|
---|
Category:SAFETY EVALUATION REPORT--LICENSING & RELATED ISSUES
MONTHYEARML20212E6341999-09-23023 September 1999 Suppl to SE Resolving Error in Original 990802 Se,Clarifying Fact That Licensee Has Not Committed to Retain Those Specific Compensatory Measures That Were Applied to one-time Extension ML20212D3831999-09-20020 September 1999 Safety Evaluation Supporting Proposed Rev to Withdrawal Schedule for First & Third Surveillance Capsules for BFN-3 RPV ML20210N1221999-08-0202 August 1999 Safety Evaluation Accepting Licensee Request for Relief from ASME B&PV Code,Section XI Requirements.Request 3-ISI-7, Pertains to Second 10-year Interval ISI for Plant,Unit 3 ML20209J0771999-07-16016 July 1999 Safety Evaluation Concluding That Licensee Provided Adequate Information to Resolve ampacity-related Points of Concern Raised in GL 92-08 for BFN & That No Outstanding Issues Re GL 92-08 Ampacity Issues for Browns Ferry NPP Exist ML20196F8811999-06-23023 June 1999 Safety Evaluation Accepting GL 95-07, Pressure Locking & Thermal Binding of Safety-Related Power Operated Gate Valves ML20205F9341999-04-0101 April 1999 Safety Evaluation Authorizing Licensee 990108 Relief Request PV-38,from Requirements of ASME BPV Code Section XI IST Testing,Valve Program for Plant,Units 1,2 & 3 ML20153H3141998-09-28028 September 1998 SE Accepting Util Proposed Alternatives as Contained in Relief Requests 3-SPT-3 & 3-SPT-4 for Second Interval & Code Case N-546 ML20247M1901998-05-20020 May 1998 Safety Evaluation Related to Browns Ferry,Unit 3 Nuclear Power Plant Individual Plant Exam ML20217E5431997-09-22022 September 1997 Safety Evaluation Re Flaw Evaluation of Core Spray Internal Piping for Plant,Unit 3 ML20217C2191997-09-11011 September 1997 Safety Evaluation Supporting Amend 249 to License DPR-52 ML20149L2301997-07-28028 July 1997 Safety Evaluation Accepting License Relief Request from Certain ASME Code Requirements Delineated in Change to 10CFR50.55a for Plant,Units 1,2 & 3 ML20148U3291997-07-0808 July 1997 Safety Evaluation Denying Relief Request 3-ISI-1.Based on Review,Nrc Concludes That Licensee Does Not Have Sufficient Basis for Relief from Code Required Successive Exam ML20136D7831997-03-10010 March 1997 Safety Evaluation Authorizing Use of ASME Code Case N-416-1 ML20132B2701996-12-11011 December 1996 Safety Evaluation Accepting Licensee Emi/Rfi site-survey Consistent W/Industry Stds & Practice ML20058K2411993-12-0707 December 1993 Supplemental Safety Evaluation Supporting Structural Steel Thermal Growth Design Critera at Plant ML20058J1091993-12-0303 December 1993 Safety Evaluation Accepting Licensee 921228 Submittal of Suppl Response to GL 88-01, NRC Position on Intergranular Stress Corrosion Cracking (IGSCC) in BWR Austenitic Stainless Steel Piping ML20059C2451993-10-22022 October 1993 Safety Evaluation Accepting IST Program Requests for Relief ML20246M3891989-05-0909 May 1989 Safety Evaluation Supporting Util 890317 Proposed long-term Solution to Correct Rust Problems in Containment Spray Headers ML20245H3371989-05-0101 May 1989 Safety Evaluation Re Generic Ltr 83-28,Item 2.1 (Part 2) About Vendor Interface Program ML20245D5711989-04-19019 April 1989 Safety Evaluation Re Rust in Lower Containment Spray Header Due to Leaking Isolation Valves ML20247K5561988-09-23023 September 1988 Safety Evaluation Supporting Amends 155,151 & 126 to Licenses DPR-33,DPR-52 & DPR-68,respectively ML20154H2721988-04-19019 April 1988 Safety Evaluation Describing Relationship of Util Nuclear Performance Plan,Vol 3,Part Ii,Section 2.6, QA to TVA-TR75-1A, QA Program Description for Design,Const... W/Proper Implementation,Qa Program Description Acceptable ML20148K9051988-03-23023 March 1988 Safety Evaluation Supporting Util Responses to Generic Ltr 83-28,Items 3.1.1,3.1.2,3.2.1 & 3.2.2, Post-Maint Testing of Reactor Trip Sys & All Other Safety-Related Components ML20246M2341988-02-29029 February 1988 Safety Evaluation Supporting Amends 145,141 & 116 to Licenses DPR-33,DPR-52 & DPR-68,respectively ML20214H9091987-05-13013 May 1987 Safety Evaluation Supporting Amends 133,129 & 104 to Licenses DPR-33,DPR-52 & DPR-68,respectively ML20206L9821986-06-20020 June 1986 Safety Evaluation Supporting Requests for Establishment of Common Date to Implement Inservice Insp Program Requirements.Start Date of 880301 Accepted for Second 10-yr Insp Interval ML20127D6641985-06-17017 June 1985 Safety Evaluation Re Licensee Response to Item 1.1 of Generic Ltr 83-28 on post-trip Review Program & Procedures. Post-trip Review Program & Procedures Acceptable ML18029A5381985-05-0606 May 1985 Safety Evaluation Re Mark I Containment long-term Program Pool Dynamic Loads Review for Plant.Pool Dynamic Loads Meet Acceptance Criteria of NUREG-0661 or Alternative Criteria Acceptable ML18029A5401985-05-0606 May 1985 Safety Evaluation Re Mark I Containment long-term Program Structural Review for Plant.Mods Follow NUREG-0661 Guidelines & Acceptable.Analyses Verified & Approved ML20148T7811980-12-0101 December 1980 Generic Safety Evaluation Re BWR Scram Discharge Sys ML20062A4221978-09-29029 September 1978 Safety Evaluation Rept Supporting Amend 43 to Lic DPR-33 Covering Pump Seizure Accident,Inadvertent Cold Loop Startup Transient & Monitoring of Safety Margins for 1 Loop Oper ML20247C1721976-02-23023 February 1976 Safety Evaluation Supporting Operation of Plant After Restoration & Mods of Facilities Following 750322 Fire 1999-09-23
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML18039A9041999-10-15015 October 1999 LER 99-010-00:on 990917,automatic Reactor Scram on Turbine Stop Valve Closure Occurred.Caused by High Water Level in Main Steam Moisture Separator 2C2.Unit 2C2 Reservoir Level Transmitter & Relays Were Replaced & Tested Satisfactorily ML18039A8981999-10-14014 October 1999 LER 99-009-00:on 990915,manual Reactor Scram Was Noted Due to EHC Leak.Caused by Failure of Stainles Steel Tubing Connection.Removed Damaged Tubing & Connection Plug ML18039A8951999-10-0808 October 1999 LER 99-008-00:on 990905,HPCI Was Inoperable Due to Failed Flow Controller.Caused by Premature Failure of Capacitor 2C3.Replaced Controller & HPCI Sys Was Run IAW Sys Operating Instructions ML18039A8751999-09-30030 September 1999 LER 99-005-00:on 990901,SR for Standby Liquid Control Sampling Was Not Met.Caused by Deficient Procedure for Chemical Addition to Standby Liquid Control.Revised Procedure.With 990930 Ltr ML20217F9671999-09-30030 September 1999 Monthly Operating Repts for Sept 1999 for Browns Ferry Nuclear Plant,Units 1,2 & 3.With ML20212E6341999-09-23023 September 1999 Suppl to SE Resolving Error in Original 990802 Se,Clarifying Fact That Licensee Has Not Committed to Retain Those Specific Compensatory Measures That Were Applied to one-time Extension ML20212D3831999-09-20020 September 1999 Safety Evaluation Supporting Proposed Rev to Withdrawal Schedule for First & Third Surveillance Capsules for BFN-3 RPV ML20212B8561999-08-31031 August 1999 Monthly Operating Repts for Aug 1999 for Browns Ferry Nuclear Plant.With ML18039A8821999-08-31031 August 1999 Increased MSIV Leakage Tech Spec Change Submittal - Seismic Evaluation Rept. ML18039A8391999-08-0606 August 1999 BFN Unit 2 Cycle 10 ASME Section XI NIS-1 & NIS-2 Data Repts. ML20210N1221999-08-0202 August 1999 Safety Evaluation Accepting Licensee Request for Relief from ASME B&PV Code,Section XI Requirements.Request 3-ISI-7, Pertains to Second 10-year Interval ISI for Plant,Unit 3 ML20210R0931999-07-31031 July 1999 Monthly Operating Repts for July 1999 for Browns Ferry Nuclear Plant,Units 1,2 & 3.With ML18039A8201999-07-26026 July 1999 LER 99-004-00:on 990625,facility Core Spray Divisions I & II Inoperable at Same Time Due to Personnel Error.Electrical Supply Breaker to Core Spray Division II Pump 3B Returned to Normal Racked in Position ML18039A8171999-07-20020 July 1999 LER 99-007-00:on 990623,discovered That SR for Monitoring of Primary Containment Oxygen Concentration Had Not Been Met. Caused by Failure of Operators to Adequately Communicate. Required Surveillances Were Performed.With 990720 Ltr ML18039A8161999-07-19019 July 1999 LER 99-006-00:on 990618,noted That Main Steam SRV Exceeded TS Setpoint Tolerance.Caused by Pilot Vlve disc-seat Bonding.Util Replaced All 13 SRV Pilot Cartridges with Cartridges Certified to Be Witin +/-1%.With 990719 Ltr ML20209J0771999-07-16016 July 1999 Safety Evaluation Concluding That Licensee Provided Adequate Information to Resolve ampacity-related Points of Concern Raised in GL 92-08 for BFN & That No Outstanding Issues Re GL 92-08 Ampacity Issues for Browns Ferry NPP Exist ML18039A8121999-07-12012 July 1999 LER 99-005-00:on 990617,ESF Actuation & HPCI Declared Inoperable.Caused by Personnel Error.Reset HPCI & Returned Sys to Operable Status with 25 Minutes.With 990712 Ltr ML20209H4381999-06-30030 June 1999 Monthly Operating Repts for June 1999 for Browns Ferry Nuclear Plant,Units 1,2 & 3.With ML18039A8101999-06-28028 June 1999 LER 99-004-00:on 990530,safety Features Sys Actuations Occurred Due to RPS Trip.Caused by Failure of MG Set AC Drive Motor Starter Contractor Coil.Licensee Placed 2B RPS Bus on Alternate Feed & Half Scram Was Reset ML20196F8811999-06-23023 June 1999 Safety Evaluation Accepting GL 95-07, Pressure Locking & Thermal Binding of Safety-Related Power Operated Gate Valves ML18039A8071999-06-14014 June 1999 LER 99-003-00:on 990515,automatic Reactor Scram Due to Turbine Trip Was Noted.Caused by Failure of Mechanical Trip Cylinder to Latch When Hydraulically Reset.Operations Crew Stabilized Reactor Following Scram ML18039A8021999-06-14014 June 1999 LER 99-002-00:on 990501,SRs for Single CR Withdrawal During Cold SD Were Not Adequately Implemented.Caused by Procedural Inadequacy.Revised Applicable Plant Surveillances.With 990614 Ltr ML18039A8011999-06-14014 June 1999 LER 99-001-00:on 990515,automatic Reactor Scram Occurred Due to Tt.Caused by Failure of Mechanical Trip Cylinder to Latch When Hydraulically Reset.Operations Crew Stabilized Reactor Following Scram.With 990614 Ltr ML20196B8051999-05-31031 May 1999 Monthly Operating Repts for May 1999 for Browns Ferry Nuclear Plant,Units 1,2 & 3.With ML18039A7791999-05-0606 May 1999 LER 99-003-00:on 990408,declared Plant HPCI Sys Inoperable Due to Loose Wire.Caused by Failure to Properly Tighten Screw at Some Time in Past.Loose Wire Was Tightened ML18039A7761999-04-30030 April 1999 Revised Surveillance Specimen Program Evaluation for TVA Browns Ferry Unit 3. ML20206R0731999-04-30030 April 1999 Monthly Operating Repts for Apr 1999 for Bfnp.With ML18039A7561999-04-23023 April 1999 Bfnp Risk-Informed Inservice Insp (RI-ISI) Program Submittal. ML18039A7671999-04-0808 April 1999 Rev 0 to TVA-COLR-BF2C11, Browns Ferry Nuclear Plant Unit 2 Cycle 11 Colr. ML18039A7461999-04-0707 April 1999 LER 99-001-00:on 990308,determined That Two Trains of Standby Gas Treatment (SGT) Were Inoperable.Caused by Trip C SGT Blower Motor Breaker.Initiated Shutdown of Plant,Reset C SGT Blower Motor Breaker & Declared Train Operable ML20205N8341999-04-0101 April 1999 Part 21 Rept Re Automatic Switch Co Nuclear Grade Series X206380 & X206832 Solenoid Valves Ordered Without Lubricants That Were Shipped with Std Lubrication to PECO & Tva.Affected Plants Were Notified ML20205F9341999-04-0101 April 1999 Safety Evaluation Authorizing Licensee 990108 Relief Request PV-38,from Requirements of ASME BPV Code Section XI IST Testing,Valve Program for Plant,Units 1,2 & 3 ML20205T5441999-03-31031 March 1999 Monthly Operating Repts for Mar 1999 for Bfnp.With ML20205S0601999-03-31031 March 1999 Rept on Status of Public Petitions Under 10CFR2.206 with Status Change from Previous Update,990331 ML20205S0661999-03-31031 March 1999 Rept on Status of Public Petitions Under 10CFR2.206 with No Status Change from Previous Update,990331, Atlas Corp ML18039A7361999-03-11011 March 1999 Rev 4 to TVA-COLR-BF2C10, Bfnp,Unit 2,Cycle 10 Colr. ML20204C7891999-02-28028 February 1999 Monthly Operating Repts for Feb 1999 for Browns Ferry Nuclear Plant,Units 1,2 & 3.With ML18039A6951999-02-19019 February 1999 LER 99-002-00:on 990122,LCO Was Not Entered During Calibration Testing of 3D 480 Volt Rmov Board.Caused by Personnel Error.Tva Has Briefed Operations Personnel to Preclude Recurrence of Event.With 990219 Ltr ML18039A6871999-02-12012 February 1999 LER 99-001-00:on 990114,Unit 3 HPCI Was Noted Inoperable. Caused by Oil Leak on Stop Valve.Corrective Maint Was Performed to Repair Oil Leak.With 990212 Ltr ML18039A6931999-02-0303 February 1999 Rev 3 to TVA-COLR-BF2C10, Bfnp Unit 2 Cycle 10 Colr. ML18039A6941999-02-0303 February 1999 Rev 1 to TVA-COLR-BF3C9, Bfnp Unit 3 Cycle 9 Colr. ML18039A6671998-12-31031 December 1998 LER 98-004-00:on 981202,SR Intent Was Not Adequately Implemented.Caused by Procedural Inadequacy.Revised Procedures to Provide Proper SR Implementation.With 981231 Ltr ML18039A6661998-12-31031 December 1998 Ro:On 981215,HRPCRM 2-RM-90-273C Was Declared Inoperable. Caused by Downscale Indication.Containment RM Will Be Utilized as Planned Alternate Method of Monitoring Until Hrpcrm 2-RM-90-273C Can Be Returned to Operable Status ML20199K8951998-12-31031 December 1998 Monthly Operating Repts for Dec 1998 for Browns Ferry Nuclear Plant.With ML20199F2721998-12-31031 December 1998 ISI Summary Rept (NIS-1), for BFN Unit 3,Cycle 8 Operation ML18039A6471998-12-15015 December 1998 LER 98-007-00:on 981116,unplanned ESF Following Loss of 4kV Unit Board 3B Occurred.Caused by Temporary Energization of Lockout Relay on 4kV Unit Board 3B When Resistor on Relay Monitoring Lamp Circuit Shorted.Replaced Resistor ML18039A6371998-12-0707 December 1998 LER 98-006-00:on 981116,MSSR Valves Exceeded TS Setpoint Tolerance.Caused by Pilot Valve Disc/Seat Bonding. Installed SRV Pressure Switches During Unit 3,cycle 8 Outage.With 981207 Ltr ML20199F2791998-12-0303 December 1998 Bfnp Unit 3 Cycle 8 ASME Section XI NIS-2 Data Rept ML20198D9621998-11-30030 November 1998 Monthly Operating Repts for Nov 1998 for Bfn,Units 1,2 & 3. with ML18039A6071998-11-12012 November 1998 LER 98-005-00:on 981014,mode Changes Not Allowed by TS 3.0.4 Were Made During Reactor Startup.Caused by TS LCO 3.0.4 Not Being Properly Applied.Training Info Memo Re Proper Application for TS LCO 3.0.4 Was Prepared.With 981112 Ltr 1999-09-30
[Table view] |
Text
-
?
/ >
UNITED STATES j
? ,j NUCLEAR REGULATORY CCMMISSION wAswiwaTom, c. c.2asas !
I
%, %s f SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION SUPPORTING AMEN 0 MENT NO. 43 FACILITY LICENSE NO. DPR-33 TENNESSEE VALLEY AUTHORITY BROWNS FERRY NUCLEAR PLANT, UNIT NO. 1 DOCKET NO. 50-259 Introduction On Septemcer 19, 1978, we issued Amendment No. 41 to Facility Operating License No. DPR-33 which permitted TVA to operate Browns Ferry Unit No.1 (BF-1) with one recirculation loop out of service for the remainder of the current fuel cycle (cycle 2) but with the restriction that power level be limited to a maximum of 50% of licensed power. Power was limited to 50% of full licensed pcwer by the new Technical Specifications due to lack of an acceptable analysis of the locked pump rotor accident for one Icop operation. Our SER issued with the Technical Specification changes gave the bases for acceptability of the 50% power limit. That SER also discussed the bases for a restriction that pcwer c:uld not exceed eB% of full licensed pcwer until further infor nation regarding the inadventent pump startup transient analysis was provided.
Su: mary We have reviewed the TVA submittal of September 28, 1978, requesting deletion of the above described power restrictions. We find it acceptable to remove both of the pcwer restrictions on the bases discussed belew, provided that the maximum power level not exceed 82% of full licensed power for the reasons discussed belcw.
Evaluation !
One Pum: Sei:ure Accident TVA has sucmitted results of calculations for the pumo sei:ure accident assuming one loop operation (submittal of September 23,1978). These calculations utili:ed tne standard, conservative, plant scecific inputs that were used for the transients and accidents nat were analy:ed -
for :he lates: 3F-1 relcad (Amencment 35 issued January 10,1978).
fpg These calculations utilized the General Electric REDY c:de to mcdel the ;
transient behavior of the reactor core. No model chances were made to the '
75/OlWeede for this use. The code is currently used for reload transient analyses perfor :ed for SF-1 and cther SWRs. . ump sei:ure was simulated in the same PCR t10eCA c f* .2 59 P 15o 9pf
acceptable manner as for previously perfomed pump seizure analyses with two pump operation (the method results in the pump stopping completely in less than one revolution). Appropriate input changes were made to, reflect operation with one recirculation loop. Although a review is currently in progress concerning continued acceptability of the REDY code for analysis of pressurization transients, this transient is characterized as a loss-of-flow event. REDY code results are currently accepted for such analyses.
REDY results were input into the General Electric SCAT 02 code which cal-culates themal margin (Minimum Critical power Ratio, MCpR). This code was not modified in any way for this purpose. SCAT 02 is currently used and accepted for BF-1 and other plant transient analyses that are per-formed for reload submittals.
Two sets of initial conditions were analy:ed (power-ficw initial conditions equal to 75% power - 58% flow and 82% power - 56% ficw). These conditions represent, respectively: (1) the maximum flow possible through the core (allowing for backflow through the idle jet pumps) due to one pump cpera-tion with power corresponding to that flow frem the highest (105%) power-ficw load line; and (2) an even higher power for the same one pump opera-tion (core flow is 2% lower due to increased flow resistance in the core due to added voiding at the higher power). We find these assumed initial conditions acceptable since they conservatively bound the highest power operation possible under one loop operation conditions.
The analyses indicate that the following sequence of events occurs: the operating pump seizes and external recirculation loop flow goes very rapidly to :ero; core flow continues due to momentum effects and buoyancy effects; as momentum is dissipated, core flow will decrease; as core flow decreases, voiding in the core will increase; increased voiding will reduce core thermal pcwer due to the feedback effect frem the negative void coefficient; and finally, the core will reach a new equilibrium power and flow detemined by the natural re-circulation characteristics of the core, wi.. no ficw in the external recirculation loop (flow will be up through the core, driven by buoyant force as water is heated and boiled in the core, then dcwn through the internal jet pumps, then repeat). Steam produced will continue to go cut the main steam line to the turbine / condenser system, then back to the reactor througn the feedwater system. Water level in the core will first increase due to the increased voiding, then will decrease as core pcwer decreases and stored hea; is removed, but the level fluctua-ions are not severe enough to trio (scram) ne reactor on either hign or icw water level. Neutr:n flux decreases cue to tne void feedback so no high flux scram occurs. pressure does not reach the high pressure scram point (in fact, pressure decreases) -
r ~ :e no isolation occurs and steam continues ficwing o ne taroine wnile steam production decreases as gewer decreases. Thus, no reactor scram is anticipated frem any signal.
. .- ~._ - . - - . . . . _ - - - . . - . __
, I 3
i 4
During the above sequence of events, the MCPR does not go below the Safety Limit MCPR, which is set to insure lack of any significant fuel damage.
Therefore, we conclude that no significant fuel damage will occur, and therefore the acceptance criteria is met for this accident -(f.e. , that i
releases remain below a small fraction of the requirments stated in 10 :
! CFR Part 100). '
i On the basis of the above described plant specific analyses which have 3 been provided, we conclude that the 50% power limit previously imposed on SF-1 for single loop operation for the remainder of the present cycle can be increased to 82% pcwer, the maximum power level for which the L consequences of the pump seizere accident have been demonstrated to be 4
acceptable.
I Inadvertent Cold Loco Startuo Transient -
TVA has closed the suction valve on the disabled loop and has locked out and tagge power to that valve and to the disabled loop's recirculation i pump. In addition, TVA has stated that "the brushes have been lifted from the recirculation pump M-G set and will not be reinstated until the next refueling outage. Replacement of the brushes takes several hours and could not be performed without authorization." Therefore, we consider unplanned startup of the idle loop to be incredible during the remainder of the present cycle. Furthermore, the discharge valve (whose internal failure and partial closure caused the loop's shutdown) cannot be repaired until the unit is.
i shut down at end-of-cycle. Therefore, planned loop startup will not occur during the remainder of the present cycle, and the attendant slight possibility of utilizing improper procedures during such a planned startup, and inadvertently introducing cold water suddenly into the primary system, will be avoided.
On the above stated bases we conclude that the occurrence of this transient is not credible during the remainder of the present cycle, and we find it-acceptable to delete the 68% maximum power restriction for one loop oper-4 ation stated in our previous SER.
- Monitorina of Safety Marcins for One Loco Ocerstion I
Our orevicus SER, issued with Amendment No. 41, stated the bases for a ceptability of the 3F-1 MAPLHGR limits that will be observed during the remainder of this cycle for one loco operation. Those limits
- conservatively account for the unavilability of one of the olants recirculatien icoas by assuming no credit for ccastdewn ficw frcm i
the unavailable loco folicwing a LCCA. We therefore cenclude that oceration with cne loco out of service, with thereduced limits, dces not result in any decrease in overall plant safety margins, i.e., that -
the reduced limits acceotably account for the reducticn in plant
- souipment tnat is availaole.
?
1
~ '
-4 The plant is required to monitor ccmpliance with the MAPUGR limits every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. The process computer prints out a quantity called r MAPRAT, which is the ratio of the current (measured) MAPUGR to the current MAPUGR calculated limit. This is done every 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for the, 6 locations in the core that are closest to the limit. Values greater than 1.0 thus indicate a violation. The process computer has been, programed to assume the reduced limitsthat have been approved for one loop operation when calculating MAPRAT. We find the above described method of monitoring cc:npliance with the MAPUGR limits to be easy to monitor and acceptable.
We do not believe that overall plant safety margins have been decreased as stated in the first paragraph above. We note that we have previously approved operation of BF-1 at higher pcwer levels with the same method and frequency of monitoring for compliance with the MAPUGR limits.
Since safety margins has not been degraded by operation with a single loco, we find the method of monitoring equally to be acceptable for one loop operation.
Environmental Consideration We have determined that this amendment does not authorize a change in effluent types or total amounts nor an increase in power level authori:ed by the license and will not result in any significant environmental impact.
Having made this determination, we have further concluded that this amendment involves an action which is insignificant frem the standpoint of environmental impact and pursuant to 10 CFR 151.5(d)(4) that an environmental imcact statement, negative declaration, or environmental impact appraisal need not be prepared in connection with the issuance of this amendment.
Conclusion We have concluded, based on the considerations discussed above, that:
(1) because the amendment does not involve a significant increase in the probability of consequences of accidents previously considered and does not involve a significant decrease in a safety margin, the amendment
- does not involve a significant ha
- ards consideration, (2) there is reason-able assurance that the health and safety of the public will not be endangered by operation in the proposed manner, and (3) such activities ,
will be concucted in ceccliance with the Ccrmission's regulations and the issuance of these amendments will net be inimical to the comon cefense i and security or to the health and safety of the public.
Dated: Septamcer 29, 1978 l
l
_-. - .