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Category:FUEL CYCLE RELOAD REPORTS
MONTHYEARML20196K7981999-03-25025 March 1999 Rev 4 to COLR, for Cycle 8 ML20217D3991998-03-31031 March 1998 Cycle 13 Voltage-Based Repair Criteria 90-Day Rept ML20198B9391997-12-22022 December 1997 Cycle 13 Reload & Colr ML20129A8631996-10-10010 October 1996 Cycle 7 Colr ML20108D0411996-05-0101 May 1996 Cycle 12 Colr ML20082T5221995-04-24024 April 1995 Core Operating Limits Rept ML20080R7861995-02-28028 February 1995 Cycle 11 Colr ML20058F1851993-11-24024 November 1993 Cycle 5 Core Operating Limits Rept ML20044H4151993-05-28028 May 1993 Updated Beaver Valley,Unit 1 Cycle 10 Colr. ML20114B0381992-08-0606 August 1992 Cycle 4 Startup Physics Test Rept ML20096C1281992-04-30030 April 1992 Cycle 4 Core Operating Limits Rept ML20077E6661991-04-30030 April 1991 Cycle 9 Core Operating Limits Rept ML20236R8631987-10-31031 October 1987 Reload Safety Evaluation,Beaver Valley Nuclear Plant Unit 1 Cycle 7 ML20098E9221984-07-31031 July 1984 Reload Safety Evaluation,Beaver Valley Nuclear Plant Unit 1 Cycle 5 ML20085L0031983-09-30030 September 1983 Rev 1 to Reload Safety Evaluation,Beaver Valley Nuclear Plant Unit 1,Cycle 4 ML20071J9491983-02-28028 February 1983 Reload Safety Evaluation,Beaver Valley Nuclear Plant Unit 1,Cycle 4 1999-03-25
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARL-99-154, Monthly Operating Repts for Sept 199 for Bvps,Units 1 & 2. with1999-09-30030 September 1999 Monthly Operating Repts for Sept 199 for Bvps,Units 1 & 2. with L-99-139, LER 99-S01-00:on 990813,uncompensated Loss of Ability to Detect within Single Intrusion Security Detection Zone Occurred.Caused by Procedure non-compliance.Involved Personnel Received Counseling Re Event.With1999-09-0202 September 1999 LER 99-S01-00:on 990813,uncompensated Loss of Ability to Detect within Single Intrusion Security Detection Zone Occurred.Caused by Procedure non-compliance.Involved Personnel Received Counseling Re Event.With L-99-140, Monthly Operating Repts for Aug 1999 for Bvps,Units 1 & 2. with1999-08-31031 August 1999 Monthly Operating Repts for Aug 1999 for Bvps,Units 1 & 2. with L-99-126, Monthly Operating Repts for Jul 1999 for Beaver Valley Power Station,Units 1 & 2.With1999-07-31031 July 1999 Monthly Operating Repts for Jul 1999 for Beaver Valley Power Station,Units 1 & 2.With L-99-107, Monthly Operating Repts for June 1999 for Bvps,Units 1 & 2. with1999-06-30030 June 1999 Monthly Operating Repts for June 1999 for Bvps,Units 1 & 2. with ML20209D9531999-06-27027 June 1999 Inservice Insp Ninety-Day Rept Bvps,Unit 2 Outage 7,Year 1999 L-99-096, Monthly Operating Repts for May 1999 for BVPS Units 1 & 2. with1999-05-31031 May 1999 Monthly Operating Repts for May 1999 for BVPS Units 1 & 2. with L-99-078, Special Rept:On 990326,seismic Monitoring Instruments Were Declared Inoperable.Caused by Resolution of Potential TS Compliance Issue & Work Scheduling Issue.Instrumentation Was Returned to Svc Following Calibr & Declared Operable1999-05-0303 May 1999 Special Rept:On 990326,seismic Monitoring Instruments Were Declared Inoperable.Caused by Resolution of Potential TS Compliance Issue & Work Scheduling Issue.Instrumentation Was Returned to Svc Following Calibr & Declared Operable L-99-079, Monthly Operating Repts for Apr 1999 for Beaver Valley Power Station,Units 1 & 2.With1999-04-30030 April 1999 Monthly Operating Repts for Apr 1999 for Beaver Valley Power Station,Units 1 & 2.With ML20205L0401999-04-0909 April 1999 SER Accepting Util Relief Requests for Inservice Insp Second 10-year Interval for Beaver Valley Power Station, Unit 2 L-99-054, Special Rept:On 990320,meteorological Tower Wind Speed Sensors Were Declared Inoperable.Caused by Calibration Completed by Vendor Did Not Adequately Cover Full Operating Range of Sensors.Removed Sensors & Sent Offsite1999-04-0505 April 1999 Special Rept:On 990320,meteorological Tower Wind Speed Sensors Were Declared Inoperable.Caused by Calibration Completed by Vendor Did Not Adequately Cover Full Operating Range of Sensors.Removed Sensors & Sent Offsite L-99-058, Monthly Operating Repts for Mar 1999 for Bvps,Units 1 & 2. with1999-03-31031 March 1999 Monthly Operating Repts for Mar 1999 for Bvps,Units 1 & 2. with ML20196K7981999-03-25025 March 1999 Rev 4 to COLR, for Cycle 8 L-99-038, Monthly Operating Repts for Feb 1999 for Bvps,Units 1 & 2. with1999-02-28028 February 1999 Monthly Operating Repts for Feb 1999 for Bvps,Units 1 & 2. with ML20203E1181999-02-10010 February 1999 SER Accepting Proposed Revs to Plant,Units 1 & 2 Quality Assurance Program Description L-99-019, Special Rept:On 990120,meteorological Tower Wind Speed Sensors Declared Inoperable.Caused by Processor Card for Sensor Locked Up & Needed to Be Reset.Heater That Fit Around Shaft of Sensor Replaced1999-02-0505 February 1999 Special Rept:On 990120,meteorological Tower Wind Speed Sensors Declared Inoperable.Caused by Processor Card for Sensor Locked Up & Needed to Be Reset.Heater That Fit Around Shaft of Sensor Replaced ML20196F7011999-01-31031 January 1999 BVPS Unit 2 Heatup & Cooldown Limit Curves During Normal Operation at 15 EFPY Using Code Case N-626 ML20203D4811999-01-31031 January 1999 Monthly Operating Repts for Jan 1999 for Bvps,Units 1 & 2, in Accordance with NRC GL 97-02.With ML20207E6631999-01-28028 January 1999 Rev 0 to EMECH-0713-1, Operational Assessment of SG Tubing at Beaver Valley Unit 1,Cycle 13 ML20210G7041999-01-22022 January 1999 BVPS Unit 1 Facility Changes,Tests & Experiments for 980123-990122 ML20207E5861998-12-31031 December 1998 Annual Rept 1998 for Toledo Edison ML20207E5601998-12-31031 December 1998 Annual Rept 1998 for Pennpower ML20198B9021998-12-31031 December 1998 BVPS Unit 1 Simulator Four Yr Certification Rept for 1995-1998 ML20207E5901998-12-31031 December 1998 Dqe 1998 Annual Rept to Shareholders ML20199C9971998-12-31031 December 1998 Monthly Operating Repts for Dec 1998 for Bvps,Units 1 & 2. with ML20207E5521998-12-31031 December 1998 Annual Rept 1998 for Ohio Edison ML20207E5761998-12-31031 December 1998 Annual Rept 1998 for Illuminating Co ML20204J6751998-12-31031 December 1998 1998 Annual Rept for Dbnps,Unit 1,PNPP,Unit 1 & BVPS Units 1 & 2 ML20199F5341998-12-29029 December 1998 Safety Evaluation Granting Relief Requests 1-TYP-3-B3.140-1, 1-TYP-3-B5.70-1,1-TYP-3-RH-E-1-1,1-TYP-3-B-G-1, 1-TYP-3-APP-I-1,1-TYP-3-UT-1,1-TYP-3-N-509,1-TYP-3-N-521, 1-TYP-3-N-524,1-TYP-3-B3.120-1 & 1-TYP-3-C6.10-1 ML20198K8551998-12-21021 December 1998 SER Granting Relief Request PRR-5 for Third 10-year Inservice Testing for Beaver Valley Power Station,Unit 1 ML20198A1631998-12-0909 December 1998 SER Approving Implementation Program to Resolve USI A-46 at Facility That Has Adequately Addressed Purpose of 10CFR50.54(f) Request L-98-229, Monthly Operating Repts for Nov 1998 for Bvps,Units 1 & 2. with1998-11-30030 November 1998 Monthly Operating Repts for Nov 1998 for Bvps,Units 1 & 2. with ML20195J3131998-11-12012 November 1998 Safety Evaluation Granting First & Second 10-yr Interval Inservice Insp Request for Relief L-98-210, Monthly Operating Repts for Oct 1998 for Bvps,Units 1 & 2. with1998-10-31031 October 1998 Monthly Operating Repts for Oct 1998 for Bvps,Units 1 & 2. with ML20206G0291998-10-31031 October 1998 BVPS Unit 2 Facility Changes,Tests & Experiments for Period 971101-981031 ML20154R9121998-10-20020 October 1998 Safety Evaluation Accepting Proposed Changes to QA Program Description in Chapter 17.2 of BVPS-2 Ufsar.Proposed Changes Would Modify QA Organization to Allow Warehouse QC Inspectors to Report to Manager of Nuclear Procurement Dept ML20154P7491998-10-19019 October 1998 SE Accepting Second ten-year Interval Inservice Insp Request for Relief RR-1-TYP-2-B5.40-1,Rev 0,for Plant, Unit 1 ML20198F7611998-10-0606 October 1998 Duquesne Light Co,Beaver Valley Power Station 1998 Emergency Preparedness Ingestion Zone Exercise, Conducted on 981006 ML20154C6711998-10-0101 October 1998 Safety Evaluation Concluding That Revised Model Identified in Dl Submittal Was Appropriate for Analysis of Installed Conduit Ampacity Limits.Determined That There Are No Outstanding Safety Concerns with Respect to Ampacity ML20154D5001998-09-30030 September 1998 Special Rept on Overview of BVPS-1 & BVPS-2 TS Compliance Issues & Corrective Action Taken L-98-197, Monthly Operating Repts for Sept 1998 for Beaver Valley Power Station,Units 1 & 2.With1998-09-30030 September 1998 Monthly Operating Repts for Sept 1998 for Beaver Valley Power Station,Units 1 & 2.With ML20154E2171998-09-28028 September 1998 Follow-up Part 21 Rept Re Defect with 1200AC & 1200BC Recorders Built Under Westronics 10CFR50 App B Program. Westronics Has Notified Bvps,Ano & RBS & Is Currently Making Arrangements to Implement Design Mods L-98-188, Special Rept:During 1998,Unit 2 SG Eddy Current exam,26 Tubes Were Improperly Encoded in SG 2RCS-SG21C During Previous Outage.Use of Independent Databases to Track New Indications Being Implemented as Preventive Measure1998-09-21021 September 1998 Special Rept:During 1998,Unit 2 SG Eddy Current exam,26 Tubes Were Improperly Encoded in SG 2RCS-SG21C During Previous Outage.Use of Independent Databases to Track New Indications Being Implemented as Preventive Measure L-98-178, Monthly Operating Repts for Aug 1998 for Bvps,Units 1 & 2. with1998-08-31031 August 1998 Monthly Operating Repts for Aug 1998 for Bvps,Units 1 & 2. with ML20155B5871998-08-28028 August 1998 Non-proprietary Rev 1 to 51-5001925-01, Risk Assessment for Installation of Electrosleeves at BVPS & Callaway Plant ML20236X2351998-08-0505 August 1998 Part 21 Rept Re Defect Associated W/Westronics 1200AC & 1200BC Recorders Built Under Westronics 10CFR50,App B Program.Beaver Valley,Arkansas Nuclear One & River Bend Station Notified.Design Mod Is Being Developed L-98-168, Monthly Operating Repts for July 1998 for Bvps,Units 1 & 21998-07-31031 July 1998 Monthly Operating Repts for July 1998 for Bvps,Units 1 & 2 L-98-157, Special Rept:On 980423,inoperability of Seismic Monitoring Instrument Noted.Caused by Obsolescence of Instrument & Inability to Obtain Necessary Spare Parts.Design Change Is Being Pursued to Obtain Replacement Product1998-07-29029 July 1998 Special Rept:On 980423,inoperability of Seismic Monitoring Instrument Noted.Caused by Obsolescence of Instrument & Inability to Obtain Necessary Spare Parts.Design Change Is Being Pursued to Obtain Replacement Product L-98-139, Monthly Operating Repts for June 1998 for Bvps,Units 1 & 21998-06-30030 June 1998 Monthly Operating Repts for June 1998 for Bvps,Units 1 & 2 L-98-119, Monthly Operating Repts for Bvps,Units 1 & 21998-05-31031 May 1998 Monthly Operating Repts for Bvps,Units 1 & 2 1999-09-30
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DPR-66 BEAVER VALLEY UNIT 1 CYCLE 11 l CORE OPERATING LIMITS REPORT This . Core. Operating Limits Report provides the cycle specific parameter limits developed in accordance with the NRC approved methodologies specified in Technical Specification Administrative Control 6.9.1.14.
Soecification 3.1.3.5 Shutdown Rod Insertion Lim'its The shutdown rods shall be withdrawn to at least 225 steps.
Specification 3.1.3.6 Control Rod Insertion Limits Control Banks A and B shall be withdrawn to at least 225 steps.
Control Banks C and D shall be limited in physical insertion as shown in Figure 1.
Soecification 3.2.1 Axial Flux Difference NOTE: The target band is 7% about the target flux from 0% to .]
100% RATED THERMAL POWER. i 1
The indicated Axial Flux Difference:
l a'. Above 90% RATED THERMAL POWER shall be maintained within the 7% target band about the target flux difference.
- b. Between '50% and 90% RATED THERMAL POWER is within the limits shown on Figure 2.
- c. Below 50% RATED THERMAL POWER may deviate outside the target band.
Specification 3.2.2 Fg(Z) and F xy Limits Fg(Z) 5 GEQ
Fg(Z) $ GEQ
0.5 Where
CFQ = 2.4 P=- THERMAL POWER RATED THERMAL POWER K(Z) = the function obtained from Figure 3.
l BEAVER VALLEY - UNIT 1 1 OF 6 COLR 11 I 9503100078 950220 PDR ADDCK05000g4 P
,~
DPR-66 .
.The F li [F x for RATED THERMAL POWER within specific corepYEnesmits.shall be:y(L))' ;
'Fxy(L) =
Fxy(RTP) (1 + PFXY * (1-P))
Where: For all core planes containing D-BANK:
i Fxy(RTP) 1.1.71 For unrodded core planes:
Fxy(RTP) $ 1.75 from 1.8 ft. elevation to 2.70 ft. elevation-Fxy(RTP) $ 1.82 from 2.70 ft. elevation to 7.40 ft. elevation Fxy(RTP) $ 1.76 from 7.40 ft. elevation to 9.40 ft. elevation Fxy (RTP) i 1. 69 f rom 9. 4 0 f t . elevation to 10.20 ft. elevation PFXY = 0.2 P= THERMAL POWER RATED THERMAL POWER Figure 4 provides the maximum total peaking factor times. relative T
power (Fg ,prel) as a function of axial core height during normal core operation.
Soecification 3.2.3 FNDH FNDH $ CFDH *(1 + PFDH *(1-P))
Where: CFDH = 1.62 PFDH = 0.3 P= THERMAL POWER RATED THERMAL POWER A
BEAVER VALLEY - UNIT 1 2 OF 6 COLR 11 l l
l
DPR-66 220 e' !
l(54,53,225) l 200 f l (100,187) 160 f
/ BANK C E 140 1 5 z 120 7 O
/
I (0,114) l l
BANK D b 100 '
g
$ 80 f E
O 60 # i 8
C 40 '
/ I 20 '
(8,0) l l 0
O 10 20 30 40 50 60 70 80 90 100 RELATIVE POWER (Percent) 1 FIGURE 1 CONTROL ROD INSERTION LIMITS AS A FUNCTION OF POWER LEVEL BEAVER VALLEY - UNIT 1 3 of 6 COLR 11 l
DPR-66 100 E (~I I' ") (I I' ")
-UNACCEPTABLE UNACCEPTABLE OPERATION 2 !
~ / \ . OPERATION ~
i" m 70 /
/ \ '
60 50 '
ACCEPTABLE OPERATION \ ' '
- u. (-31, 50) (31, 50)
O 40
$ 30 5
1 20 '
I 10 0
- -50 -40 -30 -20 -10 0 10 20 30 40 50 FLUX DIFFERENCE (AI) /o I
l FIGURE 2 AXIAL FLUX DIFFERENCE LIMITS AS A FUNCTION OF l RATED THERMAL POWER BEAVER VALLEY - UNIT 1 4 of 6 COLR 11 l
a DPR-66.
1.2 (0,1.000) (6,1.000) 1.0 ~ (10.8,.940) -
.80
\ :
g g .60 (12,.647)
.40
.20 0.00 0 2 4 6 8 10 12 l CORE HEIGHT (Feet) l l
I I
FIGURE 3 F[ NORMALIZED OPERATING ENVELOPE, K(Z) i l
l BEAVER VALLEY - UNIT 1 5 of 6 COLR 11 I
.I
I DPR-66 l
1 i i j
0.0, 2.400 6.0, 2.400 '
2.4 m 10.8, 2.256 -
^
- T'%49$$P4*iW14"~4##%P44*r . . , , N
2.0
\
+ \
Q w t \
a, E1.6 \
4 12.0, 1.553I 3 go
k BASIS F 4
2
1.76 FROM 7.4 TO 9.4 FT.
- 1.69 FROM 9.4 TO 10.2 FT. *
.40 x
0 2 4 6 8 10 12 CORE HEIGHT (Feet)
FIGURE 4 MAXIMUM (F[
- SEL) VS. AXIAL CORE HEIGHT DURING NORMAL CORE OPERATION BEAVER VALLEY - UNIT 1 6 of 6 COLR 11 1
. . ATTACHMENT A Beaver Valley Power Station, Unit No. 1 Cycle 11 Reload and Core Operating Limits Report Technical Specification Bases Change This change modifies Bases 3/4.1.2, Boration Systems, to address a change in methodology and assumptions for calculating boration requirements.
Remove Inser_t B 3/4 1-3 B 3/4 1-3 l.
1
REACTIVITY CONTROL SYSTEMS BASES 3/4.1.2 BORATION SYSTEMS (Continued)
The boration capability of either system is sufficient to provide a SHUTDOWN MARGIN from all operating conditions of 1.0% Ak/k after xenon decay and cooldown to 200*F. The maximum boration capability requirements occur at BOL from full power peak xenon conditions and I requires 11,336 gallons of 7000 ppm borated water from the boric acid storage tanks or 65,000 gallons of 2000 ppm borated water from the l refueling water storage tank.
With the RCS temperature below 200*F, one injection system is acceptable without single failure consideration on the basis of the stable reactivity condition of the reactor and the additional restrictions prohibiting CORE ALTERATIONS and positive reactivity change in the event the single injection system becomes inoperable.
The boration capability required below 200*F is sufficient to provide a SHUTDOWN MARGIN of 1% Ak/k after xenon decay and cooldown from 200'F to 140'F. This condition requires either 5000 gallons of 7000 l
ppm borated water from the boric acid storage tanks or 175,000 gallons of 2000 ppm borated water from the refueling water storage tank. '
3/4.1.3 MOVABLE CONTROL ASSEMBLIES l The specifications of this section ensure that (1) acceptable power distribution limits are maintained, (2) the minimum SHUTDOWN MARGIN l is maintained, and (3) the potential effects of rod misalignment on associated accident analyses are limited. OPERABILITY of the movable control assemblies is established by observing rod motion and l
determining that rods are positioned within 12 steps (indicated position), of the respective group demand counter position. The OPERABILITY of the rod position indication system is established by appropriate periodic CHANNEL CHECKS, CHANNEL FUNCTIONAL TESTS and l
CHANNEL CALIBRATIONS. OPERABILITY of the control rod position indicators is required to determine control rod position and thereby ensure compliance with the control rod alignment and insertion limits. The OPERABLE condition for the analog rod position indicators is defined as being capable of indicating rod position within , 12 steps of the associated group demand indicator. For power levels below 50 percent, the specifications of this section permit a one hour stabilization period to permit stabilization of known thermal drift in the analog rod position indicator channels.
During this stabilization period, greater reliance is placed upon the group demand position indicators to determine rod position. Above 50 percent power, rod motion is not expected to induce thermal l transients of sufficient magnitude to exceed the rod position indicator instrument accuracy of 12 steps. Limited use of rod position indication primary detector voltages is allowed as a backup method of determining control rod positions. Comparison of the group demand indicator to the calibration curve is sufficient to allow determination that a control rod is indeed misaligned from its bank when primary voltage measurements are used. Comparison of the group demand counters to the bank insertion limits with verification of rod position with the analog rod BEAVER VALLEY - UNIT 1 B 3/4 1-3 Revised by NRC letter dated