3.8.1 BASES ACTIONS A.1 To ensure a highly reliable power source remains with one offsite circuit inoperable, it is necessary to verify the OPERABILITY of the remaining required offsite circuit on a more frequent basis. Since the Required Action only specifies "perform," a failure of SR 3.8.1.1 acceptance criteria does not result in a Required Action not met. However, if the second required circuit fails SR 3.8.1.1, the second offsite circuit is inoperable, and Condition D, for two offsite circuits inoperable, is entered.

A.2 Required Action A.2, which only applies if the train cannot be powered from an offsite source, is intended to provide assurance that an event coincident with a single failure of the associated DG will not result in a complete loss of safety function of critical redundant required features.

These redundant required features are those that are assumed to function to mitigate an accident, coincident with a loss of offsite power, in the safety analyses, such as the Emergency Core Cooling System and Auxiliary Feedwater System. These redundant features do not include monitoring requirements, such as Post Accident Monitoring and Remote Shutdown. These features are powered from the redundant AC electrical power train. This includes motor driven auxiliary feedwater pumps and the turbine driven auxiliary feedwater pump which must be available for mitigation of a feedwater line break. Single train systems, other than the turbine driven auxiliary feedwater pump, are not included in this Condition.

A Note is added to this Required Action stating that in MODES 1, 2, and 3, the turbine driven auxiliary feedwater pump is considered a required redundant feature. The reason for the Note is to confirm the OPERABILITY of the turbine driven auxiliary feedwater pump in this Condition, since the remaining OPERABLE motor driven auxiliary feedwater pump is not by itself capable of providing 100% of the auxiliary feedwater flow assumed in the safety analysis.

The Completion Time for Required Action A.2 is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This Completion Time also allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." In this Required Action, the Completion Time only begins on discovery that both:

a.

The train has no offsite power supplying its loads; and Wolf Creek - Unit 1 B 3.8.1-5 Revision 59

AC Sources - Operating B 3.8.1 BASES ACTIONS A.2 (continued)

b.

A required feature on the other train is inoperable and not in the safeguards position.

If at any time during the existence of Condition A (one offsite circuit inoperable) a redundant required feature subsequently becomes inoperable, this Completion Time begins to be tracked.

Discovering no offsite power to one train of the onsite Class 1 E Electrical Power Distribution System coincident with one or more inoperable required support or supported features, or both, that are associated with the other train that has offsite power, results in starting the Completion Times for the Required Action. Twenty-four hours is acceptable because it minimizes risk while allowing time for restoration before subjecting the unit to transients associated with shutdown.

The remaining OPERABLE offsite circuit and DGs are adequate to supply electrical power to Train A and Train B of the onsite Class 1 E Distribution System. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time takes into account the component OPERABILITY of the redundant counterpart to the inoperable required feature. Additionally, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

A.3 According to Regulatory Guide 1.93 (Ref. 6), operation may continue in Condition A for a period that should not exceed 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . With one offsite circuit inoperable, the reliability of the offsite system is degraded, and the potential for a loss of offsite power is increased, with attendant potential for a challenge to the unit safety systems. In this Condition, however, the remaining OPERABLE offsite circuit and DGs are adequate to supply electrical power to the onsite Class 1 E Distribution System.

The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

The second Completion Time for Required Action A.3 establishes a limit on the maximum time allowed for any combination of required AC power sources to be inoperable during any single contiguous occurrence of failing to meet the LCO. If Condition A is entered while, for instance, a DG is inoperable and that DG is subsequently returned OPERABLE, the LCO may already have been not met for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . This could lead to a Wolf Creek - Unit 1 B 3.8.1-6 Revision 25

AC Sources - Operating B 3.8.1 BASES ACTIONS F.1 (continued)

According to Reference 6, with both DGs inoperable, operation may continue for a period that should not exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

G.A and G.2 Required Action G.A provides assurance that the appropriate Action is entered for the affected DG and offsite circuit if its associated LSELS becomes inoperable. An LSELS failure results in the inability of the EDG to start upon a loss of ESF bus voltage or degraded voltage condition.

Additionally, LSELS trips the ESF bus normal and alternate feeder supplies and trips non-essential loads. A sequencer failure results in the inability to start all or part of the safety loads powered from the associated ESF bus and thus when an LSELS is inoperable it is appropriate to immediately enter the Conditions for an inoperable DG and offsite circuit.

Because an inoperable LSELS affects all or part of the safety loads, an immediate Completion Time is appropriate.

The LSELS is an essential support system to both the offsite circuit and the DG associated with a given ESF bus. Furthermore, the sequencer is on the primary success path for most major AC electrically powered safety systems powered from the associated ESF bus. Therefore, loss of an ESF bus sequencer affects every major ESF system in the division. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Completion Time of Required Action G.2 provides a period of time to correct the problem commensurate with the importance of maintaining sequencer OPERABILITY. This time period also ensures that the probability of an accident (requiring sequencer OPERABILITY) occurring during periods when the sequencer is inoperable is minimal.

H.1 and H.2 If the inoperable AC electric power sources or the load shedder and emergency load sequencer cannot be restored to OPERABLE status within the required Completion Time, or Required Actions B.1, B.2, B.3.1, B.3.2, B.4.1 or B.4.2 2 cannot be met within the required Completion Times, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the unit must be brought to at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging plant systems.

Wolf Creek - Unit I B 3.8.1-17 Revision 26

AC Sources - Operating B 3.8.1 BASES ACTIONS 1.1 (continued)

Condition I corresponds to a level of degradation in which all redundancy in the AC electrical power supplies has been lost. At this severely degraded level, any further losses in the AC electrical power system will cause a loss of function. Therefore, no additional time is justified for continued operation. The unit is required by LCO 3.0.3 to commence a controlled shutdown.

SURVEILLANCE REQUIREMENTS The AC sources are designed to permit inspection and testing of all important areas and features, especially those that have a standby function, in accordance with 10 CFR 50, Appendix A, GDC 18 (Ref. 8).

Periodic component tests are supplemented by extensive functional tests during refueling outages (under simulated accident conditions). The SRs for demonstrating the OPERABILITY of the DGs are in accordance with the recommendations of Regulatory Guide 1.9 (Ref. 3), Regulatory Guide 1.108 (Ref. 9), and Regulatory Guide 1.137 (Ref. 10), as addressed in the USAR.

Where the SRs discussed herein specify voltage and frequency tolerances, the following is applicable. This minimum steady state output voltage of 3950 V is 95% of the nominal 4160 V output voltage. This value, which is 210 V above the minimum utilization voltage specified in ANSI C84.1 (Ref. 11), allows for voltage drop to the terminals of 4000 V motors whose minimum operating voltage is specified as 90% or 3600 V.

It also allows for voltage drops to motors and other equipment down through the 120 V level. This value provides for the OPERABILITY of required loads as shown by load flow calculations in support of NRC Branch Technical Position PSB-1. These calculations have demonstrated that no end use loads will be adversely affected from sustained operation above the degraded voltage allowable value as specified in SR 3.3.5.3.

The 3950 V is above the calculated allowable value. The specified maximum steady state output voltage of 4320 V ensures that for a lightly loaded distribution system, the voltage at the terminals of 4000 V motors is no more than the maximum rated operating voltages. The specified minimum and maximum frequencies of the DG are 59.4 Hz and 60.6 Hz.

SR 3.8.1.1 This SR ensures proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network and availability of offsite AC electrical power. The breaker alignment verifies that each breaker is in its correct position to ensure that distribution buses and loads are connected to their preferred power source, and that appropriate Wolf Creek - Unit 1 B 3.8.1-18 Revision 59 Wolf Creek - Unit 1 B 3.8.1-18 Revision 59

AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.13 (continued)

REQUIREMENTS mitigate the DBA is more critical than protecting the engine against minor problems that are not immediately detrimental to emergency operation of the DG.

The 18 month Frequency is based on engineering judgment and is intended to be consistent with expected fuel cycle lengths. Operating experience has shown that these components usually pass the SR when performed at the 18 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.8.1.14 Regulatory Guide 1.9, Rev. 3, (Ref. 3), requires demonstration once per 18 months that the DGs can start and run continuously at full load capability for an interval of not less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , 2! 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of which is at a load not greater than 110% of the continuous duty rating (short-time rated load) and the remainder of the time at a load equivalent to the continuous duty rating (continuous rated load) of the DG. The short-time rated load and the continuous rated load may be applied in either order.

The DG starts for this Surveillance can be performed either from standby or hot conditions. The provisions for prelubricating and warmup, discussed in SR 3.8.1.2, and for gradual loading, discussed in SR 3.8.1.3, are applicable to this SR.

In order to ensure that the DG is tested under load conditions that are as close to design conditions as possible, testing must be performed using a power factor of > 0.8 and _ 0.9 at a voltage of 4160 +160 -210 volts and a frequency of 60 + 0.6 Hz. This power factor is chosen to be representative of the actual design basis inductive loading that the DG would experience. The load band is provided to avoid routine overloading of the DG. Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.

Administrative controls for performing this SR in MODES 1 or 2, with the DG connected to an offsite circuit, ensure or require that:

a.

Weather conditions are conducive for performing this SR.

b.

The offsite power supply and switchyard conditions are conducive for performing this SR, which includes ensuring that switchyard access is restricted and no elective maintenance within the switchyard is performed.

c.

No equipment or systems assumed to be available for supporting the performance of the SR are removed from service.

Wolf Creek - Unit 1 B 3.8.1-27 Revision 59

AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.14 (continued)

REQUIREMENTS The DG is considered OPERABLE during performance of the Surveillance, i.e., while it is paralleled to the offsite power source, consistent with the Technical Evaluation (i.e., Section 4.0) contained in the Safety Evaluation provided for Amendment No. 154 (Reference 17).

This includes consideration of the potential challenges to the DG, its response to a LOCA and/or a loss of offsite power, and appropriate operator actions to restore the DG.

The 18 month Frequency is consistent with the recommendations of Regulatory Guide 1.9, Rev. 3 (Ref. 3), and is intended to be consistent with expected fuel cycle lengths.

This Surveillance is modified by a Note. The Note states that momentary transients due to changing bus loads do not invalidate this test. Similarly, momentary power factor transients outside the power factor range will not invalidate the test.

SR 3.8.1.15 This Surveillance demonstrates that the diesel engine can restart from a hot condition, such as subsequent to shutdown from normal Surveillances, and achieve the required voltage and frequency within 12 seconds. The 12 second time is derived from the requirements of the accident analysis to respond to a design basis large break LOCA. The 18 month Frequency is consistent with the recommendations of Regulatory Guide 1.9, Rev. 3 (Ref. 3).

This SR is modified by two Notes. Note 1 ensures that the test is performed with the diesel sufficiently hot. The load band is provided to avoid routine overloading of the DG. Routine overloads may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY. The requirement that the diesel has operated for at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months at full load conditions prior to performance of this Surveillance is based on manufacturer recommendations for achieving hot conditions. Momentary transients due to changing bus loads do not invalidate this test. Note 2 allows all DG starts to be preceded by an engine prelube period to minimize wear and tear on the diesel during testing.

Wolf Creek - Unit I B 3.8.1-28 Revision 59

AC Sources - Shutdown B 3.8.2 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.2 AC Sources - Shutdown BASES BACKGROUND A description of the AC sources is provided in the Bases for LCO 3.8.1, "AC Sources -Operating."

APPLICABLE The OPERABILITY of the minimum AC sources during MODES 5 and 6, SAFETY ANALYSES and during movement of irradiated fuel assemblies ensures that:

a.

The unit can be maintained in the shutdown or refueling condition for extended periods;

b.

Sufficient instrumentation and control capability is available for monitoring and maintaining the unit status; and

c.

Adequate AC electrical power is provided to mitigate events postulated during shutdown, such as a fuel handling accident.

In general, when the unit is shut down, the Technical Specifications requirements ensure that the unit has the capability to mitigate the consequences of postulated accidents. However, assuming a single failure and concurrent loss of all offsite or all onsite power is not required.

The rationale for this is based on the fact that many Design Basis Accidents (DBAs) that are analyzed in MODES 1, 2, 3, and 4 have no specific analyses in MODES 5 and 6. Worst case bounding events are deemed not credible in MODES 5 and 6 because the energy contained within the reactor pressure boundary, reactor coolant temperature and pressure, and the corresponding stresses result in the probabilities of occurrence being significantly reduced or eliminated, and in minimal consequences. These deviations from DBA analysis assumptions and design requirements during shutdown conditions are allowed by the LCO for required systems.

During MODES 1, 2, 3, and 4, various deviations from the analysis assumptions and design requirements are allowed within the Required Actions. This allowance is in recognition that certain testing and maintenance activities must be conducted provided an acceptable level of risk is not exceeded. During MODES 5 and 6, performance of a significant number of required testing and maintenance activities is also required. In MODES 5 and 6, the activities are generally planned and administratively controlled. Relaxations from MODE 1, 2, 3, and 4 LCO Wolf Creek - Unit I B 3.8.2-1 Revision 57

AC Sources - Shutdown B 3.8.2 BASES APPLICABLE requirements are acceptable during shutdown modes based on:

SAFETY ANALYSES (continued)

a.

The fact that time in an outage is limited. This is a risk prudent goal as well as a utility economic consideration.

b.

Requiring appropriate compensatory measures for certain conditions. These may include administrative controls, reliance on systems that do not necessarily meet typical design requirements applied to systems credited in operating MODE analyses, or both.

c.

Prudent utility consideration of the risk associated with multiple activities that could affect multiple systems.

d.

Maintaining, to the extent practical, the ability to perform required functions (even if not meeting MODE 1, 2, 3, and 4 OPERABILITY requirements) with systems assumed to function during an event.

In the event of an accident during shutdown, this LCO ensures the capability to support systems necessary to avoid immediate difficulty, assuming either a loss of all offsite power or a loss of all onsite diesel generator (DG) power.

In addition to the requirements established by the Technical Specifications, the plant staff must also manage shutdown tasks and electrical support to maintain risk at an acceptably low value.

As required by the Technical Specifications, one train of the required equipment during shutdown conditions is supported by one train of AC and DC power and distribution. The availability of additional equipment, both redundant equipment as required by the Technical Specifications and equipment not required by the specifications, contributes to risk reduction and this equipment should be supported by reliable electrical power systems. Typically the Class 1 E power sources and distribution systems of the unit are used to power this equipment because these power and distribution systems are available and reliable. When portions of the Class 1 E power or distribution systems are not available (usually as a result of maintenance or modifications), other reliable power sources or distribution are used to provide the needed electrical support. The plant staff assesses these alternate power sources and distribution systems to assure that the desired level of minimal risk is maintained (frequently referred to as maintaining a desired defense in depth). The level of detail involved in the assessment will vary with the significance of the equipment being supported. In some cases, prepared guidelines are used which include controls designed to manage risk and retain the desired defense in depth.

Wolf Creek - Unit 1 B 3.8.2-2 Revision 0

AC Sources - Shutdown B 3.8.2 BASES APPLICABLE The AC sources satisfy Criterion 3 of the 10 CFR 50.36(c)(2)(ii).

SAFETY ANALYSES (continued)

LCO One offsite circuit capable of supplying the onsite Class 1 E power distribution subsystem of LCO 3.8.10, "Distribution Systems - Shutdown,"

ensures that one train of required loads are powered from offsite power.

An OPERABLE DG, associated with the distribution system train required to be OPERABLE by LCO 3.8.10, ensures a diverse power source is available to provide electrical power support, assuming a loss of the offsite circuit. Together, OPERABILITY of the required offsite circuit and DG ensures the availability of sufficient AC sources to operate the unit in a safe manner and to mitigate the consequences of postulated events during shutdown (e.g., fuel handling accidents).

The DG must be supporting the train of AC electrical distribution required to be OPERABLE per LCO 3.8.10. The offsite circuit must also support the train of AC electrical distribution required to be OPERABLE per LCO 3.8.10. When the second AC electrical power distribution train (subsystem) is needed to support redundant required systems, equipment and components, the second train may be energized from any available source. The available source must be Class 1 E or another reliable source. The available source must be capable of supplying sufficient AC electrical power such that the redundant components are capable of performing their specified safety function(s) (implicitly required by the definition of OPERABILITY). Otherwise, the supported components must be declared inoperable and the appropriate conditions of the LCOs for the redundant components must be entered.

The qualified offsite circuit must be capable of maintaining rated frequency and voltage, and accepting required loads during an accident, while connected to the Engineered Safety Feature (ESF) bus(es).

Qualified offsite circuits are those that are described in the USAR and are part of the licensing basis for the unit.

One offsite circuit consists of the #7 transformer feeding through the 13-48 breaker power the ESF transformer XNBO1, which, in turn powers the NB01 bus through its normal feeder breaker. Transformer XNB01 may also be powered from the SL-7 supply through the 13-8 breaker provided the offsite 69 KV line is not connected to the 345 kV system.

Another offsite circuit consists of the startup transformer feeding through breaker PA201 powering the ESF transformer XNB02, which, in turn powers the NB02 bus through its normal feeder breaker.

Wolf Creek - Unit 1 B 3.8.2-3 Revision 0

AC Sources - Shutdown B 3.8.2 BASES LCO (continued)

The DG must be capable of starting, accelerating to rated speed and voltage, and connecting to its respective ESF bus on detection of bus undervoltage. This sequence must be accomplished within 12 seconds.

The DG must be capable of accepting required loads within the assumed loading sequence intervals, and continue to operate until offsite power can be restored to the ESF buses. These capabilities are required to be met from a variety of initial conditions such as DG in standby with the engine hot and DG in standby at ambient conditions.

Initiating an EDG start upon a detected under voltage or degraded voltage condition, tripping of nonessential loads, and proper sequencing of loads, is a required function of load shedder and emergency load sequencer (LSELS) and required for DG OPERABILITY. Only the shutdown sequencer on the train supported by the OPERABLE DG is required to be OPERABLE in MODES 5 and 6. In addition, the LSELS Automatic Test Indicator (ATI) is an installed testing aid and is not required to be OPERABLE to support the sequencer function. Absence of a functioning ATI does not render LSELS inoperable.

It is acceptable for one offsite circuit to be connected to more than one ESF bus through the normal or alternate feeder breakers with the loading limitations of calculation XX-E-006, "AC System Analysis," not being exceeded. Each offsite circuit can be manually aligned to supply power to the opposite NB bus.

APPLICABILITY The AC sources required to be OPERABLE in MODES 5 and 6, and during movement of irradiated fuel assemblies provide assurance that:

a.

Systems to provide adequate coolant inventory makeup are available for the irradiated fuel assemblies in the core;

b.

Systems needed to mitigate a fuel handling accident are available;

c.

Systems necessary to mitigate the effects of events that can lead to core damage during shutdown are available; and

d.

Instrumentation and control capability is available for monitoring and maintaining the unit in a cold shutdown condition or refueling condition.

The AC power requirements for MODES 1, 2, 3, and 4 are covered in LCO 3.8.1.

Wolf Creek - Unit I B 3.8.2-4 Revision 57

AC Sources - Shutdown B 3.8.2 BASES ACTIONS LCO 3.0.3 is not applicable while in MODE 5 or 6. However, since irradiated fuel assembly movement can occur in MODE 1, 2, 3, or 4, the ACTIONS have been modified by a Note stating that LCO 3.0.3 is not applicable. If moving irradiated fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operations. Entering LCO 3.0.3, while in MODE 1, 2, 3, or 4 would require the unit to be shutdown unnecessarily.

A.1 An offsite circuit would be considered inoperable if it were not available to one required ESF train. The one train with offsite power available may be capable of supporting sufficient required features to allow continuation of CORE ALTERATIONS and fuel movement. By the allowance of the option to declare required features inoperable, with no offsite power available, appropriate restrictions will be implemented in accordance with the affected required features LCO's ACTIONS.

A.2.1, A.2.2, A.2.3. A.2.4, B.1, B.2. B.3. and B.4 With the offsite circuit not available to one required train, the option would still exist to declare all required features inoperable. Since this option may involve undesired administrative efforts, the allowance for sufficiently conservative actions is made. With the required DG inoperable, the minimum required diversity of AC power sources is not available. It is, therefore, required to suspend CORE ALTERATIONS, movement of irradiated fuel assemblies, and operations involving positive reactivity additions that could result in loss of required SDM (MODE 5) of LCO 3.1.1 or boron concentration (MODE 6) of LCO 3.9.1. Suspending positive reactivity additions that could result in failure to meet the minimum SDM or boron concentration limit is required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than that required in the RCS for minimum SDM or refueling boron concentration. This may result in an overall reduction in RCS boron concentration, but provides acceptable margin to maintaining subcritical operation. Introduction of temperature changes, including temperature increases when operating with a positive MTC, must also be evaluated to ensure they do not result in a loss of required SDM.

Suspension of these activities does not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability or the occurrence of postulated events. It is further required to immediately initiate action to restore the required AC sources and to Wolf Creek - Unit 1 B 3.8.2-5 Revision 57

AC Sources - Shutdown B 3.8.2 BASES ACTIONS A.2.1, A.2.2, A.2.3, A.2.4, B.1. B.2. B.3. and B.4 (continued) continue this action until restoration is accomplished in order to provide the necessary AC power to the unit safety systems.

The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required AC electrical power sources should be completed as quickly as possible in order to minimize the time during which the unit safety systems may be without sufficient power.

Pursuant to LCO 3.0.6, the Distribution System's ACTIONS would not be entered even if all AC sources to it are inoperable, resulting in de-energization. Therefore, the Required Actions of Condition A are modified by a Note to indicate that when Condition A is entered with no AC power to the required ESF bus, the ACTIONS for LCO 3.8.10 must be immediately entered. This Note allows Condition A to provide requirements for the loss of the offsite circuit, whether or not a train is de-energized. LCO 3.8.10 would provide the appropriate restrictions for the situation involving a de-energized train.

C.1 Required Action C.1 provides assurance that the appropriate Action is entered for the affected DG and offsite circuit if the shutdown portion of the load shedder and emergency load sequencer LSELS becomes inoperable. The shutdown portion of the LSELS is an essential support system to both the offsite circuit and the DG associated with a given ESF bus. Furthermore, the sequencer is on the primary success path for most AC electrically powered safety systems powered from the associated ESF bus. With the required LSELS (shut down portion) inoperable, immediately declare the affected DG and offsite circuit inoperable and take the Required Actions of Conditions A and B. The Completion Time of immediately is consistent with the required times for actions requiring prompt attention.

SURVEILLANCE SR 3.8.2.1 REQUIREMENTS SR 3.8.2.1 requires the SRs from LCO 3.8.1 that are necessary for ensuring the OPERABILITY of the AC sources in other than MODES 1, 2, 3, and 4. SR 3.8.1.12, SR 3.8.1.13, SR 3.8.1.17, SR 3.8.1.18 (LOCA portion), SR 3.8.1.19, and SR 3.8.1.21 (LOCA portion) are excepted because the capability to respond to a safety injection signal is not required to be demonstrated in MODE 5 or 6. For SR 3.8.1.18 and SR 3.8.1.21, only the portion which tests the LSELS is required in MODE 5 Wolf Creek - Unit 1 B 3.8.2-6 Revision 57 1

AC Sources - Shutdown B 3.8.2 BASES SURVEILLANCE SR 3.8.2.1 (continued)

REQUIREMENTS and 6. SR 3.8.1.20 is excepted because starting independence is not required with the DG that is not required to be OPERABLE.

This SR is modified by a Note. The reason for the Note is to preclude requiring the OPERABLE DG from being paralleled with the offsite power network or otherwise rendered inoperable during performance of SRs, and to preclude de-energizing a required 4160 V ESF bus or disconnecting a required offsite circuit during performance of SRs. With limited AC sources available, a single event could compromise both the required circuit and the DG. It is the intent that these SRs must still be capable of being met, but actual performance is not required during periods when the DG and offsite circuit is required to be OPERABLE.

Refer to the corresponding Bases for LCO 3.8.1 for a discussion of each SR.

REFERENCES None Wolf Creek - Unit 1 B 3.8.2-7 Revision 57 1

DC Sources - Shutdown B 3.8.5 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.5 DC Sources - Shutdown BASES BACKGROUND A description of the DC sources is provided in the Bases for LCO 3.8.4, "DC Sources -Operating."

APPLICABLE SAFETY ANALYSES The initial conditions of Design Basis Accident and transient analyses in the USAR, Chapter 6 (Ref. 1) and Chapter 15 (Ref. 2), assume that Engineered Safety Feature systems are OPERABLE. The DC electrical power system provides normal and emergency DC electrical power for the diesel generators, emergency auxiliaries, and control and switching during all MODES of operation.

The OPERABILITY of the DC subsystems is consistent with the initial assumptions of the accident analyses and the requirements for the supported systems' OPERABILITY.

The OPERABILITY of the minimum DC electrical power sources during MODES 5 and 6, and during movement of irradiated fuel assemblies ensures that:

a.

The unit can be maintained in the shutdown or refueling condition for extended periods;

b.

Sufficient instrumentation and control capability is available for monitoring and maintaining the unit status; and

c.

Adequate DC electrical power is provided to mitigate events postulated during shutdown, such as a fuel handling accident.

In general, when the unit is shut down, the Technical Specifications requirements ensure that the unit has the capability to mitigate the consequences of postulated accidents. However, assuming a single failure and concurrent loss of all offsite or all onsite power is not required.

The rationale for this is based on the fact that many Design Basis Accidents (DBAs) that are analyzed in MODES 1, 2, 3, and 4 have no specific analyses in MODES 5 and 6. Worst case bounding events are deemed not credible in MODES 5 and 6 because the energy contained within the reactor pressure boundary, reactor coolant temperature and pressure, and the corresponding stresses result in the probabilities of occurrence being significantly reduced or eliminated, and in minimal consequences. These deviations from DBA analysis assumptions and Wolf Creek - Unit 1 B 3.8.5-1 Revision 57

DC Sources - Shutdown B 3.8.5 BASES APPLICABLE design requirements during shutdown conditions are allowed by the LCO SAFETY ANALYSES for required systems.

(continued)

During MODES 1, 2, 3, and 4, various deviations from the analysis assumptions and design requirements are allowed within the Required Actions. This allowance is in recognition that certain testing and maintenance activities must be conducted provided an acceptable level of risk is not exceeded. During MODES 5 and 6, performance of a significant number of required testing and maintenance activities is also required. In MODES 5 and 6, the activities are generally planned and administratively controlled. Relaxations from MODE 1, 2, 3, and 4 LCO requirements are acceptable during shutdown modes based on:

a.

The fact that time in an outage is limited. This is a risk prudent goal as well as a utility economic consideration.

b.

Requiring appropriate compensatory measures for certain conditions. These may include administrative controls, reliance on systems that do not necessarily meet typical design requirements applied to systems credited in operating MODE analyses, or both.

c.

Prudent utility consideration of the risk associated with multiple activities that could affect multiple systems.

c.

Maintaining, to the extent practical, the ability to perform required functions (even if not meeting MODE 1, 2, 3, and 4 OPERABILITY requirements) with systems assumed to function during an event.

In addition to the requirements established by the Technical Specifications, the plant staff must also manage shutdown tasks and electrical support to maintain risk at an acceptably low value.

As required by the Technical Specifications, one train of the required equipment during shutdown conditions is supported by one train of AC and DC power and distribution. The availability of additional equipment, both redundant equipment as required by the Technical Specifications and equipment not required by the specifications, contributes to risk reduction and this equipment should be supported by reliable electrical power systems. Typically the Class 1 E power sources and distribution systems of the unit are used to power this equipment because these power and distribution systems are available and reliable. When portions of the Class 1 E power or distribution systems are not available (usually as a result of maintenance or modifications), other reliable power sources or distribution are used to provide the needed electrical support. The plant staff assesses these alternate power sources and distribution systems to Wolf Creek - Unit 1 B 3.8.5-2 Revision 0

DC Sources - Shutdown B 3.8.5 BASES APPLICABLE assure that the desired level of minimal risk is maintained (frequently SAFETY ANALYSES referred to as maintaining a desired defense in depth). The level of (continued) detail involved in the assessment will vary with the significance of the equipment being supported. In some cases, prepared guidelines are used which include controls designed to manage risk and retain the desired defense in depth.

The DC sources satisfy Criterion 3 of the 10 CFR 50.36(c)(2)(ii).

LCO One DC electrical power subsystem and the corresponding control equipment and interconnecting cabling within the train, are required to be OPERABLE to support one train of the DC electrical power distribution systems required by LCO 3.8.10, "Distribution Systems - Shutdown." The required DC electrical power subsystem (Train A or Train B) consists of two DC buses energized from the associated batteries and chargers or spare charger powered from the respective Class 1 E 480 V load center and the corresponding control equipment and interconnecting cabling within the train. This ensures the availability of sufficient DC electrical power sources to operate the unit in a safe manner and to mitigate the consequences of postulated events during shutdown (e.g., fuel handling accidents).

The required DC electrical power distribution subsystem is supported by one train of DC electrical power system. When the second DC electrical power distribution train (subsystem) is needed to support redundant required systems, equipment and components, the second train may be energized from any available source. The available source must be Class 1 E or another reliable source. The available source must be capable of supplying sufficient DC electrical power such that the redundant components are capable of performing their specified safety functions(s)

(implicitly required by the definition of OPERABILITY). Otherwise, the supported components must be declared inoperable and the appropriate conditions of the LCOs for the redundant components must be entered.

APPLICABILITY The DC electrical power sources required to be OPERABLE in MODES 5 and 6, and during movement of irradiated fuel assemblies provide assurance that:

a.

Required features to provide adequate coolant inventory makeup are available for the irradiated fuel assemblies in the core;

b.

Required features needed to mitigate a fuel handling accident are available; Wolf Creek - Unit 1 B 3.8.5-3 Revision 57

DC Sources - Shutdown B 3.8.5 BASES APPLICABILITY

c.

Required features necessary to mitigate the effects of events that (continued) can lead to core damage during shutdown are available; and

d.

Instrumentation and control capability is available for monitoring and maintaining the unit in a cold shutdown condition or refueling condition.

The DC electrical power requirements for MODES 1, 2, 3, and 4 are covered in LCO 3.8.4.

ACTIONS LCO 3.0.3 is not applicable while in MODE 5 or 6. However, since irradiated fuel assembly movement can occur in MODE 1, 2, 3, or 4, the ACTIONS have been modified by a Note stating that LCO 3.0.3 is not applicable. If moving irradiated fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operations. Entering LCO 3.0.3, while in MODE 1, 2, 3, or 4 would require the unit to be shutdown unnecessarily.

A.1. A.2.1, A.2.2, A.2.3, and A.2.4 By allowing the option to declare required features inoperable with the associated DC power source(s) inoperable, appropriate restrictions will be implemented in accordance with the affected required features LCO ACTIONS. In many instances, this option may involve undesired administrative efforts. Therefore, the allowance for sufficiently conservative actions is made (i.e., to suspend CORE ALTERATIONS, movement of irradiated fuel assemblies, and operations involving positive reactivity additions that could result in loss of required SDM (MODE 5) of LCO 3.1.1 or boron concentration (MODE 6) of LCO 3.9.1). Suspending positive reactivity additions that could result in failure to meet the minimum SDM or boron concentration limit is required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than that required in the RCS for minimum SDM or refueling boron concentration. This may result in an overall reduction in RCS boron concentration, but provides acceptable margin to maintaining subcritical operation. Introduction of temperature changes, including temperature increases when operating with a positive MTC, must also be evaluated to ensure they do not result in a loss of required SDM.

Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition. These actions minimize probability of the occurrence of postulated events. It is further required to Wolf Creek - Unit 1 B 3.8.5-4 Revision 57

DC Sources - Shutdown B 3.8.5 BASES ACTIONS A.1, A.2.1. A.2.2. A.2.3, and A.2.4 (continued) immediately initiate action to restore the required DC electrical power subsystem and to continue this action until restoration is accomplished in order to provide the necessary DC electrical power to the unit safety systems.

The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required DC electrical power subsystem should be completed as quickly as possible in order to minimize the time during which the unit safety systems may be without sufficient power.

SURVEILLANCE SR 3.8.5.1 REQUIREMENTS SR 3.8.5.1 requires performance of all Surveillances required by SR 3.8.4.1 through SR 3.8.4.8. Therefore, see the corresponding Bases for LCO 3.8.4 for a discussion of each SR.

This SR is modified by a Note. The reason for the Note is to preclude requiring the OPERABLE DC sources from being discharged below their capability to provide the required power supply or otherwise rendered inoperable during the performance of SRs. It is the intent that these SRs must still be capable of being met, but actual performance is not required.

REFERENCES

1.

USAR, Chapter 6.

2.

USAR, Chapter 15.

Wolf Creek - Unit 1 B 3.8.5-5 Revision 57 1

Inverters - Shutdown B 3.8.8 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.8 Inverters -Shutdown BASES BACKGROUND A description of the inverters is provided in the Bases for LCO 3.8.7, "Inverters - Operating."

APPLICABLE SAFETY ANALYSES The initial conditions of Design Basis Accident (DBA) and transient analyses in the USAR, Chapter 6 (Ref. 1) and Chapter 15 (Ref. 2),

assume Engineered Safety Feature systems are OPERABLE. The DC to AC inverters are designed to provide the required capacity, capability, redundancy, and reliability to ensure the availability of necessary power to the Reactor Protection System and Engineered Safety Features Actuation System instrumentation and controls so that the fuel, Reactor Coolant System, and containment design limits are not exceeded.

The OPERABILITY of the inverters is consistent with the initial assumptions of the accident analyses and the requirements for the supported systems' OPERABILITY.

The OPERABILITY of the minimum inverters to each AC vital bus during MODES 5 and 6, and during movement of irradiated fuel assemblies ensures that:

a.

The unit can be maintained in the shutdown or refueling condition for extended periods;

b.

Sufficient instrumentation and control capability is available for monitoring and maintaining the unit status; and

c.

Adequate power is available to mitigate events postulated during shutdown, such as a fuel handling accident.

In general, when the unit is shut down, the Technical Specifications requirements ensure that the unit has the capability to mitigate the consequences of postulated accidents. However, assuming a single failure and concurrent loss of all offsite or all onsite power is not required.

The rationale for this is based on the fact that many Design Basis Basis Accidents (DBAs) that are analyzed in MODES 1, 2, 3, and 4 have no specific analyses in MODES 5 and 6. Worst case bounding events are deemed not credible in MODES 5 and 6 because the energy contained within the reactor pressure boundary, reactor coolant temperature and pressure, and the corresponding stresses result in the probabilities of Wolf Creek - Unit 1 B 3.8.8-1 Revision 57

Inverters - Shutdown B 3.8.8 BASES APPLICABLE occurrence being significantly reduced or eliminated, and in minimal SAFETY ANALYSES consequences. These deviations from DBA analysis assumptions and (continued) design requirements during shutdown conditions are allowed by the LCO for required systems.

During MODES 1, 2, 3, and 4, various deviations from the analysis assumptions and design requirements are allowed within the Required Actions. This allowance is in recognition that certain testing and maintenance activities must be conducted provided an acceptable level of risk is not exceeded. During MODES 5 and 6, performance of a significant number of required testing and maintenance activities is also required. In MODES 5 and 6, the activities are generally planned and administratively controlled. Relaxations from MODE 1, 2, 3, and 4 LCO requirements are acceptable during shutdown modes based on:

a.

The fact that time in an outage is limited. This is a risk prudent goal as well as a utility economic consideration.

b.

Requiring appropriate compensatory measures for certain conditions. These may include administrative controls, reliance on systems that do not necessarily meet typical design requirements applied to systems credited in operating MODE analyses, or both.

c.

Prudent utility consideration of the risk associated with multiple activities that could affect multiple systems.

d.

Maintaining, to the extent practical, the ability to perform required functions (even if not meeting MODE 1, 2, 3, and 4 OPERABILITY requirements) with systems assumed to function during an event.

In addition to the requirements established by the Technical Specifications, the plant staff must also manage shutdown tasks and electrical support to maintain risk at an acceptably low value.

As required by the Technical Specifications, one train of the required equipment during shutdown conditions is supported by one train of AC and DC power and distribution. The availability of additional equipment, both redundant equipment as required by the Technical Specifications and equipment not required by the specifications, contributes to risk reduction and this equipment should be supported by reliable electrical power systems. Typically the Class 1 E power sources and distribution systems of the unit are used to power this equipment because these power and Wolf Creek - Unit 1 B 3.8.8-2 Revision 0

Inverters - Shutdown B 3.8.8 BASES APPLICABLE distribution systems are available and reliable. When portions of the SAFETY ANALYSES Class 1 E power or distribution systems are not available (usually as a (continued) result of maintenance or modifications), other reliable power sources or distribution are used to provide the needed electrical support. The plant staff assesses these alternate power sources and distribution systems to assure that the desired level of minimal risk is maintained (frequently referred to as maintaining a desired defense in depth). The level of detail involved in the assessment will vary with the significance of the equipment being supported. In some cases, prepared guidelines are used which include controls designed to manage risk and retain the desired defense in depth.

The inverters satisfy Criterion 3 of the 10 CFR 50.36(c)(2)(ii).

LCO One train of inverters is required to be OPERABLE to support one train of the onsite Class 1 E AC vital bus electrical power distribution subsystems required by LCO 3.8.10, "Distribution Systems - Shutdown." The required train of inverters (Train A or Train B) consists of two AC vital buses energized from the associated inverters with each inverter connected to the respective DC bus. The inverters ensure the availability of electrical power for the instrumentation for systems required to shut down the reactor and maintain it in a safe condition after an anticipated operational occurrence or a postulated DBA. The battery powered inverters provide uninterruptible supply of AC electrical power to the AC vital buses even if the 4.16 kV safety buses are de-energized. OPERABILITY of the inverters requires that the AC vital bus be powered by the inverter. This ensures the availability of sufficient inverter power sources to operate the unit in a safe manner and to mitigate the consequences of postulated events during shutdown (e.g., fuel handling accidents).

The required AC vital bus electrical power distribution subsystem is supported by one train of inverters. When the second (subsystem) of AC vital bus electrical power distribution is needed to support redundant required systems, equipment and components, the second train may be energized from any available source. The available source must be Class 1 E or another reliable source. The available source must be capable of supplying sufficient AC electrical power such that the redundant components are capable of performing their specified safety function(s)

(implicitly required by the definition of OPERABILITY). Otherwise, the supported components must be declared inoperable and the appropriate conditions of the LCOs for the redundant components must be entered.

Wolf Creek - Unit 1 B 3.8.8-3 Revision 0

Inverters -Shutdown B 3.8.8 BASES APPLICABILITY The inverters required to be OPERABLE in MODES 5 and 6 provide assurance that:

a.

Systems to provide adequate coolant inventory makeup are available for the irradiated fuel in the core;

b.

Systems needed to mitigate a fuel handling accident are available;

c.

Systems necessary to mitigate the effects of events that can lead to core damage during shutdown are available; and

d.

Instrumentation and control capability is available for monitoring and maintaining the unit in a cold shutdown condition or refueling condition.

Inverter requirements for MODES 1, 2, 3, and 4 are covered in LCO 3.8.7.

ACTIONS LCO 3.0.3 is not applicable while in MODE 5 or 6. However, since irradiated fuel assembly movement can occur in MODE 1, 2, 3, or 4, the ACTIONS have been modified by a Note stating that LCO 3.0.3 is not applicable. If moving irradiated fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operations. Entering LCO 3.0.3, while in MODE 1, 2, 3, or 4 would require the unit to be shutdown unnecessarily.

A.1, A.2.1, A.2.2. A.2.3, and A.2.4 By the allowance of the option to declare required features inoperable with the associated inverter(s) inoperable, appropriate restrictions will be implemented in accordance with the affected required features LCOs' Required Actions. In many instances, this option may involve undesired administrative efforts. Therefore, the allowance for sufficiently conservative actions is made (i.e., to suspend CORE ALTERATIONS, movement of irradiated fuel assemblies, and operations involving positive reactivity additions that could result in loss of required SDM (MODE 5) of LCO 3.1.1 or boron concentration (MODE 6) of LCO 3.9.1). Suspending positive reactivity additions that could result in failure to meet the minimum SDM or boron concentration limit is required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than that required in the RCS for minimum SDM or refueling boron concentration. This may result in an overall reduction in RCS boron concentration, but provides acceptable Wolf Creek - Unit 1 B 3.8.8-4 Revision 57

Inverters -Shutdown B 3.8.8 BASES ACTIONS A.1, A.2.1. A.2.2, A.2.3. and A.2.4 (continued) margin to maintaining subcritical operation. Introduction of temperature changes, including temperature increases when operating with a positive MTC, must also be evaluated to ensure they do not result in a loss of required SDM.

Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability of the occurrence of postulated events. It is further required to immediately initiate action to restore the required inverters and to continue this action until restoration is accomplished in order to provide the necessary inverter power to the unit safety systems.

The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required inverters should be completed as quickly as possible in order to minimize the time the unit safety systems may be without power or powered from a constant voltage (Sola) transformer.

SURVEILLANCE SR 3.8.8.1 REQUIREMENTS This Surveillance verifies that the inverters are functioning properly with all required circuit breakers closed and AC vital buses energized from the inverter. The verification of proper voltage output ensures that the required power is readily available for the instrumentation connected to the AC vital buses. The 7 day Frequency takes into account the redundant capability of the inverters and other indications available in the control room that alert the operator to inverter malfunctions.

REFERENCES

1.

USAR, Chapter 6.

2.

USAR, Chapter 15.

Wolf Creek - Unit 1 B 3.8.8-5 Revision 57 1

Distribution Systems - Shutdown B 3.8.10 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.10 Distribution Systems - Shutdown BASES BACKGROUND A description of the AC, DC, and AC vital bus electrical power distribution systems is provided in the Bases for LCO 3.8.9, "Distribution Systems -

Operating."

APPLICABLE SAFETY ANALYSES The initial conditions of Design Basis Accident and transient analyses in the USAR, Chapter 6 (Ref. 1) and Chapter 15 (Ref. 2), assume Engineered Safety Feature (ESF) systems are OPERABLE. The AC, DC, and AC vital bus electrical power distribution systems are designed to provide sufficient capacity, capability, redundancy, and reliability to ensure the availability of necessary power to ESF systems so that the fuel, Reactor Coolant System, and containment design limits are not exceeded.

The OPERABILITY of the AC, DC, and AC vital bus electrical power distribution system is consistent with the initial assumptions of the accident analyses and the requirements for the supported systems' OPERABILITY.

The OPERABILITY of the minimum AC, DC, and AC vital bus electrical power distribution subsystems during MODES 5 and 6, and during movement of irradiated fuel assemblies ensures that:

a.

The unit can be maintained in the shutdown or refueling condition for extended periods;

b.

Sufficient instrumentation and control capability is available for monitoring and maintaining the unit status; and

c.

Adequate power is provided to mitigate events postulated during shutdown, such as a fuel handling accident.

In general, when the unit is shut down, the Technical Specifications requirements ensure that the unit has the capability to mitigate the consequences of postulated accidents. However, assuming a single failure and concurrent loss of all offsite or all onsite power is not required.

The rationale for this is based on the fact that many Design Basis Accidents (DBAs) that are analyzed in MODES 1, 2, 3, and 4 have no specific analyses in MODES 5 and 6. Worst case bounding events are deemed not credible in MODES 5 and 6 because the energy contained Wolf Creek - Unit 1 B 3.8.10-1 Revision 57

Distribution Systems - Shutdown B 3.8.10 BASES APPLICABLE within the reactor pressure boundary, reactor coolant temperature and SAFETY ANALYSES pressure, and the corresponding stresses result in the probabilities of (continued) occurrence being significantly reduced or eliminated, and in minimal consequences. These deviations from DBA analysis assumptions and design requirements during shutdown conditions are allowed by the LCO for required systems.

During MODES 1, 2, 3, and 4, various deviations from the analysis assumptions and design requirements are allowed within the Required Actions. This allowance is in recognition that certain testing and maintenance activities must be conducted provided an acceptable level of risk is not exceeded. During MODES 5 and 6, performance of a significant number of required testing and maintenance activities is also required. In MODES 5 and 6, the activities are generally planned and administratively controlled. Relaxations from MODE 1, 2, 3, and 4 LCO requirements are acceptable during shutdown modes based on:

a.

The fact that time in an outage is limited. This is a risk prudent goal as well as a utility economic consideration.

b.

Requiring appropriate compensatory measures for certain conditions. These may include administrative controls, reliance on systems that do not necessarily meet typical design requirements applied to systems credited in operating MODE analyses, or both.

c.

Prudent utility consideration of the risk associated with multiple activities that could affect multiple systems.

d.

Maintaining, to the extent practical, the ability to perform required functions (even if not meeting MODE 1, 2, 3, and 4 OPERABILITY requirements) with systems assumed to function during an event.

In addition to the requirements established by the Technical Specifications, the plant staff must also manage shutdown tasks and electrical support to maintain risk at an acceptably low value.

As required by the Technical Specifications, one train of the required equipment during shutdown conditions is supported by one train of AC and DC power and distribution. The availability of additional equipment, both redundant equipment as required by the Technical Specifications and equipment not required by the specifications, contributes to risk reduction and this equipment should be supported by reliable electrical power systems. Typically the Class 1 E power sources and distribution systems of the unit are used to power this equipment because these Wolf Creek - Unit 1 B 3.8.10-2 Revision 0

Distribution Systems - Shutdown B 3.8.10 BASES APPLICABLE SAFETY ANALYSES (continued) power and distribution systems are available and reliable. When portions of the Class 1 E power or distribution systems are not available (usually as a result of maintenance or modifications), other reliable power sources or distribution are used to provide the needed electrical support. The plant staff assesses these alternate power sources and distribution systems to assure that the desired level of minimal risk is maintained (frequently referred to as maintaining a desired defense in depth). The level of detail involved in the assessment will vary with the significance of the equipment being supported. In some cases, prepared guidelines are used which include controls designed to manage risk and retain the desired defense in depth.

The AC and DC electrical power distribution systems satisfy Criterion 3 of the 10 CFR 50.36(c)(2)(ii).

LCO Various combinations of subsystems, equipment, and components are required OPERABLE by other LCOs, depending on the specific plant condition. Implicit in those requirements is the required OPERABILITY of necessary support required features. This LCO explicitly requires energization of the portions of one train of the electrical distribution system as necessary to support OPERABILITY of one train of required systems, equipment, and components - all specifically addressed in each LCO and implicitly required via the definition of OPERABILITY.

Maintaining these portions of the distribution system energized ensures the availability of sufficient power to operate the unit in a safe manner to mitigate the consequences of postulated events during shutdown (e.g.,

fuel handling accidents).

The AC electrical power distribution subsystems are supported by the AC electrical power sources as required by LCO 3.8.2, "AC Sources -

Shutdown."

The required DC electrical power distribution subsystem is supported by one train of the DC electrical power system as required by LCO 3.8.5, "DC Sources-Shutdown." When the second DC electrical power distribution train (subsystem) is needed to support redundant required systems, equipment, and components, the second train may be energized from any available source. The available source must be Class 1 E or another reliable source. The available source must be capable of supplying sufficient DC electrical power such that the redundant components are capable of performing their specified safety function(s)

(implicitly required by the definition of OPERABILITY). Otherwise, the Wolf Creek - Unit 1 B 3.8.10-3 Revision 0

Distribution Systems - Shutdown B 3.8.10 BASES LCO supported components must be declared inoperable and the appropriate (continued) conditions of the LCOs for the redundant components must be entered.

The required AC vital bus electrical power distribution subsystem is supported by one train of inverters as required by LCO 3.8.8, "Inverters -

Shutdown." When the second (subsystem) of AC vital bus electrical power distribution is needed to support redundant required systems, equipment, and components, the second train may be energized from any available source. The available source must be Class 1 E or another reliable source. The available source must be capable of supplying sufficient AC electrical power such that the redundant components are capable of performing their specified safety function(s) (implicitly required by the definition of OPERABILITY). Otherwise, the supported components must be declared inoperable and the appropriate conditions of the LCOs for the redundant components must be entered.

APPLICABILITY The AC and DC electrical power distribution subsystems required to be OPERABLE in MODES 5 and 6, and during movement of irradiated fuel assemblies provide assurance that:

a.

Systems to provide adequate coolant inventory makeup are available for the irradiated fuel in the core;

b.

Systems needed to mitigate a fuel handling accident are available;

c.

Systems necessary to mitigate the effects of events that can lead to core damage during shutdown are available; and

d.

Instrumentation and control capability is available for monitoring and maintaining the unit in a cold shutdown condition and refueling condition.

The AC, DC, and AC vital bus electrical power distribution subsystems requirements for MODES 1, 2, 3, and 4 are covered in LCO 3.8.9.

ACTIONS LCO 3.0.3 is not applicable while in MODE 5 or 6. However, since irradiated fuel assembly movement can occur in MODE 1, 2, 3, or 4, the ACTIONS have been modified by a Note stating that LCO 3.0.3 is not applicable. If moving irradiated fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operations. Entering LCO 3.0.3, while in MODE 1, 2, 3, or 4 would require the unit to be shutdown unnecessarily.

Wolf Creek - Unit 1 B 3.8.10-4 Revision 57

Distribution Systems - Shutdown B 3.8.10 BASES ACTIONS A.1. A.2.1, A.2.2, A.2.3, A.2.4, and A.2.5 (continued)

By allowing the option to declare required features associated with an inoperable distribution subsystem inoperable, appropriate restrictions are implemented in accordance with the affected distribution subsystem LCO's Required Actions. In many instances, this option may involve undesired administrative efforts. Therefore, the allowance for sufficiently conservative actions is made (i.e., to suspend CORE ALTERATIONS, movement of irradiated fuel assemblies, and operations involving positive reactivity additions that could result in loss of required SDM (MODE 5) of LCO 3.1.1 or boron concentration (MODE 6) of LCO 3.9.1). Suspending positive reactivity additions that could result in failure to meet the minimum SDM or boron concentration limit is required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than that required in the RCS for minimum SDM or refueling boron concentration. This may result in an overall reduction in RCS boron concentration, but provides acceptable margin to maintaining subcritical operation. Introduction of temperature changes, including temperature increases when operating with a positive MTC, must also be evaluated to ensure they do not result in a loss of required SDM.

Suspension of these activities does not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability of the occurrence of postulated events. It is further required to immediately initiate action to restore the required AC and DC electrical power distribution subsystems and to continue this action until restoration is accomplished in order to provide the necessary power to the unit safety systems.

Notwithstanding performance of the above conservative Required Actions, a required residual heat removal (RHR) subsystem may be inoperable. In this case, Required Actions A.2.1 through A.2.4 do not adequately address the concerns relating to coolant circulation and heat removal. Pursuant to LCO 3.0.6, the RHR ACTIONS would not be entered. Therefore, Required Action A.2.5 is provided to direct declaring RHR inoperable, which results in taking the appropriate RHR actions.

The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required distribution subsystems should be completed as quickly as possible in order to minimize the time the unit safety systems may be without power.

Wolf Creek - Unit 1 B 3.8.10-5 Revision 57 1

Distribution Systems - Shutdown B 3.8.10 BASES SURVEILLANCE SR 3.8.10.1 REQUIREMENTS This Surveillance verifies that the required AC, DC, and AC vital bus electrical power distribution subsystems are functioning properly, with all the buses energized. The verification of proper voltage availability on the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connected to these buses. The 7 day Frequency takes into account the capability of the electrical power distribution subsystems, and other indications available in the control room that alert the operator to subsystem malfunctions.

REFERENCES

1.

USAR, Chapter 6.

2.

USAR, Chapter 15.

Wolf Creek - Unit 1 B 3.8.10-6 Revision 57 1

LIST OF EFFECTIVE PAGES - TECHNICAL SPECIFICATION BASES PAGE (1)

REVISION NO. (2)

CHANGE DOCUMENT (3)

DATE EFFECTIVE/

IMPLEMENTED (4)

TAB - Title Page Technical Specification Cover Page Title Page TAB - Table of Contents i

34 DRR 07-1057 7/10/07 ii 29 DRR 06-1984 10/17/06 iii 44 DRR 09-1744 10/28/09 TAB - B 2.0 SAFETY LIMITS (SLs)

B 2.1.1-1 0

Amend. No. 123 12/18/99 B 2.1.1-2 14 DRR 03-0102 2/12/03 B 2.1.1-3 14 DRR 03-0102 2/12/03 B 2.1.1-4 0

Amend. No. 123 2/12/03 B 2.1.2-1 0

Amend. No. 123 12/18/99 B 2.1.2-2 12 DRR 02-1062 9/26/02 B 2.1.2-3 0

Amend. No. 123 12/18/99 TAB - B 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILTY B 3.0-1 34 DRR 07-1057 7/10/07 B 3.0-2 0

Amend. No. 123 12/18/99 B 3.0-3 0

Amend. No. 123 12/18/99 B 3.0-4 19 DRR 04-1414 10/12/04 B 3.0-5 19 DRR 04-1414 10/12/04 B 3.0-6 19 DRR 04-1414 10/12/04 B 3.0-7 19 DRR 04-1414 10/12/04 B 3.0-8 19 DRR 04-1414 10/12/04 B 3.0-9 42 DRR 09-1009 7/16/09 B 3.0-10 42 DRR 09-1009 7/16/09 B 3.0-11 34 DRR 07-1057 7/10/07 B 3.0-12 34 DRR 07-1057 7/10/07 B 3.0-13 34 DRR 07-1057 7/10/07 B 3.0-14 34 DRR 07-1057 7/10/07 B 3.0-15 34 DRR 07-1057 7/10/07 B 3.0-16 34 DRR 07-1057 7/10/07 TAB - B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.1-1 B 3.1.1-2 B 3.1.1-3 B 3.1.1-4 B 3.1.1-5 B 3.1.2-1 B 3.1.2-2 B 3.1.2-3 B 3.1.2-4 B 3.1.2-5 B 3.1.3-1 B 3.1.3-2 B 3.1.3-3 B 3.1.3-4 0

0 0

19 0

0 0

0 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 04-1414 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 12/18/99 12/18/99 12/18/99 10/12/04 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 Wolf Creek - Unit 1 Revision 60

LIST OF EFFECTIVE PAGES - TECHNICAL SPECIFICATION BASES PAGE (1)

REVISION NO. (2)

CHANGE DOCUMENT (3)

DATE EFFECTIVE/

IMPLEMENTED ()

TAB - B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.3-5 0

B 3.1.3-6 0

B 3.1.4-1 0

B 3.1.4-2 0

B 3.1.4-3 48 B 3.1.4-4 0

B 3.1.4-5 0

B 3.1.4-6 48 B 3.1.4-7 0

B 3.1.4-8 0

B 3.1.4-9 0

B 3.1.5-1 0

B 3.1.5-2 0

B 3.1.5-3 0

B 3.1.5-4 0

B 3.1.6-1 0

B 3.1.6-2 0

B 3.1.6-3 0

B 3.1.6-4 0

B 3.1.6-5 0

B 3.1.6-6 0

B 3.1.7-1 0

B 3.1.7-2 0

B 3.1.7-3 48 B 3.1.7-4 48 B 3.1.7-5 48 B 3.1.7-6 0

B 3.1.8-1 0

B 3.1.8-2 0

B 3.1.8-3 15 B 3.1.8-4 15 B 3.1.8-5 0

B 3.1.8-6 5

(continued)

Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 10-3740 Amend. No. 123 Amend. No. 123 DRR 10-3740 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 10-3740 DRR 10-3740 DRR 10-3740 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 03-0860 DRR 03-0860 Amend. No. 123 DRR 00-1427 12/18/99 12/18/99 12/18/99 12/18/99 12/28/10 12/18/99 12/18/99 12/28/10 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/28/10 12/28/10 12/28/10 12/18/99 12/18/99 12/18/99 7/10/03 7/10/03 12/18/99 10/12/00 TAB - B 3.2 POWER DISTRIBUTION LIMITS B 3.2.1-1 48 B 3.2.1-2 0

B 3.2.1-3 48 B 3.2.1-4 48 B 3.2.1-5 48 B 3.2.1-6 48 B 3.2.1-7 48 B 3.2.1-8 48 B 3.2.1-9 29 B 3.2.1-10 48 B 3.2.2-1 48 B 3.2.2-2 0

B 3.2.2-3 48 B 3.2.2-4 48 B 3.2.2-5 48 B 3.2.2-6 48 DRR 10-3740 Amend. No. 123 DRR 10-3740 DRR 10-3740 DRR 10-3740 DRR 10-3740 DRR 10-3740 DRR 10-3740 DRR 06-1984 DRR 10-3740 DRR 10-3740 Amend. No. 123 DRR 10-3740 DRR 10-3740 DRR 10-3740 DRR 10-3740 12/28/10 12/18/99 12/28/10 12/28/10 12/28/10 12/28/10 12/28/10 12/28/10 10/17/06 12/28/10 12/28/10 12/18/99 12/28/10 12/28/10 12/28/10 12/28/10 Wolf Creek - Unit 1 ii ReAsin60

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TAB - B 3.2 POWER DISTRIBUTION LIMITS (continued)

B 3.2.3-1 0

Amend. No. 123 12/18/99 B 3.2.3-2 0

Amend. No. 123 12/18/99 B 3.2.3-3 0

Amend. No. 123 12/18/99 B 3.2.4-1 0

Amend. No. 123 12/18/99 B 3.2.4-2 0

Amend. No. 123 12/18/99 B 3.2.4-3 48 DRR 10-3740 12/28/10 B 3.2.4-4 0

Amend. No. 123 12/18/99 B 3.2.4-5 48 DRR 10-3740 12/28/10 B 3.2.4-6 0

Amend. No. 123 12/18/99 B 3.2.4-7 48 DRR 10-3740 12/28/10 TAB - B 3.3 INSTRUMENTATION B 3.3.1-1 0

B 3.3.1-2 0

B 3.3.1-3 0

B 3.3.1-4 0

B 3.3.1-5 0

B 3.3.1-6 0

B 3.3.1-7 5

B 3.3.1-8 0

B 3.3.1-9 0

B 3.3.1-10 29 B 3.3.1-11 0

B 3.3.1-12 0

B 3.3.1-13 0

B 3.3.1-14 0

B 3.3.1-15 0

B 3.3.1-16 0

B 3.3.1-17 0

B 3.3.1-18 0

B 3.3.1-19 0

B 3.3.1-20 0

B 3.3.1-21 0

B 3.3.1-22 0

B 3.3.1-23 9

B 3.3.1-24 0

B 3.3.1-25 0

B 3.3.1-26 0

B 3.3.1-27 0

B 3.3.1-28 2

B 3.3.1-29 1

B 3.3.1-30 1

B 3.3.1-31 0

B 3.3.1-32 20 B 3.3.1-33 48 B 3.3.1-34 20 B 3.3.1-35 19 B 3.3.1-36 20 B 3.3.1-37 20 B 3.3.1-38 20 B 3.3.1-39 25 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 00-1427 Amend. No. 123 Amend. No. 123 DRR 06-1984 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 02-0123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 00-0147 DRR 99-1624 DRR 99-1624 Amend. No. 123 DRR 04-1533 DRR 10-3740 DRR 04-1533 DRR 04-1414 DRR 04-1533 DRR 04-1533 DRR 04-1533 DRR 06-0800 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 10/12/00 12/18/99 12/18/99 10/17/06 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 2/28/02 12/18/99 12/18/99 12/18/99 12/18/99 4/24/00 12/18/99 12/18/99 12/18/99 2/16/05 12/28/10 2/16/05 10/13/04 2/16/05 2/16/05 2/16/05 5/18/06 Wolf Creek - Unit I iii Revision 60

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TAB - B 3.3 INSTRUMENTATION (continued)

B 3.3.1-40 20 B 3.3.1-41 20 B 3.3.1-42 20 B 3.3.1-43 20 B 3.3.1-44 20 B 3.3.1-45 20 B 3.3.1-46 48 B 3.3.1-47 20 B 3.3.1-48 48 B 3.3.1-49 20 B 3.3.1-50 20 B 3.3.1-51 21 B 3.3.1-52 20 B 3.3.1-53 20 B 3.3.1-54 20 B 3.3.1-55 25 B 3.3.1-56 20 B 3.3.1-57 20 B 3.3.1-58 29 B 3.3.1-59 20 B 3.3.2-1 0

B 3.3.2-2 0

B 3.3.2-3 0

B 3.3.2-4 0

B 3.3.2-5 0

B 3.3.2-6 7

B 3.3.2-7 0

B 3.3.2-8 0

B 3.3.2-9 0

B 3.3.2-10 0

B 3.3.2-11 0

B 3.3.2-12 0

B 3.3.2-13 0

B 3.3.2-14 2

B 3.3.2-15 0

B 3.3.2-16 0

B 3.3.2-17 0

B 3.3.2-18 0

B 3.3.2-19 37 B 3.3.2-20 37 B 3.3.2-21 37 B 3.3.2-22 37 B 3.3.2-23 37 B 3.3.2-24 39 B 3.3.2-25 39 B 3.3.2-26 39 B 3.3.2-27 37 B 3.3.2-28 37 B 3.3.2-29 0

B 3.3.2-30 0

B 3.3.2-31 52 DRR 04-1533 DRR 04-1533 DRR 04-1533 DRR 04-1533 DRR 04-1533 DRR 04-1533 DRR 10-3740 DRR 04-1533 DRR 10-3740 DRR 04-1533 DRR 04-1533 DRR 05-0707 DRR 04-1533 DRR 04-1533 DRR 04-1533 DRR 06-0800 DRR 04-1533 DRR 04-1533 DRR 06-1984 DRR 04-1533 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 01-0474 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 00-0147 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 08-0503 DRR 08-0503 DRR 08-0503 DRR 08-0503 DRR 08-0503 DRR 08-1096 DRR 08-1096 DRR 08-1096 DRR 08-0503 DRR 08-0503 Amend. No. 123 Amend. No. 123 DRR 11-0724 2/16/05 2/16/05 2/16/05 2/16/05 2/16/05 2/16/05 12/28/10 2/16/05 12/28/10 2/16/05 2/16/05 4/20/05 2/16/05 2/16/05 2/16/05 5/18/06 2/16/05 2/16/05 10/17/06 2/16/05 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 5/1/01 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 4/24/00 12/18/99 12/18/99 12/18/99 12/18/99 4/8/08 4/8/08 4/8/08 4/8/08 4/8/08 8/28/08 8/28/08 8/28/08 4/8/08 4/8/08 12/18/99 12/18/99 4/11/11 Wolf Creek - Unit I iv Revision 60

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TAB - B 3.3 INSTRUMENTATION (continued)

B 3.3.2-32 52 B 3.3.2-33 0

B 3.3.2-34 0

B 3.3.2-35 20 B 3.3.2-36 20 B 3.3.2-37 20 B 3.3.2-38 20 B 3.3.2-39 25 B 3.3.2-40 20 B 3.3.2-41 45 B 3.3.2-42 45 B 3.3.2-43 20 B 3.3.2-44 20 B 3.3.2-45 20 B 3.3.2-46 54 B 3.3.2-47 43 B 3.3.2-48 37 B 3.3.2-49 20 B 3.3.2-50 20 B 3.3.2-51 43 B 3.3.2-52 43 B 3.3.2-53 43 B 3.3.2-54 43 B 3.3.2-55 43 B 3.3.2-56 43 B 3.3.2-57 43 B 3.3.3-1 0

B 3.3.3-2 5

B 3.3.3-3 0

B 3.3.3-4 0

B 3.3.3-5 0

B 3.3.3-6 8

B 3.3.3-7 21 B 3.3.3-8 8

B 3.3.3-9 8

B 3.3.3-10 19 B 3.3.3-11 19 B 3.3.3-12 21 B 3.3.3-13 21 B 3.3.3-14 8

B 3.3.3-15 8

B 3.3.4-1 0

B 3.3.4-2 9

B 3.3.4-3 15 B 3.3.4-4 19 B 3.3.4-5 1

B 3.3.4-6 9

B 3.3.5-1 0

B 3.3.5-2 1

B 3.3.5-3 1

DRR 11-0724 Amend. No. 123 Amend. No. 123 DRR 04-1533 DRR 04-1533 DRR 04-1533 DRR 04-1533 DRR 06-0800 DRR 04-1533 Amend. No. 187 (ETS)

Amend. No. 187 (ETS)

DRR 04-1533 DRR 04-1533 DRR 04-1533 DRR 11-2394 DRR 09-1416 DRR 08-0503 DRR 04-1533 DRR 04-1533 DRR 09-1416 DRR 09-1416 DRR 09-1416 DRR 09-1416 DRR 09-1416 DRR 09-1416 DRR 09-1416 Amend. No. 123 DRR 00-1427 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 01-1235 DRR 05-0707 DRR 01-1235 DRR 01-1235 DRR 04-1414 DRR 04-1414 DRR 05-0707 DRR 05-0707 DRR 01-1235 DRR 01-1235 Amend. No. 123 DRR 02-1023 DRR 03-0860 DRR 04-1414 DRR 99-1624 DRR 02-0123 Amend. No. 123 DRR 99-1624 DRR 99-1624 4/11/11 12/18/99 12/18/99 2/16/05 2/16/05 2/16/05 2/16/05 5/18/06 2/16/05 3/5/10 3/5/10 2/16/05 2/16/05 2/16/05 11/16/11 9/2/09 4/8/08 2/16/05 2/16/05 9/2/09 9/2/09 9/2/09 9/2/09 9/2/09 9/2/09 9/2/09 12/18/99 10/12/00 12/18/99 12/18/99 12/18/99 9/19/01 4/20/05 9/19/01 9/19/01 10/12/04 10/12/04 4/20/05 4/20/05 9/19/01 9/19/01 12/18/99 2/28/02 7/10/03 10/12/04 12/18/99 2/28/02 12/18/99 12/18/99 12/18/99 Wolf Creek - Unit 1 V

Revision 60

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TAB - B 3.3 INSTRUMENTATION (continued)

B 3.3.5-4 1

DRR 99-1624 12/18/99 B 3.3.5-5 0

Amend. No. 123 12/18/99 B 3.3.5-6 22 DRR 05-1375 6/28/05 B 3.3.5-7 22 DRR 05-1375 6/28/05 B 3.3.6-1 0

Amend. No. 123 12/18/99 B 3.3.6-2 0

Amend. No. 123 12/18/99 B 3.3.6-3 0

Amend. No. 123 12/18/99 B 3.3.6-4 0

Amend. No. 123 12/18/99 B 3.3.6-5 0

Amend. No. 123 12/18/99 B 3.3.6-6 0

Amend. No. 123 12/18/99 B 3.3.6-7 0

Amend. No. 123 12/18/99 B 3.3.7-1 0

Amend. No. 123 12/18/99 B 3.3.7-2 57 DRR 13-0006 1/16/13 B 3.3.7-3 57 DRR 13-0006 1/16/13 B 3.3.7-4 0

Amend. No. 123 12/18/99 B 3.3.7-5 0

Amend. No. 123 12/18/99 B 3.3.7-6 57 DRR 13-0006 1/16/13 B 3.3.7-7 0

Amend. No. 123 12/18/99 B 3.3.7-8 0

Amend. No. 123 12/18/99 B 3.3.8-1 0

Amend. No. 123 12/18/99 B 3.3.8-2 0

Amend. No. 123 12/18/99 B 3.3.8-3 57 DRR 13-0006 1/16/13 B 3.3.8-4 57 DRR 13-0006 1/16/13 B 3.3.8-5 0

Amend. No. 123 12/18/99 B 3.3.8-6 24 DRR 06-0051 2/28/06 B 3.3.8-7 0

Amend. No. 123 12/18/99 TAB - B 3.4 B 3.4.1-1 B 3.4.1-2 B 3.4.1-3 B 3.4.1-4 B 3.4.1-5 B 3.4.1-6 B 3.4.2-1 B 3.4.2-2 B 3.4.2-3 B 3.4.3-1 B 3.4.3-2 B 3.4.3-3 B 3.4.3-4 B 3.4.3-5 B 3.4.3-6 B 3.4.3-7 B 3.4.4-1 B 3.4.4-2 B 3.4.4-3 B 3.4.5-1 B 3.4.5-2 B 3.4.5-3 B 3.4.5-4 REACTOR COOLANT SYSTEM (RCS) 0 10 10 0

0 0

0 29 0

0 53 29 0

Amend. No. 123 DRR 02-0411 DRR 02-0411 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 06-1984 Amend. No. 123 Amend. No. 123 DRR 11-1513 DRR 06-1984 Amend. No. 123 12/18/99 4/5/02 4/5/02 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 10/17/06 12/18/99 12/18/99 7/18/11 10/17/06 12/18/99 Wolf Creek - Unit 1 vi Revision 60

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TAB - B 3.4 REACTOR B 3.4.5-5 B 3.4.5-6 B 3.4.6-1 B 3.4.6-2 B 3.4.6-3 B 3.4.6-4 B 3.4.6-5 B 3.4.7-1 B 3.4.7-2 B 3.4.7-3 B 3.4.7-4 B 3.4.7-5 B 3.4.8-1 B 3.4.8-2 B 3.4.8-3 B 3.4.8-4 B 3.4.9-1 B 3.4.9-2 B 3.4.9-3 B 3.4.9-4 B 3.4.10-1 B 3.4.10-2 B 3.4.10-3 B 3.4.10-4 B 3.4.11-1 B 3.4.11-2 B 3.4.11-3 B 3.4.11-4 B 3.4.11-5 B 3.4.11-6 B 3.4.11-7 B 3.4.12-1 B 3.4.12-2 B 3.4.12-3 B 3.4.12-4 B 3.4.12-5 B 3.4.12-6 B 3.4.12-7 B 3.4.12-8 B 3.4.12-9 B 3.4.12-10 B 3.4.12-11 B 3.4.12-12 B 3.4.12-13 B 3.4.12-14 B 3.4.13-1 B 3.4.13-2 B 3.4.13-3 B 3.4.13-4 B 3.4.13-5 B 3.4.13-6 COOLANT SYSTEM (RCS) 12 12 53 29 12 12 12 12 17 42 42 12 53 42 42 42 0

0 0

0 5

5 0

32 0

1 19 0

1 0

32 56 56 0

56 56 56 56 1

56 0

56 32 0

32 0

29 29 35 35 29 (continued)

DRR 02-1062 DRR 02-1062 DRR 11-1513 DRR 06-1984 DRR 02-1062 DRR 02-1062 DRR 02-1062 DRR 02-1062 DRR 04-0453 DRR 09-1009 DRR 09-1009 DRR 02-1062 DRR 11-1513 DRR 09-1009 DRR 09-1009 DRR 09-1009 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 00-1427 DRR 00-1427 Amend. No. 123 DRR 07-0139 Amend. No. 123 DRR 99-1624 DRR 04-1414 Amend. No. 123 DRR 99-1624 Amend. No. 123 DRR 07-0139 DRR 12-1792 DRR 12-1792 Amend. No. 123 DRR 12-1792 DRR 12-1792 DRR 12-1792 DRR 12-1792 DRR 99-1624 DRR 12-1792 Amend. No. 123 DRR 12-1792 DRR 07-0139 Amend. No. 123 DRR 07-0139 Amend. No. 123 DRR 06-1984 DRR 06-1984 DRR 07-1553 DRR 07-1553 DRR 06-1984 9/26/02 9/26/02 7/18/11 10/17/06 9/26/02 9/26/02 9/26/02 9/26/02 5/26/04 7/16/09 7/16/09 9/26/02 7/18/11 7/16/09 7/16/09 7/16/09 12/18/99 12/18/99 12/18/99 12/18/99 10/12/00 10/12/00 12/18/99 2/7/07 12/18/99 12/18/99 10/12/04 12/18/99 12/18/99 12/18/99 2/7/07 11/7/12 11/7/12 12/18/99 11/7/12 11/7/12 11/7/12 11/7/12 12/18/99 11/7/12 12/18/99 11/7/12 2/7/07 12/18/99 2/7/07 12/18/99 10/17/06 10/17/06 9/28/07 9/28/07 10/17/06 Wolf Creek - Unit 1 vii Revfision 60

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TAB - B 3.4 REACTOR COOLANT SYSTEM (RCS) (continued)

B 3.4.14-1 0

Amend. No. 123 12/18/99 B 3.4.14-2 0

Amend. No. 123 12/18/99 B 3.4.14-3 0

Amend. No. 123 12/18/99 B 3.4.14-4 0

Amend. No. 123 12/18/99 B 3.4.14-5 32 DRR 07-0139 2/7/07 B 3.4.14-6 32 DRR 07-0139 2/7/07 B 3.4.15-1 31 DRR 06-2494 12/13/06 B 3.4.15-2 31 DRR 06-2494 12/13/06 B 3.4.15-3 33 DRR 07-0656 5/1/07 B 3.4.15-4 33 DRR 07-0656 5/1/07 B 3.4.15-5 31 DRR 06-2494 12/13/06 B 3.4.15-6 31 DRR 06-2494 12/13/06 B 3.4.15-7 31 DRR 06-2494 12/13/06 B 3.4.15-8 31 DRR 06-2494 12/13/06 B 3.4.16-1 31 DRR 06-2494 12/13/06 B 3.4.16-2 31 DRR 06-2494 12/13/06 B 3.4.16-3 31 DRR 06-2494 12/13/06 B 3.4.16-4 31 DRR 06-2494 12/13/06 B 3.4.16-5 31 DRR 06-2494 12/13/06 B 3.4.17-1 29 DRR 06-1984 10/17/06 B 3.4.17-2 58 DRR 13-0369 02/26/13 B 3.4.17-3 52 DRR 11-0724 4/11/11 B 3.4.17-4 57 DRR 13-0006 1/16/13 B 3.4.17-5 57 DRR 13-0006 1/16/13 B 3.4.17-6 57 DRR 13-0006 1/16/13 B 3.4.17-7 58 DRR 13-0369 02/26/13 TAB - B 3.5 B 3.5.1-1 B 3.5.1-2 B 3.5.1-3 B 3.5.1-4 B 3.5.1-5 B 3.5.1-6 B 3.5.1-7 B 3.5.1-8 B 3.5.2-1 B 3.5.2-2 B 3.5.2-3 B 3.5.2-4 B 3.5.2-5 B 3.5.2-6 B 3.5.2-7 B 3.5.2-8 B 3.5.2-9 B 3.5.2-10 B 3.5.2-11 B 3.5.3-1 B 3.5.3-2 B 3.5.3-3 B 3.5.3-4 EMERGENCY CORE COOLING SYSTEMS (ECCS) 0 Amend. No. 123 0

Amend. No. 123 0

Amend. No. 123 1

DRR 99-1624 1

DRR 99-1624 16 DRR 03-1497 1

DRR 99-1624 0

Amend. No. 123 0

Amend. No. 123 41 DRR 09-0288 42 DRR 09-1009 42 DRR 09-1009 38 DRR 08-0624 38 DRR 08-0624 41 DRR 09-0288 41 DRR 09-0288 56 DRR 12-1792 56 DRR 12-1792 56 DRR 12-1792 56 DRR 12-1792 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 11/4/03 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 3/20/09 7/16/09 7/16/09 5/1/08 5/1/08 3/20/09 3/20/09 11/7/12 11/7/12 11/7/12 11/7/12 Wolf Creek - Unit 1 viii Revision 60

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TAB - B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) (continued)

B 3.5.4-1 0

Amend. No. 123 12/18/99 B 3.5.4-2 0

Amend. No. 123 12/18/99 B 3.5.4-3 0

Amend. No. 123 12/18/99 B 3.5.4-4 0

Amend. No. 123 12/18/99 B 3.5.4-5 0

Amend. No. 123 12/18/99 B 3.5.4-6 26 DRR 06-1350 7/24/06 B 3.5.5-1 21 DRR 05-0707 4/20/05 B 3.5.5-2 21 DRR 05-0707 4/20/05 B 3.5.5-3 2

Amend. No. 132 4/24/00 B 3.5.5-4 21 DRR 05-0707 4/20/05 TAB - B 3.6 CONTAINMENT SYSTEMS B 3.6.1-1 0

B 3.6.1-2 0

B 3.6.1-3 0

B 3.6.1-4 17 B 3.6.2-1 0

B 3.6.2-2 0

B 3.6.2-3 0

B 3.6.2-4 0

B 3.6.2-5 0

B 3.6.2-6 0

B 3.6.2-7 0

B 3.6.3-1 0

B 3.6.3-2 0

B 3.6.3-3 0

B 3.6.3-4 49 B 3.6.3-5 49 B 3.6.3-6 49 B 3.6.3-7 41 B 3.6.3-8 36 B 3.6.3-9 36 B 3.6.3-10 8

B 3.6.3-11 36 B 3.6.3-12 36 B 3.6.3-13 50 B 3.6.3-14 36 B 3.6.3-15 39 B 3.6.3-16 39 B 3.6.3-17 36 B 3.6.3-18 36 B 3.6.3-19 36 B 3.6.4-1 39 B 3.6.4-2 0

B 3.6.4-3 0

B 3.6.5-1 0

B 3.6.5-2 37 B 3.6.5-3 13 B 3.6.5-4 0

B 3.6.6-1 42 B 3.6.6-2 0

Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 04-0453 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 11-0014 DRR 11-0014 DRR 11-0014 DRR 09-0288 DRR 08-0255 DRR 08-0255 DRR 01-1235 DRR 08-0255 DRR 08-0255 DRR 11-0449 DRR 08-0255 DRR 08-1096 DRR 08-1096 DRR 08-0255 DRR 08-0255 DRR 08-0255 DRR 08-1096 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 08-0503 DRR 02-1458 Amend. No. 123 DRR 09-1009 Amend. No. 123 12/18/99 12/18/99 12/18/99 5/26/04 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18199 12/18/99 1/31/11 1/31/11 1/31/11 3/20/09 3/11/08 3/11/08 9/19/01 3/11/08 3/11/08 3/9/11 3/11/08 8/28/08 8/28/08 3/11/08 3/11/08 3/11/08 8/28/08 12/18/99 12/18/99 12/18/99 4/8/08 12/03/02 12/18/99 7/16/09 12/18/99 Wolf Creek - Unit 1 ix Revision 60

LIST OF EFFECTIVE PAGES - TECHNICAL SPECIFICATION BASES PAGE (1)

REVISION NO. (2)

CHANGE DOCUMENT (3)

DATE EFFECTIVE/

IMPLEMENTED (4)

TAB - B 3.6 CONTAINMENT SYSTEMS (continued)

B 3.6.6-3 37 DRR 08-0503 4/8/08 B 3.6.6-4 42 DRR 09-1009 7/16/09 B 3.6.6-5 0

Amend. No. 123 12/18/99 B 3.6.6-6 18 DRR 04-1018 9/1/04 B 3.6.6-7 0

Amend. No. 123 12/18/99 B 3.6.6-8 32 DRR 07-0139 2/7/07 B 3.6.6-9 58 DRR 13-0369 2/26/13 B 3.6.7-1 0

Amend. No. 123 12/18/99 B 3.6.7-2 42 DRR 09-1009 7/16/09 B 3.6.7-3 0

Amend. No. 123 12/18/99 B 3.6.7-4 29 DRR 06-1984 10/17/06 B 3.6.7-5 42 DRR 09-1009 7/16/09 TAB - B 3.7 PLANT SYSTEMS B 3.7.1-1 B 3.7.1-2 B 3.7.1-3 B 3.7.1-4 B 3.7.1-5 B 3.7.1-6 B 3.7.2-1 B 3.7.2-2 B 3.7.2-3 B 3.7.2-4 B 3.7.2-5 B 3.7.2-6 B 3.7.2-7 B 3.7.2-8 B 3.7.2-9 B 3.7.2-10 B 3.7.2-11 B 3.7.3-1 B 3.7.3-2 B 3.7.3-3 B 3.7.3-4 B 3.7.3-5 B 3.7.3-6 B 3.7.3-7 B 3.7.3-8 B 3.7.3-9 B 3.7.3-10 B 3.7.3-11 B 3.7.4-1 B 3.7.4-2 B 3.7.4-3 B 3.7.4-4 B 3.7.4-5 B 3.7.5-1 0

0 0

0 32 32 44 44 44 44 44 44 44 44 44 44 44 37 50 37 37 37 37 37 37 37 38 37 1

1 19 19 1

54 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 07-0139 DRR 07-0139 DRR 09-1744 DRR 09-1744 DRR 09-1744 DRR 09-1744 DRR 09-1744 DRR 09-1744 DRR 09-1744 DRR 09-1744 DRR 09-1744 DRR 09-1744 DRR 09-1744 DRR 08-0503 DRR 11-0449 DRR 08-0503 DRR 08-0503 DRR 08-0503 DRR 08-0503 DRR 08-0503 DRR 08-0503 DRR 08-0503 DRR 08-0624 DRR 08-0503 DRR 99-1624 DRR 99-1624 DRR 04-1414 DRR 04-1414 DRR 99-1624 DRR 11-2394 12/18/99 12/18/99 12/18/99 12/18/99 2/7/07 2/7/07 10/28/09 10/28/09 10/28/09 10/28/09 10/28/09 10/28/09 10/28/09 10/28/09 10/28/09 10/28/09 10/28/09 4/8/08 3/9/11 4/8/08 4/8/08 4/8/08 4/8/08 4/8/08 4/8/08 4/8/08 5/1/08 4/8/08 12/18/99 12/18/99 10/12/04 10/12/04 12/18/99 11/16/11 Wolf Creek - Unit 1 X

Revision60

LIST OF EFFECTIVE PAGES - TECHNICAL SPECIFICATION BASES PAGE (1)

REVISION NO. (2)

CHANGE DOCUMENT (3)

DATE EFFECTIVE/

IMPLEMENTED (4)

TAB - B 3.7 PLANT SYSTEMS B 3.7.5-2 B 3.7.5-3 B 3.7.5-4 B 3.7.5-5 B 3.7.5-6 B 3.7.5-7 B 3.7.5-8 B 3.7.5-9 B 3.7.6-1 B 3.7.6-2 B 3.7.6-3 B 3.7.7-1 B 3.7.7-2 B 3.7.7-3 B 3.7.7-4 B 3.7.8-1 B 3.7.8-2 B 3.7.8-3 B 3.7.8-4 B 3.7.8-5 B 3.7.9-1 B 3.7.9-2 B 3.7.9-3 B 3.7.9-4 B 3.7.10-1 B 3.7.10-2 B 3.7.10-3 B 3.7.10-4 B 3.7.10-5 B 3.7.10-6 B 3.7.10-7 B 3.7.10-8 B 3.7.10-9 B 3.7.11-1 B 3.7.11-2 B 3.7.11-3 B 3.7.11-4 B 3.7.12-1 B 3.7.13-1 B 3.7.13-2 B 3.7.13-3 B 3.7.13-4 B 3.7.13-5 B 3.7.13-6 B 3.7.13-7 B 3.7.13-8 B 3.7.14-1 B 3.7.15-1 B 3.7.15-2 B 3.7.15-3 B 3.7.16-1 (continued) 54 0

60 44 44 32 14 32 0

0 0

0 1

0 0

0 3

3 3

3 41 41 41 41 57 57 57 41 41 0

57 57 0

0 24 1

42 57 57 57 57 1

0 0

5 DRR 11-2394 Amend. No. 123 DRR 13-2562 DRR 09-1744 DRR 09-1744 DRR 07-0139 DRR 03-0102 DRR 07-0139 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 99-1624 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 134 Amend. No. 134 Amend. No. 134 Amend. No. 134 DRR 09-0288 DRR 09-0288 DRR 09-0288 DRR 09-0288 DRR 13-0006 DRR 13-0006 DRR 13-0006 DRR 09-0288 DRR 09-0288 Amend. No. 123 DRR 13-0006 DRR 13-0006 Amend. No. 123 Amend. No. 123 DRR 06-0051 DRR 99-1624 DRR 09-1009 DRR 13-0006 DRR 13-0006 DRR 13-0006 DRR 13-0006 DRR 99-1624 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 00-1427 11/16/11 12/18/99 10/25/13 10/28/09 10/28/09 2/7/07 2/12/03 2/7/07 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 7/14/00 7/14/00 7/14/00 7/14/00 3/20/09 3/20/09 3/20/09 3/20/09 1/16/13 1/16/13 1/16/13 3/20/09 3/20/09 12/18/99 1/16/13 1/16/13 12/18/99 12/18/99 2/28/06 12/18/99 7/16/09 1/16/13 1/16/13 1/16/13 1/16/13 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 10/12/00 Wolf Creek - Unit 1 xi Reasion 60

LIST OF EFFECTIVE PAGES - TECHNICAL SPECIFICATION BASES PAGE (1)

REVISION NO. (2)

CHANGE DOCUMENT (3)

DATE EFFECTIVE/

IMPLEMENTED (4)

TAB - B 3.7 PLANT SYSTEMS (continued)

B 3.7.16-2 23 DRR 05-1995 9/28/05 B 3.7.16-3 5

DRR 00-1427 10/12/00 B 3.7.17-1 7

DRR 01-0474 5/1/01 B 3.7.17-2 7

DRR 01-0474 5/1/01 B 3.7.17-3 5

DRR 00-1427 10/12/00 B 3.7.18-1 0

Amend. No. 123 12/18/99 B 3.7.18-2 0

Amend. No. 123 12/18/99 B 3.7.18-3 0

Amend. No. 123 12/18/99 B 3.7.19-1 44 DRR 09-1744 10/28/09 B 3.7.19-2 54 DRR 11-2394 11/16/11 B 3.7.19-3 54 DRR 11-2394 11/16/11 B 3.7.19-4 54 DRR 11-2394 11/16/11 B 3.7.19-5 54 DRR 11-2394 11/16/11 B 3.7.19-6 54 DRR 11-2394 11/16/11 B 3.7.19-7 54 DRR 11-2394 11/16/11 TAB - B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.1-1 54 B 3.8.1-2 0

B 3.8.1-3 47 B 3.8.1-4 54 B 3.8.1-5 59 B 3.8.1-6 25 B 3.8.1-7 26 B 3.8.1-8 35 B 3.8.1-9 42 B 3.8.1-10 39 B 3.8.1-11 36 B 3.8.1-12 47 B 3.8.1-13 47 B 3.8.1-14 47 B 3.8.1-15 47 B 3.8.1-16 26 B 3.8.1-17 26 B 3.8.1-18 59 B 3.8.1-19 26 B 3.8.1-20 26 B 3.8.1-21 33 B 3.8.1-22 33 B 3.8.1-23 40 B 3.8.1-24 33 B 3.8.1-25 33 B 3.8.1-26 33 B 3.8.1-27 59 B 3.8.1-28 59 B 3.8.1-29 54 B 3.8.1-30 33 B 3.8.1-31 33 B 3.8.1-32 33 B 3.8.1-33 39 B 3.8.1-34 47 DRR 11-2394 Amend. No. 123 DRR 10-1089 DRR 11-2394 DRR 13-1524 DRR 06-0800 DRR 06-1350 DRR 07-1553 DRR 09-1009 DRR 08-1096 DRR 08-0255 DRR 10-1089 DRR 10-1089 DRR 10-1089 DRR 10-1089 DRR 06-1350 DRR 06-1350 DRR 13-1524 DRR 06-1350 DRR 06-1350 DRR 07-0656 DRR 07-0656 DRR 08-1846 DRR 07-0656 DRR 07-0656 DRR 07-0656 DRR 13-1524 DRR 13-1524 DRR 11-2394 DRR 07-0656 DRR 07-0656 DRR 07-0656 DRR 08-1096 DRR 10-1089 11/16/11 12/18/99 6/16/10 11/16/11 6/26/13 5/18/06 7/24/06 9/28/07 7/16/09 8/28/08 3/11/08 6/16/10 6/16/10 6/16/10 6/16/10 7/24/06 7/24/06 6/26/13 7/24/06 7/24/06 5/1/07 5/1/07 12/9/08 5/1/07 5/1/07 5/1/07 6/26/13 6/26/13 11/16/11 5/1/07 5/1/07 5/1/07 8/28/08 6/16/10 Wolf Creek - Unit 1 xii Revision 60

LIST OF EFFECTIVE PAGES - TECHNICAL SPECIFICATION BASES PAGE (1)

REVISION NO. (2)

CHANGE DOCUMENT (3)

DATE EFFECTIVE/

IMPLEMENTED (4)

TAB - B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.2-1 57 B 3.8.2-2 0

B 3.8.2-3 0

B 3.8.2-4 57 B 3.8.2-5 57 B 3.8.2-6 57 B 3.8.2-7 57 B 3.8.3-1 1

B 3.8.3-2 0

B 3.8.3-3 0

B 3.8.3-4 1

B 3.8.3-5 0

B 3.8.3-6 0

B 3.8.3-7 12 B 3.8.3-8 1

B 3.8.3-9 0

B 3.8.4-1 0

B 3.8.4-2 0

B 3.8.4-3 0

B 3.8.4-4 0

B 3.8.4-5 50 B 3.8.4-6 50 B 3.8.4-7 6

B 3.8.4-8 0

B 3.8.4-9 2

B 3.8.5-1 57 B 3.8.5-2 0

B 3.8.5-3 57 B 3.8.5-4 57 B 3.8.5-5 57 B 3.8.6-1 0

B 3.8.6-2 0

B 3.8.6-3 0

B 3.8.6-4 0

B 3.8.6-5 0

B 3.8.6-6 0

B 3.8.7-1 0

B 3.8.7-2 5

B 3.8.7-3 0

B 3.8.7-4 0

B 3.8.8-1 57 B 3.8.8-2 0

B 3.8.8-3 0

B 3.8.8-4 57 B 3.8.8-5 57 B 3.8.9-1 54 B 3.8.9-2 54 B 3.8.9-3 54 B 3.8.9-4 0

B 3.8.9-5 0

B 3.8.9-6 0

(continued)

DRR 13-0006 Amend. No. 123 Amend. No. 123 DRR 13-0006 DRR 13-0006 DRR 13-0006 DRR 13-0006 DRR 99-1624 Amend. No. 123 Amend. No. 123 DRR 99-1624 Amend. No. 123 Amend. No. 123 DRR 02-1062 DRR 99-1624 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 11-0449 DRR 11-0449 DRR 00-1541 Amend. No. 123 DRR 00-0147 DRR 13-0006 Amend. No. 123 DRR 13-0006 DRR 13-0006 DRR 13-0006 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 Amend. No. 123 DRR 00-1427 Amend. No. 123 Amend. No. 123 DRR 13-0006 Amend. No. 123 Amend. No. 123 DRR 13-0006 DRR 13-0006 DRR 11-2394 DRR 11-2394 DRR 11-2394 Amend. No. 123 Amend. No. 123 Amend. No. 123 1/16/13 12/18/99 12/18/99 1/16/13 1/16/13 1/16/13 1/16/13 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 9/26/02 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 3/9/11 3/9/11 3/13/01 12/18/99 4/24/00 1/16/13 12/18/99 1/16/13 1/16/13 1/16/13 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 12/18/99 10/12/00 12/18/99 12/18/99 1/16/13 12/18/99 12/18/99 1/16/13 1/16/13 11/16/11 11/16/11 11/16/11 12/18/99 12/18/99 12/18/99 Wolf Creek - Unit I xiii Revision 60

LIST OF EFFECTIVE PAGES - TECHNICAL SPECIFICATION BASES PAGE (1)

REVISION NO. (2)

CHANGE DOCUMENT (3)

DATE EFFECTIVE/

IMPLEMENTED (4)

TAB - B 3.8 ELECTRICAL POWER SYSTEMS (continued)

B 3.8.9-7 0

Amend. No. 123 12/18/99 B 3.8.9-8 1

DRR 99-1624 12/18/99 B 3.8.9-9 0

Amend. No. 123 12/18/99 B 3.8.10-1 57 DRR 13-0006 1/16/13 B 3.8.10-2 0

Amend. No. 123 12/18/99 B 3.8.10-3 0

Amend. No. 123 12/18/99 B 3.8.10-4 57 DRR 13-0006 1/16/13 B 3.8.10-5 57 DRR 13-0006 1/16/13 B 3.8.10-6 57 DRR 13-0006 1/16/13 TAB - B 3.9 REFUELING OPERATIONS B 3.9.1-1 0

Amend. No. 123 12/18/99 B 3.9.1-2 19 DRR 04-1414 10/12/04 B 3.9.1-3 19 DRR 04-1414 10/12/04 B 3.9.1-4 19 DRR 04-1414 10/12/04 B 3.9.2-1 0

Amend. No. 123 12/18/99 B 3.9.2-2 0

Amend. No. 123 12/18/99 B 3.9.2-3 0

Amend. No. 123 12/18/99 B 3.9.3-1 24 DRR 06-0051 2/28/06 B 3.9.3-2 51 DRR 11-0664 3/21/11 B 3.9.3-3 51 DRR 11-0664 3/21/11 B 3.9.3-4 53 DRR 11-1513 7/18/11 B 3.9.4-1 23 DRR 05-1995 9/28/05 B 3.9.4-2 13 DRR 02-1458 12/03/02 B 3.9.4-3 25 DRR 06-0800 5/18/06 B 3.9.4-4 23 DRR 05-1995 9/28/05 B 3.9.4-5 33 DRR 07-0656 5/1/07 B 3.9.4-6 23 DRR 05-1995 9/28/05 B 3.9.5-1 0

Amend. No. 123 12/18/99 B 3.9.5-2 32 DRR 07-0139 2/7/07 B 3.9.5-3 32 DRR 07-0139 2/7/07 B 3.9.5-4 32 DRR 07-0139 2/7/07 B 3.9.6-1 0

Amend. No. 123 12/18/99 B 3.9.6-2 42 DRR 09-1009 7/16/09 B 3.9.6-3 42 DRR 09-1009 7/16/09 B 3.9.6-4 42 DRR 09-1009 7/16/09 B 3.9.7-1 25 DRR 06-0800 5/18/06 B 3.9.7-2 0

Amend. No. 123 12/18/99 B 3.9.7-3 0

Amend. No. 123 12/18/99 Wolf Creek - Unit 1 xiV Revision 60

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REVISION NO. (2)

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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. Amendment No.

123 issued the improved Technical Specifications and associated Bases which affected each page. The NRC has indicated that Bases changes will not be issued with License Amendments. Therefore, the change document should be a DRR number in accordance with AP 26A-002.

Note 4 The date effective or implemented is the date the Bases pages are issued by Document Control.

Wolf Creek - Unit 1 XM Revision 60

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