BSEP 05-0043, Submittal of Technical Specification Bases Change

Submittal of Technical Specification Bases Change

ML050950297
Person / Time
Site:	Brunswick
Issue date:	03/24/2005
From:	O'Neil E Progress Energy Carolinas
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
BSEP 05-0043
Download: ML050950297 (14)

Text

Cj Progress Energy MAR 2 4 2005 SERIAL: BSEP 05-0043 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001

SUBJECT:

Brunswick Steam Electric Plant, Unit No. 2 Docket No. 50-324/License No. DPR-62 Submittal of Technical Specification Bases Change Ladies and Gentlemen:

In accordance with Technical Specification (TS) 5.5.10 for the Brunswick Steam Electric Plant (BSEP), Unit No. 2, Carolina Power & Light Company, now doing business as Progress Energy Carolinas, Inc., is submitting Revision 37 to the BSEP, Unit 2 TS Bases.

Please refer any questions regarding this submittal to Mr. Leonard R. Beller, Supervisor -

Licensing/Regulatory Programs, at (910) 457-2073.

Sincerely, Edward T. O'Neil Manager - Support Services Brunswick Steam Electric Plant WRM/wrm

Enclosures:

1. Summary of Revisions to Technical Specification Bases

2. Page Replacement Instructions

3. Unit 2 Technical Specification Bases Replacement Pages Progress Energy Carolinas, Inc.

Brunswick Nuclear Plant P.O.Box 10429 Southport, NC 28461

Document Control Desk BSEP 05-0043 / Page 2 cc (with enclosures):

U. S. Nuclear Regulatory Commission, Region II ATTN: Dr. William D. Travers, Regional Administrator Sam Nunn Atlanta Federal Center 61 Forsyth Street, SW, Suite 23T85 Atlanta, GA 30303-8931 U. S. Nuclear Regulatory Commission ATITN: Mr. Eugene M. DiPaolo, NRC Senior Resident Inspector 8470 River Road Southport, NC 28461-8869 U. S. Nuclear Regulatory Commission (Electronic Copy Only)

AT'fN: Ms. Brenda L. Mozafari (Mail Stop OWFN 8G9) 11555 Rockville Pike Rockville, MD 20852-2738 Ms. Jo A. Sanford Chair - North Carolina Utilities Commission P.O. Box 29510 Raleigh, NC 27626-0510 Ms. Beverly 0. Hall, Section Chief Radiation Protection Section, Division of Environmental Health North Carolina Department of Environment and Natural Resources 3825 Barrett Drive Raleigh, NC 27609-7221

BSEP 05-0043 Enclosure 1 Page I of 1 Summary of Revisions to Technical Specification Bases Revision1 Affected Date Implemented Title/Description Unit 37 2 March 10, 2005

Title:

TRACG Methodology for Determining Core Operating Limits

Description:

This change revises B 3.2.2, "Minimum Critical Power Ratio (MCPR)," to reflect use of the TRACG methodology for determining core operating limits. Use of the TRACG methodology for Unit 2 was approved by License Amendment No. 262 dated March 4, 2005.

Title:

Testing Allowance for Oscillation Power Range Monitor (OPRM)

Upscale Function

Description:

This change revises B 3.3.1.1, "Reactor Protection System (RPS) Instrumentation," to incorporate an allowance for testing after changing algorithms for the OPRM upscale function.

I Revision 37 for Unit 2 incorporates bases change packages TSB-2004-02 and TSB-2004-09.

BSEP 05-0043 Enclosure 2 Page 1 of 1 Page Replacement Instructions Remove I Insert Technical Specifications Bases - Book 1 Title Page, Revision 36 Title Page, Revision 37 LOEP-1, Revision 36 LOEP-1, Revision 37 LOEP-2, Revision 35 LOEP-2, Revision 37 B 3.2.2-1, Revision 30 B 3.2.2-1, Revision 37 B 3.2.2-2, Revision 30 B 3.2.2-2, Revision 37 B 3.2.2-4, Revision 30 B 3.2.2-4, Revision 37 B 3.2.2-5, Revision 30 B 3.2.2-5, Revision 37 B 3.3.1.1-28, Revision 30 B 3.3.1.1-28, Revision 37 B 3.3.1.1-29, Revision 30 B 3.3.1.1-29, Revision 37

BSEP 05-0043 Enclosure 3 Unit 2 Technical Specification Bases Replacement Pages

BASES TO THE FACILITY OPERATING LICENSE DPR-62 TECHNICAL SPECIFICATIONS FOR BRUNSWICK STEAM ELECTRIC PLANT UNIT 2 CAROLINA POWER & LIGHT COMPANY REVISION 37

LIST OF EFFECTIVE PAGES - BASES Page No. Revision No. Page No. Revision No.

Title Page 37 B 3.1.2-1 30 I B 3.1.2-2 30 List of Effective Pages - Book 1 B 3.1.2-3 30 B 3.1.2-4 30 30 LOEP-1 LOEP-2 37 37 B 3.1.2-5 B 3.1.3-1 B 3.1.3-2 30 30 I

LOEP-3 35 LOEP-4 35 B 3.1.3-3 30 B 3.1.3-4 30 30 B 3.1.3-5 30

i. B 3.1.3-6 30 ii 30 B 3.1.3-7 30 B 2.1.1-1 30 B 3.1.3-8 30 B 2.1.1-2 30 B 3.1.3-9 30 B 2.1.1-3 30 B 3.1.4-1 30 B 2.1.1-4 30 B 3.1.4-2 30 B 2.1.1-5 30 B 3.1.4-3 30 B 2.1.2-1 30 B 3.1.4-4 30 B 2.1.2-2 30 B 3.1.4-5 30 B 2.1.2-3 30 B 3.1.4-6 30 B 3.1.4-7 30 B 3.0-1 30 B 3.1.5-1 30 B 3.0-2 30 B 3.1.5-2 30 B 3.0-3 30 B 3.1.5-3 30 B 3.0-4 30 B 3.1.5-4 30 B 3.0-5 30 B 3.1.5-5 30 B 3.0-6 30 B 3.1.6-1 30 B 3.0-7 30 B 3.1.6-2 30 B 3.0-8 30 B 3.1.6-3 30 B 3.0-9 30 B 3.1.6-4 30 B 3.0-10 30 B 3.1.6-5 30 B 3.0-11 30 B 3.1.7-1 30 B 3.0-12 30 B 3.1.7-2 30 B 3.0-13 30 B 3.1.7-3 30 B 3.0-14 30 B 3.1.7-4 30 B 3.0-15 30 B 3.1.7-5 30 B 3.0-16 30 B 3.1.7-6 30 B 3.1.8-1 30 B 3.1.1-1 30 B 3.1.8-2 34 B 3.1.1-2 30 B 3.1.8-3 34 B 3.1.1-3 30 B 3.1.8-4 30 B 3.1.1-4 30 B 3.1.8-5 30 B 3.1.1-5 30 B 3.1.1-6 30 (continued)

Brunswick Unit 2 LOEP-1 Revision 37

LIST OF EFFECTIVE PAGES - BASES (continued)

Page No. Revision No. Page No. Revision No.

B 3.2.1-1 30 B 3.3.1.1-34 30 B 3.2.1-2 30 B 3.3.1.1-35 30 B 3.2.1-3 30 B 3.3.1.1-36 30 B 3.2.1-4 30 B 3.3.1.1-37 30 B 3.2.1-5 30 B 3.3.1.1-38 30 B 3.2.2-1 37 B 3.3.1.1-39 30 B 3.2.2-2 37 B 3.3.1.1-40 30 B 3.2.2-3 B 3.2.2-4 30 37 37 B 3.3.1.1-41 B 3.3.1.1-42 B 3.3.1.1-43 33 33 30 I

B 3.2.2-5 B 3.3.1.2-1 30 B 3.3.1.1-1 30 B 3.3.1.2-2 30 B 3.3.1.1-2 30 B 3.3.1.2-3 30 B 3.3.1.1-3 30 B 3.3.12-4 30 B 3.3.1.1-4 30 B 3.3.1.2-5 30 B 3.3.1.1-5 30 B 3.3.1.2-6 30 B 3.3.1.1-6 30 B 3.3.1.2-7 30 B 3.3.1.1-7 30 B 3.3.1.2-8 30 B 3.3.1.1-8 30 B 3.3.1.2-9 30 B 3.3.1.1-9 30 B 3.3.2.1-1 30 B 3.3.1.1-10 30 B 3.3.2.1-2 30 B 3.3.1.1-11 30 B 3.3.2.1-3 30 B 3.3.1.1-12 30 B 3.3.2.1-4 32 B 3.3.1.1-13 30 B 3.3.2.1-5 30 B 3.3.1.1-14 30 B 3.3.2.1-6 30 B 3.3.1.1-15 30 B 3.3.2.1-7 30 B 3.3.1.1-16 30 B 3.3.2.1-8 30 B 3.3.1.1-17 30 B 3.3.2.1-9 30 B 3.3.1.1-18 30 B 3.3.2.1-10 30 B 3.3.1.1-19 30 B 3.3.2.1-11 30 B 3.3.1.1-20 30 B 3.3.2.1-12 30 B 3.3.1.1-21 30 B 3.3.2.1-13 30 B 3.3.1.1-22 30 B 3.3.2.1-14 30 B 3.3.1.1-23 30 B 3.3.2.1-15 30 B 3.3.1.1-24 30 B 3.3.2.2-1 30 B 3.3.1.1-25 30 B 3.3.2.2-2 30 B 3.3.1.1-26 30 B 3.3.2.2-3 30 B 3.3.1.1-27 30 B 3.3.2.2-4 30 B 3.3.1.1-28 37 B 3.3.2.2-5 30 B 3.3.1.1-29 37 B 3.3.22-6 30 I B 3.3.1.1-30 30 B 3.3.2.2-7 30 B 3.3.1.1-31 30 B 3.3.3.1-1 30 B 3.3.1.1-32 30 B 3.3.3.1-2 30 B 3.3.1.1-33 30 B 3.3.3.1-3 30 (continued)

Brunswick Unit 2 LOEP-2 Revision 37 l

MCPR B 3.2.2 B 3.2 POWER DISTRIBUTION LIMITS B 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)

BASES BACKGROUND MCPR is a ratio of the fuel assembly power that would result in the onset of boiling transition to the actual fuel assembly power. The MCPR Safety Limit (SL) is set such that 99.9% of the fuel rods avoid boiling transition if the limit is not violated (refer to the Bases for SL 2.1.1.2). The operating limit MCPR is established to ensure that no fuel damage results during anticipated operational occurrences (AOOs). Although fuel damage does not necessarily occur if a fuel rod actually experienced boiling transition (Ref. 1), the critical power at which boiling transition is calculated to occur has been adopted as a fuel design criterion.

The onset of transition boiling is a phenomenon that is readily detected during the testing of various fuel bundle designs. Based on these experimental data, correlations have been developed to predict critical bundle power (i.e., the bundle power level at the onset of transition boiling) for a given set of plant parameters (e.g., reactor vessel pressure, flow, and subcooling). Because plant operating conditions and bundle power levels are monitored and determined relatively easily, monitoring the MCPR is a convenient way of ensuring that fuel failures due to inadequate cooling do not occur.

APPLICABLE The analytical methods and assumptions used in evaluating the AOOs to SAFETY ANALYSES establish the operating limit MCPR are presented in References 2, 3,4, 5, 6, 7, and 8. To ensure that 99.9% of the fuel rods avoid boiling transition during any transient that occurs with moderate frequency, limiting transients are analyzed either with TRACG or other methodologies. The types of transients evaluated are loss of flow, increase in pressure and power, positive reactivity insertion, and coolant temperature decrease.

The TRACG methodology calculates an operating limit MCPR (OLMCPR) for the transient initial condition that will yield the largest change in CPR (ACPR) resulting from the limiting transient. When the largest delta-CPR is added to the MCPR SL, an OLMCPR is obtained. The most limiting of the OLMCPR calculated by either the TRACG or other methodology sets the core operating limits.

The MCPR operating limits derived from the transient analysis are dependent on the operating core flow and power state (MCPR, and (continued)

Brunswick Unit 2 B 3.2.2-1 Revision No. 37 l

MCPR B 3.2.2 BASES APPLICABLE MCPRp, respectively) to ensure adherence to fuel design limits during the SAFETY ANALYSES worst transient that occurs with moderate frequency (Ref. 7).

(continued)

Flow dependent MCPR limits are determined using the methodology described in Reference 2 to analyze slow flow runout transients. The operating limit is dependent on the maximum core flow limiter setting in the Recirculation Flow Control System.

Power dependent MCPR limits (MCPRp) are determined using the methodology described in Reference 2. Due to the sensitivity of the transient response to initial core flow levels at power levels below those at which the turbine stop valve closure and turbine control valve fast closure scrams are bypassed, high and low flow MCPRP operating limits are provided for operating between 23% RTP and the previously mentioned bypass power level.

The MCPR satisfies Criterion 2 of 10 CFR 50.36(c)(2)(ii) (Ref. 9). I LCO The MCPR operating limits, as a function of core flow, core power, and cycle exposure, specified in the COLR are the result of the Design Basis Accident (DBA) and transient analysis. The operating limit MCPR is determined by the larger of the MCPR, and MCPRp limits.

APPLICABILITY The MCPR operating limits are primarily derived from transient analyses that are assumed to occur at high power levels. Below 23% RTP, the reactor is operating at a minimum recirculation pump speed and the moderator void ratio is small. Surveillance of thermal limits below 23% RTP is unnecessary due to the large inherent margin that ensures that the MCPR SL is not exceeded even if a limiting transient occurs.

Statistical analyses indicate that the nominal value of the initial MCPR expected at 23% RTP is > 3.5. Studies of the variation of limiting transient behavior have been performed over the range of power and flow conditions. These studies encompass the range of key actual plant parameter values important to typically limiting transients. The results of these studies demonstrate that a margin is expected between performance and the MCPR requirements, and that margins increase as (continued)

Brunswick Unit 2 B 3.2.2-2 Revision No. 37 l

MCPR B 3.2.2 BASES SURVEILLANCE SR 3.2.2.1 (continued)

REQUIREMENTS slowness of changes in power distribution during normal operation. The 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> allowance after THERMAL POWER Ž 23% RTP is achieved is acceptable given the large inherent margin to operating limits at low power levels.

SR 3.2.2.2 Because the transient analysis takes credit for conservatism in the scram speed performance, it must be demonstrated that the specific scram speed distribution is consistent with that used in the transient analysis.

SR 3.2.2.2 determines the value of T,which is a measure of the actual scram speed distribution compared with the assumed distribution. The MCPR operating limit is then determined based on an interpolation between the applicable limits for Option A (scram times of LCO 3.1.4, "Control Rod Scram Times") and Option B (realistic scram times) analyses. The MCPR operating limits for the Option A and Option B analyses are specified in the COLR. The parameter r must be determined once within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after each set of scram time tests required by SR 3.1.4.1, SR 3.1.4.2, and SR 3.1.4.4 because the effective scram speed distribution may change during the cycle. The 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Completion Time is acceptable due to the relatively minor changes in Texpected during the fuel cycle.

REFERENCES 1. UFSAR Section 4.4.2.1.

2. NEDO-2401 1-P-A, General Electric Standard Application for Reactor Fuel (latest approved version).

3. UFSAR, Chapter 4.

4. UFSAR, Chapter 6.

5. UFSAR, Chapter 15.

6. NEDC-31776P, Brunswick Steam Electric Plant Units 1 and 2 Single-Loop Operation, December 1989.

(continued)

Brunswick Unit 2 B 3.2.2-4 Revision No. 37 l

MCPR B 3.2.2 BASES REFERENCES 7. NEDC-31654P, Maximum Extended Operating Domain (continued) Analysis for Brunswick Steam Electric Plant, February 1989.

8. NEDE-32906P-A, TRACG Application for Anticipated Operational Occurrences (AOO) Transient Analyses,' approved version as specified in the COLR.

9. 10 CFR 50.36(c)(2)(ii).

Brunswick Unit 2 B 3.2.2-5 Revision No. 37 l

RPS Instrumentation B 3.3.1.1 BASES ACTIONS D.1 (continued)

Condition D will be entered for that channel and provides for transfer to the appropriate subsequent Condition.

E.1, F.1, and G.1 If the channel(s) is not restored to OPERABLE status or placed in trip (or the associated trip system placed in trip) within the allowed Completion Time, the plant must be placed in a MODE or other specified condition in which the LCO does not apply. The allowed Completion Times are reasonable, based on operating experience, to reach the specified condition from full power conditions in an orderly manner and without challenging plant systems. In addition, the Completion Time of Required Action E.1 is consistent with the Completion Time provided in LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)."

H.1 If the channel(s) is not restored to OPERABLE status or placed in trip (or the associated trip system placed in trip) within the allowed Completion Time, the plant must be placed in a MODE or other specified condition in which the LCO does not apply. This is done by immediately initiating action to fully insert all insertable control rods in core cells containing one or more fuel assemblies. Control rods in core cells containing no fuel assemblies do not affect the reactivity of the core and are, therefore, not required to be inserted. Action must continue until all insertable control rods in core cells containing one or more fuel assemblies are fully inserted.

1.1 Condition I exists when the OPRM Upscale Trip capability has been lost for all APRM channels due to unanticipated equipment design or instability detection algorithm problems, or when testing to confirm plant responselperformance following algorithm modifications. References 15 and 16 justified use of alternate methods to detect and suppress oscillations under limited conditions. The alternate methods are procedurally established consistent with the guidelines identified in Reference 20. The alternate methods procedures require operating (continued)

Brunswick Unit 2 B 3.3.1.1-28 Revision No. 37 l

RPS Instrumentation B 3.3. 1.1 BASES ACTIONS 1.1 (continued) outside a "restricted zone" in the power-flow map and manual operator action to scram the plant if certain predefined events occur. The 12-hour allowed Completion Time for Required Action 1.1 is based on engineering judgment to allow orderly transition to the alternate methods while limiting the period of time during which no automatic or alternate detect and suppress trip capability is formally in place. Based on the small probability of an instability event occurring at all, the 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> is judged to be reasonable.

This Required Action is intended to allow continued plant operation under limited conditions when an unanticipated equipment design or instability detection algorithm problem causes OPRM Upscale Function inoperability in all APRM channels. This Required Action is not intended and was not evaluated as a routine alternative to return failed or inoperable equipment to OPERABLE status. Correction of routine equipment failure or inoperability is expected to be accomplished within the completion times allowed for Required Actions for Condition A. The alternate method to detect and suppress oscillations implemented in accordance with 1.1 is intended to be applied only as long as is necessary to implement and test corrective action to resolve the unanticipated equipment design or instability detection algorithm problem.

SURVEILLANCE As noted at the beginning of the SRs, the SRs for each RPS REQUIREMENTS instrumentation Function are located in the SRs column of Table 3.3.1.1-1.

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 for up to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, provided the associated Function maintains RPS trip capability. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 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. 11, 15, and 16) assumption of the average time required to perform channel Surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> testing allowance does not significantly reduce the probability that the RPS will trip when necessary.

(continued)

Brunswick Unit 2 B 3.3.1.1-29 Revision No. 37 1