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Supplement to Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee-Controlled Program
	ML16196A240
Person / Time
Site:	Brunswick
Issue date:	06/29/2016
From:	William Gideon; Duke Energy Progress
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	BSEP 16-0047, TSC-2015-03
	Download: ML16196A240 (40)
	v • d • e

William R. Gideon

(-,DUKE

~ ENERGY Vice President Brunswick Nuclear Plant P.O. Box 10429 Southport, NC 28461 o: 910.457.3698 June 29, 2016 Serial: BSEP 16-0047 TSC-201 S-03 10 CFR S0.90 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20SSS-0001

Subject:

Brunswick Steam Electric Plant, Unit Nos. 1 and 2 Renewed Facility Operating License Nos. DPR-71 and DPR-62 Docket Nos. S0-32S and S0-324 Supplement to Application For Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee-Controlled Program *

References:

1. Duke Energy Progress, Inc. letter, Brunswick Steam Electric Plant, Unit Nos. 1 and 2, Application For Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee-Control/ed Program, dated December 21, 201 S (ML16004A249)

2. Nuclear Regulatory Commission letter, Brunswick Steam Electric Plant, Unit Nos. 1 and 2; Shearon Harris Nuclear Power Plant, Unit 1; Catawba Nuclear Station, Units 1 and 2; McGuire Nuclear Station, Units 1 and 2; and Oconee Nuclear Station, Units 1, 2, and 3: Issuance of Amendments Regardjng Adoption of TSTF-523 (GAG Nos. MF6413 Through MF6422), dated April 29, 2016 (ML1608SA113)

Ladies and Gentlemen:

By letter dated December 21, 201 S (i.e., Reference 1), Duke Energy Progress, Inc. (Duke Energy) submitted a license amendment request (LAR) for the Brunswick Steam Electric Plant (BSEP), Unit Nos. 1 and 2. The proposed amendments modify the Technical Specifications (TSs) by relocating specific surveillance*trequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specification Initiative Sb, Risk-Informed Method for Control of Surveillance Frequencies." Additionally, the change would add a new program, the Surveillance Frequency Control Program, to TS Section S.S, "Programs and Manuals." The c~anges are consistent with Nuclear Regulatory ;

Commission (NRG) approved Technical Specification Task Force (TSTF) Standard T,echnical Specifications (STS) Change TSTF-42S, "Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative Sb," Revision 3 (ADAMS Accession No. ML0908S0642).

On April 29, 2016, the NRG issued Amendments 270 and 298 to the Renewed Facility Operating License for BSEP Units 1.and 2, respectively (i.e., Reference 2). These amendments approved the adoption of TSTF-S23, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation." These amendments included new Surveillance Requirements (SRs) and

U.S. Nuclear Regulatory Commission Page 2 of 3 revised existing SRs that fall within the scope of the proposed TSTF-425 LAR. As such, this submittal supplements the original TSTF-425 LAR to include the new SRs and revise the impacted SRs consistent with Amendments 270 and 298. The following table provides a listing

of the impacted SRs.

New Surveillance Requirements Impacted Surveillance Requirements SR 3.4.7.2 SR 3.5.1.1 SR 3.4.8.2 SR 3.5.1.2 SR 3.6.2.3.3 SR 3.5.2.3 SR 3.9.7.2 SR 3.5.2.4 SR 3.9.8.2 SR 3.5.3.1 SR 3.5.3.2 Duke Energy has determined that the relocation of the frequencies for the newly issued and revised SRs is consistent with the intent of TSTF-425, Revision 3, and with the NRC's model safety evaluation dated July 6, 2009 (74 FR 31996), including the scope exclusions identified in Section 1.0, "Introduction," of the model safety evaluation. As such, this supplement does not change the No Significant Hazards Determination provided in Reference 1.

Enclosures 1 and 2 provide the impacted TS pages marked up to show the proposed changes for Units 1 and 2, respectively. Enclosure 3 provides a cross-reference between the TSTF-425 marked up TS pages and the BSEP Unit 1 and 2 TS pages. Revisions to this table are identified with a revision bar in the right margin.

In accord~nce with 10 CFR 50.91, Duke Ene.rgy is providing a copy of the proposed license amendment to the designated representative for the State of North Carolina.

Please refer any questions regarding this submittal to Mr. Lee Grzeck, Manager - Regulatory Affairs, at {910) 457-2487.

I declare, under penalty of perjury, that the foregoing is true and correct. Executed on June 29, 2016.

Sincerely, r* _.,f\(\

~

William R. Gideon

'I MAT/mat

Enclosures:

1. Marked-up Technical Specification and Operating License Pages - Unit 1

2. Marked-up Technical Specification and Operating License Pages - Unit 2

3. Cross-Reference between TSTF-425, Revision 3 and BSEP Technical Specifications

}

U.S. Nuclear Regulatory Commission Page 3 of 3 cc (with enclosures):

U.S. Nuclear Regulatory Commission, Region II ATTN: Ms. Catherine Haney, Regional Administrator 245 Peachtree Center Ave, NE, Suite 1200 Atlanta, GA 30303-1257 U.S. Nuclear Regulatory Commission ATTN: Mr. Andrew Hon (Mail Stop OWFN 8G9A) (Electronic Copy Only) 11555 Rockville Pike Rockville, MD 20852-2738 U.S. Nuclear Regulatory Commission ATTN: Ms. Michelle Catts, NRC Senior Resident Inspector 8470 River Road Southport, NC 28461-8869 Chair - North Carolina Utilities Commission 4325 Mail Service Center Raleigh, NC 27699-4300 Mr. W. Lee Cox, Ill, Section Chief (Electronic Copy Only)

Radiation Protection Section North Carolina Department of Health and Human Services 1645 Mail Service Center Raleigh, NC 27699-1645 lee.cox@dhhs.nc.gov

BSEP 16-0047 Enclosure 1 Marked-up Technical Specification Pages - Unit 1

RHR Shutdown Cooling System-Hot Shutdown 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4 .7.1 ------------------------------N()TE---------------------------------

Not required to be met until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reactor steam dome pressure is less than the RHR shutdown cooling isolation pressure.

Verify one required RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or recirculation pump is operating .

SR 3.4.7.2 --------------------------------N ()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 reactor steam dome pressure is less than the RHR shutdown cooling isolation pressure.

Verify RHR shutdown cooling subsystem location susceptible to gas accumulation are sufficiently fi with water.

In accordance with the Surveillance Frequency Control Program Brunswick Unit 1 3.4-16 Amendment No. ~

RHR Shutdown Cooling System-Cold Shutdown 3.4 .8 ACTIONS (continued)

COMPLETION CONDITION REQUIRED ACTION TIME B. No RHR shutdown cooling B.1 Verify reactor coolant 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from subsystem in operation . circulating by an alternate discovery of no method . reactor coolant circulation No recirculation pump in operation .

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter B.2 Monitor reactor coolant Once per hour temperature.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4 .8.1 Verify one required RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or recirculation pump is operating.

SR 3.4.8.2 Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

In accordance with the Surveillance Frequency Control Program Brunswick Unit 1 3.4-18 Amendment No. ~

ECCS-Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. Two or more low pressure J.1 Enter LCO 3.0.3 . Immediately ECCS injection/spray subsystems inoperable for reasons other than Condition A or B.

HPCI System and two or more required ADS valves inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem , 92 days locations susceptible to gas accumulation are sufficiently filled with water.

1' (continued)

In accordance with the Surveillance Frequency Control Program J

Brunswick Unit 1 3.5-4 Amendment No. ~

ECCS-Operating 3.5.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.5.1.2 ---------------------------------NOTES----------------------------

1. Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the Residual Heat Removal (RHR) shutdown cooling isolation pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable.

2. Not required to be met for system vent flow paths opened under administrative control.

Verify each ECCS injection/spray subsystem manual , 31 days power operated , and automatic valve in the flow path ,

that is not locked , sealed , or otherwise secured in position , is in the correct position .

SR 3.5.1.3 Verify ADS pneumatic supply header pressure is

~ 95 psig .

SR 3.5.1.4 Verify the RHR System cross tie valve is locked closed .

SR 3.5.1 .5 ---------------------------------N 0 TE----------------------

N ot required to be performed if performed withi t e previous 31 days.

Verify each recirculation pump discharge val Once each startup bypass valve cycles through one complete prior to exceeding travel or is de-energized in the closed posi 25% RTP (continued)

In accordance with the Surveillance Frequency Control Program Brunswick Unit 1 3.5-5 Amendment No . ~

ECCS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.5 .2.2 Verify, for each required core spray (CS) subsystem , 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the:

a. Suppression pool water level is :?: -31 inches ; or

b. ----------------------------N 0 TE----------------------------

0 n ly one required CS subsystem may take credit for this option during OPDRVs .

Condensate storage tank water volume is

?: 228 ,200 gallons.

SR 3.5.2.3 Verify, for each requ ired ECCS injection/spray 31 days subsystem , locations susceptible to gas accumulati n are sufficiently filled with water.

SR 3.5.2.4 -------------------------------N0 TES-------------------------- ---

1. One LPCI subsystem may be considered OPERABLE during alignment and operatio decay heat removal if capable of being ma realigned and not otherwise inoperable.

2. Not required to be met for system vent flo paths opened under administrative control Verify each required ECCS injection/spray sub 31 days manual , power operated , and automatic valve i flow path , that is not locked , sealed , or otherwi secured in position , is in the correct position .

(continued)

In accordance with the Surveillance Frequency Control Program Brunswick Unit 1 3.5-10 Amendment No. ~

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System locations susceptible to gas 92 days accumulation are sufficiently filled with water.

SR 3.5.3.2 --------------------------------N 0 TE------------------------------

N ot required to be met for system vent flow paths opened under administrative control.

Verify each RCIC System manual , power operate ,

and automatic valve in the flow path , that is not locked , sealed , or otherwise secured in position the correct position .

SR 3.5 .3.3 --------------------------------N 0 TE-------------------

1. Use of auxiliary steam for the perform the SR is not allowed .

2. Not required to be performed until reactor steam pressure is adequat the test.

Verify, with reactor pressure ;;::: 945 ps* a psig , the RCIC pump can develop a f w ate

400 gpm against a system head c rr ponding to reactor pressure.

(continued)

In accordance with the Surveillance Frequency Control Program Brunswick Unit 1 3.5-13 Amendment No. 2+G

RHR Suppression Pool Cooling 3.6.2 .3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6 .2.3.1 Verify each RHR suppression pool cooling subsystem manual, power operated , and automatic valve in the flow path that is not locked , sealed , or otherwise secured in position is in the correct position or can be aligned to the correct position .

SR 3.6.2.3.2 Verify each RHR pump develops a flow rate

~ 7700 gpm through the associated heat exchanger while operating in the suppression pool cooling mo SR 3.6 .2.3.3 Verify RHR suppression pool cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

In accordance with the Surveillance Frequency Control Program Brunswick Unit 1 3.6-25 Amendment No. ~

RHR-High Water Level 3.9 .7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify one RHR shutdown cooling subsystem is operating.

SR 3.9.7.2 Verify required RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

In accordance with the Surveillance Frequency Control Program .

Brunswick Unit 1 3.9-12 Amendment No. ~

RHR-Low Water Level 3.9.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months operating .

SR 3.9.8 .2 Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently fille with water.

In accordance with the Surveillance Frequency Control Program Brunswick Unit 1 3.9-15 Amendment No. ~

BSEP 16-0047 Enclosure 2 Marked-up Technical Specification Pages - Unit 2

RHR Shutdown Cooling System-Hot Shutdown 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 --------------------------------N()TE-------------------------------

Not required to be met until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reactor steam dome pressure is less than the RHR shutdown cooling isolation pressure.

Verify one required RHR shutdown cooling subsystem or recirculation pump is operating.

SR 3.4 .7.2 --------------------------------N()TE-------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam dome pressure is less than the RHR shutdown cooling isolation pressure.

Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently fille with water.

In accordance with the Surveillance Frequency Control Program Brunswick Unit 2 3.4-16 Amendment No. ~

RHR Shutdown Cooling System-Cold Shutdown 3.4 .8 ACTIONS (continued)

COMPLETION CONDITION REQUIRED ACTION TIME B. No RHR shutdown cooling B.1 Verify reactor coolant 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from subsystem in operation. circulating by an alternate discovery of no method. reactor coolant circulation No recirculation pump in AND operation .

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.2 Monitor reactor coolant Once per hour temperature.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one required RHR shutdown cooling subsystem or recirculation pump is operating .

SR 3.4.8 .2 Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

In accordance with the Surveillance Frequency Control Program Brunswick Unit 2 3.4-18 Amendment No. ~

ECCS-Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. Two or more low pressure J.1 Enter LCO 3.0.3. Immediately ECCS injection/spray subsystems inoperable for reasons other than Condition A or B.

HPCI System and two or more required ADS valves inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem , Q2 days locations susceptible to gas accumulation are sufficiently filled with water.

(continued)

In accordance with the Surveillance Frequency Control Program Brunswick Unit 2 3.5-4 Amendment No. ~

EGGS-Operating 3.5.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.5.1.2 -------------------------------NOTES-------------------------------

1. Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the Residual Heat Removal (RHR) shutdown cooling isolation pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable.

2. Not required to be met for system vent flow paths opened under administrative control.

Verify each ECCS injection/spray subsystem manual , 31 days power operated , and automatic valve in the flow path ,

that is not locked , sealed , or otherwise secured in position , is in the correct position.

SR 3.5.1.3 Verify ADS pneumatic supply header pressure is

~ 95 psig .

SR 3.5 .1.4 Verify the RHR System cross tie valve is locked closed .

SR 3.5.1.5 -------------------------------NOTE------------------------

Not required to be performed if performed withi t previous 31 days.

Verify each recirculation pump discharge val e Once each startup bypass valve cycles through one complete c prior to exceeding travel or is de-energized in the closed positi 25% RTP (continued)

In accordance with the Surveillance Frequency Control Program Brunswick Unit 2 3.5-5 Amendment No. 2-W

ECCS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify, for each required core spray (CS) subsystem , 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the:

a. Suppression pool water level is 2". -31 inches; or

b. --------------------------N 0 TE-----------------------------

0 nIy one required CS subsystem may take credit for this option during OPDRVs.

Condensate storage tank water volume is 2". 228 ,200 gallons.

SR 3.5.2.3 Verify, for each required ECCS injection/spray 31 days subsystem , locations susceptible to gas accumulatio are sufficiently filled with water.

SR 3.5.2.4 -------------------------------N0 TES---------------------------- -

1. One LPCI subsystem may be considered OPERABLE during alignment and operation f r decay heat removal if capable of being manually realigned and not otherwise inoperable.

2. Not required to be met for system vent flow paths opened under administrative control.

Verify each required ECCS injection/spray subsy t manual, power operated , and automatic valve in flow path , that is not locked, sealed , or otherwis secured in position , is in the correct position .

(continued)

In accordance with the Surveillance Frequency Control Program Brunswick Unit 2 3.5-10 Amendment No. ~

RCIC System 3 .5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5 .3.1 Verify the RCIC System locations susceptible to gas Q2 days accumulation are sufficiently filled with water.

SR 3.5 .3.2 ----------------------------------NOTE-----------------------------

Not required to be met for system vent flow paths opened under administrative control.

Verify each RCIC System manual , power operated ,

and automatic valve in the flow path , that is not locke ,

sealed, or otherwise secured in position , is in the correct position.

SR 3.5.3.3 ----------------------------------NOTES------------------------- --

1. Use of auxiliary steam for the performance of the SR is not allowed .

2. Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after reactor steam pressure is adequate to perform the test.

Verify, with reactor pressure ;;::: 945 psig and :<::; 10 psig , the RCIC pump can develop a flow rate

400 gpm against a system head corresponding reactor pressure.

(continued)

In accordance with the Surveillance Frequency Control Program Brunswick Unit 2 3.5-13 Amendment No. ~

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling subsystem manual, power operated , and automatic valve in the flow path that is not locked , sealed , or otherwise secured in position is in the correct position or can be aligned to the correct position .

SR 3.6.2.3.2 Verify each RHR pump develops a flow rate

: : 7700 gpm through the associated heat exchange while operating in the suppression pool cooling m SR 3.6.2.3.3 Verify RHR suppression pool cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

In accordance with the Surveillance Frequency Control Program Brunswick Unit 2 3.6-25 Amendment No. ~

RHR- High Water Level 3.9.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify one RHR shutdown cooling subsystem is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months operating .

SR 3.9.7.2 Verify required RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

In accordance with the Surveillance Frequency Control Program Brunswick Unit 2 3.9-12 Amendment No. ~

RHR-Low Water Level 3.9.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months operating .

SR 3.9.8.2 Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently fille with water.

In accordance with the Surveillance Frequency Control Program Brunswick Unit 2 3.9-15 Amendment No. 2-W

BSEP 16-0047 Enclosure 3 Cross-Reference between TSTF-425, Revision 3 and BSEP Technical Specifications

BSEP 16-0047 Enclosure 3 Page 1 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Reactivity Anomalies N/A 3.1.2 Verify core reactivity N/A 3.1.2.1 Control Rod OPERABILITY 3.1.3 3.1.3 Determine control rod position 3.1.3.1 3.1.3.1 Perform notch test - fully withdrawn control rods 3.1 .3.2 N/A Perform notch test - withdrawn control rods 3.1.3.3 3.1.3.2 Control Rod Scram Times 3.1.4 3.1.4 Perform scram time testing 3.1.4.2 3.1.4.2 Control Rod Scram Accumulators 3.1.5 3.1.5 Verify control rod scram accumulator pressure 3.1 .5.1 3.1.5.1 Rod Pattern Control 3.1.6 3.1.6 Verify control rods comply with withd rawal sequence 3.1.6.1 3.1 .6.1 Standby Liquid Control System 3.1.7 3.1.7 Verify volume of sodium pentaborate solution 3.1.7.1 3.1.7.1 Verify temperature of sodium pentaborate solution 3.1 .7.2 3.1.7.2 Verify temperature of SLC piping 3.1.7.3 3.1.7.3 Verify continuity of explosive charge 3.1.7.4 3.1.7.4 Verify concentration of boron solution 3.1.7.5 3.1.7.5 Verify manual/power operated valve positon 3.1.7.6 N/A 2

Verify pump flow rate 3.1.7.7 3.1.7.6 Verify flow through SLC subsystem 3.1.7.8 3.1.7.7 Verify heat traced piping is unblocked 3.1.7.9 N/A Scram Discharge Volume (SDV) Vent and Drain Valves 3.1.8 . 3.1.8 Verify each SDV vent and drain valve is open 3.1.8.1 3.1.8. 1 Cycle each SDV vent and drain valve 3.1.8.2 3.1.8.2 Verify automatic operation of each SDV vent and drain valve 3.1.8.3 3.1.8.3 Average Planar Linear Heat Generation Rate (APLHGR) 3.2.1 3.2.1 Verify all APLHGRs are less than or equal to limits 3.2.1.1 3.2.1.1 Minimum Critical Power Ratio (MCPR) 3.2.2 3.2.2 Verify all MCPRs are greater than or equal to limits 3.2.2.1 3.2.2.1 Linear Heat Generation Rate (LHGR) 3.2.3 3.2.3 Verify all LHGRs are less than or equal to limits 3.2.3. 1 3.2.3.1 Average Power Range Monitor Gain and Setpoints 3.2.4 N/A Verify MFLPD is within limits 3.2.4.1 N/A

BSEP 16-0047 Enclosure 3 Page 2 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Verify APRM setpoints or gains are adjusted for the calculated 3.2.4.2 N/A MFLPD Reactor Protection System (RPS) Instrumentation 3.3.1.1 3.3.1.1 Perform CHANNEL CHECK 3.3.1.1 .1 3.3.1 .1.2 Verify absolute difference between APRM channels and 3.3.1.1 .2 N/A calculated power Adjust the channel to conform to a calibrated flow signal 3.3.1.1.3 N/A Adjust the APRM channels to conform to the calculated power N/A 3.3.1 .1.3 Perform CHANNEL FUNCTIONAL TEST 3.3.1.1.4 3.3.1.1.4 Perform CHANNEL FUNCTIONAL TEST 3.3.1.1.5 N/A Perform a functional test of each automatic scram contactor N/A 3.3.1.1.5 Verify the IRM and APRM channels overlap N/A 3.3.1.1.7 Calibrate the local power range monitors 3.3.1.1.6 3.3.1.1.8 Perform CHANNEL FUNCTIONAL TEST 3.3.1.1.7 3.3.1.1.9 Calibrate the trip units 3.3.1.1.8 3.3.1.1.10 Perform CHANNEL CALIBRATION 3.3.1.1.9 N/A Perform CHANNEL FUNCTIONAL TEST N/A 3.3.1.1.1 1 Perform CHANNEL FUNCTIONAL TEST 3.3.1.1.10 3.3.1.1.12 Perform CHANNEL CALIBRATION 3.3.1.1.11 3.3.1.1.13 Verify the APRM Flow Biased Simulated Thermal Power 3.3.1.1.12 N/A Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.1.1.13 3.3.1.1 .15 Verify Turbine Stop Valve - Closure and Turbine Control Valve 3.3.1.1 .14 3.3.1 .1.16 Fast Closure, Trip Oil Pressure - Low Functions are not bypassed Verify the RPS RESPONSE TIME is within limits 3.3.1 .1.15 3.3.1.1.17 Verify OPRM is not bypassed when APRM Simulated Thermal N/A 3.3.1.1.19 Power is ;;:: 25% and recirculation drive flow is $ 60%

Source Range Monitor (SRM) Instrumentation 3.3.1.2 3.3.1.2 Perform CHANNEL CHECK 3.3.1 .2.1 3.3.1.2 .1 Verify an OPERABLE SRM detector 3.3.1 .2.2 3.3.1.2.2 Perform CHANNEL CHECK 3.3.1 .2.3 3.3.1.2.3 Verify count rate 3.3.1.2.4 3.3.1.2.4 Perform CHANNEL FUNCTIONAL TEST 3.3.1 .2.5 3.3.1.2.5 Perform CHANNEL FUNCTIONAL TEST 3.3.1.2.6 3.3.1.2.6 Perform CHANNEL CALIBRATION 3.3.1.2 .7 3.3.1.2.7

BSEP 16-0047 Enclosure 3 Page 3 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Control Rod Block Instrumentation 3.3.2.1 3.3.2.1 Perform CHANNEL FUNCTIONAL TEST 3.3.2.1 .1 3.3.2.1 .1 Perform CHANNEL FUNCTIONAL TEST 3.3.2.1.2 3.3.2.1.2 Perform CHANNEL FUNCTIONAL TEST 3.3.2.1.3 3.3.2.1.3 Verify the RBM 3.3.2.1.4 3.3.2.1.4 Verify the RWM is not bypassed 3.3.2.1.5 3.3.2.1.5 Perform CHANNEL FUNCTIONAL TEST 3.3.2.1.6 3.3.2.1 .6 Perform CHANNEL CALIBRATION 3.3.2.1.7 3.3.2.1 .7 Feedwater and Main Turbine High Water Level Trip 3.3.2.2 3.3.2.2 Instrumentation Perform CHANNEL CHECK 3.3.2.2.1 3.3.2.2 .1 Perform CHANNEL FUNCTIONAL TEST 3.3.2.2.2 N/A Perform CHANNEL CALIBRATION 3.3.2.2.3 3.3.2.2.2 Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.2.2.4 3.3.2.2.3 Post Accident Monitoring (PAM) Instrumentation 3.3.3.1 3.3.3.1 Perform CHANNEL CHECK 3.3.3.1.1 3.3.3.1.1 Perform CHANNEL CALIBRATION 3.3.3.1.2 3.3.3.1.3 Remote Shutdown Monitoring Instrumentation 3.3.3.2 3.3.3.2 Perform CHANNEL CHECK 3.3.3.2.1 3.3.3.2.1 Verify each required control circuit and transfer switch 3.3.3.2.2 N/A Perform CHANNEL CALIBRATION 3.3.3.2.3 3.3.3.2.2 End of Cycle Recirculation Pump Trip (EOC-RPn 3.3.4.1 N/A Instrumentation Perform CHANNEL FUNCTIONAL TEST 3.3.4.1.1 N/A Calibrate trip units 3.3.4.1.2 N/A Perform CHANNEL CALIBRATION 3.3.4.1.3 N/A Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.4.1.4 N/A Verify TSV - Closure and TCV Fast Closure, Trip Oil Pressure - 3.3.4.1 .5 N/A Low Functions are not bypassed Verify the EOC-RPT SYSTEM RESPONSE TIME 3.3.4.1.6 N/A Determine RPT breaker interruption time 3.3.4.1 .7 N/A Anticipated Transient Without Scram Recirculation Pump Trip 3.3.4.2 3.3.4.1 (ATWS-RPT) Instrumentation Perform CHANNEL CHECK 3.3.4.2. 1 3.3.4.1.1 Perform CHANNEL FUNCTIONAL TEST 3.3.4.2.2 3.3.4.1.2

BSEP 16-0047 Enclosure 3 Page 4 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Calibrate the trip unit 3.3.4.2.3 3.3.4.1.3 Perform CHANNEL CALIBRATION 3.3.4.2.4 3.3.4.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.4.2.5 3.3.4.1.5 Emergency Core Cooling System (ECCS) Instrumentation 3.3.5.1 3.3.5.1 Perform CHANNEL CHECK 3.3.5.1.1 3.3.5.1.1 Perform CHANNEL FUNCTIONAL TEST 3.3.5.1.2 3.3.5.1.2 Calibrate the trip unit 3.3.5.1.3 3.3.5.1.3 Perform CHANNEL CALIBRATION 3.3.5.1.4 N/A Perform CHANNEL CALIBRATION 3.3.5.1 .5 3.3.5.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.5.1.6 3.3.5.1.5 Perform CHANNEL FUNCTIONAL TEST N/A 3.3.5.1.6 Verify the ECCS RESPONSE TIME is within limits 3.3.5.1.7 N/A Reactor Core Isolation Cooling (RCIC) System Instrumentation 3.3.5.2 3.3.5.2 Perform CHANNEL CHECK 3.3.5.2.1 3.3.5.2.1 Perform CHANNEL FUNCTIONAL TEST 3.3.5.2.2 3.3.5.2.2 Calibrate the trip units 3.3.5.2.3 3.3.5.2.3 Perform CHANNEL CALIBRATION 3.3.5.2.4 N/A Perform CHANNEL CALIBRATION 3.3.5.2.5 3.3.5.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.5.2.6 3.3.5.2.5 Primary Containment Isolation Instrumentation 3.3.6.1 3.3.6.1 Perform CHANNEL CHECK 3.3.6.1.1 3.3.6.1.1 Perform CHANNEL FUNCTIONAL TEST 3.3.6.1.2 3.3.6.1.2 Calibrate the trip unit 3.3.6.1.3 3.3.6.1.3 Perform CHANNEL CALIBRATION 3.3.6.1.4 3.3.6.1.4 Perform CHANNEL FUNCTIONAL TEST 3.3.6.1.5 3.3.6.1.5 Perform CHANNEL CALIBRATION 3.3.6.1 .6 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.6.1.7 3.3.6.1.7 Verify the ISOLAITON SYSTEM RESPONSE TIME is within 3.3.6.1.8 3.3.6.1.8 limits Perform CHANNEL FUNCTIONAL TEST N/A 3.3.6.1.9 Secondary Containment Isolation Instrumentation 3.3.6.2 3.3.6.2 Perform CHANNEL CHECK 3.3.6.2.1 3.3.6.2.1 Perform CHANNEL FUNCTIONAL TEST 3.3.6.2.2 3.3.6.2.2 Calibrate the trip unit 3.3.6.2.3 3.3.6.2.3 Perform CHANNEL CALIBRATION 3.3.6.2.4 N/A

BSEP 16-0047 Enclosure 3 Page 5 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Perform CHANNEL CALIBRATION 3.3.6.2.5 3.3.6.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.6.2.6 3.3.6.2.5 Verify the ISOLAITON SYSTEM RESPONSE TIME is within 3.3.6.2.7 N/A limits Low-Low Set (LLS) Instrumentation 3.3.6.3 N/A Perform CHANNEL CHECK 3.3.6.3.1 N/A Perform CHANNEL FUNCTIONAL TEST 3.3.6.3.2 N/A Perform CHANNEL FUNCTIONAL TEST 3.3.6.3.3 N/A Perform CHANNEL FUNCTIONAL TEST 3.3.6.3.4 N/A Calibrate the trip unit 3.3.6.3.5 N/A Perform CHANNEL CALIBRATION 3.3.6.3.6 N/A Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.6.3.7 N/A Main Control Room Environmental Control (MCREC) System 3.3.7.1 3.3.7.1 Instrumentation I Control Room Emergency Ventilation (CREV) System Instrumentation Perform CHANNEL CHECK 3.3.7.1.1 3.3.7.1.1 Perform CHANNEL FUNCTIONAL TEST 3.3.7.1 .2 3.3.7.1.2 Calibrate the trip unit 3.3.7.1.3 N/A Perform CHANNEL CALIBRATION 3.3.7.1.4 3.3.7.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.7.1.5 3.3.7.1.4 Condenser Vacuum Pump Isolation Instrumentation N/A 3.3.7.2 Perform CHANNEL CHECK N/A 3.3.7.2.1 Perform CHANNEL FUNCTIONAL TEST N/A 3.3.7.2.2 Perform CHANNEL CALIBRATION N/A 3.3.7.2.3 Perform LOGIC SYSTEM FUNCTIONAL TEST N/A 3.3.7.2.4 Loss of Power (LOP) Instrumentation 3.3.8.1 3.3.8.1 Perform CHANNEL CHECK 3.3.8.1.1 N/A Perform CHANNEL FUNCTIONAL TEST 3.3.8.1.2 3.3.8.1.1 Perform CHANNEL CALIBRATION 3.3.8.1 .3 3.3.8.1.2 Perform CHANNEL CALIBRATION N/A 3.3.8.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST 3.3.8.1.4 3.3.8.1.4 Reactor Protection System (RPS) Electric Power Monitoring 3.3.8.2 3.3.8.2 Perform CHANNEL FUNCTIONAL TEST 3.3.8.2.1 3.3.8.2.1 Perform CHANNEL CALIBRATION 3.3.8.2.2 3.3.8.2.2 Perform CHANNEL CALIBRATION N/A 3.3.8.2.3

BSEP 16-0047 Enclosure 3 Page 6 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Perform a system functional test 3.3.8.2.3 3.3.8.2.4 Recirculation Loops Operating 3.4.1 3.4.1 Verify recirculation loop jet pump flow mismatch 3.4.1.1 3.4.1.1 Jet Pumps 3.4.2 3.4.2 Verify at least one criteria is satisfied for each operating 3.4.2.1 3.4.2.1 recirculation loop Safety/Relief Valves (SRVs) 3.4.3 3.4.3 2

Verify the safety function lift setpoints of the SRVs 3.4.3.1 3.4.3.1 Verify each required SRV opens when manually actuated 3.4.3.2 3.4.3.2 RCS Operational LEAKAGE 3.4.4 3.4.4 Verify RCS unidentified and total LEAKAGE and unidentified 3.4.4.1 3.4.4.1 LEAKAGE increase are within limits RCS Pressure Isolation Valve (PIV) Leakage 3.4.5 N/A Verify equivalent leakage of each RCS PIV 3.4.5.1 N/A RCS Leakage Detection Instrumentation 3.4.6 3.4.5 Perform a CHANNEL CHECK 3.4.6.1 3.4.5.1 Perform CHANNEL FUNCTIONAL TEST 3.4.6.2 3.4.5.2 Perform CHANNEL CALIBRATION 3.4.6.3 3.4.5.3 RCS Specific Activity 3.4.7 3.4.6 Verify reactor coolant DOSE EQUIVALENT 1-131 3.4.7.1 3.4.6.1 Residual Heat Removal (RHR) Shutdown Cooling System -Hot 3.4.8 3.4.7 Shutdown Verify one required RHR shutdown cooling subsystem or 3.4.8.1 3.4.7.1 recirculation pump is operating Verify locations susceptible to gas accumulation are sufficiently N/A 3.4.7.23 filled Residual Heat Removal (RHR) Shutdown Cooling System - 3.4.9 3.4.8 Cold Shutdown Verify one required RHR shutdown cooling subsystem or 3.4.9.1 3.4.8.1 recirculation pump is operating Verify locations susceptible to gas accumulation are sufficiently N/A 3.4.8.2 3 filled RCS Pressure and Temperature (PIT) Limits 3.4.10 3.4.9 Verify RCS pressure, temperature, heatup/cooldown N/A 3.4.9.1 (heatup/cooldown operations)

Verify RCS pressure, temperature, heatup/cooldown (inservice 3.4.10.1 3.4.9.2 leak and hydrostatic testing)

BSEP 16-0047 Enclosure 3 Page 7 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Verify reactor vessel flange and head flange temperatures 3.4.10.7 3.4.9.6 (tensioning)

Verify reactor vessel flange and head flange temperatu res 3.4.10.8 3.4.9.7 (Mode 4 80 degrees F)

Verify reactor vessel flange and head flange temperatures 3.4.10.9 . 3.4.9.8 (Mode 4 100 degrees F)

Reactor Steam Dome Pressure 3.4.11 3.4.10 Verify reactor steam dome pressure 3.4.11.1 3.4.10.1 ECCS - Operating 3.5.1 3.5.1 4

Verify each ECCS injection/spray subsystem , locations 3.5.1.1 3.5.1.1 susceptible to gas accumulation , are sufficiently filled Verify each ECCS injection/spray subsystem manual , power 3.5.1.2 3.5.1.2 4 operated, and automatic valve is in the correct position Verify ADS air supply header pressure 3.5.1.3 3.5.1 .3 Verify the RHR System cross tie valve is locked closed 3.5.1.4 3.5.1.4 Verify each LPCI inverter output voltage 3.5.1.5 N/A Verify ECCS pumps flow rates 3.5.1.7 3.5.1.6 Verify HPCI pump flow rate 3.5.1 .8 3.5.1.7 Verify HPCI pump flow rate 3.5. 1.9 3.5.1 .8 Verify each ECCS injection/spray subsystem automatic initiation 3.5.1 .10 3.5.1.9 Verify the ADS automatic initiation 3.5.1.11 3.5.1.10 Verify each required ADS valve opens when manually actuated 3.5.1 .12 3.5.1.11 Verify the ECCS RESPONSE TIME for each required ECCS N/A 3.5.1.12 injection/spray subsystem ECCS - Shutdown 3.5.2 3.5.2 Verify the suppression pool water 3.5.2.1 3.5.2. 1 Verify, for each required core spray (CS) subsystem , 3.5.2.2 3.5.2. 2 suppression pool water level and condensate storage tank water level/volume Verify each ECCS injection/spray subsystem , locations 3.5.2.3 3.5.2.34 susceptible to gas accumulation , are sufficiently filled Verify manual, power operated , and automatic valve position 3.5.2.4 3.5.2.44 Verify each required ECCS pump develops the specified flow 3.5.2.5 3.5.2.5 Verify each required ECCS injection/spray subsystem automatic 3.5.2.6 3.5.2.6 initiation Verify the ECCS RESPONSE TIME for each required ECCS N/A 3.5.2.7 injection/spray subsystem

BSEP 16-0047 Enclosure 3 Page 8 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick RCIC System 3.5.3 3.5.3 Verify the RCIC System locations susceptible to gas 3.5.3.1 3.5.3.1 4 accumulation, are sufficiently filled Verify each RCIC System manual, power operated, and 3.5.3.2 3.5.3.2 4 automatic valve position Verify the RCIC pump flow rate 3.5.3.3 3.5.3.3 Verify the RCIC pump flow rate 3.5.3.4 3.5.3.4 Verify the RCIC System automatic initiation 3.5.3.5 3.5.3.5 Primary Containment 3.6.1.1 3.6.1.1 Verify drywell to suppression chamber differential pressure drop 3.6.1.1.2 3.6.1.1.2 Primary Containment Air Lock 3.6.1.2 3.6.1.2 Verify only one door in the primary containment air lock can be 3.6.1.2.2 3.6.1.2.2 opened at a time Primary Containment Isolation Valves (PCIVs) 3.6.1.3 3.6.1.3 Verify each primary containment purge valve is sealed closed 3.6.1.3.1 N/A except one Verify each primary containment purge valve is closed 3.6.1.3.2 N/A Verify each primary containment isolation manual valve and 3.6.1.3.3 3.6.1.3.1 blind flange that is located outside primary containment is closed.

Verify continuity of the traversing incore probe (TIP) shear 3.6.1.3.5 3.6.1 .3.3 isolation valve explosive charge 2

Verify the isolation time of each power operated and each 3.6.1 .3.6 3.6.1.3.4 automatic PCIV, except for MSIVs, is within limits Perform leakage rate testing for each primary containment 3.6.1.3.7 N/A purge valve with resilient seals 2

Verify the isolation time of each MSIV 3.6.1.3.8 3.6.1.3.5 Verify each automatic PCIV actuates to the isolation position 3.6.1.3.9 3.6.1 .3.6 Verify a representative sample of reactor instrumentation line 3.6.1.3.10 3.6.1.3.7 EFCVs actuate 2

Remove and test the explosive squib from each shear isolation 3.6.1.3.11 3.6.1.3.8 valve of the Tl P System Verify each primary containment purge valve is blocked to 3.6.1.3.15 N/A restrict valve from opening Drywell Pressure 3.6.1.4 N/A Verify drywell pressure is within limits 3.6.1.4.1 N/A

BSEP 16-0047 Enclosure 3 Page 9 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Drywell Air Temperature 3.6.1.5 3.6.1.4 Verify drywell average air temperature is within limit 3.6.1 .5.1 3.6.1.4.1 Low-Low Set (LLS) Valves 3.6.1.6 N/A Verify each LLS valve opens when manually actuated 3.6.1.6.1 N/A Verify the LLS System automatic initiation 3.6.1 .6.2 N/A Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.7 3.6.1.5 Verify nitrogen bottle ~upply pressure of each nitrogen backup N/A 3.6.1 .5.1 subsystem Verify each vacuum breaker is closed 3.6.1 .7.1 3.6.1.5.2 Perform a functional test of each vacuum breaker 3.6.1.7.2 3.6.1.5.3 Verify the open setpoint of each vacuum breaker 3.6.1 .7.3 3.6.1 .5.4 Verify leakage rate of each nitrogen backup subsystem N/A 3.6.1.5.5 Verify the Nitrogen Backup System supplies nitrogen to the N/A 3.6.1.5.6 vacuum breakers on an actuation signal Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.8 3.6.1.6 Verify each vacuum breaker is closed 3.6.1 .8.1 3.6.1.6.1 Perform a functional test of each requ ired vacuum breaker 3.6.1.8.2 3.6.1.6.2 Verify the full open setpoint of each vacuum breaker 3.6.1 .8.3 3.6.1.6. 3 Main Steam Isolation Valve (MSIV) Leakage Control System 3.6.1.9 N/A Operate each MSIV LCS blower 3.6.1 .9.1 N/A Verify electrical continuity of each inboard MSIV LCS subsystem 3.6.1.9.2 N/A heater element circuitry Perform a system functional test of each MSIV LCS subsystem 3.6.1.9.3 N/A Suppression Pool Average Temperature 3.6.2.1 3.6.2.1 Verify suppression pool average temperature is within limits 3.6.2.1.1 3.6.2.1 .1 Suppression Pool Water Level 3.6.2.2 3.6.2.2 Verify suppression pool water level is within limits 3.6.2.2.1 3.6.2.2.1 Residual Heat Removal (RHR) Suppression Pool Cooling 3.6.2.3 3.6.2.3 Verify each RHR suppression pool cooling subsystem manual, 3.6.2.3.1 3.6.2.3.1 power operated, and automatic valve is in the correct position or can be aligned to the correct position Verify each RHR pump a flow rate 3.6.2.3.2 3.6.2.3.2 Verify RHR suppression pool cooling subsystem locations N/A 3. 6.2.3.3 3 susceptible to gas accumulation, are sufficiently filled

BSEP 16-0047 Enclosure 3 Page 10 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Residual Heat Removal (RHR) Suppression Pool Spray 3.6.2.4 N/A Verify each RHR suppression pool cooling subsystem manual , 3.6.2.4.1 N/A power operated, and automatic valve is in the correct position or can be al igned to the correct position Verify each RHR pump a flow rate 3.6.2.4.2 N/A Drywell-to-Suppression Chamber Differential Pressure 3.6.2.5 N/A Verify drywell-to-suppression chamber differential pressure is 3.6.2.5.1 N/A within limits Drywell Cooling System Fans 3.6.3.1 N/A Operate each requ ired drywell cooling system fan 3.6.3.1.1 N/A Verify each required drywell cooling system fan flow rate 3.6.3.1.2 N/A Primary Containment Oxygen Concentration 3.6.3.2 3.6.3.1 Verify primary containment oxygen concentration is within limits 3.6.3.2.1 3.6.3.1.1 Containment Atmosphere Dilution (CAD) System 3.6.3.3 N/A Verify volume of liquid nitrogen 3.6.3.3.1 N/A Verify each CAD subsystem manual, power operated, and 3.6.3.3.2 N/A automatic valve is in the correct position or can be aligned to the correct position Secondary Containment 3.6.4.1 3.6.4.1 Verify secondary containment vacuum 3.6.4.1. 1 N/A Verify all secondary containment equipment hatches are closed 3.6.4.1.2 3.6.4.1.1 and sealed Verify one secondary containment access door is closed in each 3.6.4.1.3 3.6.4.1.2 access opening Verify secondary containment can be drawn down using one 3.6.4.1.4 N/A SGT subsystem Verify each SGT subsystem can maintain vacuum water gauge 3.6.4.1.5 3.6.4.1.3 in the secondary containment for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Secondary Containment Isolation Valves (SCIVs) I Secondary 3.6.4.2 3.6.4.2 Containment Isolation Dampers (SCIDs)

Verify each secondary containment isolation manual valve and 3.6.4.2.1 N/A blind flange that is required to be closed during accident conditions is closed .

Verify the isolation time of each automatic SCIV is within limits 3.6.4.2.2 3.6.4.2. 1 Verify each automatic SCIV actuates to the isolation position 3.6.4.2.3 3.6.4.2.2 Standby Gas Treatment (SGT) System 3.6.4.3 3.6.4.3 Operate each SGT subsystem with heaters operating 3.6.4.3.1 3.6.4.3.1

BSEP 16-0047 Enclosure 3 Page 11 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Verify each SGT subsystem actuates 3.6.4.3.3 3.6.4.3.3 Verify each SGT filter cooler bypass damper can be opened and 3.6.4.3.4 N/A the fan started Residual Heat Removal Service Water (RHRSW) System 3.7.1 3.7.1 Verify each RHRSW manual, power operated, and automatic 3.7.1.1 3.7.1.1 valve is in the correct position or can be aligned to the correct position Plant Service Water (PSW) System I Service Water (SW) 3.7.2 3.7.2 System and Ultimate Heat Sink (UHS)

Verify cooling tower water level 3.7.2.1 N/A Verify intake structure pump well water level 3.7.2.2 3.7.2.1 Verify water temperature of the UHS 3.7.2.3 3.7.2.2 Operate each cooling tower fan 3.7.2.4 N/A Verify each SW manual, power operated, and automatic valve is 3.7.2.5 3.7.2.3 in the correct position Verify automatic transfer of each DG cooling water supply from N/A 3.7.2.4 the normal SW supply to the alternate SW supply Verify each required SW System automatic actuation 3.7.2.6 3.7.2.5 Diesel Generator (DG) Standby Service Water (SSW) System 3.7.3 N/A Verify each DG SSW System manual, power operated, and 3.7.3.1 N/A automatic valve in the flow path, is in the correct position Verify the DG SSW System pump starts automatically and 3.7.3.2 N/A energizes the respective bus Main Control Room Environmental Control (MCREC) System I 3.7.4 3.7.3 Control Room Emergency Ventilation (CREV) System Operate each MCREC subsystem 3.7.4.1 3.7.3.1 Verify each MCREC subsystem actuates 3.7.4.3 3.7.3.4 Verify each MCREC subsystem can maintain a positive 3.7.4.4 N/A pressure Control Room Air Conditioning (AC) System 3.7.5 3.7.4 Verify each control room AC subsystem can remove the 3.7.5.1 3.7.4.1 assumed heat load Main Condenser Offgas 3.7.6 3.7.5 Verify the gross gamma activity rate of the noble gases 3.7.6.1 3.7.5.1 Main Turbine Bypass System 3.7.7 3.7.6 Verify one complete cycle of each main turbine bypass valve 3.7.7.1 3.7.6.1 Perform a system functional test 3.7.7.2 3.7.6.2

BSEP 16-0047 Enclosure 3 Page 12 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Verify the TURBINE BYPASS SYSTEM RESPONSE TIME is 3.7.7.3 3.7.6.3 within limits Spent Fuel Storage Pool Water Level 3.7.8 3.7.7 Verify the spent fuel storage pool water level 3.7.8.1 3.7.71 AC Sources-Operating 3.8.1 3.8.1 Verify correct breaker alignment and indicated power availabil ity 3.8.1 .1 3.8.1.1 of offsite circuits Verify each DG starts from standby conditions 3.8.1.2 3.8.1.2 Verify each DG is synchronized and loaded and operates 3.8.1.3 3.8.1.3 Verify each day tank fuel oil 3.8.1.4 3.8.1.4 Check for and remove accumulated water from each day tank 3.8.1 .5 3.8.1.5 Verify the fuel oil transfer system operates to transfer oil 3.8.1 .6 3.8.1.6 Verify each DG starts from standby condition and achieves and 3.8.1 .7 3.8.1.7 maintains voltage and frequency Verify automatic and manual transfer of the unit power supplies 3.8.1 .8 3.8.1.8 Verify each DG rejects a load greater than or equal to its 3.8.1.9 3.8.1.9 associated single largest post-accident load Verify each DG does not trip and voltage is maintained during 3.8.1. 10 N/A and following a load rejection Verify on an actual or simulated loss of offsite power signal: de- 3.8.1.11 N/A energization of emergency buses, load shedding from emergency buses, and DG auto-starts Verify on an actual or simulated ECCS initiation signal each DG 3.8.1.12 N/A auto-starts from standby condition Verify each DG's automatic trips are bypassed on an actual or 3.8.1 .13 3.8.1.10 simulated ECCS initiation signal Verify each DG operates for greater than or equal to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 3.8.1.14 N/A Verify each DG operating at a power factor greater than or equal N/A 3.8.1.11 0.9 operates for greater than or equal 60 minutes when loaded Verify each DG starts and achieves voltage and frequency 3.8.1 .15 N/A Verify each DG: synchronizes with offsite power source, 3.8.1.16 N/A transfers loads to offsite power source , and returns to ready-to-load operation Verify with a DG operating in test mode and connected to its 3.8.1.17 3.8.1.12 bus, an actual or simulated ECCS initiation signal overrides the test mode Verify interval between each sequenced load block is within 3.8.1.18 3.8.1.13

+/- 10% of design interval

BSEP 16-0047 Enclosure 3 Page 13 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Verify, on an actual or simulated loss of offsite power signal in 3.8.1.19 3.8.1.14 conjunction with an actual or simulated ECCS initiation signal:

de-energization of emergency buses, load shedding from emergency buses, and DG auto-starts Verify, when started simultaneously from standby condition , 3.8 .1.20 N/A each DG achieves voltage and frequency Diesel Fuel Oil, Lube Oil, and Starting Air I Diesel Fuel Oil 3.8.3 3.8.3 Verify fuel oil storage tanks inventory 3.8.3.1 3.8.3.1 Verify lube oil inventory 3.8.3.2 N/A Verify each DG air start receiver pressure 3.8.3.4 N/A Check for and remove water from each fuel oil storage tank 3.8.3.5 3.8.3.3 DC Sources - Operating 3.8.4 3.8.4 Verify battery terminal voltage 3.8.4.1 3.8.4.1 Verify battery terminals and connectors N/A 3.8.4.2 Verify battery cells, cell plates, and racks show no damage N/A 3.8.4.3 Remove visible corrosion and verify anti-corrosion material N/A 3.8.4.4 Verify each required battery charger 3.8.4.2 3.8.4.5 Verify battery capacity is adequate to supply the required 3.8.4.3 3.8.4.6 emergency loads Verify battery capacity is greater than or equal to 80% of the N/A 3.8.4.7 manufacturer's rating Battery Parameters I Battery Cell Parameters 3.8.6 3.8.6 Verify each battery float current 3.8.6.1 N/A Verify each battery pilot cell voltage 3.8.6.2 N/A Verify each battery connected cell electrolyte level 3.8.6.3 N/A Verify each battery cell temperature 3.8.6.4 N/A Verify each battery connected cell voltage 3.8.6.5 N/A Verify battery capacity is greater than or equal to 80% of the 3.8.6.6 N/A manufacturer's rating .

Verify battery cell parameters meet Table 3.8.6-1 Category A N/A 3.8.6.1 limits Verify battery cell parameters meet Table 3.8.6-1 Category B N/A 3.8.6.2 limits Verify average electrolyte temperature of representative cells N/A 3.8.6.3 Inverters - Operating 3.8.7 N/A Verify correct inverter voltage , frequency, and alignment 3.8.7.1 N/A

BSEP 16-0047 Enclosure 3 Page 14 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Inverters - Shutdown 3.8.8 N/A Verify correct inverter voltage , frequency, and alignment 3.8.8.1 N/A Distribution Systems - Operating 3.8.9 3.8.7 Verify correct breaker alignments and indicated power 3.8.9.1 3.8.7.1 availability to required AC and DC electrical power distribution subsystems Verify no combination of more than two power conversion N/A 3.8.7.2 modules (consisting of either two lighting inverters or one lighting inverter and one plant uninterruptible power supply unit) are aligned to Division II bus B.

Distribution Systems - Shutdown 3.8.10 3.8.8 Verify correct breaker alignments and indicated power 3.8 .10.1 3.8.8.1 availability to required AC and DC electrical power distribution subsystems Refueling Equipment Interlocks 3.9.1 3.9.1 Perform CHANNEL FUNCTIONAL TEST on required refueling 3.9.1.1 3.9.1.1 equipment interlock inputs Refuel Position One-Rod-Out Interlock 3.9.2 3.9.2 Verify reactor mode switch locked in Refuel position 3.9.2.1 3.9.2 .1 Perform CHANNEL FUNCTIONAL TEST 3.9.2.2 3.9.2.2 Control Rod Position 3.9.3 3.9.3 Verify all control rods are fully inserted 3.9.3.1 3.9.3.1 Control Rod Operability - Refueling 3.9.5 3.9.5 Insert Each withdrawn control rod at least one notch 3.9.5.1 3.9.5.1 Verify each withdrawn control rod scram accumulator pressure 3.9.5.2 3.9.5.2 Reactor Pressure Vessel (RPV) Water Level - Irradiated Fuel 3.9.6 3.9.6 Verify RPV water level 3.9.6.1 3.9.6.1 Reactor Pressure Vessel (RPV) Water Level - New Fuel or 3.9.7 3.9.6 Control Rods Verify RPV water level 3.9.7.1 3.9.6.1 Residual Heat Removal (AHR) - High Water Level 3.9.8 3.9.7 Verify one RHR shutdown cooling subsystem is operating 3.9.8.1 3.9.7.1 Verify required RHR shutdown cooling subsystems locations N/A 3.9.7.2 3 susceptible to gas accumulation are sufficiently filled Residual Heat Removal (AHR) - Low Water Level 3.9.9 3.9.8 Verify one RHR shutdown cooling subsystem is operating 3.9.9.1 3.9.8.1

BSEP 16-0047 Enclosure 3 Page 15 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Verify RHR shutdown cooling subsystems locations susceptible N/A 3. 9.8.23 to gas accumulation are sufficiently filled Reactor Mode Switch Interlock Testing 3.10.2 3.10.2 Verify all control rods are fully inserted in core cells containing 3.10.2.1 3.10.2.1 one or more fuel assemblies Verify no CORE ALTERATIONS are in progress 3.10.2.2 3.10.2.2 Single Control Rod Withdrawal - Hot Shutdown 3.10.3 3.10.3 Verify all control rods, other than the control rod being 3.10.3.2 3.10.3.2 withdrawn , in a five by five array centered on the control rod being withdrawn , are disarmed Verify all control rods, other than the control rod being 3.10.3.3 3.10.3.3 withdrawn , are fully inserted Single Control Rod Withdrawal - Cold Shutdown 3.10.4 3.10.4 Verify all control rods, other than the control rod being 3.10.4.2 3.10.4.2 withdrawn , in a five by five array centered on the control rod being withdrawn , are disarmed Verify all control rods, other than the control rod being 3.10.4.3 3.10.4.3 withdrawn , are fully inserted Verify a control rod withdrawal block is inserted 3.10.4.4 3.10.4.4 Single Control Rod Drive (CRD) Removal - Refueling 3.10.5 3.10.5 Verify all control rods, other than the control rod withdrawn for 3.10.5.1 3.10.5.1 the removal of the associated CRD, are fully inserted Verify all control rods, other than the control rod withdrawn for 3.10.5.2 3.10.5.2 the removal of the associated CRD, in a five by five array centered on the control rod withdrawn for the removal of the associated CRD, are disarmed Verify a control rod withdrawal block is inserted 3.10.5.3 3.10.5.3 Verify no other CORE ALTERATIONS are in progress 3.10.5.5 3.10.5.5 Multiple Control Rod Withdrawal - Refueling 3.10.6 3.10.6 Verify the four fuel assemblies are removed from core cells 3.10.6.1 3.10.6.1 associated with each control rod or CRD removed Verify all other control rods in core cells containing one or more 3.10.6.2 3.10.6.2 fuel assemblies are fully inserted Verify fuel assemblies being loaded are in compliance with an 3.10.6.3 3.10.6.3 approved reload sequence SHUTDOWN MARGIN (SOM) Test - Refueling 3.10.8 3.10.8 Verify no other CORE ALTERATIONS are in progress 3.10.8.4 3.10.8.4 Verify CRD charging water header pressure 3.10.8.6 3.10.8.6

BSEP 16-0047 Enclosure 3 Page 16 of 16 Technical Specification Cross Reference for TSTF-425 and Brunswick Mark-ups Technical Specification Section Title/Surveillance Description 1 TSTF-425 Brunswick Recirculation Loops - Testing 3.10.9 N/A Verify LCO 3.4.1 requirements suspended 3.10.9.1 N/A Verify THERMAL POWER during PHYSICS TESTS 3.10.9.2 N/A Training Startups 3.10.10 N/A Verify all OPERABLE IRM channels 3.10.10.1 N/A Verify average reactor coolant temperature 3.10.10.2 N/A Notes:

1. The information provided in the Technical Specification Section Title/Surveillance Description portion of this Enclosure represent summary descriptions of the referenced TSTF 425/BSEP TS Surveillances, provided for information purposes only, and not intended to be verbatim descriptions.

2. This BSEP Surveillance Frequency is provided in the BSEP lnservice Testing Program.

This BSEP Surveillance Frequency is not proposed for inclusion in the Surveillance Frequency Control Program.

3. New Surveillance Requirement based on the NRC issued Amendments 270 and 298 to the Renewed Facility Operating License for Units 1 and 2, respectively. These amendments approved the adoption of TSTF-523, Revision 2, "Generic Letter 2008-01 , Managing Gas Accumulation."

4. Revised Surveillance Requirement based on the NRC issued Amendments 270 and 298 to the Renewed Facility Operating License for Units 1 and 2, respectively. These amendments approved the adoption of TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Acc um ulation."

William R. Gideon

(-,DUKE

~ ENERGY Vice President Brunswick Nuclear Plant P.O. Box 10429 Southport, NC 28461 o: 910.457.3698 June 29, 2016 Serial: BSEP 16-0047 TSC-201 S-03 10 CFR S0.90 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20SSS-0001

Subject:

Brunswick Steam Electric Plant, Unit Nos. 1 and 2 Renewed Facility Operating License Nos. DPR-71 and DPR-62 Docket Nos. S0-32S and S0-324 Supplement to Application For Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee-Controlled Program *

References:

1. Duke Energy Progress, Inc. letter, Brunswick Steam Electric Plant, Unit Nos. 1 and 2, Application For Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee-Control/ed Program, dated December 21, 201 S (ML16004A249)

2. Nuclear Regulatory Commission letter, Brunswick Steam Electric Plant, Unit Nos. 1 and 2; Shearon Harris Nuclear Power Plant, Unit 1; Catawba Nuclear Station, Units 1 and 2; McGuire Nuclear Station, Units 1 and 2; and Oconee Nuclear Station, Units 1, 2, and 3: Issuance of Amendments Regardjng Adoption of TSTF-523 (GAG Nos. MF6413 Through MF6422), dated April 29, 2016 (ML1608SA113)

Ladies and Gentlemen:

By letter dated December 21, 201 S (i.e., Reference 1), Duke Energy Progress, Inc. (Duke Energy) submitted a license amendment request (LAR) for the Brunswick Steam Electric Plant (BSEP), Unit Nos. 1 and 2. The proposed amendments modify the Technical Specifications (TSs) by relocating specific surveillance*trequencies to a licensee-controlled program with the implementation of Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specification Initiative Sb, Risk-Informed Method for Control of Surveillance Frequencies." Additionally, the change would add a new program, the Surveillance Frequency Control Program, to TS Section S.S, "Programs and Manuals." The c~anges are consistent with Nuclear Regulatory ;

Commission (NRG) approved Technical Specification Task Force (TSTF) Standard T,echnical Specifications (STS) Change TSTF-42S, "Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative Sb," Revision 3 (ADAMS Accession No. ML0908S0642).

On April 29, 2016, the NRG issued Amendments 270 and 298 to the Renewed Facility Operating License for BSEP Units 1.and 2, respectively (i.e., Reference 2). These amendments approved the adoption of TSTF-S23, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation." These amendments included new Surveillance Requirements (SRs) and

U.S. Nuclear Regulatory Commission Page 2 of 3 revised existing SRs that fall within the scope of the proposed TSTF-425 LAR. As such, this submittal supplements the original TSTF-425 LAR to include the new SRs and revise the impacted SRs consistent with Amendments 270 and 298. The following table provides a listing

of the impacted SRs.

New Surveillance Requirements Impacted Surveillance Requirements SR 3.4.7.2 SR 3.5.1.1 SR 3.4.8.2 SR 3.5.1.2 SR 3.6.2.3.3 SR 3.5.2.3 SR 3.9.7.2 SR 3.5.2.4 SR 3.9.8.2 SR 3.5.3.1 SR 3.5.3.2 Duke Energy has determined that the relocation of the frequencies for the newly issued and revised SRs is consistent with the intent of TSTF-425, Revision 3, and with the NRC's model safety evaluation dated July 6, 2009 (74 FR 31996), including the scope exclusions identified in Section 1.0, "Introduction," of the model safety evaluation. As such, this supplement does not change the No Significant Hazards Determination provided in Reference 1.

Enclosures 1 and 2 provide the impacted TS pages marked up to show the proposed changes for Units 1 and 2, respectively. Enclosure 3 provides a cross-reference between the TSTF-425 marked up TS pages and the BSEP Unit 1 and 2 TS pages. Revisions to this table are identified with a revision bar in the right margin.

In accord~nce with 10 CFR 50.91, Duke Ene.rgy is providing a copy of the proposed license amendment to the designated representative for the State of North Carolina.

Please refer any questions regarding this submittal to Mr. Lee Grzeck, Manager - Regulatory Affairs, at {910) 457-2487.