Text

Proposed Tech Specs Re Hydrogen Igniter Surveillance Test Requirement,Containment Isolation Valve Operability & Pressurizer Spray Nozzle Operational Limits & Changes to Table 3.2-1 for DNB Parameters
	ML20077D732
Person / Time
Site:	Sequoyah
Issue date:	07/21/1983
From:	; TENNESSEE VALLEY AUTHORITY
To:	;
Shared Package
ML20077D722	List: ML20077D714; ML20077D732;
References
	NUDOCS 8307270040
	Download: ML20077D732 (33)
	v • d • e

n- 1 ENCLOSURE 1 l

IVA-SQN-IS-44 i

SEQUOYAH NU(LEAR PLANT l GANGE NO.1 i

GANGES IN TABLE 3.2.1 FOR DNB PARAMETERS 4

i B307270040 830721 PDR ADOCK 05000327 P PDR

IVA-SQN-TS-46 GANGE NO.1 SEQUOYAH NU EEAR PLANT PROPOSED TEGNICAL SPECIFICATIONS i

l l

l I

vi TABLE 3.2-1 E3 E5 DNB PARAMETERS 5

x

' LIMITS

! E

1 4 Loops In 3 Loops in .

PARAMETER Operation Operation **

Reactor Coolant System T ,yg < 583*F Pressurizer Pressure > 2220 psia

i .

" Limit not applicable during either a THERMAL POWER ramp in excess of 5% RATED THERMAL POWER !

I per minute or a THERMAL POWER step in excess of 10% RATED THERMAL POWER. physics test, or w performance of surveillance requirement 4.1.1.3.b.

]s ** Limits pending NRC approval of 3 loop operation.

i no t

j 1

4 1 i 4

lABLE 3.2-1 m

j@ DNB PARAMETLRS S

N LIMITS C

25 4 1. cops In 3 Loops In Opera-Operation

-4 PARAMETER tion ro Reactor Coolant System I,yg < 583*F Pressurizer Pressure > 2220 psia * ,

'b - .

? ,

O

Limit not appTicable during either a 111ERMAL POWER ramp in excess of 5% of RATED THERMAL POWER per minute or a THERMAL POWER step in excess of 10% of RATED THERMAL POWER, physics test, or performance of surveillance requiremen't 4.1.1.3.b.

- Limits pending NRC approval of 3 loop operation.

- J

'IVA SQN 'IS-46 CHANGE NO.1 JUSTIFICATION PROPOSED TEGNICAL SPECIFICATIONS During the power coefficient measurement (physics test) and during the perf ormance of surveillance requirement (S/ R) 4.1.1.3.b, maintaining pressurizer pressure greater than or equal to 2220 psia has been very difficult. Measurement of the moderator temperature coefficient (MTC) required by S/R 4.1.1.3.b has a high probability of violating the departure f rom nucleate boiling (DNB) parameters specified by technical specifica-tion (T/S) 3.25. S/R 4.1.1.3.b has been performed twice and has narrowly missed a violation of the DNB parameters. He test is made difficult by the competing effects of cooling down the system to measure KFC and yet maintain the system pressure above the DNB limit specified by T/S 3.2.5.

H e reactor coolant system T must be dropped a minimum of 4-6*F below the T for an accuraN3 measurement. The associated drop in pressurizer"[Ivel results in a downswing of pressurizer pressure and 2220 psia is difficult to maintain. Allowing the-pressure to f all during the MIC measurement will not compromise DNB considerations because the overtemperature delta-T trip will still provide core protection for all coehinations of pressure and coolant temperatures.

The requested change has been evaluated pursuant to 10 CF2 50.92 and no significant hazards considerations are involved because the change does not:

1) Involve an increase in the probability or consecuences of an accident previously evaluated.

Based on the f act that this type of transient has already been analyzed and because a relaxation of the DNB pressure limit is already allowed i

f or other transients such as step and ramp power changes, the change does not involve an increase in the probability or consequence of an accident previously evaluated.

2) Create the possibility of a new or different kind of accident f rom any accident previously evaluated.

Based on the f act that this type of transient has been previously analyzed and is within the scope of those documented within the FSAR, this change does not create the possibility of a new or dif ferent hind of accident from any accident previously evaluated.

l' e

e- e .--- -

y ,w,e ,-t r-* ---_,.m.------,--eyw-- - -+*w= e 9 - -sww-- s-*we w -- -wv ~---v--g v -e,- p --y--- - - ---v+-- -g y

);

. 3) Involve a reduction in the margin of saf ety.

I Allowing the pressure to f all below the value specified in T/S 3.25 during the MIC measurement will not compromise DNB considerations because the overtemperature delta-T trip will still provide core pro-tection for all combinations of pressure and coolant temperatures.

Based on the above f act, as well as items (1) and (2), the change does not involve a reduction in the margin of saf e ty.

ENGOSURE 2 i

IVA-SQN-TS-46 SFAUOYAH NUCLEAR PLANT CHANGE NO. 2 i

1 REVISION 10 THE HYDROGEN IGNITER SURVEILLANCE TEST REQUIREMENT, 4.6.4.3.b d

i i

I l

,-~--e --.. ,,----..n- , a -,w. - . . . . - - - - - - - . , . . -.,,...,c,,,, ,v rr, -,e.--,,.-,- ,,.y, , , - - - - , y,-. - , , , - , , --,-- --p ,-r n,v,,-~.s, -

IVA-SQN-13-46 GANGE NO. 2 SEQUOYAH NUCLEAR PLANT PROPOSED TEGNICf.L SPECIFICATIONS l

i

ilYDROGFN MITIGATION SYSTEM LIMITING CONDITION FOR OPERATION 3.6.4.3 The primary containment hydrogen mitigation system shall be operable.

APPLICABILITY: MODES 1 and 2. .

s' ACTION:

With one train of hydrogen mitigation system inoperable, restore the inoperable train to OPERABLE status within 7 days or increase the surveillance interval of SvR. 4.6.4.3(a) from 92 days to 7 days on the operable train until the inoperable train is returned to. OPERABLE status. ,

SURVEILLANCE REQUIREMENTS 4.6.4.3 The hydrogen mitigation system shall be demonstrated OPERABLE:

a. At least once per 92 days by energizing the supply breakers and verifying that at least 66 of 68 igniters are energized.*

b. At least once per 18 months by verifying,t'he temperatures of at least a 10% sample of the igniters are a minimum of 1700*F. For each igniter found inoperable during this verification, an additional sample of at least 10% of all the igniters shall be temperature tested until no more inoperable igniters are found or all igniters have been verified OPERABLE.

., s

" Inoperable igniters must not be on corresponding redundant circuits which provide coverage for the same region.

SEQUOYAH - UNIT 1 3/4 6- 25a

. . _. . . . . N . - -. m.. ......+.....--:s-~ .:' - ~ ---~'* " ~ - - - - - - ~ "

r EDR,0GFN MITIGATION SYSTEM LIMITING CONDITION FOR OPERATION 3.6.4.3 -The primary containment hydrogen mitigation system shall be operable.

APPL.ICABILITY: MODES 1 and 2. .

s' ACTION:

With one train of hydrogen mitigation system inoperable, restore the inoperable train to OPERABLE status within 7 days or increase the surveillance interval of SrR. 4.6.4.3(a) from 92 days to 7 days on the operable train until the inoperable train is returned to.0PERABLE status.

SURVEILLANCE REQUIREMENTS 4.6.4.3 The hydrogen mitigation system shall be demonstrated OPERABLE:

a. At least once per 92 days by energizing the supply breakers and verifying that at least 66 of 68 igniters are energized.*

b. At least once per 18 months by verifying the temperatures of at least a 10% sample of the igniters are a minimum of 1700*F. For each inniter found inoperable during this verification, an additional sample of at least 10% of all the igniters shall be temperature tested until no more inoperable igniters are found or all igniters have been verified OPERABLE. ,

5 ph.

Inoperable igniters must not be on cc: e isponding redundant circuits which provide coverage for the same region.

SEQUOYAH - UNIT 2 3/4 6- 26

. . . a. - u . . _

. . . . .- a .. . - 1 2-=. w ac.: r -. . . x ~ ~ ... ' -u- - - .'~ u. -- - : -- ' - = - -

TVA-SQN 'IS-46 CHANGE NO. 2 Jt1STIFICATION FOR PROPOSED TEGNICAL SPECIFICATION A large percentage of the igniters cannot easily be surf ace temperature tested because of physical constraints, such as those located in the upper compartment of containment and because of ALARA considerations, such as those located in the lower compartment of containment. The additional costs and the additional radiation exposure to perf orm 100-percent surf ace temperture testing of the igniters is not acceptable.

We believe that a surf ace temperature test every 18 months for all of the igniters is not necessary to verify operability. As stated in the techni-cal specifications f or Sequoyah unit 1, each 92 days, the igniters are energized to ensure circuit continuity. As stated in supplement 6 of the Sequoyah Nuclear Plant Saf ety Evaluation Report (SQN SSER 6), during energization current and voltage readings will be taken and compared to i baseline current and voltage levels taken during preoperational testing.

These readings will indicate whether each circuit is supplying sufficient power to produce acceptable igniter surf ace temperatures. Additionally, in order to ensure that the baseline circuit power (voltage times current) surf ace temperature correlation doesn't change over the service lif e of the igniters, a surface temperature test every 18 months will be conducted on a 10-per ce nt sample of the igniters. This data will also provide f or more accurate proj ections of the service lif e of the ignitors under normal containment conditions.

The requested change has been evaluated pursuant to 10 CFR 50.92 and no significant hazards considerations are involved because the change does not:

1) Involve an increase in the probability or consequences of an accident previously evaluated.

Based on the f act that the proposed surveillance will provide adequate verification of operability there is not an increase in the probability or consequences of an accident previously evaluated.

2) Create the possibility of a new or dif f erent kind of accident f rom any accident previously evaluated.

Based on the f act that the proposed surveillance will provide verifica-tion' of operability, the change does not create the possibility for an accident different from previously evaluated.

- ~ _ .- _ _ - . _ _ _. ,_ _. . . . _ . - - _ _ - _ _ _ _ _ , _

j

3) Involve a reduction in the margin of safety.

Ba sed on the fact that the system will still be verified to be operable, the change does not involve a reduction in the margin of safety.

I 1

l f

f i

h e

l

.. -- .., _ _ . . . . . _ , , _ . _ _ . . . _ , . - - . - . _ _ _ _ _ . , _ _ .. . . _ _ . . _ _ . , . _ . . . . _ _ _ _ _ _ . _ _ . . . . ~ . . , . _ . . . . - . . . . . . . _ . _ .

0 I

i ENCLOSURE 3 1

IVA-SQN-TS-46 SEQUOYAH NUCLEAR PLANT GANGE NO. 3 l

l i

.I

i. REVISION OF TABLE 3.6.2 FOR OPERABILITY

, OF CONTAINNENT ISOLATION VALVES d.

?

i I

i t

l t

I l

l.

D t

4 a

- ., ...wa> - -- - , --o-,. g.~-,,.,v.,_ w-y,-ww - eg,,,,,,,,m--,, n---m,,-n,w,,-,..w,mn.~we,m., ,,,w,,enwe,,,.-,,wn,-,,,,r.,-.

IVA-SQN-TS-46 GANGE NO. 3 SEQUOYAH NUCLEAR PLANT PROPOSED TEGNICAL SPECIFICATIONS l

_. - . . . . - , , . , - - . _ . - ~. -

TABLE-3.6-2 m

j CONTAINMENT' ISOLATION VALVES 5

x e VALVE NUMBER FUNCTION MAXIMUM ISOLATION TIME (Seconds)

C A. PHASE "A" ISOLATION

1. FCV-1-7 SG Blow Dn 10*

~

2. FCV-1-14 SG Blow Dn 10*

3. FCV-1-25 SG Blow Dn 10*

4. FCV-1-32 SG Blow Dn 10*

5. FCV-1-181 SG Blow Dn 15*

6. FCV-1-182 SG Blow Dn 15*

7. FCV-1-183 SG Blow Dn 15*

8. FCV-1-184 SG Blow Dn 15*

9. FCV-31C-222 CW-Inst Room Clrs 10*

10. FCV-31C-223 CW-Inst Room Clrs 10*

11. FCV-31C-224 CW-Inst Room Clrs 10*

12. FCV-31C-225 CW-Inst Room C1rs 10*

R

13. FCV-31C-229 CW-Inst Room Clrs 10*

14. FCV-31C-230 CW-Inst Room Clrs 10*

T 15. FCV-31C-231 CW-Inst Room Clrs 10*

U 16. FCV-31C-232 -CW-Inst Room Clrs 10*

17 FCV-43-22 Sample RC Outlet Hdrs 10*

18. FCV-43-23 Sample RC Outlet Hdrs 10*

19. FCV-43-55 SG Blow Dn Sample Line 10*

20. FCV-43-58 SG Blow Dn Sample Line 10*-

21. FCV-43-61 SG. Blow Dn Sample Line 10*

22. FCV-43-64 SG Blow Dn Sample Line 10*

23. FCV-61-96 Gylcol Inlet to Floor Cooler 30*

24. FCV-61-97 -Gylcol Inlet to Floor Cooler 30*

25. FCV-61-110 Gylcol Outlet to Floor Cooler 30*

26. FCV-61-122 Gylcol Outlet to Floor Cooler 30*

27. FCV-61-191 Ice Condenser - Gylcol In 30*

28. FCV-61-192 Ice Condenser - Gylcol In 30*

29. FCV-61-193 Ice Condenser - Gylcol Out 30*

30. FCV-61-194 Ice Condenser - Gylcol Out 30*

31. FCV-62-61 RCP Seals 10 9

-TABLE 3.6-2 (Continued)

$ CONTAINMENT ISOLATION VALVES j

Y z

MAXIMUM ISOLATION TIME (Seconds)

FUNCTION

. VALVE NUMBER b

A. PHASE "A" ISOLATION (Cont.)

RCP Seals-10.

32. FCV-62-63 10*-

33. FCV-62-72 Letdown Line 10*

34. FCV-62-73 Letdown Line 10*

35. FCV-62-74 Letdown Line 20

36. FCV-62-77 Letdown Line 10*

FCV-63-23 - Accum to. Hold Up Tank

37. 10*

38. FCV-63-64 WDS N 2 to Accum 10*

FCV-63-71 Accum to Hold Up Tank

39. 10*

Accum to Hold Up Tank

40. FCV-63-84 10*

41. FCV-68-305 '!DS N, to PRT 10*

42. FCV-68-307 -PRT tB Gas Analyzer 10*

t' 43. FCV-68-308 .PRT to Gas Analyzer- 10*

44. FCV-70-85 CCS from Excess Lt Dn Hx 60*

T 45. FCV-70-143 CCS to Excess Lt On Hx 10*

RCDT Purep Disch f Es 46. FCV-77 10*

47. FCV-77-10 RCDT Pump Disch RCOT to Gas Analyzer 10*

48. FCV-77-16 10*

FCV-77-17 RCOT to Gas Analyzer

49. 10*

50. FCV-77-18 RCDT and PRT to V H 10*

,51. FCV-77-19 RCDT and PRT-to V H 10*

52. FCV-77-20 N to RCOT 10*

53. FCV-77-127 F$oorSumpPumpDisch Floor Sump Pump Disch 10* ,

54. FCV-77-128 10*

55. FCV-81-12 Primary Water Makeup 10*

56. FCV-87-7 UHI Test Line 10*

57. FCV-87-8 UHI Test Line 10*

58. 'FCV-87-9 UHI Test Line 10*

59. FCV-87-10 UHI Test Line 10*

60. FCV-87-ll UHI Test Line 20

61. FCV-26-240 Fire Protection <Isol. 20

62. FCV-26-243 Fire Protection Isol.

a-

I 1 ABI E 3.6-2 (ConLinued) un E CONIA MMINI ISOLAll0N VAlVIS 8

$- ftJNCTION MAXIl10M IS01.Ai10N 11110 (Seconds)

VALVE NUMutR A. PilASL "A" !$0L ATION (Cont. )

10*- i I

62. tCV-d3-2 Sample Przr Steam Space 10*

63. TCV 93-3 Sample Przr Steam Space 10* -

64. ICV-43-il Sample Przr Liquid 10*

65. FCV-43-12 Sample Przr Liquid b*

l Accum Sample

66. ICV-43-34 Accum Sample b'*

67. fCV-43-3S Baron Analyzer S*

68. f CV /S Boron Analyzer S*

69. fCV-43-77 B. PilASE "B" JSOLATION R

s.

Control Air Supply ,10 p 1. FCV-32-81 10

2. FCV-32-103 Control Air Supply 10

$ 3. TCV-32-Ill Control Air Supply 60*

LRCW - LWR Cmpt Clrs

4. FCV-67-83 60*

ERCW - LWR Cmpt Cirs

b. FCV-6/-87 60*

ERCW - LWR Cmpt Clrs

6. FCV-67-88 60*

fCV-6/-91 ERCW - LWR Cmpt Cirs

7. 60*

FCV-6/-95 ERCW - LWR Cmpt Clrs

8. 60*

ERCW - (WR Cmpt Cirs

9. FCV-6/-96 60*

ERCW - LWR Cmpt Cirs

10. ICV-67-99 60*

fCV-67-103 ERCW - LWR Cmpt Cirs

11. 60*

ICV-6/-104 ERCW - LWR Cmpt Cirs

12. 60*

ERCW - LWR Cmpt Cirs

13. ICV-67-107 60*

' ICV-6/-ill liRCW - lWR Cmpt Cirs 14.

ERCW - LWR Cmpt Cirs 60*

15. ICV-6/-il2 60*

F CV-6 /- 130 ERCW - Up Cmpt Cirs

16. 60*

ICV-67-131 ERCW - Up Cmpt Cirs

17. 60*

.18. FCV-67-133 ERCW - tip Cmpt Cirs 60*

19. I CV-6 /- 134 EltCW - Up Cmpt Cirs 60*

l fCV-6/-138 ERCW - Up Cmpt Clrs 20.

l

m TABLE 3.6-2 (Continued)- ,'

c CONIAINHfNI ISOLAll0N VAIVFS e

z I

e VALVE NUMBER FUNCTION MAXIMUM'IS0l AT10N llML (Seconds)

B. PHASE "B" ISOLATION (Cont. )

~

21. FCV-67-139 ERCW .Up Cmpt Clrs 60*

22. FCV-67-141 ERCW '- Up Cmpt Clrs 60*

23. FCV-67-142 ERCW - Up Cmpt Clrs 60*

24. FCV-67-295 ERCW - Up Cmpt Clrs 60*

25. fCV-67-296 'ERCW - Up Capt Clrs 60*

26. FCV-67-297 ERCW - Up Cmpt Clrs 60*

27. FCV-67-298 ERCW - Up Cmpt Clrs 60*

28. FCV-70-87 RCP Theraial Barrier Ret 60

29. FCV-70-89 CCS from RCP Oil Coolers 60

, w 30. FCV-70-90 RCP Thermal Barrier Ret 60

D 31. FCV-70-92 CCS'from RCP Oil Coolers 60 p' 32. FCV-70-134 To RCP Thermal Barriers 60 g 33. FCV-70-140 CCS to RCP Oil Coolers 60 C. PHASE "A" CONTAINMENT VENT ISOLATION

1. FCV-30-7 Upper Comipt Purge Air Supply 4*

2. FCV-30-8 Upper Compt Purge Air Supply 4*

3. FCV-30-9 Upper Compt Purge Air Supply 4*

4. FCV-30-10 Upper Compt Purge Air Supply 4*

5. FCV-30-14 Lower Compt Purge Air Supply 4*

- 6. FCV-30-15 Lower Compt Purge Air Supply 4*

7. FCV-30-16 Lower Compt Purge Air Supply 4*

8. FCV-30-17 Lower Compt Purue Air Supply 4*

9. FCV-30-19 Inst Room Purge Air Supply 4*

10. FCV-30-20 Inst Room Purge Air Supply 4*

11. FCV-30-37 Lower Compt Pressure Relief 4*

12. FCV-30-40 Lower Compt Pressure Relief 4*

l' i

l ABLE 3.6-2 (Cont intied)

N CONTAltlHENT 150tATION VALVES--

S g.

'E FUNCTION MAXIMUM ISOLATION llME (Seconds]

.. VALVE NUMBER C. PilASE "A" CONTAINMENT VENT ISOLATION (Cont.-)

4*

FCV-30-50 upper Compt.Pur0e Air Exh 4*

- 13. Upper Compt Purge, Air Exh

14. FCV-30-51 4* .

FCV-30-52

. Upper Compt Pur0e Air Exh 4*

15. Upper Compt Purge Air Exh

16. FCV-30-53 4*

Lower Compt Purge Air Exh 4*

17. FCV-30-56 Lower Compt Purge Air Exh

18. FCV-30-SI 4*

Inst Room Purge Air Exh 4*

19. FCV-30-58 Inst Room Purge Air Exh

20. FCV-30-59 5*

Cntut Bldg LWR Compt Air Hon 5*

21. FCV-90-107 Cotmt Bldg LWR Compt Air Hon

22. FCV-90-108 5* ,

a Cntut Bldy LWR Compt Air Hon , 5*

2 23. -FCV-90-109 Cntet Bldg LWR Compt Air Hon

24. FCV-90-110 5*

m Catml Bldg LWR Compt Air Mon 5*

4 25. FCV-90-111 Cntet Bldg LWR Compt Air Men

"* 26. FCV-90-113 5*

Cntat Bldg LWR Compt Air Mon 5*

27. FCV-90-114 Cntut Bldg LWR Compt Air Hon S*

28. FCV-90-115 Cntat Bldg LWR Compt Air Mon

29. FCV-90-116 5*

Cntut Bldg LWR Compt Air Hon

30. FCV-90-117 D. OlllER 25

1. - FCV-30-46 Vacuum Relief Isolation Valve 25

2. FCV-30-47 Vacuum Relief Isolation Valve 25

3. FCV-30-48 Vacuum Relief Isolation Valve

TABLE 3.6-2 , ,

m j CONTAINMENT ISOLATION VALVES s

1 e VALVE NUMBER FUNCTION MAXIMUM ISOLATION TIME'(Seconds)

C

^

f A. PHASE "A" ISOLATION

1. FCV-1-7 SG Blow Dn 10*

2. FCV-1-14 SG Blow Dn 10*

i 3. FCV-1-25 SG Blow Dn 10*

l'

4. FCV-1-32 SG Blow Dn 10*

5. FCV-1-181 SG Blow Dn .15*

6. FCV-1-182 SG Blow Dn 15*

l 7. FCV-1-183 SG Blow Dn 15*

3

8. FCV-1-184 .

SG Blow Dn 15*

9. FCV-31C-222 CW-Inst Room Clrs 10*

10. FCV-31C-223 CW-Inst Room Clrs 10*

11. FCV-31C-224 CW-Inst Room Clrs 10*

12. FCV-31C-225 CW-Inst Room Clrs ' 10*

s*

1 13. FCV-31C-229 CW-Inst Room Clrs 10*

i

14. FCV-31C-230 CW-Inst Room Clrs 10*

i i 15. FCV-31C-231 CW-Inst Room Cirs 10*

O 16. FCV-31C-232 .CW-Inst Room Clrs 10*

17. FCV-43-22 Sample RC Outlet Hdrs 10*

1 18. FCV-43-23 Sample RC Outlet Hdrs 10*

2-

19. FCV-43-55 SG Blow Dn Sample Line 10*

i 20. FCV-43-58 SG Blow Dn Sample Line 10*

21. FCV-43-61 SG Blow Dn Sample Line 10*

22. FCV-43-64 .SG Blow Dn Sample Line 10*

i 23. FCV-61-96 Gylcol Inlet to Floor Cooler 30*

i 24. FCV-61-97 Gylcol Inlet to Floor Cooler 30*

l 25. FCV-61-110 Gylcol Outlet to Floor Cooler 30*

i 26. FCV-61-122 Gylcol Outlet to Floor Cooler 30*

! 27. FCV-61-191 Ice Condenser - Gylcol In 30*

l 28. FCV-61-192 Ice Condenser - Gylcol In 30*

29. FCV-61-193 Ice Condenser - Gylcol Out 30*

i 30. FCV-61-194 Ice Condenser - Gylcol Out 30*

- 31. FCV-62-61 RCP Seals 10 i

i

. .. - . -.. -~ . . . . - - . . . - - .. - .- . . -~- . - - .

},

i' .

i t I ..

. t

' TABLE 3.6-2 (Continued)

t-CONTAINMENT ISOLATION VALVES _

i 4 S

S ,

E FUNCTION MAXIMUM ISOLATION TIME (Seconds)

, l

p i VALVE NUMBER C '

5 A. PHASE "A" ISOLATION (Cont.) 10' ,

FCV-62-63 RCP Seals 10*

32.

3

" 33. FCV-62-72 Letdown Line l@

34. FCV-62-73 Letdown Line 10*

35. FCV-62-74 Letdown Line 20

36. FCV-62-77 Letdown Line 10*

Accum to Hold Up Tank 10*

37. FCV-63-23 FCV-63-64 WDS N to Accum 10* .

38. Accum 2 to Hold Up Tank

39. FCV-63-71 10*

Accum to Hold Up Tank 10*

40. FCV-63-84

WDS N., to PRT ~ 10*

4 41. FCV-68-305 PRT tB Gas Analyzer ,

42. FCV-68-307 10*

g PRT to Gas Analyzer 10*

R 43. FCV-68-308

'

44. FCV-70-85 CCS from Excess Lt Dn Hx 60*

45. FCV-70-143 CCS to Excess Lt Dn Hx 10* - !

i ? RCDT. Pump Disch 10*

j

@ 46. FCV-77-9 1RCOT Pump Disch

47. FCV-77-10 10*

RCDT to Gas Analyzer 10*

2

48. FCV-77-16 ' :RCOT to Gas Analyzer

49. FCV-77-17 10*

i RCOT and PRT.to V H

! 50. FCV-77-18 10*

FCV-77-19 RCOT and PRT to V H 10*.

51. !

I 52. FCV-77-20 N to RCDT 10*_

F$oorSumpPumpDisch 10*

' 53. FCV-77-127 Floor Sump Pump Disch 10*

54. FCV-77-128 Primary Water Makeup

55. FCV-81-12 10*

' 56. FCV-87-7 UHI Test Line 10*

UHI. Test Line j

57. FCV-87-8 10* "

l 58.

UHI Test Line .

10*

.FCV-87-9 UHI Test Line

59. FCV-87-10 l@

60. FCV-87-ll UHI-Test Line 20

61. FCV-26-240 Fire Protection Isol. 20

62. FCV-26-243 Fire Protection Isol.

2 i .

4

r- - _ _ _ _ __

1ABlE 3.6-2 (Continued) m g CONIA1]NMIN1 150l AIION VAlVIS

' FilNCTION MAXIMUM ISOLATION llME (Seconds)

VALVE NilHUFR 9e q ' A. PilASE "A" IsotATION (Cont.)

" 10* i

62. FCV-43-2 Sample Przr Steam Space I Sample Przr Steam Space 10*

63. FCV-43-3 Sample Przr Liquid 10*

64. FCV-43-il 10*

65. FCV-43-12 Sample Przr Liquid

66. ICV-43-34 Accum Sample S*

67. FCV-43-35 Accum Sample S*

68. FCV-43-75 Boron Analyzer 5* -

69. FCV-43-77 Boron Analyzer 5*

B. PilASE "B" ISOLATION

~

Control Air Supply , 10 p- 1. FCV-32-81 Control Air Supply 10 N 2. FCV-32-103

3. FCV-32-lli Control Air Supply 10

'ERCW - LWR Cmpt Clrs 6(P

4. FCV-67-83 ERCW - LWR Cmpt Clrs 60*

5. FCV-6/-87 ERCW - LWR Cmpt Clrs 6 04

6. FCV-67-88 ERCW - LWR Cmpt Cirs 60*

7. FCV-67-91 FCV-67-95 ERCW - LWR Cmpt Clrs 60*

8.

ERCW - LWR Cmpt Clrs 60*

9. FCV-67-96 ERCW - LWR Cmpt Cirs 60*

10. ICV-67-99 FCV-67-103 ERCW - LWR Cmpt Cirs 60*

11.

-ERCW - IWR Cmpt Clrs 60*

-12. FCV-6/-104 ICV-67-107 ERCW - LWR Cmpt Clrs 60*

13.

LRCW - IWR Cmpt Cirs 6(P

14. I CV-6 /- i l l ERCW - LWR Cmpt Clrs 6 04

15. ICV-6/-ll2 ERCW - Up Cmpt Cirs 60*

16. ICV-6/-130 LRCW - lip Cmpt Cirs 6 04

17. ICV-67-131 ICV-67-133 LRCW - tip Cmpt Cirs 60*

18.

19. ICV-67-134 iRCW - tip Cmpt Clrs 6th

20. fCV-6/-138 ERCW - lip Cmpt Cirs 6tf w

TABif 3.6-2 (Continuett) e CONIAINMFHI li,0LAll0N VALVFS w I!

FUNCIION- MAXIMUM ISOLATION IIME (Seconds) e VALVE NUMBER PilASE "!!" ISOLATION (Cont. )

B.

" .ERCW - Up Cmpt Clrs 60*

21. FCV-67-139 60*

22. FCV-67-141 ERCW'- Up Cmpt'Cirs ERCW - Up Cmpt Clrs 60*

23. FCV-67-142 60*

24. FCV-67-295' ERCW - Up Cmpt Clrs ERCW - Up Cmpt Clrs 60*

25. ICV-67-296 60*

26. FCV-67-297 ERCW - Up Cmpt Clrs

.ERCW - tip Cmpt Clrs 60* -

27. FCV-67-298 60

28. FCV-70-87 RCP Thermal Barrier Ret CCS from RCP Oil Coolers 60

29. FCV-70-89 60 w 30. FCV-70-90 RCP Thermal Barrier Ret ,

CCS~from RCP Oil Coolers 60 D 31. FCV-70-92 m' 32. FCV-70-134 To RCP Thermal Barriers '60 CCS to RCP Oil Coolers- 60

33. FCV-70-140 h

- C. PHASE "A" CONTAINMENT VENT ISOLATION Upper Compt Purge Air Supply 4*

1. FCV-30-7 Upper Compt Purge. Air Supply 4*

2. .FCV-30-8 Upper Compt Purge Air Supply 4*

3. FCV-30-9 Upper Compt' Purge Air Supply 4*

4. FCV-30-10

'4*

.5. FCV-30-14 Lower Compt Purge. Air Supply-Lower Compt Purge Air Supply- 4*.

6. FCV-30-15 4*

7. FCV-30-16 Lower Compt. Purge Air Supply Lower Compt. Purge Air Supply 4*

8. ICV-30-l7 4*

9. FCV-30-19 Inst Room Purge Air Supply lust Room Purge Air Supply 4*

10. FCV-30-20 Lower Compt Pressure Relief 4*

11. FCV-30-37 Lower Compt Pressure Relief 4*

12. FCV-30-40 1

l ABI E 3. 6-2 (Continueil)

S CO.N.TAltiMENI 1501 AT10ri VAI V.LS--

E FUNCTION MAXIMUM ISOLATION TIME (Seconds) i VALVE NUMBER b-4 C. PilASE "A" CONTAINMENT VENT ISOLATION'(Cont.) *

" Upper Compt Purge Air Exh 4*

13. FCV-30-50 4*

14. F CV 51 Upper Compt Purge Air Exh 4*

15. FCV-30-52 Upper Compt Purge Air Exh Upper Coinpt Purge Air Exh 4* .

16. FCV-30-53 4*

17. FCV-30-b6 Lower Compt Purge Air Exh Lower Compt Purge Air Exh 4*

18. FCV-30-57 4* -

19. FCV-30-58 Inst Room Purge Air Exh Inst Room Purge Air Exh 4*

20. FCV-30-59 S*

21. FCV-90-107 Cntmt Bldg LWR Compt Air Hon Cntmt Bldg LWR Compt Air Hon S*

a 22. FCV-90-108 S*

23. FCV-90-109 Cntat Bldy LWR Compt Air Hon

% Cntml Bldg LWR Compt Air Hon ,S*

m- 24. FCV-90-Il0 S*

25. FCV-90-lll Cntat Bldg LWR Compt Air Hon A

" Cntmt Bldg LWR Compt Air Hon S*

26. FCV-90-113 S*

27. FCV-90-Il4 Cntmt Bldg LWR Compt Air Hon Cntmt Bldg LWR Compt Air Hon S*

28. FCV-90-Il5 S*

29. FCV-90-ll6 Cntmt Bldg LWR Compt Air Hon Cntml Bldg LWR Compt Air Hon S*

30. FCV-90-Il7

0. OTifER vacuum Relief Isolation valve 25

1. FCV-30-46 25

2. FCV-30-47 Vacuum Relief Isolation Valve Vacuum Relief Isolation Valve 25

3. FCV-30-48 4 ,

t G

- - . = .

i

i IVA-SQN-IS-46 ,

CHANGE NO. 3 JUSTIFICATION FOR PROPOSED TEGNICAL SPECIFICATION In a telephone conversation with the NRC on February- 17, 1983, we discussed our interpretation of the definition of operability as related to the

~

containment isolation valves. During the telephone conversati~on, the NRC agreed with our interpretation but suggested a submittal of a technical specification change. The valves noted in Tablo.3.6.2 wili not preclude t changes in the operational modes if the valves are secured in their isolated position. This change is needed because L00-3/4.6.3 will not allow the plant to change modes f or startup even though the containment isolation valves are performing their saf ety function. This change should-be allowed because the valves noted in Tabis 3.6.2 will still perform tteir safety function even though secured in the isolated posi tion.

The requested change has been evaluated pursuant to 10 CFR 50.92 and no significant hazards are involved because the. change doos not:

1) Involve an increase in the probability or, consequence s of an' accident previously evalua ted.

The valves will be in the isolated position'. with power removed. The

! operator can restore power to the valves from the vicinity of the control room af ter the initiation signal has been reset. Based on the above facts, the change does not involve an-increase in the probability of an accident previously evaluated. ,

2) Create the possibility of a new or different kind of accident.from any ,, '

accident previously evaluated. s Based on the f act that the valves will perform the saf ety- function by being in the isolated position, no possibility exists f or a new or diff erent kind of accident f rom any ' accident previously evaluated.

I ~

l 3) Involve a reduction in the margin of safety.,

I 1he new requirement will comply with the techni, cal specification base s since the valves as noted in Table 3.6.2 can be closed before an accident. Therefore, the limits assumed in ;the saf ety analyses would not be exceeded. Therefore, the change does not involve a reduction in .

the margin of safety.

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ENCLOSUEE 4

'IVA-SQN-TS-46 SEQUOYAH NUCLEAR PLANT GANGE NO. 4 o

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REVISION OF THE OPERATIONAL LIMITS ASSOCIATED WITH 'IHE ' PRESSURIZER SPRAY N0Z2LE s s i

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IVA-SQN-IS-46 GANGE NO. 4 ,

l SEQUOYAH NUCLEAR PLANT PROPOSED TEGNICAL SPECIFICATIONS 1

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REACTOR COOLANT SYSTEM PRESSURIZER LIMITING CONDITION FOR OPERATION ' '

3.4.9.2 The pressurizer temperature shall be iimited to:

a. A maximum heatup of 100'F in any one hour period,

b. A maximum cooldown of 200*F in any one hour period, and

c. A maximum spray water temperature differential of 560 F.

APPLICABILITY: At all times.

ACTION:

With the pressurizer temperature limits in excess of any of the above limits, restore the temperature to within the limits within 30 minutes; perform an engineering evaluation to determine the effects of the out-of-limit condition on the structural integrity of the pressurizer; determine that the pressurizer remains acceptable for continued operation or be in at least HOT STAND 8Y within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and reduce the pressurizer pressure to less than 500 psig within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.4.9.2.1The pressurizer temperatures shall be determined to be within the limits at least once per 30 minutes during system heatup or cooldown.

4.4.9.2.2 Any occurrence of spray operation with a differential temperature greater than 320 F shall be recorded for evaluation of the cyclic limits in table 5.7.1.

SEQUOYAH - UNIT 1 3/4 4-26

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REACTOR COOLANT SYSTEM PRESSURIZER LIMITING CONDITION FOR OPERATION - -

3.4.9.2 The pressurizer temperature shall be limited to:

a. A maximum heatup of 100*F in any one hour period,

b. A maximum cooldown of 200*F in.any one hour period, and

c. A maximum spray water temperature differential of 560 F.

APPLICABILITY: At all times.

ACTION:

With the pressurizer temperature limits in excess of any of the above limits, restore the temperature to within the limits within 30 minutes; perform an engineering evaluation to determine the effects of the out-of-limit condition on the structural integrity of the pressurizer; determine that the pressurizer remains acceptable for continued operation or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and reduce the pressurizer pressure to less than 500 psig within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS i

4.4.9.2. lThe pressurizer temperatures shall be determined to be within the limits at least once per 30 minutes during system heatup or cooldown.

44.9.2.2 Any occurrence of spray operation with a differential temperature greater than 320 F shall be recorded for evaluation of the cyclic limits in table 5.7.1.

SEQUOYAH - UNIT 2 3/4 4-32 a -, - e . - -_ . - - - - , , a .n- .,, . m ,,- , , . .- .,

TABLE 5.7-1 M

S COMPONENT CYCLIC OR TRANSIENT LIMITS S!

? CYCLIC OR DESIGN CYCLE TRANSIENT LIMIT OR 1RANSIENT 4 c COMPONENT 5

Reactor Coolant System 200 heatup cycles at < 100*F/hr Heatupcgcle-Tavg from < 200 F-

" and 200 cooldown cycles at to > 550 F.

< 100*F/hr. CooTdown cycle - Tavg from

> 550 F to < 200 F.

200 pressurizer cooldown cycles Pressurizer cooldown cycle at < 200 F/hr. temperatures from > 650 F to

< 200 F.

80 loss of load cycles, without > 15% of RATED THERMAL POWER to 4' immediate turbine or reactor trip. D% of RATED TilERMAL POWER.

sn 40 cycles of loss of offsite Loss of offsite A.C. electrical A.C. electrical power. power source supplying the onsite ESF Electrical System.

80 cycles of loss of flow in one Loss of only one reactor reactor coolant loop.i coolant pump.

400 reactor trip cycles. 100% to 0% of RATED TilERMAL POWER.

12 spray actuation Spray water temperature differential I cycles > 320*F and < 560 F.

50 leak tests. Pressurized to 2485 psig.

5 hydrostatic pressure tests. Pressurized to 3105 psig.

Secondary System 5 hydrostatic pressure tests. Pressurized to 1330 psig.

s t

TABLE 5.7-1 m"'

COMPONENT CYCLIC OR TRANSIENT LIMITS is S .

3E CYCLIC OR DESIGN CYCLE i TRANSIENT LIMIT OR 1RANSIENT c: COMPONENT

i lleatupcycle-Tavg from < 200 F

-d Reactor Coolant System 200 heatup cycles at < 100*F/hr -

~~ and 200 cooldown cycles at to > 550 F.

< 100*F/hr. CooTdown cycle - Tavg from

> 550 F to < 200*F.

200 pressurizer cooldown cycles Pressurizer cooldown cycle at < 200*F/hr. temperatures from > 650 F to

< 200*F.

y 80 loss of load cycles, without > IS% of RATED THERMAL POWER to S'

immediate turbine or reactor trip. D% of RATED THERMAL POWER.

sn 40 cycles of loss of offsite loss of offsite A.C. electrical A.C. electrical power. power source supplying the onsite ESF Electrical System.

4 80 cycles of loss of flow in one loss of only one reactor reactor coolant loop.- coolant pump.

i 400 reactor trip cycles. 100% to 0% of RATED TilERMAL POWER.

6 12 soray actuation Spray water temperature differential a

cycles > 320 F and < 560 F.

50 leak tests. Pressurized to 2485 psig.

5 hydrostatic pressure tests. Pressurized to 3105 psig.

Secondary System 5 hydrostatic pressure tests. Pressurized to 1330 psig.

l s

J

1 l

. l TVA-SQN-TS-46 s

CHANGE NO. 4 JUSTIFICATION FOR PROPOSED TECHNICAL SPECIFICATION CHANGE l l

TVA has reviewed the INPO report on the steam generator tube rupture events at Oconee and Ginna (reference 1). One of the operational problems identified in the mitigation of the Ginna tube rupture event was the existence of administrative controls that prohibited the use of auxiliary spray. The administrative controls required that the differential temperature between the spray water and the pressurizer vapor be less than 320 F for auxiliary spray system operation. The basis for this tempera-ture limit was to avoid or limit thermal shock to the spray nozzle.

Sequoyah has a similar administrative limit on spray water differential temperature in order to comply with technical specification 3.4.9.2.c.

We have reviewed the basis for this technical specification, and it appears to be inconsistent with the component cyclic or transient limits specified in table 5.7.1 of the technical specifications and the Sequoyah pressurizer stress reports (references 2, 3, and 4). Normal operation, upset conditions, and test conditions have been analyzed. The spray differential temperature of 3200F is associated with nozzle usage cycles caused by normal operation during plant heatups and cooldowns. A maximum differen-tial temperature of 5600F was used for the upset condition cycles caused by auxiliary spray operation. Table 5.7.1 of the technical specifications recognizes this fact and allows 10 inadvertent spray cycles with a differ-ential temperature greater than 320 F. Actually, 12 cycles with a differential temperature of 560 F were analyzed in the Sequoyah pressurizer stress reports.

Changes to technical specification 3 4.9.2.c and its associated surveillance requirement are proposed to clarify the operational limits on the pressurizer spray nozzle. This will permit operation of the auxiliary -

spray during emerger.cy conditions without violating the technical specifi-cations. The proposed change to specification 3 4.9 2.c recognizes the fact that upper limit on spray differential temperature is 5600F. Sur-veillance requirement 4.4.9.2 has been rewritten to require determination of the spray differential temperature before operation of the auxiliary l

spray system. In addition, the spray differential temperature will be recorded whenever it exc~eds 320 F. This will permit calculation of the actual nozzle usage factce for 0 spray operation cycles with differential I temperature greater than 320 F but less than 560 F. The requirement to check auxiliary spray differential temprature every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months has been deleted because the important consideration for nozzle shock is the differential temperature at the initiation of the spray. The proposed surveillance requirement 4.4.9.2.2 requires this determination.

Changes to table 5.7.1 are proposed to clarify the operational limits on the pressurizer spray nozzle. The 12 cycles of auxiliary spray operation with a differential temperature of 5600F were evaluated in the Sequoyah pressurizer stress reports. Table 5 7.1 has been revised to recognize that up to 12 cycles with differential temperatures of 560 F are allowed.

This change also recognizes that any spray operation above 320 F affects

6 the nozzle in the same manner as auxiliary spray. Spray operation above 320*F but less than 560*F will be counted as a cycle and the operational conditions recorded. Actual nozzle usage f actors will be calculated at a future date to account f or the f act that operation with a lower dif f erential temperature has a lesser eff ect than operation with a higher diff erential temperature. The number of remaining cycles would be revised as a result of these analyses.

The requested change has been evaluated pursuant to 10 CFR 50.92 and no significant hazards . considerations are involved because the change does not:

1) Involve an increase in the probability or consequences of an accident previously evaluated.

Because the proposed changes are bounded by the analyses perf ormed f or the pressurizer spray nozzle and documented in the pressurizer stress report, there is no increase in the probability of an accident previously evaluated.

2) Create the possibility of a new or dif ferent kind of accident f rom any accident previously evaluated.

Because the proposed changes a re bounded by the analyse s perf ormed f or the pressurizer spray nozzle and documented in the pressurizer stress r e por t , there is no possibility of a new or different kind of accident f rom those previously evaluated.

3) Involve a reduction in the margin of saf ety.

Because the change corrects an inconsistency between specification 3.4.9.2 and Table 5.7.1 regarding the operational limits on the pressurizer spray nozzle, the changes does not involve a reduction in the margin of safety.

References

1. Institute of Nuclear Power Operations. ' Analysis of Steam Generator Tube Rupture Events at Oconee and Ginna,' INPO Report INPO 83-030, INPO, Atlanta, Georgia, November 1982.

2. Watson, T. C., '51 Series Fabricated Head Pressurizer Spray Nozzle Analysis,' W1D-SM-74-092, Westinghouse Electric Corporatita, Tampa, Florida, August 1974.

3. Fe r na nde z , R. E. and Flury, R. L., '51 Series Cast Head Pressurizer Spray Nozzle Analysi s ,' WTD-SM-74-047, We stinghouse Electric Corporation Tampa, Florlds, June 1974.

4. Wocht, R. N. . and Bas se t t, J. B. , ' Update of the TVA/ TEN 84 Series Pressurizer Stress Report to E-Spec Addendam-677234 Revision 4,'

WTD-SM-77-005, Westinghouse Electric Corporation, Tampa, Florida, January 1977.

i

ML20077D732

Text

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