ML020720059
| ML020720059 | |
| Person / Time | |
|---|---|
| Site: | Catawba  |
| Issue date: | 03/04/2002 |
| From: | Tuckman M Duke Power Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| Download: ML020720059 (7) | |
Text
Duke Duke Power 526 South Church St. EC07H PUw~en Charlotte, NC 28202 A Duke Energy Company P.O. Box 1006 EC07H Charlotte, NC 28201-1006 M. S. Tuckman (704) 382-2200 OFFICE Executive Vice President (704) 382-4360 FAX Nuclear Generation March 4, 2002 U.S. Nuclear Regulatory Commission Washington, D.C.
20555-0001 ATTENTION:
Document Control Desk
SUBJECT:
Duke Energy Corporation Catawba Nuclear Station - Units 1 & 2 Docket Nos. 50-413 and 50-414 Withdrawal of a Portion of a License Amendment Request Applicable to Technical Specification 3.3.2 and Technical Specification Table 3.3.2-1
REFERENCE:
M. S.
Tuckman, Duke Energy Corporation, Letter to the NRC Dated December 20, 2001 Duke Energy Corporation (Duke) submitted a license amendment request (LAR) applicable to Catawba Technical Specification (TS) 3.3.2 and TS Table 3.3.2-1 in a letter to the NRC dated December 20, 2001.
Based on discussions conducted in a conference call with NRC officials held on February 27,
- 2002, Duke is hereby withdrawing one of the changes contained in this LAR.
The change to Footnote e on TS Table 3.3.2-1 that was proposed in the December 20, 2001 LAR is being withdrawn.
Please note that this withdrawal affects three of the new pages contained in the December 20, 2001 LAR submittal package.
Accordingly, revised TS Pages 3.3.2-13 and 3.3.2-14 and Bases Page B3.3.2-22 are included as an attachment to this letter.
Duke has determined that this withdrawal has no impact on the determination of no significant hazards consideration provided in the December 20, 2001 submittal package.
This letter contains no regulatory commitments.
Questions regarding this matter should be directed to J.
S.
Warren at (704) 382-4986.
Very truly
- yours,
)K.~
M. S.
Tuckman Attachments 4Qo/
U.
S.
Nuclear Regulatory Commission March 4, 2002 Page 2 xc w/Attachments:
L.
A.
Reyes, Regional Administrator U.S. Nuclear Regulatory Commission, Region II Atlanta Federal Center 61 Forsyth St.,
SW, Suite 23T85 Atlanta, GA 30303 C.
P. Patel (Addressee only)
NRC Senior Project Manager (CNS)
U.
S.
Nuclear Regulatory Commission Mail Stop 0-8 H12 Washington, DC 20555-0001 D.
J.
Roberts, NRC Senior Resident Inspector (CNS)
R. Wingard, Director Division of Radioactive Waste Management South Carolina Bureau of Land and Waste Management 2600 Bull Street
- Columbia, SC 29201
U.
S. Nuclear Regulatory Commission March 4, 2002 Page 3 M. S.
Tuckman, affirms that he is the person who subscribed his name to the foregoing statement, and that all the matters and facts set forth herein are true and correct to the best of his knowledge.
M. S.
Tuckman, Executive Vice President Subscribed and sworn to me:
WAlAo--t4-4 2
Date
?
-d
, Notary Public My commission expires:
S221 2066 SEAL
S.
U.
S.
Nuclear Regulatory Commission March 4, 2002 Page 4 bxc w/Attachments:
M. T.
Cash L. E. Nicholson C. J.
Thomas G. D. Gilbert K. E. Nicholson J. M. Smith (2)
L. J.
Rudy CNS Master File CN04DM ELL
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 5)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT
- 4. Steam Line Isolation (continued)
(2) Negative 3 (b)(c) 3 per steam D
< 1 2 2.8 (d) 1 0 0(d) psi Rate - High line SR 3.3.2.5 psi SR 3.3.2.9 SR 3.3.2.10
- 5.
Turbine Trip and Feedwater Isolation
- a.
Turbine Trip (1) Automatic 1(f), 2 (f) 2 trains I
SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (2) SG Water 1(),2()
4 per SG J
_ 85.6%
83.9%
Level-SR 3.3.2.2 (Unit 1)
(Unit 1)
High-High SR 3.3.2.4
< 78.9%
77.1%
(P-14)
SR 3.3.2.5 (Unit 2)
(Unit 2)
SR 3.3.2.6 SR 3.3.2.9 SR 3.3.2.10 (3)
Safety Refer to Function 1 (Safety Injection) for all initiation functions and requirements. See Injection Item 5.a.(1) for Applicable MODES.
(4) Reactor I(f),2(f) 1 per train, S
SR 3.3.2.8 NA NA Trip (P-4) 2 trains
- b.
Feedwater Isolation (1)
Automatic 1,2 (e),3(e) 2 trains H
SR 3.3.2.2 NA NA Actuation SR 3.3.2.4 Logic and SR 3.3.2.6 Actuation Relays (continued)
(b) Except when all MSIVs are closed and de-activated.
(c) Trip function automatically blocked above P-11 (Pressurizer Pressure) interlock and may be blocked below P-1I when Steam Line Isolation Steam Line Pressure - Low is not blocked.
(d) Time constant utilized in the rate/lag controller is > 50 seconds.
(e) Except when all MFIVs, MFCVs, and associated bypass valves are closed and de-activated or isolated by a closed manual valve.
(f) Except when steam admission to the Main Turbine is prevented.
Catawba Units 1 and 2 Amendment Nos.
3.3.2-13
ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 5)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT 4 per SG (2)
SG Water Level-High High (P-14)
D SR 3.3.2.1 SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.5 SR 3.3.2.6 SR 3.3.2.9 SR 3.3.2.10
< 85.6%
(Unit 1)
< 78.9%
(Unit 2) 83.9%
(Unit 1) 77.1%
(Unit 2)
(3) Safety Refer to Function 1 (Safety Injection) for all initiation functions and requirements. See Injection Item 5.b.(1) for Applicable MODES.
(4) Tavg-Low coincident with Reactor Trip, P-4 4
J SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 Refer to Function 8.a (Reactor Trip, P-4) for all initiation functions and requirements.
- 6.
- a.
Automatic Actuation Logic and Actuation Relays
- b.
SG Water Level
- Low Low
- c.
Safety Injection
- d.
- e.
Trip of all Main Feedwater Pumps
- f.
Auxiliary Feedwater Pump Train A and Train B Suction Transfer on Suction Pressure - Low 1,2,3 1,2,3 2 trains 4 per SG H
SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.6 D
SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 Refer to Function 1 (Safety Injection) for all initiation functions and requirements.
1,2,3 3 per bus 1,2 3 per pump 1,2,3 3 per train T
SR 3.3.2.3 SR 3.3.2.9 SR 3.3.2.10 K
SR 3.3.2.8 SR 3.3.2.10 M, U SR 3.3.2.8 SR 3.3.2.10 A) > 9.5 psig A) 10.5 psig Catawba Units 1 and 2
> 561IF 564°F NA
_> 9%
(Unit 1)
> 35.1%
(Unit 2)
NA 10.7%
(Unit 1) 36.8%
(Unit 2)
> 3242 V NA 3500 V NA B) > 5.2 psig (Unit 1)
> 5.0 psig (Unit 2)
(continued)
(e)
Except when all MFIVs, MFCVs, and associated bypass valves are closed and de-activated or isolated by a closed manual valve.
B) 6.2 psig (Unit 1) 6.0 psig (Unit 2)
Amendment Nos.
3.3.2-14
ESFAS Instrumentation B 3.3.2 BASES APPLICABLE SAFETY ANALYSES, LCO, and APPLICABILITY (continued)
Control System. Therefore, the actuation logic must be able to withstand both an input failure to the control system (which may then require the protection function actuation) and a single failure in the other channels providing the protection function actuation.
Thus, four OPERABLE channels are required to satisfy the requirements with a two-out-of-four logic.
The setpoints are based on percent of narrow range instrument span.
(3)
Feedwater Isolation-Safety Iniection Feedwater Isolation is also initiated by all Functions that initiate SI. The Feedwater Isolation Function requirements for these Functions are the same as the requirements for their SI function. Therefore, the requirements are not repeated in Table 3.3.2-1.
Instead Function 1, SI, is referenced for all initiating functions and requirements. Item 5.b.(1) is referenced for the applicable MODES.
(4)
Feedwater Isolation - RCS T.v - Low coincident with Reactor Trip (P-4)
This signal provides protection against excessive cooldown, which could subsequently introduce a positive reactivity excursion after a plant trip. There are four channels of RCS Tavg - Low (one per loop),
with a two-out-of-four logic required coincident with a reactor trip signal (P-4) to initiate a feedwater isolation. The P-4 interlock is discussed in Function 8.a.
The Feedwater Isolation Function must be OPERABLE in MODES 1 and 2 and also in MODE 3 (except for the functions listed in Table 3.3.2-1). Feedwater Isolation is not required OPERABLE when all MFIVs, MFCVs, and associated bypass valves are closed and de-activated or isolated by a closed manual valve. In lower MODES, the MFW System is not in service and this Function is not required to be OPERABLE.
Catawba Units 1 and 2 Revision No. I B 3.3.2-22