CNL-19-010, Application to Revise Technical Specifications to Adopt Technical Specifications Task Force (TSTF)-542, Reactor Pressure Vessel Water Inventory Control, Revision 2 (BFN-TS-513)

From kanterella
Jump to navigation Jump to search

Application to Revise Technical Specifications to Adopt Technical Specifications Task Force (TSTF)-542, Reactor Pressure Vessel Water Inventory Control, Revision 2 (BFN-TS-513)
ML19031C826
Person / Time
Site: Browns Ferry  Tennessee Valley Authority icon.png
Issue date: 01/25/2019
From: Henderson E
Tennessee Valley Authority
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
BFN-TS-513, CNL-19-010
Download: ML19031C826 (439)
v • d • e


Text

[[:#Wiki_filter:Tennessee Valley Authority, 1101 Market Street, Chattanooga, Tennessee 37402 CNL-19-010 January 25, 201.9 10 CFR 50.90 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, D.C. 20555-0001 Browns Ferry Nuclear Plant, Units 1, 2, and 3 , Renewed Facility Operating License Nos. DPR-33, DPR-52, and DPR-68 NRC Docket Nos. 50-259, 50-260, and 50-296

Subject:

Application to Revise Technical Specifications to Adopt Technical Specifications Task Force (TSTF)-542, "Reactor Pressure Vessel Water Inventory Control," Revision 2 (BFN-TS-513) In accordance with the provisions of Title 1O of the Code of Federal Regulations (10 CFR) 10 CFR 50.90, Tennessee Valley Authority (TVA) is submitting a request for an amendment to" the Technical Specifications (TS) for the Browns Ferry Nuclear Plant (BFN), Units 1, 2, and 3. In accordance with TSTF-542, the proposed changes replace existing TS requirements related to "operations with a potential for draining the reactor vessel" with new requirements on Reactor Pressure Vessel Water Inventory Control to continue to protect Safety Limit 2.1.1.3. Safety Limit 2.1.1.3 requires reactor vessel water level to be greater than the top of active irradiated fuel. Attachment 1 provides a description and assessment of the proposed changes. Attachments 2, 3, and 4 provide the existing TS pages marked to show the proposed changes for the three units. Attachments 5, 6, al)d 7 provide revised (clean) TS pages. Attachment 8 provides existing TS Bases pages marked to show the proposed changes for information only. Note - Only the Uni_t 1 TS Bases pages have been provided, as the Unit 2 and 3 changes will be nearly identical. Approval of the proposed amendment is requested by one year from the date of this letter. The 3-unit BFN refueling outages are sequenced to occur in coordinated intervals (Spring, Fall, Spring) followed by 10 months of 3-unit power operation before the next refueling outage interval begins. Because of shared-system complexity and to ensure uniform implementation across all three units, the amendments shall be implemented for all three units prior to the start of the interval beginning with the BFN Unit 3 Spring 2022 Cycle 20 refueling outage (3U20).

U.S. Nuclear Regulatory Commission CNL-19-010 Page 2 January 25, 2019 TVA has determined that there are no significant hazards considerations associated with the proposed change and that the TS change qualifies for a categorical exclusion from environmental review pursuant to the provisions of 10 CFR 51.22(c)(9). In accordance with 10 CFR 50.91 (b)(1 ), TVA is sending a copy of this letter and attachments to the Alabama State Department of Public Health. There are no new regulatory commitments contained in this submittal. Please address any questions regarding this submittal to Michael A. Brown at (423) 751-3275. I declare under penalty of perjury that the foregoing is true and correct. Executed on this

  • 2sth day of January 2019.

E .. K. Henderson Director, Nuclear Regulatory Affairs Attachments: 1. Description and Assessment

2. Proposed Technical Specification Changes (Unit 1 Mark-Up)
3. Proposed Technical Specification Changes (Unit 2 Mark-Up)
4. Proposed Technical Specification Changes (Unit 3 Mark-Up)
5. Revised Technical Specification Pages (Unit 1 Clean)
6. Revised Technical Specification Pages (Unit 2 Clean)
7. Revised Technical Specification Pages (Unit 3 Clean)
8. Proposed Technical Specification Bases Changes (Unit 1 Mark-Up)

(Information Only) cc (w/Attachments): NRC Regional Administrator- Region II NRC Senior Resident Inspector - Browns Ferry Nuclear Plant NRC Project Manager - Browns Ferry Nuclear Plant State Health Officer, Alabama State Department of Health

Attachment 1 to CNL-19-010 Description and Assessment CNL-19-010 Page 1 of 19

DESCRIPTION AND ASSESSMENT

1.0 DESCRIPTION

The proposed change replaces existing Technical Specifications (TS) requirements related to "operations with a potential for draining the reactor vessel" (OPDRVs) with new requirements on Reactor Pressure Vessel Water Inventory Control (RPV WIC) to protect Safety Limit 2.1.1.3. Safety Limit 2.1.1.3 requires reactor vessel water level to be greater than the top of active irradiated fuel. 2.0 ASSESSMENT 2.1 Applicability of Published Safety Evaluation Tennessee Valley Authority (TVA) has reviewed the safety evaluation provided to the Technical Specifications Task Force (TSTF) on December 20, 2016, as well as the information provided in TSTF-542. TVA has concluded that the justifications presented in TSTF-542 and the safety evaluation prepared by the NRC staff are applicable to the Browns Ferry Nuclear Plant (BFN) - Units 1, 2, and 3 and justify this amendment for the incorporation of the changes to the BFN TS. The following BFN TS reference or are related to OPDRVs and are affected by the proposed change: 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation 3.3.6.1 Primary Containment Isolation Instrumentation 3.3.6.2 Secondary Containment Isolation Instrumentation 3.3.7.1 Control Room Emergency Ventilation (CREV) System Instrumentation 3.5.2 ECCS - Shutdown 3.6.1.3 Primary Containment Isolation Valves (PCIVs) 3.6.4.1 Secondary Containment 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) 3.6.4.3 Standby Gas Treatment (SGT) System 3.7.3 Control Room Emergency Ventilation (CREV) System 3.7.4 Control Room Air Conditioning (AC) System 3.8.2 AC Sources - Shutdown 3.8.5 DC Sources - Shutdown 3.8.8 Distribution Systems - Shutdown 2.2 Variations TVA is proposing the.following variations from the TS changes described in TSTF-542 or the applicable parts of the Nuclear Regulatory Commission (NRC) staff's safety evaluation. These variations do not affect the applicability of TSTF-542 or the NRC staffs safety evaluation to the proposed license amendment. BFN is a BWR/4 plant. The proposed variations are based on the TSTF-542 markup of NUREG-1433 without a Setpoint Control Program. The BFN TS do not contain a Surveillance Frequency Control Program. Therefore, the references to a Surveillance Frequency Control Program for TS 3.3.5.2 and 3.5.2 are not included in the proposed TS. CNL-19-010 Page 2 of 19

2.2.1 Administrative Variations 2.2.1.1 The 8FN TS utilize different numbering, titles, and other minor differences than the Standard Technical Specifications (STS) on which TSTF-542 was based. The following table relates the administrative differences between the TS described in TSTF-542 and the 8FN TS: NUREG-1433 / NUREG-1433 / BFN Number BFN Nomenclati,..ire TSTF-542 TSTF-542 Number Nomenclature Table 3.3.5.1-1 Reactor Steam Dome Table 3.3.5.1-1 Reactor Steam Dome Function 1.c Pressure - Low Function 1.c Pressure - Low (Injection Permissive) (Injection Permissive and ECCS Initiation) Table 3.3.5.2-1 Required Channels Per Table 3.3.5.2-1 Required Channels Per Function 1.b (new) Function Function 1.b Function (new) [1 per pump(a)] " 1 per subsystem<a> TS 3.3.6.1 Initiate action to isolate TS 3.3.6.1 Initiate action to isolate Required Action J.2 the Residual Heat Required Action the Residual Heat (old) Removal (RHR) 1.2 (old) Removal (RHR) Shutdown Cooling Shutdown Cooling System System TS Table 3.3.7.1-1 Control Room Air Inlet TS Table Control Room Air Supply Function 5 Radiation - High 3.3.7.1-1 Duct Radiation - High Function 5 TS 3.5.2 Required Initiate action to TS 3.5.2 Initiate action to suspend Action 8.1 (old) suspend operations with Required Action OPDRVs a potential for draining 8.1 (old) the reactor vessel (OPDRVs) Surveillance Verify for each required SR 3.5.2.2 (old) Verify for each required Requirement

  • ECCS injection/spray ECCS injection/spray (SR) 3.5.2.3 (old) subsystem, the piping is subsystem, the piping is filled with water from the filled with water from the pump discharge valve to pump discharge valve to the injection valve the injection valve CNL-19-010 Page 3 of 19

NUREG-1433 / NUREG-1433 / BFN Number BFN Nomenc.latore TSTF-542 TSTF-542 Number Nomenclature SR 3.5.2.4 (old) Verify each required SR 3.5.2.3 (old) Verify each required ECCS injection/spray ECCS injection/spray subsystem manual, subsystem manual, power operated, and power operated, and automatic valve in the automatic valve in the flow path, that is not flow path, that is not locked, sealed, or locked, sealed, or otherwise secured in otherwise secured in position, is in the correct position, is in the correct position position SR 3.5.2.5 (old) Verify each required SR 3.5.2.4 (old) Verify each required ECCS pump develops ECCS pump develops the specified flow rate the specified flow rate [against a system head [against a system head corresponding to the corresponding to the specified reactor specified reactor pressure]. pressure. [Pump Performance [Pump Performance Table] Table] 1 SR 3.5.2.7 (new) Verify each valve SR 3.5.2.6 (new) Verify each valve credited for credited for automatically automatically isolating a isolating a penetration penetration flow path flow path actuates to the actuates to the isolation isolation position on an position on an actual or actual or simulated simulated isolation isolation signal signal TS 3.7.4 Main Control Room TS 3.7.3 Control Room Environmental Control Emergency Ventilation (MCREC) System (CREV) System TS 3.7.5 Control Room Air TS 3.7.4 Control Room Air Conditioning (AC) Conditioning (AC) System System TS 3.8.5 Required Initiate action to TS 3.8.5 Initiate action to suspend Action B.2.3 (old) suspend operations with Required Action operations with a a potential for draining A.2.3 (old) potential for draining the the reactor vessel. reactor vessel. 1 The format of the ECCS Pump Performance Table is different between the two SRs, but contains equivalent information. CNL-19-010 Page 4 of 19

NUREG-1433 / NUREG-1433 / BFN Number. BFN Nomenclature TSTF-542 *TSTF-542 Number N,omenclature TS 3.8.5 Required Initiate action to restore TS 3.8.5 Initiate action to restore Action B.2.3 (new) required DC electrical Required Action required DC electrical power subsystems to A.2.3 (new) power subsystems or Operable status. systems to Operable status. TS 3.8.10 Distribution Systems - TS 3.8.8 Distribution Systems - Shutdown Shutdown 2.2.1.2 The BFN TS do not contain some of the STS on which TSTF-542 made changes. The following table dispositions the TSTF-542 TS changes that are not applicable to BFN: NUREG-1433 / NUREG-1433 / Disposition TSTF-542 TSTF-542 Number Description Table 3.3.5.1-1 Perform Channel The NUREG-1433 SR 3.3.5.1.5 is performed Functions 1.c and Calibration with a cyclic frequency, and correlates with BFN 2.c. invoking SR SR 3.3.5.1.5. For these functions, SR 3.3.5.1.4 3.3.5.1.5 is performed, which has a 184 day frequency. However, the justification provided in TSTF-542 remains valid for removing the Mode 4 and Mode 5 applicability for performing this SR. ' Table 3.3.5.1-1 ECCS Response Removal of this SRs applicability to Modes 4 Functions 1.a/c Time testing and 5 from Table 3.3.5.1-1 Functions 1.a, 1.c, and 2.a/c invoking 2.a, and 2.c is not applicable to BFN. SR 3.3.5.1. 7 TS 3.3.5.3 (new) As required by BFN Condition D does not invoke Table 3.3.5.2-Condition D Required Action A.1 1 (old). Therefore, the change in table and referenced in designation is not applicable. Table 3.3.5.3-1 (new) SR 3.3.5.3.3 (new) Calibrate trip units BFN does not have this requirement. Therefore, the re-designation of SR 3.3.5.2.3 to 3.3.5.3.3 is not applicable to this surveillance. SR 3.3.5.3.4 (new} Perform Channel BFN does not have this requirement. Calibration [92 days] Therefore, the re-designation of SR 3.3.5.2.4 to 3.3.5.3.4 is not applicable to this surveillance. CNL-19-010 Page 5 of 19

NUREG-1433 / NUREG-1433 / Disposition TSTF-542 TSTF-542 Number Description TS Table 3.3.5.2-1 Reactor Water The analogous BFN function actuates on Level Function 4.a Cleanup (RWCU) 3 rather than Level 2. However, for purposes of System Isolation including this function on new Table 3.3.5.2-1 Reactor Vessel this is an administrative variation. Water Level - Low Low, Level 2 TS Table 3.3.5.3-1 Condensate Storage BFN does not have this function. Therefore, the (new) Function 3 Tank Level - Low re-designation of the SR nomenclature is not applicable. TS Table 3.3.6.2-1 Reactor Vessel The analogous BFN function actuates on Level Function 1 Water Level - Low 3 rather than Level 2. However, for purposes of Low, Level 2 removing Footnote (a) from this function this is an administrative variation. TS Table 3.3.6.2-1 During movement of BFN.does not have this footnote. Therefore, its Footnote (b) (old) [recently] irradiated re-designation as Footnote (a) is not applicable fuel assemblies in for Functions 3 and 4. As a result, with the [secondary] deletion of Footnote (a}, the comma is being containment removed after Mode 3 for Functions 3 and 4. Additionally, BFN does not have Function 5 for which Footnote (b) is re-designated. TS Table 3.3.7.1-1 Reactor Vessel The analogous BFN function actuates on Level Function 1 Water Level - Low 3 rather than Level 1. However, for purposes of Low Low, Level 1 removing Footnote (a) from this function this is an administrative variation. TS Table 3.3.7.1-1 During movement of BFN does not have this footnote. Therefore, its Footnote (b) (old) [recently] irradiated re-designation as Footnote (a) is not applicable fuel assemblies in for Functions 4 and 5. As a result, with the [secondary] deletion of Footnote (a}, the comma is being containment removed after Mode 3 for Functions 4 and 5. SR 3.5.2.1 (old) Verify for each BFN SR 3.5.2.1 (old) encompasses equivalent required low pressure suppression pool level verification for both LPCI SR 3.5.2.2 (old} coolant injection and CS. Therefore, the revised wording will be * (LPCI) subsystem, "the required ECCS," consistent with the the suppression pool changes made in new BFN SRs 3.5.2.3, 3.5.2.4, water level is ~ [12 ft 3.5.2.5, and 3.5.2.7, which is an administrative 2 inches] variation. Verify for each The deleted Note in SR 3.5.2.2 (old) and required core spray verification of condensate storage tank level is (CS) subsystem, the: not applicable to BFN. a) Suppression pool CNL-19-010 Page 6 of 19

NUREG-1433 / NUREG-1433 / Disposition TSTF-542 TSTF-542 Number Description water level is ~ [12 ft 2 inches] orb) Condensate storage tank water level is ~ [12 ft] TS 3.8.8 Inverters - Shutdown BFN does not have this TS; therefore, it is not applicable. 2.2.1.3 Certain variations are taken in footnote changes in Tables 3.3.5.1-1 and 3.3.6.1-1. As described in the following table, these are considered to be administrative in nature: NUREG-1433 BFN Footnote Disposition Footnote Table 3.3.5.1-1 Table 3.3.5.1-1 The deleted footnote in NUREG-1433 references Footnote (a) (old) Footnote (a) (old) LCO 3.5.2, which is not included in the analogous BFN footnote. However, the meaning is identical. Table 3.3.5.1-1 Table 3.3.5.1-1 TSTF-542 deletes this footnote and re-designates Footnote (a) (new) Footnote (a) (new) the subsequent footnotes. TVA has opted to and subsequent insert "Deleted" in Footnote (a) and maintain the footnote re- subsequent footnote designations to minimize designations procedural impacts. Table 3.3.6.1-1 Table 3.3.6.1-1 The deleted BFN footnote differs from NUREG-Footnote (c) (old) Footnote (b) (old) 1433 due to differences in the isolation logic for the RHR shutdown cooling isolation valves, and is immaterial to the footnote's deletion on this table. Because a Footnote (c) exists fqr this table the text for Footnote (b) is replaced with "Deleted.". 2.2.1.4 Per TSTF-542, TS Table 3.3.5.2-1 Function 1.a [Core Spray System Reactor Steam Dome Pressure - Low (Injection Permissive)] and Function 2.a [Low Pressure Coolant Injection Reactor Steam Dome Pressure - Low (Injection Permissive)] are required in Modes 4 and 5. Prior to TSTF-542, the analogous Functions 1.c and 2.c in TS Table 3.3.5.1-1 had a Mode 4 and 5 applicability modified by a footnote

  • specifying that these functions were only required when the associated ECCS were required to be Operable per LCO 3.5.2, "ECCS Shutdown." The footnote was inadvertently omitted from Table 3.3.5.2-1 Functions 1.a and 2.a in TSTF-542 (although the Bases for these new functions specify that operability is only required when supporting manual initiation for LCO 3.5.2). Without the footnote, the Reactor Steam Dome Pressure - Low functions are required to be operable for all low CNL-19-010 Page 7 of 19

pressure ECCS subsystems, regardless of whether they are credited for meeting TS 3.5.2, "Reactor Pressure Vessel Water Inventory Control." Requiring the functions for all ECCS subsystems is unnecessary. In Modes 4 and 5 with the reactor steam dome at atmospheric pressure, these functions only serve to satisfy permissives to open low pressure ECCS injection valves for manual actuation. Accordingly, an administrative variation is proposed to affix Footnote (a) ("Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, 'Reactor Pressure Vessel Water Inventory Control"') to the Required Channels Per Function (RCPF) column of Functions 1.a and 2.a of TS Table 3.3.5.2-1. 2.2.1.5 TSTF-542 removes Footnote (a), "During operations with a potential for draining the reactor vessel," from Table 3.3.7.1-1, Function 4, "Refueling Floor Area Radiation - High." The BFN design does not have refueling floor area radiation monitors that actuate the CREV System. Instead, the BFN design has Function 3, "Reactor Zone Exhaust Radiation - High," and Function 4, "Refueling Floor Exhaust Radiation - High," which provide the CREV System actuation with the identical footnote. The justification in TSTF-542 remains valid for removing the footnote from these alternate BFN functions, so this is considered to be administrative in nature. 2.2.1.6 In NUREG-1433, LCO 3.5.2 is modified by a Note regarding the Low Pressure Coolant Injection subsystem being considered OPERABLE during alignment and operation for decay heat removal. This Note is modified by TSTF-542 to change . 

        "one" to "a." In the BFN TS, this Note modifies new SR 3.5.2.4 (rather than the LCO). The verbiage is the same between the BFN TS and NUREG-1433, but the location of the Note in NUREG-1433 was changed from the SR to the LCO as a result of TSTF-416. To maintain consistency with the presentation in TSTF-542, the SR 3.5.2.4 note is being deleted from the SR and moved to LCO 3.5.2 at the LCO level. This variation is administrative and does not affect the applicability of rsTF-542 to the BFN TS.

2.2.1.7 TSTF-542 establishes new SR 3.5.2.6 as: "Operate the required ECCS injection/spray subsystem through the recirculation line for~ 10 minutes." The term "recirculation line" is replaced with "test return line" in new SR 3.5.2.5. This is the proper BFN terminology, and is changed to avoid confusion with the Reactor Recirculation piping. 2.2.1.8 BFN TS 3.6.1.3 contains the following Applicability in addition to Modes 1, 2, and 3: When associated instrumentation is required to be Operable per LCO 3.3.6.1, "Primary Containment Isolation Instrumentation." However, with the removal of Modes 4 and 5 Applicability for Table 3.3.6.1-1 Function 6.b, "Shutdown Cooling System Isolation - Reactor Vessel Water Level - Low, Level 3," this table no longer contains any other Applicable Modes designated besides Modes 1, 2, or 3. Accordingly, the TS 3.6.1.3 Applicability is revised to delete the above sentence referencing LCO 3.3.6.1. Additionally, since the only Applicability for TS 3.6.1.3 will be Modes 1, 2, and 3, it is not necessary to reiterate these Modes in Actions Note 4 and Condition E, and so references to Modes 1, 2, and 3 are being deleted. CNL-19-010 Page 8 of 19

2.2.1.9 BFN TS 3.6.1.3 Condition F states: Required Action and associated Completion Time of Condition A, B, C, or D not met for PCIV(s) required to be Operable during Mode 4 or 5. This Condition is analogous to STS 3.6.1.3 Condition H, as revised by - TSTF-542 (except without the reference to OPDRVs). However, with the removal of Modes 4 and 5 Applicability for Table 3.3.6.1-1 Function 6.b, "Shutdown Cooling System Isolation - Reactor Vessel Water Level - Low, Level 3," there are no longer any PCIV operability requirements when in Modes 4 or 5. Accordingly, the entire Condition, Required Action, and Completion Time are being removed (versus just the references to OPDRVs in TSTF-542), as this is no longer applicable. 2.2.1.10 As a result of incorporating TSTF-542 changes, BFN TS 3.6.4.1 will only have Applicability in Modes 1, 2, and 3. Accordingly, in Condition A, since it is no longer necessary to specify "in Modes 1, 2, or 3," this phrase is being deleted. 2.2.1.11 BFN TS 3.6.4.1 Condition C states: Secondary containment inoperable during OPDRVs. This Condition is analogous to STS 3.6.4.1 Condition C, as revised by TSTF-542. However, the BFN TS does not contain the requirements related to the movement of irradiated fuel in the LCO Applicability or in this Condition. Accordingly, the entire Condition, Required Action, and Completion Time are being removed (versus just the references to OPDRVs in TSTF-542), as this is no longer applicable. 2.2.1.12 As a result of incorporating TSTF-542 changes, BFN TS 3.6.4.2 will only have Applicability in Modes 1, 2, and 3. Accordingly, in Condition C, since it is no longer necessary to specify "in Modes 1, 2, or 3," this phrase is being deleted. 2.2.1.13 BFN TS 3.6.4.2 Condition D states: Required Action and associated Completion Time of Condition A or B not met during OPDRVs. This Condition is analogous to STS 3.6.4.2 Condition D, as revised by TSTF-542. However, the BFN TS does not contain the requirements related to the movement of irradiated fuel in the LCO Applicability or in this Condition. Accordingly, the entire Condition, Required Action, and Completion Time are being removed (versus just the references to OPDRVs in TSTF-542), as this is no longer applicable. 2.2.1.14 As a result of incorporating TSTF-542 changes, BFN TS 3.6.4.3 will only have Applicability in Modes 1, 2, and 3. Accordingly, in Condition B and Condition C (new), since it is no longer necessary to specify "in Modes 1, 2, or 3," this phrase is being deleted. 2.2.1.15 BFN TS 3.6.4.3 Condition C states: Required Action and associated Completion Time of Condition A not met during OPDRVs. CNL-19-010 Page 9 of 19

This Condition is analogous to STS 3.6.4.3 Condition C, as revised by TSTF-542. However, the BFN TS does not contain the requirements related to the movement of irradiated fuel in the LCO Applicability or in this Condition. Accordingly, the entire Condition, Required Action, and Completion Time are being removed (versus just the text related to OPDRVs in TSTF-542), as this is no longer applicable. As a result, the subsequent Condition D is being re-designated as Condition C. 2.2.1.16 BFN TS 3.6.4.3 Condition E states: Two orthree SGT subsystems inoperable during OPDRVs. This Condition is analogous to STS 3.6.4.3 Condition E, as revised by TSTF-542. However, the BFN TS does not contain the requirements related to the movement of irradiated fuel in the LCO Applicability or in this Condition. Accordingly, the entire Condition, Required Action, and Completion Time are being removed (versus just the text related to OPDRVs in TSTF-542), as this is no longer applicable. 2.2.1.17 As a result of incorporating TSTF-542 changes, BFN TS 3.7.3 will only have Applicability in Modes 1, 2, and 3. Accordingly, in Conditions B and E and Condition F (new), since it is no longer necessary to specify "in Modes 1, 2, or 3," this phrase is being deleted. 2.2.1.18 BFN TS 3. 7.3 Condition F states: Required Action and associated Completion Time of Condition A or D not met during OPDRVs. and BFN TS 3.7.3 Condition H states: Required Action and associated Completion Time of Condition C not met during 

            *QPDRVs.

Two GREV subsystems inoperable during OPDRVs for reasons other than Condition C. One or more GREV subsystems inoperable due to an inoperable CRE Boundary during OPDRVs. These Conditions are collectively analogous to STS 3.7.4 Conditions D and F, which are revised by TSTF-542. However, the BFN TS do not contain the requirements related to the movement of irradiated fuel in the LCO Applicability or in these Conditions. Accordingly, the entire Condition F and H, Required Actions, and Completion Times are being removed (versus just the references to OPDRVs in TSTF-542), as they are no longer applicable. As a result, Condition G (which follows) is re-designated as Condition F. CNL-19-010 Page 1O of 19

2.2.1.19 BFN TS 3. 7.4 Condition D states: 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. This Condition is analogous to STS 3.7.4 Condition D and E, as revised by TSTF-542 (although without the requirements related to Core Alterations). The BFN Condition D removes the reference to OPDRVs consistent with the TSTF-542 changes to STS Condition D and E. BFN Required Action D.2.3 regarding suspending OPDRVs and its Completion Time are deleted consistent with TSTF-542 for Required Action D.2.2 and E.2. 2.2.1.20 BFN TS 3.8.2 Condition B contains four Required Actions designated 8.1.1, B.1.2, B.1.3, and B.1.4. Required Action B.1.3 is being deleted, consistent with the deletion of Required Action B.3 in TSTF-542. However, because there is no existing "B.2" Required Action, the resulting Required Actions are re-designated as B.1, B.2, and B.3, consistent with the TSTF-GG-05-01, Revision 1, "Writer's Guide for Plant-Specific Improved Technical Specifications." (ADAMS ML070660229) 2.2.1.21 The following administrative changes are made: TVA is taking this opportunity to rebaseline the BFN Units 1/2/3 TS Tables of Contents (TOC) contained in the TS of record. This includes:

1) Adding TS 3.9.9, "Decay Time," that was inadvertently not included in the BFN Unit 1/2/3 TOC by Amendments 251/290/249 respectively.
2) Revising the List of Figures for BFN Unit 2/3 page numbers for Figure 3.4.9-1, and entering a new line item was entered for Figure 3.4.9-2. These were the*result of License Amendments 314/278, for BFN Unit 2/3 respectively. .
3) Deleting Figure 3.7.1-1 from the BFN Unit2/3 List of Figures as a result of License Amendments 323/283, respectively.
4) To promote consistency of content, the List of Tables and List of Figures is added to the BFN Unit 1 TOC, and the List of Tables is added to the BFN Unit 2 TOC.
5) BFN Unit 1/2 TOC pages are re-issued in Attachments 5 and 6 due to a previous conversion to a newer word processing software version.

Changes to the Drain Time definition formatting are made *in conformance with BFN TS numbering convention A typographical correction is made to Paragraph b.3 of the Drain Time definition: 

            " ... who is in continuous communication ... "

The "1" designation is removed from the Note in TS 3.3.5.1 Required Action B.1 which was inadvertently retained in the traveler. TS 3.3.5.2 Required Action E.1 defines first use of "ECCS" in accordance with the TSTF-GG-05-01. CNL-19-010 Page 11 of 19

TS Table 3.3.5.2-1 Function 3 is defined as "Shutdown Cooling System Isolation, consistent with the analogous function in Table 3.3.6.1-1 from which it was derived. The comma is removed from the TS 3.6.4.1, 3.6.4.2, 3.6.4.3, and 3.7.3 Applicability after Mode 3, and from TS 3.7.4 Applicability after Core Alterations, because there is no subsequent line any longer. For TS 3.6.1.3, 3.6.4.1, 3.6.4.2, 3.6.4.3, 3.7.3, 3.8.5, necessary formatting changes are made such as text relocations to preceding pages, designations of intentionally blank pages, page deletions, and insertions of double underlines that are not specifically annotated in TSTF-542. Consistent with the TSTF-GG-05-01, periods (.) have been added at the end of the TS Applicability entries for TS 3.5.2, 3.6.4.1, 3.6.4.3, 3.7.3, and 3.7.4. 2.2.2 Technical Variations 2.2.2.1 The BFN TS contain certain requirements not included in the STS that were not addressed by TSTF-542, but are affected by the proposed change. The following table dispositions these TS changes. 13FNTS BFN TS Disposition Number Description Table 3.3.5.-1-1 Core Spray Pump Start - NUREG-1433 does not have a requirement Function 1.e Time Delay Relay during for this function in Modes 4 and 5 and so was Modes 4 and 5 not addressed in TSTF-542. However, this Function is similar to Function 2.f for LPCI that was deleted by TSTF-542, and not relocated to new Table 3.3.5.2 because ECCS auto-start on the diesel generators is no longer required. Accordingly, it is appropriate to delete this function for CS. 2.2.2.2 There are STS requirements on which TSTF-542 is based, related to "manual initiation," that do not appear in the BFN TS. STS Table 3.3.5.1-1 contains Functions 1.e and 2.h, Manual Initiation, for CS and LPCI, respectively. The "manual initiation" logic does not exist in the BFN design. Therefore, Table 3.3.5.2-1 Functions 1.c and 2.c, as well as the related TSTF-542 SR 3.3.5.2.3 and SR 3.5.2.8, do not apply to BFN. As an alternative, TVA proposes that TS 3.5.2 include SR 3.5.2.7 to verify that the BFN required ECCS injection/spray subsystem can be manually operated. The manual operation of the required ECCS injection/spray subsystem for the control of reactor cavity or reactor pressure vessel inventory is a relatively simple evolution and involves the manipulation of a small number of components. These subsystem alignments can be performed by licensed operators from the Main Control Room. CNL-19-010 Page 12 of 19

This alternative is justified by the fact that a draining event is a slow evolution when compared to a design basis loss of coolant accident, which is assumed to occur at full power. Therefore, there is adequate time to take manual actions (i.e., hours versus minutes). Adequate time to take action is assured because the proposed TS 3.5.2, Condition E, prohibits plant conditions that result in drain times that are less than one hour. Therefore, there is sufficient time for the licensed operators to take manual action to stop an unanticipated draining event, and to manually start an ECCS injection/spray subsystem or the additional method of water injection. Because the EGGS injection/spray subsystem can be placed in service using manual means in a short period of time (i.e., within the time frames assumed in the development of TSTF-542), using controls and indications that are readily available in the Main Control Room, manual operation of the required subsystem would be an equivalent alternative to system initiation via manual initiation logic. Current SR 3.5.1.6 and SR 3.5.2.4 require manually operating the EGGS injection/spray pumps to verify each required EGGS injection/spray pump develops the specified flow rate against a system head corresponding to the specified reactor pressure at a frequency specified by the lnservice Testing (1ST) Program. The 1ST Program requires the ECCS injection/spray subsystems motor operated injection valves, minimum flow valves and test flow path valves be cycled to demonstrate operability at a frequency specified by the 1ST Program. The manual operation of the ECCS injection/spray subsystem to demonstrate operability required by the proposed SR 3.5.2. 7 is equivalent to the testing that is presently required to be performed on the ECCS injection/spray subsystems. This variation was also proposed by Dresden Nuclear Power Station, Brunswick Steam Electric Plant, Cooper Nuclear Station, James A. FitzPatrickNuclear Power Plant, and Edwin I. Hatch Nuclear Plant. 2.2.2.3 TSTF-542 Table 3.3.5.2-1 Function 1.d. [Core Spray Pump Discharge Flow - Low (Bypass)] specifies the inclusion of SR 3.3.5.1.1, "Perform Channel Check." BFN does not have the capability to perform a Channel Check for analogous Table 3.3.5.2-1, Function 1.b., and this is not a current requirement in BFN TS Table 3.3.5.1-1. Accordingly, no Channel Check is proposed for this function. This variation was. also proposed by Cooper Nuclear Station, Duane Arnold Energy Center, and Dresden Nuclear Power Station. 2.2.2.4 BFN TS Table 3.3.5.1-1 Function 1.c [Core Spray System Reactor Steam Dome Pressure - Low (Injection Permissive and ECCS Initiation)] specifies four RCPF with two per trip system. Each trip system correlates to a single CS injection valve, and has a one-out of-two logic. As described in the Bases for this function, four channels are required to ensure that no single instrument failur~ can preclude ECCS initiation. However, as described in Section 3.3 of the TSTF-542 Safety Evaluation, only one ECCS injection/ spray subsystem is required to be operable in Modes 4 and 5, as no additional single failure is assumed. In developing the new BFN Table 3.3.5.2-1, that principle is carried forward in requiring only a single channel per CS subsystem be operable for Function 1.a. 2.2.2.5 BFN TS Table 3.3.5.1-1 Function 2.c (LPCI System Reactor Steam Dome Pressure 

        - Low (Injection Permissive and ECCS Initiation) specifies four RCPF. This CNL-19-010
  • Page 13 of 19

correlates to two channels in Trip System A (powered by Division I) and two channels in Trip System B (powered by Division II) which are configured in series with a cross-connect between the divisional output contacts. Since outage planning and scheduling is typically based around "protected" Divisions, it follows that either Trip System A or B may be unavailable. Notwithstanding, trip capability is maintained by the other trip system in a two-out-of-two trip logic for each LPCI Injection Valve. As described in Section 3.3 of the TSTF-542 Safety Evaluation, only one EGGS injection/spray subsystem is required to be operable in Modes 4 and 5, as no additional single failure is assumed. Consistent with single failure not being applicable for RPV Water Inventory Control, only two channels in one trip system are required to be operable for Function 2.a. 2.2.2.6 STS Table 3.3.5.1-1 Function 2.g (LPCI Pump Discharge Flow - Low, Bypass) does not exist in the BFN TS. This is because the RHR minimum flow valve is open when in the standby configuration, and is sized such that LPCI subsystem remains operable even with the valve fully open. Accordingly, the analogous STS Table 3.3.5.2-1 Function 2.b (LPCI Pump Discharge Flow - Low, Bypass) has not been added to new BFN Table 3.3.5.2-1. 2.2.2.7 STS Table 3.3.6.1-1 Function 6.b (Shutdown Cooling System Isolation - Reactor Vessel Water Level - Low, Level 3) designates two required channels in one trip system in Modes 4 and 5. This was transferred to new Table 3.3.5.2-1 Function 3.a with two required channels in one trip system. As described in the STS 3.3.6.1 Bases Background for Function 6, four reactor water level channels input to two two-out-of-two trip systems, with each of the two trip systems associated with one of the two valves on each shutdown cooling penetration. Thus, two channels are required in one trip system to ensure either the inboard or outboard isolation valve closes on a valid signal. The logic design for BFN is different from the NUREG-1433 reference plant. The BFN logic is four channels arranged with two channels in Trip System A and two channels in Trip System B. They are arranged in a one-out-of-two-taken-twice logic, which isolates both the inboard and outboard isolation valves. Thus, for new Table 3.3.5.2-1 Function 3.a, one required channel per trip system is specified. This is consistent with the existing requirements in Table 3.3.6.1-1 Footnote (b). The closure logic is the same for the RWCU isolation valves. Therefore, new Table 3.3.5.2-1 Function 4.a similarly specifies one required channel per trip system. 2.2.2.8 BFN is designed with three subsystems of SGT servicing all three units. A minimum of two subsystems of SGT are required per the TS 3.6.4.3 Bases to keep the three Reactor Building Zones and the common Refueling Zone at the required negative pressure. In contrast, the reference plant for NUREG-1433 requires only a single SGTS subsystem to maintain secondary containment at negative pressure, as described in the Bases to STS 3.6.4.3. Accordingly, a technical variation is taken for new TS 3.5.2 Required Action C.3 to require verification of two SGT subsystems are capable of being placed in operation in less than the Drain Time, instead of a single SGT subsystem. Similarly, new Required Action D.4 will initiate action to establish two SGT subsystems are capable of being placed in operation, instead of a single SGT subsystem. 2.2.2.9 TSTF-542 TS 3.5.2 Required Actions C.1, C.2, C.3, D.2, D.3, and D.4 are premised on the assumption that secondary containment has been relaxed. BFN Units 1, 2, and 3 have a common refueling floor and shared SGT subsystems. This results in CNL-19-010 Page 14 of 19

secondary containment rarely being relaxed; i.e. secondary containment, the SCIVs, and the SGT System are maintained Operable per an online Unit's TS. Accordingly, a technical variation is taken for Required Action D.3 to allow crediting automatic isolation of each secondary containment penetration flow path as an alternative to a manual isolation from the control room. A statement is also made in the TS Bases that Required Actions C.1, C.2, C.3, D.2, D.3, and D.4 are considered to be met when secondary containment, secondary containment isolation valves, and the SGT system are Operable. 2.2.2.1 O BFN Units 1 and 2 SR 3.8.2.1 require that for the Unit 1 and 2 AC sources required to be Operable, the SRs of Specification 3.8.1 are applicable. This SR is modified by a Note that excludes certain SRs from the AC Sources - Operating TS. As stated in the SR 3.8.2.1 Bases, it is the intent that these excluded SRs must still be capable of being met, but actual performance is not required during periods when the DG and offsite circuit is required to be Operable. However, with the adoption of TSTF-542, there is no longer a need for a diesel generator auto start on an accident signal. Accordingly, SR 3.8.1.9, "Verify, on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal. .. ," may be removed from the SR 3.8.2.1 Note and listed .as an exception to this SR. Similarly, SR 3.8.1.6, "Verify on an actual or simulated accident signal each DG auto-starts from standby condition," is no longer necessary and may be included as an exception to SR 3.8.2.1. Analogous changes are made to the BFN Unit 3 SR 3.8.2.1 related to the Unit 3 AC sources required to be Operable. 2.3 Site-Specific Justifications 2.3.1 Surveillance Frequencies TSTF-542 contains several new SRs with Frequencies that are designated as site specific. A justification for these values is provided in the table below. BFN SR BFN Disposition Frequency SR 3.3.5.2.1 - Perform 24 hours This Frequency is consistent with the current Channel Check licensing basis for these Functions formerly performed as part of TS 3.3.5.1 and 3.3.6.1. SR 3.3.5.2.2 - Perform 92 days This Frequency is consistent with the current Channel Functional Test licensing basis for these Functions formerly performed as part of TS 3.3.5.1 and 3.3.6.1. SR 3.5.2.1 - Verify Drain 12 hours The Frequency is selected based on the fact Time ;:: 36 hours that numerous indications of changes in RPV level are available to the operator, as noted in Section 3.2 of the TSTF-542 Safety Evaluation. SR 3.5.2.5 - Operate the 92 days The Frequency is consistent with other at-required ECCS injection/ power testing, as noted in Section 3.2 of the spray subsystem through TSTF-542 Safety Evaluation. the test return line for ;:: 10 minutes. CNL-19-010 Page 15 of 19

BFNSR BFN

  • Disposition Frequency SR 3.5.2.6 - Verify each 24 months The [18] month Frequency specified in TSTF-valve credited for 542 correlates to performance once every automatically isolating a refueling cycle. BFN has a 24 month penetration flow path refueling cycle.

actuates to the isolation position on an actual or simulated isolation signal. 2.3.2 Table 3.3.5.2-1 Entries New Table 3.3.5.2-1 contains site-specific values for the RCPF and Allowa61e Value (AV) columns. A justification for these values is provided in the table below. - BFN Table BFN Values TSTF-542 Disposition 3.3.5.2-1 Function Values 1.a - Core Spray RCPF- 1 per RCPF- [4] As described in Section 2.2.2.4 System Reactor subsystem Steam Dome Pressure - Low AV- s 465 AV- [S 500] As transcribed from the AV from (Injection psig psig Table 3.3.5.1-1 Function 1.c (per Permissive) TSTF-542, onlv the upper AV is required)

  • . 1.b - Core Spray RCPF- 1 per RCPF- [1 BFN has a single min-flow valve for each Pump Discharge subsystem per pump] two-pump CS subsystem Flow- Low (Bypass)

AV-'?:.1647 AV- Not As transcribed from the AV from Table gpm and specified 3.3.5.1-1 Function 1.d s 2910 gpm 2.a - LPCI System RCPF-2 in RCPF- [4] As described in Section 2.2.2.5 Reactor Steam one trip Dome Pressure - system Low (Injection Permissive) AV- s 465 AV - [S 500] As transcribed from the AV from Table psig psig 3.3.5.1-1 Function 2.c (per TSTF-542, only the upper AV is required) 3.a - Shutdown RCPF- 1 per RCPF- [2 in As described in Section 2.2.2. 7 Cooling System trip system one trip Isolation - Reactor system] Vessel Water Level - Low, Level AV-'?:. 528 AV-'?:.[10] As transcribed from the AV from Table 3 inches above inches 3.3.6.1-1 Function 6. b vessel zero CNL-19-010 Page 16 of 19

BFN Table BFN Values TSTF-542 Disposition 3.3.5.2-1 Function Values 4.a-RWCU RCPF- 1 per RCPF- [2 in As described in Section 2.2.2. 7 System Isolation - trip system one trip Reactor Vessel system] Water Level - Low, Level 3 AV-~ 528 AV - ~ [-47] As transcribed from the AV from Table inches above inches 3.3.6.1-1 Function 5.h for Modes 1, 2, and vessel zero 3. Per Section 2.3.3.2.2.5 of the TSTF-542 Safety Evaluation, the AV is

  • unchanged for this new function.

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Consideration Analysis Tennessee Valley Authority, (TVA) requests adoption of Technical Specification Task Force (TSTF)-542 "Reactor Pressure Vessel Water Inventory Control," which is an approved change to the Standard Technical Specifications, into the Browns Ferry Nuclear Plant Units 1, 2, and 3, Technical Specifications (TS). The proposed amendment replaces the existing requirements in the TS related to "operations with a potential for draining the reactor vessel" (OPDRVs) with new requirements on Reactor Pressure Vessel Water Inventory Control (RPV WIC) to protect Safety Limit 2.1.1.3. Safety Limit 2.1.1.3 requires reactor vessel water level to be greater than the top of active irradiated fuel. TVA has evaluated whether or not a significant hazards consideration is involved with the proposed amendmerit(s) by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below:

1. Does the proposed amendment involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No The proposed change replaces existing TS requirements related to OPDRVs with new requirements on RPV WIC that will protect Safety Limit 2.1.1.3. Draining of RPV water inventory in Mode 4 (i.e., cold shutdown) and Mode 5 (i.e., refueling) is not an accident previously evaluated and, therefore, replacing the existing TS controls to prevent or mitigate such an event with a new set of controls has no effect on any accident previously evaluated. RPV water inventory control in Mode 4 or Mode 5 is not an initiator of any accident previously evaluated. The existing OPDRV controls or the proposed RPV WIC controls are not mitigating actions assumed in any accident previously evaluated. The proposed change reduces the probability of an unexpected draining event (which is not a previously evaluated accident) by imposing new requirements on the limiting time in which an unexpected draining event could result in the reactor vessel water level dropping to the top of the active fuel (TAF). These controls require cognizance of the plant configuration and control of configurations with unacceptably short drain times. CNL-19-010 Page 17 of 19

These requirements reduce the probability of an unexpected draining event. The currenf TS requirements are only mitigating actions and impose no requirements that reduce the probability of an unexpected draining event. The proposed change reduces the consequences of an unexpected draining event (which is not a previously evaluated accident) by requiring an Emergency Core Cooling System (EGGS) subsystem to be operable at all times in Modes 4 and 5. The current TS requirements do not require any water injection systems, EGGS or otherwise, to be Operable in certain conditions in Mode 5. The change in requirement from two EGGS subsystems to one EGGS subsystem in Modes 4 and 5 does not significantly affect the consequences of an unexpected draining event because the proposed Required Actions ensure equipment is available within the limiting drain time that is as capable of mitigating the event as the current requirements. The proposed controls provide escalating compensatory measures to be established as calculated drain times decrease, such as verification of a second method of water injection and additional confirmations that containment and/or filtration would be available if needed. The proposed change reduces or eliminates some requirements that were determined to be unnecessary to manage the consequences of an unexpected draining event, such as automatic initiation of an EGGS subsystem and control room ventilation. These changes do not affect the consequences of any accident previously evaluated because a draining event in Modes.4 and 5 is not a previously evaluated accident and the requirements are not needed to adequately respond to a draining event. Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

2. Does the proposed amendment create the possibility of a new or different kind of accident from any previously evaluated?

Response: No The proposed change replaces existing TS requirements related to OPDRVs with new requirements on RPV WIG that will protect Safety Limit 2.1.1.3. The proposed change will not alter the design function of the equipment involved. Under the proposed change, some systems that are currently required to be operable during OPDRVs would be

  • required to be available within the limiting drain time or to be in service depending on the limiting drain time. Should those systems be unable to be placed into service, the consequences are no different than if those systems were unable to perform their function under the current TS requirements.

The event of concern under the current requirements and the proposed change is an unexpected draining event. The proposed change does not create new failure mechanisms, malfunctions, or accident initiators that would cause a draining event or a new or different kind of accident not previously evaluated or included in the design and licensing bases. Therefore, the proposed change does not create the possibility of a new or different kind of accident from any previously evaluated. CNL-19-010 Page 18 of 19

3. Does the proposed amendment involve a significant reduction in a margin of safety?

Response: No The proposed change replaces existing TS requirements related to OPDRVs with new requirements on RPV WIC. The current requirements do not have a stated safety basis and no margin of safety is established in the licensing basis. The safety basis for the new requirements is to protect Safety Limit 2.1.1.3. New requirements are added to determine the limiting time in which the RPV water inventory could drain to the top of the fuel in the reactor vessel should an unexpected draining event occur. Plant configurations that could result in lowering the RPV water level to the TAF within one hour are now prohibited. New escalating compensatory measures based on the limiting drain time replace the current controls. The proposed TS establish a safety margin by providing defense-in-depth to ensure that the Safety Limit is protected and to protect the public health and safety. While some less restrictive requirements are proposed for plant configurations with long calculated drain times, the overall effect of the change is to

  • improve plant safety and to add safety margin.

Therefore, the proposed change does not involve a significant reduction in a margin of safety. Based on the above, TVA concludes that the proposed change presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and, accordingly, a finding of "no significant hazards consideration" is justified. 4.0 ENVIRONMENTAL EVALUATION The proposed change would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or surveillance requirement. However, the proposed change does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed change. CNL-19-010 Page 19 of 19

Attachment 2 to CNL-19-01 O Proposed Technical Specification Changes (Unit 1 Mark-up) (55 total pages) CNL-19-010

TABLE OF CONTENTS BROWNS FERRY NUCLEAR PLANT TECHNCAL SPECIFICATIONS (REQUIREMENTS) SE AND APPLICATION ...........................*............... ........................ 1.1-1 Definitions .......................................... ......................... ...... ......... 1.1-1 1.2 Logical Connectors .............................................................. ...... 1.2-1 1.3 Completion Times ............................................................. : ........ 1.3~1 1.4 Frequency.................................................................................. 1. 4-1 2.0 SAFElY LIMITS (Sls) ...................................................................... 2.0-1 2.1 SLs ........ ~ ....................................................................*............... 2.0-1 2.2 SL Violations ...................................................:......................... 2.0:..1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY......................................................................... 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ................ 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS ........... :.......... ., ................. 3.1-1 3.1.1 SHUTDOWN MARGIN (SD~) ............................................. 3.1-1 3.1.2 Reactivity Anomalies *...*..........*.. ~ ......................................... 3.1-5 3.1.3 Control Rod OPERABILITY.................................................. 3.1-7 3.1.4 Control Rod Scram Times .................................................... 3.1-12 3.1.5 Control Rod Scram Accumulators.:................*...*..*......*....... 3.1-16 3.1.6 Rod Pattern Control ............................................................. 3.1-20 3.1.7 Standby Liquid Control (SLC) System................. ~ ................ 3.1-23. 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves ..... 3.1-28 3.2 POWER DISTRIBUTION LIMITS ...........................................~ .. 3.2-1 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) *....*....*...............................................:.. 3.2-1 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)....*.*..***....*~ .* 3.2-3 3~2.3 LINEAR HEAT GENERATION RATE (LHGR) ..................... 3.2-5 . 3.3 INSTRUMENTATION ................................................................ 3.3-1 3.3.1.1 Reactor Protection System (RPS) Instrumentation .............. 3.3-1 3.3.1.2 Source Range Monitor.(SRM) Instrumentation .................... 3.3-9 3.3.2.1 Control Rod Block Instrumentation ...................................... 3.3-15 3.3.2.2

  • Feedwater and Main Turbine High Water L_ evel
                    . Trip Instrumentation .....................:.........................:....,... 3.3-21 3.3.3.1          Post Accident Monitoring (PAM) Instrumentation.*..****..*.*.... 3.3-23 3.3.3.2          Backup Control System ...............................................*......... 3.3-27 (continued)

BFN-UNIT 1

3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control ..... .. ..... .... 3.3-47a Section Page No. 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation ..................................................... ~ ...*...... 3.3-29 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation ....................... 3.3-32 Emergency Core Cooling System (ECCS) Instrumentation ............................................................... 3.3-35 3.3.5.~ Reactor Core Isolation Cooling (RCIC) System 

                     . lnstrument~tion ....................................... :...................... :. 3.3-48 3.3.6.1         Primary Containment Isolation Instrumentation ................... 3.3-52 3.3.6.2         Secondary Containment Isolation Instrumentation............... 3.3-61 3.3.7.1         Control Room Emergency Ventilation (CREV)

System Instrumentation .................................................. 3.3-65 3.3.8.1 Loss of Power (LOP) Instrumentation .................................. 3.3-70 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring .........................................................-.............. 3.3-75 3.4 REACTOR COOLANT SYSTEM (RCS) .................................... 3.4-1 3.4.1 Recirculation Loops Operating ............................................. 3.4-1 3.4.2 Jet Pumps ............................................................................ 3.4-5 3.4.3 Safety/Relief Valves (S/RVs) ............................................... 3.4-7 

 . 3.4.4           RCS Operational LEAKAGE ................................................ 3.4-9 3.4.5           RCS Leakage Detection Instrumentation ............................. 3.4-12 3.4.6           RCS Specific Activity ............................................................ 3.4-15 3.4.7           Residual Heat Removal (RHR) Shutdown Cooling
  • esidua Heat Removal (RHR) Shutdown Coo ing System - Cold Shutdown ................................................. 3.4-21 3.4.9 RCS Pressure arid Temperature (PIT) Limits ...................... 3.4-24 3.4.10 Reactor Steam Dome Pressure ................................. :.-......... 3.4-30 3.5 *EMERGENCY CORE COOLING SYSTEMS (ECCS) AND
                . REACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM ....... :................................................................. 3.5-1 . . *3.5.1 ECCS - Operating ................................................................ 3.5-1 3.5:2 ~oti---tiA\:ffiEle'f'IA ................................................................ 3.5-8 3.5.3 RCIC System ...................................................................... 3.5-12 Reactor Pressure Vessel (RPV) Water Inventory Control BFN-UNIT 1 ii Amendment No. 234

Section Page No. 3.6 CONTAINMENT SYSTEMS ...................................................... 3.6-1 3.6.1.1 Primary Containment. ........................................................... 3.6-1 3.6.1.2. Primary Containment Air Lock .............................................. 3.6-3 3.6.1.3 Primary Containment Isolation Valves (PCIVs) .................... 3.6-9 3.6.1.4 Drywell Air Temperature ...................................................... 3.6-17 3.6.1.5 Reactor Bµilding-to-Suppression Chamber Vacuum Breakers .......................................... :.............................. 3.6-19 3.6.1.6 Suppression Chamber-to-Drywell Vacuum Breakers ........... 3.6-22 3.6.2.1 Suppression Pool Average Temperature ............................. 3.6-24 3.6.2.2 Suppression Pool Water Level... .......................................... 3.6-29 3.6.2.3 Residual Heat Removal (RHR) Suppression

  • Pool Cooling ................................................................... 3.6-31 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray ............................................ :......................... 3.6-34 3.6.2.5 Residual Heat Removal (RHR) Drywell Spray ..................... 3.6-36 3.6.2.6 Drywell-to-Suppression Chamber Differential Pressure ....... 3.6-38 3.6.3.1 Containment Atmosphere Dilution (CAD) System ......... :...... 3.6-40 3.6.3.2 Primary Containment Oxygen Concentration ....................... 3.6-42 3.6.4.1 Secondary Containment ....................................................... 3.6~4 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) ............... 3.6-47 3.6.4.3 Standb Gas Treatment SGT S stem ................................ 3.6-51 3.7 PLANT SYSTEMS ..................................................................... 3.7-1 3.7.1 Residual Heat Removal Service Water (RHRSW)

System ..................................... ~ ........................... ~ .......... 3. 7-1 \J 3.7.2 Emergency Equipment Cooling Water (EECW) . System and Ultimate Heat Sink (UHS) ........................... 3.7-6 3.7.3 Control Room Emergency Ventilation (CREV) System ........ 3. 7-8 3.7.4 Control Room Air Conditioning (AC) System ....................... 3.7-12 3.7.5 Main Turbine Bypass System .............. ,................................. 3.7-16

  • 3.7.6 Spent Fuel Storage Pool Water Level.. ................................ 3.7-18 3.8 ELECTRICAL POWER SYSTEMS .........................*................... 3.8-1 3.8.1 AC Sources~ Operating ....................................................... 3.8-1 3.8.2 AC Squrces - Shutdown ....................................................... 3.8-14 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air .................. ~ ........ 3.8-19 3.8.4 DC Sources - Operating ....................................................... 3.8-22 3.8.5 DC Sources - Shutdown ....................................................... 3.8-26 3.8.6 Battery Cell Parameters ....................................................... 3.8-29 3.8.7 Distribution Systems - Operating ......................................... *3.8-33 3.8.8 Distribution Systems - Shutdown ......: .................................. 3.8-39
  *BFN-UNIT 1                                                                           Amendment No. ~

3.9.9 Decay Time ...... .. ....................................... ...... ........... .. ........ .. ... .. 3.9-22 Section . Page No. 3.9 REFUELING OPERATIONS .................................................... 3.9-1 3.9.1 Refueling Equipment I rlocks ........................................... 3.9-1 . 3.9.2 Refuel Position One- od-Out Interlock ................................ 3.9-3 3.9.3 Control Rod Posit" n ....................................................: ....... 3.9-5 3.9.4 Control Rod Po ion Indication ............................................ 3.9-7 3.9.5 Control Rod ERABILITY - Refueling ............................... 3.9-10 3.9.6 Reactor P ssure Vessel (RPV) Water Level ...................... 3.9-12 3.9.7 Residu Heat Removal (RHR) - High Water Level ............. 3.9-14 3.9.8 Res* al Heat Removal (RHR)- Low Water Level .............. 3.9-18 3.10 SPECIAL OPERATIONS ......................... :................................. 3.10-1 3.10.1 lnservice Leak and Hydrostatic Testing Operation .............. 3.10-1

  • 3.10.2 Reactor Mode Switch Interlock Testing ................................ 3 ..10-4 3.10.3 Single Control Rod Withdrawal - Hot Shutdown .................. 3.10-7 3.10.4 Single Control Rod Withdrawal - Cold ~hutdown ................ 3.10-10 3.10.5 Single Control Rod Drive {CRD) Removal- Refueling ......... 3.10-14 3.10.6 Multiple Control Rod Withdrawal - Refueling ....................... 3.10-17 3.10.7 Control Rod Testing - Operating .......................................... 3.1.0-20 3.10.8 SHUTDOWN MARGIN (SOM) Test - Refueling ................... 3.10-22
  • 4.0 DESIGN FEATURES ........................................................................ 4.0-1 4.1 Site Location .............................................................................. 4.0-1 4.2 Reactor Core ............................................................................. 4.0-1 4.3 Fuel Storage .............................................................................. 4.0-2 5.0 ADMINISTRATIVE CONTROLS ....................................................... 5.0-1 5.1 Responsibility .. :......................................................................... 5.0-1 5.2. Organization ..................................................................:............ 5.0-2 5.3 Unit Staff Qualifications ............................................................. 5.0-6 5.4 Procedures ..................................*............................................. 5.0-7 5.5 Programs and Manuals .............................................................. 5.0-8 5.6 Reporting Requirements .................................................. :....... :. 5.0-22 5.7 High Radiation Area ......'............................................................ 5.0-26 BFN-UNIT 1 iv
  • Amendment No. ~

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF TABLES Page No . Table 1.1-1 ................................. .... ............ .................. ........ .... .. .............. ....... ... 1.1-9 Table 3.1.4-1 ... ... ............ ............................. ........ ... ............................................ 3.1-15 Table 3.3.1.1-1 ... ................ ... .... ....... ..... .... ... ..... ....... .................... .. .................... 3.3-6 Table 3.3.1.2-1 ............ ..... ..... ... .............. ................ .. .. ........... ........ .............. ...... .3.3-14 Table 3.3.2 .1-1 .... ... ...... .... .. .......... .................... ..... .................... ....................... ..3.3-20 Table 3.3.3 .1-1 .. .. ..... ...... .. .. ........ .................. .... ... ........... ................... .......... ... .... 3.3-26 Table 3.3.5.1-1 .... .... ..... ................................... ...... ............................................. 3.3-42 Table 3.3.5.2-1 ............................................ ...................... .. .. ... ..........................3.3-47c Table 3.3.5.3-1 .... ..... ...... .. ............. ...... .................... ... ....................................... . 3.3-51 Table 3.3.6.1-1 .... ............... .. ..... ............... ...... ........ ... ................ .. ...... ..... .. .. ........ 3.3-58 Table 3.3.6.2-1 .... .. ... .... .... ...... .. ............ ..................... ......... ................................ 3.3-64 Table 3.3.7 .1-1 ..... .... .................. .. ......... ......... ... .. ..... .... .... ...... ...... ........ ....... .. .... .3.3-69 Table 3.3.8.1-1 .... .... ....... .. .... .... .. .. ..... .. ........................ ... .. ...... ... .... ........ ...... ... .... 3.3-74 Table 3.8.6-1 ... ....... ..... ............. ........... .... ....... ... ... .. ...... ... ..... .... .... ................ .. .. ... 3.8-32 BFN-UNIT 1 vi Amendment No.

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS} LIST OF FIGURES Figure Page No . Figure 3.1 .7-1 ..................................................................................................... 3.1-27 Figure 3.4.1-1 .....................................................................................................3.4-4 Figure 3.4.9-1 ..................................................................................................... 3.4-29/29b Figure 3.4.9-2 ..... .... ... ................ .. .......................................................................3.4-29a/29c BFN-UNIT 1 vii Amendment No.

Definitions 1.1 1.1 Definitions (continued) CORE OPERATING LIMITS The COLR is the unit specific document that provides REPORT (COLR) cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications. DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of 1-131, 1-132, 1-133, 1-134, and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in Table Ill of Insert 1 TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites." INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f) . (continued ) BFN-UNIT 1 1.1-3 Amendment No. ~ . J.G.:t

Insert 1 DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a. The water inventory above the TAF is divided by the limiting drain rate;
b. The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the TAF except:
1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths;
2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or
3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who is in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation devices without offsite power.
c. The penetration flow paths required to be evaluated per paragraph b are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory;
d. No additional draining events occur; and
e. Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value.

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. As required by Required 8.1 NOTES Action A.1 and referenced 1. Only applicable in in Table 3.3.5.1-1. MODES 1, 2, and 3. 

                                   -2:-0nly applicable for
  • Functions 1.a, 1.b, 2.a, and 2.b.

Declare supported ECCS 1 hourfrom feature(s} inoperable discovery of loss 

                                 *. when its redundant          of initiation feature ECCS initiation     capability for capability is inoperable. features in both divisions AND B.2                NOTE Only applicable for Functions 3.a and 3.b.

Declare High Pressure. 1 hourfrom Coolant Injection {HPCI) discovery of loss System .inoperable. of HPCI initiation capability ANO 8.3 Place channel in trip. 24 hours (continued) BFN-UNIT 1 3.3-36 Amendment No. -234-

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) u CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Required C.1 NOTES Action A.1 and referenced 1. 9Aly a19191iea~le iA in Table 3.3.5.1-1. M9DES 1, 2, am:I a. 2:-0nly applicable for

  • Functions 1.c, 1.e, 2.c, 2.d, and 2.f.

Declare supported ECCS 1 hour from feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND C.2 Restore channel to 24 hours OPERABLE status. D. As required by Required 0.1 NOTE Action A.1 and referenced Only applicable if HPCI in Table 3.3.5.1-1. pump suction is not aligned to the suppression pool. Declare HPCI System 1 hour inoperable. (continued) BFN-UNIT 1 3.3-37 Amendment No. 2a4

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1 ~~~NOTES~ ~ - Action A.1 and referenced 1. Only applieable in in Table 3.3.5.1-1 . MODES 1, 2, and a. 2-:--0nly applicable for Function 1.d. Declare supported ECCS 1 hourfrom feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. subsystems in both divisions E.2 Restore channel to 7days OPERABLE status. (continued) BFN-UNIT 1 3.3-38 Amendment No. 234

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 6) 

                                          . Emergency Core Cooling System Instrumentation APPLICABLE                           CONDITIONS MODES          REQUIRED         REFERENCED
              . FUNCTION                    OR OTHER          CHANNELS              FROM           SURVEILLANCE             ALLOWABLE SPECIFIED             PER            REQUIRED         REQUIREMENTS                  VALUE CONDITIONS          FUNCTION          ACTIONA.1
1. Core Spray System
a. Reactor Vessel Water 1,2,3, 4{b) B SR 3.3.5.1.1 ~398 inches Levei - Low Low Low, SR 3.3.5.1.2 above vessel Level 1(e) SR 3.3.5.1.5 zero SR 3.3.5.1.6
b. Drywell Pressure - 1,2,3 B SR 3.3.5.1.2 s2.5 pslg High(e) SR 3.3.5.1.5 SR 3.3.5.1.6 C. Reactor Steam Dome 1,2,3 C SR 3.3.5.1.2 ~435 psig Pressure - Low (Injection SR 3.3.5.1.4 and Permissive and ECCS SR 3.3.5.1.6 :S465 pslg lnltiat_ion)(e) 4(a), 5(a) B- SR S.S.5.1'2  :.: 435 pslg SR S.S.5.1.4 and SR S.S.5.1.6 . 5"4o5 psfg
d. Core Spray Pump . SR 3.3.5.1.2 -~ 1647"gpm Discharge Flow - Low SR 3.3.5.1.5 and (Bypass) :S2910gpm
e. Core Spray Pump Start -

Time Delay Relay Pumps A,B,C,D (with SR 3.3.5.1.5 ~ 6 seconds diesel power) SR 3.3.5.1.6 and

S 8seconds Pump A {with normal C SR 3.3.5.1.5 * ~Oseconds power) SR 3.3.5.1.6 and s 1 second Pump B (with normal 1 C SR 3.3.5.1.5 ~6 seconds power) SR 3.3.5.1.6 and
S 8 seconds continued (a)

(b) Whal'I esseeicled s1:1bsystem(s) are rei;tlired le be OPERABLE. 

                                                                         <               iDeleted.

Channels affect Commori Accident Signal Logic. Refer to LCO 3.8.1, "AC Sources - Operating." I (e) During Instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by Its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service In accordance with the Surveillance. If the As Found Instrument channel setpoint Is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.' Prior to returning a channel to service, the Instrument chaMel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference In the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, lhe predefined As Found Tolerance, and the As Left Tolerance-band, and a listing of the setpoint design output documenta6on shall be specified In Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 1 3.3-42 Amendment No.~ ~

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of6) Emergency Core Coofing System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER

  • REQUIRED REQUIREMENTS VALUE CONDITIONS -FUNCTION ACTIONA.1
1. Core Spray System (continued)
e. . Core Spray Pump Start -

Time Delay Relay (continued) Pump C (with normal power) C SR 3.3.5.1 .5 ~ 12 seconds SR 3.3.5.1 .6 and s 16 seconds Pump D (with normal power) C SR 3.3.5.1.5 <!: 18 seconds SR 3.3.5.1.6 and S24 seconds

2. Low Pressure Coolant Injection (LPCI) System
a. Reactor Vessel Water Level 8 SR 3.3.5.1.1 <!:398 inches
            * - Low Low Lem, Level 1(e)                                                             SR   3.3.5.1 .2          above vessel SR   3.3.5.1.5           zero SR   3.3.5.1 .6
    . b. Drywell Pressure - Hlgh(e)                  1,2,3               4                8         SR 3.3.5.1.2             s 2.5 psig SR 3.3.5.1.5 SR 3.3.5.1.6
c. Reactor Steam Dome 1,2,3 4 C SR 3.3.5.1.2 <!: 435 psig and Pressure - Low (Injection SR 3.3.5.1.4 S465 psig Permissive and ECCS SR 3.3.5.1.6 lnitiation)(e) 4 6- SR 3.3.5.1.2 SR 3.3.5.1.4 S465 psig SR 3.3.5.1 .6 continued (a) 'fl.11:!eR esseeie!ed su~system(s) e re re11t1lred le be OPERABLE. ~

4Deleted . j (b) Deleted. (e) Curing Instrument calibrations, If the As Found chaMel setpoint is conservative with respect to the Allowable Value but outside Its acceptable As Found band as defined by Its associated Surveillance Requirement procedure, then there shall be an Initial determination to ensure confidence that the channel can perform as required before returning the channel to service In accordance with the su*rventance. If the As Found Instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Prior to returning a channel to service, the Instrument channel setpoint shall be calibrated to a value that Is within the acceptable As Left tolerance of the setpoint; otherwise, th~ channel shall be declared Inoperable. The nominal Trip Setpoint shall be specified on design output documentation which Is Incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified In Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 1 3.3-43 Amendment No. ~ 251-

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of 6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS 

                                                 ,MODES           REQUIRED           REFERENCED FUNCTION                      OR OTHER          CHANNELS                FROM             SURVEILLANCE           ALLOWABLE SPECIFIED             PER              REQUIRED            REQUIREMENTS                VALUE CONDITIONS           FUNCTION            ACTIONA.1
2. LPCI System (continued)
d. Reactor Steam Dome 4 . C SR 3.3.5.1.2 c!:. 215 psig Pressure
  • Low SR 3.3.5.1.4 and (Recira.llation Discharge SR 3.3.5.1.6 :S245 psig Valve Permissive)Ce)
e. Reactor Vessel Water Level 1,2,3 2 B SR 3.3.5.1.1 c!: 312 5/16
  • Level 0 1 per SR 3.3.5.1.2 inches above subsystem SR 3.3.5.1.5 vessel zero SR 3.3.5.1 .6
  • f. Low Pressure Coolant Injection Pump Start
  • Time
           . Delay Relay PumpA.B,C,D (with diesel
  • 1,2,3, 4 C SR 3.3.5.1.5 c!: 0 seconds power) SR 3.3.5.1.6 and s 1 second Pump A (with normal power) c!: 0 seconds and s 1 second Pump B (with normal power) c!: 6 seconds and
S 8 seconds Pump C (with normal power) C SR 3.3.5.1.5 c!: 12 seconds SR 3.3.5.1.6 and
S 16 seconds Pump O (with normal power) 1,2,3, 1 C SR 3.3.5.1.5 c!:.18 seconds 4(8), s(a) SR 3.3.5.1.6 and s 24 seconds (continued)

(a) '.'l'heA tie esseei11ted stibs~slemt.,) el'e re!ltl& ed to be OPERABLE. ~ . ---,..J Deleted -I (c) With associated recirculation pump discharge valve open. (e) During Instrument calibrations, If the As Found channel setpolnt Is conservative with respect to the Allowable Value but outside ifs acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service In accordance with the Surveillance. If the As Found Instrument channel setpoint ls not conservative with respect to the Allowable Value, the channel shall be declared Inoperable.

  • Prior to returning a channel to service, the Instrument channel setpolnt shall be calibrated to a value that Is within the acceptable As Left tolerance or the setpoint: otherwise, the channel shall be declared Inoperable.
  • The nominal Trip Setpoint shall be specified on design output documentation which Is Incorporated by reference In the Updaled F"inal Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in
  • Chapier 7 or the Updated Final Safety Analysis Report.

BFN-UNIT 1 3.3-44 Amendment No. 234, 250, ~

RPV Water Inventory Control Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE. APPLICABILITY: According to Table 3.3.5.2-1 . ACTIONS

1\JOTE-----------------------------------------------------------

Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel. B. As required by Required 8 .1 Declare associated Immediately Action A. 1 and penetration flow path(s) referenced in incapable of automatic Table 3.3.5.2-1 . isolation. AND B.2 Calculate DRAIN TIME. Immediately C. As required by Required C.1 Place channel in trip. 1 hour Action A. 1 and referenced in Table 3.3.5.2-1 . D. As required by Required 0 .1 Restore channel to 24 hours Action A. 1 and OPERABLE status. referenced in Table 3.3.5.2-1 . BFN-Unit 1 3.3-XX Amendment No.

RPV Water Inventory Control Instrumentation 3.3.5.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E. 1 Declare associated low Immediately associated Completion pressure Emergency Core Time of Condition C or D Cooling System (ECCS) not met. injection/spray subsystem inoperable. SURVEILLANCE REQUIREMENTS

NO TE-----------------------------------------------------------

Refer to Table 3.3.5.2-1 to determine which SRs apply for each ECCS Function. SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. 24 hours SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days BFN-Unit 1 3.3-XX Amendment No. 

            ~                                                   RPV Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1)

RPV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE

1. Core Spray System
a. Reactor 4, 5 1 per C SR 3.3.5.2.1 5' 465 psig Steam Dome subsystem<aJ SR 3.3.5.2.2 Pressure - Low (Injection Permissive)
b. Core Spray Pump 4, 5 1 per D SR 3.3.5.2.2 c 1647 gpm Discharge Flow - subsystem<a! and Low (Bypass) 5' 2910 gpm
2. Low Pressure Coolant Injection (LPCI) System
a. Reactor Steam 4, 5 2 in one C SR 3.3.5.2. 1 5' 465 psig Dome Pressure - trip system<aJ SR 3.3.5.2.2 Low (Injection Permissive)
3. Shutdown Cooling System Isolation
a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2.1 2: 528 inches Water Level - Low, system SR 3.3.5.2.2 above vessel Level3 zero
4. Reactor Water Cleanup (RWCU) System Isolation
a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2.1 2: 528 inches Water Level - Low, system SR 3.3.5.2.2 above vessel Level 3 zero (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel Water Inventory Control. "

(b) When automatic isolation of the associated penetration flo w path(s) is credited in calculating DRAIN TIME. BFN-Unit 1 3.3-XX Amendment No.

RCIC System Instrumentation 3.3.5.z-- 3.3 INSTRUMENTATION V 3.3.5.r eactor Core Isolation Cooling (RCIC) System Instrumentation RCIC System instrumentation for each Function in able . .5.r- shall be OPERABLE. APPLICABILITY: MODE 1, MODES 2 and 3 with reacto

  • ACTIONS
 ~~~~~~~~~~~~~~NOTE~~~~~---+-+~~~~~-

Separate Condition entry is allowed for each channel. CONDITION COMPLETION TIME A. One or more channels A.1 Immediately inoperable.

8. As required by Re ired 8.1 Declare RCIC System 1 hourfrom Action A.1 and erenced inoperable .. discovery of loss in Table 3.3.5;~ 1. of RCIC initiation capability AND 8.2 Place channel in trip. 24 hours.

(continued)

  • 8FN-UNIT 1 3.3-48 Amendment No. 254-

RCIC System Instrumentation

3. . ACTIONS continued CONDITION COMPLETION TIME C. As required by Re C.1 Restore channel to 24 hours Action A.1 and r renced OPERABLE status.

in Table 3.3.5.2--1. D. Required Action and D.1 Declare RCIC System Immediately associated Completion inoperable. Time of Condition B or C not met. BFN-UNIT 1 3.3-49 Amendment No. z3:4-

RCIC System Instrumentation 3.3.5-=2-SURVEILLANCE REQUIREMENTS 

                                    -NOTES-               --------+--
1. Refer to Table 3.3.5.£-1 to determine which SRs apply for each RCIC Fune *on.
2. When a channel is placed an inoperable status solely for performance f required Surveillances, *entry into assoc* ed Conditions and Required Actions m~y be delayed as follows: (a) for up to 6 urs for Function 2 and (b) for up t 6 hours for Function 1 provided the associated F tion maintains RCIC initiatio capability.

SURVEILLANCE FREQUENCY SR 3.3.5.2-., 92 days 24 months SR 3.3.5.~.4 Perf9rm LOGIC SYSTEM FUNCTIONAL 24 months TEST. BFN-UNIT 1 3.3-50 Amendment No. 234, 263

  • RCIC System Instrumentation 3.3.s.i-Table 3.3.5.-2>1 Reactor Core Isolation Cooli CONDITIONS REQUIRED REFERENCED ALLOWABLE FUNCTION CHANNELS PER FROM REQUIRED VALUE FUNCTION .ACTIONA.1
1. Reactor Vessel Water Level
  • 4 B Lov,o Low, level 2(a)
2. Reactor Vessel Water Level
  • 2 C High, Level 8 (a) During instrument calibrations, if the As Found channel setpoint is conservaUve with respect to the Allowable Value but outside its acceptable As Found band as defined by Its associated Surveillance Requirement procedure, then there shall be an Initial determination to ensure confidence that the channel can perform as required before returning the channel to service In accordance with the Surveillance. If the As Found Instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared Inoperable.
  • Prior to returning a channel to service, the Instrument channel setpoint shall be calibrated*to a value that Is within the acceptable As Left tolerance or the setpolnt; otherwise, the channel shall be declared Inoperable * .

The nominal Trip Setpoint shall be specified on design output documentatiun which Is Incorporated by reference In the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing or the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 1 3.3-51 Amendment No. ~ 2§7- .

Primary Containment Isolation Instrumentation 

                                      .                                    3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COM.PLETION TIME H. As required by Required H.1 Declare standby liquid 1 hour Action C.1 and control system (SLC) refere need in inoperable. Table *3.3.6.1-1. OR H.2 Isolate the Reactor Water 1 hour Cleanup System. I. As required by Required 1.1 . Initiate action to restore Immediately Action C.1 and channel to OPERABLE referenced in status. Table 3.3.6.1-1. GR-1.2 IAitiate aetieA te iselate *immediately the Resid1:tal Heat Removal {RHR) Sh~do-.m Geelin~ System. BFN-UNIT 1 3.3-56 Amendment No. -234

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 3) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTION C.1

5. Reactor Water Cleanup (RWCU) System Isolation
a. Main Steam Valve Vault 1,2,3 2 F SR 3.3.6.1 .2 :5 201°F Area Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
b. Pipe Trench Area 1,2,3 2 F SR 3.3.6.1.2 s 135°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
c. Pump Room A Area 1,2,3 2 F SR 3.3.6.1 .2 s 152°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
d. Pump Room B Area 1,2,3 2 F SR 3.3.6.1.2 s 152°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
e. Heat Exchanger Room 1,2,3 2 F SR 3.3 .6.1.2 s 170°F Area (West Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6.1.6
f. Heat Exchanger Room 1,2,3 2 F SR 3.3.6.1.2 s 143°F Area (East Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6.1.6
g. SLC System Initiation 1,2,3 1(a) H SR 3.3.6 .1.6 NA
h. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 ~ 526 inches Level - Low, Level 3 SR 3.3.6.1.2 above vessel SR 3.3.6.1.5 zero SR 3.3.6.1.6
6. Shutdown Cooling System Isolation
a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.2 s 115 psig Pressure - High SR 3.3.6.1.5 SR 3.3.6.1.6
b. Reactor Vessel Water 3;-+, 2tel- SR 3.3 6.1.1 ~ 528 inches Level-Low, Level3 SR 3.3.6.1 .2 above vessel SR 3.3.6.1.5 zero SR 3.3.6.1.6
c. Drywell Pressure - High 1,2,3 2 F SR 3.3.6.1.2 s 2.5 psig SR 3.3.6.1.5 SR 3.3.6.1.6 (a) One SLC System Initiation signal provides logic input to close both RWCU valves.

(b) * ~  : : : ; : :*.' ~ OOES 4 " ' 0 " ' " RHR s,~..,,, S,olisg s,*,m i-riO moiot,iOfflc BFN-UNIT 1 3.3-60 Amendment Nos. ~ . ~ . 

                                                                                                             ~.~. ~

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1) 

                                .Secondary Containment Isolation lnstru_mentation APPLICABLE MODES OR                REQUIRED
        . FUNCTION                  OTHER                  CHANNELS            SURVEILLANCE      ALLOWABLE SPECIFIED                   PER            REQUIREMENTS         VALUE CONDITIONS              TRIP SYSTEM
1. Reactor Vessel Water Level - 1.2.3, 2 SR 3.3.6.2.1 l!: 528inches Low, Level3 -(at- SR 3.3.6.2.2 above vessel zero SR 3.3.6.2.3 SR 3.3.6.2.4
2. Drywell Pressure - High 1,2,3 2 SR 3.3.6.2.2 s 2.5 psig SR 3.3.6.2.3 SR 3.3.6.2.4
3. Reactor Zone Exhaust 1,2,3, SR 3.3.6.2.1 s 100 mR/hr Radiation - High SR 3.3.6.2.2
  • SR SR 3.3.6.2.3 3.3.6.2.4
4. Refueling Aoor Exhaust 1,2,3, 1 SR 3.3.6.2.1 s 100mR/hr Radiation - High . -(et- SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4 BFN-:-UNIT 1 3.3-64 Amendment No. 234,261, 258-

CREV System Instrumentation 

                                         .~
  • 3.3.7.1 Table 3.3.7.1-1 (page 1 of 1)

Control Room Emergency Ventilation System Instrumentation APPLICABLE CONDITIONS MODES OR

  • REQUIRED REFERENCED
               ~ FUNCTION                           OTHER            CHANNELS             FROM     SURVEILLANCE     ALLOWABLE SPECIFIED.          PER TRIP         REQUIRED    REQUIREMENTS         VALUE CONDITIONS           SYSTEM           ACTIONA.1
1. Reactor Vessel Water Level
  • 1,2.~ 2 B SR 3.3.7.1 .1 .!: 528 inches Low,Level3 SR 3.3.7.1.2 above vessel SR 3.3.7.1.5
  • zero SR 3.3.7.1.6
2. Drywall Pressure - High
  • 1,2,3 B SR 3.3.7.1.2 :S2.5 pslg SR 3.3.7.1.5 SR 3.3.7.1 .6
3. Reactor Zone Exhaust 1,2,3 C SR 3.3.7.1.1 :S 100 mRltY Radiation - High -(er SR 3.3.7.i.2 SR 3.3.7.1.5 SR 3.3.7.1 .6
4. Refueling Floor Exhaust 1,2,3, C SR 3.3.7.1.1 :S 100 mR/hr Radiation - High ~ SR 3.3 :7.1.2 SR 3.3.7.1.5 SR 3.3.7.1.6
5. Control Room Air Supply Duct 1,2,3, D SR 3.3.7.1.1 s270cpm Radiation - High ,(et SR 3.3.7.1.2 above SR 3.3.7.1.3 background SR -3.3.7.1.4
 * (a)  Q11FiA9 epei:atieAs witt:l a petenllal fer eralAiA!J tM ,eaoter ¥eseel.

BFN.:.UNIT 1 3.3-69 Amendment No. 234, 251, 2§8--

ECCS - Operating 

                                        , RPVWATER INVENTORY 3.5.1 CONTROL, u 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE
      !SOLATION 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 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 pressures 150 psig. ACTIONS NOTE-LCO 3.0.4.b is not applicable to HPCI. u ------------------------------- 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. One low pressure coolant injection (LPCI) pump in both LPCI subsystems inoperable. 

                                                                            . (continued)

BFN-UNIT 1 3.5-1 Amendment No. 234, 240, 24 

                                  , RPV WATER INVENTORY CONTROL,
                                                                                                                   .t ECCS
  • Shutdo'4vn 3.5.2 IRPV Water Inventory Control  !

3.5 EMERGENCY CORE COOLING SYSTEMS {ECC AND REACTOR CORE ISOLATION COOLING {RCIC) SYSTEM 3.5.2 EGOS

  • Shutdewn Reactor Pressure Vessel (RPV)

Water Inventory Control LCO 3.5.2 :rwe- low pressure ECCS injection/spray subsystems shall be 7 

                *APPLICABILITY:

One OPERABLE. MODE ~ ~ [§] J/ 

                                                                                       *   . ~ - v - v - - , ~.............'"V"V"\

Relocation from SR 3.5.2 .3 MODE 5, except with the spent ftJel ster-ege pool gates Femot1ed and ..vater level ~ 22 fl ever the top ef the reactor pressure vessel fleAge. ACTIONS R CONDITION REQUIRED ACTION COMPLETION TIME A. ~ required ECCS A.1 Restore required ECCS 4 hours Initiate action to injection/spray subsystem injection/spray subsystem establish a inoperable. to OPERABLE status. 

 .                                                                                                                                   method of water B. Required Action and                8.1     IF1itiate aetiOFI to SUSJ:'eFla     lmmedi~tely
  • injection associated Completion OPO~. / capable of Time of Condition A not
                                                                                           '                                         operating met.                                                                                                          without offsite electrical C. T¥.'O requires EGGS                C.1 . Initiate aetion to suspend          Immediately                     power.

ifljeeti oA!spFay OPDR\<s. subsystems iFloperable. 

                                                         ~

C.2 Restore one E66S 4 hours 

             /
                   /                                             iAjeGtioi:vs~ray suesystem to OPERABbE stat1.1s.

(continued) f1n'sert1' l BFN-UNIT1 3.5-8 Amendment No. 234-DRAIN TIME of RPV water inventory to the top of active fuel (TAF) ..__-------------l shall be 2! 36 hours. 

                                     !RPV Water Inventory Control      L-1-->~   ECCS
  • Shutdown 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME 0 . Re~uir:ea AetieA G.2 aRel ~ lflitiate aetiaA ta FestaFe Immediately associated GefflpletieA seeaAdary eantainment ta 

     -~--         -

1111- I *-* I,,-,. OPERABLE status. AN9 M lflittate aetiaA ta FesteFe Immediately tv.1e staAdey gas tFeatmeAt suesystems ta OPERABLE status. AN9 M IAitiate eetiaA ta Fesmre ff:Rmediately* . 

                          /r,..               iselatioA eapaeility iA eaeh FeE1uiFea seeaF1Efaf)'

eaAtaiAmeAt peAetFatieA fiO'tY patl'I Aet isolated. I f~n~e~ 2_ ~

.eFN-UNIT 1 3.5-9 Amendment No. 234-

IRPV Water Inventory Control 1-I --->~ EGOS

  • Shutdewn 3.5.2 SURVEILLANCE REQUIREMENTS FREQUENCY SR 3.5.2. Verify, for eacl=t required ECCS 12 hours
          \        injection/spray subsystem, the suppression pool water level is ~ -6.25 inches with or
                   -7.25 inches without differential pressure control.

SR 3.5.2.2- Verify, for east:. quired ECCS 31 days 

           \

injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve. SR 3.5.2.S-~ ~----~-NOTE~------ 

                   -ene LPCI subsystem may be considered

~ - - - - - - - - { OPE LE during alignment and operation for decay at removal if capable of being manually rea

  • ned and not otherwise inoperable. A Low Pressure Coolant Injection (LPCI) for the Ve eae!=t-required ECCS injection/spray 31 days subsystem manual, power operated, and automatic Ive in the flow path, that is not locked, se led, or otherwise secured in position, is in the correct position.

(continued) each BFN-UNIT 1 3.5-10 Amendment No. ~

jRPV Water Inventory Control 1-!-->+ ~CCS - Shutdowr, 3.5.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3 .6 .2.4 Verify eaeh requir=ed EGGS pump develops In aooorda nse the specified flow rate agaiAst a system head with the correspoAding to the specified pressure. INSERVIGE TESTING PROGRAM SYSTEM I IEA9 GQRRESPONDING TO A VESSEL TO TOffiffi NG,-GF DIFFERENTIAL S¥5'fEM Fl:9WRATE PtlMPS PRESSURE OF es ~gpm 2 2- 105 ~Sid INDICATED 

                                           ~        SYSTEM 5¥SfEM      FLOW RATE        ~        PRESSURE
               ~          z! MOO    ffi       4-SR 3.5.2.5-   -------------------------NOTE-----------------------

1 Vesse I injection/spray may be excluded . Verify required ECCS injection/spray 24 months subsystem actuates or, ar, actual or sin,ulated a1,1tomatic iAitiatior, signal. can be manually operated. BFN-UNIT 1 3.5-11 Amendment No. ~ . 263, ~

TS 3.5.2 Inserts Insert 1 TS 3.5.2 Page 3.5-8 C. DRAIN TIME C.1 Verify secondary containment 4 hours 

      < 36 hours and      boundary is capable of being
      ~ 8 hours.          established in less than the DRAIN TIME.

AND C.2 Verify each secondary containment 4 hours penetration flow path is capable of being isolated in less than the DRAIN TIME. AND C.3 Verify two standby gas treatment 4 hours subsystems are capable of being placed in operation in less than the DRAIN TIME.

Insert 2 TS 3.5 .2 Page 3.5-9 D. DRAIN TIME < 8 hours. 0 .1 ----------- NO TE --------------- Required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power. Initiate action to establish an additional Immediately method of water injection with water sources capable of maintaining RPV water level > TAF for.'! 36 hours. AND 0 .2 Initiate action to establish secondary Immediately containment boundary. AND 0 .3 Initiate action to isolate each Immediately secondary containment penetration flow path or verify it can be automatically or manually isolated from the control room . AND 0 .4 Initiate action to verify two standby gas Immediately treatment subsystems are capable of being placed in operation. E. Required Action and E.1 Initiate action to restore DRAIN TIME Immediately associated Completion to .'! 36 hours. Time of Condition C or D not met. OR DRAIN TIME < 1 hour.

Insert 3 TS 3.5.2 Page 3.5-10 SR 3.5.2.1 Verify DRAIN TIME;:: 36 hours. 12 hours Insert 4 TS 3.5.2 Page 3.5-11 SR 3.5.2.5 Operate the required ECCS injection/spray 92 days subsystem through the test return line for 

                    ;:: 1O minutes.

SR 3.5.2.6 Verify each valve credited for automatically 24 months isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal. 

                                        , RPVWATER INVENTORY             RCIC System CONTROL,                                 3.5.3 u 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3           The RCIC System shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure> 150 psig. ACTIONS 

                        .  *- - - - N O T E LCO 3.0.4.b is not applicable to RCIC.

CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable. A.1 Verify by administrative Immediately means High Pressure Coolant Injection System is OPERABLE. AMQ A.2 Restore RCIC System to 14 days OPERABLE status. B. Required Action and 8.1 Bein MODE 3. 12 hours associated Completion Time not met. AND B.2 Reduce reactor steam 36 hours dome pressure to 

                                         ~ 150 psig.

BFN-UNIT 1 3.5-12 Amendment No. 234-; 249-

PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS \__/ 3.6.1.3 Primary Containment Isolation Valves (PCIVs) LCO 3.6.t.3 Each PCIV, except reactor building-to-suppression chamber vacuum breakers, shall be OPERABLE. APPLICABILITY: MODES 1, 2, and ~ 83 

                       '#hen associated instrumentation is re1:1uired to be OPERABLE peF LGO 3.3.6.1, "Primery Containment Isolation Instrumentation."

Relocated text from Page 3.6-10 

    . BFN-UNIT 1                            3.6-9                                 Amendment No.~

PCIVs 3.6.1 .3 ACTIONS ~~~~~~~~~~~~~~NOTES~~~~~~~~~~~~~

1. Penetration flow paths except for 18 and 20 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls.
2. Separate Condition entry is allowed for each penetration flow pat~.
3. Enter applicable Conditions and Required Actions for syst~ms made inoperable by PCIVs.

4 . Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment," when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria in MODES 1, 2, end 3. CONDITION REQUIRED ACTION COMPLETION TIME ' A. NOTE--- A.1 Isolate the affected 4 hours except for Only applicable to . penetration flow path by main steam line penetration flow paths use of at least one closed with two PCIVs. and de-activated automatic v_alve, closed manual valve, blind 8 hours for main 

      .One or more penetration            flange, or check valve      steam.line flow paths with one PCIV           with flow through the inoperable except due to           valve secured.
  • MS IV leakage not within limits.

(continued)

  • BFN-UNIT 1 3.6-10 Amendment No.~

PCIVs 3.6.1 .3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. One or more penetration D.1 Restore leakage rate to 4 hours flow paths with MSIV within limit. leakage not within limits. E. Required Action and E.1 Bein MODE 3. 12 hours associated Completion Time of Condition A, B, C, AND or D not met in MODE 1, 2, ora. E.2 Bein MODE 4. 36 hours F. Ree;uireet Aetien anet ~ Initiate aetien le suspenet Immediately . 

   *asseeiateet GempleHeA             epemUens witt:i a
    +ime ef Genelitien A, 8, 6 ,      potenUal feF emining lt:le eF D net met feF PGIV{s)          reaetor vessel (OPDRVs).

ree;uireel to be OPERABLE during GR M0DE4 ors.

  • F.2 NO+E Only applieaele fer inapeFaele RHR St:iuleloi.\lfl Ceeling Vah*es.

Initiate aetion le restore ~ 

                                      'i<al*.*e(s) lo OPERABLE slatt:fS; BFN-UNIT 1                             3.6-13                      Amendment No. -234-

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 T~e secondary containment shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3, DuriRg eperstieRs \ .:ith a peteRtlel fer drainiRg the reactor 'o'e!!el 1 (OPDRVs). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours inoperable iR MODE 1, 2, containment to era. OPERABLE status.

8. Required Action and B.1 Bein MODE3. 12 hours

~J associated Completion Time of Condition A not AND met. 8.2 Be in MODE4. 36 hours 

                                                      "                                                     (eentin1:1ed)
                                      ~ D~uble u'nde;line'
                                          .I. .I. .I. .I. .I. .I. .I. .I. .I. .I. .I. .I. .I.

1 BFN-UNIT 1 3.6-44 Amendment No. '* 2-& Secondary Containment Delete information on this page 3.6.4.1 and insert "This page intentionally left blank." \.._) ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Seco,,dary containment C.1 Initiate aetien te s1:1spend Immediately 

         *mopersei.e c1 urm9
  • OPOR\ls.

9P8R\!5. BFN-UNIT 1 3.6-45 Amendment No. ~ . -254---

SCIVs 3.6.4.2 \,,.__} 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) LCO 3.6.4.2 Each SCIV shall be OPERABLE. APPLICABILITY: MODES 11 21 and 3;- 01:JFiAg operations with a potential for draining the reactor vessel (OPDRVs). ACTIONS 

       --------------NOTES-                                                   -------
1. Penetration flow paths may be untsolated intermittently under administrative controls.
2. Separate Condition entry Is allowed for each penetration flow path.
3. Enter appllcable Conditions and Required Actions for systems made inoperable by SCIVs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more penetration A.1 Isolate the affected 8 hours flow paths with one SCIV penetration flow path by inoperable.

  • use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange.

(continued} \. 

 --- /

BFN-UNIT 1 3.6-47 Amendment No. 2M, ~

SCIVs 3.6.4.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 . NOTE Isolation devices in high radiation areas may be verified by u~e of . administrative means. Verify the affected Once per 31 days penetration flow path is isolated. B. NOTE 8.1 Isolate the affected 4 hours Only applicable to penetration flow path by penetration flow paths use of at least one closed with two isolation valves. and de-activated automatic valve, closed manual valve, or blind One or more penetration flange. u flow paths with two SC IVs inoperable. C.

  • Required Action and c:1 Be in MODE 3. 12 hours -

associated Completion Time of Condition A or B AND not met iR MODE 1, 2, er

a. C.2 Bein MODE 4. 36 hours (sontinued)
                                              !Double undeline     I
 . BFN-UNIT 1                             3.6-48                     Amendment No.~

SCIVs Delete information on this page 3.6.4.2 and insert "This page intentionally left blank." ACTIONS (continued) ' ' ' ' ' ' ' ' ' ' J. i. J. 1. .1.._ CONDITION REQUIRED ACTION COMPLETION TIME D. ReqtJifed AelleA eAel D.1 Initiate eetioA to suspend Imme diatoly assaeiateel Gem13leUeA OPDFWs. 

     ;=ir.,e of 60,1dltion A or B RGt met El~FiA§ 9P9RVs.

u BFN-UNIT 1 3.6-49 Amendment No. M, ~

SGT System 3.6.4.3 "-) 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Three SGT subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3;- DuriAg eper=atieF1s with a potential fer elrelning the Feaster vessel (OJ;?CRVs). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem 7 days inoperable. to OPERABLE status. B. Required Action and B.1 Bein MODE3. 12 hours associated Completion Time of Condition A not AND I I met in MQQE ~, :2, oF 3. B.2 Bein MODE4. 36 hours J\ (eeF1tiAt:1eel) 1- Relocate remaining row

  • 1- from Page 3.6-52

\_.,1 BFN-UNIT 1 3.6-51 Amendment No.~. ~

Relocate remaining row to SGT System Page 3.6-51 insert "This page 3.6.4.3 intentionally left blank." \. } 

~      ACTIONS continued CONDITION                      REQUIRED ACTION                 COMPLETION TIME C. Requi,ed Action and          6 .1    Place two OPERABLE           Immediately asseeialeel Completien               SGT subsystems ifl Time ef CcAdition A not              operation.

met dt:lring OPDRVs. C.2 lnitlete action le st1spend Immediately OPDRV-s.

e. Two or three SGT .1 Enter LCO 3.0.3. Immediately ubsystems Inoperable iA (continued) u
~   I
      .BFN-UNIT 1                              3.6-52                  Amendment No. ~ . ~

                                     '                '       '       '             '    '   '     .                                      SGT System Delete information on this page .                                                                              3.6.4.3
                               ~ and insert "This page intentionally left blank."                                                                  .

A CTIONS (continued) .I. .I.. .l,._ .I,._ .. .I.. .. .I.. .I.. J,. .I.. ...... .I. .I. .I.. lt. .I. .l.. .I. CONDITION REQUIRED ACTION COMPLETION TIME E. TWO or II nee SST E.1 Initiate action to suspend Immediately stibsystems inopereble OPDRVs. duriR~ 9P9RVs. \ 

\_./' BFN-UNIT 1                                                            3.6-53                                             Amendment No. ~ , ~

CREVSystem 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency Ventilation {CREV) System LCO 3.7.3 Two CREV subsystems shall be OPERABLE. 

      ~~~~~~~~~_.,.OTE~~~~~~~~~

The main control room envelope (CRE) boundary may be opened Intermittently under administrative control. APPLICABILITY: MODES 1, 2, and 3~FiAg 8t}eFatiens with a petefltial fer er-sifting the reseter vessel tOPORVs). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREV subsystem A.1 Restore CREV subsystem 7days inoperable for reasons to OPERABLE status. other than Condition B, C, orD. B. One or.more CREV B.1 Initiate action to Immediately subsystems inoperable implement mitigating due to inoperable CRE actions boundary iA MQDE ~, 2, eF-3. ANO B.2 Verify mitigating actions 24 hours ensure CRE oa:upant exposures to radiological hazards will not exceed limits, and verify the CRE occupants are protected from smoke and chemical hazards. AND B.3 Restore CRE boundary to 90days OPERABLE status. (continued) BFN-UNIT 1 3.7-8 Amendment No.~.~. a7i, 

                                                                           ~

CREV System 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Two CREV subsystems C.1 Restom HEPA filter and ?days inoperable due to one charcoal adsorber to inoperable High Efficiency OPERABLE status. Particulate Air (HEPA) filter or charcoal adsorbers which do not impact ability of CREV subsystems to meet flowrate requirements specified in the Ventilation Filter Testing Program (VFTP).

0. One CREV subsystem 0.1 Restore charcoal 14 days inoperable due to adsorber to OPERABLE inoperable charcoal status.

adsorber which does not impact the ability of CREV subsystem to meet flowrate requirements specified in the VFTP. E. Required Action and E.1 Bein MODE3. 12 hours associated Completion Time of Condition A, B, C, M:!12 or D not met in MODI!; 1, 

    ~-                          E.2   Bein MODE 4.             36 hours Relocate remaining row from next page BFN-UNIT 1                              3.7~
                                            /        Amendment No. 246, ~ . ~ .
                                                                   ~

Relocate remaining row to previous page and delete this page CREV System 3.7.3 ACTIONS continued CON_D ITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Place OPERABLE GREV lmmeaietely asseeiatea Gempleticr, StJi:)sysfftffi iA Time of CMditien A or D pressuFizetieR meae. f'let met atJAAg OPDRVs. F.2 Initiate aetieA to S1:1Sf)ene Immediate!~ OPDRVs. 

-S. Two CREV subsystems            & .1  Enter LCO 3.0.3.              Immediately
    ; operable in MOOfi 1, 2,
    ~~        reasons other dition B or C.

(eeAtiAl::l8d}- BFN-UNIT 1 3.7-9 Amendment No.~ . ~.~. 

                                                                           -282"

Delete information on this page and insert "This page CREV System 3.7.3 intentionally left blank ." ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME H. RequiFed Action aAd M-A Initiate aGtioA to suspeAd Immediately associated Cor-'Apletion OPDR\Js. Time of Condition C not met during OPDR>Js. T*::o GREV subsystems inepereble dl:lring OPDR\'s for reaSORs other than COAEihk>A C. One or FAOFe GREV S1:1bsystems inoperable due te an inoperable CRE Boundary during OPDRVs. BFN-UNIT 1 3.7-10 Amendment No. m .~ . ~ . 

                                                                     -z62-

Control Room AC System 3.7.4 3.7 PLANT SYSTEMS \.........J 3.7.4 Control Room Air Conditioning (AC) System LCO 3.7.4 Two Unit 1 and 2 control room AC subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2,*and 3, _ During movement of irradiated fuel assemblies in the secondary

  • containment, During CORE ALTERATIONS.

During operations with a potential for dr-eirtirtg ttle reseter ¥essel (OPDR\'s). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Unit 1 and 2 control A1 Restore Unit 1 and 2 30 days room AC subsystem control room AC inoperable. subsystem to OPERABLE status. (continued) BFN-UNIT 1 3.7-12 Amendment No. ~

Control Room AC System 3.7.4 ACTIONS continued '\ ._.) CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and 0.1 ~~~NOTE~~~ associated Completion LCO 3.0.3 is not Time of Condition A or B applicable. not met during movement of irradiated fuel assemblies in the Place OPERABLE control Immediately secondary containment, room AC subsystem in during CORE operation. ALTERATIONS, or d~ring OPDRVs. QB 0.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment. AND 0.2.2 Suspend CORE Immediately 

                                     . ALTERATIONS.
                                        ~

02.a lr,itiate action to suspend Immediately OPDR',,'s. BFN-UNIT 1 3.7-14 Amendment No. 234

AC Sources - Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A-2-:a lr,itiete eetien te suspend Immediately epeFaUeAs with a J:)OteAtial foF eraiRiRg the FeastoF \'essel (OPDRVs) . 

                                 . AN9 .

Initiate action to restore Immediately required offsite power circuit to OPERABLE status. B. One or more required Suspend CORE Immediately Unit 1 and 2 DGs ALTERATIONS. inoperable. AND 8.1.2 Suspend movement of Immediately irradiated fuel assemblies in secondary containment. AN9 IRitjate actioA to suspend Immediately OPDRVs. 8.1:i!I- Initiate action to restore Immediately required Unit 1 and 2 DGs to OPERABLE status. (continued} BFN-UNIT 1 3.8-16 Amendment No. ~ \_,;*

AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS V SURVEILLANCE FREQUENCY SR 3.8.2.1 ~~~~~~-NOTE--~~~~~ The following SRs are not required to be performed: SR 3.8.1.2, SR 3.8.1.5, SR 3.8.1.7, ~ R 3.8.1.B, and SR 3.8.1.9. For Unit 1 an and C sources required to be In accordance OPERABLE, the SRs _of Specification 3.8.1 with applicable are applicable. SRs SR 3.8.2.2 For the required Unit DG, the SRs of Unit 3 In accordance Technical Specifications re applicable. with applicable SRs 

                                         !,except SR 3.8.1.6 and SR 3.8.1.9 I BFN-UNIT 1                        3.8-18                    Amendment No. 28:4

DC Sources - Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to suspend Immediately operations vrith a potential for draining the reactor *.<<essel. ANO Initiate action to restore lmmediat.ely required DC electrical power subsystems or systems to OPERABLE status. BFN-UNIT 1 3.8-27 Amendment No. ~

Distribution Systems - Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued} A.2;3 Initiate aetier, te suspend Immediately operatier,s 'h'ith a peter,tial fer draining the reactor \'essel. AND A.2.4-- Initiate actions to restore Immediately i required AC and DC electrical power distribution subsystems to OPERABLE status. AND . A.2. Declare associated Immediately 1 required shutdown cooling subsystem(s} inoperable and not in operation. BFN-UNIT 1 3.8-40 Amendment No. ~ \.._J**

Attachment 3 to CNL-19-01 O Proposed Technical Specification Changes (Unit 2 Mark-up) (55 total pages) CNL-19-010

Section AND APPLICATION.................... .......................................... 1.1-1 BROWNS FERRY NUCLEAR PLANT ............. 1.1-1 TECHNCAL SPECIFICATIONS (REQUIREMENTS) ............. 1.2-1 Completion Times ......................................................-................ 1.3-1 Frequency.................................................................................. 1.4-1 2.0 SAFETY LIMITS (SLs) .................................................................... :. 2.0-1 2.1 SLs ............................................................................................ 2.0-1 2.2 SL Violations .......................................*..................................... 2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY......................................................................... 3.0-1

  • 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ................ 3.0-4 3.1 REACTIVITY.CONTROL SYSTEMS ............ ~ ............................ 3.1-1 3.1.1 SHUTDOWN MARGIN (SOM) ............................................. 3.1-1 3.1.2 Reactivity Anomalies ............................................................ 3.1-5 3.1.3 Control Rod OPERABILITY.................................................. 3.1-7 3.1.4 Control Rod Scram Times .................................................... 3.1-12 3.1.5 Control Rod Scram Accumulators ........................................ 3.1-16 3.1.s* Rod Pattern Control ............................................................. 3.1-20 3.1.7 Standby Liquid Control (SLC) System .................................. 3.1-23.

3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves ..... 3.1-28 3.2 POWER DISTRIBUTION LIMITS .............................................. 3.2-1 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION . RATE (APLHGR) ..................................................*...... :... 3.2-1 3.2:2 MINIMUM CRITiCAL POWER RATIO (MCPR).................... *3.2-3 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) ..................... 3.2-5 3.3

  • INSTRUMENTATION ................................................................ 3.3-1 3.3.1.1 Reactor Protection System (RPS) Instrumentation .............. 3.3-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation .................... 3.3-10 3.3.2.1 Control Rod Block Instrumentation ...................................... 3.3-16 3.3.2.2 Feedwater and Main *Turbine High Water Level Trip Instrumentation .............................................:.......... 3.3-22 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation ................. 3.3-24 3.3.3.2 Backup Control System ........................ ;............................... 3.3-28 BFN-UNIT2 Amendment No. ~

3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control ...... ..... ... .. 3.3-48a Section Page No. 3.3.4.1 a of Cycle Recirculation Pump Trip (EOC-RPT) lnstrur:nentation .....................................................,......... 3.3-30 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation ....................... 3.3-33 3.3.5.1 Emergency Core Cooling System (ECCS) . Instrumentation ............................................................... 3.3-36 3.3.5.~ Reactor Core Isolation Cooling (RCIC) System Instrumentation ............................................................... 3.3-49 3.3.6.! ~ Primary Containment Isolation Instrumentation ................... 3.3-53 3.3.6.2 Secondary Containment Isolation Instrumentation............... 3.3-62 3.3.7.1 Control Room Emergency Ventilation (CREV) System Instrumentation .................................................. 3.3-66 3.3.8.1 Loss of Power (LOP) Instrumentation .................................. 3.3-71 3.3.8.2 Reactor Protec.lion System (RPS) Electric Power Monitoring .........................................*.............................. 3.3-76 3.4 REACTOR COOLANT SYSTEM (RCS) .................*.................. 3.4-1 3.4.1 Recirculation Loops Operating ............................................. 3.4-1 3.4.2 Jet Pumps ..... ,...................................................................... 3.4-5 3.4.3 Safety/Relief Valves (S/RVs) ............................................... 3.4-7 3.4.4 RCS Operational LEAKAGE ................................................ 3.4-9 3.4.5* RCS Leakage Detection Instrumentation ............................. 3.4-12 3.4.6 RCS Specific Activity....................... ~************************************ 3.4-15 3.4.7 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown .................................................. 3.4-18 es1 ua ea emova ut own oo mg System - Cold Shutdown......................*.....*....*.......*...*.:. 3.4-21 3.4.9 RCS Pressure and Temperature (PIT) Limits ************:*******'* 3.4-24 3.4.10 Reactor Steam Dome Pressure ............................................ 3.4-30 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND 

              ~EACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM ....................................................*.................... 3.5-1

  • 3:5.1 ECCS - Operating*................................................................ 3.5-1 3.5.2 EGGS - Shl:Jlet8\*m ................................................................ 3.5-8 3.5.3 RCIC Syst ........................................................................ 3.5-12 Reactor Pressure Vessel (RPV) Water Inventory Control ii Amendment No. 25a

Section Pace No. 3.6 CONTAINMENT -SYSTEMS .......................................... .......... .. 3.6-1 3.6.1.1 Primary Containment.. .......................................................... 3.6-1 3.6.1.2

  • Primary Containment Air Lock.............................................. 3.6-3 3.6.1.3" Primary Containment Isolation Valves (PCIVs) .................... 3.6-9 3.6.1.4 Drywell Air Temperature ...................................................... 3.6-17 3.6.1.5 Reactor Building-to-Suppression Chamber Vacuum Breakers ......................................................................... 3.6-19 3.6.1.6 Suppression Chamber-to-Drywell Vacuum Breakers ........... 3.6-22 3.6.2.1 Suppression Pool Average Temperature ............................. 3.6-24 3.6.2.2 Suppression Pool Water Level.. ........................................... 3.6-29 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling ................................................................... 3.6-31 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray ...................................................................... 3.6-34 3.6.2.5 Residual Heat Removal (RHR) Drywell Spray ..................... 3.6-36 3.6.2.6 Drywell-to-Suppression Chamber Differential Pressure ....... 3.6-38 3.6.3.1 Containment Atmosphere Dilution (CAD) System ................ 3.6-40 3.6.3.2 Primary Containment Oxygen Concentration ....................... 3.6-42 3.6.4.1 Secondary Containment.. ......................... ,........................... 3.6-44 3.6.4.2 Secondary Containment Isolation Valves lsCIVs) ............... 3.6-47 3.6.4.3 Standby Gas Treatment (SGT) System ................................ 3.6-51 3.7 PLANT SYSTEMS ..................................................................... 3.7-1 3.7.1 Residual Heat Removal Service Water (RHRSW)
  • Systeni and lfl.tmate Heat Sink (UHS) ******* -. **** 3.7-1 3.7.2 Emergency Equipment Cooling Water (EECW)

System and Ultimate Heat Sink (UHS) ........................... 3.7-7 3.7.3 Control Room Emergency Ventilation (CREV) System ........ 3.7-9 3.7.4 Control Room Air Conditioning (AC) System ....................... 3.7-13 3.7.5 Main Turbine Bypass System ............................................... 3. 7-17

  • 3.7.6 Spent Fuel Storage Pool Water Level.. ................................ 3.7-19 3.8 ELECTRICAL POWER SYSTEMS ............................................ 3.8-1 3.8.1 AC Sources - Operating ....................................................... 3.8-1 3.8.2 AC Sources - Shutdown .....................................................~. 3.8-14 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ........................... 3.8-19 3.8.4 DC Sources - Operating ....................................................... 3.8-22 3.8.5 DC Sources - Shutdown ....................................................... 3.8-26 3.8.6 Battery Cell Parameters ........................................................3.8-29 3.8.7 Distribution Systems - Operating ......................................... 3.8-33 3.8.8 Distribution Systems - Shutdown ......................................... 3.8-39 BFN-UNIT2 Scroll to next page iii Amendment No.~

u MAR t 

                                                                                                            ~
                                                                                                             ,t-£899

3.9.9 Decay Time .. .. .......... ....... .... ..... .. ..... .................. ...... ...... .. ....... ..... 3.9-22 Section Page No. 3.9 REFUELING O ERATIONS ...................................................... 3.9-1 3.9.1 Refueling uipment Interlocks ........................................... 3.9-1 3.9.2 Refuel Po 1tion One-Rod-Out Interlock ................................ 3.9-3 -.) 3.9.3 Control od Position ............................................................ 3.9-5 3.9.4 Control ad Position Indication .............................*............... 3.9-7 3.9.5 Contra Rod OPERABILITY - Refueling ................................ 3.9-1 O 3.9.6 Rea r Pressure Vessel (RPV} Water Level ...................... 3.9-12 3.9.7 Res* ual Heat Removal (RHR} - High Water Level ............. 3.9-14 3.9.8 R dual Heat Removal (RHR} - Low Water Level .............. 3.9-18 3.10

  • SPECIAL OPERATIONS ..............................-..................... ~ .. ;.... 3.10-1
  • 3.10.1
  • lnservice Leak and Hydrostatic Testing Operation .............. 3.10-1 3.10.2 Reactor Mode Switch Interlock Testing ................................ 3.10-4
        -3.10.3            Single Control Rod Withdrawal - Hot Shutdown ... '. .............. 3.10-7 3.10.4            Single Control Rod Withdrawal - Cold Shutdown ....... : ........ 3.10-10 3.10.5            Single Control Rod Drive (CRD} Removal - Refueling ......... 3.10-14 3.10.6            Multiple Control Rod Withdrawal - Refueling ....................... 3.10-17 3.10.7            Control Rod Testing - Operating .......................................... 3.10-20 3.10.8            SHUTDOWN MARGIN (SOM} Test - Refueling ................... 3.10-22 4.0      DESIGN FEATURES ......................................................................:. 4.0-1 4.1           Site Location .............................................................................. 4.0-1 4.2           Reactor Core ............................................................................. 4.0-1 4.3           Fuel Storage .............................................................................. 4.0-2 5.0      ADMINISTRATIVE CONTROLS ....................................................... 5.0-1 5.1"          Responsibility .........................................................................._.. 5.0-,1 5.2         . Organization ...........................................................................:.. 5.0-2 5.3 .        Unit Staff Qualifications ............................................................. 5.0-6 5.4          procedures ................................................_................................ 5.0-7 5.5          Programs and Manuals .............................................................: 5.0-8 5.6 .        Reporting Requirements ............................................................ 5.0-22 5.7
  • High Radiation Area ............................................... ~ .................. 5.0-26
  • BFN-UNIT2 iv Amendment No. 263

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF TABLES Page No. Table 1.1-1 .. .... ...... ... ................. ........... .... ..... ... .............................. ..... ... ........ .... 1.1-8 Table 3.1.4-1 ... ..... ........ .... ............... ... .. ... ... ........ ..... ..... ............................... ....... 3.1-15 Table 3.3.1.1-1 .... ........... ... .. ....... .................. ............ .. ........................................ 3.3-7 Table 3.3.1.2-1 .............................. ... .. ................... ............. ........ ............... ... ..... 3 .3-15 Table 3.3.2.1-1 .... .... ......... ... ............ ....... .... ...................... ... ..... ........ ...... .... .. .. ... 3.3-21 Table 3.3.3.1-1 ... .... ... .. ...................... ..... ......... ................ .................. ... ...... .. ..... 3.3-27 Table 3.3.5.1 -1 ... ............ ............. ... .......... ....... .. .. .............................................. 3.3-43 Table 3.3.5.2-1 .. ... ............ .. ... .... ........ ... ........... ....... .. .... ....................... ..... ... ....... 3.3-48c Table 3.3.5.3-1 .................. .... ..... .. ...... ....... ...... ........ .. ...................... .......... ........ 3.3-52 Table 3.3.6.1-1 .... ...... ..... ...... ........ ...... .................. .... ........ .... ............ ... ... .......... . 3.3-59 Table 3.3.6.2-1 ..... ................... .... .. ....... .... ........ .. .. ........ ....................... ..... ..... .... 3.3-65 Table 3.3.7.1 -1 ......... .. ..... .................. ............. ............... ............ ..... ... .. .... .......... 3.3-70 Table 3.3.8.1-1 ............ .. .......... ........ ...... ..... .......... ...... .. .. ... ...... .... ............ ... .... .. . 3.3-75 Table 3.8.6-1 ....... ...... ........ ........................... .......... ..... .... ...... .. .............. .. ... .... .. .. 3 .8-32 BFN-UNIT 2 vi Amendment No.

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF FIGURES Figure Page No .. Figure 3.1.7-1 .................................................................................................... 3.1-27 Figure 3.4.1-1 .................................................................................................... 3.4-4 Figure 3.4.9-1 .................................................................................................... 3.4-29/29b 

   .                ................................................................................................. .                                 I Figure 3.4.9-2 ... .... .................... ..... .. ... ....... .. ... ........... ... ....... .. .. .. .. ........ ........ ... ... .. .3.4-29a/29c V BFN-UNIT 2                                                             ?
                                                                   -4J..:                                    Amendment No.                    ~~

h!lotR t 4 2809

Definitions 1.1 1.1 Definitions (continued) CORE OPERATING LIMITS The COLR is the unit specific document that provides REPORT (COLR) cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications. DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of 1-131 , 1-132, 1-133, 1-134, and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in Table Ill of Insert 1 TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites." INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f). (continued) BFN-UNIT 2 1.1-3 Amendment No. ~ . J.2.5

Insert 1 DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a. The water inventory above the TAF is divided by the limiting drain rate;
b. The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the TAF except:
1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths;
2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or
3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who is in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation devices without offsite power.
c. The penetration flow paths required to be evaluated per paragraph b are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory;
d. No additional draining events occur; and
e. Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value.

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) 

       . CONDITION               REQUIRED ACTION                 COMPLETION TIME B. As required by Required   8.1             NOTES Action A.1 and referenced      1. Gnly aJ3J3lieaele in in Table 3.3.5.1-1 .               MODES 1, 2, and 3 .

2= Only applicable for Functions 1.a, 1.b, 2.a, and 2.b. Declare supported ECCS 1 hourfrom feature(s) inoperable discoyery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND 8.2 NOTE Only applicable for Functions 3.a and 3.b. Decl~re High Pressure 1 hourfrom Coolant Injection (HPCI) discovery of loss 

              ..                  System *inoperable.         of HPCI initiation
                                                              ~pability AND 8.3  Place channel in trip.      24 hours (continued) 8FN-UNIT2                         3.3-37                    Amendment No. ~

ECCS Instrumentation 3.3.5.1 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Required C.1 NOTES Action A.1 and referenced 1. 0Aly ai:,r,lieable ifl in Table 3.3.5.1-1. MODES 1, 2, aAd 3. 2: Only applicable for

  • Functions 1.c, 1.e, 2.c, 2.d, and 2.f.

Declare supported ECCS 1 hourfrom feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND C;2 Restore channel to 24 hours OPERABLE status. V D. As required by Required D.1 NOTE Action A.1 and referenced Ohly applicable if HPCI in Table 3.3.5.1-1. pump suction is not aligned .to the suppression pool. Declare HPCI System 1 hour inoperable. (continued)

  • BFN-UNIT2 3.3-38 Amendment No. 25a

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1 ~----NOTES- - - - - Action A.1 and referenced 1. Only applicable in in Table 3.3.5.1-1 . MODES 1, 2, Bnd 3.

r. Only applicable for Function 1.d.

Declare supported ECCS 1 hourfrom feature(s) inoperable discovery of loss when -its redundant of initiation feature ECCS initiation capability for capability is inoperable. subsystems in both divisions E.2 Restore channel to 7 days OPERABLE status. (continued) 

*BFN-UNIT2                         3.3-39                    Amendment No.253

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 or 6) Emergency Core Goofing System lnstrumentalion APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED . REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA1

1. Core Spray System
a. Reactor Vessel Water 1,2,3, 4(b) B SR 3.3.5.1.1 ~398 lnches Level - Low Low Low, SR 3.3.5.1 .2 above vessel Level 1(e) SR 3.3.5.1.5 zero SR 3.3.5.1.6
b. Drywell Pressure - 1,2,3 . B SR 3.3.5.1.2 S2.5psig High(e)
  • SR 3.3;5.1.5 SR 3.3.5.1.6
c. Reactor Steam Dome 1,2,3 C SR 3.3.5.1.2 ~435 psig Pressure - Low (Injection SR 3.3.5.1.4 and Permissive a*nd ECCS SR 3.3.5.1.6 S465 psig Initiation)( e) 4(a), 5{a) e- SR S.S.5.U ~435 pslg SR S.S.5.1.4 and SR a.a.s.1.s s 465 psig
d. Core Spray Pump 2 SR 3.3.5.1.2 ~ 1647 gpm Discharge Flow - Low SR 3.3.5.1.5 and (Bypass) s 2910 gpm
e. Core Spray Pump Start -

Time Delay Relay Pumps A,B,C,O (with SR 3.3.5.1.5 ~ 6 seconds diesel power) SR 3.3.5.1.6 and s 8 seconds Pump A (with normal C SR 3.3.5.1.5 ~ 0 seconds power) SR 3.3.5.1 .6 and s 1 second Pump B (with normal 1,2,3, 1 C SR 3.3.5.1.5 ~ 6 seconds power) 4(il), 5(il) SR 3.3.5.1.6 and s 8 seconds continued (a) V'IReR eeseeiateEI e1:11i1S)'6l8R'1(6) 81'8 F8E!l:liFeEI 18 lie GPERABbE. 

                                                                                   <                      Joeleted. I (b)  Channels affect Common Accident Signal Logic. Refer to LCO 3.8. 1, "AC Sources - Operating.*

(e) During Instrument calibrations, If the As Found channel setpoint is conservative with respect to the Allowable Value but outside Its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service In accordance with the Surveillance. If the As Found Instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared Inoperable.

  • Prior to returning a channel to service, the instrument channel setpolnt shaD be ca6brated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared Inoperable*.

The nominal Trip Setpolnt shall be specified on design output documentation which Is Incorporated by reference In the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint. the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 or the Updated Final Safety Analysis Report. BFN-UNIT 2 3.3-43 Amendment No.~ ~ 

       \                                                                                                   ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of 6)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION

  • ACTIONA.1
1. Core Spray System (continued)
e. Core *spray Pump Start -

Time Delay Relay (continued) Pump C (with normal power) SR 3.3.5.1 .5 2: 12 seconds SR 3.3.5:1.6 and s 16 seconds Pump D (with normal power) SR 3.3.5.1.5 2: 18 seconds SR 3.3.5.1.6 and S24 seconds

2. Low Pressure Coolant Injection (LPCI) System
a. Reactor Vessel Water Level SR 3.3.5.1.1 ,!;398 inches
          - Low Low Low, Level 1(e)                                                                 SR SR 3.3.5.1.2 3.3.5.1.5 above vessel zero r

SR 3.3.5.1 .6

b. Drywell Pressure - High(e) 1,2,3 4 B SR 3.3.5.1.2 s 2.5 psig SR 3.3.5.1 .5 SR 3.3.5.1.6
c. Reactor Steam Dome 1.2.3 4 C SR 3.3.5.1.2  ;>:435 psig PressU"e - Low (Injection SR 3.3.5.1.4 and Permissive and ECCS SR 3.3.5.1 .6 S465 psig lnitiation){e) 4(a), 5(a) 4 s SR 3.3.6.~.2 ~435 psig SR 9.3.5.1.4 and SR. 3.3.5:t:5 S<m5 psfg continued (a) lWleR asseeiateEI s1:1hsysteA'l(e) Bfe reiit1ired to be. OPERABLE. ~

1Deleted.  ! {b) Deleted. (e) During instrument cafibra tions, If the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by Its associated Surveillance Requirement procedure , then there shall be an Initial determination to ensure confidence that the cha.noel can perform as required before returning the channel to service in accordance with the Surveillance . If the As Found Instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shan be declared Inoperable. Prior to returning a channel to service, the Instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpolnt; othe:Wise, the channel sh~II be declared Inoperable. The nominal Trip Setpoinl shall be specified on design output documentation which Is Incorporated by reference In the Updated Final Safety Analysis Report. The methodology used lo determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN.:UNIT2 3.3-44 Amendment No.~ 296

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1*1 (page 3 of 6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA:1

2. LPCI System (continued)
d. Reactor Steam Dome 1(c),2(c), 4 C SR 3.3.5.1.2 :i!: 215 psig Pressure
  • Low SR 3.3.5.1.4 and 3(c)

(Recirculation Discharge SR 3.3.5.1 .6 :S245psig Valve Permissive)(e)

e. Reactor Vessel Water Level 1,2,3 2 B SR. 3.3.5.1.1 ~ 312 5/16
          - Level 0                                                 1 per                             SR  3.3.5.1.2           inches above subsystem                             SR  3.3.5.1.5           vessel zero SR  3 .3.5.1.6
f. Low Pressure Coolant Injection Pump Start * .Time Delay Relay Pump A.B,C,O (with diesel 4 C SR 3.3.5.1.5 ~ 0 seconds power) SR 3.3.5.1 .6 and
s 1 second Pump A (with normal power) ~ 0 seconds and
s 1 second Pump B (with normal power) :i!: 6 seconds and s 8 seconds Pump C (with normal power) C SR 3.3.5.1.5  ;;: 12 seconds SR 3.3.5.1.6 and
s 16 seconds Pump D (with normal power) 1,2,3, C SR 3.3.5.1.5 ~ 18 seconds 4(a), 5(a) SR 3.3.5.1.6 and
s 24 seconds continued (a) 1Nl'le:, !he e~eeieted st1es,slem(s) ere reL!jt1ired le be OPERABLE.

(c) With associated recirculation pump discharge valve open. (e) During Instrument calibrations, if the As Found channel setpolnt Is conservative with respect to the Allowable Value but outside Its acceptable As Found band as defined by Its associated Survelllance Requirement procedure, then there shan be an Initial determination to ensure confidence that the channel can perform as required before retuming the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint Is not conservative with respect to the Allowable Value, the channel shall .be declared inoperable. Prfor to returning a channel to service, the Instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shan be dedared Inoperable. The nominal Trip Setpolnt shall be specified on design output documentation which Is Incorporated by reference In the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpolnt. the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified In Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 2 3.3-45 Amendment No. 253, 289, ~

RPV Water Inventory Control Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE. APPLICABILITY: According to Table 3.3.5.2-1 . ACTIONS

NO TE-----------------------------------------------------------

Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel. B. As required by Required 8 .1 Declare associated Immediately Action A. 1 and penetration flow path(s) referenced in incapable of automatic Table 3.3.5.2-1 . isolation. AND 8 .2 Calculate DRAIN TIME. Immediately C. As required by Required C.1 Place channel in trip. 1 hour Action A. 1 and referenced in Table 3.3.5.2-1. D. As required by Required 0 .1 Restore channel to 24 hours Action A. 1 and OPERABLE status. referenced in Table 3.3.5.2-1 . BFN-Unit 2 3.3-XX Amendment No.

RPV Water Inventory Control Instrumentation 3.3.5.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E. 1 Declare associated low Immediately associated Completion pressure Emergency Core Time of Condition C or D Cooling System (ECCS) not met. injection/spray subsystem inoperable. SURVEILLANCE REQUIREMENTS

NO TE ----------------------------------------------------------

Refer to Table 3.3. 5. 2-1 to determine which SRs apply for each ECCS Function . SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. 24 hours SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days BFN-Unit 2 3.3-XX Amendment No. 

            ~                                                   RPV Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1)

RPV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE

1. Core Spray System
a. Reactor 4, 5 1 per C SR 3.3.5.2. 1 S 465 psig Steam Dome subsystem(a! SR 3.3.5.2.2 Pressure - Low (Injection Permissive)
b. Core Spray Pump 4, 5 1 per D SR 3.3.5.2.2 c 1647 gpm Discharge Flow - subsystem(a! and Low (Bypass) s 2910gpm
2. Low Pressure Coolant Injection (LPG/) System
a. Reactor Steam 4, 5 2 in one C SR 3.3.5.2. 1 S 465 psig Dome Pressure - trip system(aJ SR 3.3.5.2.2 Low (Injection Permissive)
3. Shutdown Cooling System Isolation
a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2.1 c 528 inches Water Level - Low, system SR 3.3.5.2.2 above vessel Level 3 zero
4. Reactor Water Cleanup (RWCU) System Isolation
a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2.1 c 528 inches Water Level - Low, system SR 3.3.5.2.2 above vessel Leve/3 zero (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel Water Inventory Control. "

(b) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME. BFN-Unit 2 3.3-XX Amendment No.

RCIC System Instrumentation 3.3.5.2" 3.3 INSTRUMENTATION "-.) 3.3.s:2- eactor Core Isolation Cooling {RCIC) System Instrumentation RCIC System instrumentation for each Function in able . 5. shall *be OPERABLE. APPLICABILITY: MODE 1, MODES 2 and 3 with reactor ACTIONS . 

                               .                   NOTE.~~~~--,.'--:i'--~ ~ ~ ~ ~

Separate Condition entry is allowed for each channel. CONDITION COMPLETION TIME A. One or more channels A.1 Immediately inoperable. 

      .B. As required by Req
  • ed
  • 8.1 Declare RCIC System 1 hourfrom Action A.1 and r renced inoperable.. discovery of loss jn Table 3.3.5.2-= . of RCIC initiation capability B.2 Pl~ce channel in trip. 24 hours (continued)

BFN-UN1T2 3.3-49 Amendment No. 253

RCIC System Instrumentation ACTIONS continued CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Re red C.1 Restore channel to 24 hours Action A.1 and r renced OPERABLE status. in Table 3.3.5.~ 1. D. Required Action and 0.1 Declare RCIC System Immediately associated Completion inoperable. Time of Condition B or C not met. u BFN-UNIT2 3.3-50 Amendment No. ~

RCIC System Instrumentation 3.3.5. \._/ SURVEILLANCE REQUIREMENTS 

    ~~~~~~~~~~~~~NOTES                                              .
1. Refer to Table 3.3.5.z:- to determine which SRs apply for each RCIC Fun
2. When a channel is placed an inoperable status solely for performance f required Surveillances, entry I associated Conditions and Requiredt tions may be delayed as follows: (a) for up t hours for Function 2 and (b) for u to 6 hours for Function 1 provided the associate unction maintains RCIC initi 10n capability.

SURVEILLANCE FREQUENCY SR 3.3.5.2: 92 days SR 3.3.5.2: 24 months SR 3.3.5.2. Perform LOGIC .SYSTEM FUNCTIONAL 24 months TEST. u BFN-UNIT2 3.3-51

RCIC System Instrumentation 3.3.5. Table 3.3.5.2' Reactor Core Isolation Coo CONDITIONS REQUIRED REFERENCED ALLOWABLE FUNCTION CHANNELS PER FROM REQUIRED VALUE FUNCTION ACTIONA.1

1. Reactor Vessel Water Level
  • 4 8 Low Low, Level 2(a)
2. Reactor Vessel Water Level - 2 C High, Level 8 (a) During Instrument calibrations, if the As Found channel setpolnt Is conservative with respect to the Allowable Value but outside Its acceptable As Found band as defined by its associated Survelffance Requirement procedure, then there shall be an initial
  , determination to ensure confidence that the channel can perform as required before retumlng the channel to service In accordance with the Surveillance. fr the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.
  • Prior to retumlng a channel to service, the instrument channel setpolnt shall be calibrated to a value that Is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable.

The nominal Trip Setpolnt shall be specified on design output documentation which is incorporated by reference In the Updated Final _Safety Analysis Report. The methodology used to determine the nominal Trip Setpolnt, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpolnt design output documentation shall be specified In Chapter 7 of the Updated Final Safety Analysis Report.

  • BFN-UNIT 2 3.3-52 Amendment No.~ 2-96

Primary Containment Isolation Instrumentation 3.3.6 .1 ACTIONS (continued) u CONDITION REQUIRED ACTION COMPLETION TIME H. As required by Required H.1 Declare standby liquid 1 hour 

         .Action C.1 and              control system (SLC) referenced in               inoperable.

Table 3.3.6.1-1. OR H.2 Isolate the Reactor Water . 1 hour Cleanup System. I. As required by Required 1.1 Initiate action to restore Immediately Action C.1 and channel to OPERABLE refere need in status. Table 3.3.6.1-1. 9R b2 IAiliate aetieA ta iselate Immediately tAe Resial:lal Heat Reme*1al ERHR) Shl:ltacwm Geeting System.

.. BFN-UNIT2 3.3-57 Amendment No. 25a u

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 3) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTION C.1

5. Reactor Water Cleanup (RWCU) System Isolation
a. Main Steam Valve Vault 1,2,3 2 F SR 3.3.6.1.2 s 188°F Area Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
b. Pipe Trench Area 1,2,3 2 F SR 3.3.6.1.2 s 135°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
c. Pump Room A Area 1,2,3 2 F SR 3.3.6.1.2 s 152°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
d. Pump Room B Area 1,2,3 2 F SR 3.3.6.1.2 s 152°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
e. Heat Exchanger Room 1,2,3 2 F SR 3.3.6.1.2 s 143°F Area (West Wall) SR 3.3.6 .1.5 Temperature -.High SR 3.361 .6
f. Heat Exchanger Room 1,2,3 2 F SR 3.3.6.1.2 s 170°F Area (East Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6.1.6
g. SLC System Initiation 1,2,3 1<a) H SR 3.3.6.1.6 NA
h. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 ~ 528 inches Level - Low, Level 3 SR 3.3.6.1.2 above vessel SR 336 .1.5 zero SR 3.3.6.1 .6
6. Shutdown Cooling System Isolation
a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.2 s 115 psig Pressure - High SR 3.3.6.1.5 SR 3.3.6.1 .6
b. Reactor Vessel Water 3-;+,e- 2~ SR 3.3.6.1.1 ~ 528 inches Level - Low, Level 3 SR 3.3.6.1 .2 above vessel SR 3.3.6.1.5 zero SR 3.36.1 .6
c. Drywell Pressure - High 1,2,3 2 F SR 3.3.6.1.2 s 2.5 psig SR 3.3.6.1.5 SR 3.3.6.1.6 (a) One SLC System Initiation signal provides logic input to close both RWCU valves.

(b) Qo,h

  • 8P.e eheMel l;?e f !rif;! eysle FR Fefill:!iFee iR MG9!:S 4 eRa 5 t.tJR8A RI-IR SRl:!IS8WR CaeliR!I SysleFR iRlegript FRaiRlaiASQ,---

Deleted. BFN-UNIT 2 3.3-62 Amendment No. ~ . 254, 2W, 

                                                                                                                              ~ . ~ . -3,-9--

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2*1 (page 1 cf 1) Sec:cnd21Y Containment l!clatlcn Instrumentation APPLICABLE MODES OR REQUIRED FUNCTION OTHER CHANNELS SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIREMENTS VALUE CONDITIONS TRIP SYSTEM

1. Reader Vessel Water Level - 2 SR 3.3.6.2.1 ~ 528 Inches &bcve LCM', l.e'lel 3 SR 3.3.6.2.2 vessel zero SR 3.3.6.2.3 SR 3.3.6.2.4
2. Drywed Pressure
  • High 1,2,3 2 SR 3 .3.6.2.2 ~2.Spslg SR 3.3.6.2.3 SR 3.3.6.2.4
3. Reader Zone Exhaust SR 3.3.6.2.1 S100mRJhr Radlallcn - High R 3.3.11.2.2 Remove comma R 3.3.6.2.3 R 3.3.6.2.4
4. Refuelng Fleer Exhaust 1.2,3, 1 SR 3.3.6.2.1 S100mRJhr RadlatlCX\ - High -w- SR SR 3.3.6.2.2 3.3.6.2.3 SR 3.3.6.2.4
 ,a> D mg cpecaticas Mdtb a poteotlal b: dcalolog Iba raadQr,,.,..,,

u BFN-UNIT 2 3.3-65 Amendment No.~. ~9. 299

CREV System Instrumentation 3.3.7.1 V Table 3.3.7. M (page 1 of 1) Control Room Emergency Ventilation System lns!nJmentatlon APPLICASLE CONDITIONS MODES OR REQUIRED REFERENCED FUHCTION OTHER CHANMELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTIONA.1

1. Reactor Vessel Wa~r Level
  • 1.2.J;{et- 2 B SR 3.3.7.1.1 ~5281nches Low, Level 3 SR 3.3.7.1.2 above vesSEI SR 3 .3 .7.1.5 zero SR 3 .3.7.1.6
2. Drywen Fressl68
  • High 1.2,3 2 B SR 3.3.7.1.2  ::s 2.5 pslg SR 3.3.7.1.5 SR 3.3.7.1.6
3. Reactor 2one Exhaust 1,2,3 1 C SR 3.3.7.1.1  ::S1D0mR"1r Radiation* High ~ SR 3.3.7.1.2 SR 3.3.7 .1.5 SR 3.3.7.1.6
4. Refuellng Floor Exhaust Radlatlcn
  • High 1.2,3,
                                                          ~

SR SR SR 3.3.7.1.1 3.3.7.1.2 3.3.7,1.5 S100mR"1r SR 3.3.7.1.6

5. Control Room Afr Supply Duct 1,2,3, 1 D SR 3.3.7.1.1  ::S270cpm Radiation
  • High ~ SR 3.3.7.1.2 atxiw l i SR 3.3.7.1.3 background

'-..,.I SR 3.3.7.1.4 fa) Gvrhg epaFalkaM wlll:l a psileAllal fw dFainlflS Ille.11111der vessel. u BFN-UNIT 2 3.3-70 Amendment No.~.~. 200

ECCS - Operating 

                                             ~.-R-PV_W_A_T_E_R_I_N_V_E-NT_O_R_Y---.         . 3.5.1 u                                             CONTROL, 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 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 pressures 150 psig.

ACTIONS 

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

LCO 3.0.4.b is not applicable to HPCI. u CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7 days< 1> injection/spray subsystem ECCS injection/spray inoperable. subsystem(s) to OPERABLE status. One low pressure coolant injection (LPCI) pump in both LPCI subsystems inoperable. (continued) 1 

 < >- This Completion Time may be extended to 14 days on a one-time basis. This temporary approval expires June 1, 2005.

BFN-UNIT 2 3.5-1 Amendment No. 253, 269, 286, 294

ECCS

  • Shutdo'NA
                                       , RPV WATER INVENTORY                                                      3.5.2 CONTROL, RPV Water Inventory Control 3.5 EMERGENCY CORE COOLING SYSTEMS (ECC ) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 ECCS - Shutdown                  ~---'Reactor Pressure Vessel (RPV)

Water Inventory Control LCO 3.5.2 .!fwe- low pressure ECCS injection/spray subsystems shall be 

                                -- ~        PERABLE.
                                ~                   s                                                  Relocation from
                                                       . bnrll                                         SR 3.5.2 .3 APPLICABILITY:               MODE . ~                                                              .

MODE 5, except with the spent fuel storage pool gates removed-and water let1el :c:: 22 ft o*,er the top of the reastor pressure vessel flange. ACTIONS R CONDITION REQUIRED ACTION COMPLETION . TIME Initiate A. ~ equired ECCS A.1 Restore required ECCS 4 hours action to injection/spray subsystem injection/spray subsystem establish a inoperable. to OPERABLE status. method of water B. .Required Action and 8.1 Initiate eetion to suspend Immediately . injection associated Completion OPORV-s. / capable of 

                                                                                          .....                    operating Time of Condition A not
                       .met.                                                                                       without offsite electrical G. Two required EGGS                6;-1    Initiate action to suspeoo         Immediately     power.

injeetioAJspray OPOR'ls. subsystems inoperable. AN9. 

                 /

G;2 Restore one EGGS 4 hours iRjestionJspray subsystem to OPERABbE status. 

          ./                                                                                             (continued) fins~rt'1
  ...... I.. ......
                    ~

BFN-UNIT2 3.5-8 Amendment No. 26a DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be 2:: 36 hours. 

                                                    !RPV Water Inventory Control        L-1---+> EGGS    Shutdo*.vn 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Req1;1ireel Aetier, G.2 ar,d 9-:4 lr,itiate aetior, te FesteFe Immediately assoE?iated Completion seeer,dary eer,tair,ment te Time not met. OPERABLE status. ANf} M Initiate aetien te Festere Immediately twe staneley ~as treatment s1:1esystems to OPERABLE status. ANf} 9;-3 Initiate aetion te restore Immediately 

                                 ~\

iselatien sapaeility in eaet:I Feq1;1iFeel seeenaafY eentainment penetration flew patt:I Aet isalatea. \._ . ./ f I ln...sertT2 

                                  ...... l,._ l,._  .I.

BFN-UNIT2 3.5-9 Amendment No. ~ 

                                                                !RPV Water Inventory Control                                     i-1  -->~ EGGS                                     Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS FREQUENCY SR 3.5.2.1-                                       Verify, for eaGt:l=required ECCS                                                                         12 hours
                            \                       injection/spray subsystem, the suppression pool water level is ~ -6.25 inches with or
                                                    -7.25 inches without differential pressure control.                            the SR 3.5.2.2-\                                      Verify, for          quired ECCS                                                                        31 days injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve.
  • SR 3.5.2.ll-\

One LPCI subsystem may be considered OPERABL ring alignment and operation for decay heat r oval if capable of being 

,-.>,.--~.._._._....,.__....... l_                  manually realigned a not otherwise
.._...._...........__ __._.__..._............,._, r inoperable. A Low Pressure Coolant Injection (LPCI) for the ...___---.....-.---------...........--.-............................-.......................................................................,._.-----

Ve required ECCS injection/spray 31 days subsystem anual, power operated, and automatic Ive in the flow path, that is not locked, sea d, or otherwise secured in position, is i the correct position. (continued} 8FN-UNIT2 3.5-10 Amendment No. 263 

                    !RPV Water Inventory Control i-!---)-,. EGGS             Sl:lutdovm 3.5.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE                                       FREQUENCY SR 3.6.2.4    Verify each required EGGS pump dc't*clops             In assordance the specified flow rate against a system l:lead       with the corresponding to tl:le spccilied pressure.            INSERVIGE TESTING PROGRAM SYSTEM HEAD GGRRESPONDING TO A VESSEL TO feffi:1-5 Ne:-9F  DIFFERENTIAL SYSTEM      FLOW RATE      PYMP PRESSURE OF 66          ~ ~!WA'!          i1:  r. ~

INDICATED Ne:-eF SYSTEM SYSTEM FLOW RATE PtJMfLS PRESSURE SR 3.5 .2. 5 ---~-----------~--------N()TE----------------~------- 

           \

Vessel injection/spray may be excluded. Verify ~ ECCS injection/spray 24 months subsystem act1:1ates on an actual or sifl"lulated automatic initiation signa l. can be manually operated . BFN-UNIT 2 3.5-11 Amendment No. ~ . ~

TS 3.5.2 Inserts Insert 1 TS 3.5.2 Page 3.5-8 C. DRAIN TIME C.1 Verify secondary containment 4 hours 

      < 36 hours and      boundary is capable of being 2:: 8 hours.        established in less than the DRAIN TIME.

AND C.2 Verify each secondary containment 4 hours penetration flow path is capable of being isolated in less than the DRAIN TIME. AND C.3 Verify two standby gas treatment 4 hours subsystems are capable of being placed in operation in less than the DRAIN TIME.

Insert 2 TS 3.5.2 Page 3.5-9

0. DRAIN TIME< 8 hours. 0 .1 ----------- NO TE ---------------

Required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power. Initiate action to establish an additional Immediately method of water injection with water sources capable of maintaining RPV water level > TAF for~ 36 hours. ANO 0 .2 Initiate action to establish secondary Immediately containment boundary. ANO 0.3 Initiate action to isolate each secondary Immediately containment penetration flow path or verify it can be automatically or manually isolated from the control room . ANO 0 .4 Initiate action to verify two standby gas Immediately treatment subsystems are capable of being placed in operation. E. Required Action and E.1 Initiate action to restore DRAIN TIME Immediately associated Completion to ~ 36 hours. Time of Condition C or D not met. OR DRAIN TIME < 1 hour.

Insert 3 TS 3.5.2 Page 3.5-10 SR 3.5.2.1 Verify DRAIN TIME~ 36 hours. 12 hours Insert 4 TS 3.5.2 Page 3.5-11 SR 3.5.2.5 Operate the required ECCS injection/spray 92 days subsystem through the test return line for 

                    ~ 1O minutes.

SR 3.5.2.6 Verify each valve credited for automatically 24 months isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal. 

                                        , RPV WATER INVENTORY            RCIC System CONTROL,                                 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS {ECCS) AND REACTOR CORE ISOLATION COOLING {RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3           The RCIC System shall be OPERABLE.

APPLICABILITY: MODE 1. MODES 2 and 3 with reactor steam dome pressure > 150 psig. ACTIONS LCO 3.0.4.b is not applicable to RCIC. CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable. A.1 Verify by administrative Immediately means High Pressure Coolant Injection System is OPERABLE. AND A.2 Restore RCIC System to 14 days OPERABLE status. B. Required Action and B.1 Be in MOOE 3. 12 hours associated Completion Time not met. AND 8.2 Reduce reactor. steam 36 hours dome pressure to 

                                          ~ 150 psig.

u BFN-UNIT2 3.5-12 Amendment No. 2a3, 286

PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS \.._.,} 3.6.1.3 Primary Containment Isolation Valves (PCIVs) LCO 3.6.1.3 Each PCIV, except reactor building-to-suppression chamber vacuum breakers, shall be OPERABLE. 

                                                          ~

APPLICABILITY: MODES 1, 2, and 3, ~ . When associated instrumentation is required to be OPERABLE per LGO a.a.6.1, "Priffiary Containment Isolation Instrumentation." Relocated text from Page 3.6-10 BFN-UNIT2 3.6-9 Amendment No. 263-

PCIVs 3.6.1.3 

         ~~_;,_~~~~~~~~~~NOTES                                                           .
1. Penetration flow paths except for 18 and 20 inch purge valve 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 PCIVs.
4. Enter applicable Conditions and Required Actions of LCO 3.6.1 .1, "Primary Containment," when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria iA MODES 1, 2, aAa a.

IACTIONSI CONDITION REQUIRED ACTION COMPLETION TIME A. . NOTE A.1 Isolate the affected 4 hours except for Only applicable to penetration flow path by main steam line penetration flow paths use of at least one closed with two PCIVs. and de-activated AND automatic valve, closed manual valve, blind 8 hours for main Ohe or more penetration flange, or check valve steam line flow paths with one PCIV with flow through the inoperable except due to valve secured. MSIV leakage not within limits. AND {continued) BFN-UN1T2

  • 3.6-1 0 Amendment No. 253

PCIVs 3.6.1.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. One or more penetration 0.1 Restore leakage rate to 4 hours flow paths with MSIV within limit. leakage not within limits. E. Required Action and E.1 Be in MODE 3. 12 hours associated Completion Time of Condition A, B, C, AND or D not met iA MODE 1, 2, er:a. E.2 Be in M0DE4. 36 hours 

  .. Requir:ee AetieA BAd C                               F:-1  IAitiete eetier, te suspeAd    Immediately asseeiated SempletieA             eperetior,s with e
      +ime eJ SeAditieA A, B, 6 ,       petefltiBI fflf dFBiAiAg the er: D Aet met fer: P6f)i(s)       reeC'teF 'f'essel (OPDRVs).

required te be OPERABLE dur:ir,g OR-M90E4eF 5. . u ~ N9+E 0Aly epplieeele JeF iAepeFBble RHR Shutdewn GeeliAg 

                                        '"hl't'eS.

IAitiete aetieA te r:esteFe Immediately val*,e(s) te OPERABLE. stattts. BFN-UNIT2 3.6-13 Amendment No. '25a u

Secondary Containment 3.6.4.1 \._) 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3;- DufiRg operations with a potential for draining the reaotor vessel 1. (OPORVs). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours inoperable ifl MODE 1, 2, containment to era. OPERABLE status. B. Required Action and 8.1 Bein MODE 3. 12 hours associated Completion Time of Condition A not AND met. 8.2 Bein MODE 4. 36 hours J:,.. (continued) 

                                      ~ D~~bl~ u~?e~li*n~ * , 1 BFN-UNIT 2                             3.6-44                  Amendment No. 253,    '-

Delete information on this page and insert "This page Secondary Containment intentionally left blank." 3.6.4.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Seeondery eontaiAment GA Initiate action to suspend Immediately inopoFable during OPDRVs. OPDRVs. \ '--j; BFN-UNIT 2 3.6-45 Amendment No. 253, 298

SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) LCO 3.6.4.2 Each SCIV shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3, During operations with a potential for draining the roaster vessel (OPDW/s). ACTIONS 

 -----------------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 SCNs.

u ------------------------------------------------ CONDITION REQUIRED ACTION COMPLETION TIME A. One or more penetration A1 Isolate the affected 8 hours flow paths with one SCIV penetration flow path by inoperable. lise of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. (continued) BFN-UNIT2 3.6-47 Amendment No. 253, 299

SCIVs 3.6.4.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 NOTE Isolation devices in high radiation areas may be verified by use of a.dministrative means. Verify the affected Once per 31 days penetration flow path is isolated. B. NOTE B.1 Isolate the affected 4 hours Only applicable to penetration flow path by penetration flow paths use of at least one closed with two isolation valves. and de-activated automatic valve, closed manual valve, or blind One or more penetration flange. flow paths with two SC IVs inoperable. C. Required Action and C.1 Bein MODE3. 12 hours associated Completion Time of Condition A or B AND not met iA MG9E ~, 2, eF

a. C.2 Bein MODE 4. 36 hours (sentin~ed)

BFN-UNIT2 3.6-48 Amendment No. ~

Delete information on this SCIVs page and insert "This page 3.6.4.2 intentionally left blank. " ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and 9.-=t Initiate aetioA to suspend Immediately associated Completion OPDRVs. Time of Condition A or B Rot met during OPDRVs. '--.,/I BFN-UNIT 2 3.6-49 Amendment No. ~ . 2 SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Three SGT subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3, DuriF1g opcratieF1s with a J:)eteF1tiel for draiF1iF1g the reseter vessel (O~CRlt s). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem 7days inoperable. to OPERABLE status. B. Required Action and 8.1 Bein MODE 3. 12 hours u associated Completion Time of Condition A not AND met iFI M99E 1, 2, eF a. 8.2 Be in MODE 4. 36 hours 

                                                        '1'                          (continued)

I 

                                          "   'l  T  T   'l T   T T I,, Relocate remaining row
  • from Page 3.6-52 .

BFN-UNIT 2 3.6-51 Amendment Mo. ~. 200-

Relocate remaining row to SGT System Page 3.6-51 and insert "This 3.6.4.3 page intentionally left blank." I I ACTIONS continued \..J CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and GA Place two OPERABLE Immediately associated CompletioA SGT subsystems iA Time of Condition A not operation. met during OPDRVs. 

                                      &.2     Initiate aetieA ta suspend Immediately OPDRVs.
      -9; Two or three SGT            -&.1    Enter LCO 3.0.3.           Immediately subsystems Inoperable-JR-(c0Rtim1ed) u BFN-UNIT 2                              3.6-52                 Amendment No. ~ .  ~

Delete information on this page and insert "This page SGT System intentionally left blank." 3.6.4.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. Two 01 tluee SGT E-1 Initiate action to suspend Immediately subsyste111s h1operable OPDRVs. daring OPDRVs. u BFN-UNIT2 3.6-53 Amendment No.~. ~

CREV System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency Ventilation (GREV) System LCO 3.7.3 Two CREV subsystems shall be OPERABLE. 

                   ~~~-~~NOTE~~~~*~~~~~~~~~

The main control room envelope (CRE) boundary may be opened intermittently under administrative control. APPLICABILITY: MODES 1, 2, and 3, El~FiRg 0f)8Fations will:\ a l*)teRtial for EfminiAg t~e reseter 'f'essel (OPDRVs). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREV subsystem A.1 Restore CREV subsystem 7days inoperable for reasons to OPERABLE status. other than Condition B, C, or 0. B. One or more CREV B.1 Initiate actions to Immediately subsystems inoperable implement mitigating due to inoperable CRE actions. boundary in MODE 1, 2, Sf-3. AHQ B.2 Verify mitigating actions 24 Hours ensure CRE occupant exposures to radiological hazards will not exceed limits, and verify the CRE occupants are protected from smoke and chemical hazards. ANQ 8.3 Restore CRE boundary to 90days OPERABLE status. (continued) BFN-UNIT 2 3.7-9 Amendment No. i!83, 298, 302, 6GB

CREV System 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Two CREV subsystems C.1 Restore HEPA filter and ?days inoperable due to one charcoal adsorber to inoperable High Efficiency OPERABLE status. Particulate Air (HEPA) filter or charcoal adsorbers which do not impact ability of CREV subsystems to meet flowrate requirements specified In the Ventilation Filter Testing Program (VFTP). 0 . One CREV subsystem 0.1 Restore charcoal 14 days inoperable due to adsorber to OPERABLE inoperable charcoal status. adsorber which does not impact the ability of CREV subsystem to meet' flowrate requirements specified in the VFTP. E. Required Action and E.1 Bein MOOE3. 12 hours associated Completion Time of Condition A, B, C, ANO or D not met iA MODE 1, t,""8f-3. E.2 Bein MODE 4. 36 hours Relocate remaining row from next page BFN-UNIT2 r 3.7-98-- Amendment No. m 398 

                                                                          ,~. ~ .

CREVSystem Relocate remaining row to 3.7.3 previous page and delete this page ACTIONS continued CONDITION REQUIRED ACTION COMPLETION TIME F. Requ ired Aotion and Place OPERABLE GREV lmmooialely assooiated Completion subsystem in Time of Condition A or D pressuria3tion mode. not met dl:IFing OPDRVs. F.2 IAitiate astioR to Sl:ISpend lmmeEliately OPORVs. G:- Two CREV subsystems 6:1 Enter LCO 3.0.3. Immediately noperable in MODE 4.-2, for reasons other tha1 Condition B or C. (eeRtiF11:1 ed) Double underline BFN-UNIT 2 3.7-10 Amendment No. ~ . 283, 299, aQ8

Delete information on this CREVSystem page and insert "This page 3.7.3 intentionally left blank." ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME H. Rftq1:1ired AetiOA SAE! HA IAitiate action to suspcAd Immediately assoeiatoo Completion OPDRVs. Time of GendltieA C AOt met euriAg OPDRVs T'tJO CRE\J subsystems inepemble duriAQ OPDRVs for reaSOAS ottier than GonditioA C. One or mOFe GREV subsystems ineperable due to an iAopemble CRE BouAElary duFing OPORVs. BFN-UNIT 2 3.7-11 Amendment No. ~ . ~. ~ . a88

Control Room AC System 3.7.4 3.7 PLANT SYSTEMS u 3.7.4 Control Room Air Conditioning {AC) System LCO 3. 7 .4 Two Unit 1 and 2 control room AC subsystems shall be OPERABLE. ~. APPLICABILITY: MODES 1, 21 and 3, . During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS, During operations with a potential for draining the reactor ¥essel (OPDRVs). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Unit 1 and 2 control A. 1 Re~tore Unit 1 and 2 30 days room AC subsystem control room AC inoperable. subsystem to OPERABLE status. {continued) BFN-UNIT2 3.7-13 Amendment No. 254 SEP O8 1996

Control Room AC System 3.7.4 ACTIONS continued u CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 NOTE associated Completion  !* LCO 3.0.3 is not Time of Condition A or B applicable. not met during movement of irradiated fuel assemblies in the Place OPERABLE control Immediately secondary containment, room AC subsystem in during CORE operation. ALTERATIONS, OPDR'ls. D.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment. AND 0.2.2 Suspend CORE Immediately ALTERATIONS. D.2.3 Initiate action to suspend Immediately OPDRVs. BFN-UNIT2 3.7-15 Amendment No. ~ SEP 8 8 1998

AC Sources - Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) ~ Initiate aetien te suspend Immediately

  • operations with a potential f.er draining the reactor i.*essel (OPDRVs).

A.2.-4 Initiate action to restore Immediately required offsite power circuit to OPERABLE status.

8. One or more required Suspend CORE Immediately Unit 1 and 2 DGs ALTERATIONS.

inoperable. B.~ Suspend movement of Immediately irradiated fuel assemblies in secondary containment. Initiate aetion to suspend Immediately OPORVs. B. 4;4 Initiate action to restore Immediately required Unit 1 and 2 DGs to OPERABLE status. (continued)

  • BFN-UNIT 2 3.8-16 Amendment No. 253

\_/*

AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 --~~~~~NOTE~------~~ The following SRs are not required to be performed: SR 3.8.1.2, SR 3.8.1.5, SR 3.8.1.7,JR 3.8.1.8, end SR 3.8.1.9. l land! For Unit 1 and 2 AC sources required to be In accordance OPERABLE, the $Rs of Specification 3.8.1 with applicable are applicabl7t:. . SRs SR 3.8.2.2 For the requi ed Unit 3 DG, the SRs of Unit 3 In accordance Technical SJ ecifications are applicable. with applicable SRs I I,except SR 3.8.1.6 and SR 3.8.1.9 I . BFN-UNIT2 3.8-18 Amendment No. -253

DC Sources - Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION .COMPLETION 

                                                          *
  • TIME A. (continued) ;6.:2:3 Initiate action to suspend Immediately operations with 21 potenti21I for draining the reactor vessel.

AJ2.~ Initiate action to restore Immediately required DC electrical power subsystems or 3 systems to OPERABLE status. Amendment No.-258--

Distribution Systems - Shutdown

  • 3.8.8
         *ACTIONS CONDITION        REQUIRED ACTION                     COMPLETION

\ .J TIME A (continued) A:2;-3 Initiate aetion to suspend Immediately opeFations t..vith a potential foF dFaining the FCaetoF Yessel. A.2.4- Initiate actions to restore Immediately 13 required AC and DC electrical power distribution subsystems to OPERABLE status. AND A.2.5- Declare associated Immediately 

                              £ required shutdown cooling subsystem{s) inoperable and not in operation.

BFN-UNIT 2 3.8-40 Amendment No. -263- 

  \.._;"

Attachment 4 to CNL-19-010 Proposed Technical Specification Changes (Unit 3 Mark-up) (55 total pages) CNL-19-010

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) 

     !3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control .......... ...... 3.3-48a Section                                                                                                       Page No.

3.3 TATION ........... ............................................ ......... 3.3-1 3.3.1.1 React Protection System (RPS) Instrumentation ........ ...... 3.3-1 3.3.1.2 Sour Range Monitor (SRM) Instrumentation .................... 3.3-10 3.3.2.1 3.3.2.2 Co rol Rod Block Instrumentation ....................... .... ........... 3.3-16 F dwater and Main Turbine High Water Level I* Trip Instrumentation ........ .... ..... ........................... ...... ...... 3.3-22 3.3.3.1 ost Accident Monitoring (PAM) Instrumentation ...... ........... 3.3-24 3.3.3.2 Backup Control System ........ ..... .......... ... ...... ........................ 3.3-28 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation ............... .... ........ ................. ................... 3.3-30 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation .. .. ................... 3.3-33 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation ..................... ... .................... .... ......... .. .... 3.3-36 3.3.5.~ Reactor Core Isolation Cooling (RCIC) System 

              ~

Instrumentation ....... .... ... .. .... ..................................... ...... 3.3-49 3.3.6.1 Primary Containment Isolation Instrumentation .............. .... . 3.3-53 3.3.6.2 Secondary Containment Isolation Instrumentation .... .... '. ...... 3.3-62 \_./* 3.3.7.1 Control Room Emergency Ventilation (CREV) System Instrumentation .................................................. 3.3-66 3.3.8.1 Loss of Power (LOP) Instrumentation .. ............... ....... .......... 3.3-71 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ......... .. .................. ....... ................. .................. 3.3-76 3.4 REACTOR COOLANT SYSTEM (RCS) .............. ...................... 3.4-1 3.4.1 Recirculation Loops Operating ............ ................................. 3.4-1 3.4.2 Jet Pumps .. .... .. ... ................ ........ ..... ...................... ............. . 3.4-5 3.4.3 Safety/Relief Valves (S/RVs) ........................ ............. ....... ... 3.4-7 3.4.4 RCS Operational LEAKAGE .......... ........................... ........... 3.4-9 3.4.5 RCS Leakage Detection Instrumentation ............................. 3.4-12 3.4.6 RCS Specific Activity ................ ................................... ......... 3.4-15 3.4.7 Residual Heat Removal {RHR) Shutdown Cooling System - Hot Shutdown ....................................... .. ......... 3.4-18 (continued) BFN-UNIT3 ii Amendment No. 243 

                                                                                                          ~       [I ~ *;:99

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Reactor Pressure Vessel (RPV) Water Inventory Control Section Page No. 3.4.8 Residual Heat Removal (RHR} hutdown Cooling System - Cold Shutdown. ............ ................... ............... 3.4-21 3.4.9 RCS Pressure and Temper ure (PfT) Limits .... .... ........ ...... 3.4-24 3.4.10 Reactor Steam Dome Pre sure ....... ............ ......................... 3.4-30 3.5 EMERGENCY CORE CO ING SYSTEMS (ECCS) AND REACTOR CORE IS LATION COOLING (RCIC) SYSTEM ...... ."....... ................. ........ .... .......... ......... ......... 3.5-1 3.5.1 ECCS - Operatin ................. .... ...... ........... .......................... 3.5-1 3.5.2 EGGS St=iutae'tvn ..... .. .......... ...... ................. ........................ 3.5-8 3.5.3 RCIC System ." .... ................................................................... 3.5-12 3.6 CONTAINMENT SYSTEMS ...... ............ ........ ............................ 3.6-1 3.6.1.1 Primary Containment.. ...... .. .. .. ...................... ...................... .. 3.6-1 3.6.1.2 Primary Containment Air Lock ................. .............. .. ............. 3.6-3 3.6.1.3 Primary Containment Isolation Valves (PCIVs) .................... 3.6-9 3.6.1 .4 Drywell Air Temperature ...................... ........... ....... .............. 3.6-17 3.6.1 .5 Reactor Building-to-Suppression Chamber Vacuum Breakers ............ ....... ................. .... ..... .............. .............. 3.6-19 3.6 .1.6 Suppression Chamber-to-Drywell Vacuum Breakers ........... 3.6-22 3.6.2.1 Suppression Pool Average Temperature ...... .............. ...... ... 3.6-24 3.6.2.2 Suppression Pool Water Level... ................... ....................... 3.6-29 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling ...... ...... ... .................... .......... ........... .. ......... 3.6-31 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray ... .......... ................ ..... ........................... ......... 3.6-34 3.6.2.5 Residual Heat Removal (RHR) Drywall Spray ............... ...... 3.6-36 3.6.2.6 Drywall-to-Suppression Chamber Differential Pressure ....... 3.6-38 3.6.3.1 Containment Atmosphere Dilution (CAD) System .. .............. 3.6-40 3.6.3.2 Primary Containment Oxygen Concentration ....................... 3.6-42 3.6.4.1 Secondary Containment ................................................. ...... 3.6-44 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) ............ ... 3.6-47 3.6.4.3 Standby Gas Treatment (SGT) System ......................... ....... 3.6-51 (continued) BFN-UNIT3 iii Amendment No. 243-SEP g 8 1S~B

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) -. TABLE OF CONTENTS (continued) Section Page No. 3.7 PLANT SYSTEMS .. ........_.. .. .... ...... ... ................................. ......... 3.7-1 3.7.1 Residual Heat Removal Service Water (RHRSW) System and Ultimate Heat Sink (UHS) ........................... 3.7-1 3.7.2 Emergency Equipment Cooling Water (EECW) System and Ultimate Heat Sink (UHS) ....................... .... 3.7-7 3.7.3 Control Room Emergency Ventilation (CREV) System ... .. .. . 3.7-9 3.7.4 Control Room Air Conditioning (AC) System .......... ............. 3.7-13 3.7.5 Main Turbine Bypass System .... ...... ....... ... ....... .... ................ 3.7-17 3.7.6 Spent Fuel Storage Pool Water Level... ............................... 3.7-19 3.8 ELECTRICAL POWER SYSTEMS ............................................ 3.8-1 3.8.1 AC Sources - Operating ............ ........................................... 3.8-1 3.8.2 AC Sources - Shutdown ............ ..... ...........~************************** 3.8-14 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ..... .... .................. 3.8-19 3.8.4 DC Sources - Operating ....................................................... 3.8-22 3.8.5 DC Sources - Shutdown ................ .. ...... ............ .. ................. 3.8-26 3.8.6 Battery Cell Parameters .. .. ........................... .. ...... ... ......... .... 3.8-29 3.8.7 Distribution Systems - Operating ................................. ........ 3.8-33 3.8.8 Distribution Systems - Shutdown ......................................... 3.8-39 3.9 REFUELING OPERATIONS .................. ................... ................. 3.9-1 3.9.1 Refueling Equipment Interlocks ................................ ........... 3.9-1 3.9.2 Refuel Position One-Rod-Out Interlock ................. ............... 3.9-3 3.9.3 Control Rod Position ............................................ ................ 3. 9-5 3.9.4 Control Rod Position Indication ... .......... .......... .... ................. 3.9-7 3.9.5 Control Rod OPERABILITY- Refueling ............................... 3.9-10 3.9.6 Reactor Pressure Vessel (RPV) Water Level ...................... 3.9-12 3.9.7 Residual Heat Removal (RHR) - High Water Level ............. 3.9-14 3.9.8 Residual Heat Removal (RHR) - Low Water Level .............. 3.9-18 3.9.9 Decay Time ... ..... .........................................................................3.9-22 (continued) BFN-UNIT 3 iv Amendment No. 212~3j ~

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF TABLES Page No. Table 1.1-1 ........................................................................ ................................ 1. 1-8 Table 3.1.4-1 ....... ...................................L . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.1-15 Table 3.3.1.1-1 .................................................................................................. 3.3-7 Table 3.3.1.2-1 ... .............................................................................................. . 3.3-15 Table 3.3.2.1-1 ...... ...................... .................................... .................................. 3.3-21 Table 3.3.3.1-1 .................................................................................................. 3.3-27 Table 3.3.5.1-1 ..................... ............................................................. ... ............. 3.3-43 3.3-48c Table 3.3.5.2-1 .................................................... .............................................. 3.3-62 Table 3.3.6.1-1. ................................... ........................................................... 3.3-59 Table 3.3.6.2-1 ........ . ................................................... .................................... 3.3-65 Table 3.3.7.1-1 .... ...................................................... ................. ..................... 3.3-70 Table 3.3.8.1-1 ..... ............................................. ... ..................... ...................... 3.3-75 Table 3.8.6-1 .............................................................................. ..................... 3.8-32 Table 3.3.5.3-1 ....... ............... ... .... .............. .......... ................... ....... ... ... .... ...... .... ... 3.3-52 BFN-UNIT 3 vi Amendment No. ~ SEP P 3 1~J8

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF FIGURES .\.........,' Figure Page No .. Figure 3.1.7-1 .. .... ..... ... .... ... .................... ... .... .. ...... ....... .. ., ... .. ........ ................... . 3.1-27 Figure 3.4 .1-1 .... ...... .. ...................... .................................................................. 3.4-4 Figure 3.4.9-1 ............. ......... ..... ... ... ...... ... .... ............. ... ..... .... ... ....... .. .... .. ..... .. .... 3.4-29/29b 

              .              . . ............................................................................................... .                                    I Figure 3.4.9-2 ........... ... ..................................... ..... .. ....................... .. .................... 3.4-29a/c BFN-UNIT 3                                                          vii                         Amendment No. 2,1.2,2-1-3, ~
                                                                                                                                             ; '-iJ
                                                                                                                                                 ~r.n< 1 ~ ,.,r.f\g
  • Lt .,. -

Definitions 1.1 1.1 Definitions (continued) CORE OPERATING LIMITS The COLR is the unit specific document that provides REPORT (COLR) cycle specific parameter limits for the current reload cycle . These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications. DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of 1-131 , 1-132, 1-133, 1-134, and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in Table Ill of TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites." INSERVICE TESTING The INSERVICE TESTING PROGRAM is the license PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f) . (continued) BFN-UNIT 3 1.1-3 Amendment No. ~ . U5

Insert 1 DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a. The water inventory above the TAF is divided by the limiting drain rate;
b. The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the TAF except:
1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths;
2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or
3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who is in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation devices without offsite power.
c. The penetration flow paths required to be evaluated per paragraph b) are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory;
d. No additional draining events occur; and
e. Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value.

ECCS Instrumentation 3.3.5.1 '\ ..._/ ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. As required by Required B.1 NOTES= Action A.1 and referenced **1 . Qnl)' applieaele in in Table 3.3.5.1-1 . MGDES 1, 2, and a. 2; Only applicable for Functions 1.a, 1.b, 2.a, and 2.b. Declare supported ECCS 1 hourfrom feature( s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND B.2 NOTE 

 '\ _./

Only applicable for Functions 3.a and 3.b. Declare High Pressure 1 hourfrom Coolant Injection (HPCI) discovery of loss System inoperable. of HPCI initiation capability AND B.3 Place channel in trip. 24 hours (continued) BFN-UNIT 3 3.3-37 Amendment No. 24-3 

                                                                                 ~EP fJ 3 1595-

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Required C.1 NOTES-Action A.1 and referenced **1. 9ftly e1919lieeale iR in Table 3.3.5.1-1. M9DES 1, 2, eftd a. 2: Only applicable for Functions 1.c, 1.e, 2.c, 2.d, and 2.f. Declare supported ECCS 1 hour from feature( s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND . ,/ C.2 Restore channel to 24 hours ' -* OPERABLE status. D. As required by Required D.1 NOTE Action A.1 and referenced Only applicable if HPCI in Table 3.3.5.1-1 . pump suction is not aligned to the suppression pool. Declare HPCI System 1 hour inoperable. (continued) BFN-UNIT 3 3.3-38 Amendment No. 243 

                                                                                  ,.. . ."* *~ -. . . ...
                                                                                       ~)            ,

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1 ~~~NOTES----~- Action A. 1 and referenced *'1 . ORiy applicable in in Table 3.3.5.1-1. MODES 1, 2, end 3. 2: Only applicable for Function 1.d. Declare supported ECCS 1 hourfrom feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. subsystems in both divisions E.2 Restore channel to 7days OPERABLE status. (continued} BFN-UNIT 3 3.3-39 Amendment No. 243 SEP e S 1~3B

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 6) Emergency Core Cooling System Instrumentation APPLICABLE . CONDITIONS MODES REQUIRED REFERENCED FUNCTION

  • OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA.1
1. Core Spray System
a. Reactor Vessel Water Level 4(b) B SR 3.3.5.1.1 ;e 398 Inches
           - Low Low Low, Level 1(f)                                                                    SR SR 3.3.5.1.2 3.3.5.1.5 above vessel zero
                                                                                                                                                  .I SR   3.3.5.1;6
b. Drywell P1essure - High(!) 1,2,3 8 SR 3.3.5.1.2 s 2.5 psig*

SR 3.3.5.1.5 SR 3.3.5.1.6

c. Reactor Steam Dome 1,2,3 C SR 3.3.5.1.2 ;e 435 psig and Pressure - Low (Injection SR 3.3.5.1 .4 S465 psig Permissive and ECCS SR 3.3.5.1.6 Initiation)(!)
  • 4(a}, !!(a) 4 SR a.a.5.H ! :i: 435 psig and
                                                                      ~       p                         SR a.a.5.U               s-465 irslg system                           SR a.a.5.1 .s
d. Core Spray Pump Discharge SR 3.3.5.1.2 ;e 1647 gpm Flow- Low (Bypass) SR 3.3.5.1.5 and S2910gpm
e. Core Spray Pump Start -

Time Delay Relay Pumps A,8,C,O (with diesel SR 3.3.5.1 .5 ;e 6 seconds pow.er) SR 3.3.5.1.6 and s 8 seconds Pump A (with normal power) C SR 3.3.5.1.5 ;e Oseconds SR 3.3.5.1 .6 and s 1 second Pump e (with normal power) 1 C SR 3.3.5.1.5 ;e 6 seconds SR 3.3.5.1.6 and s 8 seconds continued (a) ',Vhen associated subsyste,,,(s) a,e ,equl,ed to be OPERABLE. (b) Channels affect Common Accident Signal Logic. Refer to LCO 3,8.1, "AC Sources - (f) During Instrument calibrations, If the As Found channel setpoint Is conservative with respect to the Allowable Value but outside Its acceptable As Found band as defined by Its associated Surveillance Requirement procedure, then there shall be an Initial determination to ensure confidence* that the channel can perfo(TTI as required before re!IJrning the channel to service In accordance with the Surveillance. If the As Found Instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be.declared inoperable. Prior to returning a chanl')el to service, the Instrument channel setpoint shall be cafibraled to a value that is within the acceptable As Left tolerance of the setpolnt; otherwise, the channel shan be declared inoperable. Th.e nominal Trip Setpoint shall be specified on design output documentation which Is Incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to detennine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band. and a listing of the setpoint design output documentation shall be specified In Chapter 7 of the Updated Final Safety Analysis Report. . BFN-UNIT 3 3.3-43 Amendment No. 213, 254

ECCS Instrumentation 3.3.5.1

  • Table 3.3.5.1-1 (page 2 of 6)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA.1

1. Core Spray System (continued)
e. Core Spray Pump Start-Time Delay Relay (continued)

Pump C (with normal power) SR 3.3.5.1.5 .i: 12 seconds SR 3.3.5.1.6 and s 16 seconds Pump D (with normal power) SR 3.3.5.1 .5 .i: 18 seconds SR 3.3.5.1.6 and s24 seconds

2. Low Pressure Coolant Injection (LPCI) System
a. Reactor Vessel Water Level SR 3.3.5.1 .1 .!:398 inches
         * -Low Low Low, Level 1Cfl                                                                  SR   3.3.5.1.2           above vessel SR   3.3.5.1 .5          zero SR   3.3.5.1.6
b. Drywell Pressure - High(f) 1,2,3 4 B SR 3.3.5.1.2 :s 2.5 psig SR 3.3.5.1.5 SR 3.3.5.1.6
c. Reactor Steam Dome 1,2,3 4 C SR 3.3.5.1.2 .!: 435 psig and Pressure- Low (Injection SR 3.3.5.1.4 :S465 psig Permissive and ECCS SR 3.3.5.1.6 lnltlation)ff) 4- e- SR a.a.s.1.2 <! 435 psig and SR a.a.s. u S465 pslg SR 3.3.5.1.6 (continued (a) \OA=teA assesia!eE! s1:1!:lsystem(s) eFe FeE!YireEI le be QPERABb.E. -.:~,---..:.*-~-1~eleted .

(b) Deleted. * (f) During Instrument calibrations, if the As Found channel setpolnt Is conservative with respect to the Allowable Value but outside Its acceptable As Found band as defined by Its associated Surveillance Requirement procedure, then there shaO be an initial detenninalion to ensure confidence that the channel can perform as required before returning the channel to service In accordance with the Survemance. If the As Found instrument channel setpolnt Is not conservative with respect to the Allowable Value, the channel shall be declared Inoperable. Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that Is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be dedared Inoperable.

  • The nominal Trip Setpoint shall be specified on design output documentation which Is incorporated by reference In the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpolnt, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified In Chapter 7 of the Updated Final Safety Analysis Report.
  • BFN-UNIT.3 3.3-44 Amendment No. 213, 264

EGGS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of 6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED .REQUIREMENTS VALUE CONDITIONS FUNCTION ACTION A.1 .

2. LPCI System (continued)
d. Reactor Steam Dome 1(c),2(c), 4 C SR 3.3.5.1.2 ~ 215 psig Pressure - Low 3(c) SR 3.3.5.1.4 and s 245 psig (Recirculation Discharge SR 3.3.5.1.6 Valve Permissive)Cf)
e. Reactor Vessel Water Level 1,2,3 2 El SR 3.3.5.1.1 .!: 312 5/16
           -LevelO                                                       1 per                        SR   3.3.5.1.2           Inches above subsystem                       SR   3.3.5.1.5            vessel zero SR   3.3.5.1.6
f. Low Pressure Coolant Injection Pump Start - Time Delay Relay Pump A,B,C,D (with diesel 4 C SR 3.3.5.1.5 ~ Oseconds power) SR 3.3.5.1.6 and s 1 second Pump A (with normal power) i?: O seconds and s 1 second Pump B (with normal power) i?: 6 seconds and
                                                                                                                               ! 8 seconds Pump C (with normal power)                                                         C       SR 3.3.5.1.5             i?: 12 seconds SR 3:3.5.1.6             end s 16 seconds Pump D (with normal power)                                                         C       SR 3.3.5.1.5             i?: 18 seconds SR 3 .3.5.1.6            and s 24 secoods (continued)

(a) Wt.a, , tl':a esseeie!ed stl!'ls)slel'l'l(s} ere reqtlired le be OPERABLE. <11:(,---------11 Deleted . I (c)

  • With associated recirculation pump discharge valve open.

(f) During Instrument calibrations, If the As Found channel setpolnt ls conservative with respect 'to the Allowable Value but outside Its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found Instrument channel setpoint Is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Prior to returning a channel to service, the Instrument channel setpciint shall be cafibrated to a value that Is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared lnoperab(e, * 

                 .                                                                           II   ;      .   .                               .

The nominal Trip Setpolnt shall be specified on design output documentation which Is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. *

  • BFN-UNIT 3 . 3.3-45 , Amendment No. 213, 2e4

RPV Water Inventory Control Instrumentation 3.3.5.2 3.3 INSTRUMENTAT/ON 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE. APPLICABILITY: According to Table 3.3.5.2-1. ACTIONS

NO TE-----------------------------------------------------------

Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel. B. As required by Required 8 .1 Declare associated Immediately Action A. 1 and penetration flow path(s) referenced in incapable of automatic Table 3.3.5.2-1 . isolation. AND 8 .2 Calculate DRAIN TIME. Immediately C. As required by Required C.1 Place channel in trip. 1 hour Action A. 1 and referenced in Table 3.3.5.2-1. D. As required by Required 0 .1 Restore channel to 24 hours Action A. 1 and OPERABLE status. referenced in Table 3.3.5.2-1 . BFN-Unit 3 3.3-XX Amendment No.

RPV Water Inventory Control Instrumentation 3.3.5.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E. 1 Declare associated low Immediately associated Completion pressure Emergency Core Time of Condition C or D Cooling System (ECCS) not met. injection/spray subsystem inoperable. SURVEILLANCE REQUIREMENTS

NO TE-----------------------------------------------------------

Refer to Table 3.3.5.2-1 to determine which SRs apply for each ECCS Function. SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. 24 hours SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days BFN-Unit 3 3.3-XX Amendment No. 

            ~                                                   RPV Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1)

R PV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Core Spray System
a. Reactor 4, 5 1 per C SR 3.3.5.2.1 S 465 psig Steam Dome subsystem!*! SR 3.3.5.2.2 Pressure - Low (Injection Permissive)
b. Core Spray Pump 4, 5 1 per D SR 3.3.5.2.2 c 1647 gpm Discharge Flow - subsystem!*! and Low (Bypass) S 2910 gpm
2. Low Pressure Coolant Injection (LPG/) System
a. Reactor Steam 4, 5 2 in one C SR 3.3.5.2.1 S 465 psig Dome Pressure - trip system!*! SR 3.3.5.2.2 Low (Injection Permissive)
3. Shutdown Cooling System Isolation
a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2.1 c 528 inches Water Level - Low, system SR 3.3.5.2.2 above vessel Level 3 zero
4. Reactor Water Cleanup (RWCU) System Isolation
a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2. 1 c 528 inches Water Level - Low, system SR 3.3.5.2.2 above vessel Level 3 zero (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel Water Inventory Control. "

(b) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME. BFN- Unit 3 3.3-XX Amendment No.

RCIC System Instrumentation 3.3.5.~ 3.3 INSTRUMENTATION eactor Core Isolation Cooling (RCIC) System Instrumentation

  • RCIC System instrumentation for each Function in able . 5. shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor ~ ,::imN"lriim~ ACTIONS 

       ~~~~~~~~~~~~~~NOTE~~~~~~--4--+--~~~~~

Separate Condition entry is allowed for each channel. CONDITION COMPLETION TIME --_., A. One or more channels A.1 Immediately inoperable. 8 . As required by Req

  • ed 8 .1 Declare RCIC System 1 hourfrom
  • Action A.1 and r renced inoperable. discovery of loss in Table 3.3.5.2- . of RCIC initiation capability 8 .2 Place channel in trip. 24 hours (continued)
  • BFN-UNIT 3 3.3-49 Amendment No. 243 SEP g 3 1998

RCIC System Instrumentation ACTIONS continued i-------~ 2-CONDITION COMPLETION TIME C: As required by Re

  • ed C.1 Restore channel to 24 hours Action A.1 and r. erenced **OPERABLE status.

in Table 3.3.5.2-1 . D. Required Action and 0.1 Declare RCIC System Immediately associated Completion inoperable. Time of Condition B or C not met. BFN-UNIT 3 3.3-50 Amendment No. 24.J.. SEP a a 1sea

RCIC System Instrumentation 3.3.5.2- \,__,/ SURVEILLANCE REQUIREMENTS 

      ~~~~~~~~~~~~~N,OTES.~~~~~~~~~~+--~
1. Refer to Table 3.3.5. to determine which SRs apply for each RCIC Fun
2. When a channel is placed an inoperable status solely for performance required Surveillances, entry I o associated Conditions and Required ctions may be delayed as follows: (a} for up 6 hours for Function 2 and (b) for to 6 hours
         . for Function 1 provided the associat Function maintains RCIC initi tion capability.
  • SURVEILLANCE FREQUENCY 24 hours SR 3.3.5.2..... 92 days SR 3.3.5.2: 24 months SR 3.3.5.2:'f Perform LOGIC SYSTEM FUNCTIONAL 24 months TEST.

BFN-UNIT3 3.3--51 Amendment No. 246 MOV 3 g =199B

RCIC System Instrumentation 3.3.5. Table 3.3.5.~ Reactor Core Isolation Coo 1 CONDITIONS REQUIRED REFERENCED ALLOWABLE FUNCTION CHANNELS PER FROM REQUIRED VALUE FUNCTION ACTIONA.1

1. Reactor Vessel Water Level - 4 B Low Low, Level 2(a)
2. Reactor Vessel Water Level - 2 C High, Level 8 (a) During instrument calibrations, It the As Found channel setpolnt Is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shaD be an Initial determination to ensure confidence that the channel can perform as required before returning the channel to service In accordance with the Surveillance. If the As Found Instrument channel setpolnt is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. * *
  • Prior to returning a channel to service, the Instrument chamel setpoinl shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared Inoperable.

The nominal Trip Setpoinl shall be specified on design output documentation which Is incorporated by reference In the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoinl, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpolnl design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report BFN-.UNIT 3 3.3-52 Amendment No.~ r54

Primary Containment Isolation Instrumentation 

                                         -                                3.3.6 .1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. As required by Required H.1 Declare standby liquid 1 hour Action C.1 and .,.control system (SLC) referenced in inoperable. Table 3.3.6.1-1. OR H.2 Isolate the Reactor Water 1 hour Cleanup System. I. As required by Required 1.1 Initiate action to restore Immediately Action C.1 and channel to OPERABLE referenced in status. Table 3.3.6.1-1 . GR 

                           ~      IRitiate eetioA to isolate   Immediately U:ie Resieh::1al Heat Removal (RHR)

Shu1down Cooling System. BFN-UNIT 3 3.3-57 Amendment No. 24-3 SEP 9 3 1998

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 3) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTION C.1

5. Reactor Water Cleanup (RWCU) System Isolation
a. Main Steam Valve Vault 1,2.3 2 F SR 3.3.6.1.2 s 201'F Area Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
b. Pipe Trench Area 1,2,3 2 F SR 3.3.6.1.2 s 135'F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
c. Pump Room A Area 1,2,3 2 F SR 3.3.6.1.2 s 152'F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
d. Pump Room B Area 1,2.3 2 F SR 3.3.6.1.2 s 152'F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
e. Heat Exchanger Room 1,2.3 2 F SR 3.3.6.12 s 143'F Area (West Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6 .1.6
f. Heat Exchanger Room 1,2,3 2 F SR 3.3.6.1.2 s 170'F Area (East Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6.1.6
g. SLC System Initiation 1,2,3 1(a) H SR 3.3.6.1.6 NA
h. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 ~ 528 inches Level - Low, Level 3 SR 3.3.6.1.2 above vessel SR 3.3.6.1.5 zero SR 3.3.6.1.6
6. Shutdown Cooling System Isolation
a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.2 s 115 psig Pressure - High SR 3.3.6.1.5 SR 3.3.6.16
b. Reactor Vessel Water 3, ' 2fbt SR 3.3.6.1.1 ~ 528 inches Level - Low, Level3 SR 3.3.6.1 .2 above vessel SR 3.3.6.1.5 zero SR 3.3.6.1.6 C. Drywell Pressure - High 1,2,3 2 F SR 3.3.6.1 .2 s 2.5 psig SR 3.3.6.1.5 SR 3.3.6.1.6 (a) One SLC System Initiation signal provides logic input to close both RWCU valves.

(b) . lefl'l reei t:1iFe d jr, M09ES 4 8A8 6 WReR Rl-1R SRl:llaewA CeeliAg SysleFA iAlegFily maiAIBiAea . BFN-UNIT 3 3.3-61 Amendment No. ~ . ~ . 249, 2,Je, ~ . t+1-

Secondary Containment Isolation Instrumentation 3.3.6.2 ~ - Table 3.3.8.2-1 (page 1 af 1) Secondary Containment lsalatlcn lns1rumentatlan APPLICABLE MODES OR REQUIRED FUNCTION OTHER CHANNELS SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIREMENTS VALUE CONDmONS TRIP SYSTEM

1. Reader Vessel Waler Level
  • 1,2,3, 2 SR 3.3.S.2.1 2: 528 n:hes eboJe loiN,LMl3 SR 3.3.8.2.2 vessel zem
  • SR 3.3.6.2.3 SR 3.3.6.2.4
2. DryweD Press~re
  • High 1,2,3 2 SR 3.3.8.2.2 ~ 2.5 pslg SR 3.3.8.2.3 SR 3.3.8.2.4
3. Rader Zais Exhaust 1.2.3. ~ 100mRnlr Raclatlan - High {er
    "'* Rablng Fm Exhaust              1,2,3,                     1            SR   3.3.6.2.1 Radlallar, - High               -(er                                   SR   3.3.6.2.2 SR   3.3.6.2.3 SR   ~.3.U.4 BFN-UNIT3                                                          Amendment No. 212, 213,-248, 249

CREV System Instrumentation 3.3.7.1 

 ~

Table 3.3.7.1-1 (page 1 of 1) Control Room Emergency Venll!allon System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTIONA.1

1. Reac::IDr Vessel Watar Liver
  • 1,2,3;{ar 2 B SR 3.3.7.1.1 l!:52Blnches l.aN, Level 3 SR 3.3.7.1.2 abavewssel SR 3.3.7.1.5 zaro SR 3.3.7.1.6
2. Drywel Pressin
  • High 1.2,3 2 a SR 3.3.7.1.2 :S2.5pslg SR 3.3.7.1.5 SR 3.3.7.1.8
3. Reaclcr Zale Exhaust 1.2.3 1 C SR 3.3.7.1.1 :S 100mR/hr Radla1lon- High -(er SR 3.3.7.1.2 SR 3.3.7.1.:S SR 3.3.7.1.8
        .c. Refuelng Floer Exhaust                                                                 SR 3.3.7.1.1  S100mRJhr Radlatlcn - High                                                                       SR 3.3.7.1.2 SR 3.3.7.1.5 SR  3.3.7.1 .6
5. Ccrnrol Roan Alt ~ply Duct 1,2,3, SR 3.3.7.1.1 :S270cpm Radiation - High f*' SR 3.3.7.1.2 above
 ~   :                                                                                            SR  3.3.7.1.3  background SR  3.3.7.1.4 BFN-UNIT 3                                               3.3-70            Amendment No. 212,213,248, ~

RPV WATER INVENTORY ECCS - Operating 3 51 CONTROL, * * \.._....,* 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 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 pressures 150 psig. ACTIONS 

                              *~ ----~-------NOTE-------*---------~--------

LCO 3.0.4.b is not applicable to HPCI. I 

  '-..__../

CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7days injection/spray subsystem ECCS Injection/spray inoperable. subsystem(s) to OPERABLE status. OR One low pressure coolant injection (LPCI) pump In both LPCI subsystems inoperable. (continued) BFN-UNIT3 3.5-1 Amendment No. 212,229, 244 

                              , RPV WATER INVENTORY                                    ECCS Shutdo'i."JA
  • CONTROL , '3.5.2 RPV Water Inventory Control 3.5 EMERGENCY CORE COOLING SYSTEMS (ECC AND REACTOR CORE
  • ~ ISOLATION COOLING (RCIC) SYSTEM 3.5.2 ECCS - Sh~down ~--1Reactor Pressure Vessel (RPV)

Water Inventory Control 7 Twe low pressure ECCS injection/spray subsystems shatl be 71 

                          /      OPERABLE.
                      !One!             [ID                                             Relocation from
                                       'k                                               SR 3.5.2.3 APPLICABILITY:           MODE 4, ~

MODE 5, e>Eoept with the spent fuel storage pool gates remove~ and water level c?: 22 ft o-~er the top of the reamor pressure 

                                       ,iessel flenge.

ACTIONS R CONDITION REQUIRED ACTION COMPLETION TIME Initiate A~ .vquired ECCS A.1 Restore required ECCS 4 hours action to injedion/spray subsystem injection/spray subsystem establish a inoperable. to OPERABLE status. method of water injection B. Required Action and B.1 Initiate action to st1spend Immediately 

                                                                              /                       capable of associated Completion                 OPDRV-s.                 "                       operating Time of Condition A not met.                                                                                   without offsite electrical C. Two reEJuired EGGS             G;4     lniti8*e amion to suspend        Immediately     power.

iAjeslion!spray OPDFWs. subsystems inoperable. AN9 

            /

G;2 Restore one EGGS 4 ho~rs injeslion!spFay s~t3system to OPERABbE statl;ls. (continued) 

  ~l.n;~~  _\j BFN-UNIT3                                     3.5-8                         Amendment No. 242 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be ~ 36 hours.

                                       !RPV Water Inventory Control   1-j--> ECCS
  • Shutdown
  • 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. ReE1uired AelioR G.2 eRd 9:4 Initiate aetiaR te FesteFe Immediately associated GompletieR seeeRdaF)<eeAtaiRment to Time not met OPERABLE status. AN9 

                                         ~    IRitiate aetieR to FesteFe    Immediately twe staRdey gas tfeatmem st.it.systems to OPERABLE statt.is.

Mm M Initiate aetieR te Festere Immediately 

                      )1',                    isolation eapaeility in eaef:I Fequi_ ree seeendaF)'

eemeinmeAt penetFatieR flew path net isolated: I 

                  ~ ln,sert'2'-~

BFN-UNIT3 3.5-9 Amendment No. 2-12 

                        !RPV Water Inventory Control    -I--)-+ eCCS    Shutdown
  • 3.5.2 SURVEILLANCE REQUIREMENTS FREQUENCY SR 3.5.2. t-\ Verify, for eaeh- required ECCS injection/spray subsystem, the suppression pool water level.is :2: ~.25 inches with or 12 hours
              -7 .25 inches without differential pressure control.                         the Verify, for         quired ECCS                   31 days injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve.

SR 3.5.2. ~~~~~~-NOTE~~~~~~ One LPCI subsystem may be considered OPE during alignment and operation _ _ _ _ _ __,, for decay hea oval if capable of being manually realigned ot otherwise inoperable. A Low Pressure Coolant Injection (LPCI) Ve required ECCS injection/spray 31 days subsystem anual, power operated, and automatic Ive in the flow path, that is not locked, scale , or otherwise secured in position, is in correct position. (continued) BFN-UNIT3 3.5-10 Amendment No. ~ 

                        !RPV Water Inventory Control             1--!-->7  ECCS   c Shutdowr, 3.5 .2 SURVE ILLANCE REQUIREMENTS continued SURVEILLANCE                                           FREQUENCY SR 3.6.2.41    V-erify each re~uired EGGS pufflp de*/eleps                 IA accordaAce the specified flm*.* Fate against a system head             with the cerrespondiAg to the specified pressure .                   INSE~VIGE TESTING PROGRAM SYSTEM MEAD CORRESPONDING Te A VESSEi: TO roffiJS Ne:-er- DIFFERENTIAL SYSTEM      Fl:GWRA=FE       PHMPS   PRESSURE OF es          ~gl:)ffl            2    J! 105 r,sid IND1C/\TE9 NQ-GF   SYSTEM SYSTEM FceW:flA!E            PUMPS   PRESSURE l::PG1      ? 9,000 gr,,m      -+

SR 3.5.2 .e --~------~---~--~-----N()l"E:------------------~--~- 

           \

Vessel injection/spray may be excluded. Verify required ECCS injection/spray 24 months subsystem aotuates OR aA actual ef simulated autor:natis initiatioA sigAal. can be manually operated . BFN-UNIT 3 3.5-11 Amendment No. 2:-t-a, i..g..s.

TS 3.5.2 Inserts Insert 1 TS 3.5.2 Page 3.5-8 C. DRAIN TIME C. 1 Verify secondary containment 4 hours 

      < 36 hours and       boundary is capable of being
      ~ 8 hours.           established in less than the DRAIN TIME.

AND C.2 Verify each secondary containment 4 hours penetration flow path is capable of being isolated in less than the DRAIN TIME. AND C.3 Verify two standby gas treatment 4 hours subsystems are capable of being placed in operation in less than the DRAIN TIME.

Insert 2 TS 3.5.2 Page 3.5-9 D. DRAIN TIME < 8 hours. D.1 ----------- NO TE --------------- Required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power. Initiate action to establish an additional Immediately method of water injection with water sources capable of maintaining RPV water level > TAF for 2: 36 hours. AND 0 .2 Initiate action to establish secondary Immediately containment boundary. AND 0 .3 Initiate action to isolate each secondary Immediately containment penetration flow path or verify it can be automatically or manually isolated from the control room . AND 0.4 Initiate action to verify two standby gas Immediately treatment subsystems are capable of being placed in operation. E. Required Action and E.1 Initiate action to restore DRAIN TIME Immediately associated Completion to 2: 36 hours. Time of Condition C or D not met. OR DRAIN TIME < 1 hour.

Insert 3 TS 3.5.2 Page 3.5-10 SR 3.5.2.1 Verify DRAIN TIME ;:: 36 hours. 12 hours Insert 4 TS 3.5.2 Page 3.5-11 SR 3.5.2.5 Operate the required ECCS injection/spray 92 days subsystem through the test return line for 

                    ;:: 10 minutes.

SR 3.5.2.6 Verify each valve credited for automatically 24 months isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal. 

                                     , RPV WATER INVENTORY               RCIC System CONTROL,                                   3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC} SYSTEM 3.5.3 RCIC System LCO 3.5.3           The RCIC System shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig. ACTIONS LCO 3.0.4.b Is not applicable to RCIC. CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable. A.1 Verify by administrative Immediately means High Pressure Coolant Injection System is OPERABLE. ANO A.2 Restore RCIC System to 14 days OPERABLE status. B. Required Action and B.1 Be in M0DE3. 12 hours associated Completion . Time not met AND B.2 Reduce reactor steam 36 hours dome pressure to 

                                         ~ 150 psig.

BFN-UNIT3 3.5-12 Amendment No.-242, 244

PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs) LCO 3.6.1.3 Each PCIV, except rea'ctor building-to-suppression chamber vacuum breakers, shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3~ ~ 

                    ¥/her, esseeieted iAstrumemet10A 1s required to be OPERABLE per LCO 3.3.6.1, "Primary CooteiAmem lsolatioA IAstrumeAtation."

Relocated text from Page 3.6-10

  • ~

BFN-UNIT3 3.6-9 Amendment No. 2-

PCIVs 3.6.1.3 ACTIONS 

          ~~~~~~~~~~~~~~NOTES.~~~~~~~~~~~~~
1. Penetration flow paths except for 18 and 20 inch purge valve 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 PCIVs.
4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment," when PCIV leakage results in exceeding overall containment leakage rate acceptance aiteria in MODES 1, 2, and 3.

IACTIONSI CONDITION REQUIRED ACTION COMPLETION TIME A NOTE A1 Isolate the affected . 4 hours except for Only applicable to penetration flow path by main steam line penetration flow paths use of at least one closed \.._, with two PCIVs.

  • and de-activated AND automatic valve, closed manual valve, blind 8 hours for main One or more penetration flange, or check valve steam line flow paths with one PCIV with flow through the inoperable except due to valve secured.

MSIV leakage not within limits. AND (continued) BFN-UNIT3 3.6-10 Amendment No. ~

PCl\/s 3.6.1.3 ACTIONS Ccontinued) CONDITION REQUIRED ACTION COMPLETION TIME

0. One or more penetration D.1 Restore leakage rate to 4 hours flow paths with MSIV within limit leakage not within limits.

E. Required Action and

  • E.1 Bein MODE 3. 12 hours associated Completion Time of Condition A, e; C, ~

or D not met in MODE 1, 2, 8F3. E.2 Be in MODE 4. 36 hours F. Reqt;tireEt Aetien anEt F;4 Initiate*aetieA to st.tspend Immediately esseeiateEt GempletieA epeFetiens wlitA e 

   +i~e ef. GeAEtitieA A:, B, 6 ,      r:,eteAtiel feF dFBining the eF 9 Aet met feF PGW(s)            reeeteF vessel (OPDR¥s).

req1;tired te he OPERABLE during OR MC9 E 4eF 6. F;2 NOlE Only applieal::>le feF inoperable RHR Shutda,m Cooling 

                                      ,..,telves.

Initiate eetien to restere Immediately vel*,e(s) to OPERABLE st8tt1S. BFN-UNIT3 3.6-13 Amendment No. 2

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3;- DuriAg operations with a potential for ElralniRg the reactor \lessel (OPDRVs). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours Inoperable in MODE 1, 2, containment to or-a-. OPERABLE status. B. Required Action and B.1 Bein MODE 3. 12 hours associated Completion Time of Condition A not AND met. 8.2 Bein M0DE4. 36 hours 

                                            )'/\                              (continued) fD~ubl~' ~nderli'n~ ' 1 I.  ..        I. " I.

BFN-UNIT 3 3.6-44 Amendment No. m, ~

Delete information on this Secondary Containment 3.6.4 .1 page and insert "This page intentionally left blank." ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME

e. Seconder, eonteinmeAI C.1 Initiate ection to st1spend lmmeaietoly Inoperable auFing OPDRVs.

9PBRVs. BFN-UNIT 3 3.6-45 Amendment No. 2-1-2, ~

SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) LCO 3.6.4.2 Each SCIV shall be OPERABLE. APPLICABILITY: MODES 1, 21 and 3, During eperatieAs 't'.Pith a peteAtial for dFelning the reaotor vessel (OPDRVs). ACTIONS

----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 REQUIRED ACTION COMPLETION TIME A One or more penetration A.1 Isolate the affected 8 hours flow paths with one SCIV penetration flow path by inoperable. use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. (continued) 8FN-UNIT3 3.6-47 Amendment No. ~ . 249-

SClVs 3.6.4.2 ACTIONS

  • CONDITION REQUIRED ACTION COMPLETION TIME A (continued) A2 NOTE Isolation devices in high radiation areas may be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow path is isolated. B. NOTE 8.1 Isolate the affected 4 hours Only applicable to penetration flow path by penetration flow paths use of at feast one closed with two isolation valves. and de-activated automatic valve, closed manual valve, or blind One or more penetration flange. flow paths with two SCIVs inoperable. C. Required Action and C.1 Bein MOOE 3. 12 hours associated Completion Time of Condition A or B AND not met in MODE 1, 2, or

5. C.2 Bein MODE 4. 36 hours (continued) fD~~bl~ 'undeli~e , 1 I. I. I. I,.

BFN-UNIT3 3.6-48 Amendment No. ~

Delete information on this SCIVs page and insert "This page 3.6.4.2 intentionally left blank." ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and 0 .1 Initiate aetion to suspend lmme~iately associated Completion OPDRVs. Time of Conditio, 1 A o, B r.et met duriRg OPDRVs. BFN-UNIT 3 3.6-49 Amendment No. a.P-, ~

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Three SGT subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3, During operations with a potential for dreir,lng the reseter -..essel {OPDRVs). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem 7 days Inoperable. to OPERABLE status. B. Required Action and B.1 Bein M0DE3. 12 hours associated Completion Time of Condition A not AND met i,1 M6BE 1, 2, 01 ""3. B.2 Bein MODE 4. 36 hours l'I'- (ccntinued)

Relocate remaining row ..
                                       >- from Page 3.6-52                        .

I. I. I. I,_ I. I. I. I. I. I. I. I. I 

~ -

BFN-UNIT 3 3.6-51 Amendment No. a:t-a, 248--

Relocate remaining row to Page 3.6-51 and insert "This SGT System page intentionally left blank." 3.6.4.3 ACTIONS continued CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and ~ Place lvJo OPERABLE Immediately associated Completion SGT subsystems In Time of Condition A not operation. met during OPDRVs. 

                                 ~     Initiate action to suspoRd  Immediately OPDRVs.

fr. Two or three SGT -G; 1 Enter LCO 3.0.3. Immediately ubsystems lnoperable-ift. (contiRued) BFN-UNIT 3 3.6-52 Amendment No. ~ . 249

Delete information on this page and insert "This page SGT System intentionally left blank." 3.6.4.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. Two er three SGT E.-1 Initiate aolion to suspend Immediately subsystems IAopeFSble OPDRVs. during OPDR\ls. I 3.6-53 Amendment No. m. -249-BFN-UNIT 3

CREV System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency Ventilation (CREV) System LCO 3 .7.3 Two CREV subsystems shall be OPERABLE. 

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

The main control room envelope (CRE) boundary may be opened intermittently under administrative control. APPLICABILITY: MODES 1, 2, and 3, duFiR§ eperatioRs wUR a poteRtial fer EtFSining the reactor ~essel (OPDRVs). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREV subsystem A.1 Restore CREV subsystem 7days inoperable for reasons to OPERABLE status. other than Condition B, C, orD. B. One or more CREV B.1 Initiate actions to Immediately subsystems inoperable implement mitigating due to inoperable CRE actions. boundary in MOOE t, 2, 

    ~ .                            AND B.2     Verify mitigating actions   24 hours ensure CRE occupant exposures to radiological hazards will not exceed limits, and verify the CRE ocrupants are protected from smoke and chemical hazards.

AND B.3 Restore CRE boundary to 90days OPERABLE status. (continued) BFN-UNIT3 3.7-9 Amendment No.~. ~ . ~ . 267

CREV System 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Two CREV subsystems C.1 Restore HEPA filter and 7days inoperable due to one charcoal adsorber to inoperable High Efficiency OPERABLE status. Particulate Air (HEPA) filter or charcoal adsorbers which do not impact ability of CREV subsystems to meet flowrate requirements specified in the Ventllatlon Filter Testing Program (VFTP). D. One CREV subsystem D.1 Restore charcoal 14 days inoperable due to adsofber to OPERABLE inoperable charcoal status. adsorber which does not impact the ability of CREV subsystem to meet flowrate requirements specified in the VFTP. E. Required Action and E.1 Bein MODE 3. 12 hours associated Completion Time of Condition A. B, C, AND or D not met iA MODE 1, 2, 81'-3. E.2 Bein MODE 4. 36 hours (continued~ Relocate remaining row from next page 

                                                 ~

BFN-UNIT3 3.7-L ' Amendment No. 244, ~ . 2e,:1., 267

Relocate remaining row to previous page and delete this page CREV System 3.7.3 ACTIONS continued CONDITION REQUIRED ACTION COMPLETION TIME F. Required AetiOA aAd FA Place OPERABLE GREV lmmeaiatety. associated Completion suesystem in Time of Cendilion A or D press1:1rw3tion mode. not met during OPDRVs. F.2 Initiate BGtion to suspend Immediately OPDR'Js. &. Two CREV subsystems 6 .1 Enter LCO 3.0.3. Immediately 

  . operable in MODE 1, 2, or reasons other than     dition B 9r C.

(oominued) Double underline BFN-UNIT3 3.7-10 Amendment No. ~ . 244, 249, 261

Delete information on this page and insert "This page CREV System intentionally left blank." 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME H. Required AetioA eAd M-A Initiate action to suspeAd Immediately assooiated Completion OPORVs. Time of Condition C not met during OPDRVs. Tv,o GREV subsystems inopemble duFiAg OPDRVs for reesens other tl'len GoAditioA C. OR One or more GREV subsystems inoJ]8Fable due 10 an iAOperable CR& Boundary dufiAg OPORVs. BFN-UNIT 3 3.7-11 Amendment No. ~ .~ .~ . 267

Control Room AC System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Control Room Air Conditioning (AC) System LCO 3. 7 .4 Two Unit 3 control*.*.room AC subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS. Durir,g eperetier,s with e patent-isl fer dreir1ir1g the reecior ttessel (OPDR\ls). ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Unit 3 control room A. 1 Restore Unit 3 control 30 days 

~       **      AC subsystem                          room AC subsystem to inoperable.                          OPERABLE status.

(continued) \'-..., * . Amendment No. 1 BFN-UNIT3 3.7-13 6EP 8 6 199B

Control Room AC System 3.7.4 ACTIONS continued CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action end 0.1 ~- N~~~~ associated Completion LCO 3.0.3 is not Time of Condition A or B applicable. not met during movement of irradiated fuel assemblies in the Place OPERABLE control Immediately secondary containment1 room AC subsystem in during CORE operation. ALTERATIONS, sr dwring OPOR>.<s. QB D.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment. AND D.2.2 Suspend CORE Immediately ALTERATIONS. 0 .2.3 Initiate eetion to suspend ~mmediately OPDRVs. BFN-UNIT3 3.7-15 Amem ent No. .au-- 0 g 1998

AC Sources - Shutdown 

                                                                                        ' 3.8.2 ACTIONS

\ ....../ CONDITION REQUIRED ACTION COMPLETION TIME A (continued) A:2-:3 IAiliate aelieA te s1:1speAEI Immediately eperatioRs with a patemial feF EiFaiAiAg the reamer vessel (OPDRl.Js). A-NB A2.4- Initiate adion to restore Immediately required offsite power circuit to OPERABLE status. B. One or more required Suspend CORE Immediately Unit 3 DGs inoperable. ALTERATIONS. 8 .+.2 Suspend movement of Immediately irradiated fuel assemblies in secondary containment Initiate aeUoR to s1:1speAEI Immediately OPOR\ls. Initiate action to restore Immediately required Unit 3 DGs to OPERABLE status. (continued) BFN-UNIT3 3.8-16 Amendment No. 2-1-2

AC Sources - Shutdown

  • 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 ------------------------NOTE------------------------

The following SRs are not required to be performed: SR 3.8.1.2, SR 3.8.1.5, SR 3.8.1.7, ~ R 3.8.1.8, eAd SR a.8.1.9 . 

                       .     ~

For Unit 3 ~ ources required to be In accordance OPERABLE, the SRs of Specification 3.8.1 with applicable are applicable. SRs I~ SR 3.8.2.2 For the requiri ~d Unit 1 and 2 DG, the SRs of In accordance Unit 1 and 21 echnical Specifications are with applicable applicable. SRs I, except SR 3.8 .1.6 and SR 3.8.1.9 I BFN-UNIT3 3.8-18 Amendment No. 242

DC Sources - Shutdown 

                                                                        ' 3.8.5 ACTIONS .

CONDITION REQUIRED ACTION COMPLETION TIME A. ( continued) A:2:-3 Initiate eotioA to suspend Immediately opeFations -.vith a potential for draining the i:eaotor vessel. A.l2.4- Initiate action to restore Immediately required DC electrical power subsystems or 3 systems to OPERABLE status.

  • BFN-UNIT3 . 3.8-27 Amendment No.~

Distribution Systems - Shutdown

  • 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ( continued) ~ lnftiate aeUon to suspend Immediately opeFOtions with a potential for draining the reactor \Jessel.

A.2. Initiate actions to restore Immediately required AC and DC electrical power 3 distribution subsystems to OPERABLE status. Declare associated Immediately required shutdown cooling subsystem(s) \_,,** inoperable and not in operation. BFN-UNIT3 3.8-40 Amendment No. ~

Attachment 5 to CNL-19-010 Revised Technical Specification Pages (Unit 1 Clean) (52 total pages) CNL-19-010

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS Section Page No. 1.0 USE AND APPLICATION .................................................................. 1.1-1 .r 1.1 Definitions ................................................................................. 1.1-1 1.2 Logical Connectors ..................................................................... 1.2-1 1.3 Completion Times ............................................. ;......................... 1.3-1 1.4 Frequency .................................................................................. 1.4-1 2.0 SAFETY LIMITS (SLs) .......................................................................2.0-1 2.1 SLs .............................................................................................2.0-1 2.2 SL Violations -..............................................................................2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY ........................................................................ 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ................. 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS .......................................... 3.1-1 3.1.1 SHUTDOWN MARGIN (SOM) ..............................................3.1-1 3.1.2 Reactivity Anomalies .............................................................3.1-5 3.1.3 Control Rod OPERABILITY ..................................................3.1-7 3.1.4 Control Rod Scram Times .................................................... 3.1-12 3.1.5 Control Rod Scram Accumulators ........................................ 3.1-16 3.1.6 Rod Pattern Control ................... *........................................... 3.1-20 3.1.7 Standby Liquid Control (SLC) System ................................. 3.1-23 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves ..... 3.1-28 3.2 POWER DISTRIBUTION LIMITS .............................................. 3.2-1 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) .............................................................3.2-1 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) .................... 3.2-3 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) ...................... 3.2-5 (continued) BFN-UNIT 1 Amendment No. 234,262,

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Section Page No. 3.3 INSTRUMENTATION ................................................................. 3.3-1 3.3.1.1 Reactor Protection System (RPS) Instrumentation ............... 3.3-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation ..................... 3.3-9 3.3.2.1 Control Rod Block Instrumentation ....................................... 3.3-15 3.3.2.2 Feedwater and Main Turbine High Water Level Trip Instrumentation ......................................................... 3.3-21 3.3.3.1 Post Accident Monitoring (PAM) lnstrumentation .................. 3.3-23 3.3.3.2 Backup Control System ........................................................ 3.3-27 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation ................................................................ 3.3-29 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation ........................ 3.3-32 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation ................................................................ 3.3-35 3.3.5.2 Reactor Pressure Vessel (RVP) Water Inventory Control .............................................................................3.3-47a 3.3.5.3 Reactor Core Isolation Cooling (.RCIC) System Instrumentation ................................................................ 3.3-48 3.3.6.1 Primary Containment Isolation Instrumentation .................... 3.3-52 3.3.6.2 Secondary Containment Isolation lnstrumentation .. :............. 3.3-61 3.3.7.1 Control Room Emergency Ventilation (CREV) System Instrumentation ................................................... 3.3-65 3.3.8.1 Loss of Power (LOP) Instrumentation ................................... 3.3-70 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ........................................................................ 3.3-75 3.4 REACTOR COOLANT SYSTEM (RCS) ..................................... 3.4-1 3.4.1 Recirculation Loops Operating .............................................. 3.4-1 3.4.2 Jet Pumps ............................................................................. 3.4-5 3.4.3 Safety/Relief Valves (S/RVs) ................................................ 3.4-7 3.4.4 RCS Operational LEAKAGE ................................................. 3.4-9 3.4.5 RCS Leakage Detection Instrumentation .............................. 3.4-12 3.4.6 RCS Specific Activity ............................................................ 3.4-15 3.4.7 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown ................................................... 3.4-18 (continued) BFN-UNIT 1 ii Amendment No. ~

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Section Page No. 3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown .................................................3.4-21 3.4.9 RCS Pressure and Temperature (PIT) Limits ....................... 3.4-24 3.4.10 Reactor Steam Dome Pressure ............... ,............................ 3.4-30 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM ..........................................................................3.5-1 3.5.1 ECCS - Operating .................................................................3.5-1 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control ..... 3.5-8 3.5.3 RCIC System ........................................................................3.5-12 3.6 CONTAINMENT SYSTEMS .......................................................3.6-1 3.6.1.1 Primary Containment ............................................................3.6-1 3.6.1.2 Primary Containment Air Lock ............................................. 3.6-3 3.6.1.3 Primary Containment Isolation Valves (PCIVs) .................... 3.6-9 3.6.1.4 Drywall Air Temperature .......................................................3.6-17 3.6.1.5 Reactor Building-to-Suppression Chamber Vacuum Breakers ..........................................................................3.6-19 3.6.1.6 Suppression Chamber-to-Drywall Vacuum Breakers ........... 3.6-22 3.6.2.1 Suppression Pool Average Temperature ............................. 3.6-24 3.6.2.2 Suppression Pool Water Level. .............................................3.6-29 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling ....................................................................3.6-31 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray ............... ,.......................................................3.6-34 3.6.2.5 Residual Heat Removal (RHR) Drywall Spray ..................... 3.6-36 3.6.2.6 Drywall-to-Suppression Chamber Differential Pressure ....... 3.6-38 3.6.3.1 Containment Atmosphere Dilution (CAD) System ................ 3.6-40

  • 3.6.3.2 Primary Containment Oxygen Concentration ....................... 3.6-42 3.6.4.1 Secondary Containment .......................................................3.6-44 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) ............... 3.6-47
  • 3.6.4.3 Standby Gas Treatment (SGT) System ................................ 3.6-51 (continued)

BFN-UNIT 1 iii Amendment No. ~ .

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Section Page No. 3.7 PLANT SYSTEMS ......................................................................3.7-1 3.7.1 Residual Heat Removal Service Water (RHRSW) System .............................................................................3.7-1 3.7.2 Emergency Equipment Cooling Water (EECW) System and Ultimate Heat Sink (UHS) ............................ 3.7-6 3.7.3 Control Room Emergency Ventilation (GREV) System ......... 3. 7-8 3.7.4 Control Room Air Conditioning (AC) System ........................ 3.7-12 3.7.5 Main Turbine Bypass System ............................................... 3.7-16 3.7.6 Spent Fuel Storage Pool Water Level.. ................................. 3.7-18 3.8 ELECTRICAL POWER SYSTEMS ............................................. 3.8-1 3.8.1 AC Sources - Operating ........................................................ 3.8-1 3.8.2 AC Sources - Shutdown ........................................................ 3.8-14* 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ............................ 3.8-19 3.8.4 DC Sources - Operating ........................................................ 3.8-22 3.8.5 DC Sources - Shutdown ................................... ,................... 3.8-26 3.8.6 Battery Cell Parameters ........................................................ 3.8-29 3.8.7 Distribution Systems - Operating .......................................... 3.8-33 3.8.8 Distribution Systems - Shutdown ................................. :........ 3.8-39 3.9 REFUELING OPERATIONS ...................................................... 3.9-1

5.9.1 Refueling Equipment Interlocks ............................................ 3 ..9-1 3.9.2 Refuel Position One-Rod-Out lnterlock ................................. 3.9-3 3.9.3 Control Rod Position ............................................................. 3.9-5 3.9.4 Control Rod Position Indication ............................................. 3.9-7 3.9.5 Control Rod OPERABILITY - Refueling ................................ 3.9-10 3.9.6 Reactor Pressure Vessel (RPV) Water Level ....................... 3.9-12 3.9.7 Residual Heat Removal (RHR) - High Water Level .............. 3.9-14 3.9.8 Residual Heat Removal (RHR) - Low Water Level ............... 3.9-18 3.9.9 Decay Heat ...........................................................................3.9-22 (continued)

BFN-UNIT 1 iv Amendment No. ~ .

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Section Page No. 3.10 SPECIAL OPERATIONS ............................................................3.10-1 3.10.1 lnservice Leak and Hydrostatic Testing Operation ............... 3.10-1 3.10.2 Reactor Mode Switch Interlock Testing ................................. 3.10-4 3.10.3 Single Control Rod Withdrawal - Hot Shutdown ................... 3.10-7 3.10.4 Single Control Rod Withdrawal - Cold Shutdown .................. 3.10-10 3.10.5 Single Control Rod Drive (CRD) Removal - Refueling .......... 3.10-14 3.10.6 Multiple Control Rod Withdrawal - Refueling ........................ 3.10-17 3.10.7 Control Rod Testing - Operating ........................................... 3.10-20 3.10.8 SHUTDOWN MARGIN (SOM) Test - Refueling .................... 3.10-22 4.0 DESIGN FEATURES .................................................................... ;.... 4.0-1 4.1 Site Location ..............................................................................4.0-1 4.2 Reactor Core ..............................................................................4.0-1 4.3 Fuel Storage ...............................................................................4.0-2 5.0 ADMINISTRATIVE CONTROLS ........................................................5.0-1 5.1 Responsibility .............................................................................5.0-1 5.2 Organization ...............................................................................5.0-2 5.3 Unit Staff Qualifications ..............................................................5.0-6 5.4 Procedures .................................................................................5.0-7 5.5 Programs and Manuals ............................................................. ,5.0-8 5.6 Reporting Requirements ........................................................... 5.0-22 5.7 High Radiation Area ...................................................................5.0-26 BFN-UNIT 1 V Amendment No.

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF TABLES Page No. Table 1.1-1 ......................................................................................................... 1.1-9 Table 3.1.4-1 ...................................................................................................... 3.1-15 Table 3.3.1.1-1 ................................................................................................... 3.3-6 Table 3.3.1.2-1 ...................................................................................................3.3-14. Table 3.3.2.1-1 ...................................................................................................3.3-20 Table 3.3.3.1-1 ...................................................................................................3.3-26 Table 3.3.5.1-1 ...................................................................................................3.3-42 Table 3.3.5.2-1 ...................................................................................................3.3-47c Table 3.3.5.3-1 ...................................................................................................3.3-51 Table 3.3.6.1-1 ...................................................................................................3.3-58 Table 3.3.6.2-1 ...................................................................................................3.3-64 Table 3.3.7.1-1 ...................................................................................................3.3-69 Table 3.3.8.1-1 ...................................................................................................3.3-74 Table 3.8.6-1 ...................................................................................................... 3.8-32 BFN-UNIT 1 vi Amendment No.

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF FIGURES-Figure Page No. Figure 3.1. 7-1 .....................................................................................................3.1-27 Figure 3.4.1-1 .....................................................................................................3.4-4 Figure 3.4.9-1 .....................................................................................................3.4-29/29b Figure 3.4.9-2 .................................................................................................... 3.4-29a/29c BFN-UNIT 1 vii Amendment No.

Definitions 1.1 1.1 Definitions (continued) CORE OPERATING LIMITS The COLR is the unit specific document that provides

  • REPORT (COLR) cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of 1-131, 1-132, 1-133, 1-134, and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in Table Ill of TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites." DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a. The water inventory above the TAF is divided by the limiting drain rate;
b. The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the T AF except:
1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths; (continued)

BFN-UNIT 1 1.1-3 Amendment No. ~ . ~ .

Definitions 1.1 1.1 Definitions (continued) DRAIN TIME (continued) 2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or *

3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who is in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation devices without offsite power.
c. The penetration flow paths required to be evaluated per paragraph b are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory;
d. No additional draining events occur; and
e. Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value. INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f). (continued) BFN-UNIT 1 1.1-3a Amendment No.

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. As required by Required B.1 ------------NOTE------------ Action A.1 and referenced Only applicable for in Table 3.3.5.1-1. Functions 1.a, 1.b, 2.a, and 2.b. Declare supported ECCS 1 hour from feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND B.2 -------------NOTE------------ Only applicable for Functions 3.a and 3.b. Declare High Pressure 1 hour from Coolant Injection (HPCI) discovery of loss System inoperable. of HPCI initiation capability AND B.3 Place channel in trip. 24 hours (continued) BFN-UNIT 1 3_3:..35 Amendment No. ~ .

ECCS Instrumentation 3.3.5.1 ACTION'S (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Required C.1 ------------NOTE------------ Action A.1 and referenced Only applicable for in Table 3.3.5.1-1. Functions 1.c, 1.e, 2.c, 2.d, and 2.f. Declare supported ECCS 1 hour from feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND C.2 Restore channel to 24 hours OPERABLE status. D. As required by Required D.1 -------------NOTE------------ Action A.1 and referenced Only applicable if HPCI in Table 3.3.5.1-1. pump suction is not aligned to the suppression pool. Declare H PC I System 1 hour inoperable. (continued) BFN-UNIT 1 3.3-37 Amendment No. ~ .

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1 ------------NOTE------------ Action A.1 and referenced Only applicable for in Table 3.3.5.1-1. Function 1.d. Declare supported ECCS 1 hour from feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. subsystems in both divisions AND E.2 Restore channel to 7 days OPERABLE status. (continued) BFN-UNIT 1 3.3-38 Amendment No. ~ .

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA.1

1. Core Spray System
a. Reactor Vessel Water 1,2,3 B SR 3.3.5.1.1 <!: 398 inches Level - Low Low Low, SR 3.3.5.1.2 above vessel Level 1(e) SR 3.3.5.1.5 zero SR 3.3.5.1.6
                  )
b. Drywell Pressure - 1,2,3 B SR 3.3.5.1.2 ~ 2.5 psig High(e) SR 3.3.5.1.5 SR 3.3.5.1.6 C. Reactor Steam Dome 1,2,3 4(b) C SR 3.3.5.1.2 <!:435 psig Pressure - Low (Injection 2 per trip SR 3.3.5.1.4 and Permissive and ECCS system SR 3.3.5.1.6 ~465 psig lnitiation)(e)
d. Core _Spray Pump 1,2,3 2 E SR 3.3.5.1.2 <!: 1647gpm Discharge Flow - Low 1 per SR 3.3.5.1.5 and (Bypass) subsystem ~ 2910 gpm
e. Core Spray Pump Start -

Time Delay Relay Pumps A,B,C;D (with 1,2,3 4 C SR 3.3.5.1.5 <!: 6 seconds diesel power) 1 per pump SR 3.3.5.1.6 and 

                                                                                                                         ~ 8 seconds Pump A (with normal                 1,2,3                                C             SR 3.3.5.1.5           <!: 0 seconds    I power)                                                                                 SR 3.3.5.1.6           and
                                                                                                                         ~ 1 second Pump B (with normal                 1,2,3                                C             SR 3.3.5.1.5           <!: 6 seconds power)                                                                                 SR 3.3.5.1.6           and
                                                                                                                         ~ 8 seconds continued (a) Deleted.

(b) Channels affect Common Accident Signal Logic. Refer to LCO 3.8.1, "AC Sources - Operating." (e) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

  • Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable.

The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 1 3.3-42 Amendment No. ~ . 2§7,

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTION A.1

1. Core Spray System (continued)
e. Core Spray Pump Start -

Time Delay Relay (continued) Pump C (with normal power) 1,2,3 C SR 3.3.5.1.5  ;:,: 12 seconds SR 3.3.5.1.6 and

-:; 16 seconds Pump D (with normal power) 1,2,3 C SR 3.3.5.1.5  ;:,: 18 seconds SR 3.3.5.1.6 and
-:; 24 seconds
2. Low Pressure Coolant Injection (LPCI) System
a. Reactor Vessel Water 1,2,3 4 B SR 3.3.5.1.1  ;:,: 398 inches Level - Low Low Low, SR 3.3.5.1.2 above vessel Level 1(e) SR 3.3.5.1.5 zero SR 3.3.5.1.6
b. Drywell Pressure - High(e) 1,2,3 4 B SR 3.3.5.1.2  :-:; 2.5 psig SR 3.3.5.1.5 SR 3.3.5.1.6
c. Reactor Steam Dome 1,2,3 4 C SR 3.3.5.1.2  ;:,: 435 psig and Pressure - Low (Injection SR 3.3.5.1.4  :-:; 465 psig Permissive and ECCS SR 3.3.5.1.6 lnitiation)Ce)

I (continued~ (a) Deleted. (b) Deleted. (e) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 1 3.3-43 Amendment No. ~ . ~ .

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA.1

2. LPCI System (continued)
d. Reactor Steam Dome 4 C SR 3.3.5.1.2 ~215 psig Pressure - Low SR 3.3.5.1.4 and (Recirculation Discharge SR 3.3.5.1.6  :-,; 245 psig Valve Permissive)(e)
e. Reactor Vessel Water 1,2,3 2 B SR 3.3.5.1.1 ~ 312 5/16 Level - Level 0 1 per SR 3.3.5.1.2 inches above subsystem SR 3.3.5.1.5 vessel zero SR 3.3.5.1.6
f. Low Pressure Coolant Injection Pump Start - Time Delay Relay Pump A,B,C,D (with diesel 1,2,3 4 C SR 3.3.5.1.5 ~ 0 seconds power) SR 3.3.5.1.6 and
-;; 1 second Pump A (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ 0 seconds SR 3.3.5.1.6 and
-;; 1 second Pump B (with normal power) 1,2,3 C SR 3.3.5.1.5 ~6 seconds SR 3.3.5.1.6 and
-,; 8 seconds Pump C (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ 12 seconds SR 3.3.5.1.6 and
-, 16 seconds Pump D (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ 18 seconds SR 3.3.5.1.6 and
-,; 24 seconds (continued)

(a) Deleted. I (c) With associated recirculation pump discharge valve open. (e) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 1 3.3-44 Amendment No.~.~.~.

RPV Water Inventory Control Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control Instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE. APPLICABILITY: According to Table 3.3.5.2-1. ACTIONS

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

Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel. B. As required by Required 8.1 Declare associated Immediately Action A.1 and referenced penetration flow path(s) in Table 3.3.5.2-1. incapable of automatic isolation. AND 8.2 Calculate DRAIN TIME. Immediately C. As required by Required C.1 Place channel in trip. 1 hour Action A.1 and referenced in Table 3.3.5.2-1. (continued) I BFN-UNIT 1 3.3-47a Amendment No.

RPV Water Inventory Control Instrumentation 3.3.5.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. As required by Required D.1 Restore channel to 24 hours Action A.1 and referenced OPERABLE status. in Table 3.3.5.2-1. E. Required Action and E.1 Declare associated low Immediately associated Completion pressure Emergency Time of Condition C or D Core Cooling System not met. (ECCS) injection/spray subsystem inoperable. SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.5.2-1 to determine which SRs apply for each ECCS Function. SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. 24 hours SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. . 92 days BFN-UNIT 1 3.3-47b Amendment No.

RPV Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-t (page 1 of 1) RPV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE

1. Core Spray System
a. Reactor 4,5 1 per C SR 3.3.5.2.1 ~465 psig Steam Dome subsystem<a) SR 3.3.5.2.2 Pressure - Low (Injection Permissive)
b. Core Spray Pump 4,5 1 per D SR 3.3.5.2.2  :?: 1647 gpm Discharge Flow - subsystem<a) and Low (Bypass) ~ 2910 gpm
2. Low Pressure Coolant Injection (LPCI) System
a. Reactor Steam 4, 5 2 in one trip C SR 3.3.5.2.1 ~465 psig Dome Pressure - system<a) SR 3.3.5.2.2 Low (Injection Permissive)
3. Shutdown Cooling.

System Isolation

a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2.1  :?: 528 inches Water Level - Low, system SR 3.3.5.2.2 above vessel Level3 zero
4. Reactor Water Cleanup (RWCU) System Isolation
a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2.1  :?: 528 inches Water Level - Low, system SR 3.3.5.2.2 above vessel Level3 zero (a) Associated with an EGGS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel Water Inventory Control."

(b) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME. BFN-UNIT 1 3.3-47c Amendment No.

RCIC System Instrumentation 3.3.5.3 3.3 INSTRUMENTATION 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.3 The RCIC System instrumentation for each Function in Table 3.3.5.3-1 shall be OPERABLE. APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure> 150 psig. ACTIONS

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

Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.3-1 for the channel. B. As required by Required 8.1 Declare RCIC System 1 hour from Action A.1 and referenced inoperable. discovery of loss in Table 3.3.5.3-1. of RCIC initiation capability AND B.2 Place channel in trip. 24 hours (continued) BFN-UNIT 1 3.3-48 Amendment No. ~ .

RCIC System Instrumentation 3.3.5.3 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Required C.1 Restore channel to 24 hours Action A.1 and referenced OPERABLE status. in Table 3.3.5.3-1. D. Required Action and D.1 Declare RCIC System Immediately associated Completion inoperable. Time of Condition B or C not met. BFN-UNIT 1 3.3-49 Amendment No. ~ .

RCIC System Instrumentation 3.3.5.3 SURVEILLANCE REQUIREMENTS

N()TES--------------------------------------------------

1. Refer to Table 3.3.5.3-1 to determine which SRs apply for each RCIC 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 as follows: (a) for up to 6 hours for Function 2 and (b) for up to 6 hours for Function 1 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.3.1 Perform CHANNEL CHECK. 24 hours SR 3.3.5.3.2 Perform CHANNEL FUNCTl()NAL TEST. 92 days SR 3.3.5.3.3 Perform CHANNEL CALIBRATl()N. 24 months* SR 3.3.5.3.4 Perform L()GIC SYSTEM FUNCTl()NAL 24 months TEST. BFN-UNIT 1 3.3-50 Amendment No. ~ . ~ .

RCIC System Instrumentation 3.3.5.3 Table 3.3.5.3-1 (page 1 of 1) Reactor Core Isolation Cooling System Instrumentation CONDITIONS REQUIRED REFERENCED SURVEILLANCE ALLOWABLE FUNCTION CHANNELS PER FROM REQUIRED REQUIREMENTS VALUE FUNCTION ACTIONA.1

1. Reactor Vessel Water 4 B SR 3.3.5.3.1 ~470 inches Level - Low Low, Level 2(a) SR 3.3.5.3.2 above vessel zero SR 3.3.5.3.3 SR 3.3.5.3.4
2. Reactor Vessel Water 2 C SR 3.3.5.3.1  :,; 583 inches Level - High, Level 8 SR 3.3.5.3.2 above vessel zero SR 3.3.5.3.3 SR 3.3.5.3.4 (a) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 1 3.3-51 Amendment No. ~ . 2-a+,

Primary Containment Isolation Instrumentation 3.3.6.1 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME H. As required by Required H.1 Declare standby liquid 1 hour Action C.1 and referenced control system (SLC) in Table 3.3.6.1-1. inoperable. OR H.2 Isolate the Reactor Water 1 hour Cleanup System. I. As required by Required 1.1 Initiate action to restore Immediately Action C.1 and referenced channel to OPERABLE in Table 3.3.6.1-1. status. BFN-UNIT 1 3.3-56 Amendment No. ~ .

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 3) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTION C.1

5. Reactor Water Cleanup (RWCU) System Isolation
a. Main Steam Valve Vault 1,2,3 2 F SR 3.3.6.1.2 ~ 201°F Area Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
b. Pipe Trench Area 1,2,3 2 F SR 3.3.6.1.2 ~ 135°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6 C. Pump Room A Area 1,2,3 2 F SR 3.3.6.1.2 ~ 152°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
d. Pump Room B Area 1,2,3 2 F SR 3.3.6.1.2 ~ 152°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
e. Heat Exchanger Room 1,2,3 2 F SR 3.3.6.1.2 ~ 170°F Area (West Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6.1.6
f. Heat Exchanger Room 1,2,3 2 F SR 3.3.6.1.2 ~ 143°F Area (East Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6.1.6
g. SLC System Initiation 1,2,3 1(a) H SR 3.3.6.1.6 NA
h. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 ~ 528 inches Level - Low, Level 3 SR 3.3.6.1.2 above vessel SR 3.3.6.1.5 zero SR 3.3.6.1.6
6. Shutdown Cooling System Isolation
a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.2 ~ 115 psig Pressure - High SR 3.3.6.1.5 SR 3.3.6.1.6
b. Reactor Vessel Water 3 2 SR 3.3.6.1.1 ~ 528 inches Level - Low, Level 3 SR 3.3.6.1.2 above vessel SR 3.3.6.1.5 zero SR 3.3.6.1.6 C. Drywell Pressure - High 1,2,3 2 F SR 3.3.6.1.2 ~ 2.5 psig SR 3.3.6.1.5 SR 3.3.6.1.6 (a) One SLC System Initiation signal provides logic.input to close both RWCU valves.

(b) Deleted. BFN-UNIT 1 3.3-60 Amendment Nos. 2-J4, 200 

                                                                                               ~.~.~.

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1) Secondary Containment Isolation Instrumentation APPLICABLE MODES OR REQUIRED FUNCTION OTHER CHANNELS SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIREMENTS VALUE CONDITIONS TRIP SYSTEM

1. Reactor Vessel Water 1,2,3 2 SR 3.3.6.2.1 ;;;: 528 inches Level - Low, Level 3 SR 3.3.6.2.2 above vessel zero SR 3.3.6.2.3 SR 3.3.6.2.4
2. Drywell Pressure - High 1,2,3 2 SR 3.3.6.2.2 :s; 2.5 psig SR 3.3.6.2.3 SR 3.3.6.2.4
3. Reactor Zone Exhaust 1,2,3 SR 3.3.6.2.1 :s: 100 mR/hr Radiation - High SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4
4. Refueling Floor Exhaust 1,2,3 SR 3.3.6.2.1 :s: 100 mR/hr Radiation - High SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4 BFN-UNIT 1 3.3-64 Amendment No. ~ . ~ . 288,

GREV System Instrumentation 3.3.7.1 Table 3.3.7.1-1 (page 1 of 1) Control Room Emergency Ventilation System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTIONA.1

1. Reactor Vessel Water 1,2,3 2 B SR 3.3. 7 .1.1 ~ 528 inches Level - Low, Level 3 SR 3.3. 7 .1.2 above vessel SR 3.3.7.1.5 zero SR 3.3.7.1.6
2. Drywell Pressure - High 1,2,3 2 B SR 3.3.7.1.2  :<,; 2.5 psig SR 3.3.7.1.5 SR 3.3.7.1.6
3. Reactor Zone Exhaust 1,2,3 C SR 3.3.7.1.1  :<,; 100 mR/hr Radiation - High SR 3.3.7.1.2 SR 3.3.7.1.5 SR 3.3.7.1.6
4. Refueling Floor Exhaust 1,2,3 C SR 3.3.7.1.1  :<,; 100 mR/hr Radiation - High SR 3.3.7.1.2 SR 3.3.7.1.5 SR 3.3.7.1.6
5. Control Room Air Supply Duct 1,2,3 D SR 3.3.7.1.1  :<>270 cpm Radiation - High SR 3.3.7.1.2 above SR 3.3.7.1.3 background SR 3.3.7.1.4 BFN-UNIT 1 3.3-69 Amendment No.~.~.~.

ECCS - Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, 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 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~ 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 press*ure 7 days injection/spray subsystem ECCS injection/spray inoperable. subsystem(s) to OPERABLE status. OR One low pressure coolant injection (LPCI) pump in both LPCI subsystems inoperable. (continued) BFN-UNIT 1 3.5-1 Amendment No.~.~.~.

RPV Water Inventory Control 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be ;:: 36 hours. One low pressure ECCS injection/spray subsystem shall be OPERABLE. 

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

A Low Pressure Coolant Injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable. APPLICABILITY: MODES 4 and 5. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS A.1 Restore required ECCS 4 hours injection/spray subsystem injection/spray subsystem inoperable. to OPERABLE status.

8. Required Action and 8.1 Initiate action to establish Immediately associated Completion a method of water Time of Condition A not injection capable of met. operating without offsite electrical power.

C. DRAIN TIME < 36 hours C.1 Verify secondary 4 hours and;:: 8 hours. containment boundary is capable of being established in less than the DRAIN TIME. AND (continued) BFN-UNIT 1 3.5-8 Amendment No. ~ .

RPV Water Inventory Control 3.5.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Verify each secondary 4 hours containment penetration flow path is capable of being isolated in less than the DRAIN TIME. AND C.3 Verify two standby gas 4 hours treatment subsystems are capable of being placed in operation in less than the DRAIN TIME. D. DRAIN TIME < 8 hours. D.1 ---------- NOTE ------------ Required ECCS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power. Initiate action to establish Immediately an additional method of water injection with water sources capable of maintaining RPV water level > TAF for ;:: 36 hours. AND D.2 Initiate action to establish Immediately secondary containment boundary. AND (continued) BFN-UNIT 1 3.5-9 Amendment No. ~ .

RPV Water Inventory Control 3.5.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.3 Initiate action to isolate Immediately each secondary containment penetration flow path or verify it can be automatically or manually isolated from the control room. AND D.4 Initiate action to verify two Immediately standby gas treatment subsystems are capable of being placed in operation. E. Required Action and E.1 Initiate action to restore Immediately associated Completion DRAIN TIME to ~ 36 Time of Condition C or D hours. not met. OR DRAIN TIME< 1 hour. BFN-UNIT 1 3.5-10 Amendment No. ~ .

RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify DRAIN TIME ;:: 36 hours. 12 hours SR 3.5.2.2 Verify, for the required ECCS injection/spray 12 hours subsystem, the suppression pool water level is I 

           ~ -6.25 inches with or -7 .25 inches without differential pressure control.

SR 3.5.2.3 Verify, for the required ECCS injection/spray 31 days I. subsystem, the piping is filled with water from the pump discharge valve to the injection valve. SR 3.5.2.4 Verify for the required ECCS injection/spray 31 days subsystem each 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. SR 3.5.2.5 Operate the required ECCS inj~ction/spray 92 days subsystem through the test return line for ;:: 10 minutes. SR 3.5.2.6 Verify each valve credited for automatically 24 months isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal. SR 3.5.2.7 ------------------------------NOTE----------------------------- Vessel injection/spray may be excluded. Verify the required ECCS injection/spray 24 months subsystem can be manually operated. BFN-UNIT 1 3.5-11 Amendment No. 2-34, ~ . ~ .

RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE. APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure> 150 psig. ACTIONS

NOl"E--------------------------------------------------

LCO 3.0.4.b is not applicable to RCIC. CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable. A.1 Verify by administrative Immediately means High Pressure Coolant Injection System is OPERABLE. AND A.2 Restore RCiC System to 14 days OPERABLE status. B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Reduce reactor steam 36 hours dome pressure to

5 150 psig.

BFN-UNIT 1 3.5-12 Amendment No. ~ . ~ .

PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs) LCO 3.6.1.3 Each PCIV, except reactor building-to-suppression chamber vacuum breakers, shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS

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

1 . Penetration flow paths except for 18 and 20 inch purge valve 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 PCIVs.
4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment," when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria.

BFN-UNIT 1 3.6-9 Amendment No. ~ .

PCIVs 3.6.1.3 ACTIONS

========;============:;==
                                                                                     .I CONDITION                    REQUIRED ACTION               COMPLETION TIME A. --------------NOTE------------ A.1  Isolate the affected       4 hours except for Only applicable to                  penetration flow pattt1by  main steam line penetration flow paths              use of at least one closed with two PCIVs.                     and de-activated           AND automatic valve, closed manual valve, blind        8 hours for main One or more penetration             flange, or check valve     steam line flow paths with one PCIV            with flow through the inoperable except due to            valve secured.

MSIV leakage not within limits. (continued) BFN-UNIT 1 3.6-10 Amendment No. ~ .

PCIVs 3.6.1.3. ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. One or more penetration D.1 Restore leakage rate to 4 hours flow paths with MSIV within limit. leakage not within limits. E. Required Action and E.1 Be in MODE 3. 12 hours associated Completion Time of Condition A, B, AND C, or D not met. E.2 Be in MODE4. 36 hours BFN-UNIT 1 3.6-13 Amendment No. ~ .

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours inoperable. containment to OPERABLE status. B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time of Condition A not AND met. B.2 Be in MODE 4. 36 hours BFN-UNIT 1 3.6-44 Amendment No. 2-34, ~ .

Secondary Containment 3.6.4.1 This page intentionally left blank. BFN-UNIT 1 3.6-45 Amendment No. ~ . ~ .

SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) LCO 3.6.4.2 Each SCIV shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS

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 REQUIRED ACTION COMPLETION TIME* A. One or more penetration A.1 Isolate the affected 8 hours flow paths with one SCIV penetration flow path by inoperable. use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. (continued) BFN-UNIT 1 3.6-47 Amendment No. ~ . ~ .

SCIVs 3.6.4.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 --------------NOTE------------ Isolation devices in high radiation areas may be verified by use of administrative means. Verify the affected Once per 31 days penetration flow path is isolated. B. --------------NOTE------------ B.1 Isolate the affected 4 hours Only applicable to penetration flow path by penetration flow paths use of at least one closed with two isolation valves. and de-activated 

   ----------------------------------      automatic valve, closed manual valve, or blind One or more penetration                 flange.

flow paths with two SCIVs inoperable. C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time of Condition A or B AND not met. C.2 Be in MODE4. 36 hours BFN-UNIT 1 3.6-48 Amendment No. ~ .

SCIVs 3.6.4.2 This page intentionally left blank. BFN-UNIT 1 3.6-49 Amendment No. ~ . 2M,

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Three SGT subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem 7 days inoperable. to OPERABLE status. B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time of Condition A not AND met. 8.2 Be in MODE4. 36 hours C. Two or three SGT C.1 Enter LCO 3.0.3. Immediately subsystems inoperable. BFN-UNIT 1 3.6-51 Amendment No. ~ . ~ .

SGT System 3.6.4.3 This page intentionally left blank. BFN-UNIT 1 3.6-52 Amendment No. ~ . ~ .

SGT System 3.6.4.3 This page intentionally left blank. BFN-UNIT 1 3.6-53 Amendment No. ~ . ~ .

GREV System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency Ventilation (GREV) System LCO 3.7.3 Two GREV subsystems shall be OPERABLE. 

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

The main control room envelope (CRE) boundary may be opened intermittently under administrative control. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One GREV subsystem A.1 Restore GREV subsystem 7 days inoperable for reasons to OPERABLE status. other than Condition B, C, or D . B. One or more GREV 8.1 Initiate action to Immediately subsystems inoperable implement mitigating due to inoperable CRE actions boundary. AND 8.2 Verify mitigating actions 24 hours ensure CRE occupant exposures to radiological hazards will not exceed limits, and verify the CRE occupants are protected from smoke and chemical hazards. AND 8.3 Restore CRE boundary to 90 days OPERABLE status. (continued) BFN-UNIT 1 3.7-8 Amendment~. 249, ~ . 

                                                                                       ~.~,

CREV System 3.7.3 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Two CREV subsystems C.1 Restore HEPA filter and 7 days inoperable due to one charcoal adsorber to inoperable High OPERABLE status. Efficiency Particulate Air (HEPA) filter or charcoal 

   . adsorbers which do not
                                                                       /

impact ability of CREV subsystems to meet flowrate requirements specified in the Ventilation Filter Testing Program (VFTP). D. One CREV subsystem D.1 Restore charcoal 14 days inoperable due to adsorber to OPERABLE inoperable charcoal status. adsorber which does not impact the ability of CREV subsystem to meet flowrate requirements specified in the VFTP. E. Required Action and E.1 Be in MODE 3. 12 hours associated Completion Time of Condition A, B, AND C, or D not met. E.2 Be in MODE4. 36. hours F. Two CREV subsystems F.1 Enter LCO 3.0.3. Immediately inoperable for reasons other than Condition B or C. BFN-UNIT 1 3.7-9 Amendment 234, 246, 2§4., 

                                                                     .2-1a.~.

GREV System 3.7.3 This page intentionally left blank. BFN-UNIT 1 3.7-10 Amendment-246,--2.§.!l ,-2-76, 282-,

Control Room AC System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Control Room Air Conditioning (AC) System LCO 3.7.4 Two Unit 1 and 2 control room AC subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Unit 1 and 2 control A.1 Restore Unit 1 and 2 30 days room AC subsystem control room AC inoperable. subsystem to OPERABLE status. (continued) BFN-UNIT 1 3.7-12 Amendment No. ~ .

Control Room AC System 3.7.4 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 -------------NOTE------------- associated Completion LCO 3.0.3 is not Time of Condition A or B applicable. not met during movement of irradiated fuel assemblies in the Place OPERABLE control Immediately secondary containment or room AC subsystem in during CORE operation. ALTERATIONS. D.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment. AND D.2.2 Suspend CORE Immediately ALTERATIONS. BFN-UNIT 1 3.7-14 Amendment No. ~ .

AC Sources - Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to restore Immediately required offsite power circuit to OPERABLE status. B. One or more required B.1 Suspend CORE Immediately Unit 1 and 2 DGs ALTERATIONS. inoperable. AND B.2 Suspend movement of Immediately irradiated fuel assemblies in secondary containment. AND B.3 Initiate action to restore Immediately required Unit 1 and 2 DGs to OPERABLE status. (continued) BFN-UNIT 1 3.8-16 Amendment No. ~ .

AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 --------------------------N()TE------------------------- The following SRs are not required to be performed: SR 3.8.1.2, SR 3.8.1.5, SR 3.8.1.7, and SR 3.8.1.8. For Unit 1 and 2 AC sources required to be In accordance ()PERABLE, the SRs of Specification 3.8.1 with applicable are applicable, except SR 3.8.1.6 and SRs SR 3.8.1 ..9. SR 3.8.2.2 For the required Unit 3 DG, the SRs of Unit 3 In accordance Technical Specifications are applicable. with applicable SRs BFN-UNIT 1 3.8-18 Amendment No. ~ .

DC.Sources - Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to restore Immediately required DC electrical power subsystems or systems to OPERABLE status. BFN-UNIT 1 3.8-27 Amendment No. ~ .

Distribution Systems - Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate actions to restore Immediately required AC and DC electrical power distribution subsystems to OPERABLE status. A.2.4 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation. BFN-UNIT 1 3.8-40 Amendment No. ~ .

Attachment 6 to CNL-19-010 Revised Technical Specification Pages (Unit 2 Clean) (52 total pages) CNL-19-010

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS Section Page No. 1.0 USE AND APPLICATION .................................................................. 1.1-1 1.1 Definitions ..................................................................................1.1-1 1.2 Logical Connectors ..................................................................... 1.2-1 1.3 Completion Times ...................................................................... 1.. 3-1 1.4 Frequency .................................................................................. 1.4-1 2.0 SAFETY LIMITS (SLs) .......................................................................2.0-1 2.1 SLs ............................................................................................. 2.0-1 2.2 SL Violations ...............................................................................2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY .........................................................................3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ................. 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS ..........................................3.1-1 3.1.1 SHUTDOWN MARGIN (SOM) .............................................. 3.1-1 3.1.2 Reactivity Anomalies .......... :.................................................. 3.1-5 3.1.3 Control Rod OPERABILITY .................................................. 3.1-7 3.1.4 Control Rod Scram Times ..................................................... 3.1-12 3.1.5 Control Rod Scram Accumulators ......................................*... 3.1-16 3.1.6 Rod Pattern Control ..............................................................3.1-20 3.1.7 Standby Liquid Control (SLC) System ..................................3.1-23 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves ...... 3.1-28 3.2 POWER DISTRIBUTION LIMITS ............................................ :.. 3.2-1 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) .............................................................3.2-1 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) .................... 3_.2-3 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) ...................... 3.2-5 (continued) BFN-UNIT 2 Amendment No. ~ .

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Section Page No. 3;3 INSTRUMENTATION .................................................................3.3-1 3.3.1.1 Reactor Protection System (RPS) Instrumentation ............... 3.3-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation .................... 3.3-10 3.3.2.1 Control Rod Block Instrumentation ...................................... 3.3-16 3.3.2.2 Feedwater and Main Turbine High Water Level Trip Instrumentation ......................................................... 3.3-22 3.3.3.1 Post Accident Monitoring (PAM) lnstrumentation._................. 3.3-24 3.3.3.2 Backup Control System ......................................................... 3.3-28 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation ................................................................3.3-30 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation ....................... 3.3-33 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation ................................................................3.3-36 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control ................ , ............................................................3.3-48a 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation ................................................................3.3-49 3.3.6.1 Primary Containment Isolation Instrumentation .................... 3.3-53 3.3.6.2 Secondary Containment Isolation Instrumentation ................ 3.3-62 3.3.7.1 Control Room Emergency Ventilation (GREV) System Instrumentation ...................................................3.3-66 3.3.8.1 Loss of Power (LOP) Instrumentation .................................. 3.3-71 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ....................................................................... 3.3-76 3.4 REACTOR COOLANT SYSTEM (RCS) ..................................... 3.4-1 3.4.1 Recirculation Loops Operating .............................................. 3.4-1 3.4.2 Jet Pumps .............................................................................3.4-5 3.4.3 Safety/Relief Valves (S/RVs) ................................................ 3.4-7 3.4.4 RCS Operational LEAKAGE ................................................. 3.4-9 3.4.5 . RCS Leakage Detection Instrumentation ............................. 3.4-12 3.4.6 RCS Specific Activity ............................................................ 3.4-15 3.4.7 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown ................................................... 3.4-18 (continued) BFN-UNIT 2 ii Amendment No. ~ .

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Section Page No. 3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown .................... .' ........................... 3.4-21 3.4.9 RCS Pressure and Temperature (PIT) Limits ....................... 3.4-24 3.4.10 Reactor Steam Dome Pressure ........................................... 3.4-30 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM ..........................................................................3.5-1 3.5.1 ECCS - Operating .................................................................3.5-1 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control ..... 3.5-8 3.5.3 RCIC System ........................................................................3.5-12 3.6 CONTAINMENT SYSTEMS .......................................................3.6-1 3.6.1.1 Primary Containment ............................................................3.6-1 3.6.1.2 Primary Containment Air Lock ...............................................3.6-3 3.6.1.3 Primary Containment Isolation Valves (PC IVs) ..................... 3.6-9 3.6.1.4 Drywell Air Temperature ........................................................3.6-17 3.6.1.5 Reactor Building-to-Suppression Chamber Vacuum Breakers ..........................................................................3.6-19 3.6.1.6 Suppression Chamber-to-Drywell Vacuum Breakers ........... 3.6-22 3.6.2.1 Suppression Pool Average Temperature .............................. 3.6-24 3.6.2.2 Suppression Pool Water Level ............................................... 3.6-29 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling ....................................................................3.6-31 3.6.2.4 Residual Heat Removal (RHR) Suppression* Pool Spray .......................................................................3.6-34 3.6.2.5 Residual Heat Removal (RHR) Drywell Spray ...................... 3.6-36 3.6.2.6 Drywell-to-Suppression Chamber Differential Pressure*....... 3.6-38 3.6.3.1 Containment Atmosphere Dilution (CAD) System ................ 3.6-40 3.6.3.2 Primary Cont~inment Oxygen Concentration ....... : ................ 3.6-42 3.6.4.1 Secondary Containment. ...................................................... 3.6-44 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) ............... 3.6-47 3.6.4.3 Standby Gas Treatment (SGT) System ............................... 3.6-51 (continued) BFN-UNIT 2 iii Amendment No. ~ . ~ .

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Section Page No. 3.7 PLANT SYSTEMS ......................................................................3.7-1 3.7.1 Residual Heat Removal Service Water (RHRSW) System and Ultimate Heat Sink (UHS) ............................ 3.7-1 3.7.2 Emergency Equipment Cooling Water (EECW) System and Ultimate Heat Sink (UHS) ............................ 3.7-7 3.7.3 Control Room Emergency Ventilation (CREV) System ......... 3. 7-9 3.7.4 Control Room Air Conditioning (AC) System ........................ 3.7-13 3.7.5 Main Turbine Bypass System ...............................................3.7-17 3.7.6 Spent Fuel Storage Pool Water Level. ................................. 3.7-19 3.8 ELECTRICALPOWER SYSTEMS ............................................. 3.8-1 3.8.1 AC Sources - Operating ........................................................ 3.8-1 3.8.2 AC Sources - Shutdown ........................................................ 3.8-14 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ............................ 3.8-19 3.8.4 DC Sources - Operating ........................................................3.8-22 3.8.5 DC Sources - Shutdown ........................................................3.8-26 3.8.6 Battery Cell Parameters ........................................................3.8-29 3.8.7 Distribution Systems - Operating ......................................... 3.8-33 3.8.8 Distribution Systems - Shutdown ......................................... 3.8-39 3.9 REFUELING OPERATIONS ...................................................... 3.9-1 3.9.1 Refueling Equipment Interlocks ............................................ 3.9-1 3.9.2 Refuel Position One-Rod-Out lnterlock ................................. 3.9-3 3.9.3 Control Rod Position ............................................................. 3.9-5 3.9.4 Control Rod Position Indication .............................................3.9-7 3.9.5 Control Rod OPERABILITY - Refueling ............................... 3.9-10 3.9.6 Reactor Pressure Vessel (RPV) Water Level. ....................... 3.9-12 3.9.7 Residual Heat Removal (RHR) - High Water Level. .............. 3.9-14 3.9.8 Residual Heat Removal (RHR) - Low Water Level. ............... 3.9-18 3.9.9 Decay Time ...........................................................................3.9-22 (continued) BFN-UNIT 2 iv Amendment No. ~ .

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Section Page No. 3.10 SPECIAL OPERATIONS ........................................................... 3.10-1 3.10.1 lnservice Leak_ and Hydrostatic Testing Operation ................ 3.10-1 3.10.2 Reactor Mode Switch Interlock Testing ................................ 3.10-4 3.10.3 Single Control Rod Withdrawal - Hot Shutdown ................... 3.10-7 3.10.4 Single Control Rod Withdrawal - Cold Shutdown .................. 3.10-10 3.10.5 Single Control Rod Drive (CRD) Removal - Refueling ........ :.3.10-14 3.10.6 Multiple Control Rod Withdrawal - Refueling ......................... 3.10-17 3.10.7 Control Rod Testing - Operating ...........................................3.10-20 3.10.8 SHUTDOWN MARGIN (SDM) Test - Refueling .................... 3.10-22 4.0 DESIGN FEATURES .........................................................................4.0-1 4.1 Site Location ...............................................................................4.0-1 4.2 Reactor Core .........................*.....................................................4.0-1 4.3 Fuel Storage ...............................................................................4.0-2 5.0 ADMINISTRATIVE CONTROLS ........................................................ 5.0-1 5.1 Responsibility .............................................................................5.0-1 5.2 Organization ...............................................................................5.0-2 5.3 Unit Staff Qualifications ..............................................................5.0-6 5.4 Procedures ................................................................................. 5.0-7 5.5 Programs and Manuals ..............................................................5.0-8 5.6 Reporting Requirements ............................................................5.0-22 5.7 High Radiation Area ...................................................................5.0-26 BFN-UNIT 2 V Amendment No. 2-a3, ~ .

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF TABLES Page No. Table 1.1-1 ......................................................................................................... 1.1-8 Table 3.1.4-1 ...................................................................................................... 3.1-15 Table 3.3.1.1-1 ....................... :....................................................... :................... 3.3-7 Table 3.3.1.2-1 ............ , ..................................................................................... 3.3-15 Table 3.3.2.1-1 .................................................................................................. 3.3-21 Table 3.3.3.1-1 .................................................................................................. 3.3-27 Table 3.3.5.1-1 .................................................................................................. 3.3-43 Table 3.3.5.2-1 ........................................................... ,. ....................................... 3.3-48c Table 3.3.5.3-1 .................................................................................................. 3.3-52 Table 3.3.6.1-1 .................................................................................................. 3.3-59 Table 3.3.6.2-1 .................................................................................................. 3.3-65 Table 3.3.7.1-1 .................................................................................................. 3.3..,70 Table 3.3.8.1-1 ................................................................................................... 3.3-75 Table 3.8.6-1 ...................................................................................................... 3.8-32 BFN-UNIT 2 vi Amendment No.

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF FIGURES Figure Page No. Figure 3.1.7-1 .....................................................................................................3.1-27 Figure 3.4.1-1 .....................................................................................................3.4-4 Figure 3.4.9-1 .....................................................................................................3.4-29/29b Figure 3.4.9-2 ..................................................................................................... 3.4-29a/29c BFN-UNIT 2 vii Amendment No.

Definitions 1.1 1.1 Definitions (continued) CORE OPERATING LIMITS The COLR is the unit specific document that provides REPORT (COLR) cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications. DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of 1-131, 1-132, 1-133, 1-134, and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in Table Ill of TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites." DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a. The water inventory above the TAF is divided by the limiting drain rate;
b. The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetrate on flow paths below the TAF except:
1. Penetration flow path connected to an intact closed system, or isolated by manual or (continued)

BFN-UNIT 2 1.1-3 Amendment No. ~ . ~ .

Definitions 1.1 1.1 Definitions (continued) DRAIN TIME (continued) automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the pen~tration flow paths;

2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or
3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who is in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation devices without offsite power.
c. The penetration flow paths required to be evaluated per paragraph b are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory;
d. No additional draining events occur; and
e. Realistic cross-sectional areas and drain rates are used.

A bounding ORAN TIME may be used in lieu of a calculated value. INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f). (continued) BFN-UNIT 2 1.1-3a Amendment No.

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. As required by Required B.1 -------------NOTE------------ Action A.1 and Only applicable for referenced in Functions 1.a, 1.b, 2.a, Table 3.3.5.1-1. and 2.b. Declare supported ECCS 1 hour from feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND B.2 --------------NOTE------------ Only applicable for Functions 3.a and 3.b. Declare High Pressure 1 hour from Coolant Injection (HPCI) discovery of loss System inoperable. of HPCI initiation capability AND B.3 Place channel in trip. 24 hours (continued) BFN-UNIT 2 3.3-37 Amendment No. ~ .

ECCS Instrumentation 3.3.5.1 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Required C.1 -------------NOTE------------- Action A.1 and Only applicable for referenced in Functions 1.c, 1.e, 2.c, 2.d, Table 3.3.5.1-1. and 2.f. Declare supported ECCS 1 hour from feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND C.2 Restore channel to 24 hours OPERABLE status. D. As required by Required D.1 --------------NOTE------------ Action A.1 and Only applicable if HPCI referenced in pump suction is not Table 3.3.5.1-1. aligned to the suppression pool. Declare HPCI System 1 hour inoperable. (continued) BFN-UNIT 2 3.3-38 Amendment No. ~ .

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1 -------------NOTE------------ Action A.1 and Only applicable for referenced in Function 1.d. Table 3.3.5.1-1. Declare supported ECCS 1 hour from feature(s) inoperable dis co very of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. subsystems in both divisions E.2 Restore channel to 7 days OPERABLE status. (continued) BFN-UNIT 2 3.3-39 Amendment No. ~ .

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTION A.1

1. Core Spray System
a. Reactor Vessel Water 1,2,3 4(b} B SR 3.3.5.1.1 ~ 398 inches Level - Low Low Low, SR 3.3.5.1.2 above vessel Level 1(e) SR 3.3.5.1.5 zero SR 3.3.5.1.6
b. Drywell Pressure - 1,2,3 4(b) B SR 3.3.5.1.2 $2.5 psig High(e) SR 3.3.5.1.5 SR 3.3.5.1.6 C. Reactor Steam Dome 1,2,3 4(b) C SR 3.3.5.1.2 ~435 psig Pressure - Low (Injection 2 per trip SR 3.3.5.1.4 and Permissive and ECCS system SR 3.3.5.1.6 $465 psig lnitiation)Ce)
d. Core Spray Pump Discharge Flow - Low 1,2,3 2 1 per E SR 3.3.5.1.2 SR 3.3.5.1.5
                                                                                                                         ~

and 1647 gpm I (Bypass) subsystem $ 2910 gpm

e. Core Spray Pump Start - Time Delay Relay Pumps A,B,C,D (with 1,2,3 4 C SR 3.3.5.1.5 ~ 6 seconds diesel power) 1 per pump SR 3.3.5.1.6 and
                                                                                                                         $ 8 seconds Pump A (with normal                 1,2,3                                C             SR 3.3.5.1.5           ~  0 seconds power)                                                                                 SR 3.3.5.1.6           and
                                                                                                                         $ 1 second Pump B (with normal                 1,2,3                                C             SR 3.3.5.1.5           ~6 seconds power)                                                                                 SR 3.3.5.1.6           and
                                                                                                                         $ 8 seconds continued (a) Deleted.

(b) Channels affect Common Accident Signal Logic. Refer to LCO 3.8.1, "AC Sources - Operating." (e) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 2 3.3-43 Amendment No. ~ . ~ .

  • ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 {page 2 of6)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA.1

1. Core Spray System {continued)
e. Core Spray Pump Start -

Time Delay Relay {continued) Pump C {with normal power) 1,2,3 C SR 3.3.5.1.5  ;;:: 12 seconds SR 3.3.5.1.6 and

5 16 seconds Pump D {with normal power) 1,2,3 C SR 3.3.5.1.5  ;;:: 18 seconds SR 3.3.5.1.6 and
                                                                                                                             ;;; 24 seconds
2. Low Pressure Coolant Injection

{LPCI) System

a. Reactor Vessel Water 1,2,3 4 B SR 3.3.5.1.1  ;;:: 398 inches Level - Low Low Low, SR 3.3.5.1.2 above vessel Level 1(e) SR 3.3.5.1.5 zero SR 3.3.5.1.6
b. Drywell Pressure - High(e) 1,2,3 4 B SR 3.3.5.1.2 :5 2.5 psig SR 3.3.5.1.5 SR 3.3.5.1.6
c. Reactor Steam Dome 1,2,3 4 C SR 3.3.5.1.2  ;;:: 435 psig and Pressure - Low {Injection SR 3.3.5.1.4 :5 465 psig Permissive and ECCS SR 3.3.5.1.6 Initiation)(e)

I (continued) {a) Deleted. {b) Deleted. {e) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 2 3.3-44 Amendment No. ~ . ~ .

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA.1

2. LPCI System (continued) d, Reactor Steam Dome 4 C SR 3.3.5.1.2 ~ 215 psig Pressure - Low SR 3.3.5.1.4 and :s; 245 psig (Recirculation Discharge SR 3.3.5.1.6 Valve Permissive)(e)
e. Reactor Vessel Water 1,2,3 2 B SR 3.3.5.1.1 ~ 312 5/16 Level - Level 0 1 per SR 3.3.5.1.2 inches above subsystem SR 3.3.5.1.5 vessel zero SR 3.3.5.1.6
f. Low Pressure Coolant Injection Pump Start - Time Delay Relay Pump A,B,C,D (with diesel 1,2,3 4 C SR 3.3.5.1.5 ~ 0 seconds power) SR 3.3.5.1.6 and
s; 1 second Pump A (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ O seconds SR 3.3.5.1.6 and
s; 1 second Pump B (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ 6 seconds SR 3.3.5.1.6 and
s; 8 seconds Pump C (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ 12 seconds SR 3.3.5.1.6 and
s; 16 seconds Pump D (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ 18 seconds SR 3.3.5.1.6 and
s; 24 seconds (continued)

(a) Deleted. I (c) With associated recirculation pump discharge valve open. (e) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 2 3.3-45 Amendment No.~.~.~.

RPV Water Inventory Control Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control Instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE. APPLICABILITY: According to Table 3.3.5.2-1. ACTIONS

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

Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel. B. As required by Required 8.1 Declare associated Immediately Action A.1 and referenced . penetration flow path(s) in Table 3.3.5.2-1. incapable of automatic isolation. AND 8.2 Calculate DRAIN TIME. Immediately C. As required by Required C.1 Place channel in trip. 1 hour Action A.1 and referenced in Table 3.3.5.2-1. (continued) BFN-UNIT 2 3.3-48a Amendment No.

RPV Water Inventory Control Instrumentation 3.3.5.2 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. As required by Required D.1 Restore channel to 24 hours Action A.1 and OPERABLE status. referenced in Table 3.3.5.2-1. E. Required Action and E.1 Declare associated low Immediately associated Completion pressure Emergency Core Time of Condition C or D Cooling System (ECCS) not met. injection/spray subsystem inoperable. SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.5.2-1 to determine which SRs apply for each ECCS Function. SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. 24 hours SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days BFN-UNIT 2 3.3-48b Amendment No.

RPV Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1) RPV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE

1. Core Spray System
a. Reactor 4, 5 1 per C SR 3.3.5.2.1 s465 psig Steam Dome subsystem<a> SR 3.3.5.2.2 Pressure - Low (Injection Permissive)
b. Core Spray Pump 4,5 1 per D SR 3.3.5.2.2 ~ 1647 gpm Discharge Flow - subsystem<a> and Low (Bypass) s 2910 gpm
2. Low Pressure Coolant Injection (LPCI) System
a. Reactor Steam 4,5 2 in one trip C SR 3.3.5.2.1 s465 psig Dome Pressure - system<a> SR 3.3.5.2.2 Low (Injection Permissive)
3. Shutdown Cooling System Isolation
a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2.1 ~ 528 inches Water Level - Low, system SR 3.3.5.2.2 above vessel Level3 zero
4. Reactor Water Cleanup (RWCU) System Isolation
a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2.1 ~ 528 inches Water Level - Low, -system SR 3.3.5.2.2 above vessel Level3 zero (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel Water Inventory Control."

(b) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME. BFN-UNIT 2 3.3-48c Amendment No.

RCIC System Instrumentation 3.3.5.3 3.3 INSTRUMENTATION 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.3 The RCIC System instrumentation for each Function in Table 3.3.5.3-1 shall be OPERABLE. APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig. ACTIONS 

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

Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION \ TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.3-1 for the channel. B. As required by Required 8.1 Declare RCIC System 1 hour from Action A.1 and inoperable. discovery of loss referenced in of RCIC initiation Table 3.3.5.3-1. capability AND 8.2 Place channel in trip. 24 hours (continued) BFN-UNIT 2 3.3-49 Amendment No. ~ .

RCIC System Instrumentation 3.3.5.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Required C.1 Restore channel to 24 hours Action A.1 and OPERABLE status. referenced in Table 3.3.5.3-1. D. Required Action and D.1 Declare RCIC System Immediately associated Completion inoperable. Time of Condition B or C not met. BFN-UNIT 2 3.3-50 Amendment No. ~ .

RCIC System Instrumentation 3.3.5.3 SURVEILLANCE REQUIREMENTS

N()TES--------------------------------------------------

1. Refer to Table 3.3.5.3-1 to determine which SRs apply for each RCIC 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 as follows: (a) for up to 6 hours for Function 2 and (b) for up to 6 hours for Function 1 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.3.1 Perform CHANNEL CHECK. 24 hours SR 3.3.5.3.2 Perform CHANNEL FUNCTl()NAL TEST. 92 days SR 3.3.5.3.3 Perform CHANNEL CALIBRATl()N. 24 months SR 3.3.5.3.4 Perform L()GIC SYSTEM FUNCTl()NAL 24 months TEST. BFN-UNIT 2 3.3-51 Amendment No. ~ .

RCIC System Instrumentation 3.3.5.3 Table 3.3.5.3-1 (page 1 of 1) Reactor Core Isolation Cooling System Instrumentation CONDITIONS REQUIRED REFERENCED SURVEILLANCE ALLOWABLE FUNCTION CHANNELS PER FROM REQUIRED REQUIREMENTS VALUE FUNCTION ACTIONA.1

1. Reactor Vessel Water 4 B SR 3.3.5.3.1 ~470 inches Level - Low Low, Level 2(a) SR 3.3.5.3.2 above vessel zero SR 3.3.5.3.3 SR 3.3.5.3.4
2. Reactor Vessel Water 2 C SR 3.3.5.3.1 :s: 583 inches Level - High, Level 8 SR 3.3.5.3.2 above vessel zero SR 3.3.5.3.3 SR 3.3.5.3.4 (a) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 2 3.3-52 Amendment No. ~ . ~ .

Primary Containment Isolation Instrumentation 

                                                      .                  3.3.6.1 A CTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. As required by Required H.1 Declare standby liquid 1 hour Action C.1 and control system (SLC) referenced in inoperable. Table 3.3.6.1-1. OR H.2 Isolate the Reactor Water 1 hour Cleanup System. I. As required by Required 1.1 Initiate action to restore Immediately l Action C.1 and channel to OPERABLE referenced in status. Table 3.3.6.1-1. BFN-UNIT 2 3.3-57 Amendment No. ~ .

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of3) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTION C.1

5. Reactor Water Cleanup (RWCU) System Isolation
a. Main Steam Valve Vault 1,2,3 2 F SR 3.3.6.1.2 ~ 188°F Area Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
                                                                                          /
b. Pipe Trench Area 1,2,3 2 F SR 3.3.6.1.2 ~ 135°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6 C. Pump Room A Area 1,2,3 2 F SR 3.3.6.1.2 ~ 152°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
d. Pump Room B Area 1,2,3 2 F SR 3.3.6.1.2 ~ 152°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
e. Heat Exchanger Room 1,2,3 2 F SR 3.3.6.1.2 ~ 143°F Area (West Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6.1.6
f. Heat Exchanger Room 1,2,3 2 F SR 3.3.6.1.2 ~ 170°F Area (East Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6.1.6
g. SLC System Initiation 1,2,3 1(a) H SR 3.3.6.1.6 NA h; Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 :2: 528 inches Level - Low, Level 3 SR 3.3.6.1.2 above vessel SR 3.3.6.1.5 zero SR 3.3.6.1.6
6. Shutdown Cooling System Isolation
a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.2 ~ 115 psig Pressure - High SR 3.3.6.1.5 SR 3.3.6.1.6
b. Reactor Vessel Water 3 2 SR 3.3.6.1.1 :2: 528 inches Level - Low, Level 3 SR 3.3.6.1.2 above vessel SR 3.3.6.1.5 zero SR 3.3.6.1.6 C. Drywell Pressure - High 1,2,3 2 F SR 3.3.6.1.2 ~ 2.5 psig SR 3.3.6.1.5 SR 3.3.6.1.6 (a) One SLC System Initiation signal provides logic input to close both RWCU valves.

(b) Deleted. BFN-UNIT 2 3.3-62 Amendment N o . ~ . ~ . ~ 2:7+, ~ . 34--9,

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1) Secondary Containment Isolation Instrumentation APPLICABLE MODES OR REQUIRED FUNCTION OTHER CHANNELS SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIREMENTS VALUE CONDITIONS TRIP SYSTEM

1. Reactor Vessel Water 1,2,3 2 SR 3.3.6.2.1 ~ 528 inches Level - Low, Level 3 SR 3.3.6.2.2 above vessel zero SR 3.3.6.2.3 SR 3.3.6.2.4
2. Drywell Pressure - High 1,2,3 2 SR 3.3.6.2.2 ~ 2.5 psig SR 3.3.6.2.3 SR 3.3.6.2.4
3. Reactor Zone Exhaust 1,2,3 SR 3.3.6,2.1 ~ 100 mR/hr Radiation - High SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4
4. Refueling Floor Exhaust 1,2,3 SR 3.3.6.2.1 ~ 100 mR/hr Radiation - High SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4 BFN-UNIT 2 3.3-65 Amendment No.~.~.~.

GREV System Instrumentation 3.3.7.1 Table 3.3.7.1-1 (page 1 of 1) Control Room Emergency Ventilation System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTION A.1

1. Reactor Vessel Water 1,2,3 2 B SR 3.3.7.1.1 ~528inches Level - Low, Level 3 SR 3.3.7.1.2 above vessel SR 3.3.7.1.5 zero SR 3.3.7.1.6
2. Drywell Pressure - High 1,2,3 2 B SR 3.3.7.1.2 ~2.5 psig SR 3.3.7.1.5 SR 3.3.7.1.6
3. Reactor Zone Exhaust 1,2,3 C SR 3.3.7.1.1 ~ 100 mR/hr Radiation - High SR 3.3.7.1.2 SR 3.3.7.1.5 SR 3.3.7.1.6
4. Refueling Floor Exhaust 1,2,3 C SR 3.3.7.1.1 ~ 100 mR/hr Radiation - High SR 3.3.7.1.2 SR 3.3.7.1.5 SR 3.3.7.1.6
5. Control Room Air Supply Duct 1,2,3 D SR 3.3.7.1.1 ~270 cpm Radiation - High SR 3.3.7.1.2 above SR 3.3.7.1.3 background SR 3.3.7.1.4 BFN-UNIT 2 3.3-70 Amendment No. ~ . 200, 2-9-Q,

ECCS - Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, 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 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<1> injection/spray subsystem ECCS injection/spray inoperable. subsystem(s) to OPERABLE status. OR One low pressure coolant injection (LPCI) pump in both LPCI subsystems inoperable. (continued) 1 <> - This Completion Time may be extended to 14 days on a one-time basis. This temporary approval expires June 1, 2005. BFN-UNIT 2 3.5-1 Amendment No.~.~.~. 

                                                                                                    ~.

RPV Water Inventory Control 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be 2: 36 hours. One low pressure ECCS injection/spray subsystem shall be OPERABLE. 

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

A Low Pressure Coolant Injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable. APPLICABILITY: MODES 4 and 5. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS A.1 Restore required ECCS 4 hours injection/spray subsystem injection/spray subsystem inoperable. to OPERABLE status. B. Required Action and 8.1 Initiate action to establish Immediately associated Completion a method of water Time of Condition A not injection capable of met. operating without offsite electrical power. (continued) BFN-UNIT 2 3.5-8 Am~ndment No. ~ .

RPV Water Inventory Control 3.5.2 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. DRAIN TIME < 36 hours C.1 Verify secondary 4 hours and =:: 8 hours. containment boundary is capable of being established in less than the DRAIN TIME. AND C.2 Verify each secondary 4 hours containment penetration flow path is capable of being isolated inless than the DRAIN TIME. AND C.3 Verify two standby gas 4 hours treatment subsystems are capable of being placed in operation in less than the DRAIN TIME. D. DRAIN TIME < 8 hours. D.1 ------------NOTE------------- Required ECCS injections/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power. Initiate action to establish Immediately an additional method of water injection with water sources capable of maintaining RPV water level > TAF for =:: 36 hours. AND (continued) BFN-UNIT 2 3.5-9 Amendment No. ~ .

RPV Water Inventory Control 3.5.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.2 Initiate action to establish Immediately secondary containment boundary. AND D.3 Initiate action to isolate Immediately each secondary containment penetration 

                     '           flow path or verify it can be automatically or manually isolated from the control room.

AND D.4 Initiate action to verify two Immediately standby gas treatment subsysems are capable of being placed in operation. E. Required Action and E.1 Initiate action to restore Immediately associated Completion DRAIN TIME to ~ 36 Time of Condition C or D hours. not met. OR DRAIN TIME < 1 hour. BFN-UNIT 2 3.5-10 Amendment No. ~ .

RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify DRAIN TIME;:: 36 hours. 12 hours SR 3.5.2.2 Verify, for the required ECCS injection/spray 12 hours subsystem, the suppression pool water level is 

           ~ -6.25 inches with or -7.25 inches without differential pressure control.

SR 3.5.2.3 Verify, for the required ECCS injectiqn/spray 31 days subsystem, the piping is filled with water from the pump discharge valve to the injection valve. SR 3.5.2.4 Verify for the required ECCS injection/spray 31 days subsystem each 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. SR 3.5.2.5 Operate the required ECCS injection/spray 92 days subsystem through the test return line for;:: 10 minutes. SR 3.5.2.6 Verify each valve credited for automatically 24 months isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal. SR 3.5.2.7 *-----------------------------NOTE----------------------------- Vessel injection/spray may be excluded. Verify the required ECCS injection/spray 24 months subsystem can be manually operated. BFN-UNIT 2 3.5-11 Amendment No. ~ . ~ .

RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE. APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig. ACTIONS

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

LCO 3.0.4.b is not applicable to RCIC. CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable. A.1 Verify by administrative Immediately means High Pressure Coolant Injection System is OPERABLE. AND A.2 Restore RCIC System to 14 days OPERABLE status. B. Required Action and 8.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Reduce reactor steam 36 hours dome pressure to 

                                                     ~ 150 psig.

BFN-UNIT 2 3.5-12 Amendment No. ~ . ~ .

PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs) LCO 3.6.1.3 Each PCIV, except reactor building-to-suppression chamber vacuum breakers, shall be OPERABLE. APPLICABILITY: MODES 1,. 2, and 3. ACTIONS

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

1. Penetration flow paths except for 1'8 and 20 inch purge valve 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 PCIVs.
4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment," when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria.

BFN-UNIT 2 3.6-9 Amendment No. ~ .

PCIVs 3.6.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. --------------NOTE------------ A.1 Isolate the affected 4 hours except for Only applicable to penetration flow path by main steam line penetration flow paths use of at least one closed with two PCIVs. and de-activated AND automatic valve, closed manual valve, blind 8 hours for main One or more penetration flange, or check valve steam line flow paths with one PCIV with flow through the inoperable except due to valve secured., MSIV leakage not within limits. (continued) BFN-UNIT 2 3.6-10 Amendment No.~.

PCIVs 3.6.1.3 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. One or more penetration D.1 Restore leakage rate to 4 hours flow paths with MSIV within limit. leakage not within limits. E. Required Action and E.1 Be in MODE 3. 12 hours associated Completion Time of Condition A, B, AND C, or D not met. E.2 Be in MODE 4. 36 hours BFN-UNIT 2 3.6-13 Amendment No. ~ .

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours inoperable. containment to OPERABLE status. B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time of Condition A not AND met. B.2 Be in MODE4. 36 hours BFN-UNIT 2 3.6-44 Amendment No. ~ . ~ .

Secondary Containment 3.6.4.1 This page intentionally left blank. BFN-UNIT 2 3.6-45 Amendment No. ~ . ~ .

SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) LCO 3.6.4.2 Each SCIV shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS

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 REQUIRED ACTION COMPLETION TIME A. One or more penetration A.1 Isolate the affected 8 hours flow paths with one SCIV penetration flow path by , inoperable. use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. (continued) BFN-UNIT 2 3.6-47 Amendment No. ~ . 2QQ,

SCIVs 3.6.4.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 --------------NOTE----~------- Isolation devices in high radiation areas may be verified by use of administrative means. Verify the affected Once per 31 days penetration flow path is isolated.

8. --------------NOTE------------ 8.1 Isolate the affected 4 hours Only applicable to penetration flow path by penetration flow paths use of at least one closed with two isolation valves. and de-activated
   ----------------------------------      automatic valve, closed manual valve, or blind One or more penetration                 flange.

flow paths with two SCIVs inoperable. C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion Time of Condition A or B AND not met. C.2 Be in MODE4. 36 hours BFN-UNIT 2 3.6-48 Amendment No. ~ .

SCIVs 3.6.4.2 This page intentionally left blank. BFN-UNIT 2 3.6-49 Amendment No. ~ . ~ .

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Three SGT subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem 7 days inoperable. to OPERABLE status. B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time of Condition A not AND met. B.2 Be in MODE4. 36 hours C. Two or three SGT C.1 Enter LCO 3.0.3. Immediately subsystems inoperable. BFN-UNIT 2 3.6-51 Amendment No. 2§3, ~ .

SGT System 3.6.4.3 This page intentionally left blank. BFN-UNIT 2 3.6-52 Amendment No. ~ . ~ .

SGT System 3.6.4.3 This page intentionally left blank. BFN-UNIT 2 3.6-53 Amendment No. ~ . 2-QQ,

CREV System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency Ventilation (CREV) System LCO 3.7.3 Two CREV subsystems shall be OPERABLE. 

                    ----------------------------------N()TE----------------------------------------------

The,main control room envelope (CRE) boundary may be opened intermittently under administrative control. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREV subsystem A.1 Restore CREV subsystem 7 days inoperable for reasons to OPERABLE status. other than Condition B, C, or D. B. One or more CREV 8.1 Initiate action to Immediately subsystems inoperable implement mitigating

  • due to inoperable CRE actions boundary.

AND 8.2 Verify mitigating actions 24 hours ensure CRE occupant exposures to radiological hazards will not exceed limits, and verify the CRE occupants are protected from smoke and chemical hazards. AND 8.3 Restore CRE boundary to 90 days OPERABLE status. (continued) BFN-UNIT 2 3.7-9 Amendment ~.~ ....JG2. 

                                                                                         .JOO,

GREV System 3.7.3 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Two GREV subsystems C.1 Restore HEPA filter and 7 days inoperable due to one charcoal adsorber to inoperable High OPERABLE status. Efficiency Particulate Air (HEPA) filter or charcoal adsorbers which do not impact ability of CREV subsystems to meet flowrate requirements specified in the Ventilation Filter Testing Program (VFTP). D. One GREV subsystem D.1 Restore charcoal 14 days inoperable due to adsorber to OPERABLE inoperable charcoal status. adsorber which does not impact the ability of GREV subsystem to meet flowrate requirements specified in the VFTP. E. Required Action and E.1 Be in MODE 3. 12 hours associated Completion Time of Condition A, B, AND C, or D not met. E.2 Be in MODE4. 36 hours F. Two GREV subsystems F.1 Enter LCO 3.0.3. Immediately inoperable for reasons other than Condition B or C. BFN-UNIT 2 3.7-10 Amendment-234, ~ . W, 

                                                              -398,

GREV System 3.7.3 This page intentionally left blank. BFN-UNIT 2 . 3.7-11 Amendment-zSS, 298, -362, 

                                                    -368,

Control Room AC System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Control Room Air Conditioning (AC) System LCO 3.7.4 Two Unit 1 and 2 control room AC subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary 

                       . containment, During CORE ALTERATIONS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Unit 1 and 2 control A.1 Restore Unit 1 and 2 30 days room AC subsystem control room AC inoperable. subsystem to OPERABLE status. (continued) BFN-UNIT 2 3.7-13 Amendment No. 284,

Control Room AC System 3.7.4 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 -------------NOTE------------- associated Completion LCO 3.0.3 is not Time of Condition A or B applicable. not met during movement of irradiated fuel assemblies in the Place OPERABLE control Immediately secondary containment or room AC subsystem in during CORE operation. ALTERATIONS. D.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment. AND D.2.2 Suspend CORE Immediately ALTERATIONS. BFN-UNIT 2 3.7-15 Amendment No. ~ .

AC Sources - Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to restore Immediately required offsite power circuit to OPERABLE status. B. One or more required 8.1 Suspend CORE Immediately Unit 1 and 2 DGs ALTERATIONS. inoperable. AND 8.2 Suspend movement of Immediately irradiated fuel assemblies in secondary containment. AND 8.3 Initiate action to restore Immediately required Unit 1 and 2 DGs to OPERABLE status. (continued) BFN-UNIT 2 3.8-16 Amendment No. ~ .

AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 --------------------------N()TE------------------------- The following SRs are not required to be performed: SR 3.8.1.2, SR 3.8.1.5, SR 3.8.1.7, and SR 3.8.1.8. For Unit 1 and 2 AC sources required to be In accordance ()PERABLE, the SRs of Specification 3.8.1 with applicable are applicable, except SR 3.8.1.6 and SR SRs 3.8.1.9. SR 3.8.2.2 For the required Unit 3 DG, the SRs of Unit 3 In accordance Technical Specifications are applicable. with applicable SRs BFN-UNIT 2 3.8-18 Amendment No. ~ .

DC Sources - Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to restore Immediately required DC electrical power subsystems or systems to OPERABLE status. BFN-UNIT 2 3.8-27 Amendment No. ~ .

  • Distribution Systems - Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate actions to restore Immediately required AC and DC electrical power distribution subsystems to OPERABLE status.

A.2.4 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation. BFN-UNIT 2 3.8-40 Amendment No. ~ .

Attachment 7 to CNL-19-01 O Revised Technical Specification Pages (Unit 3 Clean) (50 total pages) CNL-19-010

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS} TABLE OF CONTENTS (continued) Section Page No. 3.3 INSTRUMENTATION ................................................................ 3.3-1 3.3.1.1 Reactor Protection System (RPS) Instrumentation .............. 3.3-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation ..................... 3.3-10 3.3.2.1 Control Rod Block Instrumentation ....................................... 3.3-16 3.3.2.2 Feedwater and Main Turbine High Water Level Trip Instrumentation ........................................................ 3.3-22 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation ................. 3.3-24 3.3.3.2 Backup Control System ........................................................ 3.3-28 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation ............................................................... 3.3-30. 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation ........................ 3.3-33 3.3.5.1 Emergency Core Cooling System (EGGS) Instrumentation ............................................................... 3.3-36 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control .... 3.3-48a 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation ............................................................... 3.3-49 3.3.6.1 Primary Containment Isolation Instrumentation .................... 3.3-53 3.3.6.2 Secondary Containment Isolation Instrumentation ............... 3.3-62 3.3.7.1 Control Room Emergency Ventilation (GREV) System Instrumentation .................................................. 3.3-66 3.3.8.1 Loss of Power (LOP) Instrumentation .................................. 3.3-71 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ....................................................................... 3.3-76 3.4 REACTOR COOLANT SYSTEM (RCS) .................................... 3.4-1 3.4.1 Recirculation Loops Operating ............................................. 3.4-1 3.4.2 Jet Pumps .............. :............................................................. 3.4-5 3.4.3 Safety/Relief Valves (S/RVs) ................................................ 3.4-7 3.4.4 RCS Operational LEAKAGE ................................................ 3.4-9 3.4.5 RCS Leakage Detection Instrumentation ............................. 3.4-12 3.4.6 RCS Specific Activity ............................................................ 3.4-15 3.4.7 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown .................................................. 3.4-18 (continued) BFN-UNIT 3 ii Amendment No. ~ .

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Section Page No. 3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown ................................................ 3.4-21 3.4.9 RCS Pressure and Temperature (PIT) Limits ....................... 3.4-24 3.4.10 Reactor Steam Dome Pressure ............................................ 3.4-30

  • 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC)

SYSTEM ............................................................... .-.*........ 3.5-1 3.5.1 ECCS - Operating ................................................................ 3.5-1 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control .... 3.5-8 3.5.3 RCIC System ........................................................................ 3.5-12 3.6 CONTAINMENT SYSTEMS ...................................................... 3.6-1 3.6.1.1 Primary Containment. ........................................................... 3.6-1

3.6.1.2 Primary Containment Air Lock .............................................. 3.6-3 3.6.1.3 Primary Containment Isolation Valves (PCIVs) .................... 3.6-9 3.6.1.4 Drywell Air Temperature ....................................................... 3.6-17 3.6.1.5 Reactor Building-to-Suppression Chamber Vacuum Breakers .......................................................................... 3.6-19 .

3.6.1.6 Suppression Chamber-to-Drywell Vacuum Breakers ........... 3.6-22 3.6.2.1 Suppression Pool Average Temperature ............................. 3.6-24 3.6.2.2 Suppression Pool Water Level ............................................. 3.6-29 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling .................................................................... 3.6-31 3.6.2.4 Residual HeafRemoval (RHR) Suppression Pool Spray ...................................................................... 3.6-34 3.6.2.5 Residual Heat Removal (RHR) Drywell Spray ...................... 3.6-36 3.6.2.6

  • Drywell-to-Suppression Chamber Differential Pressure ....... 3.6-38 3.6.3.1 Containment Atmosphere Dilution (CAD) System ................ 3.6-40 3.6.3.2 Primary Containment Oxygen Concentration ....................... 3.6-42 3.6.4.1 Secondary Containment ....................................................... 3.6-44 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) ............... 3.6-47 3.6.4.3
  • Standby Gas Treatment (SGT) System ................................ 3.6-51 (continued)

BFN-UNIT 3 iii Amendment No. ~ .

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) TABLE OF CONTENTS (continued) Section Page No. 3.7 PLANT SYSTEMS ..................................................................... 3.7-1 3.7.1 Residual Heat Removal Service Water (RHRSW) System ............................................................................ 3.7-1 3.7.2 Emergency Equipment Cooling Water (EECW) System and Ultimate Heat Sink (UHS) ........................... 3.7-7 3.7.3 Control Room Emergency Ventilation (CREV) System ........ 3. 7-9 3.7.4 Control Room Air Conditioning (AC) System ........................ 3.7-13 3.7.5 Main Turbine Bypass System ............................................... 3.7-17 3.7.6 Spent Fuel Storage Pool Water Level .................................. 3.7-19 3.8 ELECTRICAL POWER SYSTEMS ............................................ 3.8-1 3.8.1 AC Sources - Operating ....................................................... 3.8-1 3.8.2 AC Sources - Shutdown ....................................................... 3.8-14 . 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ............................ 3.8-19 3.8.4 DC Sources ..: Operating ....................................................... 3.8-22 3.8.5 DC Sources - Shutdown ....................................................... 3.8-26 3.8.6 Battery Cell Parameters ....................................................... 3.8-29 3.8.7 Distribution Systems - Operating .......................................... 3.8-33 3.8.8 Distribution Systems - Shutdown .......................................... 3.8-39 3.9 REFUELING OPERATIONS ...................................................... 3.9-1 3.9.1 Refueling Equipment Interlocks ............................................ 3.9-1 3.9.2 Refuel Position One-Rod-Out Interlock ................................ 3.9-3 3.9.3 Control Rod Position ............................................................ 3.9-5 3.9.4 Control Rod Position Indication ..................................... ,...... 3.9-7 3.9.5 Control Rod OPERABILITY - Refueling ............................... 3.9-10 3.9.6 Reactor Pressure Vessel (RPV) Water Level ....................... 3.9-12 3.9.7 Resi.dual Heat Removal (RHR) - High Water Level .............. 3.9-14 3.9.8 Residual Heat Removal (RHR) - Low Water Level. .............. 3.9-18 3.9-9 Decay Time .......................................................................... 3.9-22 (continued) BFN-UNIT 3 iv Amendment No. -242, -243, -223,

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF TABLES Page No. Table 1.1-1 ............................ _............................................................................. 1.1-8 Table 3.1.4-1 .. :.................................................................................................. 3.1-15 Table 3.3.1.1-1 ................................................................................................. ..' 3.3-7 Table 3.3.1.2-1 .................................................................. ,............................... 3.3-15 Table 3.3.2.1-1 .................................................................................................. 3.3-21 Table 3.3.3.1-1 ............................................. :..................................................... 3.3-27

  • Table 3.3.5.1-1 ..._............................................................................................... 3.3-43 Table 3.3.5.2-1 .......................................................................................... -........ 3.3-48c Table 3.3.5.3-1 ...................................*............................................................... 3.3-52 Table 3.3.6.1-1 ........... '.,, ....................................................... :............................. 3.3-59 Table 3.3.6.2-1 ......................................................... ~: ....................................... 3.3-65 Table 3.3.7.1-1 ,.........................................................................._....................... 3.3-70 Table 3.3.8.1-1 ................................................................................... .- ............... 3.3-75 Table 3.8.6-1 ..................................................................................................... 3.8-32 BFN-UNIT 3 vi Amendment No. ~ .

BROWNS FERRY NUCLEAR PLANT TECHNICAL SPECIFICATIONS (REQUIREMENTS) LIST OF FIGURES Figure Page No. Figure 3.1.7-1 .....................................................................................................3.1-27 Figure 3.4.1-1 .................................................................................................... 3.4-4 Figure 3.4.9-1 ....................... ,............................................................................. 3.4-29/29b Figure 3.4.9-2 .................................................................................................... 3.4-29a/29c BFN-UNIT 3 vii Amendment No.~. -243, ~ .

Definitions 1.1 1.1 Definitions (continued) CORE OPERATING LIMITS The COLR is the unit specific document that provides REPORT (COLR) cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications. DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of 1-131, 1-132, 1-133, 1-134, and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in Table Ill of TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites." DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a. The water inventory above the TAF is divided by the limiting drain rate;
b. The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the TAF except:
1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths; (continued)

BFN-UNIT 3 1.1-3 Amendment No. ~ . ~ .

Definitions 1.1 1.1 Definitions (continued) DRAIN TIME (continued) 2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or

3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who is in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation devices without offsite power.
c. The penetration flow paths required to be evaluated per paragraph b are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory;
d. No additional draining events occur; and
e. Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value. INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f). (continued) BFN-UNIT 3 1.1-3a Amendment No.

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. As required by Required B.1 --------------NOTE------------- Action A 1 and Only applicable for referenced in Functions 1.a, 1.b, 2.a, Table 3.3.5.1-1. and 2.b. Declare supported ECCS 1 hour from feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND B.2 --------------NOTE------------ Only applicable for Functions 3.a and 3.b. Declare High Pressure 1 hour from Coolant Injection (HPCI) discovery of loss System inoperable. of HPCI initiation capability AND B.3 Place channel in trip. 24 hours (continued) BFN-UNIT 3 3.3-37 Amendment No. ~ .

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Required C.1 --------------NOTE------------- Action A.1 and Only applicable for referenced in Functions 1.c, 1.e, 2.c, Table 3.3.5.1-1. 2.d, and 2.f. Declare supported ECCS 1 hour from feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. features in both divisions AND C.2 Restore channel to 24 hours OPERABLE status. D. As required by Required D.1 --------------NOTE------------ Action A.1 and Only applicable if HPCI referenced in pump suction is not , Table 3.3.5.1-1. aligned to the suppression pool. Declare HPCI System 1 hour inoperable. (continued) BFN-UNIT 3 3.3-38 Amendment No. ~ .

ECCS Instrumentation 3.3.5.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1 -------------NOTE------------ Action A.1 and Only applicable for referenced in Function 1.d. Table 3.3.5.1-1. Declare supported ECCS 1 hour from feature(s) inoperable discovery of loss when its redundant of initiation feature ECCS initiation capability for capability is inoperable. subsystems in both divisions E.2 Restore channel to 7 days OPERABLE status. (continued) BFN-UNIT 3 3.3-39 Amendment No. ~ .

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA.1

1. Core Spray System
a. Reactor Vessel Water Level 1,2,3 B SR 3.3.5.1.1 .: 398 inches
          -   Low Low Low, Level 1(f)                                                                SR  3.3.5.1.2           above vessel SR  3.3.5.1.5           zero SR 3.3.5.1.6
b. Drywell Pressure - High(f) 1,2,3 B SR 3.3.5.1.2 ~ 2.5 psig SR 3.3.5.1.5 SR 3.3.5.1.6
c. Reactor Steam Dome 1,2,3 4(b) C SR 3.3.5.1.2 .: 435 psig and Pressure - Low (Injection 2 per trip SR 3.3.5.1.4 ~465 psig .

Permissive and ECCS system SR 3.3.5.1.6 lnitiation)(f)

d. .Core Spray Pump Discharge 1,2,3 2 E SR 3.3.5.1.2  ;;: 1647 gpm Flow-Low (Bypass) 1 per SR 3.3.5.1.5 and subsystem ~2910gpm
e. Core Spray Pump Start -

Time Delay Relay I Pumps A,B,C,D (with diesel 1,2,3 4 C SR 3.3.5.1.5 .: 6 seconds power) 1 per pump SR 3.3.5.1.6 and 

                                                                                                                             ~ 8 seconds Pump A (with normal power)             1,2,3                                C            . SR 3.3.5.1.5           .: O seconds SR 3.3.5.1.6            and
                                                                                                                             ~ 1 second Pump B (with normal power)             1,2,3                                C              SR 3.3.5.1.5            ;;: 6 seconds SR 3.3.5.1.6            and
                                                                                                                              ~ 8 seconds (continued)

(a) Deleted. I (b) Channels affect Common Accident Signal Logic. Refer to LCO 3.8.1, "AC Sources - Operating." (f} During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 3 3.3-43 Amendment No. ~ . ~ .

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of 6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA.1

1. Core Spray System (continued)
e. Core Spray Pump Start -

Time Delay Relay (continued) Pump C (with normal power) 1,2,3 C SR 3.3.5.1.5 <!: 12 seconds SR 3.3.5.1.6 and 

                                                                                                                              ~   16 seconds Pump D (with normal power)             1,2,3                                C             SR 3.3.5.1.5            <!: 18 seconds SR 3.3.5.1.6            and
24seconds
2. Low Pressure Coolant Injection (LPCI) System
a. Reactor Vessel Water Level 1,2,3 4 B SR 3.3.5.1.1 <!: 398 inches
            -   Low Low Low, Level 1(f)                                                               SR   3.3.5.1.2          above vessel SR   3.3.5.1.5          zero SR   3.3.5.1.6
b. Drywell Pressure - High(f) 1,2,3 4 B SR 3.3.5.1.2 ~2.5 psig SR 3.3.5.1.5 SR 3.3.5.1.6
c. Reactor Steam Dome 1,2,3 4 C SR 3.3.5.1.2 <!: 435 psig and Pressure - Low (Injection SR 3.3.5.1.4  :<;465 psig Permissive and ECCS SR 3.3.5.1.6 lnitiation)(f)

(continued) (a) Deleted. (b) Deleted. (f) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 3 3.3-44 Amendment No. ~ . ~ .

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of6) Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED FUNCTION OR OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIRED REQUIREMENTS VALUE CONDITIONS FUNCTION ACTIONA.1

2. LPCI System (continued)
d. Reactor Steam Dome 1(c),2(c), 4 C SR 3.3.5.1.2 ~ 215 psig Pressure - Low SR 3.3.5.1.4 and :,; 245 psig 3(c)

(Recirculation Discharge SR 3.3.5.1.6

  • Valve Permissive)(f)
e. Reactor Vessel Water Level 1,2,3 2 B SR 3.3.5.1.1 ~ 312 5/16
            -Level O                                                 1 per                            SR  3.3.5.1.2           inches above subsystem                           SR  3.3.5.1.5           vessel zero SR  3.3.5.1.6
f. Low Pressure Coolant Injection Pump Start- Time Delay Relay Pump A,B,C,D (with diesel 1,2,3 4 C SR 3.3.5.1.5 ~ 0 seconds power) SR 3.3.5.1.6 and
,; 1 second Pump A (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ O seconds SR 3.3.5.1.6 and
,; 1 second Pump B (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ 6 seconds SR 3.3.5.1.6 and
,; 8 seconds Pump C (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ 12 seconds SR 3.3.5.1.6 and
,; 16 seconds Pump D (with normal power) 1,2,3 C SR 3.3.5.1.5 ~ 18seconds SR 3.3.5.1.6 and
,; 24 seconds (continued)

(a) Deleted. (c) With associated recirculation pump discharge valve open. (f) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analysis Report. The methodolqgy used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 3 3.3-45 Amendment No.~.~.~.

RPV Water Inventory Control Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control lnst~umentation for each Function in Table 3.3.5.2-1 shall be OPERABLE. APPLICABILITY: According to Table 3.3.5.2-1. ACTIONS

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

Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel. B. As required by Required B.1 Declare associated Immediately Action A.1 and referenced penetration flow path(s) in Table 3.3.5.2-1. incapable of automatic isolation. AND B.2 C~lculate DRAIN TIME. Immediately C. As required by Required C. 1 Place channel in trip. 1 hour Action A.1 and referenced in Table 3.3.5.2-1. (continued) BFN-UNIT 3 3.3-48a Amendment No.

RPV Water Inventory Control Instrumentation 3.3.5.2 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. As required by Required D.1 Restore channel to 24 hours Action A.1 and referenced OPERABLE status. in Table 3.3.5.2-1. E. Required Action and E.1 Declare associated low Immediately associated Completion pressure Emergency Time of Condition C or D Core Cooling System not met. (ECCS) injection/spray subsystem inoperable. SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.5.2-1 to determine which SRs apply for each ECCS Function. SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. 24 hours SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days BFN-UNIT 3 3.3-48b Amendment No.

RPV Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1) RPV Water Inventory Control Instrumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTIONA.1 REQUIREMENTS VALUE

1. Core Spray System
a. Reactor 4,5 1 per C SR 3.3.5.2.1  ::;465 psig Steam Dome subsystem(a) SR 3.3.5.2.2 Pressure - Low (Injection Permissive)
b. Core Spray Pump 4,5 1 per D SR 3.3.5.2.2  ;::: 1647 gpm Discharge Flow - subsystem(a) and Low (Bypass) s; 2910 gpm
2. Low Pressure Coolant Injection (LPCI) System
a. Reactor Steam 4,5 2 in one trip C SR 3.3.5.2.1 s; 465 psig Dome Pressure - system(a) SR 3.3.5.2.2 Low (Injection Permissive)
3. Shutdown Cooling System Isolation
a. Reactor Vessel (b) 1 per trip B SR *3.3.5.2.1  ;::: 528 inches Water Level- Low, system SR 3.3.5.2.2 above vessel Level3 zero
4. Reactor Water Cleanup (RWCU) System Isolation
a. Reactor Vessel (b) 1 per trip B SR 3.3.5.2.1  ;::: 528 inches Water Level - Low, system SR 3.3.5.2.2 above vessel Level3 zero (a) Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, "Reactor Pressure Vessel Water Inventory Control."

(b) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME. BFN-UNIT 3 3.3-48c Amendment No.

RCIC System Instrumentation 3.3.5.3 3.3 INSTRUMENTATION 3.3.5.3 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.3 The RCIC System instrumentation for each Function in Table 3.3.5.3-1 shall be OPERABLE. APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure> 150 psig. ACTIONS

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

Separate Condition entry is allowed for each channel. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more c_hannels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.3-1 for the channel. B. As required by Required B.1 Declare RCIC System 1 hour from Action A.1 and inope_r~ble. discovery of loss referenced in of RCIC initiation Table 3.3.5.3-1. capability AND B.2 Place channel in trip. 24 hours (continued) BFN-UNIT 3 3.3-49 Amendment No. 24-3,

RCIC System Instrumentation 3.3.5.3 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. As required by Required C.1 Restore channel to 24 hours Action A.1 and OPERABLE status. referenced in Table 3.3.5.3-1. D. Required Action and D.1 Declare RCIC System Immediately associated Completion inoperable. Time of Condition B or C not met. BFN-UNIT 3 3.3-50 Amendment No. ~ .

RCIC System Instrumentation 3.3.5.3 SURVEILLANCE REQUIREMENTS

N()TES--------------------------------------------------

1. Refer to Table 3.3.5.3-1 to determine which SRs apply for each RCIC 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 as follows: (a) for up to 6 hours for Function 2 and (b) for up to 6 hours for Function 1 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.3.1 Perform CHANNEL CHECK. 24 hours SR 3.3.5.3.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.5.3.3 Perform CHANNEL CALIBRATl()N. 24 months SR 3.3.5.3.4 , Perform LOGIC SYSTEM FUNCTl()NAL 24 months TEST. BFN-UNIT 3 3.3-51 Amendment No. 240,

RCIC System Instrumentation 3.3.5.3 Table 3.3.5.3-1 (page 1 of 1) Reactor Core Isolation Cooling System Instrumentation CONDITIONS REQUIRED REFERENCED SURVEILLANCE ALLOWABLE FUNCTION CHANNELS PER FROM REQUIRED REQUIREMENTS VALUE FUNCTION ACTIONA.1

1. Reactor Vessel Water 4 B SR 3.3.5.3.1 ~470 inches Level - Low Low, Level 2(a) SR 3.3.5.3.2 above vessel zero SR 3.3.5.3.3 SR 3.3.5.3;4
2. Reactor Vessel Water 2 C SR 3.3.5.3.1 ~ 583 inches Level - High, Level 8 SR 3.3.5.3.2 above vessel zero SR 3.3.5.3.3 SR 3.3.5.3.4 (a) During instrument calibrations, if the As Found channel setpoint is conservative with respect to the Allowable Value but outside its acceptable As Found band as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. If the As Found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

Prior to returning a channel to service, the instrument channel setpoint shall be calibrated to a value that is within the acceptable As Left tolerance of the setpoint; otherwise, the channel shall be declared inoperable. The nominal Trip Setpoint shall be specified on design output documentation which is incorporated by reference in the Updated Final Safety Analyl?iS Report. The methodology used to determine the nominal Trip Setpoint, the predefined As Found Tolerance, and the As Left Tolerance band, and a listing of the setpoint design output documentation shall be specified in Chapter 7 of the Updated Final Safety Analysis Report. BFN-UNIT 3 3.3-52 Amendment No. ~ . ~ .

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME H. As required by Required H.1 Declare standby liquid 1 hour Action C.1 and control system (SLC) referenced in inoperable. Table 3.3.6.1-1. OR H.2 Isolate the Reactor Water 1 hour Cleanup System. I. As required by Required 1.1

  • Initiate action to restore Immediately Action C.1 and channel to OPERABLE referenced in status.

Table 3.3.6.1-1. BFN-UNIT 3 3.3-57 Amendment No. ~ .

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of3) Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTION C.1

5. Reactor Water Cleanup (RWCU) System Isolation
a. Main Steam Valve Vault 1,2,3 2 F SR 3.3.6.1.2 . :;;; 201°F Area Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
b. Pipe Trench Area 1,2,3 2 F SR 3.3.6.1.2  :;;; 135°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6 C. Pump Room A Area 1,2,3 2 F SR 3.3.6.1.2  :;;; 152°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
d. Pump Room B Area 1,2,3 2 F SR 3.3.6.1.2  :;;; 152°F Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6
e. Heat Exchanger Room 1,2,3 2 F SR 3.3.6.1.2  :;;; 143°F Area (West Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6.1.6
f. Heat Exchanger Room 1,2,3 2 F SR 3.3.6.1.2  :;;; 170°F Area (East Wall) SR 3.3.6.1.5 Temperature - High SR 3.3.6.1.6
g. SLC System Initiation 1,2,3 1(a) H SR 3.3.6.1.6 NA
h. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1  ;,: 528 inches Level - Low, Level 3 SR 3.3.6.1.2 above vessel SR 3.3.6.1.5 zero SR 3.3.6.1.6
6. Shutdown Cooling System Isolation
a. Reactor Steam Dome 1,2,3 F SR 3.3.6.1.2  :,; 115 psig Pressure - High SR 3.3.6.1.5 SR 3.3.6.1.6
b. Reactor Vessel Water 3 2 SR 3.3.6.1.1  ;,: 528 inches Level - Low, Level 3 SR 3.3.6.1.2 above vessel SR 3.3.6.1.5 zero SR 3.3.6.1.6 C. Drywell Pressure - High 1,2,3 2 F SR 3.3.6.1.2  :,; 2.5 psig SR 3.3.6.1.5 SR 3.3.6.1.6 (a) One SLC System Initiation signal provides logic input to close both RWCU valves.

(b) Deleted. BFN-UNIT 3 3.3-61 Amendment No. ~ . ~ . 249 

                                                                                                ~.~.~.

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1) Secondary Containment Isolation Instrumentation APPLICABLE MODES OR REQUIRED FUNCTION OTHER CHANNELS SURVEILLANCE ALLOWABLE SPECIFIED PER REQUIREMENTS VALUE CONDITIONS TRIP SYSTEM

1. Reactor Vessel Water 1,2,3 2 SR 3.3.6.2.1 ~ 528 inches Level - Low, Level 3 SR 3.3.6.2.2 above vessel zero SR 3.3.6.2.3 SR 3.3.6.2.4
2. Drywell Pressure - High 1,2,3 2 . SR 3.3.6.2.2 ~ 2.5 psig SR 3.3.6.2.3 SR 3.3.6.2.4
3. Reactor Zone Exhaust 1,2,3 . SR 3.3.6.2.1 ~ 100 mR/hr Radiation - High SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4
4. Refueling Floor Exhaust 1,2,3 SR 3.3.6.2.1 ~ 100 mR/hr Radiation - High SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4 BFN-UNIT 3 3.3-65 Amendment No. 212, 213,~.
                                                                                               ~.

GREV System Instrumentation 3.3.7.1 Table 3.3.7.1-1 (page 1 of 1) Control Room Emergency Ventilation System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED FUNCTION OTHER CHANNELS FROM SURVEILLANCE ALLOWABLE SPECIFIED PER TRIP REQUIRED REQUIREMENTS VALUE CONDITIONS SYSTEM ACTIONA.1

1. Reactor Vessel Water 1,2,3 2 B SR 3.3.7.1.1  ;:,: 528 inches Level - Low, Level3 SR 3.3. 7 .1.2 above vessel SR 3.3.7.1.5 zero SR 3.3.7.1.6
2. Drywell Pressure - High 1,2,3 2 B SR 3.3.7.1.2  :;;2.5psig SR 3.3.7.1.5 SR 3.3.7.1.6
3. Reactor Zone Exhaust 1,2,3 C SR 3.3.7.1.1  :;; 100 mR/hr Radiation - High SR 3.3.7.1.2 SR 3.3.7.1.5 SR 3.3.7.1.6
4. Refueling Floor Exhaust 1,2,3 C SR 3.3.7.1.1  :;; 100 mR/hr Radiation - High SR 3.3.7.1.2 SR 3.3.7.1.5 SR 3.3.7.1.6
5. Control Room Air Supply Duct 1,2,3 D SR 3.3.7.1.1  :;;270 cpm Radiation - High SR 3.3.7.1.2 above SR 3.3.7.1.3 background SR 3.3.7.1.4 BFN-UNIT 3 3.3-70 Amendment No. 212,213, 2-1-9, 249,

ECCS - Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, 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 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 ~ 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 low pressure coolant injection (LPCI) pump in both LPCI subsystems inoperable. (continued) BFN-UNIT 3 3.5-1 Amendment No. ~ . 229, ~ .

RPV Water Inventory Control 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be 2: 36 hours. One low pressure ECCS injection/spray subsystem shall be OPERABLE. 

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

A Low Pressure Coolant Injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable. APPLICABILITY: MODES 4 and 5. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS A.1 Restore required ECCS 4 hours injection/spray subsystem injection/spray subsystem inoperable. to OPERABLE status. B. Required Action and 8.1 Initiate action to establish Immediately associated Completion a method of water Time of Condition A not injection capable of met. operating without offsite electrical power. (continued) BFN-UNIT 3 3.5-8 Amendment No. ~ .

RPV Water Inventory Control 3.5.2 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. DRAIN TIME< 36 hours C.1 Verify secondary 4 hours and 2:: 8 hours. containment boundary is capable of being established in less than the DRAIN TIME. AND C.2 Verify each secondary 4 hours containment penetration flow path is capable of being isolated in less than the DRAIN TIME. AND C.3 Verify two standby gas 4 hours treatment subsystems are capable of being placed in operation in less than the DRAIN TIME. D. DRAIN TIME < 8 hours. D.1 ---------- NOTE------------ Required EGGS injection/spray subsystem or additional method of water injection shall be capable of operating without offsite electrical power. Initiate action to establish Immediately an additional method of water injection with water sources capable of maintaining RPV water level > TAF for 2:: 36 hours. AND (continued) BFN-UNIT 3 3.5-9 Amendment No. ~ .

RPV Water Inventory Control 3.5.2 ACTIONS (continued} CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.2 Initiate action to establish Immediately secondary containment boundary. AND D.3 Initiate action to isolate Immediately each secondary containment penetration flow path or verify it can be automatically or manually isolated from the control room. AND D.4 Initiate action to verify two Immediately standby gas treatment subsystems are capable of being placed in operation. E. Required Action and E.1 Initiate action to restore Immediately associated Completion DRAIN TIME to ::: 36 Time of Condition C or D hours. not met. OR DRAIN TIME < 1 hour. BFN-UNIT 3 3.5-10 Amendment No. ~ .

RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify DRAIN TIME 2: 36 hours. 12 hours SR 3.5.2.2 Verify, for the required ECCS injection/spray 12 hours subsystem, the suppression pool water level is 

           ~ -6.25 inches with or -7.25 inches without differential pressure control.

SR 3.5.2.3 Verify, for the required ECCS injection/spray 31 days subsystem, the piping is filled with water from the pump discharge valve to the injection valve. SR 3.5.2.4 Verify for the required ECCS injection/spray 31 days subsystem each 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. SR 3.5.2.5 Operate the required ECCS injection/spray 92 days subsystem through the test return line for 2: 10 minutes. SR 3.5.2.6 Verify each valve credited for automatically 24 months isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal. SR 3.5.2.7 ------------------------------NOTE----------------------------- Vessel injection/spray may be excluded. Verify the required ECCS injection/spray 24 months subsystem can be manually operated. BFN-UNIT 3 3.5-11 Amendment No. 24-a, 288,

RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE. APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure> 150 psig. ACTIONS

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

LCO 3.0.4.b is not applicable to RCIC. CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable. A.1 Verify by administrative Immediately means High Pressure Coolant Injection System is OPERABLE. AND A.2 Restore RCIC System to 14 days OPERABLE status. B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time not met. AND B.2 Reduce reactor steam 36 hours dome pressure to

150 psig.

BFN-UNIT 3 3.5-12 Amendment No. ~ . ~ .

PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs) LCO 3.6.1.3 Each PCIV, except reactor building-to-suppression chamber vacuum breakers, shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS

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

1. Penetration flow paths except for 18 and 20 inch purge valve 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 PCIVs.
4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment," when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria.

BFN-UNIT 3 3.6-9 Amendment No. ~ .

PCIVs 3.6.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. --------------NOTE------------ A.1 Isolate the affected 4 hours except for Only applicable to penetration flow path by main steam line

  • penetration flow paths use of at least one closed with two PCIVs. and de-activated AND automatic valve, closed
  • manual valve, blind 8 hours for main One or more penetration flange, or check valve steam line flow paths with one PCIV with flow through the inoperable except due to valve secured.

MSIV leakage not within limits. (continued) BFN-UNIT 3 3.6-10 Amendment No. ~ .

PCIVs 3.6.1.3 A CTIONS (continued) CONDl110N REQUIRED ACTION COMPLETION TIME D. One or more penetration D.1 Restore leakage rate to 4 hours flow paths with MSIV within limit. leakage not within limits. E. Required Action and E.1 Be in MODE 3. 12 hours associated Completion Time of Condition A, B, AND C, or D not met. E.2 Be in MODE4. 36 hours BFN-UNIT 3 3.6-13 Amendment No. ~ .

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPL~TION TIME A. Secondary containment A.1 Restore secondary 4 hours inoperable. containment to OPERABLE status. B. Required Action and B.1 Be in MODE 3. 12 hours associated Completion Time of Condition A not AND met. B.2 Be in MODE 4. 36 hours BFN-UNIT 3 3.6-44 Amendment No. ~ . ~ .

Secondary Containment 3.6.4.1 This page intentionally left blank. BFN-UNIT 3 3.6-45 Amendment No. ~ . ~ .

SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) LCO 3.6.4.2 Each SCIV shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS-

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 REQUIRED ACTION COMPLETION TIME A. One or more penetration A.1 Isolate the affected 8 hours flow paths with one SCIV penetration flow path by inoperable. use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange. 

                                                                                              -(continued)

BFN-UNIT 3 3.6-47 Amendment No. ~ . ~ .

SCIVs 3.6.4.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 --------------NOTE------------ Isolation devices in high radiation areas may be verified by use of administrative means. Verify the affected Once per 31 days penetration flow path is isolated. B. --------------NOTE------------ B.1 Isolate the affected 4 hours Only applicable to penetration flow path by penetration flow paths use of at least one closed with two isolation valves. and de-activated 

     ----------------------------------      automatic valve, closed manual valve, or blind One or more penetration                 flange.

flow paths with two SCIVs inoperable. C. Required Action and C.1 Be in MODE 3. 12 hours associated Completion

  • Time of Condition A or B AND not met.

C.2 Be in MODE 4. 36 hours BFN-UNIT 3 3.6-48 Amendment No. ~ .

SCIVs 3.6.4.2 This page intentionally left blank. BFN-UNIT 3 3.6-49 Amendment No. ~ . ~ .

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Three SGT subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem 7days inoperable. to OPERABLE status. B. Required Action and 8.1 Be in MODE 3. 12 hours associated* Completion Time of Condition A not AND met. 8.2 Be in MODE4. 36 hours C. Two or three SGT C.1 Enter LCO 3.0.3. Immediately subsystems inoperable. BFN-UNIT 3 3.6-51 Amendment No. ~ . 249,

SGT System 3.6.4.3 This page intentionally left blank. BFN-UNIT 3 3.6-52 Amendment No. ~ . ~ .

SGT System 3.6.4.3 This page intentionally left blank. BFN-UNIT 3 3.6-53 Amendment No. ~ . 249,

GREV System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency Ventilation (GREV) System LCO 3.7.3 Two GREV subsystems shall be OPERABLE. 

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

The main control room envelope (CRE) boundary may be opened intermittently under administrative control. APPLICABILITY: MODES 1, 2, and 3. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One GREV subsystem A.1 Restore GREV subsystem 7 days inoperable for reasons to OPERABLE status. other than Condition B, C, or D. B. One or more GREV B.1 Initiate action to Immediately subsystems inoperable implement mitigating due to inoperable CRE actions boundary. AND B.2 Verify mitigating actions 24 hours ensure CRE occupant exposures to radiological hazards will not exceed limits, and verify the CRE occupants are protected from smoke and chemical hazards. AND B.3 Restore CRE boundary to 90 days OPERABLE status. (continued) BFN-UNIT 3 3.7-9 Amendment~.~.~.~. 

                                                                                              ~.

GREV System 3.7.3 A CTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. Two GREV subsystems C.1 Restore HEPA filter and 7 days inoperable due to one charcoal adsorber to inoperable High OPERABLE status. Efficiency Particulate Air (HEPA) filter or charcoal adsorbers which do not impact ability of GREV subsystems to meet flowrate requirements specified in the Ventilation Filter Testing Program (VFTP). D. One GREV subsystem D.1 Restore charcoal 14 days inoperable due to adsorber to OPERABLE inoperable charcoal status. adsorber which does not impact the ability of GREV subsystem to meet flowrate requirements specified in the VFTP. E. Required Action and E.1 Be in MODE 3. 12 hours associated Completion Time of Condition A, B, AND C, or D not met. E.2 Be in MODE 4. 36 hours F. Two GREV subsystems F.1 Enter LCO 3.0.3. Immediately inoperable for reasons other than Condition B or C. BFN-UNIT 3 3.7-10 Amendment~.~.~. 

                                                              ~.

GREV System 3.7.3 This page intentionally left blank. BFN-UNIT 3 3.7-11 Amendment-244, -249, -264, 

                                                    ~.

Control Room AC System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Control Room Air Conditioning (AC) System LCO 3.7.4 Two Unit 3 control room AC subsystems shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Unit 3 control room A.1 Restore Unit 3 control 30 days AC subsystem room AC subsystem to inoperable. OPERABLE status. (continued) BFN-UNIT 3 3.7-13 Amendment No. ~ .

Control Room AC System 3.7.4 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 -------------NOTE------------- associated Completion LCO 3.0.3 is not Time of Condition A or B applicable. not met during movement of irradiated fuel assemblies in the Place OPERABLE control Immediately secondary containment or room AC subsystem in during CORE operation. ALTERATIONS. OR. D.2.1 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment. AND D.2.2 Suspend CORE Immediately ALTERATIONS. BFN-UNIT 3 3.7-15 Amendment No. ~ .

AC Sources - Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to restore Immediately required offsite pbwer circuit to OPERABLE status. B. One or more required B.1 Suspend CORE Immediately Unit 3 DGs inoperable. ALTERATIONS. AND B.2 Suspend movement of Immediately irradiated fuel assemblies in secondary containment. AND B.3 Initiate action to restore Immediately required Unit 3 DGs to OPERABLE status. (continued) BFN-UNIT 3 3.8-16 Amendment No. ~ .

AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 --------------------------N()TE------------------------- The following SRs are not required to be performed: SR 3.8.1.2, SR 3.8.1.5, SR 3.8.1.7, and SR 3.8.1.8. For Unit 3 AC sources required to be In accordance OPERABLE, the SRs of Specification 3.8.1 with applicable are applicable, except for SR 3.8.1.6 and SR SRs 3.8.1.9. SR 3.8.2.2 For the required Unit 1 and 2 DG, the SRs of In accordance Unit 1 and 2 Technical Specifications are with applicable applicable. SRs BFN-UNIT 3 3.8-18 Amendment No.~.

DC Sources - Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION . COMPLETION TIME A. (continued) A.2.3 Initiate action to restore Immediately required DC electrical power subsystems or systems to OPERABLE status. BFN--UNIT 3 3.8-27 Amendment No. ~ .

Distribution Systems - Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate actions to restore Immediately .I required AC and DC electrical power distribution subsystems to OPERABLE status. A.2.4 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation. BFN-UNIT 3 3.8-40 Amendment No. ~ .

Attachment 8 to CNL-19-010 Proposed Technical Specification Bases Changes (Unit 1 Mark-up) (Information only) (93 total pages) CNL-19-010

ECCS Instrumentation B 3.3.5.1 BASES APPLICABLE 1.a, 2.a. Reactor Vessel Water Level - Low Low Low, Level 1 SAFETY ANALYSES, (LS-3-58A-D) (continued) LCO, and APPLICABILITY The Reactor Vessel Water Level - Low Low Low, Level 1 Allowable Value is chosen to allow time for the low pressure injection/spray subsystems to activate and provid~ adequate cooling. Four channels of Reactor Vessel Water Level - Low Low Low, Level 1 Function are only required to be OPERABLE when the ECCS is required to be OPERABLE to ensure that no single instrument failure can preclude ECCS initiation. Ref.er to LGO 3.5.1 and LGO 3.5.2, "EGGS Shutdown," for Applicability Bases for the low pressure EGGS subsystems. For this instrument function, the nominal trip setpoint including the as-left tolerances is defined as the LSSS. The acceptable as-found band is based on a statistical combination of possible measurable uncertainties (i.e., setting tolerance, drift, temperature effects, and measurement and test equipment). During instrument calibrations, if the as-found setpoint is found to be conservative with respect to the Allowable Value, but outside its acceptable as-found band (tolerance range), as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance witQ the Surveillance. The technician performing the Surveillance will evaluate the instrument's ability to maintain a stable setpoint within the as-left tolerance. The technician's evaluation will be reviewed' by on shift personnel during the approval of the Surveillance data prior to returning the channel back to service at the completion of the Surveillance. This shall constitute the initial determination of operability. If a channel is found to exceed the channel's Allowable Value or cannot be reset within the (continued) BFN-UNIT 1 B 3.3-139 Revision--Q.,-44. November 09, 2006

ECCS Instrumentation B 3.3.5.1 BASES APPLICABLE 1.c, 2.c. Reactor Steam Dome Pressure - Low {Injection SAFETY ANALYSES, Permissive and ECCS Initiation) LCO, and (PIS-3-74A and B; PIS-68-95 and 96) (continued) APPLICABILITY channel's as-found condition will be documented in the Corrective Action Program. As part of the activities of the Corrective Action Program, additional evaluations and potential corrective actions will be performed as necessary to ensure that any as-found setting, which is conservative to the Allowable Value, but outside the acceptable as-found band is evaluated for long-term reliability trends. Four channels of Reactor Steam Dome Pressure - Low Function are only required to be OPERABLE when the ECCS is required to be OPERABLE to ensure that no single instrument failure can preclude ECCS initiation. Refer to LGO 3.5.1 and LGO 3.5.2 f-or Applicability Bases for the low pressure EGGS subsystems. 

                                                  )

(continued) BFN-UNIT 1 B 3.3-141c Revision 4 November 09, 2006

ECCS Instrumentation B 3.3.5.1 BASES APPLICABLE 1.d. Core Spray Pump Discharge Flow - Low (Bypass) SAFETY ANALYSES, (FS-75-21 and 49) LCO, and APPLICABILITY The minimum flow instruments are provided to protect the (continued) associated CS pumps from overheating when the pump is operating and the associated injection valve is not fully open. The minimum flow line valve is opened when low flow is sensed, and the valve is automatically closed when the flow rate is adequate to protect the pump. The CS Pump Discharge Flow - Low Function is assumed to be OPERABLE and capable of closing the minimum flow valves to ensure that the CS flows assumed during the transients and accidents analyzed in References 1, 2, and 3 are met. The core cooling function of the ECCS, along with the scram action of the RPS, ensures that the fuel peak cladding temperature remains below the limits of 10 CFR 50.46. One flow switch per CS subsystem is used to detect the associated subsystems' flow rates. The logic is arranged such that each flow switch causes its associated minimum flow valve to open. The logic will close the minimum flow valve once the closure setpoint is exceeded.* The Pump Discharge Flow - Low Allowable Values are high enough to ensure that the pump flow rate is sufficient to protect the pump, yet low enough (based on engineering judgment) to ensure that the closure of the minimum flow valve is initiated to allow full flow into the core. Each channel of Pump Discharge Flow - Low Function (two CS channels) is only required to be OPERABLE when the associated ECCS is required to be OPERABLE to ensure that no single instrument failure can preclude the ECCS function. Refer to LGO 3.5.1 and LGO 3.5.2 for /\pplicability Bases for the low pressure EGGS subsystems. (continued) BFN-UNIT 1 B 3.3-142 Revision Q.

ECCS Instrumentation B 3.3.5.1 BASES APPLICABLE . 1.e, 2.f. Core Spray and Low Pressure Coolant Injection SAFETY ANALYSES, Pump Start - Time Delay Relay (continued) LCO, and APPLICABILITY Each CS and LPCI Pump Start - Time Delay Relay Function is required to be OPERABLE only when the associated CS and LPCI subsystems are required to be OPERABLE. Refer to LCO 3.5.1 and LCO 3.5.2 for Applicability Bases for the CS and LPCI subsystems. (continued) BFN-UNIT 1 B 3.3-145a Revision 47, 65 May 31, 2012

ECCS Instrumentation B 3.3.5.1 BASES ACTIONS B.1, B.2, and B.3 (continued) subsystems) are inoperable and untripped, and the Completion Times started concurrently for the channels in both subsystems, this results in the affected portions in the associated low pressure ECCS being concurrently declared inoperable. For Required Action B.2, automatic HPCI initiation capability is lost if two or more Function 3.a or two or more Function 3.b channels are inoperable and untripped such that the trip system , loses initiation capability. In this situation (loss of automatic HPCI initiation capability), the 24 hour allowance of Required Action B.3 is not appropriate and the HPCI System must be declared inoperable within 1 hour. As noted (Note 1 to Required Action 8.1), Required Action B.1 is only applicable in MODES 1, 2, and 3. In MODES 4 and 5, the specific initiation time of the lov.' pressure EGGS is not assumed and the probability of a LOG/\ is lov.:er. Thus, a total loss of initiation capability for 24 hours (as allo'Ned by Required Action 8.3) is allowed during MODES 4 and 5. There is no similar Note pro'.'ided for Required Action 8.2 since HPGI instrumentation is not required in MODES 4 and 5; thus, a Note is not necessary. Notes are al-se-provided (the Note ~to Required Action B.1 and the Note to Required Action B.2) to delineate which Required Action is applicable for each Function that requires entry into Condition B if an associated channel is inoperable. This ensures that the proper loss of initiation capability check is performed. Required Action B.1 (the Required Action for certain inoperable channels in the low pressure ECCS subsystems) is not applicable to Function 2.e, since this Function provides backup to administrative controls ensuring that operators do not divert LPCI flow from injecting into the core when needed. Thus, a total loss of Function 2.e capability for 24 hours is allowed, since the LPCI subsystems remain _capable of performing their intended function. (continued) BFN-UNIT 1 B 3.3-161 Revision Q.

ECCS Instrumentation B 3.3.5.1 BASES ACTIONS C.1 and C.2 (continued) Required Action C.1 is intended to ensure that appropriate actions are taken if multiple, inoperable channels within the same Function result in redundant automatic initiation capability being lost for the feature(s). Required Action C.1 features would be those that are initiated by Functions 1.c, 2.c, 1.e, 2.d, and 2.f (i.e., low pressure ECCS). Redundant automatic initiation capability is lost if either (a) four Function 1.c channels are inoperable (i.e., both channels in both trip systems are inoperable), (b) two,or more Function 2.c channels are inoperable such that both trip systems lose initiation capability, (c) two or more Function 2.d channels are inoperable such that both trip systems lose initiation capability, (d) one or more Function 1.e channels are inoperable in both trip systems (i.e., at least one CS pump in both subsystems is affected), or (e) multiple Function 2.f channels are inoperable such that the trip systems cannot start both LPCI pumps in at least one subsystem. In this situation (loss of redundant automatic initiation capability), the 24 hour allowance of Required Action C.2 is not appropriate and the feature(s) associated with the inoperable channels must be declared inoperable within 1 hour. Since each inoperable channel would have Required Action C.1 applied separately (refer to ACTIONS Note), each inoperable channel would only require the affected portion of the associated system to be declared inoperable. However, since channels for both low pressure ECCS subsystems are inoperable (e.g., both CS subsystems), and the Completion Times started concurrently for the channels in both subsystems, this results in the affected portions in both subsystems being concurrently declared inoperable. For Functions 1.c, 2.c, 1.e, 2.d, an.d 2.f, the affected portions are the associated low pressure ECCS pumps. As noted (Note 1), Required Action C.1 is only applicable in MODES 1, 2, and 3. (continued} BFN-UNIT 1 B 3.3-163 Revision Q.

ECCS Instrumentation B 3.3.5.1 BASES ACTIONS C.1 and C.2 (continued) In MODES 4 and 5, the specific initiation time of the EGGS is not assumed and the probability of a LOGA is lo1Ner. Thus, a total loss of automatic initiation capability for 24 hours (as alloi..ved by Required Action G.2) is allmNed during MODES 4 and 5. - - - - - - - - - T h e Note- states that Required Action C.1 is only applicable for Functions 1.c, 2.c, 1.e, 2.d, and 2.f. Required Action C.1 is also not applicable to Function 3.c (which also requires entry into this Condition if a channel in this Function is inoperable). The loss of one Function 3.c channel results in a loss of the Function (two-out-of-two logic). This loss was considered during the development of Reference 4 and considered acceptable for the 24 hours allowed by Required Action C.2. The Completion Time is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This Completion Time also allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." For Required Action C.1, the Completion Time only begins upon discovery that redundant features in the same system (e.g., both CS subsystems) cannot be automatically initiated due to inoperable channels within the same Function as described in the paragraph above. The 1 hour Completion Time from discovery of loss of initiation capability is acceptable because it minimizes risk while allowing time for restoration of channels. (continued) BFN-UNIT 1 B 3.3-164 Revision Q.

ECCS Instrumentation B 3.3.5.1 BASES ACTIONS E.1 and E.2 (continued) Required Action E.1 is intended to ensure that appropriate actions are taken if multiple, inoperable channels within the Core Spray Pump Discharge Flow - Low Bypass Function results in redundant automatic initiation capability being lost for the feature(s). Automatic initiation capability of the Core Spray Pump Discharge Flow - Low (Bypass) Function in both CS subsystems is lost if two Function 1.d channels are inoperable. In this situation (loss of capability for both subsystems), the 7 day allowance of Required Action E.2 is not appropriate and the subsystem associated with each inoperable channel must be declared inoperable within 1 hour. Since each inoperable channel would have Required Action E.1 applied separately (refer to ACTIONS Note), each inoperable channel would only require the affected CS pump to be declared inoperable. However, since channels for both CS subsystems are inoperable, and the completion times started concurrently for both channels this results in all four CS pumps being concurrently declared inoperable. As noted (Note 1 to Required Action E.1), Required Action E.1 is only applicable in MODES 1, 2, and 3. In MODES 4 and 5, the specific initiation time of the EGGS is not assumed and the probability of a LOGA is lower. Thus, a total loss of initiation capability for 7 days (as allO\ved by Required Action E.2) is allov,ed during MODES 4 and 5. A Note is alsG-provided (the Note-'J to Required Action E.1) to delineate that Required Action E.1 is only applicable to Function 1.d. Required Action E.1 is not applicable to HPCI Function 3.f since the loss of one channel results in a loss of the Function (one-out-of-one logic). This loss was considered during the development of Reference 4 and considered acceptable for the 7 days allowed by Required Action E.2. The Completion Time is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This Completion Time also allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." (continued) BFN-UNIT 1 B 3.3-166 Revision Q.

RPV Water Inventory Control Instrumentation 

                                                                  .                B 3.3.5.2 B 3.3 INSTRUMENTATION B 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation BASES BACKGROUND            The RPV contains penetrations below the top of the active fuel (TAF) that have the potential to drain the reactor coolant inventory to below the TAF. If the water level should drop below the TAF. the ability to remove decay heat is reduced. which could lead to elevated cladding temperatures and clad perforation. Safety Limit 2.1.1.3 requires the RPV water level to be above the top of active irradiated fuel at all times to prevent such elevated cladding temperatures.

Technical Specifications are required by 10 CFR 50.36 to include limiting safety system settings (LSSS) for variables that have significant safety functions. LSSS are defined by the regulation as "Where a LSSS is specified for a variable on which a safety limit has been placed, the setting must be chosen so that automatic protective actions will correct the abnormal situation before a Safety Limit (SL) is exceeded." The Analytical Limit is the limit of the process variable at which a safety action is initiated to ensure that a SL is not exceeded. Any automatic protection action that occurs on reaching the Analytical Limit therefore ensures that the SL is not exceeded. However, in practice. the actual settings for automatic protection channels \ must be chosen to be more conservative than the Analytical Limit to account for instrument loop uncertainties related to the setting at which the automatic protective action would actually occur. The actual settings for the automatic isolation channels are the same as those established for the same functions in MODES 1 1 2 1 and 3 in LCO 3.3.5.1 1 "Emergency Core Cooling System (ECCS) Instrumentation," or LCO 3.3.6.1, "Primary Containment Isolation Instrumentation." With the unit in MODE 4 or 5 1 RPV water inventory control is not required to mitigate any events or accidents evaluated in the safety analyses. RPV water inventory control is required in (continued) BFN-UNIT 1 B 3.3-X Revision

( RPV Water Inventory Control Instrumentation B 3.3.5.2 BASES BACKGROUND MODES 4 and 5 to protect Safety Limit 2.1.1.3 and the fuel (continued) cladding barrier to prevent the release of radioactive material should a draining event occur. Under the definition of DRAIN TIME, some penetration flow paths may be excluded from the

  • DRAIN TIME calculation if they will be isolated by valves that will close automatically without offsite power prior to the RPV water level being the TAF when actuated by RPV water level isolation instrumentation.

The purpose of the RPV Water Inventory Control Instrumentation is to support the requirements of LCO 3.5.2, "Reactor Pressure Vessel (RPV) Water Inventory Control," and the definition of DRAIN TIME. There are functions that are required for manual operation of the ECCS injection/spray subsystem required to be OPERABLE by LCO 3.5.2 and other functions that support automatic isolation of the Residual Heat Removal (RHR) Shutdown Cooling system and Reactor Water Cleanup system penetration flow path(s) on low RPV water level. The RPV Water Inventory Control Instrumentation supports operation of core spray (CS) and low pressure coolant injection (LPCI). The equipment involved with each of these systems is described in the Bases for LCO 3.5.2. APPLICABLE With the unit in MODE 4 or 5, RPV water inventory control is not SAFETY ANALYSES, required to mitigate any events or accidents evaluated in the LCO, and safety analyses. RPV water inventory control is required in APPLICABILITY MODES 4 and 5 to protect Safety Limit 2.1.1.3 and the fuel cladding barrier to prevent the release of radioactive material should a draining event occur. A double-ended guillotine break of the Reactor Coolant System (RCS) is not postulated in MODES 4 and 5 due to the reduced RCS pressure, reduced piping stresses, and ductile piping systems. Instead, an event is postulated in which a single operator error or initiating event allows draining of the RPV water inventory through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure . (continued) BFN-UNIT 1 B 3.3-X Revision

RPV Water Inventory Control Instrumentation B 3.3.5.2 BASES APPLICABLE (e.g., seismic event, loss of normal power, single human error). SAFETY ANALYSES, It is assumed, based on engineering judgment, that while in LCO, and MODES 4 and 5, one low pressure ECCS injection/spray APPLICABILITY subsystem can be manually started to maintain adequate (continued) reactor vessel water level. As discussed in References 1, 2, 3. 4. and 5, operating experience has shown RPV water inventory to be significant to public health and safety. Therefore. RPV Water Inventory Control satisfies Criterion 4 of 10 CFR 50.36(c)(2)(ii). Permissive and interlock setpoints are generally considered as nominal values without regard to measurement accuracy. The specific Applicable Safety Analyses, LCO. and Applicability discussions are listed below on a Function by Function basis . 

                . Core Spray and Low Pressure Coolant Injection Systems 1.a. 2.a. Reactor Steam Dome Pressure - Low (Injection Permissive)

Low reactor steam dome pressure signals are used as permissives for the low pressure ECCS injection/spray subsystems. This function ensures that, prior to opening the injection valves of the low pressure ECCS subsystems, the reactor pressure has fallen to a value below these subsystems' maximum design pressure. While it is assured during MODES' 4 and 5 that the reactor steam dome pressure will be below the ECCS maximum design pressure. the Reactor Steam Dome Pressure - Low signals are assumed to be OPERABLE and

  • capable of permitting injection valve opening as part of a manual start of the ECCS.

The Core Spray System Reactor Steam Dome Pressure - Low signals are initiated from two pressure transmitters per subsystem that sense reactor steam dome pressure. The transmitters for each subsystem are connected to two trip units. The outputs of the trip units are connected to relays whose

  • contacts are arranged in a one-out-of-two logic. While four (continued)

BFN-UNIT 1 B 3.3-X Revision

RPV Water Inventory Control Instrumentation B 3.3.5.2 BASES APPLICABLE channels are available, only a single channel per subsystem is SAFETY ANALYSES. required to be OPERABLE. LCO, and APPLICABILITY The Low Pressure Coolant Injection System Reactor Steam (continued) Dome Pressure - Low signals are initiated from four pressure transmitters (two channels in two trip systems) that sense reactor steam dome pressure. Either trip system can fulfill the function with a two-out-of-two logic. Therefore, two channels in one trip system are required to be OPERABLE. The Allowable Value is low enough to prevent overpressuring the equipment in the low pressure ECCS. The channels of Reactor Steam Dome Pressure - Low Function are required to be OPERABLE in MODES 4 and 5 when the, ECCS subsystem is required to be OPERABLE by LCO 3.5.2. 1.b Core Spray Pump Discharge Flow - Low (Bypass) The minimum flow instruments are provided to protect the associated Core Spray pump from overheating when the pump is operating and the associated injection valve is not fully open. The minimum flow line valve is opened when low flow is sensed, and the valve is automatically closed when the flow rate is adequate to protect the pump. One flow switch per Core Spray subsystem is used to detect the subsystem flow rate. The logic is arranged such that the flow switch causes the associated subsystem minimum flow valve to open. The logic will close the minimum flow valve once sufficient flow is achieved. The Core Spray Pump Discharge Flow - Low (Bypass) Allowable Values are high enough to ensure that the pump flow rate is sufficient to protect the pump, yet low enough to ensure that the closure of the minimum flow valve is initiated to allow full flow into the core. (continued) BFN-UNIT 1 B 3.3-X Revision

RPV Water Inventory Control Instrumentation B 3.3.5.2 BASES APPLICABLE One channel of the Core Spray Pump Discharge Flow - Low SAFETY ANALYSES, (Bypass) Function is required to be OPERABLE in MODES 4 LCO, and and 5 when the associated Core Spray pump is required to be APPLICABILITY OPERABLE by LCO 3.5.2 to ensure the pump is capable of (continued) injecting into the Reactor Pressure Vessel when manually started. Shutdown Cooling System Isolation 3.a - Reactor Vessel Water Level - Low, Level 3 The definition of Drain Time allows crediting the closing of penetration flow paths that are capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation. The Reactor Vessel Water Level - Low, Level 3 Function associated with the RHR Shutdown Cooling System isolation may be credited for automatic isolation of penetration flow paths associated with the RHR System. Reactor Vessel Water Level - Low. Level 3 signals are initiated from four level transmitters that sense *the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level (Variable leg) in the vessel. While four channels (two channels per trip system) of the Reactor Vessel Water Level - Low, Level 3 Function are available, only two channels (one channel for trip system A and one channel for trip system B) are required to be OPERABLE. The Reactor Vessel Water Level - Low. Level 3 Allowable Value was chosen to be the same as the Primary Containment Isolation Instrumentation Reactor Vessel Water Level - Low, Level 3 Allowable Value (LCO 3.3.6.1 ). since the capability to - cool the fuel may be threatened. The Reactor Vessel Water Level - Low. Level 3 Function is only required to be OPERABLE when automatic isolation of the associated penetration flow path is credited in calculating DRAIN TIME. This Function isolates the Group 2 valves. (continued) BFN-UNIT 1 B 3.3-X Revision

RPV Water Inventory Control Instrumentation B 3.3.5.2 BASES APPLICABLE Reactor Water Cleanup (RWCU) System Isolation SAFETY ANALYSES, LCO, and 4.a - Reactor Vessel Water Level - Low, Level 3 APPLICABILITY (continued) The definition of Drain Time allows crediting the closing of penetration flow paths that are capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by . RPV water level isolation instrumentation. The Reactor Vessel Water Level - Low, Level 3 Function associated with RWCU System isolation may be credited for automatic isolation of penetration flow paths associated with the RWCU System. Reactor Vessel Water Level - Low, Level 3 signals are initiated from four level transmitters that sense the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level (variable leg) in the vessel. While four channels (two channels per trip system) of the Reactor Vessel Water Level - Low, Level 3 Function are available, only two channels (one channel for trip system A and one channel for trip system B) are required to be OPERABLE .. The Reactor Vessel Water Level - Low, Level 3 Allowable Value was chosen to be the same as the Primary Containment Isolation Instrumentation Reactor Vessel Water Level - Low, Level 3 Allowable Value (LCO 3.3.6.1 ), since the capability to cool the fuel may be threatened. The Reactor Vessel Water Level - Low, Level 3 Function is only required to be OPERABLE when automatic isolation of the associated penetration flow path is credited in calculating DRAIN TIME. This Function isolates the Group 3 valves. (continued) BFN-UNIT 1 B 3.3-X Revision

RPV Water Inventory Control Instrumentation B 3.3.5.2 .BASES ACTIONS A Note has been provided to modify the ACTIONS related to RPVWater Inventory Control instrumentation channels. Section 1.3, Completion Times, specifies that once a Condition has been entered, subsequent divisions. subsystems, components, or variables expressed in the Condition discovered to be inoperable or not within limits will not result in separate entry into the Condition. Section 1.3 also specifies that Required Actions continue to apply for each additional failure, with Completion Times based on initial entry into the Condition. However, the Required Actions for inoperable RPV Water Inventory Control instrumentation channels provide appropriate compensatory measures for separate inoperable Condition entry for each inoperable RPV Water Inventory Control instrumentation channel. 

            . Required Action A.1 directs entry into the appropriate Condition referenced in Table 3.3.5.2-1. The applicable Condition referenced in the Table is Function dependent. Each time a channel is discovered inoperable, Condition A *is entered for that channel and provides for transfer to the appropriate subsequent
  • Condition.

B.1 and B.2 Shutdown Cooling System Isolation, Reactor Vessel Water Level - Low, Level 3, and Reactor Water Cleanup System Isolation, Reactor Vessel Water Level - Low, Level 3 functions are applicable when automatic isolation of the associated penetration flow path is credited in calculating Drain Time. If the

  • instrumentation is inoperable and credited for the DRAIN TIME calculation, Required Action B.1 directs an immediate declaration that the associated penetration flow path(s) are incapable of automatic isolation. Required Action B.2 directs calculation of DRAIN TIME (reference SR 3.5.2.1). The calculation cannot credit automatic isolation of the affected penetration flow paths.

{continued) BFN-UNIT 1 B 3.3-X Revision

RPV Water Inventory Control Instrumentation B 3.3.5.2 'BASES ACTIONS C.1 (continued) Low reactor steam dome pressure signals are used as permissives for manually aligning the low pressure ECCS injection/spray subsystem. If the permissive is inoperable, manual alignment of ECCS is precluded. Therefore, the permissive must be placed in the trip condition within 1 hour. With the permissive in the trip condition, manual alignment may be performed. The Completion Time of 1 hour is intended to allow the operator time to evaluate any discovered inoperabilities and to place the channel in trip. D.1 If a Core Spray Pump Discharge Flow - Low (Bypass) function is inoperable, there is a risk that the associated Core Spray pump could overheat when the pump is operating and the associated injection valve is not fully open. In this condition, the operator can manually secure the pump or open the injection valve to ensure the pump does not overheat, but this is not the preferred condition. The 24 hour Completion Time was chosen to allow time for the operator to evaluate and repair any discovered inoperabilities. The Completion Time is appropriate given the ability to manually secure the Core Spray pump or manually open the injection valve to ensure the pump does not overheat. E.1 With the Required Action and associated Completion Time of Condition C or D not met, the associated low pressure ECCS injection/spray subsystem may be incapable of performing the intended function, and must be declared inoperable immediately. (continued) BFN-UNIT 1 B 3.3-X Revision

RPV Water Inventory Control Instrumentation B 3.3.5.2 BASES SURVIELLANCE As noted in the beginning of the SRs, the SRs for each RPV REQUIREMENTS Water Inventory Control Instrument Function are found in the SRs column of Table 3.3.5.2-1. SR 3.3.5.2.1 Performance of the CHANNEL CHECK ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK guarantees that undetected outright channel failure is limited: thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL FUNCTIONAL TEST. Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit. The frequency of 12 hours is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the channels required by the LCO. SR 3.3.5.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. (continued) BFN-UNIT 1 B 3.3-X Revision

RPV Water Inventory Control Instrumentation B 3.3.5.2 BASES SURVIELLANCE SR 3.3.5.2.2 (continued) REQUIREMENTS Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology. The Frequency of 92 days is based upon operating experience that demonstrates channel failure is rare. REFERENCES 1. Information Notice 84-81 "Inadvertent Reduction in Primary Coolant Inventory in Boiling Water Reactors During Shutdown and Startup," November 1984.

2. Information Notice 86-74, "Reduction of Reactor Coolant Inventory Because of Misalignment of RHR Valves,"

August 1986.

3. Generic Letter 92:..04, "Resolution of the Issues Related to Reactor Vessel Water Level Instrumentation in BWRs Pursuant to 10 CFR 50.54(F), " August 1992.
4. NRC Bulletin 93-03, "Resolution of Issues Related to Reactor Vessel Water Level Instrumentation in BWRs,"

May 1993.

5. Information Notice 94-52, "Inadvertent Containment Spray and Reactor Vessel Draindown at Millstone 1,"

July 1994. (continued) BFN-UNIT 1 B 3.3-185 Revision Q

RCIC System Instrumentation B 3.3.5.~2 B 3.3 INSTRUMENTATION B 3.3.5.~2 Reactor Core Isolation Cooling (RCIC) System Instrumentation BASES BACKGROUND The purpose of the RCIC System instrumentation is to initiate actions to ensure adequate core cooling when the reactor vessel is isolated from its primary heat sink (the main condenser) and normal coolant makeup flow from the Reactor Feedwater System is unavailable, such that initiation of the low pressure Emergency Core Cooling Systems (ECCS) pumps does not occur. A more complete discussion of RCIC System operation is provided in the Bases of LCO 3.5.3, "RCIC System." The RCIC System may be initiated by either automatic or manual means. Automatic initiation occurs for conditions of reactor vessel Low Low water level. The variable is monitored by four transmitters that are connected to four trip units. The outputs of the trip units are connected to relays whose contacts are arranged in a one-out-of-two taken twice logic arrangement. Once initiated, the RCIC logic seals in and can be reset by the operator only when the reactor vessel water level signals have cleared. The RCIC test line isolation valve is closed on a RCIC initiation signal to allow full system flow. There are two sources of water for RCIC operation. Reactor grade water in the CST is the normal source and the suppression pool is the alternate source. Although the RCIC System does not monitor the water levels in the High Pressure Coolant Injection (HPCI) supply header from the condensate (continued) BFN-UNIT 1 B 3.3-176 Revision Q.

RCIC System Instrumentation B 3.3.5.J2: BASES BACKGROUND storage tank (CST) and the suppression pool, administrative (continued)

  • controls are in place that direct the transfer from the CST to the suppression pool when the HPCI System automatically transfers on low HPCI pump supply header level or high suppression pool level.

The RCIC System provides makeup water to the reactor until the reactor vessel water level reaches the high water level (Level 8) trip (two-out-of-two logic), at which time the RCIC steam supply closes and the minimum flow valve closes, if open. The RCIC System restarts if vessel level again drops to the low level initiation point (Level 2). APPLICABLE The function of the RCIC System to provide makeup coolant to SAFETY ANALYSES, the reactor is used to respond to transient events. The LCO, and RCIC System is not an Engineered Safety Feature System and APPLICABILITY no credit is taken in the safety analyses for RCIC System operation. Based on its contribution to the reduction of overall plant risk, however, the system, and therefore its instrumentation meets Criterion 4 of the NRC Policy Statement (Ref. 2). Certain instrumentation Functions are retained for other reasons and are described below in the individual Functions discussion. The OPERABILITY of the RCIC System instrumentation is dependent upon the OPERABILITY of the individual instrumentation channel Functions specified in Table 3.3.5.~2:-1. Each Function must have a required number of OPERABLE channels with their setpoints within the specified Allowable Values, where appropriate. A channel is inoperable if its actual trip setpoint is not within its required Allowable Value. The setpoint is calibrated consistent with applicable setpoint methodology assumptions (nominal trip setpoint). (continued) BFN-UNIT 1 B 3.3-177 Revision Q

RCIC System Instrumentation B 3.3.5.~2 BASES APPLICABLE Allowable Values are specified for each RCIC System . SAFETY ANALYSES, instrumentation Function specified in the Table. Nominal trip LCO, and setpoints are specified in the setpoint calculations and APPLICABILITY contained in design output documents, which for instrument (continued) functions that have a specific footnote in Table 3.3.1.1-1, is incorporated by reference in Chapter 7 of the Updated Final Safety Analysis Report (UFSAR). For these, the methodology used to determine the nominal trip setpoint, the predefined as-found tolerance, the as-left tolerance band, and a listing of the setpoint design output documentation is specified in Chapter 7 of the UFSAR. The nominal setpoints are selected to ensure that the setpoints do not exceed the Allowable Value between CHANNEL CALIBRATIONS. Operation with a trip setpoint less conservative than the nominal trip setpoint, but within its Allowable Value, is acceptable. Each Allowable Value specified accounts for instrument uncertainties appropriate to the Function. These uncertainties are described in the setpoint methodology. The individual Functions are required to be OPERABLE in MODE 1, and in MODES 2 and 3 with reactor steam dome pressure > 150 psig since this is when RCIC is required to be OPERABLE. (Refer to LCO 3.5.3 for Applicability Bases for the RCIC System.) The specific Applicable Safety Analyses, LCO, and Applicability discussions are listed below on a Function by Function basis.

1. Reactor Vessel Water Level - Low Low, Level 2 (LIS-3-58A-D)

Low reactor pressure vessel (RPV) water level indicates that normal feedwater flow is insufficient to maintain reactor vessel water level and that the capability to cool the fuel may be threatened. Should RPV water level decrease too far, fuel damage could result. Therefore, the RCIC System is initiated at Level 2 to assist in maintaining water level above the top of the active fuel. (continued) BFN-UNIT 1 B 3.3-178 Revision Q, November 09, 2006

RCIC System Instrumentation B 3.3.5.~2: BASES APPLICABLE 1. Reactor Vessel Water Level - Low Low, Level 2 SAFETY ANALYSES, (LIS-3-58A-D) (continued) LCO, and APPLICABILITY Reactor Vessel Water Level - Low Low, Level 2 signals are initiated from four level transmitters that sense the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level (variable leg) in the vessel. The Reactor Vessel Water Level - Low Low, Level 2 Allowable Value is set high enough such that for complete loss of feedwater flow, the RCIC System flow with high pressure coolant injection assumed to fail will be sufficient to avoid initiation of low pressure ECCS at Level 1. Four channels of Reactor Vessel Water Level - Low Low, Level 2 Function are available and are required to be OPERABLE when RCIC is required to be OPERABLE to ensure that no single instrument failure can preclude RCIC initiation. Refer to LCO 3.5.3 for RCIC Applicability Bases. For this instrument function, the nominal trip setpoint including the as-left tolerances is defined as the LSSS. The acceptable as-found band is based on a statistical combination of possible measurable uncertainties (i.e., setting tolerance, drift, temperature effects, and measurement and test equipment). During instrument calibrations, if the as-found setpoint is found to be conservative with respect to the Allowable Value, but outside its acceptable as-found band (tolerance range), as defined by its associated Surveillance Requirement procedure, then there shall be an initial determination to ensure confidence that the channel can perform as required before returning the channel to service in accordance with the Surveillance. The technician performing the Surveillance will evaluate the instrument's ability to maintain a stable setpoint within the (continued) BFN-UNIT 1 B 3.3-179 Revision Q,-44 November 09, 2006

RCIC System Instrumentation B 3.3.5.~2 BASES APPLICABLE 1. Reactor Vessel Water Level - Low Low, Level 2 SAFETY ANALYSES, (LIS-3-58A-D) (continued)

  • LCO, and APPLICABILITY as-left tolerance. The technician's evaluation will be reviewed by on shift personnel during the approval of the Surveillance data prior to returning the channel back to service at the completion of the Surveillance. This shall constitute the initial determination of operability. If a channel is found to exceed the channel's Allowable Value or cannot be reset within the acceptable as-left tolerance, the channel shall be declared inoperable. Also, after the Surveillance is completed, the channel's as-found condition will be documented in the Corrective Action Program. As part of the activities of the Corrective Action Program, additional evaluations and potential corrective actions will be performed as necessary to ensure that any as-found setting, which is conservative to the Allowable Value, but outside the acceptable as-found band is evaluated for long-term reliability trends.
2. Reactor Vessel Water Level - High, Level 8 (LIS-3-208A and 208C)

High RPV water level indicates that sufficient cooling water inventory exists in the reactor vessel such that there is no danger to the fuel. Therefore, the Level 8 signal is used to close the RCIC steam supply valve to prevent overflow into the main steam lines (MSLs). Reactor Vessel Water Level - High, Level 8 signals for RCIC are initiated from two level transmitters from the narrow range water level measurement instrumentation, which sense the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level (variable leg) in the vessel. (continued) BFN-UNIT 1 B 3.3-179a Revision 44 November OQ, 2006

RCIC System Instrumentation B 3.3.5.J,2. BASES APPLICABLE 2. Reactor Vessel Water Level - High, Level 8 SAFETY ANALYSES, (LIS-3-208A and 208C) (continued) LCO, and APPLICABILITY The Reactor Vessel Water Level - High, Level 8 Allowable Value is high enough to preclude closing the RCIC steam supply valve, yet low enough to trip the RCIC System prior to water overflowing into the MSLs. Two channels of Reactor Vessel Water Level - High, Level 8 Function are available and are required to be OPERABLE when RCIC is required to be OPERABLE. Refer to LCb 3.5.3 for RCIC Applicability Bases. ACTIONS A Note has been provided to modify the ACTIONS related to RCIC System instrumentation channels. Section 1.3, Completion Times, specifies that once a Condition has been entered, subsequent divisions, subsystems, components, or variables expressed in the Condition discovered to be inoperable or not within limits will not result in separate entry into the Condition. Section 1.3 also specifies that Required Actions of the Condition continue to apply for each additional failure, with Completion Times based on initial entry into the Condition. However, the Required Actions for inoperable RCIC System instrumentation channels provide appropriate compensatory measures. for separate inoperable channels. As such, a Note has been provided that allows separate Condition entry for each inoperable RCIC System instrumentation channel. (continued) BFN-UNIT 1 B 3.3-180 Revision 0

RCIC System Instrumentation 8 3.3.5.J2 BASES ACTIONS A.1 (continued) Required Action A.1 directs entry into the appropriate Condition referenced in Table 3.3.5.J~1. The applicable Condition referenced in the Table is Function dependent. Each time a channel is discovered to be inoperable, Condition A is entered for that channel and provides for transfer to the appropriate subsequent Condition. 8.1 and 8.2 Required Action 8.1 is intended to ensure that appropriate actions are taken if multiple, inoperable, untripped channels within the same Function result in a complete loss of automatic initiation capability for the RCIC System. In this situation (loss of automatic initiation capability), the 24 hour allowance of Required Action 8.2 is not appropriate, and the RCIC System must be declared inoperable within 1 hour after discovery of loss of RCIC initiation capability. The Completion Time is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This Completion Time also allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." For Required Action 8.1, the Completion Time only begins upon discovery that the RCIC System cannot be automatically initiated due to two or more inoperable, untripped Reactor Vessel Water Level - Low Low, Level 2 channels such that the trip system loses initiation capability. The 1 hour Completion Time from discovery of loss of initiation capability is acceptable because it minimizes risk while allowing time for restoration or tripping of channels. (continued) 8FN-UNIT 1 8 3.3-181 Revision Q.

RCIC System Instrumentation B 3.3.5.~2 BASES ACTIONS B.1 and B.2 (continued) Because of the redundancy of sensors available to provide initiation signals and the fact that the RCIC System is not assumed in any accident or transient analysis, an allowable out of service time of 24 hours has been shown to be acceptable (Ref. 1) to permit restoration of any inoperable channel to OPERABLE status. For conservatism, in some transient analyses, RCIC flow rates were used rather than HPCI flow rates. If the inoperable channel cannot be restored to OPERABLE status within the allowable out of service time, the channel must be placed in the tripped condition per Required Action B.2. Placing the inoperable channel in trip would conservatively compensate for the inoperability, restore capability to accommodate a single failure, and allow operation to continue. Alternately, if it is not desired to place the channel in trip (e.g., as in the case where placing the inoperable channel in trip would result in an initiation), Condition D must be entered and its Required Action taken. A risk based analysis was performed and determined that an allowable out of service time of 24 hours (Ref. 1) is acceptable to permit restoration of any inoperable channel to OPERABLE status (Required Action C.1 ). A Required Action (similar to Required Action B.1) limiting the allowable out of service time, if a loss of automatic RCIC initiation capability exists, is not required. This Condition applies to the Reactor Vessel Water Level - High, Level 8 Function whose logic is arranged such that any inoperable channel will result in a loss of automatic RCIC initiation capability. As stated above, this loss of automatic RCIC initiation capability was analyzed and determined to be acceptable. The Required Action does not allow placing a channel in trip since this action would not necessarily result in a safe state for the channel in all events. (continued) BFN-UNIT 1 B 3.3-182 Revision G

RCIC System Instrumentation B 3.3.5.~2: BASES ACTIONS (continued) With any Required Action and associated Completion Time not met, the RCIC System may be incapable of performing the intended function, and the RCIC System must be declared inoperable immediately. SURVEILLANCE As noted in the beginning of the SRs, the SRs for each RCIC REQUIREMENTS System instrumentation Function are found in the SRs column of Table 3.3.5.~~1. The Surveillances are modified by a Note to indicate that 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 as follows: (a) for up to 6 hours for Function 2; and (b) for up to 6 hours for Function 1, provided the associated Function maintains trip capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Ref. 1) assumption of the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the RCIC will initiate when necessary. (continued) BFN-UNIT 1 B 3.3-183 Revision Q

RCIC System Instrumentation B 3.3.5.J2 BASES SURVEILLANCE SR 3.3.5.32.1 REQUIREMENTS (continued) Performance of the CHANNEL CHECK once every 24 hours ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a parameter on other similar channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit. The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the channels required by the LCO. (continued) BFN-UNIT 1 B 3.3-184 Revision Q

RCIC System Instrumentation B 3.3.5.~2 BASES SURVEILLANCE SR 3.3.5.32.2 REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology. The Frequency of 92 days is based on the reliability analysis of Reference 1. SR 3.3.5.32.3 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology. The Frequency of SR 3.3.5.2~.3 is based upon the assumption . I of a 24 month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis. (continued) BFN-UNIT 1 B 3.3-185 Revision~ January 17, 2007

RCIC System Instrumentation B 3.3.5.~2 BASES SURVEILLANCE SR 3.3.5.32.4 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.5.3 overlaps this Surveillance to provide complete testing of the safety function. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience with these components supports performance of the Surveillance at the 24 month Frequency. REFERENCES 1. GENE-770-06-2, "Addendum to Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.

2. NRC No. 93-102, "Final Policy Statement on Technical Specification Improvements," July 23, 1993.

BFN-UNIT 1 B 3.3-186 Revision Q,--43 January 17, 2007

Primary Containment Isolation Instrumentation B 3.3.6.1 BASES APPLICABLE 6.b. Reactor Vessel Water Level - Low, Level 3 SAFETY ANALYSES, (LIS-3-203A-D) LCO, and APPLICABILITY Low RPV water level indicates that the capability to cool the (continued) fuel may be threatened. Should RPV water level decrease too far, fuel damage could result. Therefore, isolation of some reactor vessel interfaces occurs to begin isolating the potential sources of a break. The Reactor Vessel Water Level - Low, Level 3 Function associated with RHR Shutdown Cooling System isolation is not directly assumed in safety analyses because a break of the RHR Shutdown Cooling System is bounded by breaks of the recirculation and MSL. The RHR Shutdown Cooling System isolation on Level 3 supports actions to ensure that the RPV water level does not drop below the top of the active fuel during a vessel draindown event caused by a leak (e.g., pipe break or inadvertent valve opening) in the RHR Shutdown Cooling System. Reactor Vessel Water Level - Low, Level 3 signals are initiated from four level transmitters that sense the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level (variable leg) in the vessel. Four channels (two channels per trip system) of the Reactor Vessel Water Level - Low, Level 3 Function are available and are 'required to be OPERABLE to ensure that no single instrument failure can preclude the isolation function. -As-noted (footnote (b) to Table 3.3.6.1 1), only tiNo channels of the Reactor Vessel Water Level Low , Level 3 Function (one channel for PCIS trip system A and one channel for PCIS trip system B) with the capability of isolating one RHR SOC supply isolation valve are required to be OPERABLE in MODES 4 and 5, provided the RHR Shutdown Cooling System integrity is maintained. System integrity is maintained provided the piping is intact and no maintenance is being performed that has the potential for draining the reactor vessel through the system. (continued) BFN-UNIT 1 B 3.3-209 Revision 9

Primary Containment Isolation Instrumentation B 3.3.6.1 BASES APPLICABLE 6.b. Reactor Vessel Water Level - Low, Level 3 SAFETY ANALYSES, (LIS-3-203A-D) (continued) LCO, and APPLICABILITY The Reactor Vessel Water Level - Low, Level 3 Allowable Value was chosen to be the same as the RPS Reactor Vessel Water Level - Low, Level 3 Allowable Value (LCO 3.3.1.1 ), since the capability to cool the fuel may be threatened. The Reactor Vessel Water Level - Low, Level 3 Function is only required to be OPERABLE in MODES 3, 4, and 5 to prevent the potential flow paths from lowering the reactor vessel level to the top of the fuel. In MODES 1 and 2, other isolation Functions are required to be OPERABLE (i.e., Reactor Steam Dome Pressure - High and Drywell Pressure - High) and administrative controls for the flow paths prevent unexpected loss of inventory via these flow paths. This Function is required for the isolation of the Group 2 RHR LPCI to Reactor and RHR SDC Supply isolation valves. . Portions of this instrumentation are also required for Functions 2.a and 5.h. 6.c. Drywell Pressure - High (PIS-64-56A-D) High drywell pressure can indicate a break in the RCPB inside the primary containment. The isolation of some of the primary containment isolation valves on high drywell pressure supports actions to ensure that offsite dose limits of 10 CFR 50.67 are not exceeded. The Drywell Pressure - High Function, associated with isolation of the primary containment, is implicitly assumed in the FSAR accident analysis as these leakage paths are assumed to be isolated post LOCA. (continued) BFN-UNIT 1 B 3.3-210 Revision Q-,--2-9 January 25, 2005

Primary Containment Isolation Instrumentation B 3.3.6.1 BASES ACTIONS 1.1 and 1.2 (continued) If the channel is not restored to OPERABLE status or placed in trip within the allowed Completion Time, the associated penetration flow path(s) should be closed. However, if the shutdown cooling function is needed to provide core cooling, these Required Actions allow the penetration flow path(s) to remain unisolated provided action is immediately initiated to restore the channel to OPERABLE status or to isolate the RHR Shutdown Cooling System (i.e., provide alternate decay heat removal capabilities so the penetration flow path(s) can be isolated). Actions must continue until the channel is restored to OPERABLE status.:. or the RHR Shutdo1.vn Cooling System is isolated. SURVEILLANCE As noted (Note 1) at the beginning of the SRs, the SRs for REQUIREMENTS each Primary Containment Isolation instrumentation Function are found in the SRs column of Table 3.3.6.1-1. The Surveillances are modified by a Note (Note 2) to indicate that 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 hours provided the associated Function maintains trip capability. Upon completion of the Surveillance, or expiration of the 6 hour allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Refs. 5 and 6) assumption of the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour testing allowance does not significantly reduce the probability that the PCIVs will isolate the penetration flow path(s) when necessary. (continued) BFN-UNIT 1 B 3.3-218 Revision 0

Secondary Containment Isolation Instrumentation B 3.3.6.2 BASES APPLICABLE 1. Reactor Vessel Water Level- Low, Level 3 SAFETY ANALYSES, (LIS-3-203A-D) (continued) LCO, and APPLICABILITY these MODES; thus, this Function is not required. In addition, the Function is also required to be OPERABLE during operations 1Nith a potential for draining the reactor vessel (OPDRVs) because the capability of isolating potential sources of leakage must be provided to ensure that offsite dose limits are not exceeded if core damage occurs.

2. Drywell Pressure - High (PIS-64-56A-D)

High drywell pressure can indicate a break in the reactor coolant pressure boundary (RCPB). An isolation of the secondary containment and actuation of the SGT System are initiated in order to minimize the potential of an offsite dose release. The isolation on high drywell pressure supports actions to ensure that any offsite releases are within the limits calculated in the safety analysis. However, the Drywell Pressure - High Function associated with isolation is not assumed in any FSAR accident or transient analyses. It is retained for the overall redundancy and diversity of the secondary containment isolation instrumentation as required by the NRG approved licensing basis. High drywell pressure signals are initiated from pressure transmitters that sense the pressure in the drywell. These signals are the same that isolate the primary containment (additional information on the arrangement of these channels in the PCIS trip systems can be found in the Bases for LCO 3.3.6.1, "Primary Containment Isolation Instrumentation," Function 2). Four channels of Drywell Pressure - High Functions are available and are required to be OPERABLE to ensure that no single instrument failure can preclude performance of the isolation function. (continued) BFN-UNIT 1 B 3.3-227 Revision 9

Secondary Containment Isolation Instrumentation B 3.3.6.2 BASES APPLICABLE 3, 4. Reactor Zone Exhaust and Refueling Floor Radiation - SAFETY ANALYSES, High (RM-90-140, 141, 142, 143) (continued) LCO, and APPLICABILITY ventilation exhaust both of which must be OPERABLE or tripped for the channel to be OPERABLE. Both radiation elements must provide a High signal to trip the associated channel (two-out-of-two). However, the output relays from the divisional trip systems are arranged in logic systems such that if either channel for a zone trips, a secondary containment isolation signal is initiated (one-out-of-two). Six channels of Reactor Zone Exhaust Radiation - High Function and six channels of Refueling Floor Radiation - High Function are available (two channels of each Function from each unit) and are required to be OPERABLE to ensure that no single instrument failure can preclude the isolation function. The Allowable Values are chosen to provide timely detection of nuclear system process barrier leaks inside containment but are far enough above background levels to avoid spurious isolation. The Reactor Zone Exhaust and Refueling Floor Radiation - High Functions are required to be OPERABLE in MODES 1, 2, and 3 where considerable energy exists; thus, there is a probability of pipe breaks resulting in significant releases of radioactive steam and gas. In MODES 4 and 5, the probability and consequences of these events are low due to the RCS pressure and temperature limitations of these MODES; thus, these Functions are not required. In addition, the Functions are also required to be OPERABLE during OPDRVs because the capability of detecting radiation releases due to fuel failures (due to fuel uncovery) must be provided to ensure that offsite dose limits are not exceeded. (continued) BFN-UNIT 1 B 3.3-229 Revision 0, 21, 29, 35 February 14, 2006

CREV System Instrumentation B 3.3.7.1 BASES APPLICABLE The specific Applicable Safety Analyses, LCO, and Applicability SAFETY ANALYSES, discussions are listed below on a Function by Function basis. LCO, and APPLICABILITY 1. Reactor Vessel Water Level- Low, Level 3 (LIS-3-203A-D) (continued) Low reactor pressure vessel (RPV) water level indicates that the capability of cooling the fuel may be threatened. A low reactor vessel water level could indicate a LOCA and will automatically initiate the CREV System, since this could be a precursor to a potential radiation release and subsequent radiation exposure to control room personnel. Reactor Vessel Water Level - Low, Level 3 signals are initiated from four level transmitters that sense the difference between the pressure due to a constant column of water (reference leg) and the pressure due to the actual water level (variable leg) in the vessel. Four channels of Reactor Vessel Water Level - Low, Level 3 Function are available (two channels per trip system) and are required to be OPERABLE to ensure that a single instrument failure cannot preclude CREV System initiation. The Reactor Vessel Water Level - Low, Level 3 allowable value was chosen to be the same as the RPS Level 3 scram allowable value (LCO 3.3.1.1 ). The Reactor Vessel Water Level - Low, Level 3 Function is required to be OPERABLE in MODES 1, 2, and 3, and during operations with a potential for draining the reactor vessel (OPDRVs) to ensure that the control room personnel are protected during a LOCA. In MODES 4 and 5 at times other than OPDRVs, the probability of a vessel draindmrm event resulting in a release of radioactive material into the environment is minimal. In addition, adequate protection is performed by the Control Room Air Supply Duct Radiation - High Function. Therefore, this Function is not required in other MODES and specified conditions. (continued) BFN-UNIT 1 B 3.3-240 Revision Q.

CREV System Instrumentation B 3.3.7.1 BASES APPLICABLE 3., 4. Reactor Zone Exhaust and Refueling Floor SAFETY ANALYSES, Radiation - High (RM-90-140, 141, 142, 143) LCO, and APPLICABILITY High secondary containment exhaust radiation is an indication (continued) of possible gross failure of the fuel cladding. The release may have originated from the primary containment due to a break in the RCPB. A reactor zone or refueling floor exhaust high radiation signal will automatically initiate the CREV System, since this radiation release could result in radiation exposure to control room personnel. The reactor zone and refueling floor exhaust radiation monitors provide two independent channels for each ventilation exhaust path coming from the reactor zones and the refueling zone. There are two radiation monitors (each monitor provides one channel of each Function) and two divisional trip systems for each unit (Units 1, 2, and 3). Six channels of each function are available (two channels of each Function from each unit) and are required to be OPERABLE to ensure that no single instrument failure can preclude CREV System initiation. The 

                .Allowable Value was selected to ensure that the Function will promptly detect high activity that could threaten exposure to control room personnel.

The Reactor Zone Exhaust and Refueling Floor Radiation - High Functions are required to be OPERABLE in MODES 1, 2, and 3 and during operations *.vith a potential for draining the reactor vessel (OPDRVs), to ensure that control room personnel are protected during a LOCA or vessel draindown event. During MODES 4 and 5, when these specified conditions are not in progress (e.g., OPDRVs), the probability of a LOCA or fuel damage is low; thus, the Function is not required. (continued) BFN-UNIT 1 B 3.3-242 Revision 0, 29, 35 February 14, 2006

CREV System Instrumentation B 3.3.7.1 BASES APPLICABLE 5. Control Room Air Supply Duct Radiation - High SAFETY ANALYSES, (RM-90-259A and B) LCO, and APPLICABILITY The control room air supply duct radiation monitors measure (continued) radiation levels in normal control room air supply ducts. A high radiation level may pose a threat to CR personnel; thus, the CREV System is automatically initiated on a control room air supply duct high radiation signal. The Control Room Air Supply Duct Radiation - High Function consists of two independent monitors. Two channels of Control Room Air Supply Duct Radiation - High are available and are required to be OPERABLE to ensure that no single instrument failure can preclude CREV System initiation. The Allowable Value was selected to ensure protection of the control room personnel. The Control Room Air Supply Duct Radiation - High Function is required to be OPERABLE in MODES 1, 2, and 3 and during OPDRVs to ensure that control room personnel are protected during a LOCA or vessel draindown event. During MODES 4 and 5, when these specified conditions are not in progress (e.g., OPDRVs), the probability of a LOCA or fuel damage is low; thus, the Function is not required. (continued) BFN-UNIT 1 B 3.3-243 Revision 4-,-2-9 January 25, 2005

ECCS - Operating B 3.5.1 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM B 3.5.1 ECCS - Operating BASES BACKGROUND The ECCS are designed, in conjunction with the primary and secondary containment, to limit the release of radioactive materials to the environment following a loss of coolant accident (LOCA). The ECCS uses two independent methods (flooding and spraying) to cool the core during a LOCA. The ECCS network consists of the High Pressure Coolant Injection (HPCI) System, the Core Spray (CS) System, the low pressure coolant injection (LPCI) mode of the Residual Heat Removal (RHR) System, and the Automatic Depressurization System (ADS). The suppression pool provides the required source of water for the ECCS. Although no credit is taken in the safety anaJyses for the condensate storage tank (CST), it is capable of providing a source of water for the HPCI, RHR and CS systems. The ECCS design requirements ensure that the criteria of Reference 12 are satisfied. On receipt of.an initiation signal, ECCS pumps automatically start; simultaneously, the system aligns and the pumps inject water, taken either from the CST or suppression pool, into the Reactor Coolant System (RCS) as RCS pressure is overcome by the discharge pressure of the ECCS pumps. Although the system is initiated, ADS action is delayed, allowing the operator to interrupt the timed sequence if the system is not needed. The HPCI pump discharge pressure almost immediately exceeds that of the RCS, and the pump injects coolant into the vessel to cool the core. If the break is sm'all, the HPCI System will maintain coolant inventory as well as vessel level while the (continued) BFN-UNIT 1 B 3.5-1 Revision Q.

ECCS - Operating B 3.5.1 BASES LCO LPCI subsystems may be considered OPERABLE during (continued) alignment and operation for decay heat removal when below the actual RHR low pressure permissive pressure in MODE 3, if capable of being manually realigned (remote or local) to the LPCI mode and not otherwise inoperable. At these low pressures and decay heat levels, a reduced complement of ECCS subsystems should provide the required core cooling, thereby allowing operation of RHR shutdown cooling when necessary. APPLICABILITY All ECCS subsystems are required to be OPERABLE during MODES 1, 2, and 3, when there is considerable energy in the reactor core and core cooling would be required to prevent fuel damage in the event of a break in the primary system piping. In MODES 2 and 3, when reactor steam dome pressure is 

             ~ 150 psig, ADS and HPCI are not required to be OPERABLE because the low pressure ECCS subsystems can provide sufficient flow below this pressure. EGGS rRequirements for MODES 4 and 5 are specified in LCO 3.5.2, "RPV Water Inventory ControlECCS Shutdown."

ACTIONS A Note prohibits the application of LCO 3.0.4 b to an inoperable HPCI subsystem. There is an increased risk associated with entering a MODE or other specified condition in the Applicability with an inoperable HPCI subsystem and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance. (continued) BFN-UNIT 1 B 3.5-8 Amendment No. 240, 249 

                                                                    . Revision O December 1, 2003

RPV Water Inventory ControlECCS Shutdovm B 3.5.2 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM B 3.5.2 Reactor Pressure Vessel (RPV) Water Inventory ControlECCS Shutdown BASES BACKGROUND The RPV contains penetrations below the top of active fuel (TAF) that have the potential to drain the reactor coolant inventory to below the TAF. If the water level should drop below the TAF, the ability to remove decay heat is reduced, which could lead to elevated cladding temperatures and clad perforation. Safety Limit 2.1.1.3 requires the RPV water level to be above the top of the active irradiated fuel at all times to prevent such elevated cladding temperatures.A description of the Core Spray (CS) System and the low pressure coolant injection (LPCI) mode of the Residual Heat Removal (RHR) System is provided in the Bases for LCO 3.5.1, "EGGS Operating." For LGO 3.5.2, only one pump is required for an OPERABLE subsystem, as stated in the LGO Bases belmv. APPLICABLE With the unit in MODE 4 or 5, RPV water inventory control is notThe EGGS performance is evaluated for the entire spectrum ef SAFETY ANALYSES required to mitigate any events or accidents*evaluated in the safety analyses. RPV water inventory control is required in MODES 4 and 5 to protect Safety Limit 2.1.1.3 and the fuel cladding barrier to prevent the release of radioactive material to the environment should an unexpected draining event occur. A double-ended guillotine break of the Reactor Coolant System (RCS) is not postulated in MODES 4 and 5 due to the reduced RCS pressure, reduced piping stresses, and ductile piping systems. Instead; an event is considered in which single operator error or initiating event allows draining of the RPV water inventory through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human (continued) BFN-UNIT 1 B 3.5-23 Revision 9

RPV Water Inventory ControlECCS Shutdm'l.'n B 3.5.2 error).break sizes in the long term cooling analysis (Ref. 1) for a postulated loss of coolant accident (LOCA). The EGGS requirements are significantly reduced during shutdovm since a LOG/\ is not postulated to occur. Ho*.&.1e*1er, some EGGS capability may be required to restore and maintain the reactor coolant level in the event of an inadvertent draindown. It is reasonable to assumeg, based on engineering judgment, that while in MODES 4 and 5, one low pressure ECCS injection/spray subsystem can maintain adequate reactor vessel water level.:. in the event of an inadvertent vessel draindov.:n. To provide redundancy, a minimum of two low pressure EGGS injection/spray subsystems are required to be OPERABLE in MODES 4 and 5. As discussed in References 1, 2, 3, 4, and 5, operating experience has shown RPV water inventory to be significant to public health and safety. Therefore, RPV Water Inventory Control satisfies Criterion 4 of 10 CFR 50.36(c)(2)(ii).The low pressure EGGS subsystems s.atisfy Criterion 3 of the NRG Policy Statement (Ref. 2). , (continued) BFN-UNIT 1 B 3.5-23 Revision Q I.

RPV Water Inventory ControlECCS Shutdown B 3.5.2 BASES (continued) LCO The RPV water level must be controlled in MODES 4 and 5 to ensure that if an unexpected draining event should occur, the reactor coolant water level remains above the top of the active irradiated fuel as required by Safety Limit 2.1.1.3. The Limiting Condition for Operation (LCO) requires the DRAIN TIME of RPV water inventory to the TAF to be;::: 36 hours. A DRAIN TIME of 36 hours is considered reasonable to identify and initiate action to mitigate unexpected draining of reactor coolant. An event that could cause loss of RPV water inventory and result in the RPV water level reaching the TAF in greater than 36 hours does not represent a significant challenge to Safety Limit 2.1.1.3 and can be managed as part of normal plant operation. One +we-low pressure ECCS injection/spray subsystems is are-- required to be OPERABLE and capable of being manually started to provide defense-in-depth should an unexpected draining event occur. A+J::\e low pressure ECCS injection/spray subsystems includeconsists of either one:.._Core S' (CS) subsystems oraru:1- one Low Pressure Coolant Injection (LPCll subsystems. Each CS subsystem consists of one motor driven pump, piping, and valves to transfer water from the suppression pool to the reactor pressure vessel (RPVt. Each LPCI subsystem consists of one motor driven pump, piping, and valves to transfer water from the suppression pool to the RPV. The necessary portions of the Emergency Equipment Cooling Water System are also required to provide adequate cooling to each required ECCS subsystem. The LCO is modified by a Note which allows a required AR-LPCI subsystem tomay be aligned for decay heat removal and considered OPERABLE for the ECCS function, if it can be manually realigned (remote or local) to the LPCI mode and is not otherwise inoperable. Because of the restrictions on DRAIN TIME, sufficient time will be available following an unexpected draining event lmN pressure and low temperature conditions in MODES 4 and 5, sufficient time will be available to manually align and initiate LPCI subsystem operation to maintain RPV (continued) BFN-UNIT 1 B 3.5-24 Revision G,--4e March 14, 2007

RPV Water Inventory Control EGGS Shutdown B 3.5.2 water inventory prior to the RPV water level reaching the TAF'"" to provide core eooling prior to postulated fuel uncovery. APPLICABILITY RPV water inventory control is required in MODES 4 and 5. Requirements on water inventory control in other MODES are contained in LCOs in Section 3.3, "Instrumentation," and other LCOs in Section 3.5, "Emergency Core Cooling Systems (ECCS), RPV Water Inventory Control, and Reactor Core Isolation Cooling (RCIC) System." RPV water inventory control is required to protect Safety Limit 2.1.1.3 which is applicable whenever irradiated fuel is in the reactor vessel.OPERABILITY of the lo*N pressure EGGS injection/spray subsystems is required in MODES 4 and 5 to ensure adequate coolant inventory and sufficient heat removal capability for the irradiated fuel in the core in case of an inadvertent draindown of the vessel. Requirements for EGGS OPERABILITY during MODES 1, 2, and 3 arc discussed in the Applicability section of the Bases for LGO 3.5.1. EGGS subsystems are not required to be OPERABLE during MODE 5 '#ith the spent fuel storage pool gates removed and the water level maintained at > 22 ft above the RPV flange. This provides suffieient eoolant inventory to allmv operator aetion to terminate the inventory loss prior to fuel uneovery in ease of an inadvertent draindown. {continued) BFN-UNIT 1 B 3.5-24 Revision Q,4e Marsh 14, 2007

RPV Water Inventory ControlECCS Shutdown B 3.5.2 BASES APPLICABILITY The Automatic Depressurization System is not required to be (continued) OPERABLE during MODES 4 and 5 because the RPV pressure is< 150 psig, and the CS System and the LPCI subsystems can provide core cooling without any depressurization of the primary system. The High Pressure Coolant Injection System is not required to be OPERABLE during MODES 4 and 5 since the low pressure EGGS injection/spray subsystems can provide sufficient flow to the vessel. ACTIONS A.1 and 8.1 If anythe-GRe required low pressure ECCS injection/spray subsystem is inoperable, !!_the inoperable subsystem must be restored to OPERABLE status within 4 hours. In this condition, the LCO controls on DRAIN TIME minimize the possibility that an unexpected draining event could necessitate the use of the ECCS injection/spray subsystem, however the defense-in-depth provided by the ECCS injection/spray subsystem is lost.#le-remaining OPERABLE subsystem can provide sufficient vessel flooding capability to recover from an inadvertent vessel draindovm. However, overall system reliability is reduced because a single failure in the remaining OPERABLE subsystem concurrent *.vith a vessel draindoi.*m could result in the EGGS not being able to perform its intended function. The 4 hour Completion Time for restoring the required low pressure ECCS injection/spray subsystem to OPERABLE status is based on engineering judgment that consider.§.ed- the LCO controls on DRAIN TIME the remaining available subsystem_-and the low probability of an unexpected draining a vessel draindm.\*n event_ that would result in loss of RPV water inventory. (continued) BFN-UNIT 1 B 3.5-25 Revision 0

RPV Water Inventory ControlECCS Shutdown B 3.5.2 BASES ACTIONS A.1 and B.1 (continued) Wi-th-!f the inoperable ECCS injection/spray subsystem !§_not restored to OPERABLE status within the required Completion Time, action must be initiated immediately initiated to establish a method of water injection capable of operating without offsite electrical power. The method of water injection includes the necessary instrumentation and controls, water sources, and pumps and valves needed to add water to the RPV or refueling cavity should an unexpected draining event occur. The method of water injection may be manually initiated and may consist of one or more systems or subsystems, and must be able to access water inventory capable of maintaining the RPV water level above the TAF for;:;: 36 hours. If recirculation of injected water would occur, it may be credited in determining the necessary water volume.suspend operations with a potential for draining the reactor vessel (OPDRVs) to minimize the probability of a vessel draindown and the subsequent potential for fission product release. Actions must continue until OPDRVs are suspended. C.1 C.2 and C.3 With the DRAIN TIME less than 36 hours but greater than or equal to 8 hours, compensatory measures should be taken to ensure the ability to implement mitigating actions should an unexpected draining event occur. Should a draining event lower the reactor coolant level to below the TAF, there is potential for damage to the reactor fuel cladding and release of radioactive material. Additional actions are taken to ensure that radioactive material will be contained, diluted, and processed prior to being released to the environment. The secondary containment provides a controlled volume in which fission products can be contained, diluted, and processed prior to release to the environment. Required Action C.1 requires Verification of the capability to establish the secondary containment boundary in less than the DRAIN TIME. The required verification confirms actions to establish the secondary (continued) BFN-UNIT 1 B 3.5-26 Revision Q:

RPV Water Inventory ControlECCS Shutdown B 3.5.2 BASES ACTIONS C.1, C.2, and C.3 (continued) containment boundary are preplanned and necessary materials are available. The secondary containment boundary is considered established when two Standby Gas Treatment (SGT) subsystems are capable of maintaining a negative pressure in the secondary containment with respect to the environment. Verification that the secondary containment boundary can be established must be performed within 4 hours. The required verification is an administrative activity and does not require manipulation or testing of equipment. Secondary containment penetration flow paths form a part of the secondary containment boundary. Required Action C.2 requires verification of the capability to isolate each secondary containment penetration flow path in less than the DRAIN TIME. The required verification confirms actions to isolate the secondary containment penetration flow paths are preplanned and necessary materials are available. Power operated valves are not required to receive automatic isolation signals if they can be closed manually within the required time. Verification that the secondary containment penetration flow paths can be isolated must be performed within 4 hours. The required verification is an administrative activity and does not require manipulation or testing of equipment. Two SGT subsystems are capable of maintaining the secondary containment at a negative pressure with respect to the environment and filter gaseous releases. Required Action C.3 requires verification of the capability to place two SGT subsystems in operation in less than the DRAIN TIME. The required verification confirms actions to place the SGT subsystems in operation are preplanned and necessary materials are available. Verification that the SGT subsystems can be placed in operation must be performed within 4 hours. (continued) BFN-UNIT 1 B 3.5-26 Revision Q

RPV Water Inventory ControlECCS Shutdo\\'n B 3.5.2 BASES ACTIONS C.1, C.2, and C.3 (continued) The required verification is an administrative activity and does not require manipulation or testing of equipment. Required Actions C.1, C.2, and C.3 are considered to be met when Secondary Containment, Secondary Containment Isolation Valves, and the Standby Gas Treatment System are OPERABLE. D.1, D.2 1 D.3, and D.4 With the DRAIN TIME less than 8 hours, mitigating actions are implemented in case an unexpected draining event should occur. Note that if the DRAIN TIME is less than 1 hour, Required Action E.1 is also applicable. Required Action D.1 requires immediate action to establish an additional method of water injection augmenting the ECCS injection/spray subsystem required by the LCO. The additional method of water injection includes the necessary instrumentation and controls, water sources, and pumps and valves needed to add water to the RPV or refueling cavity should an unexpected draining event occur. The Note to Required Action D.1 states that either the ECCS injection/ 

          §.P.@Y subsystem or the additional method of water injection must be capable of operating without offsite electrical power.

The additional method of water injection may be manually initiated and may consist of one or more systems or subsystems. The additional method of water injection must be able to access water inventory capable of being injected to maintain the RPV water level above the TAF for :2:: 36 hours. The additional method of water injection and the ECCS injection/spray subsystem may share all or part of the same water sources. If recirculation of injected water would occur. it may be credited in determining the required water volume. (continued} BFN-UNIT 1 B 3.5-26 Revision Q.

RPV Water Inventory Control EGGS Shutdovm B 3.5.2 BASES ACTIONS D.1, D.2, D.3, and D.4 (continued) Should a draining event lower the reactor coolant level to below the TAF, there is potential for damage to the reactor fuel cladding and release of radioactive material. Additional actions are taken to ensure that radioactive material will be contained, diluted, and processed prior to being released to the environment. The secondary containment provides a control volume in which fission products can be contained, diluted, and processed prior to release to the environment. Required Action D.2 requires that actions be immediately initiated to establish the secondary containment boundary. With the secondary containment boundary established, two SGT subsystems are capable of maintaining a negative pressure in the secondary containment with respect to the environment. The secondary containment penetrations form a part of the secondary containment boundary. Required Action D.3 requires that actions be immediately initiated to verify that each secondary containment penetration flow path is isolated or to verify that it can be automatically or manually isolated from the control room. Two SGT subsystems are capable of maintaining the secondary containment at a negative pressure with respect to the environment and filter gaseous releases. Required Action D.4 requires that actions be immediately initiated to verify that at least two SGT subsystems are capable of being placed in operation. The required verification is an administrative activity and does not require manipulation or testing of equipment. Required Actions D.2, D.3, and D.4 are considered to be met when Secondary Containment, Secondary Containment Isolation Valves, and the Standby Gas Treatment System are OPERABLE. (continued) BFN-UNIT 1 B 3.5-26 Revision 0

RPV Water Inventory ControlECCS Shutdown B 3.5.2

  • BASES ACTIONS E.1 If the Required Actions and associated Completion Times of Conditions C or Dare not met or if the DRAIN TIME is less than 1 hour, actions must be initiated immediately to restore the DRAIN TIME to~ 36 hours. In this condition, there may be insufficient time to respond to an unexpected draining event to prevent the RPV water inventory from reaching the TAF. Note that Required Actions D.1, D.2, D.3, and D.4 are also applicable when DRAIN TIME is less than 1 hour.

C.1, C.2, D.1, D.2, and D.3 VVith both of the required EGGS injection/spray subsystems inoperable, all coolant inventory makeup capability may be unavailable. Therefore, actions must immediately be initiated to suspend OPDRVs to minimize the probability of a vessel draindown and the subsequent potential for fission product release. Actions must continue until OPDRVs are suspended. One EGGS injection/spray subsystem must also be restored to OPERABLE status 1.nithin 4 hours. If at least one low pressure EGGS injection/spray subsystem is not restored to OPERABLE status v1ithin the 4 hour Completion Time, additional actions are required to minimize any potential fission product release to the environment. This includes ensuring secondary containment is OPERABLE; two standby gas treatment subsystems are OPERABLE; and secondary containment isolation capability (i.e., one isolation valve and associated instrumentation are OPERABLE or other acceptable administrative controls to assure isolation capability) in each associated penetration flow path not isolated that is assumed to be isolated to mitigate radioactivity releases. OPERABILITY may be verified by an administrative check, or by examining (continued) BFN-UNIT 1 B 3.5-26 Revision G

RPV Water Inventory ControlECCS Shutdown B 3.5.2 BASES ACTIONS C.1, C.2, D.1, D.2, and D.3 (continued) logs or other information, to determine whether the components are out of service for maintenance or other reasons. It is not necessary to perform the Surveillances needed to demonstrate the OPERABILITY of the components. If, hov.*ever, any required component is inoperable, then it must be restored to OPERABLE status. In this case, the Surveillance may need to be performed to restore the component to OPERABLE status. Actions must continue until all required components are OPERABLE. The 4 hour Completion Time to restore at least one low pressure EGGS injection/spray subsystem to OPERABLE status ensures that prompt action \!Jill be taken to provide the required cooling capacity or to initiate actions to place the plant in a condition that minimizes any potential fission product release to the environment. SURVEILLANCE SR 3.5.2.1 REQUIREMENTS This Surveillance verifies that the DRAIN TIME of RPV water inventory to the TAF is > 36 hours. The period of 36 hours is considered reasonable to identify and initiate action to mitigate draining of reactor coolant. Loss of RPV water inventory that would result in the RPV water level reaching the TAF in greater than 36 hours does not represent a significant challenge to Safety Limit 2.1.1.3 and can be managed as part of normal plant operation. The definitior:1 of DRAIN TIME states that realistic cross-sectional areas and drain rates are used in the calculation. A realistic drain rate may be determined using a single, step-wise, or integrated calculation considering the changing RPV water level during a draining event. For a Control Rod RPV penetration flow path with the Control Rod Drive Mechanism removed and not replaced with a blank flange, the realistic _ cross-sectional area is based on the control rod blade seated in (continued) BFN-UNIT 1 B 3.5-27 Revision 0

RPV Water Inventory ControlECCS Shutdovm B 3.5.2 the control rod guide tube. If the control rod blade will be raised from the penetration to adjust or verify seating of the blade, the exposed cross- sectional area of the RPV penetration flow path is used. The definition of DRAIN TIME excludes from the calculation those penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are locked, sealed, or otherwise secured in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths. A blank flange or other bolted device must be connected with a sufficient number of bolts to prevent draining in the event of an Operating Basis Earthquake. Normal or expected leakage from closed systems or past isolation devices is permitted. Determination that a system is intact and closed or isolated must consider the status of branch lines and ongoing plant maintenance and testing activities. The Residual Heat Removal (RHR) Shutdown Cooling System is only considered an intact closed system when misalignment issues (Reference 6) have been precluded by functional valve interlocks or by isolation devices, such that redirection of RPV water out of an RHR subsystem is precluded. The exclusion of penetration flow paths from the determination of DRAIN TIME must consider the potential effects of a single operator error or initiating event on items supporting maintenance and testing (rigging, scaffolding, temporary shielding, piping plugs, snubber removal, freeze seals, etc.). If failure of such items could result and would cause a draining event from a closed system or between the RPV and the isolation device, the penetration flow path may not be excluded from the DRAIN TIME calculation. Surveillance Requirement 3.0.1 requires SRs to be met between performances. Therefore, any changes in plant conditions that would change the DRAIN TIME requires that a new DRAIN TIME be determined. (continued) BFN-UNIT 1 B 3.5-27 Revision Q

RPV Water Inventory ControlECCS Shutdovm B 3.5.2 The Frequency of 12 hours is sufficient in view of indications of RPV water level available to the operator. SR 3.5.2.2 The minimum water level of-6.25 inches with or-7.25 inches without differential pressure control, as indicated on narrow range instrumentation, required for the suppression pool is periodically verified to ensure that the suppression pool will provide adequate net positive suction head (NPSH) for the CS. subsystem System andor LPCI subsystem pumps, recirculation volume, and vortex prevention. With the suppression pool water level less than the required limit, all ECCS injection/spray subsystems are inoperable. (continued) BFN-UNIT 1 B 3.5-27 Revision G

RPV Water Inventory ControlECCS Shutdoi.em B 3.5.2 BASES SURVEILLANCE SR 3.5.2.24 (continued) REQUIREMENTS The 12 hour Frequency of these SRs was developed considering operating experience related to suppression pool water level variations and instrument drift during the applicable MODES. Furthermore, the 12 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal suppression pool water level condition. SR 3.5.2.2, SR 3.5.2.4, and SR 3.5.2.5 The Bases provided for SR 3.5.1.1, SR 3.5.1.6, and SR 3.5.1.9 are applicable to SR 3.5.2.2, SR 3.5.2.4, and SR 3.5.2.5, respectively. SR 3.5.2.3 The flow path piping has the potential to develop voids and pockets of entrained air. Maintaining the pump discharge lines of the required ECCS injection/spray subsystems full of water ensures that the ECCS subsystem will perform properly. This may also prevent a water hammer following a manual ECCS initiation. One acceptable method of ensuring that the lines are full is to vent at the high points. The 31 day Frequency is based on the gradual nature of void buildup in the ECCS piping, the procedural controls governing system operation, and operating experience. SR 3.5.2.4~ Verifying the correct alignment for manual, power operated, and automatic valves in the required ECCS subsystem flow paths provides assurance that the proper flow paths will be available ffiE.ist....for ECCS operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an initiation signal is (continued) BFN-UNIT 1 B 3.5-28 Revision Q

RPV Water Inventory ControlECCS Shutdmr.in B 3.5.2 allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. The 31 day Frequency is appropriate because the valves are operated under procedural control and the probability of their being mispositioned during this time period is low. (continued} BFN-UNIT 1 B 3.5-28 Revision 0

RPV Water Inventory ControlECCS Shutdown B 3.5.2 BASES SURVEILLANCE SR 3.5.2.43 (continued) REQUIREMENTS In MODES 4 and 5, the RFIR System may operate in the sh1:Jtdm.vn cooling mode to remove decay heat and sensible heat from the reactor. Therefore, RFIR valves that are req1:Jired. for LPCI s1:Jbsystem operation may be aligned for decay heat removal. Therefore, this SR is modified by a ~Jote that allows one LPGI s1:Jbsystem of the RFIR System to be considered OPERABLE for the EGGS f1:Jnction if all the req1:Jired valves in the LPGI flm.v path can be man1:Jally realigned (remote or local) to allow injection into the RP'/, and the system is not otherwise inoperable. This will ens1:Jre adeq1:Jate core cooling if an inadvertent RPV draindm.vn sho1:Jld occ1:Jr. SR 3.5.2.5 Verifying that the required ECCS injection/spray subsystem can be manually started and operate for at least 10 minutes demonstrates that the subsystem is available to mitigate a draining event. Testing the ECCS injection/spray subsystem through the test return line is necessary to avoid overfilling the refueling cavity. The minimum operating time of 10 minutes was based on engineering judgement. The performance frequency of 92 days is consistent with similar at-power testing

  • required by SR 3.5.1.6.

SR 3.5.2.6 Verifying that each valve credited for automatically isolating a penetration flow path actuates to the isolation position 6n an actual or simulated RPV water level isolation signal is required to prevent RPV water inventory from dropping below the T AF should an unexpected draining event occur. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint. BFN-UNIT 1 B 3.5-29 Revision 0

RPV Water Inventory ControlECCS Shutdown B 3.5.2 SR 3.5.2.7 The required ECCS subsystem is required to have a manual start capability. The ECCS subsystem is verified-to start manually from a standby configuration. The 24 month Frequency is based on the need to perform the Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint. This SR is modified by a Note that excludes vessel injection/spray during the Surveillance. Since all active components are testable and full flow can be demonstrated by recirculation through the test return line, coolant injection into the RPV is not required during the Surveillance. REFERENCES 1. 'NEDC 32484P, "Brovms Ferry Nuelear Plant Units 1, 2, and 3, "SAFER/GESTR LOCA Loss of Coolant Aeeident Analysis," February 1996.

2. NRG No. 93 102, "Final Poliey Statement on Teehnieal Speeifieation Improvements," July 23, 1993.
1. Information Notice 84-81 "Inadvertent Reduction in Primary Coolant Inventory in Boiling Water Reactors During Shutdown and Startup," November 1984.
2. Information Notice 86-74, "Reduction of Reactor Coolant Inventory Because of Misalignment of RHR Valves,"

August 1986.

3. Generic Letter 92-04, "Resolution of the Issues Related to Reactor Vessel Water Level Instrumentation in BWRs Pursuant to 10 CFR 50.54(F}z " August 1992.

BFN-UNIT 1 B 3.5-29 Revision Q

RPV Water Inventory ControlECCS Shutdown B 3.5.2

4. NRC Bulletin 93-03, "Resolution of Issues Related to Reactor Vessel Water Level Instrumentation in BWRs."

May 1993.

5. Information Notice 94-52. "Inadvertent Containment Spray and Reactor Vessel Draindown at Millstone 1," July 1994.
6. General Electric Service Information Letter No. 388, "RHR Valve Misalignment During Shutdown Cooling Operation for BWR 3/4/5/6," February 1983.

BFN-UNIT 1 B 3.5-29 Revision 0

RCIC System B 3.5.3 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM B 3.5.3 RCIC System BASES BACKGROUND The RCIC System is not part of the ECCS; however, the RCIC System is included with the ECCS section because of their similar functions. The RCIC System is designed to operate either automatically or manually following reactor pressure vessel (RPV) isolation accompanied by a loss of coolant flow from the feedwater system to provide adequate core cooling and control of the RPV water level. Under these conditions, the High Pressure Coolant Injection (HPCI) and RCIC systems perform similar functions. The RCIC System design requirements ensure that the criteria of Reference 1 are satisfied. The RCIC System (Ref. 2) consists of a steam driven turbine pump unit, piping, and valves to provide steam to the turbine, as well as piping and valves to transfer water from the suction source to the core via the feedwater system line, where the coolant is distributed within the RPV through the feedwater sparger. Suction piping is provided from the condensate storage tank (CST) and the suppression pool. Pump suction is normally aligned to the CST to minimize injection of suppression pool water into the RPV. However, if the CST water supply is low, or the suppression pool level is high, a manual transfer to the suppression pool water source ensures a water supply for continuous operation of the RCIC System. With RCIC taking suction from the condensate storage tank and injecting to the reactor vessel, there is sufficient inventory in the tank such that the high suppression pool level suction transfer will be required before a low condensate header level would be created. The steam supply to the turbine is piped from a main steam line upstream of the associated inboard main steam line isolation valve. (continued) BFN-UNIT 1 B 3.5-30 Revision a August 17, 1QQQ

RCIC System B 3.5.3 BASES (continued) LCO The OPERABILITY of the RCIC System provides adequate core cooling such that actuation of any of the low pressure ECCS subsystems is not required in the event of RPV isolation accompanied by a loss of feedwater flow. The RCIC System has sufficient capacity for maintaining RPV inventory during an isolation event. APPLICABILITY The RCIC System is required to be OPERABLE during MODE 1, and MODES 2 and 3 with reactor steam dome pressure> 150 psig, since RCIC is the primary non-ECCS water source for core cooling when the reactor is isolated and pressurized. In MODES 2 and 3 with reactor steam dome pressure ~ 150 psig, the low pressure ECCS injection/spray subsystems can provide sufficient flow to the RPV. In and in MODES 4 and 5, RCIC is not required to be OPERABLE since it is a steam-driven system and RPV water inventory control is required by LCO 3.5.2 1 "RPV Water Level Inventory Control." the low pressure EGGS injection/spray subsystems can provide sufficient flov.* to the RP\'. ACTIONS A Note prohibits the application of LCO 3.0.4.b to an inoperable RCIC system. There is an increased risk associated with entering a MODE or other specified condition in the Applicability with an inoperable RCIC system and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance. (continued) BFN-UNIT 1 B 3.5-32 Amendment No. 249 Revision 0 December 1 , 2003

RCIC System 8 3.5.3 BASES SURVEILLANCE SR 3.5.3.5 REQUIREMENTS (continued) The RCIC System is required to actuate automatically in order to perform its design function satisfactorily. This Surveillance verifies that, with a required system initiation signal (actual or simulated), the automatic initiation logic of the RCIC System will cause the system to operate as designed, including actuation of the system throughout its emergency operating sequence; that is, automatic pump startup and actuation of all automatic valves to their required positions. This test also ensures the RCIC System will automatically restart on an RPV low-low water level (Level 2) signal received subsequent to an RPV high water level (Level 8) trip. The LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.J~ overlaps this Surveillance to provide complete testing of the assumed safety function. The 24 month Frequency is based on the need to perform the Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience with these components supports performance of the Surveillance at the 24 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint. This SR is modified by a Note that excludes vessel injection during the Surveillance. Since all active components are testable and full flow can be demonstrated by recirculation through the test line, coolant injection into the RPV is not required during the Surveillance. (continued) BFN-UNIT 1 8 3.5-51 Revision~ January 17, 2007

PCIVs B 3.6.1.3 BASES LCO MSIVs must meet additional leakage rate requirements. Other (continued) PCIV leakage rates are addressed by LCO 3.6.1.1, "Primary _Containment," as Type B or C testing. This LCO provides assurance that the PCIVs will perform their designed safety functions to minimize the loss of reactor coolant inventory and establish the primary-containment boundary during accidents. APPLICABILITY In MODES 1, 2, and 3, a DBA could cause a release of radioactive material to primary containment. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES. Therefore, mest-PCIVs are not required to be OPERABLE and the primary containment purge valves are not required to be closed in MODES 4 and 5. Certain valves, hmNever, are required to be OPERABLE to prevent inadvertent reactor vessel draindown. These valves are those i..*,hose associated instrumentation is required to be OPERABLE per LCO 3.3.6.1, "Primary Containment Isolation Instrumentation." (This does not include the valves that isolate the associated instrumentation.) ACTIONS The ACTIONS are modified by a Note allowing penetration flow path(s) except for purge valve flow path(s) to be unisolated intermittently under administrative controls. These controls consist of stationing a dedicated operator at the controls of the valve, who is in continuous communication with the control (continued) BFN-UNIT 1 B 3.6-22 Revision 0

PCIVs B 3.6.1.3 BASES ACTIONS D.1 (continued) With any MSIV leakage rate not within limits, the assumptions of the safety analysis may not be met. Therefore, the leakage must be restored to within limits within 4 hours. Restoration can be accomplished by isolating the penetration that caused the limit to be exceeded by use of one closed and de-activated automatic valve, closed manual valve, or blind flange. When a penetration is isolated, the leakage rate for the isolated penetration is assumed to be the actual pathway leakage through the isolation device. If two isolation devices are used to isolate the penetration, the leakage rate is assumed to be the lesser actual pathway leakage of the two devices. The 4 hour Completion Time is reasonable considering the time required to restore the leakage by isolating the penetration and the relative importance to the overall containment function. E.1 and E.2 If any Required Action and associated Completion Time cannot be met in MODE 1, 2, or 3, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. {continued) BFN-UNIT 1 B 3.6-28 Revision 0

PCIVs B 3.6.1.3 BASES ACTIONS F.1 and F.2 (continued) If any Required Action and associated Completion Time cannot be met for PCIVs required to be OPERABLE during MODE 4 or 5, the unit must be placed in a condition in 'Nhich the LCO does not apply. If applicable, action must be immediately initiated to suspend operations with a potential for draining the reactor vessel (OPDRVs) to minimize the probability of a vessel draindm.~.*n and subsequent potential for fission product release. Actions must continue until OPDRVs are suspended and valve(s") are restored to OPERABLE status. If suspending an OPDRV 1Nould result in closing the residual heat removal (RHR) shutdovm cooling isolation valves, an alternative Required Action is provided to immediately initiate action to restore the valve(s) to OPERABLE status. Required Action F.2 is modified by a Note that specifies this alternative action is only applicable for inoperable RHR shutdown cooling valves. This allows RHR shutdown cooling to remain in service while actions are being taken to restore the valve. SURVEILLANCE SR 3.6.1.3.1 REQUIREMENTS This SR ensures that the primary containment purge valves are closed as required or, if open, open for an allowable reason. If a purge valve is open in violation of this SR, the valve is considered inoperable. The SR is modified by a Note stating that the SR is not required to be met when the purge valves are open for the stated reasons. The Note states that these valves may be opened for inerting, de-inerting, pressure control, ALARA or air quality considerations for personnel entry, or Surveillances that require the valves to be open. The 18 and 20 inch purge valves are capable of closing in the environment (continued) BFN-UNIT 1 B 3.6-29 Revision Q.

Suppression Pool Water Level B 3.6.2.2 BASES (continued) LCO A limit that suppression pool water level be ~ -6.25 inches with and -7.25 inches without differential pressure control and 

                 ~ -1.0 inches is required to ensure that the primary containment conditions assumed for the safety analyses are met. Either the high or low water level limits were used in the safety analyses, depending upon which is more conservative for a particular calculation.

APPLICABILITY a In MODES 1, 2, and 3, DBA would cause significant loads on the primary containment. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations in these MODES. The requirements for maintaining suppression pool water level within limits in MODE 4 or 5 is addressed in LCO 3.5.2, "RPV Water Inventory ControlECCS Shutdm.*vn.:.".,. ACTIONS With suppression pool water level outside the limits, the conditions assumed for the safety analyses are not met. If water level is below the minimum level, the pressure suppression function still exists as long as main vents are covered, HPCI and RCIC turbine exhausts are covered, and S/RV quenchers are covered. If suppression pool water level is above the maximum level, protection against overpressurization still exists due to the margin in the peak containment pressure analysis and the capability of the Drywall Spray System. Therefore, continued operation for a limited time is allowed. The 2 hour Completion Time is sufficient to restore suppression pool water level to within limits. Also, it takes into account the low probability of an event impacting the suppression pool water level occurring during this interval. (continued) BFN-UNIT 1 B 3.6-66 Revision Q.

Secondary Containment B 3.6.4.1 BASES (continued) APPLICABILITY In MODES 1, 2, and 3, a LOCA could lead to a fission product release to primary containment that leaks to secondary containment. Therefore, secondary containment OPERABILITY is required during the same operating conditions that require primary containment OPERABILITY. In MODES 4 and 5, the probability and consequences of the LOCA are reduced due to the pressure and temperature limitations in these MODES. Therefore, maintaining secondary containment OPERABLE is not required in MODE 4 or 5 to ensure a control volume.:, except for other situations for which significant releases of radioactive material can be postulated, such as during operations with a potential for draining the reactor vessel (OPDRVs). ACTIONS If secondary containment is inoperable, it must be restored to OPERABLE status within 4 hours. The 4 hour Completion Time provides a period of time to correct the problem that is commensurate with the importance of maintaining secondary containment during MODES 1, 2, and 3. This time period also ensures that the probability of an accident (requiring secondary containment OPERABILITY) occurring during periods where secondary containment is inoperable is minimal. (continued) BFN-UNIT 1 B 3.6-103 Revision Q,-2-9 January 25, 2005

Secondary Containment B 3.6.4.1 BASES ACTIONS B.1 and B.2 (continued) If secondary containment cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. OPDRVs can be postulated to cause fission product release to the secondary containment. In such cases, the secondary containment is the only barrier to release of fission products to the environment. Action must be immediately initiated to suspend OPDRVs to minimize the probability of a vessel draindmvn and subsequent potential for fission product release. Actions must continue until OPDRVs are suspended. (continued) BFN-UNIT 1 B 3.6-104 Revision~ January 25, 2005

SCIVs B 3.6.4.2 BASES (continued) APPLICABILITY In MODES 1, 2, and 3, a LOCA could lead to a fission product release to the primary containment that leaks to the secondary containment. Therefore, the OPERABILITY of SCIVs is required. In MODES 4 and 5, the probability and consequences of these events are reduced due to pressure and temperature limitations in these MODES. Therefore, maintaining SCIVs OPERABLE is not required in MODE 4 or 5.:., exsept for other situations under whish significant radioactive releases san be postulated, sush as during operations 11.1ith a potential for draining the reactor vessel (OPDRVs). ACTIONS The ACTIONS are modified by three Notes. The first Note allows penetration flow paths to be unisolated intermittently under administrative controls. These controls consist of stationing a dedicated operator, who is in continuous 

                 . communication with the control room, at the controls of the isolation device. In this way, the penetration can be rapidly isolated when a need for secondary containment isolation is indicated.

The second Note provides clarification that for the purpose of this LCO separate Condition entry is allowed for each penetration flow path. This is acceptable, since'the Required Actions for each Condition provide appropriate compensatory actions for each inoperable SCIV. Complying with the Required Actions may allow for continued operation, and subsequent inoperable SCIVs are governed by subsequent Condition entry and application of associated Required Actions. (continued) BFN-UNIT 1 B 3.6-109 Revision Q,--2-9 January 25, 2005

SCIVs B 3.6.4.2 BASES ACTIONS C.1 and C.2 (continued) If any Required Action and associated Completion Time of Condition A or B cannot be met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. D.1 If any Required Action and associated Completion Time are not met, the plant must be placed in a condition in 'Nhich the LCO does not apply. Action must be immediately initiated to suspend OPDRVs in order to minimize the probability of a vessel draindov.m and the subsequent potential for fission product release. Actions must continue until OPDRVs are suspended. (continued) BFN-UNIT 1 B 3.6-112 Revision Q,--2,8 January 25, 2005

SGT System B 3.6.4.3 BASES (continued) APPLICABLE The design basis for the SGT System is to mitigate the SAFETY ANALYSES consequences of a loss of coolant accident (Ref. 3). For the loss of coolant accident, the SGT System is shown to be automatically initiated to reduce, via filtration and adsorption, the radioactive material released to the environment. The SGT System satisfies Criterion 3 of the NRC Policy Statement (Ref. 4). LCO Following a DBA, a minimum of two SGT subsystems are required to maintain the secondary containment at a negative pressure with respect to the environment and to process gaseous releases. Meeting the LCO requirements for three OPERABLE subsystems ensures operation of at least two SGT subsystems in the event of a single active failure. APPLICABILITY In MODES 1, 2, and 3, a DBA could lead to a fission product release to primary containment that leaks to secondary containment. Therefore, SGT System OPERABILITY is required during these MODES. In MODES 4 and 5, the probability and consequences of these events are reduced due to the pressure and temperature limitations in these MODES. Therefore, maintaining the SGT System in OPERABLE status is not required in MODE 4 or 5s-except for other situations under VJhich significant releases of radioactive*material can be postulated, such as during operations 'Nith a potential for draining the reactor vessel (OPDRVs). (continued) BFN-UNIT 1 B 3.6-116 Revision-Q..,-2-9 January 25, 2005

SGT System B 3.6.4.3 BASES (continued) ACTIONS With one SGT subsystem inoperable, the inoperable subsystem must be restored to OPERABLE status in 7 days. In this Condition, the remaining two OPERABLE SGT subsystems are* adequate to perform the required radioactivity release control function. However, the overall system reliability is reduced because a single failure in the OPERABLE subsystem could result in the radioactivity release control function not being adequately performed. The 7 day Completion Time is based on consideration of such factors as the availability of the remaining two OPERABLE redundant SGT subsystems and the low probability of a DBA occurring during this period. 8.1 and B.2 If the SGT subsystem cannot be restored to OPERABLE status within the required Completion Time in MODE 1, 2, or 3, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours and to MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. (continued) BFN-UNIT 1 B 3.6-117 Revision Q.

SGT System B 3.6.4.3 BASES ACTIONS G.1 aRd G.2 (continued) DuriRg OPDRVs, wheR Reeiuired /\otioR A.1 oaRROt lae eompleted \'JithiR the reeiuired Completion Time, the two OPERABLE SGT subsystems should immediately be plaeed iR opOFation. This aetioR eRsures that the remainiRg subsystems are OPeR/\BLE, tl=lat RO failures that sould prevent automatie aetuatioR have oeeurred, and that aRy other failure i.uould be readily detested. An alterRative to Reeiuired AotioR G.1 is to immediately suspend aetivities that represent a poteRtial for releasing radioaetive material to the sesoRdary oontaiRmeRt, thus plaoing the plaRt iR a eoRditioR that miRimizes risk. /\etioR must immediately be iRitiated to suspeRd OPDRVs iR order to minimize the probability of a vessel draiRdowR aRd sulaseeiuent poteRtial for fissioR produot release. /\otioRs must ooRtinue until OPDRVs are suspended. {continued) BFN-UNIT 1 B 3.6-118

  • Revision~

January 25, 2005

SGT System B 3.6.4.3 BASES ACTIONS (continued) If two or more SGT subsystems are inoperable in MODES 1, 2, or 3, the SGT system may not be capable of supporting the required radioactivity release control function. Therefore, actions are required to enter LCO 3.0.3 immediately. VVhen tv..*o SGT subsystems are inoperable, if applicable, actions must immediately be initiated to suspend OPDRVs in order to minimize the probability of a vessel draindown and subsequent potential for fission product release. Actions must continue until OPDRVs are suspended. (continued) BFN-UNIT 1 B 3.6-119 Revision G,-2-9 January 25, 2005 I

CREV System B 3.7.3 BASES (continued) APPLICABILITY In MODES 1, 2, and 3, the CREV System must be OPERABLE to ensure that the CRE will remain habitable during and following a OBA, since the OBA could lead to a fission product release. In MODES 4 and 5, the probability and consequences of a OBA are reduced because of the pressure and temperature limitations in these MODES. Therefore, maintaining the CREV System OPERABLE is not required in MODE 4 or 5.:., except for during operations with potential for draining the reactor vessel (OPDRVs). ACTIONS With one CREV subsystem inoperable, for reasons other than an inoperable CRE boundary, or inoperable HEPA filter or inoperable charcoal adsorbers (which do not impact the ability of the CREV subsystems to meet flowrate requirements specified in the VFTP), the inoperable CREV subsystem must be restored to OPERABLE status within 7 days. With the unit in this condition, the remaining OPERABLE CREV subsystem is adequate to perform the CRE occupant protection function. However, the overall reliability is reduced because a failure in the OPERABLE subsystem could result in loss of the CREV System function. The 7 day Completion Time is based on the low probability of a OBA occurring during this time period, and that the remaining subsystem can provide the required capabilities. {continued) BFN-UNIT 1 B 3.7-20 Revision 0, 29, 67 Amendment No. 2-J'!6, 27§ Al:J§ust 10, 201'2

CREV System B 3.7.3 BASES ACTIONS D.1 (continued) which has determined that the CRE 30 day dose after the DBA does not exceed 5 rem (TEDE) without credit for either the HEPA filter or the charcoal adsorbers, and the capability of the remaining OPERABLE CREV subsystem. E.1 and E.2 In MODE 1, 2, or 3, i!f the inoperable CREV subsystem or the CRE boundary cannot be restored to OPERABLE status within the required Completion Time, the unit must be placed in a MODE that minimizes accident risk. To achieve this status, the unit must be placed in at least MODE 3 within 12 hours and in MODE 4 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. i;.1 and i;.2 D1:1ring OPDRVs, if the inoperaele GREV s1:1esystem eannot ee restored to OPERABLE stat1:1s \'Jithin the req1:1ired Completion Time, the OPERABLE GREV s1:1esystem may ee plaeed in the press1:1rization n,ode. Tl=lis aetion ens1:1res tl=lat the remaining suesysten, is OPERABLE, that no fail1:1res that would prevent automatie aet1:1ation will oss1:1r, and that any astive failure '.'Viii ee readily detested. 

          /\n alternative to Req1:1ired /\etion F1 is to in,n,ediately initiate astions to s1:1spend OPDRVs to n1inin1i2:e the proeability of a vessel draindmvn and U10 suesequent potential for fission prod1:1st release. /\etions m1:1st eontin1:1e 1:1ntil the OPDRVs are s1:1spended.

(continued) BFN-UNIT 1 B 3.7-22 Revision 0, 29, 67 Amendment No. 246,275 August 10, 2012

CREV System B 3.7.3 BASES ACTIONS (continued) If both CREV subsystems are inoperable in MODE 1, 2, or 3 for reasons other than Condition B or Condition C, the CREV System may not be capable of performing the intended function and the unit is in a condition outside the accident analyses. Therefore, LCO 3.0.3 must be entered immediately. During OPDRVs, a) with two GREV subsystems inoperable for reasons other than an inoperable HEPA filter or inoperable charcoal adsorbers, b) 'Nith one or more GREV subsystems inoperable due to an inoperable CRE boundary, or c) if the HEPA filter and charcoal adsorbers can not be restored to OPERABLE status within the reEtuired Completion Time, actions must be initiated immediately to suspend OPDRVs to minimize the probability of a 1Jessel draindovm and subsequent potential for fission product release. Actions must continue until the OPDRVs are suspended. (continued) BFN-UNIT 1 B 3.7-23 Revision 0, 29, 67 Amendment No. 246,275 August 10, 2012

Control Room AC System B 3.7.4 BASES (continued) APPLICABILITY In MODE 1, 2, or 3, the Control Room AC System must be OPERABLE to ensure that the control room temperature will not exceed equipment OPERABILITY limits following control room isolation. In MODES 4 and 5, the probability and consequences of a Design Basis Accident are reduced due to the pressure and temperature limitations in these MODES. Therefore, maintaining the Control Room AC System OPERABLE is not required in MODE 4 or 5, except for the following situations under which significant radioactive releases can be postulated:

a. During operations with a potential for draining the reactor vessel (OPDRVs);

g_b. During CORE ALTERATIONS; and Q.G. During movement of irradiated fuel assemblies in the secondary containment. ACTIONS With one Unit 1 and 2 control room AC subsystem inoperable, the inoperable Unit 1 and 2 control room AC subsystem must be restored to OPERABLE status within 30 days. With the unit in this condition, the remaining OPERABLE Unit 1 and 2 control room AC subsystem is adequate to perform the Unit 1 and 2 control room air conditioning function. However, the overall reliability is reduced because a single failure in the OPERABLE subsystem could result in loss of the Unit 1 and 2 control room air conditioning function. The 30 day Completion Time is based on the low probability of an event occurring requiring control room isolation, the consideration that the remaining subsystem can provide the required protection, and the availability of alternate safety and nonsafety cooling methods. (continued) BFN-UNIT 1 B 3.7-28 Revision Q.

Control Room AC System B 3.7.4 BASES ACTIONS D.1, D.2.1, and D.2.2, and D.2.3 (continued) The Required Actions of Condition D are modified by a Note indicating that LCO 3.0.3 does not apply. If moving irradiated fuel assemblies while in MODE 1, 2, or 3, the fuel movement is independent of reactor operations. Therefore, inability to suspend movement of irradiated fuel assemblies is not sufficient reason to require a reactor shutdown. During movement of irradiated fuel assemblies in the secondary containment, or during CORE ALTERATIONS, or during OPDRVs, if Required Action A.1 cannot be completed within the required Completion Time, the OPERABLE Unit 1 and 2 control room AC subsystem may be placed immediately in operation. This action ensures that the remaining subsystem is OPERABLE, that no failures that would prevent actuation will occur, and that any active failure will be readily detected. An alternative to Required Action D.1 is to immediately suspend activities that present a potential for releasing radioactivity that might require isolation of the control room. This places the unit in a condition that minimizes risk. If applicable, CORE ALTERATIONS and movement of irradiated fuel assemblies in the secondary containment must be suspended immediately. Suspension of these activities shall not preclude completion of movement of a component to a safe position. Also, if applicable, aetions must be initiated immediately to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential for fission product release. Aetions must continue until the OPDRVs are suspended. (continued) BFN-UNIT 1 B 3.7-30 Revision Q

AC Sources - Shutdown B 3.8.2 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.2 AC Sources - Shutdown BASES BACKGROUND A description of the AC sources is provided in the Bases for LCO 3.8.1, "AC Sources - Operating." APPLICABLE The OPERABILITY of the minimum AC sources during SAFETY ANALYSES MODES 4 and 5 and during movement of irradiated fuel assemblies in the secondary containment ensures that:

a. The facility can be maintained in the shutdown or refueling condition for extended periods;
b. Sufficient instrumentation and control capability is available for monitoring and maintaining the unit status; and
c. Adequate AC electrical power is provided to mitigate events postulated during shutdown, such as an inadvertent draindovm of the vessel or a fuel handling accident.

In general, when the unit is shut down the Technical Specifications requirements ensure that the unit has the capability to mitigate the consequences of postulated accidents. However, assuming a single failure and concurrent loss of all offsite or loss of all onsite power is not required. The rationale for this is based on the fact that many Design Basis Accidents (DBAs) that are analyzed in MODES 1, 2, and 3 have no specific analyses in MODES 4 and 5. Worst case bounding events are deemed not credible in MODES 4 and 5 because the (continued) BFN-UNIT 1 B 3.8-39 Revision Q.

AC Sources - Shutdown B 3.8.2 BASES APPLICABLE In the event of an accident during shutdown, this LCO ensures SAFETY ANALYSES the capability of supporting systems necessary for avoiding (continued) immediate difficulty, assuming either a loss of all offsite power or a loss of all onsite (diesel generator (DG)) power. The AC sources satisfy Criterion 3 of the NRG Policy Statement (Ref. 1). LCO One offsite circuit capable of supplying the onsite Class 1E power distribution subsystem(s) of LCO 3.8.8, "Distribution Systems - Shutdown," ensures that all required loads are powered from offsite power. Two Unit 1 and 2 DGs and Unit 3 DGs required to support OPERABLE SGT and GREV Systems, each associated with a Distribution System Engineered Safety Feature (ESF) 4.16 kV shutdown board required OPERABLE by LCO 3.8.8, ensures that a diverse LCO power source is available for providing electrical power support assuming a loss of the offsite circuit. Together, OPERABILITY of the required offsite circuit and DGs ensures the availability of sufficient AC sources to operate the plant in a safe manner and to mitigate the consequences of postulated events during shutdown (e.g., fuel handling accidents and reactor vessel draindovm). The qualified offsite circuit(s) must be capable of maintaining rated frequency and voltage while connected to their respective 4.16 kV shutdown boards, and of accepting required loads during an accident. Qualified offsite circuits are those that are described in the FSAR and are part of the licensing basis for the unit. (continued) BFN-UNIT 1 B 3.8-41 Revision Q,--a2. May 11, 2007

AC Sources - Shutdown B 3.8.2 BASES LCO The required DGs must be capable of starting, accelerating to (continued) rated speed and voltage, connecting to respective 4.16 kV shutdown boards on detection of bus undervoltage, and accepting required loads. This sequence must be accomplished within 10 seconds. Each DG must also be capable of accepting required loads within the assumed loading sequence intervals, and must continue to operate until offsite power can be restored to the 4.16 kV shutdown boards. Proper sequencing of loads, including tripping of nonessential loads, is a required function for DG OPERABILITY. APPLICABILITY The AC sources are required to be OPERABLE in MODES 4 and 5 and during movement of irradiated fuel assemblies in the secondary containment to provide assurance that:

a. Systems that provide core cooling providing adequate coolant inventory makeup are available for the irradiated fuel assemblies in the core in case of an inadvertent draindm.vn of the reactor vessel;
b. Systems needed to mitigate a fuel handling accident are available;
c. Systems necessary to mitigate the effects of events that can lead to core damage during shutdown are available; and (continued)

BFN-UNIT 1 B 3.8-44 Revision Q,-a2-May 11, 2007

AC Sources - Shutdown B 3.8.2 BASES APPLICABILITY d. Instrumentation and control capability is available for (continued) monitoring and maintaining the unit in a cold shutdown condition or refueling condition. AC power requirements for MODES 1, 2, and 3 are covered in LCO 3.8.1. ACTIONS With the required offsite circuit inoperable, the remaining AC sources available may be capable of supporting sufficient required features to allow continuation of CORE ALTERATIONS, and fuel movement,., and operations with a potential for draining the reactor -.1essel. By the allowance of the option to declare required features inoperable that are supported by the inoperable AC source, appropriate restrictions can be implemented in accordance with the affected required feature(s) LCOs' ACTIONS. Pursuant to LCO 3.0.6, the Distribution System ACTIONS would not be entered even if all AC sources to it are inoperable, resulting in de-energization. Therefore, the Required Actions of Condition A have been modified by a Note to indicate that when Condition A is entered with no qualified AC power to any required 4.16 kV shutdown board, ACTIONS for LCO 3.8.8 must be immediately entered. This Note allows Condition A to provide requirements for the loss of the offsite circuit whether or not a 4.16 kV shutdown board is made inoperable. LCO 3.8.8 provides the appropriate restrictions for the situation involving an inoperable 4.16 kV shutdown board. (continued) BFN-UNIT 1 B 3.8-45 Revision 9

AC Sources - Shutdown B 3.8.2 BASES ACTIONS A.2.1, A.2.2, A.2.3, A.2.4, B.+.1, B.+.2, and B.+.3. and B.1.4 (continued) With no offsite circuit available or one or more DGs inoperable, the option still exists to declare all required features inoperable. However, since this option may involve undesired administrative efforts, the allowance for sufficiently conservative actions is made. It is, therefore, required to suspend CORE ALTERATIONS, and movement of irradiated fuel assemblies in the secondary containment.:., and activities that could result in inadvertent draining of the reactor vessel. Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability of the occurrence of postulated events. It is further required to immediately initiate action to restore the required AC sources and to continue this action until restoration is accomplished in order to provide the necessary AC power to the plant safety systems. The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required AC electrical power sources should be completed as quickly as possible in order to minimize the time during which the plant safety systems may be without sufficient power. (continued) BFN-UNIT 1 B 3.8-46 Revision Q

AC Sources - Shutdown B 3.8.2 BASES ACTIONS (continued) Required Action C.1 is intended to provide assurance that a loss of offsite power, during the period that a required Unit 3 DG is inoperable, does not result in a complete loss of safety function of critical systems (i.e., SGT or CREVS). These features consist of SGT or CREVS trains redundant to trains supported by the inoperable Unit 3 DG. The 30 day completion time takes into account the operability of the redundant required features and their offsite and DG power availability. Additionally, the 30 day completion time takes into account the capacity and capability of the remaining AC sources, reasonable time for repairs, and low probability of an event occurring during this period. If the redundant required feature(s) is(are) not OPERABLE, the second completion time requires immediately declaring the required feature(s), supported by the inoperable AC source, inoperable. This results in taking the appropriate Actions in the supported system specification for the inoperable function. SURVEILLANCE SR 3.8.2.1 REQUIREMENTS SR 3.8.2.1 requires the SRs from LCO 3.8.1 that are necessary for ensuring the OPERABILITY of the Unit 1 and 2 AC sources in other than MODES 1, 2, and 3. Refer to the corresponding Bases for LCO 3.8.1 for a discussion of each SR. SR 3.8.1.6 and SR 3.8.1.9 are excluded because DG auto-start on an accident signal is not required in MODES 4 and 5. This SR is modified by a Note. The reason for the Note is to preclude requiring the OPERABLE DG(s) from being paralleled with the offsite power network or otherwise rendered inoperable during the performance of SRs, and to preclude deenergizing a (continued) BFN-UNIT 1 B 3.8-47 Revision Q

DC Sources - Shutdown B 3.8.5 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.5 DC Sources - Shutdown BASES BACKGROUND A description of the DC sources is provided in the Bases for LCO 3.8.4, "DC Sources - Operating." APPLICABLE The initial conditions of Design Basis Accident and SAFETY ANALYSES transient analyses in the FSAR, Chapter 6 (Ref. 1) and Chapter 14 (Ref. 2), assume that Engineered Safety Feature systems are OPERABLE. The DC electrical power system provides normal and emergency DC electrical power for the diesel generators (DGs), emergency auxiliaries, and control and switching during all MODES of operation. The OPERABILITY of the DC subsystems is consistent with the initial assumptions of the accident analyses and the requirements for the supported systems' OPERABILITY. The OPERABILITY of the minimum DC electrical power sources during MODES 4 and 5 and during movement of irradiated fuel assemblies in* the secondary containment ensures that:

a. The facility can be maintained in the shutdown or refueling condition for extended periods;
b. Sufficient instrumentation and control capability is available for monitoring and maintaining the unit status; and
c. Adequate DC electrical power is provided to mitigate events postulated during shutdown, such as an inadvertent draindown of the vessel or a fuel handling accident.

The DC sources satisfy Criterion 3 of the NRC Policy Statement (Ref. 3). (continued) BFN-UNIT 1 B 3.8-69 Revision Q.

DC Sources - Shutdown B 3.8.5 BASES (continued) LCO The DC Electrical Power Systems - with: 1) each Unit DC subsystem, supporting Unit battery boards required OPERABLE by LCO 3.8.8, consisting of one 250 V battery, one battery charger, and the corresponding control equipment and interconnecting cabling supplying power to the associated Unit battery board; 2) each shutdown board DC subsystem, supporting DC shutdown boards required OPERABLE by LCO 3.8.8, consisting of one 250 V battery, its associated charger, and the corresponding control equipment and interconnecting cabling supplying power to the associated DC shutdown board; and 3) each DG DC subsystem supporting DGs required OPERABLE for 4.16 kV shutdown boards required OPERABLE by LCO 3.8.8, consisting of one 125 V battery, one battery charger, and the corresponding control equipment and interconnecting cabling. This requirement ensures the availability of sufficient DC electrical power sources to operate the unit in a safe manner and to mitigate the consequences of postulated events during shutdown (e.g., fuel handling accidents and inadvertent reactor vessel drairido*1m). APPLICABILITY The DC electrical power sources required to be OPERABLE in MODES 4 and 5 and during movement of irradiated fuel assemblies in the secondary containment provide assurance that:

a. Required features to provide core cooling adequate coolant inventory makeup are available for the irradiated fuel assemblies in the core in case of an inadvertent draindown of the reactor vessel;
b. Required features needed to mitigate a fuel handling accident are available; (continued)

BFN-UNIT 1 B 3.8-70 Revision Q.

DC Sources - Shutdown B 3.8.5 BASES APPLICABILITY c. Required features necessary to mitigate the effects of (continued) events that can lead to core damage during shutdown are available; and

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

The DC electrical power requirements for MODES 1, 2, and 3 are covered in LCO 3.8.4. ACTIONS A.1, A.2.1. A.2.2, A.2.3, and A.2.34 If more than one DC distribution subsystem is required according to LCO 3.8.8, the DC subsystems remaining OPERABLE with one or more DC power sources inoperable may be capable of supporting sufficient required features to allow continuation of CORE ALTERATIO NS, and fuel movement.,,, and operations with a potential f-or draining the reactor vessel. By allowance of the option to declare required features inoperable with associated DC power sources inoperable, appropriate restrictions are implemented in accordance with the affected system LCOs' ACTIONS. In many instances, this option may involve undesired administrative efforts. Therefore, the allowance for sufficiently conservative actions is made (i.e., to suspend CORE ALTERATIONS, and movement of irradiated fuel assemblies, and any activities that could result in inadvertent draining of the reactor vessel). {continued) BFN-UNIT 1 B 3.8-71 Revision Q.

DC Sources - Shutdown B 3.8.5 BASES ACTIONS ,A.1, A.2.1, A.2.2, A.2.3, and A.2.34 (continued) Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability of the occurrence of postulated events. It is further required to immediately initiate action to restore the required DC electrical power subsystems and to continue this action until restoration is accomplished in order to provide the necessary DC electrical power to the plant safety systems. The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required DC electrical power subsystems should be completed as quickly as possible in order to minimize the time during which the plant safety systems may be without sufficient power. SURVEILLANCE SR 3.8.5.1 REQUIREMENTS SR 3.8.5.1 requires performance of all Surveillances required by SR 3.8.4.1 through SR 3.8.4.5. Therefore, see the corresponding Bases for LCO .3.8.4 for a discussion of each SR. This SR is modified by a Note. The reason for the Note is to preclude requiring the OPERABLE DC sources from being discharged below their capability to provide the required power supply or otherwise rendering them inoperable during the performance of SRs. It is the intent that these SRs must still be capable of being met, but actual performance is not required, unless required to support an operating unit per Section 3.8.4. (continued) BFN-UNIT 1 B 3.8-72 Revision Q.

Distribution Systems - Shutdown B 3.8.8 BASES APPLICABLE The OPERABILITY of the minimum AC and DC electrical power SAFETY ANALYSES sources and associated power distribution subsystems during (continued) MODES 4 and 5, and during movement of irradiated fuel assemblies in the secondary containment ensures that:

a. The facility can be maintained in the shutdown or refueling condition for extended periods;
b. Sufficient instrumentation and control capability is available for monitoring and maintaining the unitstatus; and
c. Adequate power is provided to mitigate events postulated during shutdown, such as an inadvertent draindown of the vessel or a fuel handling accident.

The AC and DC electrical power distribution systems satisfy Criterion 3 of the NRG Policy Statement (Ref. 3). LCO Various combinations of subsystems, equipment, and components are required OPERABLE by other LCOs, depending on the specific plant condition. Implicit in those requirements is the required OPERABILITY of necessary support required features. This LCO explicitly requires energization of the portions of the electrical distribution system necessary to support OPERABILITY of Technical Specifications required systems, equipment, and components - both specifically addressed by their own LCO, and implicitly required by the definition of OPERABILITY. (continued) BFN-UNIT 1 B 3.8-104 Revision Q.

Distribution Systems - Shutdown B 3.8.8 BASES LCO In addition, some components that may be required by Unit 1 (continued) receive power through the Unit 3 electrical power distribution subsystems (e.g., Standby Gas Treatment (SGT} System, and Control Room Emergency Ventilation System (CREVS)). Therefore, the Unit 3 AC and DC electrical power distribution subsystems needed to support the required equipment must also be OPERABLE. For a unit in MODE 4 or 5, the AC and DC boards can be placed on their alternate feeder breakers and considered OPERABLE as long as the restrictions on the associated drawings are met. Maintaining these portions of the distribution system energized ensures the availability of sufficient power to operate the plant in a safe manner to mitigate the consequences of postulated events during shutdown (e.g., fuel handling accidents--am:1-- inadvertent reactor vessel draindown). APPLICABILITY The AC and DC electrical power distribution subsystems required to be OPERABLE in MODES 4 and 5 and during movement of irradiated fuel assemblies in the secondary containment provide assurance that:

a. Systems that provide core cooling to provide adequate coolant inventory makeup are available for the irradiated fuel in the core in case of an inadvertent draindown of the reactor vessel;
b. Systems needed to mitigate a fuel handling accident are available; (continued)

BFN-UNIT 1 B 3.8-105 Revision Q

Distribution Systems - Shutdown B 3.8.8 BASES APPLICABILITY c. Systems necessary to mitigate the effects of events that (continued) can lead to core damage during shutdown are available; and

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

The AC and DC electrical power distribution subsystem requirements for MODES 1, 2, and 3 are covered in LCO 3.8.7. ACTIONS A.1, A.2.1, A.2.2, A.2.3, and A.2.4, and A2.5 Although redundant required features may require redundant divisions of electrical power distribution subsystems to-be OPERABLE, one OPERABLE distribution subsystem division may be capable of supporting sufficient required features to allow continuation of CORE ALTERATIONS and ,fuel movement.,_, and operations v,ith a potential for draining the reactor *~*essel. By allowing the option to declare required features associated with an inoperable distribution subsystem inoperable, appropriate restrictions are implemented in accordance with the affected distribution subsystem LCO's Required Actions. In many instances this option may involve undesired administrative efforts. Therefore, the allowance for sufficiently conservative actions is made, (i.e., to suspend CORE ALTERATIONS, and movement of irradiated fuel assemblies in the secondary containment, and any activities that could result in inadvertent draining of the reactor vessel). (continued) BFN-UNIT 1 B 3.8-106 Revision 9

Distribution Systems - Shutdown B 3.8.8 BASES ACTIONS A.1, A.2.1, A.2.2, A.2.3, and A.2.4. and A.2.5 (continued) Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability of the occurrence of postulated events. It is further required to immediately initiate action to restore the required AC and DC electrical power distribution subsystems and to continue this action until restoration is accomplished in order to provide the necessary power to the plant safety systems. Notwithstanding performance of the above conservative Required Actions, a required residual heat removal-shutdown cooling (RHR-SDC) subsystem may be inoperable. In this case, Required Actions A.2.1 through A.2.4 do not adequately address the concerns relating to coolant circulation and heat removal. Pursuant to LCO 3.0.6, the RHR-SDC ACTIONS would not be entered. Therefore, Required Action A.2.5 is provided to direct declaring RHR-SDC inoperable, which results in taking the appropriate RHR-SDC ACTIONS. The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required distribution subsystems should be completed as quickly as possible in order to minimize the time the plant safety systems may be without power. (continued) BFN-UNIT 1 B 3.8-107 Revision G

lnservice Leak and Hydrostatic Testing Operation B 3.10.1 BASES APPLICABLE MODE 4 conditions, the stored energy in the reactor core will SAFETY ANALYSES be very low. Under these conditions, the potential for failed fuel (continued) and a subsequent increase in coolant activity above the LCO 3.4.6, "RCS Specific Activity," limits are minimized. In addition, the secondary containment will be OPERABLE, in accordance with this Special Operations LCO, and will be capable of handling any airborne radioactivity or steam leaks that could occur during the performance of hydrostatic or leak testing. The required pressure testing conditions provide adequate assurance that the consequences of a steam leak will C be conservatively bounded by the consequences of the postulated main steam line break outside of primary containment described in Reference 2. Therefore, these requirements will conservatively limit radiation releases to the environment. In the unlikely event of a largeany primary system leak that could result in draining of the RPV, the reactor vessel would rapidly depressurize, allo'Ning the lmN pressure core cooling systems to operate. The make-up capability of the lmu pressure coolant injection and core spray subsystems, as required in MODE 4 by LCO 3.5.2, "RPV Water Inventory ControlECCS Shutdown," would be more than adequate to keep the RPV water level above the TAF core flooded under this low decay heat load condition. Small system leaks would be detected by leakage inspections before significant inventory loss occurred. For the purposes of this test, the protection provided by normally required MODE 4 applicable LCOs, in addition to the secondary containment requirements required to be met by this Special Operations LCO, will ensure acceptable consequences during normal hydrostatic test conditions and during postulated accident conditions. As described in LCO 3.0.7, compliance with Special Operations LCOs is optional, and therefore, no criteria of the NRC Policy Statement apply. Special Operations LCOs provide flexibility to perform certain operations by appropriately modifying (continued) BFN-UNIT 1 B 3.10-3 Revision Q,a4 May 10, 2007]]

Retrieved from "https://kanterella.com/w/index.php?title=CNL-19-010,_Application_to_Revise_Technical_Specifications_to_Adopt_Technical_Specifications_Task_Force_(TSTF)-542,_Reactor_Pressure_Vessel_Water_Inventory_Control,_Revision_2_(BFN-TS-513)&oldid=2503437"