Text

Edwin I. Hatch Nuclear Plant, Unit Nos. 1 and 2 - Issuance of Amendments Regarding Multiple Technical Specification Changes (CAC Nos. MF5026 and MF5027)
	ML16231A041
Person / Time
Site:	Hatch
Issue date:	09/29/2016
From:	Orenak M D; Plant Licensing Branch II
To:	Pierce C R; Southern Nuclear Operating Co
	Orenak M D, NRR/DORL/LPL2-1
References
	CAC MF5026, CAC MF5027
	Download: ML16231A041 (172)
	v • d • e

Mr. Charles R. Pierce Regulatory Affairs Director UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 Septanber '29, 2016 Southern Nuclear Operating Company, Inc. P.O. Box 1295 I Bin 038 Birmingham, AL 35201-1295

SUBJECT:

EDWIN I. HATCH NUCLEAR PLANT, UNIT NOS. 1AND2 -ISSUANCE OF AMENDMENTS REGARDING MULTIPLE TECHNICAL SPECIFICATION CHANGES (CAC NOS. MF5026 AND MF5027)

Dear Mr. Pierce:

The U.S. Nuclear Regulatory Commission (NRC or the Commission) has issued the enclosed Amendment No. 279 to Renewed Facility Operating License No. DPR-57 and Amendment No. 223 to Renewed Facility Operating License No. NPF-5 for the Edwin I. Hatch Nuclear Plant (HNP), Unit Nos. 1 and 2, respectively. The amendments consist of changes to the Technical Specifications (TSs) in response to your application dated October 10, 2014, as supplemented by letters dated May 4, 2015, October 15, 2015, and August 26, 2016. The amendments revise Technical Specifications (TSs) by adopting 18 previously NRG-approved Technical Specifications Task Force (TSTF) travelers, two TSTF T-travelers, and one feature of the Improved Standard Technical Specifications (ISTS) not associated with a traveler. Southern Nuclear Operating Company, Inc. (SNC) stated that these changes would increase the consistency between the HNP TSs, the ISTS for Boiling Water Reactor/4 plants (NUREG-1433), and the TSs of the other plants in the SNC fleet.

C.R. Pierce A copy of the related Safety Evaluation is also enclosed. Notice of Issuance will be included in the Commission's biweekly Federal Register notice. Docket Nos. 50-321 and 50-366

Enclosures:

1. Amendment No. 279 to DPR-57 2. Amendment No. 223 to NPF-5 3. Safety Evaluation cc w/enclosures: Distribution via Listserv Michael D. Orenak, Project Manager Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SOUTHERN NUCLEAR OPERATING COMPANY, INC. GEORGIA POWER COMPANY OGLETHORPE POWER CORPORATION MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA CITY OF DAL TON, GEORGIA DOCKET NO. 50-321 EDWIN I. HATCH NUCLEAR PLANT, UNIT NO. 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 279 Renewed License No. DPR-57 1. The Nuclear Regulatory Commission (the Commission) has found that: A. The application for amendment to the Edwin I. Hatch Nuclear Plant, Unit No. 1 (the facility) Renewed Facility Operating License No. DPR-57 filed by Southern Nuclear Operating Company, Inc. (the licensee), acting for itself; Georgia Power Company; Oglethorpe Power Corporation; Municipal Electric Authority of Georgia; and City of Dalton, Georgia (the owners), dated October 10, 2014, as supplemented by letters dated May 4, 2015, October 15, 2015, and August 26, 2016, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations as set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and Enclosure 1 E. The issuance of this amendment is in accordance with 1 O CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied. 2. Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. DPR-57 is hereby amended to read as follows: (2) Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 279, are hereby incorporated in the license. Southern Nuclear shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan. 3. This license amendment is effective as of its date of issuance and shall be implemented within 120 days from the date of issuance.

Attachment:

Changes to Renewed DPR-57 and Technical Specifications Date of Issuance: Septanber '29, 2016 FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation ATTACHMENT TO LICENSE AMENDMENT NO. 279 EDWIN I. HATCH NUCLEAR PLANT, UNIT NO. 1 RENEWED FACILITY OPERATING LICENSE NO. DPR-57 DOCKET NO. 50-321 Replace the following pages of the License and the Appendix A, Technical Specifications (TSs), with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change. Remove Pages License 4 TSs 1.3-2 1.3-6 1.3-7 1.4-1 1.4-2 1.4-3 1.4-5 3.1-10 3.1-17 3.3-4 3.3-5 3.3-7 3.3-16 3.3-25 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55 3.5-1 3.5-2 3.6-8 3.6-9 3.6-11 Insert Pages License 4 TSs 1.3-2 1.3-6 1.3-7 1.4-1 1.4-2 1.4-3 1.4-5 1.4-6 1.4-7 3.1-10 3.1-17 3.3-4 3.3-5 3.3-7 3.3-16 3.3-25 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55a 3.3-55b 3.5-1 3.5-2 3.6-8 3.6-9 3.6-11 3.6-22 3.6-23 3.6-35 3.6-36 3.6-37 3.6-38 3.6-39 3.6-40 3.8-2 3.8-4 3.8-10 3.8-11 3.8-12 3.8-13 3.8-14 3.8-15 3.8-16 3.8-17 3.8-18 3.8-29 3.8-30 3.8-37 5.0-9 5.0-10 5.0-13 5.0-14 5.0-15 3.6-22 3.6-23 3.6-35 3.6-36 3.6-37 3.6-38 3.6-39 3.6-40 3.8-2 3.8-4 3.8-10 3.8-11 3.8-12 3.8-13 3.8-14 3.8-15 3.8-16 3.8-17 3.8-18 3.8-29 3.8-30 3.8-37 5.0-9 5.0-10 5.0-13 5.0-14 5.0-15 for sample analysis or instrumentation calibration, or associated with radioactive apparatus or components; (6) Southern Nuclear, pursuant to the Act and 10 CFR Parts 30 and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility. (C) This renewed license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I; Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Section 50.54 of Part 50, and Section 70.32 of Part 70; all applicable provisions of the Act and the rules, regulations, and orders of the Commission now or hereafter in effect; and the additional conditions specified or incorporated below: (1) Maximum Power Level Southern Nuclear is authorized to operate the facility at steady sate reactor core power levels not in excess of 2804 megawatts thermal. (2) Technical Specifications The Technical Specifications (Appendix A) and the Environmental Plan (Appendix B), as revised through Amendment No. 279 are hereby incorporated in the renewed license. Southern Nuclear shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan. The Surveillance Requirement (SR) contained in the Technical Specifications and listed below, is not required to be performed immediately upon implementation of Amendment No. 195. The SR listed below shall be successfully demonstrated before the time and condition specified: SR 3.8.1.18 shall be successfully demonstrated at its next regularly scheduled performance. (3) Fire Protection Southern Nuclear shall implement and maintain in effect all provisions of the fire protection program, which is referenced in the Updated Final Safety Analysis Report for the facility, as contained in the updated Fire Hazards Analysis and Fire Protection Program for the Edwin I. Hatch Nuclear Plant, Units 1 and 2, which was originally submitted by letter dated July 22, 1986. Southern Nuclear may make changes to the fire protection program without prior Commission approval only if the changes Renewed License No. DPR-57 Amendment No. 279 Completion Times 1.3 1.3 Completion Times DESCRIPTION (continued) HATCH UNIT 1 a. Must exist concurrent with the first inoperability; and b. Must remain inoperable or not within limits after the first inoperability is resolved. The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either: a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; or b. The stated Completion Time as measured from discovery of the subsequent inoperability. The above Completion Time extension does not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each division, subsystem, component or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications. The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e., "once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery ... " 1.3-2 (continued) Amendment No. 279 1.3 Completion Times EXAMPLES (continued) HATCH UNIT 1 EXAMPLE 1.3-3 ACTIONS CONDITION A. One Function X subsystem inoperable. B. One Function Y subsystem inoperable. C. One Function X subsystem inoperable. AND One Function Y subsystem inoperable. REQUIRED ACTION A.1 Restore Function X subsystem to OPERABLE status. B.1 Restore Function Y subsystem to OPERABLE status. C.1 Restore Function X subsystem to OPERABLE status. OR C.2 Restore Function Y subsystem to OPERABLE status. 1.3-6 Completion Times 1.3 COMPLETION TIME 7 days 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 72 hours 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued) Amendment No. 279 Completion Times 1.3 1.3 Completion Times EXAMPLES HATCH UNIT 1 EXAMPLE 1.3-3 (continued) When one Function X subsystem and one Function Y subsystem are inoperable, Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each subsystem, starting from the time each subsystem was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second subsystem was declared inoperable (i.e., the time the situation described in Condition C was discovered). If Required Action C.2 is completed within the specified Completion Time, Conditions Band C are exited. If the Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected subsystem was declared inoperable (i.e., initial entry into Condition A). It is possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. However, doing so would be inconsistent with the basis of the Completion Times. Therefore, there shall be administrative controls to limit the maximum time allowed for any combination of Conditions that result in a single contiguous occurrence of failing to meet the LCO. These administrative controls shall ensure that the Completion Times for those Conditions are not inappropriately extended. (continued) 1.3-7 Amendment No. 279 Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE DESCRIPTION HATCH UNIT 1 The purpose of this section is to define the proper use and application of Frequency requirements. Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated Limiting Conditions for Operation (LCO). An understanding of the correct application of the specified Frequency is necessary for compliance with the SR. The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR) Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each SR, as well as certain Notes in the Surveillance column that modify performance requirements. Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are "otherwise stated" conditions allowed by SR 3.0.1. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillance, or both. Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction. The use of "met" or "performed" in these instances conveys specific meanings. A Surveillance is "met" only when the acceptance criteria are satisfied. Known failure of the requirements of a Surveillance, even without a Surveillance specifically being "performed," constitutes a Surveillance not "met." "Performance" refers only to the requirement to specifically determine the ability to meet the acceptance criteria. Some surveillances contain notes that modify the Frequency of performance or the conditions during which the acceptance criteria must be satisfied. For these Surveillances, the MODE-entry restrictions of SR 3.0.4 may not apply. Such a Surveillance is not required to be performed prior to entering a MODE or other specified condition in the Applicability of the associated LCO if any of the following three conditions are satisfied: (continued) 1.4-1 Amendment No. 279 1.4 Frequency DESCRIPTION (continued) EXAMPLES HATCH UNIT 1 Frequency 1.4 a. The Surveillance is not required to be met in the MODE or other specified condition to be entered; or b. The Surveillance is required to be met in the MODE or other specified condition to be entered, but has been performed within the specified Frequency (i.e., it is current) and is known not to be failed; or c. The Surveillance is required to be met, but not performed, in the MODE or other specified condition to be entered, and is known not to be failed. Examples 1.4-3, 1.4-4, 1.4-5, and 1.4-6 discuss these special situations. The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the LCO (LCO not shown) is MODES 1, 2, and 3. EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time. Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the interval specified in the Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Examples 1.4-3 and 1.4-4), then SR 3.0.3 becomes applicable. (continued) 1.4-2 Amendment No. 279 1.4 Frequency EXAMPLES HATCH UNIT 1 EXAMPLE 1.4-1 (continued) Frequency 1.4 If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, then SR 3.0.4 becomes applicable. The Surveillance must be performed within the Frequency requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the mode or other specified condition or the LCO is considered not met (in accordance with SR 3.0.1) and LCO 3.0.4 becomes applicable. EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE Verify flow is within limits. FREQUENCY Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after <::: 25% RTP 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level < 25% RTP to<::: 25% RTP, the Surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND"). This type of Frequency does not qualify for the extension allowed by SR 3.0.2. "Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to < 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25% RTP. (continued) 1.4-3 Amendment No. 279 1.4 Frequency EXAMPLES (continued) HATCH UNIT 1 EXAMPLE 1.4-4 SURVEILLANCE REQUIREMENTS SURVEILLANCE ------------------------------N()TE---------------------------()n ly required to be met in M()DE 1. Verify leakage rates are within limits. Frequency 1.4 FREQUENCY 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-4 specifies that the requirements of this Surveillance do not have to be met until the unit is in M()DE 1. The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance. Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (plus the extension allowed by SR 3.0.2) interval, but the unit was not in M()DE 1, there would be no failure of the SR nor failure to meet the LC(). Therefore, no violation of SR 3.0.4 occurs when changing M()DES, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the M()DE change was not made into M()DE 1. Prior to entering M()DE 1 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR. EXAMPLE 1.4-5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY ------------------------------N()TE---------------------------()nly required to be performed in M()DE 1. Perform complete cycle of the valve. 7 days The interval continues, whether or not the unit operation is in M()DE 1, 2, or 3 (the assigned Applicability of the associated LC()) between performances. (continued) 1.4-5 Amendment No. 279 1.4 Frequency EXAMPLES HATCH UNIT 1 EXAMPLE 1.4-5 (continued) Frequency 1.4 As the Note modifies the required performance of the Surveillance, the Note is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is not in MODE 1, this Note allows entry into and operation in MODES 2 and 3 to perform the Surveillance. The Surveillance is still considered to be performed within the "specified Frequency" if completed prior to entering MODE 1. Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was not in MODE 1, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not result in entry into MODE 1. Once the unit reaches MODE 1, the requirement for the Surveillance to be performed within its specified Frequency applies and would require that the Surveillance had been performed. If the Surveillance were not performed prior to entering MODE 1, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply. EXAMPLE 1.4-6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY ------------------------------NOTE---------------------------Not required to be met in MODE 3. Verify parameter is within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-6 specifies that the requirements of this Surveillance do not have to be met while the unit is in MODE 3 (the assumed Applicability of the associated LCO is MODES 1, 2, and 3). The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance. Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by SR 3.0.2), and the unit was in MODE 3, there would be no failure of the SR nor failure to meet the LCO. Therefore, no (continued) 1.4-6 Amendment No. 279 1.4 Frequency EXAMPLES HATCH UNIT 1 EXAMPLE 1.4-6 (continued) Frequency 1.4 violation of SR 3.0.4 occurs when changing MODES to enter MODE 3, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change does not result in entry into MODE 2. Prior to entering MODE 2 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR. 1.4-7 Amendment No. 279 Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS -----------------------------------------------------------N 0 TE------------------------------------------------------------0 u ring single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator. SR 3.1.4.1 SR 3.1.4.2 SR 3.1.4.3 SR 3.1.4.4 HATCH UNIT 1 SURVEILLANCE Verify each control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure<::: 800 psig. Verify, for a representative sample, each tested control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure <::: 800 psig. Verify each affected control rod scram time is within the limits of Table 3.1.4-1 with any reactor steam dome pressure. Verify each affected control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure<::: 800 psig. 3.1-10 FREQUENCY Prior to exceeding 40% RTP after each reactor shutdown <::: 120 days In accordance with the Surveillance Frequency Control Program Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect scram time Prior to exceeding 40% RTP after fuel movement within the affected core cell Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time Amendment No. 279 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Standby Liquid Control (SLC) System LCO 3.1.7 Two SLC subsystems shall be OPERABLE. APPLICABILITY: MODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION A. Sodium pentaborate A.1 Restore sodium solution not within pentaborate solution to Region A limits of within Region A limits. Figure 3.1.7-1 or 3.1.7-2, but within the Region B limits. B. One SLC subsystem B.1 Restore SLC inoperable for reasons subsystem to other than Condition A. OPERABLE status. C. Two SLC subsystems C.1 Restore one SLC inoperable for reasons subsystem to other than Condition A. OPERABLE status. D. Required Action and D.1 Be in MODE 3. associated Completion Time not met. HATCH UNIT 1 3.1-17 SLC System 3.1.7 COMPLETION TIME 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 7 days 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 12 hours Amendment No. 279 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.1.1.2 SR 3.3.1.1.3 SR 3.3.1.1.4 SR 3.3.1.1.5 SR 3.3.1.1.6 HATCH UNIT 1 SURVEILLANCE ------------------------------N 0 TE----------------------------N ot required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL 24% RTP. Verify the absolute difference between the average power range monitor (APRM) channels and the calculated power is s 2% RTP while operating 24% RTP. (Not used.) ----------------------------N 0 TE------------------------------N ot required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2. Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL FUNCTIONAL TEST. (Not used.) 3.3-4 RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE SR 3.3.1.1.7 (Not used.) SR 3.3.1.1.8 Calibrate the local power range monitors. SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.1.1.10 ----------------------------NOTE------------------------------For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2. ------------------------------------------------------------------Perform CHANNEL FUNCTIONAL TEST. SR 3.3.1.1.11 Verify Turbine Stop Valve -Closure and Turbine Control Valve Fast Closure, Trip Oil Pressure -Low Functions are not bypassed when THERMAL POWER 27.6% RTP. SR 3.3.1.1.12 Perform CHANNEL FUNCTIONAL TEST. HATCH UNIT 1 3.3-5 RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program ( cont1 n ued) Amendment No. 279 FUNCTION 1. Intermediate Range Monitor a. Neutron Flux -High b. lnop 2. Average Power Range Monitor a. Neutron Flux -High (Setdown) b. Simulated Thermal Power-High c. Neutron Flux -High d. lnop Table 3.3.1.1-1(page1 of3) Reactor Protection System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS 2 5(a) 2 5(a) 2 1, 2 REQUIRED CHANNELS PER TRIP SYSTEM 2(d) 2(d) 2(d) 2(d) 3(c) 3(c) 3(c) 3(c) CONDITIONS REFERENCED FROM REQUIRED ACTION D.1 G H G H G F F G (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies. RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SR 3.3.1.1.1 SR 3.3.1.1.4 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.1 SR 3.3.1.1.5 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.4 SR 3.3.1.1.15 SR 3.3.1.1.5 SR 3.3.1.1.15 SR 3.3.1.1.1 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.1 SR 3.3.1.1.2 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.1 SR 3.3.1.1.2 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.10 ALLOWABLE VALUE ::; 120/125 divisions of full scale ::; 120/125 divisions of full scale NA NA => 20% RTP => 0.57W+ 56.8% RTP and :>115.5% RTP(b) s 120% RTP NA continued (b) 0.57W + 56.8% -0.57 tiW RTP when reset for single loop operation per LCO 3.4.1, "Recirculation Loops Operating." (c) Each APRM channel provides inputs to both trip systems. (d) One channel in each quadrant of the core must be OPERABLE whenever the IRMs are required to be OPERABLE. Both the RWM and a second licensed operator must verify compliance with the withdrawal sequence when less than three channels in any trip system are OPERABLE. HATCH UNIT 1 3.3-7 Amendment No. 279 ACTIONS CONDITION C. (continued) D. RWM inoperable during reactor shutdown. E. One or more Reactor Mode Switch -Shutdown Position channels inoperable. HATCH UNIT 1 Control Rod Block Instrumentation 3.3.2.1 REQUIRED ACTION COMPLETION TIME C.2.1.2 Verify by administrative Immediately methods that startup with RWM inoperable has not been performed in the last 12 months. AND C.2.2 Verify movement of During control rod control rods is in movement compliance with banked position withdrawal sequence (BPWS) by a second licensed operator or other qualified member of the technical staff. D.1 Verify movement of During control rod control rods is in movement compliance with BPWS by a second licensed operator or other qualified member of the technical staff. E.1 Suspend control rod Immediately withdrawal. AND E.2 Initiate action to fully Immediately insert all insertable control rods in core cells containing one or more fuel assemblies. 3.3-16 Amendment No. 279 Table 3.3.3.1-1(page1of1) Post Accident Monitoring Instrumentation REQUIRED FUNCTION CHANNELS 1. Reactor Steam Dome Pressure 2 2. Reactor Vessel Water Level a. -317 inches to -17 inches 2 b. -150 inches to +60 inches 2 c. 0 inches to +60 inches 2 d. 0 inches to +400 inches 1 3. Suppression Pool Water Level a. 0 inches to 300 inches 2 b. 133 inches to 163 inches 2 4. Drywell Pressure a. -1 O psig to +90 psig 2 b. -5 psig to +5 psig 2 C. 0 psig to +250 psig 2 5. Drywell Area Radiation (High Range) 2 6. Penetration Flow Path Primary Containment Isolation 2 per penetration flow Valve Position path (a)(b) 7. (Deleted) 8. (Deleted) 2(C) 9. Suppression Pool Water Temperature 6 10. Drywell Temperature in Vicinity of Reactor Level Instrument Reference Leg 11. Diesel Generator (DG) Parameters 1 per DG a. Output Voltage 1 per DG b. Output Current 1 per DG c. Output Power 1 per DG d. Battery Voltage 2 12. RHR Service Water Flow PAM Instrumentation 3.3.3.1 CONDITIONS REFERENCED FROM REQUIRED ACTION D.1 E E E E NA E E E E E F E E E NA NA NA NA E (a) Not required for isolation valves whose associated penetration flow path is isolated by at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured. (b) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel. (c) Monitoring each of four quadrants. HATCH UNIT 1 3.3-25 Amendment No. 279 Primary Containment Isolation Instrumentation 3.3.6.1 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment Isolation Instrumentation LCO 3.3.6.1 The primary containment isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE. APPLICABILITY: According to Table 3.3.6.1-1. ACTIONS ----------------------------------------------------------N 0 TES-----------------------------------------------------------1 . Penetration flow paths except for 18 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls. 2. Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for channels inoperable. Functions 2.a, 2.b, 6.b, 7.a, and 7.b AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 2.a, 2.b, 6.b, 7.a, and 7.b B. ---------------N 0 TE-------------B.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Not applicable for capability. Function 5.c. ------------------------------------One or more automatic Functions with isolation capability not maintained. C. Required Action and C.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A or B Table 3.3.6.1-1 for the not met. channel. (continued) HATCH UNIT 1 3.3-48 Amendment No. 279 ACTIONS (continued) CONDITION D. As required by Required Action C.1 and referenced in Table 3.3.6.1-1. E. As required by Required Action C.1 and referenced in Table 3.3.6.1-1. F. As required by Required Action C.1 and referenced in Table 3.3.6.1-1. G. As required by Required Action C.1 and referenced in Table 3.3.6.1-1. H. As required by Required Action C.1 and referenced in Table 3.3.6.1-1. OR Required Action and associated Completion Time of Condition F or G not met. HATCH UNIT 1 D.1 OR D.2.1 Primary Containment Isolation Instrumentation 3.3.6.1 REQUIRED ACTION COMPLETION TIME Isolate associated main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months steam line (MSL). Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND D.2.2 Be in MODE4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months F.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months penetration flow path(s). G.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months penetration flow path(s). H.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND H.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) 3.3-49 Amendment No. 279 ACTIONS (continued) CONDITION I. As required by Required 1.1 Action C.1 and referenced in Table 3.3.6.1-1. OR 1.2 J. As required by Required J.1 Action C.1 and referenced in Table 3.3.6.1-1. OR J.2 SURVEILLANCE REQUIREMENTS Primary Containment Isolation Instrumentation 3.3.6.1 REQUIRED ACTION COMPLETION TIME Declare Standby Liquid 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Control (SLC) System inoperable. Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup (RWCU) System. Initiate action to restore Immediately channel to OPERABLE status. Initiate action to isolate Immediately the Residual Heat Removal (RHR) Shutdown Cooling System. ----------------------------------------------------------N 0 TES-----------------------------------------------------------1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment Isolation Function. 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains isolation capability. SURVEILLANCE SR 3.3.6.1.1 Perform CHANNEL CHECK. HATCH UNIT 1 3.3-50 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.6.1.3 Perform CHANNEL CALIBRATION. SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. HATCH UNIT 1 3.3-51 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 279 I Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of 5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 1. Main Steam Line Isolation a. Reactor Vessel Water Level -1,2,3 2 D SR 3.3.6.1.1 <: -113 inches Low Low Low, Level 1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 b. Main Steam Line Pressure -2 E SR 3.3.6.1.3 <= 825 psig Low SR 3.3.6.1.6 c. Main Steam Line 1,2,3 2 per D SR 3.3.6.1.1 ::; 138% rated Flow-High MSL SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6 d. Condenser Vacuum -Low 1, 2 D SR 3.3.6.1.3 <: 7 inches Hg 2(a), 3(a) SR 3.3.6.1.6 vacuum e. Main Steam Tunnel 1,2,3 6 D SR 3.3.6.1.1 :5194°F Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 f. Turbine Building Area 1,2,3 16(b) D SR 3.3.6.1.2 ::; 200°F Temperature -High SR 3.3.6.1.5 SR 3.3.6.1.6 2. Primary Containment Isolation a. Reactor Vessel Water Level 1,2,3 2 H SR 3.3.6.1.1 <: 0 inches -Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 b. Drywell Pressure -High 1,2,3 2 H SR 3.3.6.1.1 ::; 1.92 psig I SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 continued (a) With any turbine stop valve not closed. (b) With 8 channels per trip string. Each trip string shall have 2 channels per main steam line, with no more than 40 ft separating any two OPERABLE channels. HATCH UNIT 1 3.3-52 Amendment No. 279 Primary Containment Isolation Instrumentation 3.3.6.1 Table3.3.6.1-1 (page2of5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 2. Primary Containment Isolation (continued) C. Drywell Radiation -1,2,3 F SR 3.3.6.1.1 s 138 R/hr High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 d. Reactor Building Exhaust 1,2,3 2 H SR 3.3.6.1.1 s 80 mR/hr I Radiation -High SR 3.3.6.1.3 SR 3.3.6.1.6 e. Refueling Floor Exhaust 1,2,3 2 H SR 3.3.6.1.1 s 80 mR/hr I Radiation -High SR 3.3.6.1.3 SR 3.3.6.1.6 3. High Pressure Coolant Injection (HPCI) System Isolation a. HPCI Steam Line Flow -1,2,3 F SR 3.3.6.1.1 s 303% rated High SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6 b. HPCI Steam Supply Line 1,2,3 2 F SR 3.3.6.1.1 <! 100 psig Pressure -Low SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 c. HPCI Turbine Exhaust 1,2,3 2 F SR 3.3.6.1.1 s 20 psig Diaphragm Pressure -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 d. Drywell Pressure -High 1,2,3 F SR 3.3.6.1.1 s 1.92 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 e. HPCI Pipe Penetration Roorr 1,2,3 F SR 3.3.6.1.1 s 169°F Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 f. Suppression Pool Area 1,2,3 F SR 3.3.6.1.1 s 169°F Ambient Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 continued HATCH UNIT 1 3.3-53 Amendment No. 279 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 3. HPCI System Isolation (continued) g. Suppression Pool Area 1,2,3 F SR 3.3.6.1.4 :;; 16 minutes Temperature -Time Delay SR 3.3.6.1.6 15 seconds Relays h. Suppression Pool Area 1,2,3 F SR 3.3.6.1.1 :;; 42°F Differential Temperature -SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6 i. Emergency Area Cooler 1,2,3 F SR 3.3.6.1.1 :;; 169°F Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 4. Reactor Core Isolation Cooling (RCIC) System Isolation a. RCIC Steam Line Flow -1,2,3 F SR 3.3.6.1.1 :;; 306% rated High SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6 b. RCIC Steam Supply Line 1,2,3 2 F SR 3.3.6.1.1 2! 60 psig Pressure -Low SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 C. RCIC Turbine Exhaust 1,2,3 2 F SR 3.3.6.1.1 :;; 20 psig Diaphragm Pressure -SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6 d. Drywell Pressure -High 1,2,3 F SR 3.3.6.1.1 :;; 1.92 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 e. RCIC Suppression Pool 1,2,3 F SR 3.3.6.1.1 :;; 169°F Ambient Area SR 3.3.6.1.2 Temperature -High SR 3.3.6.1.5 SR 3.3.6.1.6 f. Suppression Pool Area 1,2,3 F SR 3.3.6.1.4 :;; 31 minutes Temperature -Time Delay SR 3.3.6.1.6 15 seconds Relays continued HATCH UNIT 1 3.3-54 Amendment No. 279 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 4 of 5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 4. RCIC System Isolation (continued) g. RCIC Suppression Pool 1,2,3 F SR 3.3.6.1.1 :S 42°F Area Differential SR 3.3.6.1.2 Temperature -High SR 3.3.6.1.5 SR 3.3.6.1.6 h. Emergency Area Cooler 1,2,3 F SR 3.3.6.1.1 :S 169°F Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 5. RWCU System Isolation a. Area Temperature -High 1,2,3 1 per area F SR 3.3.6.1.1 :S 150°F SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 b. Area Ventilation 1,2,3 1 per area F SR 3.3.6.1.1 :S 67°F Differential Temperature -SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6 c. SLC System Initiation 1,2 1(C) SR 3.3.6.1.6 NA d. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 <: -47 inches Level -Low Low, Level 2 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 6. RHR Shutdown Cooling System Isolation a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.1 :S 145 psig Pressure -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 b. Reactor Vessel Water 3,4,5 2 (d) J SR 3.3.6.1.1 <: 0 inches Level -Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 (continued) (c) SLC System Initiation only inputs into one of the two trip systems. (d) Only one trip system required in MODES 4 and 5 when RHR Shutdown Cooling System integrity maintained. HATCH UNIT 1 3.3-55a Amendment No. 279 FUNCTION 7. Traversing lncore Probe System Isolation a. Reactor Vessel Water Level -Low, Level 3 b. Drywell Pressure -High HATCH UNIT 1 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 5 of 5) Primary Containment Isolation Instrumentation APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS 1,2,3 1,2,3 REQUIRED CHANNELS PER TRIP SYSTEM 2 2 3.3-55b CONDITIONS REFERENCED FROM REQUIRED ACTION C.1 G G SURVEILLANCE REQUIREMENTS SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 ALLOWABLE VALUE 2! 0 inches s 1.92 psig Amendment No. 279 ECCS -Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS -Operating LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System (ADS) function of six of seven safety/relief valves shall be OPERABLE. APPLICABILITY: MODE 1, MODES 2 and 3, except high pressure coolant injection (HPCI) and ADS valves are not required to be OPERABLE with reactor steam dome pressure s 150 psig. ACTIONS ----------------------------------------------------------N 0 TE-------------------------------------------------------------L CO 3.0.4.b is not applicable to HPCI. CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7 days injection/spray subsystem ECCS injection/spray inoperable. subsystem(s) to OPERABLE status. OR One LPCI pump in both LPCI subsystems inoperable. B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not AND met. B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) HATCH UNIT 1 3.5-1 Amendment No. 279 ACTIONS (continued) CONDITION C. HPCI System inoperable. D. HPCI System inoperable. AND Condition A entered. E. Two or more ADS valves inoperable. OR Required Action and associated Completion Time of Condition C or D not met. F. Two or more low pressure ECCS injection/spray subsystems inoperable for reasons other than Condition A. OR HPCI System and two or more ADS valves inoperable. HATCH UNIT 1 REQUIRED ACTION C.1 Verify by administrative means RCIC System is OPERABLE. AND C.2 Restore HPCI System to OPERABLE status. D.1 Restore HPCI System to OPERABLE status. OR D.2 Restore low pressure ECCS injection/spray subsystem to OPERABLE status. E.1 Be in MODE 3. AND E.2 Reduce reactor steam dome pressure to =:;; 150 psig. F.1 Enter LCO 3.0.3. 3.5-2 ECCS -Operating 3.5.1 COMPLETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 14 days 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 72 hours 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours Immediately Amendment No. 279 ACTIONS CONDITION REQUIRED ACTION A. (continued) A.2 ------------N 0 TES-----------1. Isolation devices in high radiation areas may be verified by use of administrative means. 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. --------------------------------Verify the affected penetration flow path is isolated. B. -------------N 0 TE---------------B.1 Isolate the affected Only applicable to penetration flow path by penetration flow paths with use of at least one two PCIVs. closed and de-activated ------------------------------------automatic valve, closed manual valve, or blind One or more penetration flange. flow paths with two PCIVs inoperable except due to leakage not within limit. HATCH UNIT 1 3.6-8 PC I Vs 3.6.1.3 COMPLETION TIME Once per 31 days for isolation devices outside primary containment AND Prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days, for isolation devices inside primary containment 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months (continued) Amendment No. 279 ACTIONS (continued) CONDITION C. ---------------N 0 TE-------------C.1 Only applicable to penetration flow paths with only one PCIV. -------------------------------------One or more penetration flow paths with one PCIV inoperable except due to leakage not within limits. AND C.2 D. One or more penetration D.1 flow paths with leakage not within limit. E. Required Action and E.1 associated Completion Time of Condition A, B, C, AND or D not met in MODE 1, 2, or 3. E.2 HATCH UNIT 1 REQUIRED ACTION Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. -----------NOTES----------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. --------------------------------Verify the affected penetration flow path is isolated. Restore leakage to within limit. Be in MODE 3. Be in MODE 4. 3.6-9 PC I Vs 3.6.1.3 COMPLETION TIME 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except for excess flow check valve (EFCV) line and penetrations with a closed system AND 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for EFCV line and penetrations with a closed system Once per 31 days 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) Amendment No. 279 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.1.3.2 SR 3.6.1.3.3 SR 3.6.1.3.4 SR 3.6.1.3.5 HATCH UNIT 1 SURVEILLANCE ------------------------------N 0 TES---------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls. Verify each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. -----------------------------N 0 TES----------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls. Verify each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Verify continuity of the traversing incore probe (Tl P) shear isolation valve explosive charge. Verify the isolation time of each power operated, automatic PCIV, except for MSIVs, is within limits. 3.6-11 PC I Vs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program Prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program (continued) Amendment No. 279 ACTIONS (continued) CONDITION B. Required Action and B.1 associated Completion Time of Condition A not met. C. Suppression pool average C.1 temperature> 105°F. AND Any OPERABLE IRM channel > 25/40 divisions of full scale on Range 7. AND Performing testing that adds heat to the suppression pool. D. Suppression pool average D.1 temperature> 110°F. AND D.2 AND D.3 HATCH UNIT 1 Suppression Pool Average Temperature 3.6.2.1 REQUIRED ACTION COMPLETION TIME Reduce THERMAL 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months POWER until all OPERABLE IRM channels s 25/40 divisions of full scale on Range 7. Suspend all testing that Immediately adds heat to the suppression pool. Place the reactor mode Immediately switch in the shutdown position. Determine suppression Once per 30 minutes pool average temperature. Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) 3.6-22 Amendment No. 279 Suppression Pool Average Temperature 3.6.2.1 ACTIONS (continued) CONDITION E. Suppression pool average temperature > 120°F. SURVEILLANCE REQUIREMENTS E.1 REQUIRED ACTION Depressurize the reactor vessel to < 200 psig. SURVEILLANCE SR 3.6.2.1.1 HATCH UNIT 1 Verify suppression pool average temperature is within the applicable limits. 3.6-23 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months FREQUENCY In accordance with the Surveillance Frequency Control Program 5 minutes when performing testing that adds heat to the suppression pool Amendment No. 279 ACTIONS CONDITION REQUIRED ACTION C. (continued) C.2 AND C.3 Suspend CORE ALTERATIONS. Initiate action to suspend OPDRVs. SURVEILLANCE REQUIREMENTS SR 3.6.4.1.1 SR 3.6.4.1.2 SR 3.6.4.1.3 HATCH UNIT 1 SURVEILLANCE Verify all secondary containment equipment hatches are closed and sealed. Verify one secondary containment access door in each access opening is closed. -----------------------------NOTE-----------------------------The number of standby gas treatment (SGT) subsystem(s) required for this Surveillance is dependent on the secondary containment configuration, and shall be one less than the number required to meet LCO 3.6.4.3, "Standby Gas Treatment (SGT) System," for the given configuration. Verify secondary containment can be drawn down to 0.20 inch of vacuum water gauge in s 120 seconds using required standby gas treatment (SGT) subsystem(s). 3.6-35 Secondary Containment 3.6.4.1 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS continued SR 3.6.4.1.4 HATCH UNIT 1 SURVEILLANCE -----------------------------N 0 TE------------------------------Th e number of SGT subsystem(s) required for this Surveillance is dependent on the secondary containment configuration, and shall be one less than the number required to meet LCO 3.6.4.3, "Standby Gas Treatment (SGT) System," for the given configuration. Verify the secondary containment can be maintained ;;:: 0.20 inch of vacuum water gauge for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months using required SGT subsystem(s) at a flow 4000 cfm per subsystem. 3.6-36 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 279 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) LCO 3.6.4.2 APPLICABILITY: ACTIONS Each SCIV shall be OPERABLE. MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS, During operations with a potential for draining the reactor vessel (OPDRVs). SCI Vs 3.6.4.2 ----------------------------------------------------------NOTES-------------------------------------------------------------1. Penetration flow paths may be unisolated intermittently under administrative controls. 2. Separate Condition entry is allowed for each penetration flow path. 3. Enter applicable Conditions and Required Actions for systems made inoperable by SCIVs. CONDITION A. One or more penetration flow paths with one SCIV inoperable. HATCH UNIT 1 REQUIRED ACTION COMPLETION TIME A.1 Isolate the affected 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months penetration flow path by use of at least one closed and deactivated automatic valve, closed manual valve, or blind flange. AND A.2 -----------NOTES-----------1. Isolation devices in high radiation areas may be verified by use of administrative means. 3.6-37 (continued) Amendment No. 279 ACTIONS CONDITION A. (continued) B. One or more penetration B.1 flow paths with two SCIVs inoperable. C. Required Action and C.1 associated Completion Time of Condition A or B AND not met in MODE 1, 2, or 3. C.2 D. Required Action and D.1 associated Completion Time of Condition A or B not met during movement of irradiated fuel assemblies in the secondary containment, during CORE ALTERATIONS, or during OPDRVs. HATCH UNIT 1 REQUIRED ACTION 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. ---------------------------------Verify the affected penetration flow path is isolated. Isolate the affected penetration flow path by use of at least one closed and deactivated automatic valve, closed manual valve, or blind flange. Be in MODE 3. Be in MODE4. -------------N 0 TE-----------LCO 3.0.3 is not applicable. --------------------------------Suspend movement of irradiated fuel assemblies in the secondary containment. 3.6-38 SCI Vs 3.6.4.2 COMPLETION TIME Once per 31 days 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Immediately (continued) Amendment No. 279 ACTIONS CONDITION REQUIRED ACTION D. (continued) AND D.2 D.3 Suspend CORE ALTERATIONS. Initiate action to suspend OPDRVs. SURVEILLANCE REQUIREMENTS SR 3.6.4.2.1 SR 3.6.4.2.2 SR 3.6.4.2.3 HATCH UNIT 1 SURVEILLANCE ----------------------------N 0 TES----------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for SCIVs that are open under administrative controls. Verify each secondary containment isolation manual valve and blind flange that is not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Verify the isolation time of each power operated, automatic SCIV is within limits. Verify each automatic SCIV actuates to the isolation position on an actual or simulated actuation signal. 3.6-39 SCI Vs 3.6.4.2 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 279 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System SGT System 3.6.4.3 LCO 3.6.4.3 The Unit 1 and Unit 2 SGT subsystems required to support LCO 3.6.4.1, "Secondary Containment," shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TERA TIONS, During operations with a potential for draining the reactor vessel (OPDRVs). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required Unit 1 SGT A.1 Restore required Unit 1 30 days from subsystem inoperable SGT subsystem to discovery of failure to while: OPERABLE status. meet the LCO 1. Four SGT subsystems required OPERABLE, and 2. Unit 1 reactor building-to-refueling floor plug not installed. B. One required Unit 2 SGT B.1 Restore required SGT 7 days subsystem inoperable. subsystem to OPERABLE status. OR One required Unit 1 SGT subsystem inoperable for reasons other than Condition A. (continued) HATCH UNIT 1 3.6-40 Amendment No. 279 ACTIONS AC Sources -Operating 3.8.1 ----------------------------------------------------------N 0 TE-------------------------------------------------------------L CO 3.0.4.b is not applicable to DGs. CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite circuit A.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. OPERABLE required offsite circuits. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Declare required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from discovery feature(s) with no offsite of no offsite power to power available one 4160 V ESF bus inoperable when the concurrent with redundant required inoperability of feature(s) are redundant required inoperable. feature(s) AND A.3 Restore required offsite 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months circuit to OPERABLE status. B. One Unit 1 or the swing B.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months DG inoperable. OPERABLE required offsite circuit(s). AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND (continued) HATCH UNIT 1 3.8-2 Amendment No. 279 ACTIONS CONDITION REQUIRED ACTION B. (continued) B.4 (continued) C. One required Unit 2 DG C.1 Perform SR 3.8.1.1 for inoperable OPERABLE required off site circuit( s). AND C.2 Declare required feature(s), supported by the inoperable DG, inoperable when the redundant required feature(s) are inoperable. AND C.3.1 Determine OPERABLE DG(s) are not inoperable due to common cause failure. OR C.3.2 Perform SR 3.8.1.2.a for OPERABLE DG(s). HATCH UNIT 1 3.8-4 AC Sources -Operating 3.8.1 COMPLETION TIME AND 14 days for the swing diesel with maintenance restrictions met 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery of Condition C concurrent with inoperability of redundant required feature(s) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 24 hours (continued) Amendment No. 279 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.1.6 SR 3.8.1.7 HATCH UNIT 1 SURVEILLANCE -----------------------------NOTE------------------------------This Surveillance shall not normally be performed in MODE 1 or 2. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify automatic and manual transfer of unit power supply from the normal offsite circuit to the alternate offsite circuit. ----------------------------N 0 TES-----------------------------1. This Surveillance shall not normally be performed in MODE 1 or 2, except for the swing DG. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. For the swing DG, this Surveillance shall not be performed in MODE 1 or 2 using the Unit 1 controls. Credit may be taken for unplanned events that satisfy this SR. 2. For the swing DG, a single test at the specified Frequency will satisfy this Surveillance for both units. Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and: a. Following load rejection, the frequency is s 65.5 Hz; and b. Within 3 seconds following load rejection, the voltage 3740 V ands 4580 V. 3.8-10 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SR 3.8.1.8 HATCH UNIT 1 SURVEILLANCE ---------------------------NOTES------------------------------1. This Surveillance shall not normally be performed in MODE 1 or 2, except for the swing DG. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. For the swing DG, this Surveillance shall not be performed in MODE 1 or 2 using the Unit 1 controls. Credit may be taken for unplanned events that satisfy this SR. 2. If grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable. 3. For the swing DG, a single test at the specified Frequency will satisfy this Surveillance for both units. Verify each DG operating at a power factor s 0.88 does not trip and voltage is maintained s 4800 V during and following a load rejection of<:: 2775 kW. 3.8-11 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SR 3.8.1.9 HATCH UNIT 1 SURVEILLANCE ----------------------------N 0 TES-----------------------------1 . All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated loss of offsite power signal: a. De-energization of emergency buses; b. Load shedding from emergency buses; and c. DG auto-starts from standby condition and: 1. Energizes permanently connected loads in :s; 12 seconds, 2. Energizes auto-connected shutdown loads through automatic load sequence timing devices, 3. Maintains steady state voltage 3740 V and :s; 4243 V, 4. Maintains steady state frequency 58.8 Hz and :s; 61.2 Hz, and 5. Supplies permanently connected and auto-connected shutdown loads for 5 minutes. 3.8-12 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SR 3.8.1.10 HATCH UNIT 1 SURVEILLANCE ----------------------------N 0 TES-----------------------------1. All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated Emergency Core Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and: a. Ins 12 seconds after auto-start achieves 3740 V, and after steady state conditions are reached, maintains voltage 3740 V ands 4243 V; b. In s 12 seconds after auto-start achieves 58.8 Hz, and after steady state conditions are reached, maintains 58.8 Hz and s 61.2 Hz; and c. Operates for 5 minutes. 3.8-13 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.11 ---------------------------N 0 TE--------------------------------HATCH UNIT 1 T his Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify each DG's non-critical automatic trips are bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ECCS initiation signal. 3.8-14 In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SR 3.8.1.12 HATCH UNIT 1 SURVEILLANCE ----------------------------N 0 TES-----------------------------1. Momentary transients outside the load and power factor ranges do not invalidate this test. 2. This Surveillance shall not normally be performed in MODE 1 or 2, unless the other two DGs are OPERABLE. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. If either of the other two DGs becomes inoperable, this surveillance shall be suspended. Credit may be taken for unplanned events that satisfy this SR. 3. If grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable. 4. For the swing DG, a single test at the specified Frequency will satisfy this Surveillance for both units. Verify each DG operating at a power factors 0.88 operates for 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: a. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 3000 kW; and b. For the remaining hours of the test loaded 2775 kW and s 2825 kW. 3.8-15 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.1.13 SR 3.8.1.14 HATCH UNIT 1 SURVEILLANCE -----------------------------N 0 TES----------------------------1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2565 kW. Momentary transients outside of load range do not invalidate this test. 2. All DG starts may be preceded by an engine prelube period. 3. For the swing DG, a single test at the specified Frequency will satisfy this Surveillance for both units. Verify each DG starts and achieves, in s 12 seconds, 3740 V and frequency 58.8 Hz; and after steady state conditions are reached, maintains 3740 V ands 4243 V and 58.8 Hz and s 61.2 Hz. ----------------------------N 0 TE-------------------------------T his Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY providec an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify each DG: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power; b. Transfers loads to offsite power source; and c. Returns to ready-to-load operation. 3.8-16 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.1.15 SR 3.8.1.16 HATCH UNIT 1 SURVEILLANCE ----------------------------N 0 TE-------------------------------T his Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify with a DG operating in test mode and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by: a. Returning DG to ready-to-load operation; and b. Automatically energizing the emergency load from offsite power. -----------------------------N 0 TE------------------------------Th is Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify interval between each sequenced load block is within +/- 10% of design interval for each load sequence timing device. 3.8-17 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.17 -----------------------------N 0 TES----------------------------HATCH UNIT 1 1 . All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify, on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal: a. De-energization of emergency buses; b. Load shedding from emergency buses; and c. DG auto-starts from standby condition and: 1. Energizes permanently connected loads in s 12 seconds, 2. Energizes auto-connected emergency loads through automatic load sequence timing devices, 3. Achieves steady state voltage 3740 V ands 4243 V, 4. Achieves steady state frequency 58.8 Hz and s 61.2 Hz, and 5. Supplies permanently connected and auto-connected emergency loads 5 minutes. 3.8-18 In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.4.6 SURVEILLANCE Verify each required battery charger supplies ;:: 400 amps for station service subsystems, and ;:: 100 amps for DG subsystems at ;:: 129 V for ;:: 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . DC Sources -Operating 3.8.4 FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.8.4.7 -----------------------------N 0 TES----------------------------HATCH UNIT 1 1. The modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7. 2. This Surveillance shall not normally be performed in MODE 1, 2, or 3, except for the swing DG battery. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test. 3.8-29 In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 279 DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.4.8 SR 3.8.4.9 HATCH UNIT 1 SURVEILLANCE -----------------------------N 0 TE------------------------------T his Surveillance shall not normally be performed in MODE 1, 2, or 3, except for the swing DG battery. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify battery capacity 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test. For required Unit 2 DC sources, the SRs of Unit 2 Specification 3.8.4 are applicable. 3.8-30 FREQUENCY In accordance with the Surveillance Frequency Control Program 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturer's rating 24 months when battery has reached 85% of expected life with capacity 100% of manufacturer's rating In accordance with applicable SRs Amendment No. 279 ACTIONS (continued) CONDITION B. One or more (Unit 1 or swing bus) DG DC electrical power distribution subsystems inoperable. C. One or more (Unit 1 or swing bus) AC electrical power distribution subsystems inoperable. D. One Unit 1 station service DC electrical power distribution subsystem inoperable. E. Required Action and associated Completion Time of Condition A, B, C, or D not met. F. Two or more electrical power distribution subsystems inoperable that result in a loss of function. HATCH UNIT 1 B.1 C.1 D.1 E.1 AND E.2 F.1 Distribution Systems -Operating 3.8.7 REQUIRED ACTION COMPLETION TIME Restore DG DC 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months electrical power distribution subsystem to OPERABLE status. Restore AC electrical 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months power distribution subsystem to OPERABLE status. Restore Unit 1 station 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months service DC electrical power distribution subsystem to OPERABLE status. Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Enter LCO 3.0.3. Immediately 3.8-37 Amendment No. 279 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued) c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 1 O CFR 20.1302 and with the methodology and parameters in the ODCM; d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 1 O CFR 50, Appendix I; e. Determination of cumulative dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days. Determination of projected dose contributions from radioactive effluents in accordance with the methodology in the ODCM at least every 31 days; f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I; g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents to areas beyond the site boundary as follows: 1) For noble gases, less than or equal to a dose rate of 500 mrem/year to the total body and less than or equal to a dose rate of 3000 mrem/year to the skin, and 2) For iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half-lives greater than 8 days, less than or equal to a dose rate of 1500 mrem/year to any organ; h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and j. Limitations on the annual dose or dose commitment to any member of the public due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190. HATCH UNIT 1 5.0-9 (continued) Amendment No. 279 5.5 Programs and Manuals (continued) 5.5.5 Component Cyclic or Transient Limit Programs and Manuals 5.5 This program provides controls to track FSAR Section 4.2, cyclic and transient occurrences, to ensure that reactor coolant pressure boundary components are maintained within the design limits. 5.5.6 lnservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports. a. Testing frequencies specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda are as follows: ASME Boiler and Pressure Vessel Code and Applicable Addenda Terminology for lnservice Testing Activities Weekly Monthly Quarterly or every 3 months Semiannually or every 6 months Yearly or annually Required Frequencies for Performing lnservice Testing Activities At least once per 7 days At least once per 31 days At least once per 92 days At least once per 184 days At least once per 366 days b. The provisions of SR 3.0.2 are applicable to the frequencies for performing inservice testing activities; c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and d. Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any Technical Specification. 5.5.7 Ventilation Filter Testing Program (VFTP) A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2, Sections C.5.c and C.5.d, and in accordance with Regulatory Guide 1.52, Revision 2. (continued) HATCH UNIT 1 5.0-10 Amendment No. 279 5.5 Programs and Manuals Programs and Manuals 5.5 5.5.8 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued) The program shall include: a. The limits for the concentrations of hydrogen in the main condenser offgas treatment system and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion); and b. A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the liquid radwaste treatment system is less than the amount that would result in concentrations less than the limits of 1 O CFR 20, Appendix B, Table 2, Column 2, at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tanks' contents. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies. 5.5.9 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following: a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has: 1. An API gravity or an absolute specific gravity within limits, 2. A flash point and kinematic viscosity within limits for ASTM 20 fuel oil, and 3. A water and sediment content within limits; b. Within 31 days following addition of the new fuel oil to storage tanks, verify that the properties of the new fuel oil, other than those addressed in a., above, are within limits for ASTM 20 fuel oil; and (continued) HATCH UNIT 1 5.0-13 Amendment No. 279 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Diesel Fuel Oil Testing Program (continued) 5.5.10 c. Total particulate concentration of the fuel oil is 10 mg/liter when tested every 92 days. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program surveillance frequencies. Safety Function Determination Program (SFDP) This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory actions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following: a. Provisions for cross division checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected; b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists; c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and d. Other appropriate limitations and remedial or compensatory actions. A loss of safety function exists when, assuming no concurrent single failure, no concurrent loss of offsite power or no concurrent loss of onsite diesel generator(s), a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and: a. A required system redundant to system(s) supported by the inoperable support system is also inoperable; or b. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or c. A required system redundant to support system(s) for the supported systems (a) and (b) above is also inoperable. (continued) HATCH UNIT 1 5.0-14 Amendment No. 279 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 5.5.11 Safety Function Determination Program (SFDP) (continued) The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. When a loss of safety function is caused by inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system. Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications. a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews. b. Licensees may make changes to Bases without prior NRG approval provided the changes do not require either of the following: 1. A change in the TS incorporated in the license; or 2. A change to the updated FSAR or Bases that requires NRG approval pursuant to 10 CFR 50.59. c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR. d. Proposed changes that meet the criteria of item b above shall be reviewed and approved by the NRG prior to implementation. Changes to the Bases implemented without prior NRG approval shall be provided to the NRG on a frequency consistent with 10 CFR 50.71(e). (continued) HATCH UNIT 1 5.0-15 Amendment No. 279 UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SOUTHERN NUCLEAR OPERATING COMPANY, INC. GEORGIA POWER COMPANY OGLETHORPE POWER CORPORATION MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA CITY OF DAL TON, GEORGIA DOCKET NO. 50-366 EDWIN I. HATCH NUCLEAR PLANT, UNIT NO. 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 223 Renewed License No. NPF-5 1. The Nuclear Regulatory Commission (the Commission) has found that: A. The application for amendment to the Edwin I. Hatch Nuclear Plant, Unit No. 2 (the facility) Renewed Facility Operating License No. NPF-5 filed by Southern Nuclear Operating Company, Inc. (the licensee), acting for itself; Georgia Power Company; Oglethorpe Power Corporation; Municipal Electric Authority of Georgia; and City of Dalton, Georgia (the owners), dated October 10, 2014, as supplemented by letters dated May 4, 2015, October 15, 2015, and August 26, 2016, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations as set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and Enclosure 2 E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied. 2. Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-5 is hereby amended to read as follows: (2) Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 223 are hereby incorporated in the license. Southern Nuclear shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan. 3. This license amendment is effective as of its date of issuance and shall be implemented within 120 days from the date of issuance.

Attachment:

Changes to Renewed NPF-5 and Technical Specifications Date of Issuance: Septenber 29, Xl16 FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation ATTACHMENT TO LICENSE AMENDMENT NO. 223 EDWIN I. HATCH NUCLEAR PLANT, UNIT NO. 2 RENEWED FACILITY OPERATING LICENSE NO. NPF-5 DOCKET NO. 50-366 Replace the following pages of the License and the Appendix A, Technical Specifications (TSs), with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change. Remove Pages License 4 TSs 1.3-2 1.3-6 1.3-7 1.4-1 1.4-2 1.4-3 1.4-5 3.1-10 3.1-17 3.3-4 3.3-5 3.3-7 3.3-16 3.3-25 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55 3.5-1 3.5-2 3.6-8 3.6-9 3.6-11 Insert Pages License 4 TSs 1.3-2 1.3-6 1.3-7 1.4-1 1.4-2 1.4-3 1.4-5 1.4-6 1.4-7 3.1-10 3.1-17 3.3-4 3.3-5 3.3-7 3.3-16 3.3-25 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55a 3.3-55b 3.5-1 3.5-2 3.6-8 3.6-9 3.6-11 3.6-22 3.6-23 3.6-34 3.6-35 3.6-36 3.6-37 3.6-38 3.6-40 3.8-2 3.8-4 3.8-10 3.8-11 3.8-12 3.8-13 3.8-14 3.8-15 3.8-16 3.8-17 3.8-18 3.8-29 3.8-30 3.8-38 5.0-9 5.0-10 5.0-13 5.0-14 5.0-15 3.6-22 3.6-23 3.6-34 3.6-35 3.6-36 3.6-37 3.6-38 3.6-40 3.8-2 3.8-4 3.8-10 3.8-11 3.8-12 3.8-13 3.8-14 3.8-15 3.8-16 3.8-17 3.8-18 3.8-29 3.8-30 3.8.38 5.0-9 5.0-10 5.0-13 5.0-14 5.0-15 (6) Southern Nuclear, pursuant to the Act and 1 O CFR Parts 30 and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility. (C) This renewed license shall be deemed to contain, and is subject to, the conditions specified in the following Commission regulations in 10 CFR Chapter I: Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Section 50.54 of Part 50, and Section 70.32 of Part 70; all applicable provisions of the Act and the rules, regulations, and orders of the Commission now or hereafter in effect; and the additional conditions2 specified or incorporated below: (1) Maximum Power Level Southern Nuclear is authorized to operate the facility at steady sate reactor core power levels not in excess of 2,804 megawatts thermal, in accordance with the conditions specified herein. (2) Technical Specifications The Technical Specifications (Appendix A) and the Environmental Protection Plan (Appendix B); as revised through Amendment No. 223 are hereby incorporated in the renewed license. Southern Nuclear shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan. (3) Additional Conditions The matters specified in the following conditions shall be completed to the satisfaction of the Commission within the stated time periods following the issuance of the renewed license or within the operational restrictions indicated. The removal of these conditions shall be made by an amendment to the license supported by a favorable evaluation by the Commission. (a) Fire Protection Southern Nuclear shall implement and maintain in effect all provisions of the fire protection program, which is referenced in the Updated Final Safety Analysis Report for the facility, as contained 2 The original licensee authorized to possess, use, and operate the facility with Georgia Power Company (GPC). Consequently, certain historical references to GPC remain in certain license conditions. Renewed License No. NPF-5 Amendment No. 223 Completion Times 1.3 1.3 Completion Times DESCRIPTION (continued) HATCH UNIT 2 a. Must exist concurrent with the first inoperability; and b. Must remain inoperable or not within limits after the first inoperability is resolved. The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either: a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; or b. The stated Completion Time as measured from discovery of the subsequent inoperability. The above Completion Time extension does not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each division, subsystem, component or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications. The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e., "once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery ... " (continued) 1.3-2 Amendment No. 223 1.3 Completion Times EXAMPLES (continued) HATCH UNIT 2 EXAMPLE 1.3-3 ACTIONS CONDITION A. One Function X subsystem inoperable. B. One Function Y subsystem inoperable. C. One Function X subsystem inoperable. AND One Function Y subsystem inoperable. REQUIRED ACTION A.1 Restore Function X subsystem to OPERABLE status. B.1 Restore Function Y subsystem to OPERABLE status. C.1 Restore Function X subsystem to OPERABLE status. OR C.2 Restore Function Y subsystem to OPERABLE status. 1.3-6 Completion Times 1.3 COMPLETION TIME 7 days 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 72 hours 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued) Amendment No. 223 Completion Times 1.3 1.3 Completion Times EXAMPLES HATCH UNIT 2 EXAMPLE 1.3-3 (continued) When one Function X subsystem and one Function Y subsystem are inoperable, Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each subsystem, starting from the time each subsystem was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second subsystem was declared inoperable (i.e., the time the situation described in Condition C was discovered). If Required Action C.2 is completed within the specified Completion Time, Conditions Band Care exited. If the Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected subsystem was declared inoperable (i.e., initial entry into Condition A). It is possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. However, doing so would be inconsistent with the basis of the Completion Times. Therefore, there shall be administrative controls to limit the maximum time allowed for any combination of Conditions that result in a single contiguous occurrence of failing to meet the LCO. These administrative controls shall ensure that the Completion Times for those Conditions are not inappropriately extended. (continued) 1.3-7 Amendment No. 223 Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE DESCRIPTION HATCH UNIT 2 The purpose of this section is to define the proper use and application of Frequency requirements. Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated Limiting Conditions for Operation (LCO). An understanding of the correct application of the specified Frequency is necessary for compliance with the SR. The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR) Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each SR, as well as certain Notes in the Surveillance column that modify performance requirements. Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are "otherwise stated" conditions allowed by SR 3.0.1. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillance, or both. Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction. The use of "met" or "performed" in these instances conveys specific meanings. A Surveillance is "met" only when the acceptance criteria are satisfied. Known failure of the requirements of a Surveillance, even without a Surveillance specifically being "performed," constitutes a Surveillance not "met." "Performance" refers only to the requirement to specifically determine the ability to meet the acceptance criteria. Some Surveillances contain notes that modify the Frequency of performance or the conditions during which the acceptance criteria must be satisfied. For these Surveillances, the MODE-entry restrictions of SR 3.0.4 may not apply. Such a Surveillance is not required to be performed prior to entering a MODE or other specified condition in the Applicability of the associated LCO if any of the following three conditions are satisfied: (continued) 1.4-1 Amendment No. 223 1.4 Frequency DESCRIPTION (continued) EXAMPLES HATCH UNIT 2 Frequency 1.4 a. The Surveillance is not required to be met in the MODE or other specified condition to be entered; or b. The Surveillance is required to be met in the MODE or other specified condition to be entered, but has been performed within the specified Frequency (i.e., it is current) and is known not to be failed; or c. The Surveillance is required to be met, but not performed, in the MODE or other specified condition to be entered, and is known not to be failed. Examples 1.4-3, 1.4-4, 1.4-5, and 1.4-6 discuss these special situations. The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the LCO (LCO not shown) is MODES 1, 2, and 3. EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time. Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the interval specified in the Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Examples 1.4-3 and 1.4-4), then SR 3.0.3 becomes applicable. (continued) 1.4-2 Amendment No. 223 1.4 Frequency EXAMPLES HATCH UNIT 2 EXAMPLE 1.4-1 (continued) Frequency 1.4 If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, then SR 3.0.4 becomes applicable. The surveillance must be performed within the Frequency requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the mode or other specified condition or the LCO is considered not met (in accordance with SR 3.0.1) and LCO 3.0.4 becomes applicable. EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE Verify flow is within limits. FREQUENCY Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after ;:: 25% RTP 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level < 25% RTP to;:: 25% RTP, the Surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND"). This type of Frequency does not qualify for the extension allowed by SR 3.0.2. "Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to < 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25% RTP. (continued) 1.4-3 Amendment No. 223 I 1.4 Frequency EXAMPLES (continued) HATCH UNIT 2 EXAMPLE 1.4-4 SURVEILLANCE REQUIREMENTS SURVEILLANCE ------------------------------N 0 TE-----------------------------0 n ly required to be met in MODE 1. Verify leakage rates are within limits. Frequency 1.4 FREQUENCY 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-4 specifies that the requirements of this Surveillance do not have to be met until the unit is in MODE 1. The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance. Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (plus the extension allowed by SR 3.0.2) interval, but the unit was not in MODE 1, there would be no failure of the SR nor failure to meet the LCO. Therefore, no violation of SR 3.0.4 occurs when changing MODES, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change was not made into MODE 1. Prior to entering MODE 1 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR. EXAMPLE 1.4-5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY ------------------------------N 0 TE-----------------------------0 n I y required to be performed in MODE 1. Perform complete cycle of the valve. 7 days The interval continues, whether or not the unit operation is in MODE 1, 2, or 3 (the assumed Applicability of the associated LCO) between performances. (continued) 1.4-5 Amendment No. 223 1.4 Frequency EXAMPLES HATCH UNIT 2 EXAMPLE 1.4-5 (continued) Frequency 1.4 As the Note modifies the required performance of the Surveillance, the Note is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is not in MODE 1, this Note allows entry into and operation in MODES 2 and 3 to perform the Surveillance. The Surveillance is still considered to be performed within the "specified Frequency" if completed prior to entering MODE 1. Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was not in MODE 1, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not result in entry into MODE 1 . Once the unit reaches MODE 1, the requirement for the Surveillance to be performed within its specified Frequency applies and would require that the Surveillance had been performed, If the Surveillance were not performed prior to entering MODE 1, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply. EXAMPLE 1.4-6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY ------------------------------N 0 TE-----------------------------N ot required to be met in MODE 3. Verify parameter is within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-6 specifies that the requirements of this Surveillance do not have to be met while the unit is in MODE 3 (the assumed Applicability of the associated LCO is MODES 1, 2, and 3). The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance. Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by SR 3.0.2), and the unit was in MODE 3, there would be no failure of the SR nor failure to meet the LCO. Therefore, no (continued) 1.4-6 Amendment No. 223 1.4 Frequency EXAMPLES (continued) HATCH UNIT 2 EXAMPLE 1.4-6 Frequency 1.4 violation of SR 3.0.4 occurs when changing MODES to enter MODE 3, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change does not result in entry into MODE 2. Prior to entering MODE 2 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR. 1.4-7 Amendment No. 223 Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS -----------------------------------------------------------N 0 TE------------------------------------------------------------0 u ring single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator. SR 3.1.4.1 SR 3.1.4.2 SR 3.1.4.3 SR 3.1.4.4 HATCH UNIT 2 SURVEILLANCE Verify each control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome 800 psig. Verify, for a representative sample, each tested control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure 800 psig. Verify each affected control rod scram time is within the limits of Table 3.1.4-1 with any reactor steam dome pressure. Verify each affected control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome 800 psig. 3.1-10 FREQUENCY Prior to exceeding 40% RTP after each reactor shutdown 120 days In accordance with the Surveillance Frequency Control Program Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect scram time Prior to exceeding 40% RTP after fuel movement within the affected core cell Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time Amendment No. 223 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Standby Liquid Control (SLC) System LCO 3.1.7 Two SLC subsystems shall be OPERABLE. APPLICABILITY: MODES 1 and 2. ACTIONS CONDITION REQUIRED ACTION A. Sodium pentaborate A.1 Restore sodium solution not within pentaborate solution to Region A limits of within Region A limits. Figure 3.1.7-1or3.1.7-2, but within the Region B limits. B. One SLC subsystem B.1 Restore SLC inoperable for reasons subsystem to other than Condition A. OPERABLE status. C. Two SLC subsystems C.1 Restore one SLC inoperable for reasons subsystem to other than Condition A. OPERABLE status. D. Required Action and D.1 Be in MODE 3. associated Completion Time not met. HATCH UNIT 2 3.1-17 SLC System 3.1.7 COMPLETION TIME 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 7 days 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 12 hours Amendment No. 223 SURVEILLANCE REQUIREMENTS (continued) SR 3.3.1.1.2 SR 3.3.1.1.3 SR 3.3.1.1.4 SR 3.3.1.1.5 SR 3.3.1.1.6 HATCH UNIT 2 SURVEILLANCE -----------------------------N 0 TE-----------------------------N ot required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER;?: 24% RTP. Verify the absolute difference between the average power range monitor (APRM) channels and the calculated power is s 2% RTP while operating at;?: 24% RTP. (Not used.) -----------------------------NOTE-----------------------------Not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2. Perform CHANNEL FUNCTIONAL TEST. Perform CHANNEL FUNCTIONAL TEST. (Not used.) 3.3-4 RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE SR 3.3.1.1.7 (Not used.) SR 3.3.1.1.8 Calibrate the local power range monitors. SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. SR 3.3.1.1.10 -----------------------------NOTE-----------------------------For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2. ------------------------------------------------------------------Perform CHANNEL FUNCTIONAL TEST. SR 3.3.1.1.11 Verify Turbine Stop Valve -Closure and Turbine Control Valve Fast Closure, Trip Oil Pressure -Low Functions are not bypassed when THERMAL POWER 27.6% RTP. SR 3.3.1.1.12 Perform CHANNEL FUNCTIONAL TEST. HATCH UNIT 2 3.3-5 RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 FUNCTION 1. Intermediate Range Monitor 2. a. Neutron Flux -High b. lnop Average Power Range Monitor a. Neutron Flux -High (Setdown) b. Simulated Thermal Power-High c. Neutron Flux -High d. lnop Table 3.3.1.1-1 (page 1 of 3) Reactor Protection System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS 2 5(a) 2 5(a) 2 1, 2 REQUIRED CHANNELS PER TRIP SYSTEM 2(d) 2(d) 2(d) 2(d) 3(c) 3(c) 3(c) 3(c) CONDITIONS REFERENCED FROM REQUIRED ACTION D.1 G H G H G F F G RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS SR 3.3.1.1.1 SR 3.3.1.1.4 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.1 SR 3.3.1.1.5 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.4 SR 3.3.1.1.15 SR 3.3.1.1.5 SR 3.3.1.1.15 SR 3.3.1.1.1 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.1 SR 3.3.1.1.2 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.1 SR 3.3.1.1.2 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.10 ALLOWABLE VALUE $ 120/125 divisions of full scale $ 120/125 divisions of full scale NA NA :> 20% RTP :> 0.57W+ 56.8% RTP and:> 115.5% RTP(b) :> 120% RTP NA continued) (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies. (b) 0.57W + 56.8% -0.57 tiW RTP when reset for single loop operation per LCO 3.4.1, "Recirculation Loops Operating." (c) Each APRM channel provides inputs to both trip systems. (d) One channel in each quadrant of the core must be OPERABLE whenever the IRMs are required to be OPERABLE. Both the RWM and a second licensed operator must verify compliance with the withdrawal sequence when less than three channels in any trip system are OPERABLE. HATCH UNIT 2 3.3-7 Amendment No. 223 ACTIONS CONDITION C. (continued) D. RWM inoperable during reactor shutdown. E. One or more Reactor Mode Switch -Shutdown Position channels inoperable. HATCH UNIT 2 Control Rod Block Instrumentation 3.3.2.1 REQUIRED ACTION COMPLETION TIME C.2.1.2 Verify by administrative Immediately methods that startup with RWM inoperable has not been performed in the last 12 months. AND C.2.2 Verify movement of During control rod control rods is in movement compliance with banked position withdrawal sequence (BPWS) by a second licensed operator or other qualified member of the technical staff. D.1 Verify movement of During control rod control rods is in movement compliance with BPWS by a second licensed operator or other qualified member of the technical staff. E.1 Suspend control rod Immediately withdrawal. AND E.2 Initiate action to fully Immediately insert all insertable control rods in core cells containing one or more fuel assemblies. 3.3-16 Amendment No. 223 Table 3.3.3.1-1(page1of1) Post Accident Monitoring Instrumentation FUNCTION 1. Reactor Steam Dome Pressure 2. Reactor Vessel Water Level a. -317 inches to -17 inches b. -150 inches to +60 inches c. 0 inches to +60 inches d. 0 inches to +400 inches 3. Suppression Pool Water Level a. 0 inches to 300 inches b. 133 inches to 163 inches 4. Drywell Pressure a. -10 psig to +90 psig b. -5 psig to +5 psig c. O psig to +250 psig 5. Drywell Area Radiation (High Range) 6. Penetration Flow Path Primary Containment Isolation Valve Position 7. (Deleted) 8. (Deleted) 9. Suppression Pool Water Temperature 10. Drywell Temperature in Vicinity of Reactor Level Instrument Reference Leg 11. Diesel Generator (DG) Parameters a. Output Voltage b. Output Current c. Output Power d. Battery Voltage 12. RHR Service Water Flow REQUIRED CHANNELS 2 2 2 2 1 2 2 2 2 2 2 2 per penetration flow path(a)(b) 2(C) 6 1 per DG 1 per DG 1 per DG 1 per DG 2 PAM Instrumentation 3.3.3.1 CONDITIONS REFERENCED FROM REQUIRED ACTION D.1 E E E E NA E E E E E F E E E NA NA NA NA E (a) Not required for isolation valves whose associated penetration flow path is isolated by at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured. (b) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel. (c) Monitoring each of four quadrants. HATCH UNIT 2 3.3-25 Amendment No. 223 Primary Containment Isolation Instrumentation 3.3.6.1 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment Isolation Instrumentation LCO 3.3.6.1 The primary containment isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE. APPLICABILITY: According to Table 3.3.6.1-1. ACTIONS ----------------------------------------------------------N 0 TES-----------------------------------------------------------1 . Penetration flow paths except for 18 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls. 2. Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for channels inoperable. Functions 2.a, 2.b, 6.b, 7.a, and 7.b AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 2.a, 2.b, 6.b, 7.a, and 7.b B. --------------N 0 TE--------------B.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Not applicable for capability. Function 5.c. ------------------------------------One or more automatic Functions with isolation capability not maintained. C. Required Action and C.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A or B Table 3.3.6.1-1 for the not met. channel. (continued) HATCH UNIT 2 3.3-48 Amendment No. 223 ACTIONS (continued) CONDITION D. As required by Required Action C.1 and referenced in Table 3.3.6.1-1. E. As required by Required Action C.1 and referenced in Table 3.3.6.1-1. F. As required by Required Action C.1 and referenced in Table 3.3.6.1-1. G. As required by Required Action C.1 and referenced in Table 3.3.6.1-1. H. As required by Required Action C.1 and referenced in Table 3.3.6.1-1. OR Required Action and associated Completion Time of Condition F or G not met. HATCH UNIT 2 D.1 OR D.2.1 Primary Containment Isolation Instrumentation 3.3.6.1 REQUIRED ACTION COMPLETION TIME Isolate associated main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months steam line (MSL). Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND D.2.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months F.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months penetration flow path(s). G.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months penetration flow path(s). H.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND H.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) 3.3-49 Amendment No. 223 ACTIONS (continued) CONDITION I. As required by Required I. 1 Action C.1 and referenced in Table 3.3.6.1-1. OR 1.2 J. As required by Required J.1 Action C.1 and referenced in Table 3.3.6.1-1. OR J.2 SURVEILLANCE REQUIREMENTS Primary Containment Isolation Instrumentation 3.3.6.1 REQUIRED ACTION COMPLETION TIME Declare Standby Liquid 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Control (SLC) System inoperable. Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup (RWCU) System. Initiate action to restore Immediately channel to OPERABLE status. Initiate action to isolate Immediately the Residual Heat Removal (RHR) Shutdown Cooling System. ----------------------------------------------------------N 0 TES-----------------------------------------------------------1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment Isolation Function. 2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains isolation capability. SURVEILLANCE SR 3.3.6.1.1 Perform CHANNEL CHECK. HATCH UNIT 2 3.3-50 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.3 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program SR 3.3.6.1. 7 ---------------------------N 0 TE-------------------------------Channel sensors are excluded. -------------------------------------------------------------------Verify the ISOLATION SYSTEM RESPONSE In accordance with TIME is within limits. the Surveillance Frequency Control Program HATCH UNIT 2 3.3-51 Amendment No. 223 I Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of 5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 1. Main Steam Line Isolation a. Reactor Vessel Water 1,2,3 2 D SR 3.3.6.1.1 <:: -113 inches Level -Low Low Low, SR 3.3.6.1.2 Level 1 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7 b. Main Steam Line 2 E SR 3.3.6.1.3 <:: 825 psig Pressure -Low SR 3.3.6.1.6 c. Main Steam Line 1,2,3 2 per D SR 3.3.6.1.1 s 138% rated Flow-High MSL SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1. 7 d. Condenser Vacuum -Low 1, 2 D SR 3.3.6.1.3 <:: 7 inches Hg 2(a), 3(a) SR 3.3.6.1.6 vacuum e. Main Steam Tunnel 1,2,3 6 D SR 3.3.6.1.1 S194°F Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 f. Turbine Building Area 1,2,3 16(b) D SR 3.3.6.1.2 s 200°F Temperature -High SR 3.3.6.1.5 SR 3.3.6.1.6 2. Primary Containment Isolation a. Reactor Vessel Water 1,2,3 2 H SR 3.3.6.1.1 <:: 0 inches Level -Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 b. Drywell Pressure -High 1,2,3 2 H SR 3.3.6.1.1 s 1.92 psig I SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 continued (a) With any turbine stop valve not closed. (b) With 8 channels per trip string. Each trip string shall have 2 channels per main steam line, with no more than 40 ft separating any two OPERABLE channels. HATCH UNIT 2 3.3-52 Amendment No. 223

2. 3. Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE Primary Containment Isolation (continued) c. Drywell Radiation -High 1,2,3 F SR 3.3.6.1.1 s 138 R/hr SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 d. Reactor Building Exhaust 1,2,3 2 H SR 3.3.6.1.1 s 80 mR/hr Radiation -High SR 3.3.6.1.3 SR 3.3.6.1.6 e. Refueling Floor Exhaust 1,2,3 2 H SR 3.3.6.1.1 s 80 mR/hr Radiation -High SR 3.3.6.1.3 SR 3.3.6.1.6 High Pressure Coolant Injection (HPCI) System Isolation a. HPCI Steam Line Flow -1,2,3 F SR 3.3.6.1.1 s 303% rated High SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6 b. HPCI Steam Supply Line 1,2,3 2 F SR 3.3.6.1.1 100 psig Pressure -Low SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 c. HPCI Turbine Exhaust 1,2,3 2 F SR 3.3.6.1.1 s 20 psig Diaphragm Pressure -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 d. Drywell Pressure -High 1,2,3 F SR 3.3.6.1.1 s 1.92 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 e. HPCI Pipe Penetration Room 1,2,3 F SR 3.3.6.1.1 s 169°F Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 f. Suppression Pool Area Ambient 1,2,3 F SR 3.3.6.1.1 s 169°F Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 continued HATCH UNIT 2 3.3-53 Amendment No. 223 I Primary Containment Isolation Instrumentation 3.3.6.1 Table3.3.6.1-1 (page3of5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 3. HPCI System Isolation (continued) g. Suppression Pool Area 1,2,3 F SR 3.3.6.1.4 :s: 16 minutes Temperature -Time Delay SR 3.3.6.1.6 15 seconds Relays h. Suppression Pool Area 1,2,3 F SR 3.3.6.1.1 :s:42°F Differential Temperature -SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6 i. Emergency Area Cooler 1,2,3 F SR 3.3.6.1.1 :s: 169°F Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 4. Reactor Core Isolation Cooling (RCIC) System Isolation a. RCIC Steam Line Flow -1,2,3 F SR 3.3.6.1.1 :s: 307% rated High SR 3.3.6.1.2 steam flow SR 3.3.6.1.5 SR 3.3.6.1.6 b. RCIC Steam Supply Line 1,2,3 2 F SR 3.3.6.1.1 60 psig Pressure -Low SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 C. RCIC Turbine Exhaust 1,2,3 2 F SR 3.3.6.1.1 :s: 20 psig Diaphragm Pressure -SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6 d. Drywell Pressure -High 1,2,3 F SR 3.3.6.1.1 :s: 1.92 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 e. RCIC Suppression Pool 1,2,3 F SR 3.3.6.1.1 :s: 169°F Ambient Area SR 3.3.6.1.2 Temperature -High SR 3.3.6.1.5 SR 3.3.6.1.6 f. Suppression Pool Area 1,2,3 F SR 3.3.6.1.4 :s: 31 minutes Temperature -Time Delay SR 3.3.6.1.6 15 seconds Relays continued) HATCH UNIT 2 3.3-54 Amendment No. 223 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 4 of 5) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 4. RCIC System Isolation (continued) g. RCIC Suppression Pool 1,2,3 F SR 3.3.6.1.1 :542°F Area Differential SR 3.3.6.1.2 Temperature -High SR 3.3.6.1.5 SR 3.3.6.1.6 h. Emergency Area Cooler 1,2,3 F SR 3.3.6.1.1 s; 169°F Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 5. RWCU System Isolation a. Area Temperature -High 1,2,3 1 per area F SR 3.3.6.1.1 s; 150°F SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 b. Area Ventilation 1,2,3 1 per area F SR 3.3.6.1.1 s; 67°F Differential Temperature -SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6 c. SLC System Initiation 1,2 1 (c) SR 3.3.6.1.6 NA d. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 ;;:: -47 inches Level -Low Low, Level 2 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 6. RHR Shutdown Cooling System Isolation a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.1 s; 145 psig Pressure -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 b. Reactor Vessel Water 3,4,5 2(d) J SR 3.3.6.1.1 ;;:: 0 inches Level -Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 (continue ) (c) SLC System Initiation only inputs into one of the two trip systems. (d) Only one trip system required in MODES 4 and 5 when RHR Shutdown Cooling System integrity maintained. HATCH UNIT 2 3.3-55a Amendment No. 223 Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 5 of 5) Primary Containment Isolation Instrumentation FUNCTION 7. Traversing lncore Probe System Isolation a. Reactor Vessel Water Level -Low, Level 3 b. Drywell Pressure -High HATCH UNIT 2 APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS 1,2,3 1,2,3 REQUIRED CHANNELS PER TRIP SYSTEM 2 2 3.3-55b CONDITIONS REFERENCED FROM REQUIRED SURVEILLANCE ACTION C.1 REQUIREMENTS G G SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 ALLOWABLE VALUE 0 inches :s 1.92 psig Amendment No. 223 ECCS -Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS -Operating LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System (ADS) function of six of seven safety/relief valves shall be OPERABLE. APPLICABILITY: MODE 1, MODES 2 and 3, except high pressure coolant injection (HPCI) and ADS valves are not required to be OPERABLE with reactor steam dome pressure s 150 psig. ACTIONS ---------------------------------------------------------------NOTE--------------------------------------------------------LCO 3.0.4.b is not applicable to HPCI. CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7 days injection/spray subsystem ECCS injection/spray inoperable. subsystem(s) to OPERABLE status. OR One LPCI pump in both LPCI subsystems inoperable. B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not AND met. B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) HATCH UNIT 2 3.5-1 Amendment No. 223 ACTIONS (continued) CONDITION C. HPCI System inoperable. D. HPCI System inoperable. AND Condition A entered. E. Two or more ADS valves inoperable. OR Required Action and associated Completion Time of Condition C or D not met. F. Two or more low pressure ECCS injection/spray subsystems inoperable for reasons other than Condition A. OR HPCI System and two or more ADS valves inoperable. HATCH UNIT 2 REQUIRED ACTION C.1 Verify by administrative means RCIC System is OPERABLE. AND C.2 Restore HPCI System to OPERABLE status. D.1 Restore HPCI System to OPERABLE status. OR D.2 Restore low pressure ECCS injection/spray subsystem to OPERABLE status. E.1 Be in MODE 3. AND E.2 Reduce reactor steam dome pressure to :s; 150 psig. F.1 Enter LCO 3.0.3. 3.5-2 ECCS -Operating 3.5.1 COMPLETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 14 days 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 72 hours 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours Immediately Amendment No. 223 ACTIONS CONDITION A. (continued) A.2 B. --------------N 0 TE---------------8.1 Only applicable to penetration flow paths with two PCIVs. -------------------------------------One or more penetration flow paths with two PCIVs inoperable except due to leakage not within limit. HATCH UNIT 2 REQUIRED ACTION ------------N 0 TES-----------1. Isolation devices in high radiation areas may be verified by use of administrative means. 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. --------------------------------Verify the affected penetration flow path is isolated. Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. 3.6-8 PC I Vs 3.6.1.3 COMPLETION TIME Once per 31 days for isolation devices outside primary containment AND Prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days, for isolation devices inside primary containment 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months (continued) Amendment No. 223 ACTIONS (continued) CONDITION C. --------------NOTE---------------C.1 Only applicable to penetration flow paths with only one PCIV. -------------------------------------One or more penetration flow paths with one PCIV inoperable except due to leakage not within limits. AND C.2 D. One or more penetration D.1 flow paths with leakage not within limit. E. Required Action and E.1 associated Completion Time of Condition A, B, C, AND or D not met in MODE 1, 2, or 3. E.2 HATCH UNIT 2 REQUIRED ACTION Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. ----------NO TES-----------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. --------------------------------Verify the affected penetration flow path is isolated. Restore leakage to within limit. Be in MODE 3. Be in MODE 4. 3.6-9 PC IVs 3.6.1.3 COMPLETION TIME 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except for excess flow check valve (EFCV) line and penetrations with a closed system AND 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for EFCV line and penetrations with a closed system Once per 31 days 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) Amendment No. 223 SURVEILLANCE REQUIREMENTS (continued) SR 3.6.1.3.2 SR 3.6.1.3.3 SR 3.6.1.3.4 SR 3.6.1.3.5 HATCH UNIT 2 SURVEILLANCE ------------------------------N 0 TES---------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls. Verify each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. -----------------------------N 0 TES----------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for PCIVs that are open under administrative controls. Verify each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Verify continuity of the traversing incore probe (TIP) shear isolation valve explosive charge. Verify the isolation time of each power operated, automatic PCIV, except for MSIVs, is within limits. 3.6-11 PC IVs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program Prior to entering MODE 2 or 3 from MODE 4 if primary containment was de-inerted while in MODE 4, if not performed within the previous 92 days In accordance with the Surveillance Frequency Control Program In accordance with the I nservice Testing Program (continued) Amendment No. 223 ACTIONS (continued) CONDITION B. Required Action and B.1 associated Completion Time of Condition A not met. C. Suppression pool average C.1 temperature> 105°F. AND Any OPERABLE IRM channel > 25/40 divisions of full scale on Range 7. AND Performing testing that adds heat to the suppression pool. D. Suppression pool average D.1 temperature> 110°F. AND D.2 AND D.3 HATCH UNIT 2 Suppression Pool Average Temperature 3.6.2.1 REQUIRED ACTION COMPLETION TIME Reduce THERMAL 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months POWER until all OPERABLE I RM channels s 25/40 divisions of full scale on Range 7. Suspend all testing that Immediately adds heat to the suppression pool. Place the reactor mode Immediately switch in the shutdown position. Determine suppression Once per 30 minutes pool average temperature. Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) 3.6-22 Amendment No. 223 Suppression Pool Average Temperature 3.6.2.1 ACTIONS (continued) CONDITION E. Suppression pool average temperature> 120°F. SURVEILLANCE REQUIREMENTS E.1 REQUIRED ACTION Depressurize the reactor vessel to < 200 psig. SURVEILLANCE SR 3.6.2.1.1 HATCH UNIT 2 Verify suppression pool average temperature is within the applicable limits. 3.6-23 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months FREQUENCY In accordance with the Surveillance Frequency Control Program AND 5 minutes when performing testing that adds heat to the suppression pool Amendment No. 223 ACTIONS CONDITION REQUIRED ACTION C. (continued) C.2 AND C.3 Suspend CORE ALTERATIONS. Initiate action to suspend OPDRVs. SURVEILLANCE REQUIREMENTS SR 3.6.4.1.1 SR 3.6.4.1.2 SR 3.6.4.1.3 HATCH UNIT 2 SURVEILLANCE Verify all secondary containment equipment hatches are closed and sealed. Verify one secondary containment access door in each access opening is closed. -----------------------------N 0 TE-----------------------------Th e number of standby gas treatment (SGT) subsystem(s) required for this Surveillance is dependent on the secondary containment configuration, and shall be one less than the number required to meet LCO 3.6.4.3, "Standby Gas Treatment (SGT) System," for the given configuration. Verify secondary containment can be drawn down to 0.20 inch of vacuum water gauge in s 120 seconds using required standby gas treatment (SGT) subsystem(s). 3.6-34 Secondary Containment 3.6.4.1 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS continued SR 3.6.4.1.4 HATCH UNIT 2 SURVEILLANCE -----------------------------N 0 TE------------------------------Th e number of SGT subsystem(s) required for this Surveillance is dependent on the secondary containment configuration, and shall be one less than the number required to meet LCO 3.6.4.3, "Standby Gas Treatment (SGT) System," for the given configuration. Verify the secondary containment can be maintained ;:: 0.20 inch of vacuum water gauge for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months using required SGT subsystem(s) at a flow rates 4000 cfm per subsystem. 3.6-35 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 223 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) LCO 3.6.4.2 APPLICABILITY: ACTIONS Each SCIV shall be OPERABLE. MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE AL TE RATIONS, During operations with a potential for draining the reactor vessel (OPDRV). SC IVs 3.6.4.2 ----------------------------------------------------------N 0 TES-------------------------------------------------------------1. Penetration flow paths may be unisolated intermittently under administrative controls. 2. Separate Condition entry is allowed for each penetration flow path. 3. Enter applicable Conditions and Required Actions for systems made inoperable by SCIVs. CONDITION A. One or more penetration flow paths with one SCIV inoperable. HATCH UNIT 2 REQUIRED ACTION COMPLETION TIME A.1 Isolate the affected 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. AND A.2 -----------NOTES-----------1. Isolation devices in high radiation areas may be verified by use of administrative means. 3.6-36 (continued) Amendment No. 223 ACTIONS CONDITION A. (continued) B. One or more penetration B.1 flow paths with two SCIVs inoperable. C. Required Action and C.1 associated Completion Time of Condition A or B AND not met in MODE 1, 2, or 3. C.2 D. Required Action and D.1 associated Completion Time of Condition A or B not met during movement of irradiated fuel assemblies in the secondary containment, during CORE ALTERATIONS, or during OPDRVs. HATCH UNIT 2 REQUIRED ACTION 2. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. -------------------------------Verify the affected penetration flow path is isolated. Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. Be in MODE 3. Be in MODE 4. -------------N 0 TE----------LCO 3.0.3 is not applicable. -------------------------------Suspend movement of irradiated fuel assemblies in the secondary containment. 3.6-37 SCI Vs 3.6.4.2 COMPLETION TIME Once per 31 days 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Immediately (continued) Amendment No. 223 ACTIONS CONDITION REQUIRED ACTION D. (continued) D.2 AND D.3 Suspend CORE ALTERATIONS. Initiate action to suspend OPDRVs. SURVEILLANCE REQUIREMENTS SR 3.6.4.2.1 SR 3.6.4.2.2 SR 3.6.4.2.3 HATCH UNIT 2 SURVEILLANCE ----------------------------N 0 TES----------------------------1. Valves and blind flanges in high radiation areas may be verified by use of administrative means. 2. Not required to be met for SCIVs that are open under administrative controls. Verify each secondary containment isolation manual valve and blind flange that is not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Verify the isolation time of each power operated, automatic SCIV is within limits. Verify each automatic SCIV actuates to the isolation position on an actual or simulated actuation signal. 3.6-38 SCI Vs 3.6.4.2 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 223 ACTIONS (continued) CONDITION B. One required Unit 2 SGT subsystem inoperable. OR One required Unit 1 SGT subsystem inoperable for reasons other than Condition A. C. Required Action and associated Completion Time of Condition A or B not met in MODE 1, 2, or 3. D. Required Action and associated Completion Time of Condition A or B not met during movement of irradiated fuel assemblies in the secondary containment, during CORE ALTERATIONS, or during OPDRVs. HATCH UNIT 2 REQUIRED ACTION B.1 Restore required SGT subsystem to OPERABLE status. C.1 Be in MODE 3. AND C.2 Be in MODE 4. ------------------N 0 TE-----------------LCO 3.0.3 is not applicable. -------------------------------------------D.1 Place remaining OPERABLE SGT subsystem(s) in operation. OR D.2.1 Suspend movement of irradiated fuel assemblies in secondary containment. AND D.2.2 Suspend CORE ALTERATIONS. AND D.2.3 Initiate action to suspend OPDRVs. 3.6-40 SGT System 3.6.4.3 COMPLETION TIME 7 days 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours Immediately Immediately Immediately Immediately (continued) Amendment No. 223 ACTIONS AC Sources -Operating 3.8.1 ---------------------------------------------------------------NOTE--------------------------------------------------------LCO 3.0.4.b is not applicable to DGs. CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite circuit A.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. OPERABLE required offsite circuits. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Declare required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from discovery feature(s) with no offsite of no offsite power to power available one 4160 V ESF bus inoperable when the concurrent with redundant required inoperability of feature(s) are redundant required inoperable. feature(s) AND A.3 Restore required offsite 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months circuit to OPERABLE status. B. One Unit 2 or the swing DG B.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. OPERABLE required offsite circuit(s). AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND (continued) HATCH UNIT 2 3.8-2 Amendment No. 223 ACTIONS CONDITION REQUIRED ACTION B. (continued) B.4 (continued) C. One required Unit 1 DG C.1 Perform SR 3.8.1.1 for inoperable. OPERABLE required offsite circuit(s). AND C.2 Declare required feature(s), supported by the inoperable DG, inoperable when the redundant required feature(s) are inoperable. AND C.3.1 Determine OPERABLE DG(s) are not inoperable due to common cause failure. OR C.3.2 Perform SR 3.8.1.2.a for OPERABLE DG(s). HATCH UNIT 2 3.8-4 AC Sources -Operating 3.8.1 COMPLETION TIME AND 14 days for the swing diesel with maintenance restrictions met 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery of Condition C concurrent with inoperability of redundant required feature(s) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 24 hours (continued) Amendment No. 223 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.1.6 SR 3.8.1.7 HATCH UNIT 2 SURVEILLANCE ----------------------------N 0 TE-------------------------------T his Surveillance shall not normally be performed in MODE 1 or 2. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify automatic and manual transfer of unit power supply from the normal offsite circuit to the alternate offsite circuit. ----------------------------N 0 TES-----------------------------1. This Surveillance shall not normally be performed in MODE 1 or 2, except for the swing DG. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. For the swing DG, this Surveillance shall not be performed in MODE 1 or 2 using the Unit 2 controls. Credit may be taken for unplanned events that satisfy this SR. 2. For the swing DG, a single test at the specified Frequency will satisfy this Surveillance for both units. Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and: a. Following load rejection, the frequency is s 65.5 Hz; and b. Within 3 seconds following load rejection, the voltage is;;:: 3740 V ands 4580 V. 3.8-10 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SR 3.8.1.8 HATCH UNIT 2 SURVEILLANCE -----------------------------N 0 TES----------------------------1. This Surveillance shall not normally be performed in MODE 1 or 2, except for the swing DG. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. For the swing DG, this Surveillance shall not be performed in MODE 1 or 2 using the Unit 2 controls. Credit may be taken for unplanned events that satisfy this SR. 2. If grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable. 3. For the swing DG, a single test at the specified Frequency will satisfy this Surveillance for both units. Verify each DG operating at a power factors 0.88 does not trip and voltage is maintained s 4800 V during and following a load rejection 2775 kW. 3.8-11 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SR 3.8.1.9 HATCH UNIT 2 SURVEILLANCE ----------------------------N 0 TES-----------------------------1. All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated loss of offsite power signal: a. De-energization of emergency buses; b. Load kdding from emergency buses; and c. DG auto-starts from standby condition and: 1. Energizes permanently connected loads in s 12 seconds, 2. Energizes auto-connected shutdown loads through automatic load sequence timing devices, 3. Maintains steady state voltage ;:; 3740 V ands; 4243 V, 4. Maintains steady state frequency ;:; 58.8 Hz and s 61.2 Hz, and 5. Supplies permanently connected and auto-connected shutdown loads for ;:; 5 minutes. 3.8-12 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SR 3.8.1.10 HATCH UNIT 2 SURVEILLANCE ---------------------------N 0 TES----------------------------1. All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated Emergency Core Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and: a. Ins 12 seconds after auto-start achieves 3740 V, and after steady state conditions are reached, maintains voltage 3740 V ands 4243 V; b. Ins 12 seconds after auto-start achieves frequency 58.8 Hz, and after steady state conditions are reached, maintains frequency 58.8 Hz and s 61.2 Hz; and c. Operates for 5 minutes. 3.8-13 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.11 --------------------------N 0 TE---------------------------------HATCH UNIT 2 Th is Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify each DG's non-critical automatic trips are bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ECCS initiation signal. 3.8-14 In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SR 3.8.1.12 HATCH UNIT 2 SURVEILLANCE ---------------------------NOTES------------------------------1. Momentary transients outside the load and power factor ranges do not invalidate this test. 2. This Surveillance shall not normally be performed in MODE 1 or 2, unless the other two DGs are OPERABLE. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. If either of the other two DGs becomes inoperable, this Surveillance shall be suspended. Credit may be taken for unplanned events that satisfy this SR. 3. If grid conditions do not permit, the power factor limit is not required to be met. Under this condition, the power factor shall be maintained as close to the limit as practicable. 4. For the swing DG, a single test at the specified Frequency will satisfy this Surveillance for both units. Verify each DG operating at a power factors 0.88 operates for <! 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: a. For<! 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2: 3000 kW; and b. For the remaining hours of the test loaded <! 2775 kW and s 2825 kW. 3.8-15 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.1.13 SR 3.8.1.14 HATCH UNIT 2 SURVEILLANCE ---------------------------NOTES------------------------------1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2565 kW. Momentary transients outside of load range do not invalidate this test. 2. All DG starts may be preceded by an engine prelube period. 3. For the swing DG, a single test at the specified Frequency will satisfy this Surveillance for both units. Verify each DG starts and achieves, in ::;; 12 seconds, voltage 37 40 V and frequency 58.8 Hz; and after steady state conditions are reached, maintains 3740 V and::;; 4243 V and 58.8 Hz and ::;; 61.2 Hz. ---------------------------N 0 TE--------------------------------Th is Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify each DG: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power; b. Transfers loads to offsite power source; and c. Returns to ready-to-load operation. 3.8-16 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 AC Sources - Operating 3.8.1 HATCH UNIT 2 3.8-17 Amendment No. 223 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.8.1.15 ---------------------------NOTE-------------------------------

This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ------------------------------------------------------------------

Verify with a DG operating in test mode and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by:

a. Returning DG to ready-to-load operation; and b. Automatically energizing the emergency load from offsite power.

In accordance with the Surveillance Frequency Control Program

SR 3.8.1.16 -----------------------------NOTE------------------------------

This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ------------------------------------------------------------------- Verify interval between each sequenced load block is within 10% of design interval for each load sequence timing device.

In accordance with the Surveillance Frequency Control Program

(continued)

SURVEILLANCE REQUIREMENTS continued SURVEILLANCE AC Sources -Operating 3.8.1 FREQUENCY SR 3.8.1.17 ----------------------------N 0 TES-----------------------------HATCH UNIT 2 1 . All DG starts may be preceded by an engine prelube period. 2. This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify, on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal: a. De-energization of emergency buses; b. Load shedding from emergency buses; and c. DG auto-starts from standby condition and: 1. Energizes permanently connected loads in ::; 12 seconds, 2. Energizes auto-connected emergency loads through automatic load sequence timing devices, 3. Achieves steady state voltage 3740 V and::; 4243 V, 4. Achieves steady state frequency 58.8 Hz and::; 61.2 Hz, and 5. Supplies permanently connected and auto-connected emergency loads for 5 minutes. 3.8-18 In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE DC Sources -Operating 3.8.4 FREQUENCY SR 3.8.4.7 -----------------------------N 0 TES----------------------------HATCH UNIT 2 1. The modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7. 2. This Surveillance shall not normally be performed in MODE 1, 2, or 3, except for the swing DG battery. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test. 3.8-29 In accordance with the Surveillance Frequency Control Program (continued) Amendment No. 223 DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued) SR 3.8.4.8 SR 3.8.4.9 HATCH UNIT 2 SURVEILLANCE -------------------------------N 0 TE----------------------------Th is Surveillance shall not normally be performed in MODE 1, 2, or 3, except for the swing DG battery. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify battery capacity is ;;:: 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test. For required Unit 1 DC sources, the SRs of Unit 1 Specification 3.8.4 are applicable. 3.8-30 FREQUENCY In accordance with the Surveillance Frequency Control Program 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturer's rating 24 months when battery has reached 85% of expected life with capacity ;;:: 100% of manufacturer's rating In accordance with applicable SRs Amendment No. 223 ACTIONS (continued) CONDITION B. One or more (Unit 2 or swing bus) DG DC electrical power distribution subsystems inoperable. C. One or more (Unit 2 or swing bus) AC electrical power distribution subsystems inoperable. D. One Unit 2 station service DC electrical power distribution subsystem inoperable. E. Required Action and associated Completion Time of Condition A, B, C, or D not met. F. Two or more electrical power distribution subsystems inoperable that result in a loss of function. HATCH UNIT 2 B.1 C.1 D.1 E.1 AND E.2 F.1 Distribution Systems -Operating 3.8.7 REQUIRED ACTION COMPLETION TIME Restore DG DC 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months electrical power distribution subsystem to OPERABLE status. Restore AC electrical 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months power distribution subsystem to OPERABLE status. Restore Unit 2 station 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months service DC electrical power distribution subsystem to OPERABLE status. Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Enter LCO 3.0.3. Immediately 3.8-38 Amendment No. 223 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued) c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the ODCM; d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I; e. Determination of cumulative dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days. Determination of projected dose contributions from radioactive effluents in accordance with the methodology in the ODCM at least every 31 days; f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I; g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents to areas beyond the site boundary as follows: 1) For noble gases, less than or equal to a dose rate of 500 mrem/year to the total body and less than or equal to a dose rate of 3000 mrem/year to the skin, and 2) For iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half-lives greater than 8 days, less than or equal to a dose rate of 1500 mrem/year to any organ; h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half lives> 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and j. Limitations on the annual dose or dose commitment to any member of the public due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190. (continued) HATCH UNIT 2 5.0-9 Amendment No. 223 5.5 Programs and Manuals (continued) 5.5.5 Component Cyclic or Transient Limit Programs and Manuals 5.5 This program provides controls to track FSAR Section 5.2, cyclic and transient occurrences, to ensure that reactor coolant pressure boundary components are maintained within the design limits. 5.5.6 lnservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports. a. Testing frequencies specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda are as follows: ASME Boiler and Pressure Vessel Code and Applicable Addenda Terminology for lnservice Testing Activities Weekly Monthly Quarterly or every 3 months Semiannually or every 6 months Yearly or annually Required Frequencies for Performing lnservice Testing Activities At least once per 7 days At least once per 31 days At least once per 92 days At least once per 184 days At least once per 366 days b. The provisions of SR 3.0.2 are applicable to the frequencies for performing inservice testing activities; c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and d. Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any Technical Specification. 5.5.7 Ventilation Filter Testing Program (VFTP) A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2, Sections C.5.c and C.5.d, and in accordance with Regulatory Guide 1.52, Revision 2. (continued) HATCH UNIT 2 5.0-10 Amendment No. 223 5.5 Programs and Manuals Programs and Manuals 5.5 5.5.8 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued) The program shall include: a. The limits for the concentrations of hydrogen in the main condenser offgas treatment system and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion); and b. A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the liquid radwaste treatment system is less than the amount that would result in concentrations less than the limits of 10 CFR 20, Appendix B, Table 2, Column 2, at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tanks' contents. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies. 5.5.9 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following: a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has: 1. An API gravity or an absolute specific gravity within limits, 2. A flash point and kinematic viscosity within limits for ASTM 20 fuel oil, and 3. A water and sediment content within limits; b. Within 31 days following addition of the new fuel oil to storage tanks, verify that the properties of the new fuel oil, other than those addressed in a., above, are within limits for ASTM 20 fuel oil; and (continued) HATCH UNIT 2 5.0-13 Amendment No. 223 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Diesel Fuel Oil Testing Program (continued) 5.5.10 c. Total particulate concentration of the fuel oil is :::; 10 mg/liter when tested every 92 days. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program surveillance frequencies. Safety Function Determination Program (SFDP) This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory actions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following: a. Provisions for cross division checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected; b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists; c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and d. Other appropriate limitations and remedial or compensatory actions. A loss of safety function exists when, assuming no concurrent single failure, no concurrent loss of offsite power or no concurrent loss of onsite diesel generator(s), a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and: a. A required system redundant to system(s) supported by the inoperable support system is also inoperable; or b. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or c. A required system redundant to support system(s) for the supported systems (a) and (b) above is also inoperable. (continued) HATCH UNIT 2 5.0-14 Amendment No. 223 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 5.5.11 Safety Function Determination Program (SFDP) (continued) The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. When a loss of safety function is caused by inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system. Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications. a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews. b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following: 1. A change in the TS incorporated in the license; or 2. A change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59. c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR. d. Proposed changes that meet the criteria of item b above shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e). HATCH UNIT 2 5.0-15 (continued) Amendment No. 223 UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION AMENDMENT NO. 279 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-57 AND AMENDMENT NO. 223 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-5 SOUTHERN NUCLEAR OPERATING COMPANY. INC. EDWIN I. HATCH NUCLEAR PLANT. UNIT NOS. 1 AND 2 DOCKET NOS. 50-321 AND 50-366

1.0 INTRODUCTION

By application dated October 10, 2014 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML 14288A226), as supplemented by letters dated May 4, 2015, October 15, 2015, and August 26, 2016 (ADAMS Accession Nos. ML 16116A201, ML 15288A232, and ML 16239A309, respectively), Southern Nuclear Operating Company, Inc. (SNC, the licensee), requested changes to the Technical Specifications (TSs) for the Edwin I. Hatch Nuclear Plant (HNP), Unit Nos. 1 and 2. The proposed changes would incorporate 21 generic changes to the HNP TSs. Specifically, SNC requests to adopt 18 previously U.S. Nuclear Regulatory Commission (NRC)-approved Technical Specifications Task Force (TSTF) travelers, two TSTF T-travelers, and one feature of NUREG-1433, Revision 4, "Standard Technical Specifications -General Electric BWR/4 Plants" (ADAMS Accession Nos. ML 12104A192 and ML 12104A193), known as the Improved Standard Technical Specifications (ISTS) not associated with a traveler. SNC stated that these changes would increase the consistency between the HNP TSs, the ISTS for boiling water reactor (BWR)/4 plants, and the TSs of the other plants in the SNC fleet. The proposed changes are listed below. The requested TSTFs for NRC approval are: 1. TSTF-30-A, Revision 3, "Extend the Completion Time for inoperable isolation valve to a closed system to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months " 2. TSTF-45-A, Revision 2, "Exempt verification of CIVs [containment isolation valves] that are not locked, sealed or otherwise secured" 3. TSTF-46-A, Revision 1, "Clarify the CIV surveillance to apply only to automatic isolation valves" 4. TSTF-222-A, Revision 1, "Control Rod Scram Time Testing (BWR)" Enclosure 3 5. TSTF-264-A, Revision 0, "3.3.9 and 3.3.10 -Delete flux monitors specific overlap requirement SRs [surveillance requirements)" 6. TSTF-269-A, Revision 2, "Allow administrative means of position verification for locked or sealed valves" 7. TSTF-273-A, Revision 2, "SFDP [Safety Function Determination Program] Clarifications" 8. TSTF-283-A, Revision 3, "Modify Section 3.8 Mode restriction Notes" 9. TSTF-284-A, Revision 3, "Add 'Met vs. Perform' to Specification 1.4, Frequency" 10. TSTF-295-A, Revision 0, "Modify Note 2 to Actions of PAM [Post-Accident Monitoring] Table to Allow Separate Condition Entry for Each Penetration" 11. TSTF-306-A, Revision 2, "Add Action to LCO [Limiting Condition for Operation] 3.3.6.1 to give option to isolate the penetration" 12. TSTF-308-A, Revision 1, "Determination of Cumulative and Projected Dose Contributions in RECP [Radioactive Effluent Controls Program)" 13. TSTF-318-A, Revision 0, "Revise 3.5.1 for one LPCI [low pressure coolant injection] pump inoperable in each of two ECCS [emergency core cooling system] divisions" 14. TSTF-322-A, Revision 2, "Secondary Containment and Shield Building Boundary Integrity SRs" 15. TSTF-323-A, Revision 0, "EFCV [Excess Flow Check Valve] Completion Time to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months " 16. TSTF-37 4-A, Revision 0, "Revision to TS 5.5.13 and associated TS Bases for Diesel Fuel Oil" 17. TSTF-400-A, Revision 1, "Clarify SR on Bypass of DG [Diesel Generator] Automatic Trips" 18. TSTF-439-A, Revision 2, "Eliminate Second Completion Times Limiting Time From Discovery of Failure To Meet an LCO" T-travelers are travelers that have not been approved by the NRC staff, but have been approved by the TSTF. The following T-travelers are being requested for NRC approval: 19. TSTF-458-T, Revision 0, "Removing Restart of Shutdown Clock for Increasing Suppression Pool Temperature" 20. TSTF-464-T, Revision 0, "Clarify the Control Rod Block Instrumentation Required Action" In addition, SNC requested one change for NRC approval that reflects ISTS requirements that were not added by a traveler: 21. ISTS Adoption #1 -Revise the 5.5.7 Introductory Paragraph to be Consistent with the ISTS The supplements dated May 4, 2015, October 15, 2015, and August 26, 2016, provided additional information that clarified the application, did not expand the scope of the application as originally noticed, and did not change the NRC staff's original proposed no significant hazards consideration determination as published the Federal Register on March 31, 2015 (80 FR 17095; July 19, 1995).

2.0 REGULATORY EVALUATION

Title 10 of the Code of Federal Regulations (10 CFR) Section 50.36, "Technical specifications," requires TSs for nuclear reactors to include items in the following categories: (1) safety limits, limiting safety system settings, and limiting control settings; (2) LCOs; (3) SRs; (4) design features; and (5) administrative controls. The regulation does not specify the particular requirements to be included in a plant's TSs. On July 22, 1993, the Commission published the "Final Policy Statement on Technical Specifications Improvements for Nuclear Power Reactors" (58 FR 39132). This Final Policy Statement discussed criteria for determining which items must be included in the TS as LCOs. These criteria were subsequently incorporated into 1 O CFR 50.36 (60 FR 36953). Specifically, 10 CFR 50.36(c)(2)(ii) requires that an LCO be established for each item meeting one or more of the following criteria: Criterion 1: Installed instrumentation that is used to detect, and indicate in the control room, a significant abnormal degradation of the reactor coolant pressure boundary. Criterion 2: A process variable, design feature, or operating restriction that is an initial condition of a design basis accident or transient analysis that either assumes the failure of or presents a challenge to the integrity of a fission product barrier. Criterion 3: A structure, system, or component that is part of the primary success path and which functions or actuates to mitigate a design basis accident or transient that either assumes the failure of or presents a challenge to the integrity of a fission product barrier. Criterion 4: A structure, system, or component which operating experience or probabilistic risk assessment has shown to be significant to public health and safety. In determining the acceptability of TS changes, the NRC staff considers the requirements of 1 O CFR 50.36 using the guidance in the ISTS and the associated Bases for the safety limits and LCOs, and the references cited in the Bases. As discussed in the Final Policy Statement, the NRC staff reviews, on a case-by-case basis, whether enforceable regulatory controls (e.g., 10 CFR 50.59) are needed for material moved to licensee-controlled documents, such as the updated safety analysis report, the Technical Requirements Manual, the TS Bases, the Quality Assurance Plan, etc. The NRC staff determines that plant-specific adoptions of ISTS format and content provide continued, adequate protection for the public health and safety when (1) the change is editorial, administrative, or provides clarification (i.e., no requirements are materially altered); (2) the change is more restrictive than the licensee's current requirement; or (3) the change is less restrictive than the licensee's current requirement, but nonetheless still affords adequate assurance of safety when judged against current regulatory standards and the facility's licensing basis. The NRC staff used the ISTS, Revision 4, issued in April 2012, in its review of the TS changes proposed by SNC. The NRC staff also referred to the TSTF travelers associated with the ISTS changes proposed for adoption by SNC. The NRC staff notes that in September 1992, the Commission issued the ISTSs (NUREG-1430 through NUREG-1434), which were developed using the guidance and criteria contained in the Commission's Final Policy Statement (58 FR 39132). In the current revisions of NUREG-1430 through NUREG-1434, the word "improved" has been dropped from the titles, therefore, throughout the rest of this safety evaluation, standard technical specifications (STS) is used in place of ISTS for consistency, except when it is contained in a document's title.

3.0 TECHNICAL EVALUATION

3.1 TSTF-30-A. Revision 3, "Extend the Completion Time for inoperable isolation valve to a closed system to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months " TSTF-323-A. Revision 0. "Excess Flow Check Valve (EFCV) Completion Time to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months " TSTF-30-A, Revision 3, revised BWR STS 3.6.1.3, "Primary Containment Isolation Valves (PCIVs)," Actions Condition C, "One or more penetration flow paths with one PCIV [primary containment isolation valve] inoperable," which is only applicable to penetration flow paths with one PCIV. Specifically, TSTF-30-A, Revision 3, revised the Completion Times for Required Action C.1 to allow 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , instead of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , to isolate an inoperable PCIV in a closed system. TSTF-323-A, Revision 0, extended the Completion Time to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for inoperable CIVs where there was only a single valve on the containment penetration. This was in recognition that these penetrations were designed with some other acceptable barrier (e.g., closed system). The NRC's approval of TSTF-323, Revision 0, preceded the NRC's approval of TSTF-30, Revision 3, since TSTF-323-A was approved in March of 1999, whereas TSTF-30-A was approved by the NRC in a letter dated August 16, 1999. As a result, approval of the TSTS-323-A, Revision 0, change preceded approval of, and was subsumed assumed, in the final version (Revision 3) of TSTF-30. HNP TS LCO 3.6.1.3, Condition C, is applicable to penetration flow paths with only one PCIV. With one or more penetration flow paths with one PCIV inoperable, except due to leakage not within limits, Required Action C.1 requires isolation of the affected penetration flow path by use of at least one closed and deactivated automatic valve, closed manual valve, or blind flange. Current Completion Time for Required Action C.1 of HNP TS 3.6.1.3 states: 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except for excess flow check valve (EFCV) line, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for EFCV line Revised Required Action C.1 Completion Time of HNP TS 3.6.1.3 would state: 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except for excess flow check valve (EFCV) and penetrations with a closed system 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for EFCV line and penetrations with a closed system NRC Staff Evaluation: In the supplement dated May 4, 2015, the licensee provided clarification on the scope of Required Action C.1 where a Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months would be retained for penetrations with only one PCIV that is not associated with a closed system or an EFCV. Specifically, the licensee provided examples of penetrations that are covered under 10 CFR Part 50, Appendix A, General Design Criterion 56, "Primary Containment Isolation," in both HNP, Units 1 and 2 (e.g., drywell pressure instrument, torus water level instrument, and traversing in-core probe nitrogen purge line). The licensee also stated that these allowed configurations are consistent with guidance in Regulatory Guide (RG) 1.11, "Instrument Lines Penetrating the Primary Reactor Containment" (ADAMS Accession No. ML 100250396). The NRC staff reviewed the referenced RG 1.11 and HNP, Unit No. 1, Final Safety Analysis Report (FSAR), Subsection 5.2.2.5.4, and HNP, Unit No. 2, FSAR Subsection 6.2.5.3.3, and found that the Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is applicable in these cases. The changes proposed for corresponding PCIV and EFCV action requirements in TS 3.6.1.3 conform to the changes made to the STS by TSTF-30-A, Revision 3, and TSTF-323-A, Revision 0. The BWR/4 design (such as the HNP design) includes a class of single-isolation valve penetrations (i.e., instrumentation lines with an EFCV) that were inadvertently not included in the markup for TSTF-30, Revision 2. That approved traveler extended the Completion Time to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for inoperable PCIVs in containment penetration flow paths with just one PCIV. The NRC staff has determined that these single-PCIV penetrations used in closed systems provide an acceptable second barrier. Similarly, a Completion Time of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for inoperable EFCVs is acceptable because EFCVs are installed on penetrations that provide acceptable barriers in the event that the single isolation valve failed. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(2) continue to be met because the minimum performance level of equipment needed for safe operation of the facility is contained in the LCO, and the appropriate remedial measures are specified if the LCO is not met. Based on the above, the NRC staff concludes that the changes to TS 3.6.1.3 are acceptable. 3.2 TSTF-45-A. Revision 2, "Exempt verification of CIVs that are not locked. sealed or otherwise secured" The NRC approved this change to the STS Revision 1 on July 26, 1999. TSTF-45-A, Revision 2, revised BWR/4 STS 3.6.1.3, "Primary Containment Isolation Valves (PCIVs)," and STS 3.6.4.2, "Secondary Containment Isolation Valves (SCIVs)," by changing valve position verification SRs. Current TS SR 3.6.1.3.2 states: Verify each primary containment isolation manual valve and blind flange that is located outside primary containment and is required to be closed during accident conditions is closed. Revised TS SR 3.6.1.3.2 would state (with the inserted portion in bold): Verify each primary containment isolation manual valve and blind flange that is located outside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Current TS SR 3.6.1.3.3 states: Verify each primary containment manual isolation valve and blind flange that is located inside primary containment and is required to be closed during accident conditions is closed. Revised TS SR 3.6.1.3.3 would state (with the inserted portion in bold): Verify each primary containment manual isolation valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. Current TS SR 3.6.4.2.1 states: Verify each secondary containment isolation manual valve and blind flange that is required to be closed during accident conditions is closed. Revised TS SR 3.6.4.2.1 would state (with the inserted portion in bold): Verify each secondary containment isolation manual valve and blind flange that is not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed. NRC Staff Evaluation: TSTF-45-A states that the proposed change is consistent with the valve position verification requirement for valves that have a function during an accident in other system TSs. The NRC staff reviewed the proposed changes and determined they are consistent with current HNP SR 3.5.1.2, which requires that each ECCS subsystem be demonstrated operable, in part, by performance of a valve alignment of each valve that is in the flow path that is not locked, sealed, or otherwise secured valves. Multiple HNP systems, such as the reactor core isolation cooling system and the residual heat removal suppression pool cooling system, spray, and drywell spray, are also demonstrated to be operable, in part, by verifying that each valve in the flow path of the system that is not locked, sealed, or otherwise secured in position, is in its correct position (SRs 3.6.2.3.1, 3.6.2.4.1, 3.6.2.5.1, and 3.6.3.1.2, respectively). Additionally, the changes proposed for HNP TS SRs 3.6.1.3.2, 3.6.1.3.1, and 3.6.4.2.1 are the same as those contained in TSTF-45-A. The NRC staff concludes that excluding locked, sealed, or otherwise secured valves from periodic position verification is acceptable because these valves were verified to be in the correct position upon being locked, sealed, or otherwise secured. The position of these valves is controlled administratively, and periodic visual verification is not necessary. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(3) continue to be met because the revised SR provides the appropriate surveillance to ensure the necessary quality of components is maintained and the LCO will be met. Based on the above, the NRC staff concludes that the changes to SRs 3.6.1.3.2, 3.6.1.3.1, and 3.6.4.2.1 are acceptable. 3.3 TSTF-46-A. Revision 1. "Clarify the CIV surveillance to apply only to automatic isolation valves" The NRC did not issue a letter approving this change to STS, Revision 1; however, this change was incorporated by the NRC into Revision 2 of the STS issued in April 2001. TSTF-46-A revises STS SR 3.6.3.5 to delete the reference to verifying the isolation time of "each power operated" CIV and only require verification of each "automatic isolation valve." Current TS SR 3.6.1.3.5 states: Verify the isolation time of each power operated and each automatic PCIV, except for MSIVs, is within limits. Revised TS SR 3.6.1.3.5 would state (with the removed portion in strikeout and additions in bold): Verify the isolation time of each pmver operated and each power operated, automatic PCIV, except for MSIVs, is within limits. Current TS SR 3.6.4.2.2 states: Verify the isolation time of each power operated and each automatic SCIV is within limits. Revised TS SR 3.6.4.2.2 would state (with the removed portion in strikeout): Verify the isolation time of each power operated, and each automatic SCIV is within limits. NRC Staff Evaluation: The original wording states that the surveillance applied to power operated or automatic containment isolation valves, which could result in an interpretation that power operated valves that do not receive an automatic closure signal for design-basis events are also required to have a closure time associated with them. These changes removed the unintended requirement to verify isolation times of non-automatic power operated CIVs. The changes proposed for the corresponding CIV SRs in HNP TS 3.6.1.3 and TS 3.6.4.2 are the same as those contained in TSTF-46-A. The NRC staff has determined that these changes only clarify the intended scope of CIVs covered by the existing surveillances and are, therefore, administrative in nature. Because the current scope of these surveillances has not changed, there is no impact to safety. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(3) continue to be met because the revised SR provides the appropriate surveillance to ensure the necessary quality of components is maintained and the LCO will be met. Based on the above, the NRC staff concludes that the proposed changes to SRs 3.6.1.3 and 3.6.4.2 are acceptable. 3.4 TSTF-222-A, Revision 1. "Control Rod Scram Time Testing" TSTF-222-A revised BWR STS 3.1.4, "Control Rod Scram Times." TS 3.1.4, "Control Rod Scram Times," SRs 3.1.4.1 and 3.1.4.4, are revised to only require scram time testing of control rods that are in an affected core cell. Current TS SR 3.1.4.1 has a Frequency of: Prior to exceeding 40% RTP [rated thermal power] after fuel movement within the reactor vessel Prior to exceeding 40% RTP after each reactor shutdown 120 days TS SR 3.1.4.4 has a Frequency of: Prior to exceeding 40% RTP after work on control rod or CRD [control rode drive] System that could affect scram time TS SRs 3.1.4.1 and 3.1.4.4 are revised, which deletes the Frequency shown in bold text above from SR 3.1.4.1, and adds a new Frequency as shown in bold text below to SR 3.1.4.4 with an AND statement: Prior to exceeding 40% RTP after fuel movement within the affected core cell. Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time. NRC Staff Evaluation: The changes to SR 3.1.4.1 and SR 3.1.4.4 result in only the affected control rod requiring testing after fuel movement. If a control rod is not affected by fuel movement, there is no basis for expecting that the control rod will perform differently than during the previous scram time test. The NRC staff has determined that these changes only clarify the intent of the existing requirements and do not reduce the testing currently required for demonstrating control rod operability. Therefore, there is no impact to safety since control rod scram time testing will be performed following any fuel movement that could affect the scram time. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(3) continue to be met because the revised SR provides the appropriate surveillance to ensure the necessary quality of components is maintained and the LCO will be met. Based on the above, the NRC staff concludes that the proposed changes to SR 3.1.4.1 and 3.1.4.4 are acceptable. 3.5 TSTF-264-A, Revision 0, "3.3.9 and 3.3.10 -Delete flux monitors specific overlap requirement SRs" TSTF-264-A was submitted to the NRC on May 9, 1998; approved on July 26, 1999; and incorporated into Revision 2 of NUREG-1433, "Standard Technical Specifications -General Electric Plants (BWR/4)," which was published on June 30, 2001. Revision 4 of NUREG-1433 contains many improvements over STS Revision 0, which was issued in 1992. One objective of these improvements was to make TS requirements in the five STS NUREGs consistent for systems that perform essentially the same functions, where possible. Such an improvement was approved by the NRC in TSTF-264-A. 3.5.1 Current HNP TS Requirements for Nuclear Instrumentation Neutron Flux Indication Overlap Verification TS 3.3.1.1, "Reactor Protection System (RPS) Instrumentation," SRs 3.3.1.1.6 and 3.3.1.1.7, require verification of overlap for the source range (neutron flux) monitor (SRM) and intermediate range (neutron flux) monitor (IRM) indications, and for the IRM and average power range (neutron flux) monitor (APRM) indications, respectively. The Bases for these SRs explain what constitutes acceptable overlap in each case and state, in part, that: Overlap between IRMs and APRMs exists when sufficient IRMs and APRMs concurrently have onscale readings such that the transition between MODE 1 and MODE 2 can be made without either APRM downscale rod block, or IRM upscale rod block. Overlap between the SRMs and IRMs similarly exists when, prior to withdrawing an SRM from the fully inserted position, its associated IRMs have cleared their downscale rod block Allowable Values, prior to the SRM having reached its upscale rod block Allowable Value. The Frequency of SR 3.3.1.1.6 (IRM-SRM overlap verification) is, "Prior to withdrawing SRMs from the fully inserted position." The surveillance column note in SR 3.3.1.1.7 (APRM-IRM overlap verification) states, "Only required to be met during entry into MODE 2 from MODE 1." The Frequency of SR 3.3.1.1.7 is, "In accordance with the Surveillance Frequency Control Program." SR 3.3.1.1.1 requires a channel check of IRM and APRM channels in accordance with the surveillance frequency control program (SFCP). As specified in TS Table 3.3.1.1-1, in Mode 2, SR 3.3.1.1.6 applies to RPS Function 1.a, IRM Neutron Flux -High, and SR 3.3.1.1.7 applies to RPS Function 1.a, and Function 2.a, APRM Neutron Flux -High (Setdown). In addition, SR 3.3.1.1.1 applies to both Function 1.a and Function 2.a 3.5.2 Proposed HNP TS Requirements for Nuclear Instrumentation Neutron Flux Indication Overlap Verification The proposed change revises HNP TS 3.3.1.1, "RPS Instrumentation," by deleting SR 3.3.1.1.6 and SR 3.3.1.1.7, which verify the SRM-IRM neutron flux indication overlap and the IRM-APRM neutron flux indication overlap, respectively. TS 3.3.1.1 retains the surveillance number designators but replaces the surveillance statement and any associated surveillance note with the phrase "(Not used.)" and leaves the frequency column blank in the SRs table rows for existing SR 3.3.1.1.6 and SR 3.3.1.1.7. Current TS SR 3.3.1.1.6 states: Verify the source range monitor (SRM) and intermediate range monitor (IRM) channels overlap. Revised TS SR 3.3.1.1.6 would state: (Not used.) Current TS SR 3.3.1.1. 7 states: -----------------------------N()TE:------------------------------()nly required to be met during entry into M()DE: 2 from M()DE: 1. Verify the IRM and APRM channels overlap. Revised TS SR 3.3.1.1.7 would state: (Not used.) A Channel Check is currently required for Functions 1.a and 2.a with a Frequency of "In accordance with the Surveillance Frequency Control Program." HNP TS Section 1.1 defines a Channel Check as follows (the same as the STS definition): A CHANNE:L CHE:CK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter. TSTF-264-A did not propose changes to this definition in the STS because it may be interpreted as requiring SRM-IRM and IRM-APRM neutron flux indication overlap verification for the IRM-and APRM-associated RPS Functions that are required to be operable in Mode 2 (i.e., Functions 1.a and 2.a). With this interpretation, the present indication overlap verifications may be considered redundant to the channel check SR SNC stated that it will relocate the existing discussions of the SR 3.3.1.1.6 and SR 3.3.1.1.7 overlap verification requirements from the existing Bases to the Bases for SR 3. 3.1.1.1. Specifically, the licensee plans to add the following paragraph to SR 3.3.1.1.1 Bases: The agreement criteria includes an expectation of one decade of overlap when transitioning between neutron flux instrumentation. The overlap between SRMs and IRMs must be demonstrated prior to withdrawing SRMs from the fully inserted position since indication is being transitioned from the SRMs to the IRMs. This will ensure that reactor power will not be increased into a neutron flux region without adequate indication. The overlap between IRMs and APRMs is of concern when reducing power into the IRM range (entry into MODE 2 from MODE 1 ). On power increases, the system design will prevent further increases (by initiating a rod block) if adequate overlap is not maintained. Overlap between IRMs and APRMs exists when sufficient IRMs and APRMs concurrently have onscale readings such that the transition between MODE 1 and MODE 2 can be made without either APRM downscale rod block, or IRM upscale rod block. Overlap between SRMs and IRMs similarly exists when, prior to withdrawing the SRMs from the fully inserted position, IRMs are above mid-scale on range 1 before SRMs have reached the upscale rod block. If overlap for a group of channels is not demonstrated (e.g., IRM/APRM overlap), the reason for the failure of the Surveillance should be determined and the appropriate channel(s) declared inoperable. Only those appropriate channels that are required in the current MODE or condition should be declared inoperable. NRC Staff Evaluation: In adopting TSTF-264-A, the HNP TS 3.3.1.1 retains the surveillance number designators but replaces the surveillance statement and any associated surveillance note with the phrase "(Not used.)" and leaves the frequency column blank in the SRs table rows for existing SR 3.3.1.1.6 and SR 3.3.1.1.7. This is in lieu of removing these rows and renumbering the existing subsequent SRs, as done in the traveler's markup of NUREG-1433, Revision 1. In addition, the references to these SRs in HNP TS Table 3.3.1.1-1 are removed. References to SR 3.3.1.1.6 and SR 3.3.1.1.7 in the Bases for HNP TS 3.3.1.2, "SRM Instrumentation," will be replaced by references to SR 3.3.1.1.1. No changes were needed to HNP TS 3.3.1.2 requirements on SRM channel operability, actions, or surveillances in Mode 2 with IRMs on Range 2 or below. SNC stated that it would maintain the existing neutron flux monitor channel indication overlap criteria by relocating the discussion of the criteria to the Bases for HNP TS SR 3.3.1.1.1 for RPS Functions 1.a and 2.a. The overlap check will be performed when SR 3.3.1.1.1 is performed for RPS Functions 1.a and 2.a. Although the TS Bases are a licensee-controlled document, changes to the TS Bases are controlled by the 10 CFR 50.59 process. The NRC staff finds that the licensee continues to uphold the previously approved definition of overlap and will maintain compliance with the requirement to verify SRM-IRM and IRM-APRM indication overlap at the necessary ranges of reactor power by performing the channel check specified for TS 3.3.1.1 Functions 1.a and 2.a at the Frequencies stated in the SFCP. The NRC staff has determined that the proposed changes are in accordance with NRC-approved TSTF-264, Revision 0, with no technical deviations, are consistent with STS Revision 4.0, and the overlap check will still be performed during surveillance testing. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(3) continue to be met because the revised SR provides the appropriate surveillance to ensure the necessary quality of components is maintained and the LCO will be met. Based on the above, the NRC staff concludes the proposed changes to SR 3.3.1.1.6, SR 3.3.1.1.7, and Table 3.3.1.1 1 of HNP TS 3.3.1.1 to be acceptable. 3.6 TSTF-269-A. Revision 2. "Allow administrative means of position verification for locked or sealed valves" The NRC approved this change to STS Revision 1 on July 27, 1999. TSTF-269-A revised STS 3.6.1.3, "Primary Containment Isolation Valves," and 3.6.4.2, "Secondary Containment Isolation Valves," by adding a note that isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means. Current TS 3.6.1.3, Required Action C.2 for Condition C, "One or more penetration flow paths with one PCIV inoperable except due to leakage not within limit," requires: Verify the affected penetration flow path is isolated. With a Frequency of: Once per 31 days Current TS 3.6.4.2, Required Action A.2 for Condition A, "One or more penetration flow paths with one SCIV inoperable," requires: Verify the affected penetration flow path is isolated. With a Frequency of: Once per 31 days. Revised TS 3.6.1.3 and TS 3.6.4.2 would add the following NOTE in the subject Required Actions C.2 and A.2, respectively. Isolation devices that are locked, sealed, or otherwise secured may be verified by administrative means. NRC Staff Evaluation: The NRC staff has reviewed the proposed changes to TS 3.6.1.3 and TS 3.6.4.2 and has determined that administrative controls for such isolation valves have proven to be adequate to ensure the valves are maintained in the positions required by the plant safety analyses when primary and secondary containment are required to be operable. The licensee did not propose a change to Action E since HNP TSs do not contain an equivalent in STS 3.6.1.3. The NRC staff has determined that this is acceptable because TSTF-269-A modification of STS 3.6.1.3 was marked as optional for licensees and HNP TS 3.6.1.3 Action E contains the shutdown requirements in the instance when Required Actions and associated Completion Times of Conditions A, B, C, and D are not met. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(2) continue to be met because the minimum performance level of equipment needed for safe operation of the facility is contained in the LCO, and the appropriate remedial measures are specified if the LCO is not met. Based on the above, the NRC staff concludes that the changes to TS 3.6.1.3 and TS 3.6.4.2 are acceptable. 3. 7 TSTF-273-A, Revision 2, "SFDP [Safety Function Determination Program] Clarifications" The NRC approved TSTF-273-A, Revision 2, to STS Revision 1, as documented in a letter from William Beckner, NRC, to James Davis, Nuclear Energy Institute (NEI), dated August 16, 1999 (ADAMS Accession No. ML 16237A031). TSTF-273-A modified STS 5.5.12, "Safety Function Determination Program (SFDP)," which implements the requirements of LCO 3.0.6. HNP TS 5.5.10, "Safety Function Determination Program (SFDP)," is similar to STS 5.5.12 and contains the following paragraphs: and A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable. The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. The proposed change adds the following statements (shown in bold) in those paragraphs: and A loss of safety function exists when, assuming no concurrent single failure, no concurrent loss of offsite power or no concurrent loss of onsite diesel generator(s), a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable. The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. When a loss of safety function is caused by the inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system. NRC Staff Evaluation: SNC proposed to revise TS 5.5.10 by incorporating TSTF-273-A, Revision 2, changes without deviations. The changes to TS 5.5.10, and the Bases for LCO 3.0.6, are intended to clarify the intent of LCO 3.0.6 in the event a single inoperable TS support system makes both redundant subsystems of a supported system inoperable (a loss of safety function condition). The STS were developed such that the LCO actions for a single support system inoperability would be addressed by that support system's actions, without cascading to the supported system's LCO actions. LCO 3.0.6 establishes this exception to LCO 3.0.2 for support systems that have an LCO specified in the TSs. However, LCO 3.0.6 also requires an evaluation under the SFDP to ensure that a loss of safety function does not exist. The NRC staff concludes that these changes do not affect the design, operation, or maintenance of HNP, but only provide clarity for determining when a loss of safety function condition exists and what LCO actions are required to be taken when a safety function is lost. By clarifying the intent of the existing requirements of the SFDP and LCO 3.0.6, these changes remove an ambiguity that could lead to a misinterpretation of those requirements. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(2) continue to be met because the minimum performance level of equipment needed for safe operation of the facility is contained in the LCO, and the appropriate remedial measures are specified if the LCO is not met. Based on the above, the NRC staff concludes that the changes to TS 5.5.10 are acceptable. 3.8 TSTF-283-A. Revision 3, "Modify Section 3.8 Mode restriction Notes" TSTF-283-A revised certain SR notes in BWR/4 STS 3.8.1, "AC Sources Operating," and 3.8.4, "DC Sources Operating," to allow full or partial performance of the SRs in the prohibited Modes to reestablish operability, provided an assessment determines the safety of the plant is maintained or enhanced. The revised surveillances (SRs 3.8.1.6, 3.8.1.7, 3.8.1.8, 3.8.1.9, 3.8.1.10, 3.8.1.11, 3.8.1.12, 3.8.1.14, 3.8.1.15, 3.8.1.16, 3.8.1.17, 3.8.4.7, and 3.8.4.8) currently have notes prohibiting their performance in Modes 1 or 2, or in Modes 1, 2, or 3. The notes are modified to state that while normally prohibited "in Modes 1 or 2," or "in Modes 1, 2, or 3," the surveillance may be performed to reestablish operability, provided an assessment determines the safety of the plant is maintained or enhanced.

Current TS SR 3.8.1.6 NOTE states, in part, that: This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR. The revised NOTE would state (with the added text in bold) in part, that: This Surveillance shall not normally be performed in MODE 1 or 2. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR

Current TS SR 3.8.1.7 NOTE 1 states, in part, that: This Surveillance shall not be performed in MODE 1 or 2, except for the swing DG. For the swing DG, this Surveillance shall not be performed in MODE 1 or 2 using the Unit [1 or 2]* controls. Credit may be taken for unplanned events that satisfy this SR The revised NOTE would state (with the added text in bold), in part, that: This Surveillance shall not normally be performed in MODE 1 or 2, except for the swing DG. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. For the swing DG, this Surveillance shall not be performed in MODE 1 or 2 using the Unit [1 or 2]* controls. Credit may be taken for unplanned events that satisfy this SR

Current TS SR 3.8.1.8 NOTE 1 states, in part, that: This Surveillance shall not be performed in MODE 1 or 2, except for the swing DG. For the swing DG, this Surveillance shall not be performed in MODE 1 or 2 using the Unit [1 or 2]* controls. Credit may be taken for unplanned events that satisfy this SR The revised NOTE would state (with the added text in bold): This Surveillance shall not normally be performed in MODE 1 or 2, except for the swing DG. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. For the swing DG, this Surveillance shall not be performed in MODE 1 or 2 using the Unit [1 or 2]* controls. Credit may be taken for unplanned events that satisfy this SR

Current TS SR 3.8.1.9 NOTE 2 states, in part, that: This Surveillance shall not be performed in MODE 1, 2 or 3. However, credit may be taken for unplanned events that satisfy this SR The revised NOTE would state (with the added text in bold) in part, that: This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Current TS SR 3.8.1.10 NOTE 2 states, in part, that: This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR. The revised NOTE would state (with the added text in bold), in part, that: This Surveillance shall not normally be performed in MODE 1 or 2. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Current TS SR 3.8.1.11 NOTE states, in part, that: This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR The revised NOTE would state (with the added text in bold), in part, that: This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Current TS SR 3.8.1.12 NOTE 2 states, in part, that: This Surveillance shall not be performed in MODE 1 or 2, unless the other two DGs are OPERABLE. If either of the other two DGs becomes inoperable, this surveillance shall be suspended. Credit may be taken for unplanned events that satisfy this SR. The revised NOTE would state (with the added text in bold), in part, that: This Surveillance shall not normally be performed in MODE 1 or 2, unless the other two DGs are OPERABLE. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. If either of the other two DGs becomes inoperable, this surveillance shall be suspended. Credit may be taken for unplanned events that satisfy this SR.

Current TS SR 3.8.1.14 NOTE states, in part, that: This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR. The revised NOTE would state (with the added text in bold), in part, that: This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Current TS SR 3.8.1.15 NOTE states, in part, that: This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR. The revised NOTE would state (with the added text in bold), in part, that: This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Current TS SR 3.8.1.16 NOTE states, in part, that: This Surveillance shall not be performed in MODE 1. 2, or 3. However, credit may be taken for unplanned events that satisfy this SR. The revised NOTE would state (with the added text in bold), in part, that: This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Current TS SR 3.8.1.17 NOTE 2 states, in part, that: This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR. The revised NOTE would state (with the added text in bold), in part, that: This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Current TS SR 3.8.4.7 NOTE 2 states: This Surveillance shall not be performed in MODE 1, 2, or 3, except for the swing DG battery. However, credit may be taken for unplanned events that satisfy this SR. The revised NOTE would state (with the added text in bold): This Surveillance shall not normally be performed in MODE 1, 2, or 3 except for the swing DG battery. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

Current TS SR 3.8.4.8 NOTE states: This Surveillance shall not be performed in MODE 1, 2, or 3, except for the swing DG battery. However, credit may be taken for unplanned events that satisfy this SR. The revised NOTE would state (with the added text in bold): This Surveillance shall not normally be performed in MODE 1, 2, or 3 except for the swing DG battery. However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. * -As appropriate per unit (i.e., 1 for Unit No. 1 or 2 for Unit No. 2) Deviation from TSTF-283-A: The licensee explained a deviation between the proposed changes and the approved traveler for SR 3.8.4.6 as follows: The Hatch Unit 1 and 2 SR 3.8.4.6 does not contain the Note that is modified, so the changes are therefore not applicable to these Hatch SRs. NRC Staff Evaluation: Initially, when the NRC staff reviewed the proposed changes to the SR notes for HNP, Unit Nos. 1 and 2, some mismatches in the application of the changes were identified when compared to TSTF-283-A, Revision 3. Consequently, the licensee corrected these mismatches in the May 4, 2015, supplement. The NRC did not issue a letter approving this change to STS Revision 1. However, this change was incorporated by the NRC into Revision 2 of the STS in NUREG-1433 for BWR/4 plants issued in June 30, 2001. The intent of the TSTF is to allow testing of the emergency diesel generators (EDGs) and Class 1 E batteries in modes not currently allowed for the purpose of maintaining or reestablishing system or component operability (e.g., post-corrective maintenance testing), provided the licensee performs a safety assessment, as described in the application, that determines the safety of the plant would be maintained or enhanced by conducting the operability testing before the testing begins. The NRC staff reviewed the proposed changes to SR notes in TS 3.8.1 for the alternating current (AC) electrical power sources and TS 3.8.4 for the direct current (DC) electrical power sources and has determined they would provide flexibility in outage scheduling and reduce outage critical path time, since these EDGs and battery surveillance tests would no longer have to be performed during an outage. In addition, the changes will potentially allow avoiding a plant shutdown if corrective maintenance (planned or unplanned) performed during power operation results in the need to perform any of the above surveillances to demonstrate operability. The change will also improve the licensee's flexibility in responding to an event during shutdown when other engineered safety feature (ESF) equipment may be out of service. The NRC staff reviewed the licensee's justification for the deviation for SR 3.8.4.6 and concludes the justification to be acceptable because the applicable note does not exist in the current SR 3.8.4.6. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(3) continue to be met because the minimum performance level of equipment needed for safe operation of the facility is contained in the LCO, and the appropriate remedial measures are specified if the LCO is not met. Based on the above, the NRC staff concludes that the changes to SRs 3.8.1.6, 3.8.1.7, 3.8.1.8, 3.8.1.9, 3.8.1.10, 3.8.1.11, 3.8.1.12, 3.8.1.14, 3.8.1.15, 3.8.1.16, 3.8.1.17, 3.8.4.7, and 3.8.4.8 are acceptable. 3.9 TSTF-284-A. Revision 3, "Add 'Met vs. Perform' to Specification 1.4, Frequency" TSTF-284-A, Revision 3, was approved by the NRC as documented in a letter from William Beckner, NRC, to James Davis, NEI, dated February 16, 2000 (ADAMS Accession No. ML003684596). The change inserts a discussion paragraph into TS 1.4, and several new examples are added to facilitate the use and application of SR notes that utilize the terms "met" and "perform." The changes also modify certain SRs to appropriately use the "met" and "perform" exceptions.

Current TS 1.4 "Frequency," the third paragraph states: Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are "otherwise stated" conditions allowed by SR 3.0.1. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillance, or both. Example 1.4-4 discusses these special situations. Revised TS 1.4 "Frequency," the third paragraph would state (with the deleted section shown in strikethrough): Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are "otherwise stated" conditions allowed by SR 3.0.1. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillance, or both. Example 1.4 4 discusses these special situations. Current TS 1.4 "Frequency," the fifth paragraph states: The use of "met" or "performed" in these instances conveys specific meanings. A Surveillance is "met" only when the acceptance criteria are satisfied. Known failure of the requirements of a Surveillance, even without a Surveillance specifically being "performed," constitutes a Surveillance not "met." "Performance" refers only to the requirement to specifically determine the ability to meet the acceptance criteria. SR 3.0.4 restrictions would not apply if both the following conditions are satisfied. a. The Surveillance is not required to be performed; and b. The Surveillance is not required to be met or, even if required to be met, is known not to be failed. Revised TS 1.4 "Frequency," the fifth paragraph would state (with the added text in bold and the deleted text in strikethrough): The use of "met" or "performed" in these instances conveys specific meanings. A Surveillance is "met" only when the acceptance criteria are satisfied. Known failure of the requirements of a Surveillance, even without a Surveillance specifically being "performed," constitutes a Surveillance not "met." "Performance" refers only to the requirement to specifically determine the ability to meet the acceptance criteria. SR 3.0.4 restrictions would not apply if both the following conditions are satisfied. c. The Surveillance is not required to be performed, and d. The Surveillance is required to be met or, even if it is required to be met, is known not to be failed. Some Surveillances contain notes that modify the Frequency of performance or the conditions during which the acceptance criteria must be satisfied. For these Surveillances, the MODE-entry restrictions of SR 3.0.4 may not apply. Such a Surveillance is not required to be performed prior to entering a MODE or other specified condition in the Applicability of the associated LCO if any of the following three conditions are satisfied: a. The Surveillance is not required to be met in the MODE or other specified condition to be entered; or b. The Surveillance is required to be met in the MODE or other specified condition to be entered, but has been performed within the specified Frequency (i.e., it is current) and is known not to be failed; or c. The Surveillance is required to be met, but not performed, in the MODE or other specified condition to be entered, and is known not to be failed. Examples 1.4-3, 1.4-4, 1.4-5, and 1.4-6 discuss these special situations. TS 1.4, "Frequency," currently includes examples up through Example 1.4-4 regarding the Frequency Based on a Specified Condition. The proposed change would also add Examples 1.4-5 and 1.4-6. EXAMPLE 1.4-5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY --------------------------------N()TE--------------------------------()nly required to be performed in M()DE 1. 7 days -------------------------------------------------------------------------Perform complete cvcle of the valve. The interval continues, whether or not the unit operation is in M()DE 1, 2, or 3 (the assumed Applicability of the associated LC()) between performances. As the note modifies the required performance of the Surveillance, the note is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is not in MODE 1, this note allows entry into and operation in MODES 2 and 3 to perform the Surveillance. The Surveillance is still considered to be performed within the "specified Frequency" if completed prior to entering MODE 1. Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was not in MODE 1, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day frequency not met, provided operation does not result in entry into MODE 1. Once the unit reaches MODE 1, the requirement for the Surveillance to be performed within its specified frequency applies and would require that the Surveillance had been performed. If the Surveillance were not performed prior to entering MODE 1, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply. EXAMPLE 1.4-6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY --------------------------------N 0 TE--------------------------------Not required to be met in MODE 3. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months -------------------------------------------------------------------------Verify parameter is within limits. Example 1.4-6 specifies that the requirements of this Surveillance do not have to be met while the unit is in MODE 3 (the assumed Applicability of the associated LCO is MODES 1, 2, and 3). The interval measurement for the frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance. Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by SR 3.0.2), and the unit was in MODE 3, there would be no failure of the SR nor failure to meet the LCO. Therefore, no violation of SR 3.0.4 occurs when changing MODES to enter MODE 3, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change does not result in entry into MODE 2. Prior to entering MODE 2 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR. NRC Staff Evaluation: The change in TSTF-284-A, Revision 3, is to modify ISTSs, Section 1.4, "Frequency," and to clarify the usage of the terms "met" and "performed" in order to facilitate the application of SR notes. Two new SR Examples, 1.4-5 and 1.4-6, are added to illustrate the application of the terms. STS Section 1.4, "Frequency," defines the proper use and application of SR frequency requirements in the STS format. It states that, "An understanding of the correct application of the specified frequency is necessary for compliance with the SR." It also establishes that, "The specified frequency consists of the requirements of the frequency column of each SR as well as certain NOTES in the Surveillance column that modify performance requirements." The purpose of TSTF-284, Revision 3, was to clarify and make consistent the use of notes in the surveillance column that modify frequency requirements. In adopting TSTF-284, Revision 3, a licensee must verify that NOTES such as those illustrated by these four examples are used properly and only as necessary. This includes ensuring the associated Bases are also correct. Proper application of these NOTES in the individual SRs in the NUREGs was verified. The staff has determined that the proposed changes and HNP adoption of the TSTF changes conforms to the guidance provided in NUREG-1433. These changes are administrative in nature because they only serve to clarify the meaning of the terms "met" and "performed" as used in SR notes throughout the HNP TSs. This change serves to improve TS usefulness by clarifying terminology usage and providing additional examples of the application of SR notes. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(2) continue to be met because the minimum performance level of equipment needed for safe operation of the facility is contained in the LCO, and the appropriate remedial measures are specified if the LCO is not met. Based on the above, the NRC staff concludes that the proposed changes to TS 1.4 are acceptable. 3.10 TSTF-295-A, Revision 0, "Modify Note 2 to Actions of PAM [Post-Accident Monitoring] Table to Allow Separate Condition Entrv for Each Penetration" The NRC approved this change to STS Revision 1 on December 21, 1999. TSTF-295-A revised Table 3.3.3.1-1 of STS 3.3.3.1, "Post Accident Monitoring (PAM) Instrumentation," by (1) prefacing the title of Function 8, "Primary Containment Isolation Valve (PCIV) Position," with the phrase "Penetration Flow Path," and (2) prefacing the title of Function 13, "Suppression Pool Water Temperature," with "Relief Valve Discharge Location." These changes were made to clarify how to apply the actions note to these two functions. The actions note states, "Separate Condition entry is allowed for each Function." The changes clarify that separate condition entry is allowed for each penetration flow path for the PAM PCIV position indication function and for each relief valve discharge location suppression pool temperature indication. The change proposed for corresponding HNP TS 3.3.3.1, Function 6, "Primary Containment Isolation Valve Position," is the same as the changes made to the STS by TSTF-295-A. The licensee did not propose a change to TS 3.3.3.1, Function 9, "Suppression Pool Water Temperature," because of its plant-specific system design as explained by the licensee in its application. Current TS Table 3.3.3.1-1, Function 6, states: Primary Containment Isolation Valve Position Revised TS Table 3.3.3.1-1, Function 6, would state: Penetration Flow Path Primary Containment Isolation Valve Position NRC Staff Evaluation: The NRC staff has determined that this change is administrative because it only clarifies the intended application of action requirements for inoperable channels of HNP TS 3.3.3.1 Function 6 and is consistent with the TS action requirements for PCIVs. This change does not reduce any existing action requirements for these PAM functions and does not affect plant safety. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(2) continue to be met because the minimum performance level of equipment needed for safe operation of the facility is contained in the LCO, and the appropriate remedial measures are specified if the LCO is not met. Based on the above, the NRC staff concludes the proposed change to TS Table 3.3.3.1-1 to be acceptable. 3.11 TSTF-306-A. Revision 2, "Add Action to LCO 3.3.6.1 to give option to isolate the penetration" The NRC approved this change to STS Revision 1 on July 13, 2000. TSTF-306-A revised STS 3.3.6.1, "Primary Containment Isolation Instrumentation," by changing the requirements for the two Traversing In-core Probe (TIP) containment isolation instrumentation functions. Specifically, TSTF-306-A would add functions for TIP system isolation (7.a and 7.b) to STS Table 3.3.6.1-1. Previously, these functions had been included under Primary Containment Isolation Functions 2.a, "Reactor Vessel Water Level -Low Level 3," and 2.b, "Drywell Pressure -High," respectively. TSTF-306-A also revised the actions of STS 3.3.6.1 by listing the new function numbers in the two Completion Times for Required Action A.1. Because these TIP system isolation functions are manual functions, the traveler specified that actions Condition G must be entered immediately upon entering Condition C, "Required Action and associated Completion Time of Condition A or B not met." This action is appropriate because Table 3.3.6.1-1 specifies entering actions Condition G for the other manual isolation instrumentation functions. Furthermore, to be consistent with a similar Note in STS 3.6.1.3, "Primary Containment Isolation," the traveler also added a Note to the STS 3.3.6.1 actions table that states, "Penetration flow paths except for 18 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls." In TS 3.3.6.1, the proposed change adds the following NOTE in the LCO ACTIONS: Penetration flow paths except for 18 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls. Additionally, Current TS 3.3.6.1, Completion Time for Required Action A.1 states: 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Functions 2.a, 2.b, and 6.b 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 2.a, 2.b, and 6.b Revised TS 3.3.6.1, Completion Time for Required Action A.1 would state: 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Functions 2.a, 2.b, 6.b, 7.a, and 7.b 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functions 2.a, 2.b, 6.b, 7.a, and 7.b TS 3.3.6.1 is revised to add the following new Condition G. Additionally, as a result, existing LCO Conditions G, H, and I change to H, I, and J, respectively, and LCO Table 3.3.6.1-1 is revised accordingly. G. As required by Required G.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Action C.1 and referenced in penetration flow path(s). Table 3.3.6.1-1. LCO Table 3.3.6.1-1 is revised to add the new functions 7a and 7b: [see next page]

FUNCTION 7. Traversing lncore Probe System Isolation a. Reactor Vessel Water Level -Low, Level 3 b. Drywell Pressure -High APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS 1,2,3 1,2,3 REQUIRED CHANNELS PER TRIP SYSTEM 2 2 CONDITIONS REFERENCED FROM REQUIRED ACTION C.1 G G SURVEILLANCE ALLOWABLE REQUIREMENTS VALUE SR 3.3.6.1.1 0 inches SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.1 s 1.92 psig SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 NRC Staff Evaluation of the Proposed Changes to TS Requirements for PC IVs: The NRC staff has determined that this change does not reduce the level of safety currently afforded by the HNP TSs because the added allowance stated in the added Note is already permitted by TS 3.6.1.3 and is consistent with the intent of the HNP TS requirements for primary containment penetration flow paths with automatically actuated PC IVs. The addition of this allowance also increases the usability of HNP TSs by clarifying that flow paths isolated to comply with TS 3.3.6.1 action requirements (except for the 18-inch purge valve penetration flow paths) may also be unisolated intermittently under administrative controls .. Associated with this change is enumeration of the existing actions table note in TS 3.3.6.1 regarding separate condition entry for each primary containment isolation instrumentation channel, as Note 2. The NRC staff concludes that this administrative change conforms to the STS format convention for Notes and has no effect on plant safety. Based on the above, the NRC staff concludes that the changes regarding TS requirements for PCIVs are acceptable. NRC Staff Evaluation of Proposed Changes Regarding the TIP System Isolation: The revised LCO and action requirements for TIP system isolation allow TIP penetration flow path isolation rather than a unit shutdown in the event supporting automatic isolation instrumentation function channels are inoperable. This relaxation is appropriate because requiring a unit shutdown is overly restrictive for inoperable TIP system isolation instrumentation. The TIP system uses a small bore penetration (approximately 1/2 inch), and its isolation in a design-basis event is assumed to be accomplished by the manually operated shear valves. The ability to manually isolate the TIP system by either the normal automatic isolation valve (TIP system ball valves) or the shear valve(s) would be unaffected by inoperable instrumentation. Therefore, the option to isolate the penetration and to continue plant operation is provided. In order to implement this allowance, a separate isolation instrumentation function is being provided for the TIP system. The Completion Time provided to isolate the penetration is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , which is the Completion Time provided in the STS for penetration isolation when a manual containment isolation instrumentation function is inoperable. These changes are consistent with the discussion of the TIP system ball and shear valves on HNP, Unit No. 1, FSAR pages 5.2-14 and 7.5-22, that TIP system isolation is accomplished by manual actuation of the ball valves, or by manual actuation of the shear valves in case a deployed TIP cannot be withdrawn. The NRC staff concludes that the small expected penetration leakage rate from a guide tube leak in the reactor pressure vessel allows adequate time for the operator to manually isolate the flow path with the shear valve. Also, the probability of an event requiring automatic isolation of a TIP system guide tube penetration flow path is low. Based on the small expected leakage rate and low probability of an event, the proposed 24-hour Completion Time of proposed new Required Action G.1 provides reasonable assurance of adequate protection of public health and safety. The other changes to TS 3.3.6.1 associated with the new action to isolate the TIP penetration flow path in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months are administrative in nature because they only change the presentation of the existing LCO and action requirements for Functions 2.a and 2.b for the TIP ball valves and do not affect plant safety. The NRC staff concludes that the requirements of 1 O CFR 50.36(c)(2) continue to be met because the minimum performance level of equipment needed for safe operation of the facility is contained in the LCO, and the appropriate remedial measures are specified if the LCO is not met. Based on the above, the NRC staff concludes that the changes to TS 3.3.6.1 and Table 3.3.6.1-1 are acceptable. 3.12 TSTF-308-A. Revision 1. "Determination of Cumulative and Projected Dose Contributions in RECP" The NRC did not issue a letter approving this change to STS Revision 1. However, this change was incorporated by the NRC into Revision 2 of the STS issued in April 2001. TSTF-308-A modified NUREG-1433, STS 5.5.4, "Radioactive Effluent Controls Program," to describe the original intent of the dose projections. Current HNP TS 5.5.4, paragraph e. states: Determination of cumulative and projected dose contributions from radioactive effluents for the current calendar quarter and current calendar year, in accordance with the methodology and parameters in the ODCM [offsite dose calculation manual], at least every 31 days. The proposed change revises paragraph e. in its entirety as follows: Determination of cumulative dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days. Determination of projected dose contributions from radioactive effluents in accordance with the methodology in the ODCM at least every 31 days. NRC Staff Evaluation: The regulation at 1 O CFR 50.36a(a)(2), "Technical specifications on effluents from nuclear power reactors," requires each licensee to submit a report to the NRC that will allow an estimation of the maximum potential annual radiation doses to the public resulting from effluent releases. Generic Letter (GL) 89-01, "Implementation of Programmatic Controls for Radiological Effluent Technical Specifications in the Administrative Controls Section of the Technical Specifications and the Relocation of Procedural Details of PETS to the Offsite Dose Calculation Manual or to the Process Control Program," dated January 31, 1989 (ADAMS Accession No. ML031140051), provides guidance in support of implementing programmatic controls in TSs for radioactive effluents and for radiological environmental monitoring that conforms to the applicable regulatory requirements. The regulation at 1 O CFR 20.1302, "Compliance with dose limits for individual members of the public," paragraph (b), requires that a licensee show compliance with the annual dose limit in 10 CFR 20.1301, "Dose limits for individual members of the public," demonstrating by measurement or calculation that the total effective dose equivalent to the individual likely to receive the highest dose from the licensed operation does not exceed the annual dose limit. GL 89-01 combined two SRs, the cumulative and projected dose determinations, into one program element. In combining these requirements, the new program element can be interpreted to require determining projected dose contributions for the calendar quarter and current calendar year every 31 days. This wording was misleading and resulted in misinterpretation of the intent of the original STS and was not consistent with the original surveillance. Therefore, TSTF-308-A was developed and subsequently approved by the NRC to not require dose projections for a calendar quarter and a calendar year every 31 days (i.e., to describe the actual intent of the dose projections). The NRC staff reviewed the changes proposed by the licensee that were prepared using the guidance in TSTF-308-A. The NRC staff concludes that the revised wording for the HNP TSs clarifies the reporting requirements for projected doses, thus ensuring consistency with the requirements of 10 CFR 50.36a and 10 CFR 20.1302 and, therefore, is acceptable. 3.13 TSTF-318-A. Revision 0, "Revise 3.5.1 for one LPCI pump inoperable in each of two ECCS divisions" The proposed change adds a provision to Condition A of Specification 3.5.1, "ECCS -Operating," to allow one LPCI pump to be inoperable in each subsystem for a period of 7 days. Current TS 3.5.1, Condition A, states: One low pressure ECCS injection/spray subsystem inoperable. Revised TS 3.5.1, Condition A, would state: One low pressure ECCS injection/spray subsystem inoperable. One LPCI pump in both LPCI subsystems inoperable. Current TS 3.5.1, Required Action A.1 for Condition A, states: Restore low pressure ECCS injection/spray subsystem to OPERABLE status. Revised TS 3.5.1, Required Action A.1 for Condition A, would state: Restore low pressure ECCS injection/spray subsystem(s) to OPERABLE status. Current TS 3.5.1, Condition D, states: HPCI System inoperable. One low pressure ECCS injection/spray subsystem inoperable. Revised TS 3.5.1, Condition D, would state: HPCI System inoperable. Condition A entered. Current TS 3.5.1, Condition F, states, in part: Two or more low pressure ECCS injection/spray subsystems inoperable. Revised TS 3.5.1, Condition F, would state, in part: Two or more low pressure ECCS injection/spray subsystems inoperable for reasons other than Condition A. NRC Staff Evaluation: The NRC staff documented its approval of TSTF-318-A, Revision 0, in a letter from William Beckner, NRC to James Davis, NEI dated June 29, 1999 (ADAMS Accession No. ML 16237 A030). The NRC staff reviewed the proposed changes and determined that TSTF-318 is applicable to HNP and is consistent with NUREG-1433. The NRC staff has determined that the proposed change allows the TSs to recognize an additional LPCI configuration that continues to ensure the design-basis analysis is met and is bounded by the currently allowed configuration. The NRC staff also determined that the proposed change is an improvement of the current TS requirements, which would require entry into LCO 3.0.3 and a plant shutdown in the event of one inoperable pump in each LPCI subsystem. Since the LPCI pumps also serve as RHR pumps, the proposed amendment would preclude the licensee having to put the plant in the RHR shutdown cooling configuration at a time when RHR capability is degraded. Additionally, the NRC staff has determined that the requirements of 10 CFR 50.36(c)(2) continue to be met because the minimum performance level of equipment needed for safe operation of the facility is contained in the LCO. and the appropriate remedial measures are specified if the LCO is not met. Based on the above, the NRC staff concludes that the proposed changes to TS 3.5.1 are acceptable. 3.14 TSTF-322-A. Revision 2. "Secondary Containment and Shield Building Boundary Integrity SRs" TSTF-322-A, Revision 2, was approved by the NRC as documented in a letter from William Beckner, NRC, to James Davis, NEI, dated February 16, 2000 (ADAMS Accession No. ML003684596). TSTF-322-A modified the secondary containment boundary integrity and shield building boundary integrity SRs to clarify their intent. Current TS SR 3.6.4.1.3 states: Verify required SGT subsystem(s) will draw down the secondary containment to 0.20 inch of vacuum water gauge in s 120 seconds. Revised TS SR 3.6.4.1.3 would state: Verify secondary containment can be drawn down to :::: 0.20 inch of vacuum water gauge in s 120 seconds using required standby gas treatment (SGT) subsystem(s). Current TS SR 3.6.4.1.4 states: Verify required SGT subsystem(s) can maintain :::: 0.20 inch of vacuum water gauge in the secondary containment for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months at a flow rate s 4000 cfm [cubic feet per minute] for each subsystem. Revised TS SR 3.6.4.1.4 would state: Verify the secondary containment can be maintained :::: 0.20 inch of vacuum water gauge for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months using required SGT subsystem(s) at a flow rate s 4000 cfm per subsystem. NRC Staff Evaluation: The changes to the secondary containment SRs in HNP TS 3.6.4.1 conform to the intent of the changes made to the STS by TSTF-322-A, with the exception of the surveillance frequency. The surveillance frequency is controlled by the SFCP, which is a program developed subsequent to the approval of TSTF-322-A. The NRC staff reviewed the TS changes and has determined that they clarify the intent of the drawdown tests for demonstrating operability of the secondary containment. If an SGT subsystem is inoperable, TS 3.6.4.3 specifies appropriate action requirements; it does not imply that the secondary containment is inoperable. The proposed changes only clarify the intended meaning of the existing SRs; therefore, they are administrative in nature and have no safety impact. Additionally, the NRC staff has determined that that the requirements of 10 CFR 50.36(c)(3) continue to be met because the revised SRs provide the appropriate surveillance to ensure the necessary quality of components is maintained and the LCO will be met. Based on the above, the NRC staff concludes that the changes to SR 3.5.4.1.3 and SR 3.6.4.1.4 are acceptable. 3.15 TSTF-323-A. Revision 0. "EFCV [Excess Flow Check Valve] Completion Time to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months " As stated in Section 3.1 of this safety evaluation, the TSTF-323-A change preceded the approval of, and was subsumed in, the final version (Revision 3) of TSTF-30. Therefore, Section 3.1 of this safety evaluation discusses the licensee's proposed adoption of both TSTF-30 and TSTF-323-A changes and provides the NRC staff's assessment. 3.16 TSTF-37 4-A, Revision 0, "Revision to TS 5.5.13 and associated TS Bases for Diesel Fuel Oil" The NRC staff documented its approval of TSTF-374-A, Revision 0, in a letter from Thomas H. Boyce, NRC, to the TSTF dated January 13, 2005 (ADAMS Accession No. ML050130309), and the NRC approved this change to STS Revision 2 on April 14, 2006. TSTF-374-A revises STS 5.5.9, "Diesel Fuel Oil Testing Program," diesel fuel oil testing program (DFOTP) to remove references to the specific American Society for Testing and Materials (ASTM) standard from the administrative controls section of TSs and alternatively places them in a licensee-controlled document. Specific criteria are added to establish the acceptability of new fuel oil for use prior to, and following, the addition to storage tanks. The DFOTP of HNP, Unit Nos. 1 and 2, is located at TS 5.5.9, while the STS DFOTP is located at TS 5.5.1 O; however, this difference in numbering is immaterial to the proposed change. Current TS 5.5.9 states: A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following: a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has not become contaminated with other products during transit, thus altering the quality of the fuel oil; and b. Total particulate concentration of the fuel oil is 10 mg [milligram]/liter when tested every 92 days utilizing the guidance provided in ASTM D-2276, Method A-2 or A-3. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program surveillance frequencies. Revised TS 5.5.9 would state: A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following: a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has: 1. An API [American Petroleum Institute] gravity or an absolute specific gravity within limits, 2. A flash point and kinematic viscosity within limits for ASTM 2D fuel oil, and 3. A water and sediment content within limits; b. Within 31 days following addition of the new fuel oil to storage tanks, verify that the properties of the new fuel oil, other than those addressed in a., above, are within limits for ASTM 2D fuel oil; and c. Total particulate concentration of the fuel oil is s 10 mg/liter when tested every 92 days. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program surveillance frequencies. NRC Staff Evaluation: The NRC staff has reviewed the changes to the DFOTP in TS 5.5.9. For HNP, the result is a specification closer to the STS than the previous specification. The former requirements, which were subject to interpretation, " ... fuel oil has not become contaminated with other products during transit, thus altering the quality of the fuel oil," are replaced by more objective tests for American Petroleum Institute gravity or specific gravity, flash point and kinematic viscosity, and sediment and water content. A specific time limit of 31 days is added for new fuel to storage tanks, and particulate content testing requirements are retained. Additionally, because of significant differences between this licensee's TS bases and the STS bases, this licensee will control the removed ASTM requirements in a license-controlled procedure. The licensee states that future changes are also subject to a 10 CFR 50.59 review as they would be in the TS Bases. The NRC staff has determined that the proposed changes to TS 5.5.9 conform to the intent of TSTF-37 4-A. Additionally, the NRC staff has determined that the requirements of 10 CFR 50.36(c)(5) continue to be met because the revised TSs provide the appropriate administrative controls to ensure the necessary quality of the fuel oil is maintained. Based on the above, the NRC staff concludes that the proposed changes to TS 5.5.9 are acceptable. 3.17 TSTF-400-A, Revision 1. "Clarify SR on Bypass of DG [Diesel Generator) Automatic Trips" The NRCs approval of TSTF-400-A, Revision 1, is documented by letter to the TSTF dated November 13, 2004 (ADAMS Accession No. ML043200067). The proposed change revises TS 3.8.1, "AC Sources -Operating," Surveillance 3.8.1.11, to clarify that the intent of the SR is to test the non-critical emergency DG automatic trips. The numbering of SRs in the HNP TSs is different from the STS numbering. STS SR 3.8.1.13 corresponds to SR 3.8.1.11 in the HNP TSs. This has no effect on the requested change. Current TS SR 3.8.1.11 states, in part that: Verify each DG's automatic trips are bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ECCS initiation signal except: a. Engine overspeed; b. Generator differential current; and c. Low lube oil pressure. Revised TS SR 3.8.1.11 would state: Verify each DG's non-critical automatic trips are bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ECCS initiation signal. NRC Staff Evaluation: The changes to SR 3.8.1.11 and the associated TS bases state that the SR only verifies that non-critical DG trips are bypassed. The non-critical DG trips are bypassed during design-basis accidents and provide an alarm on an abnormal engine condition. The NRC staff reviewed this change and has determined that it provides clarification, and no STS requirements are materially altered. Additionally, the NRC staff has determined that the requirements of 10 CFR 50.36(c)(3) continue to be met because the revised SR provides the appropriate surveillance to ensure the necessary quality of components is maintained and the LCO will be met. Based on the above, the NRC staff concludes that the changes to SR 3.8.1.11 are acceptable. 3.18 TSTF-439-A. Revision 2. "Eliminate Second Completion Times Limiting Time From Discovery of Failure To Meet an LCO" The NRC approved TSTF-439-A, Revision 2, in a letter dated January 11, 2006 (ADAMS Accession No. ML060120272). TSTF-439-A revised the STS by eliminating the second Completion Times limiting time from discovery of failure to meet an LCO from the affected Required Actions and modifies the example in TS 1.3. These Completion Times (henceforth referred to as "second Completion Times") are joined by an "AND" logical connector to the condition-specific Completion Time and state, "X days from discovery of failure to meet the LCO" (where "X" varies by specification). HNP TSs 3.1. 7, "Standby Liquid Control (SLC) System"; 3.6.4.3, "Standby Gas Treatment (SGT) System"; 3.8.1, "AC Sources -Operating"; and 3.8.7, "Distribution Systems -Operating," contain Required Actions with a second Completion Time to establish a limit on the maximum time allowed for any combination of conditions that result in a single continuous failure to meet the LCO. The proposed change deletes these second Completion Times from the affected Required Actions.

Current TS 3.1.7, Completion Time for Required Action A.1, states: 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 10 days from discovery of failure to meet the LCO Revised TS 3.1.7, Completion Time for Required Action A.1, would state: 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

Current TS 3.6.4.3, Completion Time for Required Action 8.1, states: 7 days 30 days from discovery of failure to meet the LCO Revised TS 3.6.4.3, Completion Time for Required Action 8.1, would state: 7 days

Current TS 3.8.1, Completion Time for Required Action A.3, states: 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 17 days from discovery of failure to meet LCO 3.8.1.a, b, or c Revised TS 3.8.1, Completion Time for Required Action A.3, would state: 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

Current TS 3.8.1, Completion Time for Required Action 8.4, states: 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for a Unit 1 DG with the swing DG not inhibited or maintenance restrictions not met 14 days for a Unit 1 DG with the swing DG inhibited from automatically aligning to Unit 2 and maintenance restrictions met 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for the swing diesel with maintenance restrictions not met 14 days for the swing diesel with maintenance restrictions met 17 days from discovery of failure to meet LCO 3.8.1.a, b, or c Revised TS 3.8.1, Completion Time for Required Action B.4, would state: 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for a Unit 1 DG with the swing DG not inhibited or maintenance restrictions not met 14 days for a Unit 1 DG with the swing DG inhibited from automatically aligning to Unit 2 and maintenance restrictions met 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for the swing diesel with maintenance restrictions not met 14 days for the swing diesel with maintenance restrictions met

Current TS 3.8.7, Completion Time for Required Action B.1, states: 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 16 hours from discovery of failure to meet LCO 3.8.7.a Revised TS 3.8.7, Completion Time for Required Action B.1, would state: 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

Current TS 3.8.7, Completion Time for Required Action C.1, states: 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 16 hours from discovery of failure to meet LCO 3.8.7.a Revised TS 3.8.7, Completion Time for Required Action C.1, would state: 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

Current TS 3.8.7, Completion Time for Required Action D.1, states: 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 16 hours from discovery of failure to meet LCO 3.8.7.a Revised TS 3.8. 7, Completion Time for Required Action D.1, would state: 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months The proposed change also revises TS Section 1.3, Example 1.3-3 (as shown below), to remove the discussion of second Completion Times and to revise the discussion in that example to state that alternating between conditions in such a manner that operation could continue indefinitely, without restoring systems to meet the LCO, is inconsistent with the basis of the Completion Times and is inappropriate. The proposed changes to TS 1.3, "Completion Times," are as follows:

The last paragraph on TS page 1.3-2 currently states, in part, that: Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended. The proposed change deletes the above statement.

Example 1.3-3 currently reflects for Conditions A and B, a first Completion Time of 7 days and 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , respectively, and a second Completion Time as "AND 10 days from discovery of failure to meet the LCO," for both conditions. Condition C in the example does not contain a second Completion Time. The proposed change revises Example 1.3-3 to eliminate the second Completion Times, "10 days from discovery of failure to meet the LCO," from Conditions A and B.

TS Section 1.3, the last paragraph currently describes second Completion Time as follows: The Completion Times of Conditions A and B are modified by a logical connector, with a separate 1 O day Completion Time measured from the time it was discovered the LCO was not met. In this example, without the separate Completion Time, it would be possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. The separate Completion Time modified by the phrase "from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO. This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock". In this instance, the Completion Time "time zero" is specified as commencing at the time the LCO was initially not met, instead of at the time the associated Condition was entered. The proposed change replaces the above paragraph with the following: It is possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. However, doing so would be inconsistent with the basis of the Completion Times. Therefore, there shall be administrative controls to limit the maximum time allowed for any combination of Conditions that result in a single contiguous occurrence of failing to meet the LCO. These administrative controls shall ensure that the Completion Times for those Conditions are not inappropriately extended. As stated in Section 4.0, "Commitments," of the application, SNC specifies the following commitment regarding its proposed change: SNC commits to revise Operations procedure 31GO-OPS-006-0 to include a statement similar to the following: "Alternating between LCO Conditions, in order to allow indefinite continued operation while not meeting the LCO, is not allowed." The licensee also stated that the procedure will be revised prior to implementation of the proposed TS change. NRC Staff Evaluation: The Maintenance Rule (10 CFR 50.65(a)(1 )), requires licensees to monitor the performance or conditions of structures, systems, and components (SSCs) in a manner sufficient to provide reasonable assurance that SSCs are capable of fulfilling their intended functions. If the performance or condition of an SSC does not meet established goals, appropriate corrective action is required to be taken. The NRC resident inspectors monitor the licensee's corrective action program and can take action if the licensee's maintenance program allows the systems required by a single LCO to become concurrently inoperable multiple times. The performance and condition monitoring activities required by 10 CFR 50.65 (a)(1) and (a)(2) would identify if poor maintenance practices resulted in multiple entries into the actions of the TSs and unacceptable unavailability of these SSCs. The effectiveness of these performance monitoring activities, and associated corrective actions, is evaluated at least every refueling cycle, not to exceed 24 months, per 10 CFR 50.65 (a)(3). Prior to 10 CFR 50.65, TSs were the primary rules governing operations, including what equipment must normally be in service, how long equipment can be out of service, compensatory actions, and surveillance testing to demonstrate equipment readiness. A goal of the TSs is to provide adequate assurance of the availability and reliability of equipment needed to prevent, and if necessary, mitigate, accidents and transients. The Maintenance Rule shares this goal and operates through a dynamic and comprehensive process. The objective of the cornerstone is to monitor the availability, reliability, and capability of systems that mitigate the effects of initiating events to prevent core damage. Licensees also reduce the likelihood of reactor accidents by maintaining the availability and reliability of mitigating systems. Mitigating systems include those systems associated with safety injection, decay heat removal, and their support systems, such as emergency AC power systems (which encompasses the AC sources distribution system LCOs, as noted by the licensee), and the auxiliary feedwater system. Inputs to the mitigating systems cornerstone include both inspection procedures and performance indicators to ensure that all reactor oversight process objectives are being met. Satisfactory licensee performance within the mitigation systems reactor oversight process cornerstone provides reasonable assurance in monitoring the inappropriate use of TS condition Completion Times. The NRC approved this change to the STS on January 11, 2006. TSTF-439-A revised Example 1.3-3 of the TSs to state, in part, "There shall be administrative controls to limit the maximum time allowed for any combination of Conditions that result in a single contiguous occurrence of failing to meet the LCO. These administrative controls shall ensure that the Completion Times for those Conditions are not inappropriately extended." SNC provided a regulatory commitment to revise Operations Procedure 31GO-OPS-006-0 to include a statement similar to the following: "Alternating between LCO Conditions, in order to allow indefinite continued operation while not meeting the LCO, is not allowed." The licensee will revise the procedure prior to implementation of the proposed change. The NRC staff concludes that the proposed changes establish a new TS convention to appropriately limit the time allowed for the plant to operate in any combination of LCO conditions that could result in a single continuous failure to meet the LCO. The new convention meets the intent of the Completion Times. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(2) remain unaffected by the proposed changes and would continue to be met because the minimum performance level of equipment needed for safe operation of the facility is contained in the LCO, and the appropriate remedial measures are specified if the LCO is not met. Based on the above, the NRC staff concludes that the changes to TSs 1.3, 3.1.7, 3.6.4.3, 3.8.1, and 3.8.7, are acceptable. 3.19 TSTF-458-T. Revision 0. "Removing Restart of Shutdown Clock for Increasing Suppression Pool Temperature" TSTF-458-T, Revision 0, revises BWR STS 3.6.2.1, "Suppression Pool Average Temperature," to remove a potential ambiguity between Actions D and E that would allow resetting of the shutdown Completion Time clock. Current TS 3.6.2.1, Condition D, states: Suppression pool average temperature > 110°F but s 120°F. Revised TS 3.6.2.1, Condition D, would state: Suppression pool average temperature > 110°F. Current TS 3.6.2.1, Required Action D.2, states: Verify suppression pool average temperature s 120°F. Revised TS 3.6.2.1, Required Action D.2, would state: Determine suppression pool average temperature. Current TS 3.6.2.1, Required Actions E.1 and E.2, states: E.1 Depressurize the reactor vessel to < 200 psig. AND E.2 Be in MODE 4. With Required Action E.2 having a Completion Time of: 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Revised TS 3.6.2.1 would state: Required Action E.2 and its associated Completion Time of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months are deleted, resulting in Required Action E.1 remaining: E.1 Depressurize the reactor vessel to < 200 psig. NRC Staff Evaluation: AT-traveler, such as TSTF-458-T, Revision 0, is prepared by the industry to provide further clarification of specific TS requirements, without changing the intent or scope of those requirements. The NRC does not review nor approve T-travelers, and the proposed changes under T-travelers are not incorporated in the respective STS. The NRC staff reviewed these changes and determined that they ( 1) clarify the scope of Condition D and the intent of specified actions in Condition D, and (2) remove a redundant action in Condition E to eliminate an ambiguity between specified actions for existing Conditions D and E. Thus, these changes are of administrative nature and do not affect the technical content of specified TS requirements. Specifically, this eliminates having two Required Actions and Completion Times, both directing entry into MODE 4 with staggered Completion Times. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(2) continue to be met because the revised LCO conditions provide appropriate requirements to ensure that the LCO will be met. Based on the above, the NRC staff concludes that the changes to TS 3.6.2.1 are acceptable. 3.20 TSTF-464-T. Revision 0, "Clarify the Control Rod Block Instrumentation Required Action" The proposed change clarifies the wording of Required Action C.2.1.2 of HNP TS 3.3.2.1, "Control Rod Block Instrumentation," to align with the TS Bases, Section 3.3.2.1. Current Hatch TS, and Proposed Changes: Current TS 3.3.2.1, Required Action C.2.1.2, states: Verify by administrative methods that startup with RWM [rod worth minimizer] inoperable has not been performed in the last calendar year. Revised TS 3.3.2.1, Required Action C.2.1.2, would state: Verify by administrative methods that startup with RWM inoperable has not been performed in the last 12 months. NRC Staff Evaluation: AT-traveler, such as TSTF-464-T, Revision 0, was prepared by the industry to provide further clarification of specific TS requirements, without changing the intent or scope of those requirements. The NRC did not review nor approve T-travelers, and the proposed changes under T-travelers were not incorporated in the respective STS. The NRC staff reviewed the proposed change and determined that the current ambiguity of the phrase "last calendar year" does not provide assurance that the appropriate remedial measures are performed if the LCO is not met. Replacing the phrase "last calendar year" with the proposed phrase "last 12 months" provides additional clarity and assurance that appropriate remedial measures are performed if the LCO is not met. Additionally, the NRC staff concludes that the requirements of 10 CFR 50.36(c)(2)will be met with the proposed change because the minimum performance level of equipment needed for safe operation of the facility is contained in the LCO. Based on the above, the NRC staff concludes that the change to TS 3.3.2.1 is acceptable. 3.21 STS Adoption #1 -Revise the 5.5.7 Introductory Paragraph to be Consistent with the ISTS The licensee proposed to adopt the formatting and language in the STS, NUREG-1433, STS for General Electric BWR/4 Plants, Revision 4. Current TS 5.5. 7, "Ventilation Filter Testing Program (VFTP)," the introductory paragraph states: The VFTP will establish the required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2, Sections C.5.c and C.5.d, or: 1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, 2) following painting, fire or chemical release in any ventilation zone communicating with the system, or 3) after every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of charcoal adsorber operation. TS 5.5.7 is revised to state: A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2, Sections C.5.c and C.5.d, and in accordance with Regulatory Guide 1.52, Revision 2. NRC Staff Evaluation: The changes proposed for HNP TS 5.5.7 are similar to the wording in STS 5.5.8. This change removes detail from TS 5.5.7 and makes reference to RG 1.52, "Design, Testing, and Maintenance Criteria for Post-Accident Engineered-Safety-Feature Atmosphere Cleanup System Air Filtration and Adsorption Units of Light-Water-Cooled Nuclear Power Plants." The list of requirements for the program that the licensee proposed to remove are covered in Section C.6.b of RG 1.52 and TS SR 3.0.1. The NRC staff reviewed the proposed changes and determined that incorporating the requirement by reference for the VFTP is acceptable because detail can be removed from the TSs while maintaining the testing requirement. This simplifies the TSs and allows wording and formatting to be consistent with the STS, encouraging uniformity between the HNP units and the SNC fleet. Additionally, the NRC staff concludes that the requirements of 1 O CFR 50.36(c)(5) continue to be met because the revised TS administrative controls testing program maintains its implementation requirements. Based on the above, the NRC staff concludes that the changes to TS 5.5.7 are acceptable. 4.0 REGULATORY COMMITMENTS SNC provided two regulatory commitments with the LAR. The first regulatory commitment states: A statement will be added to the FSAR similar to the following regarding the performance of logic testing for critical emergency diesel generator trip functions: The critical emergency diesel generator protective trip functions (i.e., engine overspeed, generator differential current, and low lube oil pressure) are tested periodically per station procedures. The critical protective trip functions are tested by inputting or simulating appropriate signals and demonstrating that the associated instrumentation logic will function to actuate a trip of the emergency diesel generator. This regulatory commitment is related to the adoption of TSTF-400 (discussed in Section 3.17 of this safety evaluation). The NRC staff reviewed the commitment and found that it provides additional information clarifying the testing of the EOG trip functions. The NRC staff did not use the regulatory commitment as a basis for its conclusion for Section 3.17 of this safety evaluation. The second regulatory commitment states: SNC commits to revise Operations procedure 31GO-OPS-006-0 to include a statement similar to the following: "Alternating between LCO Conditions, in order to allow indefinite continued operation while not meeting the LCO, is not allowed." This regulatory commitment is related to the adoption of TSTF-439 (discussed in Section 3.18 of this safety evaluation). The NRC staff reviewed the commitment and finds that it specifies a location for the administrative controls of TSTF-439-A. The NRC staff did not use the regulatory commitment as a basis for its conclusion for Section 3.18 of this safety evaluation.

5.0 STATE CONSULTATION

In accordance with the Commission's regulations, the Georgia State official was notified of the proposed issuance of the amendments on June 22, 2016. The State official had no comments.

6.0 ENVIRONMENTAL CONSIDERATION

The amendments change a requirement with respect to the installation or use of facility components located within the restricted area as defined in 10 CFR Part 20 and change SRs. The NRC staff has determined that the amendments involve no significant increase in the amounts and no significant change in the types of any effluents that may be released offsite and that there is no significant increase in individual or cumulative occupational radiation exposure. The Commission has previously issued a proposed finding that the amendments involve no significant hazards consideration, and there has been no public comment on such finding (80 FR 17095; March 31, 2015). Accordingly, the amendments meet the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments.

7.0 CONCLUSION

The Commission has concluded, based on the considerations discussed above, that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) there is reasonable assurance that such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendments will not be inimical to the common defense and security or to the health and safety of the public. Principal Contributors: Craig Harbuck, NRO Hien Le, NRO Margaret Chernoff, NRR Caroline Tilton, NRR Khadijah West, NRR Ravinder Grover, NRR Date: September 29, 2016 Theodore Tjader, NRO Derek Scully, NRO Matthew Hamm, NRR Pete Snyder, NRR Larry Wheeler, NRR C. Pierce A copy of the related Safety Evaluation is also enclosed. Notice of Issuance will be included in the Commission's biweekly Federal Register notice. Docket Nos. 50-321 and 50-366

Enclosures:

1. Amendment No. 279 to DPR-57 2. Amendment No. 223 to NPF-5 3. Safety Evaluation Sincerely, IRA/ Michael D. Orenak, Project Manager Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation cc w/enclosures: Distribution via Listserv DISTRIBUTION: PUBLIC LPL2-1 R/F RidsACRS_MailCTR Resource RGrover, NRR RidsNrrDorlDpr Resource RidsNrrDorllpl2-1 Resource Hle, NRO MChernoff, NRR CTilton, NRR KWest, NRR RGrover, NRR RidsNrrDssStsb Resource RidsNrrPMHatch Resource RidsNrrLALRonewicz Resource RidsRgn2Mail Center Resource RecordsAmend CHarbuck, NRO DScully, NRO MHamm, NRR PSnyder, NRR LWheeler, NRR TTjader, NRO ADAMS Accession No.: ML 16231A041 *by e-mail OFFICE NRR/DORL/LPL2-1 /PM NRR/DORL/LPL2-1 /LA NRR/DSS/STSB/BC* NAME MOrenak LRonewicz AKlein DATE 8/23/2016 8/23/2016 7/27/2016 OFFICE OGC NLO wlcomments NRR/DORL/LPL2-1 /BC NRR/DORL/LPL2-1/PM NAME Jlindell MMarkley MOrenak DATE 9/06/2016 9/29/2016 9/29/2016 OFFICIAL RECORD COPY

v t e Letter Sequence Approval
CAC:MF5026, TSTF-37, TSTF-30, TSTF-45, TSTF-46, Clarify SR on Bypass of DG Automatic Trips, Revision to TS 5.5.13 and Associated TS Bases for Diesel Fuel Oil, Modify Section 3.8 Mode Restriction Notes, Allow Administrative Means of Position Verification for Locked or Sealed Valves, Add Action to LCO 3.3.6.1 to Give Option to Isolate the Penetration, Control Rod SCRAM Time Testing, 3.3.9 and 3.3.10 - Delete Flux Monitors Specific Overlap Requirement SRS, SFDP Clarifications, Add Met Vs. Perform to Specification 1.4, Frequency, Modify Note 2 to Actions of PAM Table to Allow Separate Condition Entry for Each Penetration, Determination of Cumulative and Projected Dose Contributions in Recp, Revise 3.5.1 for One Lcpi Pump Inoperable in Each of Two ECCS Divisions, Secondary Containment and Shield Building Boundary Integrity SRS, EFCV Completion Time to 72 Hours, Eliminate Second Completion Times Limiting Time from Discovery of Failure to Meet an LCO, Removing Restart of Shutdown Clock for Increasing Suppression Pool Temperature, Clarify the Control Rod Block Instrumentation Required Action (Approved, Closed) CAC:MF5027, TSTF-37, TSTF-30, TSTF-45, TSTF-46, Clarify SR on Bypass of DG Automatic Trips, Revision to TS 5.5.13 and Associated TS Bases for Diesel Fuel Oil, Modify Section 3.8 Mode Restriction Notes, Allow Administrative Means of Position Verification for Locked or Sealed Valves, Add Action to LCO 3.3.6.1 to Give Option to Isolate the Penetration, Control Rod SCRAM Time Testing, 3.3.9 and 3.3.10 - Delete Flux Monitors Specific Overlap Requirement SRS, SFDP Clarifications, Add Met Vs. Perform to Specification 1.4, Frequency, Modify Note 2 to Actions of PAM Table to Allow Separate Condition Entry for Each Penetration, Determination of Cumulative and Projected Dose Contributions in Recp, Revise 3.5.1 for One Lcpi Pump Inoperable in Each of Two ECCS Divisions, Secondary Containment and Shield Building Boundary Integrity SRS, EFCV Completion Time to 72 Hours, Eliminate Second Completion Times Limiting Time from Discovery of Failure to Meet an LCO, Removing Restart of Shutdown Clock for Increasing Suppression Pool Temperature, Clarify the Control Rod Block Instrumentation Required Action (Approved, Closed)
Initiation Acceptance... Supplement Administration Questions Answers Results Approval Other: ML19164A017
MONTHYEAR2016-09-29 [Table View]

ML16231A041

Text

SUBJECT:

Dear Mr. Pierce:

Enclosures:

Attachment:

Attachment:

1.0 INTRODUCTION

2.0 REGULATORY EVALUATION

3.0 TECHNICAL EVALUATION

5.0 STATE CONSULTATION

6.0 ENVIRONMENTAL CONSIDERATION

7.0 CONCLUSION

Enclosures:

Navigation menu

Search