ML20151U506
| ML20151U506 | |
| Person / Time | |
|---|---|
| Site: | McGuire, Mcguire  |
| Issue date: | 08/11/1988 |
| From: | Tucker H DUKE POWER CO. |
| To: | NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM) |
| References | |
| TAC-61271, NUDOCS 8808190142 | |
| Download: ML20151U506 (75) | |
Text
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August 11, 1988 I
U.S. Nuclear Regulatory Commission ATTENTION: Document Control Desk i
Washington, DC 20555 i
Subject:
McGuire Nuclear Station, Units 1 and 2 Docket Nos. 50-369 and 50-370 IWP/IW Pump and Valve Inservice Testing Program
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NFC Review / Supplemental Request for Additional Information j
(T.'CS C1271/61272)
Gentlemen I
i The NRC ttaff (with Technical Assistance from a contracted reviewer, EG6G Idaho Inc.) is currently in the process of reviewing the McGuire Nuclear Station 10CFR50.55a(g) Pump and Valve Inservice Testing (IST) Program for the initial 120 month (10 year) inspection interval.
The proposed schedule for i
this review / approval is discussed in my May 6,1988 Unit 1 Revision 10/ Unit 2 Revision 6 program submittal, which indicates that the NRC was to request any additional information needed to complete the review (based on the program as I
submitted through Revision 10/6) by early June 1988, with Duke Power Company's i
response to be submitted prior to an August 1988 DPC/NRC meeting which is to l
be held to finalize the IST Program, j
Accordingly, Mr. D.S. Hood's (NRC/0NRR) June 16, 1988 letter transmitted a set l
of questions / comments (supplemental request for additional information) generated by NRC/EG&G relative to this review.
Note that this is a supplemental request for additional information as two previous requests had been generated by HRC/EG&G which were responded to by Duke submittale dated August 17, 1982 (Unit 1 Rev. 3) and March 31, 1983 (Unit 1 Rev. 4/ Unit 2 Rev.0).
Per NRC request, substantive written responses to the supplemental request for additional information at to be submitted prior to the AuFust meeting in order to minimize the m eting agenda items (any responses not i
submitted prior to the meeting would need to be provided during the meeting -
the purpose of the meeting is to resolve any outstanding review issues and therefore the request for additional information vill be used as an agenda for i
the meeting to the extent that it contains outstanding items).
8808190142 880811 I (
POR ADOCK 05000369 I
P PDC t
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Document Control Desk August 11, 1988 Page 2 i
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Consequently, please find attached Duke Power Company's response to the subject supplemental request for additional information (the P& ids requested by valve testing program questions / comments Nos. L.! and S.3 are enclosed).
In addition to the direct written responses to the questions / comments, the design basis for various valves are provided at the end of the response for r
background and clarification of Duke's position concerning the safety function of those valves (design basis sheets are not provided for all valves discussed in the response as the design study developing these sheets for all safety related valves is still in progress).
Note that the supplemental request for additional iaformation contained various errors which have been identified / corrected in our response, and some questions / comments had been addressed in the recent Rev.
10/6 submittal.
- Also, several of the question / comments had been previously addressed (or are similar/related to those addressed) by the August 17, 1982 submittal (note that the August 17, 1982 submittal just reflected the results of an IST working meeting held March 23-25, 1982 between DPC and EG&G during which previoutly transmitted NRC/EG6G questions / comments were resolved, the actual questions / comments responses are documented in the meeting's minutes).
Cross references (in brackets) to these previous questions / comments (by question / comment number),
along with statements as to the current applicability of the previous responses, are provided in the appropriate responses in the attachment.
Further, several of the questions / comments have been the subjects of various items identified in NRC/01E inspection reports (some are raferenced in the responses).
Note that Valve Testing Program General Questions and Comments Nos. A.2, A.6, and A.13 are being held for discussion at the August 1988 meeting, and certain i
other responses will require further discussion at the meeting (e.g. Valve Testing Program Questions / Comments Nos. A.4 and S.1, and Pump Testing Program Question / Comment No. 3),
In addition, note that the responses to several
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questions / comments will necessitate revisions to the IST Program (i.e Valve Testing Program Questions / Comments Nos.
A.8, A.10, B.1, C.1, D.1, E.1, F.5, K.1, Q.1, S.4, U.3, V.11, and V.13, and Pump Testing Program Question / Comment i
j No. 1).
In accordance with the schedule for review / approval discussed in the May 6, 1988 submittal, another revision to the IST Program is to be submitted to the NRC in early September 1988 incorporating the commitments of the August meeting.
The above listed responses will be reflected in that submittal, as 1
well as any further revisions resulting from the August meeting (in addition j
to the NRC/EG&G questions / comments, Duke Power Company would like to discuss certain diesel generator engine starting air (VG) system check valves relative 9
l to a concern raised in the April 8, 1988 NRC AEOD Diagnostic Evaluation Team Report).
This September 1988 IST Program revision may also involve as planned j
transferal (administrative revision) of the McGuire IST Program to computer, i
1 improving its forma t/ content /maintcoanc e, along with the various other i
advantages having the program of computer would provide (for example, storage j
in the computer database of information not required / desired to be contained j
in an official IST Program printout submitted to/ approved by the NRC).
Duke a
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Document Control Desk August 11, 1988 Page 3 Power Company would like to discuss this transferral at the August meeting in order to establish limits on che scope of the computerized data which will actually appear in the official MNS IU/IW IST Program submittal, and for NRC i
acceptance of the basic computer database which is desired before formal WRC approval of the McGuire IST Program.
Any questions / concerns regarding the attached responses can be addressed et the DPC/NRC August 1988 meeting which has been set for August 16 and 17, 19 t,3 (with August 18th held in reserve in case needed) at McGuire Nuclear Station (Administrative building, Room No. 111), starting at 8:30 AM each day.
This will be a working meeting (no presentations), and appropriate flow diagrams, procedures, etc., will be available for use as needed.
In conclusion, Duke Power Company would like to state i;s belief that the current McGuire Nuclear Station IWPfil?V Inservice Testing Program is essentially sound (especially in view of the fact that approximately 40% of the current questions / comments had previously been resolved as mentioned above, as well as the numerous reviews it has received through the years (e.g.
the two previous NRC/EG6G questions / comments requests and meeting referenced above, various NRC/0IE Inopection Report Reviews, the recent NRC AEOD Diagnostic Evaluation Team Assessment (referenced above),
hternal DPC audits / reviews, etc)), and consequently should not be far from being an NRC approvable program.
Duke Power Company looks forward to receiving NRC approval of the McGuire IST Program by the end of the year in accordance with the proposed schedule outlined in my May ti, 1988 submittal.
Very truly yours.
WA /}
}
Hal B. Tucker 1
PBN/106/ bhp a
i Attachment Enclosures i
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Document Control Desk August 11, 1988 Page 4 xc:
(w/ attachment only)
Dr. J. Nelson Grace l
Regional Administrator U.S. Nuclear Regulatory Commission Region II 101 Marietta Street, NW, Suite 2900 Atlanta, Georgia 30323 Mr. Darl Hood Office of Nuclear Reactor Regulation U.S. Nuclear Regulatory Commission Washington, DC 20555 Mr. W.T. Orders NRC Resident Inspector McGuire Nuclear Station (w/ attachment / enclosures) i Mr. Herb Rockhold Idaho Nations 1 Engineering Laboratory EG&G, Inc.
1520 Sawtelle Street Idaho Falls, Idaho 83401 l
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i DUKE POWER COMPANY RESPONSE TO NRC/EG&G IDAHO, INC'S MCGUIRE NUCLEAR STATION, UNITS 1 AND 2 PUMP AND VALVE INSERVICE TESTING PROGRAM REQUEST FOR ADDITIONAL INFORMATION 1.
VALVE TESTING PROGRAM A.
General Questions and Comments 1.
Provide the documentation that ensures that IWV-3300 is being met (remote position indication verification).
Response: IWV-3300 VALVE POSITION INDICATOR VERIFICATION STATES "Valves with remote postion indicators shall be ob:erved at least once every 2 years to verify that valve operation is accurately indicated."
Presently this surveillance requirement is being complied with using two methods:
1.
The valve position is visually verified at the valve while the remote position indicator is verified to ensure the valve and remote indie.ator positions are synchronized.
This is verified for the open and closed positions.
There is a specific signoff step to verify the position is accurately indicated once every two years.
2.
The remote position indicator is verified by positioning the valve into a valve line-up then observing system operating parameters; i.e., a valve is placed in the open position for a pump flow path and then flow is verified or a valve is closed then leak rate tested.
There is no specific signoff step for this method of verification and the valve may not be checked for both the open and closed positions.
The once every two year verification is met by the fact that these procedures are completed at least once every refueling.
Attached (Attachments 1, 2, and 3) are examples of both methods.
Method 1 is shown in PT/2/A/4252/02, Auxiliary Feedwater Valve Stroke Timing Procedure (Attachment 1) Section 12.2 for valve 2CA9B.
In step 12.2.8 the closed position is visually verified and in 12.2.11.1 the open position is visually verified.
2NV849AC is verified closed during the execution of PT/2/A/4200/
010, the LLRT procedure (Attach-ment 2).
It is verified open during PT/2/A/4209/09, Standby Makeup Pump Check Valve Test (Attachment 3) by passing a required amount of flow through the valve.
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4 2.
The NRC has concluded that the applicable leak test procedures and re-quirements for containment isolation valves are determined by 10CFR50, Appendix J.
Relief from paragraphs IW-3421 through 3425 for containment isolation valves presents no safety problem since the intent of IW-3421 through 3425 is met by Appendix J requirements, however, the licensee shall comply with Paragraphs IW-3425 and 3427.
t Response: This comment is being held for discussion at the' August 1988 Meeting (Note that OM-10 will be doing away with this require-ment).
3.
Provide a listing of all valves that are Appendix J, Type C, leak rate tested which are not included in the IST program and categorized A or AC7 Response: None Note:
Manual vents and drains located between containment isolation valves are used for operating convenience only and are excluded from the IST program.
- However, these valves are currently leak tested as a good i
practice even though leak-age testing is not required by Appendix J.
Paragraph 6.2 of ANSI 56.8-1987 states that, "due to their infrequent use and multiple ii barriers, they do not require leakage rate testing as long as the barrier configurations are main-tained using an administrative control program."
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4.
The NRC staff has ide'itified rapid-acting power operated valves as those which stroke in 2 seconds or less.
Relief may be obtained from the trending requirements of Section XI, Paragraph IW-3417(a), however, in l
1 order to obtain this Code relief the staff does require that the licensee assign a maximum limiting stroke time of 2 seconds to these. valves and 2
comply with the requirements of IW-3417(b) when the ? second limit is exceeded. General Relief Request I does not comply with this staff position.
L Response: General Relief Request I states 1
"TEST REQUIREMENT:
Perform trend analysis on category A and B valves as described in IW-3417(a).
BASIS FOR RELIEF:
Trend analysis performed on rapid acting valves does not gise reliable indication of valve stroke time deterioration.
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TESTING ALTERNATIVE: Trend analysis will not be performed on l
valves that normally operate with cycle time of less than 5 seconds.
Maintenance will be initiated if valve time exceeds max. limit."
Previous discussions between Duke Power Co. and EG&G Idaho f
determined that a 5 second or less maximum stroke time valve does not need to be trended.
At present, McGuire does not have r
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t a maximum time of 5' seconds assigned to these valves.
Approxi-i mately 192 valves (total on both units) consistently stroke in 5 seconds or less. Of these 192, approximately 63 valves con-sistently stroke in 2 seconds or less.
McGuire will assign maximum values of 5 seconds-to appropriate valves.
The 5 second vs. 2 second criteria will need discussion at the August 1988 meeting.
5.
Provide the limiting values of full-stroke times for all power operated valves in the McGuire Nuclear Station, Units 1 and 2, IST programs for our review.
What are the bases used to assign the limiting values of full-stroke time for these valves?
Response: The limiting values for full-stroke time for all power operated valves in the MNS, Unit I and 2 IST submittal are identified in j
the remarks column of the valve table for each system.
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response times for the individual _ valves are set such that each component will complete its required function _in time to permit the system to meet the response time limitations stated in the HNS FSAR. (Note that this question was the subject of d
unresolved item No. 369(370)/87-16-02 in NRC/01E Inspection Report No. 369(370)/87-16).
l 6.
When flow through a check valve is used to indicate a full-stroke exercise of the valve disk, the NRC staff position is that verification of the maximum flow rate identified in any of the plant's safety analyses through the valve would be an adequate demonstration of the full-stroke
- j requirement.
Any flow rate less than this will be considered I
partial-stroke exercising unless it can be shown (by some means su':h as measurement of the differential pressure across the valve), that the i
check valve's disk position at the lower flow rate would permit maximum i
required flow through the valve.
Does the test desigr,ated "MT" satisfy this NRC Staff position?
i Response: This question is being held for the August 1988 meeting.
It j
requires an itemized listing of all check valves identified by l
j the "MT" test and corresponding test flow rate (an itemized list i
4 of each "MT" check valve will of each "MT" check valve will be ready by the meeting).
Verifying that the check valve passes accident flow is considered an adequate demonstration of the IW full-stroke requirement by the NRC.
Any flow rate less than accident flow would be considered a partial-stroke exercise and requires some other full-stroke verification means such as 4
differential pressure measurement.
McGuire will pursue obtaining this information.
Additional relief requests, identifying partial-stroke j
exercising quarterly and full-stroke exercising at refueling i
outages, may be required for those valves not meeting the NRC l
position.
9 7.
Provide the documentation that ensures that IW-3415 is being met j
(fail-safe testing of valves).
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r Response: IW-3415 Fail-Safe Valves States -
"When practical, valves with fail-safe actuators shall be tested by observing the operation of the valves upon loss of actuator power.
If these valves cannot be tested once every 3 months, they shall be tested during each cold shutdown; in case of frequent cold shutdowns, these valves need not be tested more often than once every 3 months."
All failsafe actuators are air actuated. All air actuated f
valves which are stroke timed quarterly or at shutdown are stroked by using the pushbutton which deenergizes the air t
solenoid valves failing air to the valve.
8.
Section XI specifically makes provisions for testing valves during cold shutdowns when it is impractical to exercise these valves quarterly during power operation.
A formal relief request is not required, however, the licensee should include a cold shutdown justification in the IST program.
The cold shutdown justification bases should indicate the negative consequences that make quarterly testing during operation 4
impractical such as endangering personnel, damaging equipment, or resulting in a plant shutdown.
Response: Justification is provided for cold shutdown valves in the form of a relief request.
McGuire will make these justifications in the form of a cold shutdown justification and remove the relief requests from the IW submittal.
Cold shutdown justifications will be included in the respective system sections of the submittal.
These IW program revisions will be included in the
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scheduled (Ref. OPC letter to NRC dated May 6, 1988) September.
l 1988 IST program revision incorporating the commitments of the August 1988 meeting.
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9.
(See response)
Response: There is no question / comment No. 9 (the general questions and l
comments in Section A are misnumbered - this was determined i
through DPC discussions with EG&C).
10.
The valve testing frequency should be indicated in the valve tables.
j Only a portion of the valves in the McGuire IST programs currently have 4
the testir.g frequency identified in the valve tables.
Response: The IW program will be revised appropriately in the scheduled September 1988 IST program revision (Note that a planned new computerized version of the IST program will include a separate column for frequency).
r 11.
Does the fuel pool cooling system perform a safety function at the McGuire Nuclear Station?
If so, the appropriate pumps and valves should be included in the IST programs and tested in accordance with the l
requirements of Section XI to the extent practical.
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Response: The spent fuel pool cooling system is not safety-related and its operability is not required for any accident analyses.
Consequently valves IKF-3 and 24 and the spent fuel pool cooling pumps are not included in the IST program. [8/17/82 HH.1}
- 12. What is the frequency of the testing designated SP in the valve test programs?
Reponse:
Attached (Attachments 4 and 5) are copies of PT/1&2/A/4250/18 (1)&l9(2) which explain McGuire's policy on testing main steam vent to atmosphere (SV) system safety valve SP.
It is a resta-ting of IWV-3510.
Reactor coolant (NC) System safety reliefs are tested one per refueling outage which more than meets the 5 year frequency for testing (Ref. PT/0/A/4150/05, Attachment 6).
13.
The NRC staff position is that valves that serve both a pressure boundary isolation function and a containment isolation function must be leak tested to both the Appendix J and the Section XI requirments.
Identify the valves, if any, at McGuire Nuclear Station that serve both a pressure boundary isolation function and a containment isolation function.
What leak rate testing is performed on these valves?
Response: This comment / question is being held for discussion at the August 1988 meeting (clarifications to certain definitions /
positions are needed).
B.
Annulus Ventilation System 1.
Why.re valves 1(2)IVE-10A identified as passive valvec?
Response: (Note:
The valves listed in the question are incorrectly identified by the prefix "IVE" instead of "VE").
VE-10A is the H2 purge inlet blower discnarge.
It provides a class break and receives a phase A (St) isolation signal.
It is identified as passive in error and will be changed in the scheduled September 1988 IST program revision.
2.
Review the safety function of valves 1(2)IVE-5A and 6B to determine if they should be categorized A.
Response: (Note:
The valves listed in the question are incorrectly identified by the prefix "IVE instead of "VE").
The safety funct. ion of valves 1(2) VESA and GB have been re-viewed.
They should be catergorized B.
This position is unchanged from our previous response dated 8/17/82. [8/17/82 8.2]
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o C.
Auxiliary Feedwater System 1.
Concerning the relief request for valves 1(2)CA-60A, what prevents measuring the stroke time of these valves when they are exercised quarterly? What is the frequency of the stroke timing now being done, i.e., during ESF testing?
Response: CA-60A and all other auxiliary feedwater control valves (CA-64AB, CA-56A, CA-52AB, CA-448, CA-48AB, CA-408 and CA-36AB) are now cycled and timed quarterly.
The relief request will be removed in the scheduled September 1988 IST program revision.
2.
How are the following valves verified to full-stroke exercise quarterly?
1(2)CA-8 1(2)CA-10 1(2)CA-12 1(2)CA-22 1(2)CA-26 1(2)CA-31 Response: Monthly the auxiliary feedwater pumps are tested to ensure they will develop full discharge pressure at full flow per technical specifications.
The pumps are placed on recirc. to the upper surge tank.
Full flow is passed thru these valves which constitutes a full stroke exercise.
3.
What is the current frequency of the stroke timing for valves 1(2)CA-20AB?
Response: CA-20AB is timed quarterly and during Engineered Safety Features testing.
[8/17/82 C.8) 4.
What is the safety grade water source for the AFW pumps? Review the safety function of the following valves to determine if they should be included in the IST program and tested to Section XI requirements:
Valve P&ID Valve P&ID 1(2)CA-3 1(2)592-1.1 1(2)CA-4 1(2)S92-1,1 1(2)CA-5 1(2)S92-1.1 1(2)CA-6 1(2)592-1.1 1(2)CA-5 1(2)S92-1.1 Response: (Note:
Valves 1(2)CA-151 were intended to be listed in this 1
question instead of the redundant listing for valves 1(2)CA this was determined through OPC discussions with EG> l
The safety grade water source for the AFW pumps is the Nuclear Service Water (RN) System through valves 1(2) CA15A, 86A, 165 l
and 1(2) RN69A for Train "A", 1(2) CA18B and 1(2) RN162B for Train "B" and 1(2) CA165, 86A and 1(2) RN69A or 1(2) CA1168, 166 and 1(2) RN162B for T/0 AFW pump.
These valves are all being exercise tested to Section XI requirements.
i The safety function of valves 1(2) CA3, 4, 5, 6 and 151 have been reviewed.
These valves do not provide a safety function, i
thir. position is unchanged from our previous response dated 8/17/82.
[8/17/82 C.9]
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D.
Boron Recycle System 1.
If the only practical method of verifying valve closure is leak rate test-ing, then closure verification can be demonstrated each refueling out&ge.
However, it must be done o ch refueling outage irrespective of the Appen-dix J required frequency.
Does the testing fre quency for valves 1(2)NB
-262 conform to this position?
Response: Yes, McGuire will clarify wording on relief request.
Alternate testing will be changed to indicate every refueling, as indicated on the valve table portion of the submittal.
These IW program revisions will be included in the scheduled September 1988 IST program revision.
[8/17/82 0.1]
E.
Breathi,o Air System 1.
If the only practical method of verifying valve closure is leak rate testing, then closure verification can be demonstrated each refueling outage.
However, it must be done each refueling outage irrespective of the Appendix J required frequency.
Does the testing frequency for valves 1(2)VB-50 conform to this position?
Response: Yes, McGuire will clarify wording on relief request. Alternate testing will be changed to indicate every refueling, as indicated on the valve table in the subm.ttal.
These IW program revisions will be included in the scheduled September 1988 IST program revision.
[8/17/82 E.1]
F.
Chemical and Volume Control System 1.
Are Valves 1(2)NV-94AC and 958 ever required to perform a containment isolation function?
Response: Valves 1(2) NV94AC and 958 are required to perform a containment iso!ation function.
These valves should be Categorized B and are exempt from Appendix J Type C leak testing per the NRC Standard Review Plan (SRP) concerning Secondary Containment functional Design and NRC Branch Technical Position (BTP) CSB 6-3.
This position is unchanged from our previous response dated 8/17/82. [8/37/82 F.4]
2.
Review the safety function of valves 1(2)NV-78, 457A, 458A, and 459A to determine if they should be Categorized A.
Response: Valves 1(2) NV78, 457A, 458A and 459A are required to perform a containment isolation function.
Thses valves should be Categorized B and exempt from Appendix J Type C leak testing per the NRC SRP and NRC BTP CSB 6-3.
This position is unchanged from our previous response dated 8/17/82. [8/17/82 F 7].
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Do valves 1(2)NV-12 perform a safety function in the closed position?
Response: Valves 1(2) NV12 are required to perform a containment isolation function.
These valves should be Cate00rized B and exempt from
- i Appendfx J Type C leak testing per the NRC SRP and NRC BTP CSB i
6-3.
This same question was documented as an open item from our previous response dated 8/17/82.
[8/17/82 F.8) 4.
How will full-stroke exercising valves 1(2)NV-225 and 231 quarterly result in an increase in RCS boron inventory?
Reponse:
To fully stroke valves NV-225 and NV-231 the full centrifugal 3
charging pump flow of approximately 550 gpm would have to go thru the valves. The maximum reactor coolant system letdown is j
approximately 200 gpm thru the letdown orifices.
To maintain volume control tank level, the additional flow would have to 6
come from the refueling water storage tank which has a boron concentration of 2000 ppm.
[8/17/82 F.23]
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5.
Review the safety function of the following valves to determine if they q
should be included in the IST program and tested to Section XI j
requirements:
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Valve P&ID Valve P&ID 1(2)NV-45 1(2)S54-1.0 1(2)NV-29 1(2)554-1.0 i
1(2)NV-77 1(2)554-1.1 1(2)NV-61 1(2)554-1.1 l
1(2)NV-14 1(2)554-1.2 1(2)NV-15 1(2)554-1.2 l
1(2)NV-20 1(2)554-1.2 1(2)NV-841 1(2)S54-1.2 1(2)NV-218 1(2)554-3.0 1(2)NV-241 1(2)S54-3.0
)
2NV-1044 2554-3,0 2NV-1046 2554-3.O 1(2)NV-264 1(2)554-3.1 1(2)NV-472 1(2)554-3.1
)
i 1(2)NV-267A 1(2)554-3.1 1(2)NV-2658 1(2)554-3.1 1(2)NV-411 1(2)S54-5.0 1(2)NV-413 1(2)554-5.0 4
Response
Valves 1(2) NV29, 45, 61 and 77 are required to perform a containment isolation function.
These valves should be Categori::ed C and are exempt from Appendix J Type C leak testing per the NRC SRP and NRC BTP CSB 6-3.
This position is unchanged from our response d6ted 8/17/82.
1 Valves 1(2) NV14 and 15 are RCS pressure boundary valves.
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These valves are Categorized C and are exempt from leak testing per written acknowledgment by NRC (ref. DPC to NRC/0NRR letter dated November 24, 1980, and McGuire Nuclear Station units 1 and 2 safety evaluation report (NUREG-0422) supp, no. 5 section 3.9.3).
Valves 1(2) NV 20 do not perform a safety function.
These valves are Categorized C.
This position is unchanged from our previous response dated 8/17/82.
Valves 1(2) NV841 are containment isolation valves located on passive penetrations.
Since these valves do not perform a i
safety function, they are exempt from Type C leak testing, This position is unchanged from our previous response dated a
8/17/82.
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Valves 1(2) NV218 are required to prevent gross flow diversion; however, because of their location on the discharga of the Positive Displacement Charging Pumps it is our position that gross flow through those pumps would be near impossible and these valves do not require backseat testing, Valves 1(2) NV241 do not perform a safety function. This position is unchanged from our previous response dated 8/17/82.
1 Valves 2NV1044 and 1046 do r.ot perform a safety function.
l These valves were previously tagged 2NI233 and 235 but were recently changed per a Nuclear Station Modification.
These l
valves are required for reliability only, i
l Valves 1(2) NV264, 472, 267A and 2658 are required per BTP RSB l
5-1 for shutting down the reactor and will be added to our IW program in the scheduled Septerr.ber 1988 IST program revision.
This position is different from our previous response dated
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8/17/82.
Valves 1(2) NV411 and 413 are required per NRC BTP RSB 5-1 for shutting do.in the reactor and will be added to our IW program in the scheduled September 1988 IST program revision.
[8/17/82 l
F.2, F.7, F.8, F.9, F.15, F.19, F.20)
G.
Component Cooling System 1.
Do valves 1(2)KC-5, 8, 11, and 14 perform a safety function in the open l
and closed positions? If so, the valves must be exercised to both positions.
Response: Valves 1(2) KC5, 8, 11 and 14 perform a safety function in the i
open position only.
This position is unchanged from our previous response dated 8/17/82.
[8/17/82 H.1) l 2.
Review the safety function of valves 1(2)KC-972 [P&lD 1(2)S73-1.1) to I
determine if they should be included in the IST program and tested to Section XI requirements, l
l Response: Valves 1(2) KC972 cre required for overpressure protection en the KC Surge Tank.
Since these valves are not directly required for shutting down a reactor in mitigating the l
consequences of an accident +.hese valves will not be added to l
our IW program but will be included in our relief valve test I
program.
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3.
Review the safety function of valves 1(2)KC-3158, and 305B to determine i
if they should be categorized A.
Response: Valves 1(2) KC3158 and 305B perform a containment isolation function.
These valves are Categorized B and exempt from Appendix J Type C testing.
This position is unchanged from our previous response dated 8/17/82.
[8/17/82 H.8)
H.
Containment Air Release and Addition System 1.
Clarify the testing being performed on valves 1(2)QV-1A, 2B, 58, and 6A.
Response: (Note:
The valves listed in the question are incorrectly identified by the orefix "QV" of "VQ").
VQ-1A, 2B, 5B and 6A are leak tested every refueling outage in accordance with 10CFR50 appendix J.
The valves are stroke timed quarterly.
I.
Containment Purge Ventilation 1.
Clarify the proposed alternate testing in the relief request for all containment purge ventilation category A valves.
The stroke time of all power operated valve must be measured every time the valve is full-stroke 1
exercised as required in Section XI, paragraph IW-3413(b).
1 j
Response: All VP category A valves a e administrative 1y maintained closed i
4 in modes 1-4 when containtennt integrity is required.
They are j
leak tested quarterly as rq uired by technical specifications.
4 j
The valves are not timed be.cause the 3 seconds system requirement to close is not required.
l I
No trending is done on these valves.
Prior to the system being placed in service as required for refueling operations, the valves will be opened.
At this time any valve manipulations may be done manually if required.
If the valves are ever required to be operated in modes 1-4, they will be tested to ensure they will close in the 3 seconds required.
Technical I
)
specifications limit the amount of time the valves may be opened. At present, there is no intention of ever opening these valves in modes 1-4.
I I
J.
Containment Spray System 1.
The NRC Staff position is that check valves must be full-stroke exercised.
If Code required frequency is impractical, then the licensee must request relief to perform the testing at a lesser frequency.
- However, relief requests seeking exemption for never full-stroke exercising check valves will not be granted.
The relief request for the following valves I
i will be affected by this staff position:
i 10 1
1(2)NS-13 1(2)NS-16 1(2)NS-30 1(2)NS-33 1(2)NS-41 1(2)NS-#6 Response: There is no practical method of full stroke exercising these l
valves.
They are located in the containment dome just out of l
reach of a scissor type crane which sits atop of the pclar crane. Disassembly is a personnel hazard.
A full flow test is impractical because of the massive cleanup effort which would be required.
[8/17/82 J.2) 2.
Review the safety function of the following valves to determine if they should be categorized A:
1(2)NS-128 1(2)NS-158 1(2)NS-29A 1(2)MS-32A 1(2)NS-388 1(2)NS-43A Response: Valves 1(2) NS1288, ISB, 29A, 32A, 388 and 43A are required to perform a containment isolation function.
These valves are Categorized B and are exempt from Type C leak testing per the NRC SRP and NRC BTP CSB 6-3.
This position is unchanged from our previous response dated 8/17/82. [8/17/82 J.1) f K.
Diesel Generator Room Sump Pump System 1.
Do valves 1(2)WN-3, 5, 11, and 13 perform a safety function in the closed position?
l i
Response: Valves 1(2) WN3, 5, 11 and 13 are required to perform a safety function in the closed position.
In addition, on movement test, these valves will require backseat testing.
This change will be incorporated in our IW program in the scheduled September 1988 IST program revisioti.
7 L.
Diesel Generator Startino Air System I
1.
Provide P& ids MC-1609-4.0 and 2609-4.0 for our review.
Respor.se: The requested P& ids are enclosed.
M.
Equipment Decontamination System 1.
What type of valve is 2WE-23? Is the AC categorization for this valve correct?
Response: No. 2WE-23 is a pack!ess stem valve.
The AC categorization is incorrect and was changed to category A in the May 6,1988 unit I revision 10/ unit 2 revision 6 IST program submittal. [8/17/82 S.1) i 11 1
4 N.
Liquid Waste, Recycle System 1.
Review the safety function of valve 1NI-266A to determine if it should be categorized A.
Response: (Note:
Per OPC discussions with EG&G it was determined that this question regarding a safety injection (NI) system valve was inadvertently located under the liquid waste recycle system questions section (N) rather than the safety injection system l
questions section-(V)).
1 r
Valve IN!266A has been deleted by a Nuclear Station l
Modification (NSM) and was removed from our IW program (ttis
~
applies for Unit 2 also-ref, the May 6, 1988 unit I revision 10hnit 2 revision 6 IST program submittal); Note however that J
valves 1(2) NI 263,-2648, 265 and 267A have been re-tagged per a different NSM for use as containment isolation valves 1(2)
WL1306, 13018, 1307 and 1302A, respectively, Valves 1(2) i WL1301B and 1302A are Categorized A and were added tc our IWV program in revision 10 for linit 1 and revision 6 for Unit 2.
They will require Appendix J Type C testing.
0.
Main Steam Supply to Auxiliary Equipment 1.
How are valves 1(2)SA-5 and 6 verified te full-stroke open quarterly?
i l
Response: PT/1&2/A/4252/01, AFP #1/#2 Performance test which is performed monthly (ref, attachments 7 and 8).
P.
Main Steam Vent to Atmosphere l
1.
Review the safety function of the following valves to determine if they should be included in the IST program and tested to Section XI i
requirements:
l Valve P&ID Valve P&l0 i
1(2)SV-25 1(2)593-1.3 1(2)$V 26 1(2)554-1.3 1(2)SV-27 1(2}593-1.0 1(2)SV-28 1(2)593-1.0 i
l I
Response: Valves 1(2) SV25, 26, 27 and 28 do not perform a safety l
function, are not active and do not receive emergency 1E d
t
]
power.
These valves will not be added to our IW program.
j Q.
Nuclear Sampling i
1.
What type of valves are 1(2)NM-420 and 421?
Should these valves be catergorized AC?
I 12
Response: 1&2NM-420&421 are pressure equalization check valves, and should be categorized AC.
This change will be incorporated into our IW program in the scheduled September 1988 IST program revision.
R.
Nuclear Service Waeer Svstem 1.
Do valves 1(2)RN-2A and 30 perform a safety function in both the open and closed positions? If so, both positions must be verified during va!ve testing.
Response: Valve 1(2) RN28 and 30 perform a safety function in the open position only.
[8/17/82 AA 3]
l 2.
Valves 2RN-418 and 2RN-43A are listed in both Unit 1 and Unit 2 valve tables.
Is this correct?
I Response: Valves 2RN-410 and 43A are Unit ? valves; however, they will remain in unit l's IST program since they receive a unit I safety signal to shut.
This position is une. hanged from our previous responso dated 8/17/82.
[8/17/82 AA.4) 5.
The NRC Staff position is that the PORVs should be exercised during cold shutdown or prior to establishing conditions where the PORVs are utilized for low temperature overpressure protection.
The relief request for the PORVs will be affected by this Staff position.
Response: Please provide clarification of what chaages are needed.
Duke does not perceive that a change is needed.
j 2.
What is the full stroke test frequency for valycs 1(2)NC-27C and 29C?
Response: 1&2NC-27C & 29C arc not full stroke tested because no indication of position exists.
Partial stroking is verified by observing system changes when the demand positioner is changed.
3.
Provide P&IO MC-1553-2,1 for our review.
Response: The requested P&ID is enclosed.
4.
Arc valves 1(2)NC-141 and 142 passive valves?
Response: Yes, this will be reflected in the scheduled September 1988 IST j
program revision.
l l
13 i
O i
b P
T.
Refuelina Water System i
1.
Provide a detailed technical justification for not full-stroke exercising i
valves 1(2)FW-28 during cold shutdowns.
Response: During cold shutdown the expansion volume does eqi exist in the-l RCS to accomodate the flow required to-full stroke these check valves.
This position is unchanged from our previous response I
dated 8/17/82. [8/17/82 CC.4]
2.
Why are valves 1(2)FW-52 designated passive while all other stali check-l valvet that perform a thermal relief function are not?
i Response: (Note:
Based on DPC discussions with EG&G it was determined f
that valves IFW-67 and 2FW-63 ( M G that these corresponding-Units 1 and 2 valves do not ha w 8 % same number) should be listed in question T.2 instead +
t et ves 1(2)FW-52).
l IFW-67 and 2FW-63 are thermal relief check valves in a passive containment penetration.
The-other isolation valves in the penetration are 1(2)FW-11 and 1(2)FW-13 which are listed as j
passive.
Valves IFW-67 and 2FW-63 are categorized f.C parsive 3
and closure verified via the leak test performed during e' l
fueling outages.
This position is anchanged from our prt w in l
response dated 8/17/82.
[8/17/82 CC.S]
l l
U.
Residual Heat Removal System 1.
What type of leck testing is performed on valves 1(2)ND-1B and 2AC7 Do these valves perform both a pressure isolation function and a containment i
isolation function? See general comment A.13.
1 i
Response: Valves 1(2) ND1B and 2A0 perform both a RCS pressure isolation l
l and a containment isolation function.
These valves are Categorized A and receive backseat testing (are leak tested by l
PT/1&2/A/4200/088, NC Pressure Isolation Valve Leak Rate Test)
{
l but are exempt from Apoendix J Type C testing per the NRC SRP t
l and NRC BTP CSB 6-3.
2.
Provide a detailed technical justification for not full-stroke exercising valves 1(2)ND-8 and 23 during cold shutdowns, Response: Full flow per FSAR is 4096 gpm during cold leg injection.
This j
can only be simulated with the head off.
[8/17/82 00.3]
i 3.
Provide a more detailed technical justification for not full-stroke j
exercising valves 1(2)ND-70 quarterly and during cold shutdowns.
1 1
l l
14
Response: 1&2'ND 70 & 71 provide suction to the NI pumps.
1&2ND 70 also provides suction to the NV pumps.
To full stroke these. valves the NI pumps need to discharge to the RCS.
This would cycle pressure boundary check valves which would need to be reseated and leak checked.
Tech Spec 4.4.6.2.2.b requires pressure boundary valve leakage testing when the-unit-has been in cold shutdown for more than 72 hrs., and if more than 9 months has passed sinne the last test.
TS 4.4.6.2.2.d. requires testing after cycling of a pressure boundary valve.- - To prevent unneeded wear on the seating surface of the pressure boundary valves 1&2ND70 will be tested every 9 months during cold shutdown of at least 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> length.
This will also be the policy for any other check valve which requires the cycling of a RCS pressure boundary valve.
These IWV program revisions will be included in the scheduled September 1988 IST program revision.
[8/17/88 1
00.4]
4.
Why must both trains of the residual heat removal system be removed froi:
service to test the 1(2)ND-58A valves?
Response: In order to cycle 1&2ND58A interlocks.which control the suction of the ND pumps have to be jumpered to simulate suction frog, the sump.
[8/17/82 00.5]
V.
Safety Injection System 1.
Review the safety function of valves 1(2)NI-12 to determine if they should be categorized AC.
Response: Valves 1(2) NI12 perform a containment isolation fuction.
These valves are Categorized C and ere exempt from Appendix J Type C testing per the NRC SRP and NRC BTP CSB 6-3.
This position is unchanged from our response dated 8/17/82.
[8/17/82 EE.2]
2.
Review the safety function of valves 1(2)NI-11 [P&ID 1(2)S62-1.0] to determine if they should be included in the IST program and tested to Section XI requirements.
Response: Valves 1(2) Nill are passive and do not perform a safety function.
This position is unchanged from our response dated 8/17/82.
[8/17/82 EE.4]
3.
How are valves 1(2)NI-59, 70, 81, and 93 verified to full-stroke open i
during refueling outages?
)
i l
15
Response: Current practice is to open the cold leg accumulator (CLA) discharge block valves with the CLA pressure 70-100 psi greater than the NC system, using procedure PT/1&2/A/4206/09, NI check valve movement test.
4.
How are valves 1(2)NI-60, 71, 82, and 94 verified to full stroke open during cold shutdowns?
Response: Current practice is to put 3000 gpm of flow through 2 at a L
time, per procedures PT/1&2/A/4206/10, Residual Heat Removal Injection Test (ref. attachments 9 and 10).
[8/17/82 EE.6]
5.
Review the safety function of valves 1(2)NI-121A and 1528 to determine if they should be categorized A.
Response: Valves 1(2) NI121A and 152B are containment isolation valves which do not perform an automatic function. These valves are Categorized B and are exempt from Appendix J Type C testing per l
the NRC SRP and NRC BTP CSB 6-3.
This position is unchanged from our previous response dated 8/17/82.
[8/17/82 EE.14]
6.
What is the safety function of valves 1(2)NI-122B?
Response: Valves 1(2) NI1228 are passive and do not perform a safety-function.
This was an open item from our 3/82 meeting with EG&G.
Since that time, we have concluded per consultation with
)
Westinghouse that this should not be an automatic containment j
isolation valve.
Tech Spec char ies (ref. MNS facility operating license amendment nos. 63(unit 1)/44(unit 2)) have deleted these valves as Engineered Safety Features (ESF).
Therefore, these valves no longer receive a Phase A isolation signal.
[8/17/82 EE.15]
)
1 7.
Describe the procedure used to full-stroke exercise the following valves during refueling outages:
1(2)NI-124 1(2)NI-128 1(2)NI-156 1(2)NI-157 1(2)NI-159 1(2)NI-160 j
Response: Current practice is to discharge the NI pumps through each set and verify a flow > 613 gpm.
j 8.
How are valves 1(2)NI-125, 126, 129, and 134 verified to full-stroke during cold shutdowns.
Response: Current practice is to put 3000 gpm through all four per PT/1&2/A/4206/10, ND injection test.
(ref. attachments 9 and 10).
9.
Review the safety function of the following valves to determine if they should be categorized A:
lti
1(2)NI-162A 1(2)NI-173A 1(2)NI-1788 1(2)NI-1848 1(2)NI-185A Response: Valves 1(2) NI162A', 173A and 1788 are containment isolation valves which do r.ot perform an automatic isolation fucntion.
These valves are Categorized B and are exempt from Appendix J Type C testing per the NRC SRP and NRC BTP.CSB 6-3.
This position is ur. hanged from our-previous response dated 8/17/82.
Valves 1(2) NI1848 and 185A are containment sump recirculation isolation valves which do not perform an automatic isolation function.
These valves are Categorized B and are exempt from Appendix J Type C testing per the NRC SRP and NRC BTP CSB 6-3.
This position is unchanged from our previous response dated 8/17/82.
[8/17/82 EE.20, EE.22, EE.23]
10.
Review the safety function of the following valves to determine if they should be included in the IST program as category A valves and tested to Section XI requirements:
Valve P&ID 1(2)NI-163 1(2)562-3.1 1(2)NI-174 1(2)S62-3.1 1(2)NI-179 1(2)562-3.1 Response: Valves 1(2) NI163, 174 and 179 do not perform a safety function.
These valves are not included in our IWV program.
This position is unchanged from our previous response dated 8/17/82.
(8/17/82 EE.24]
11.
Describe how the interlocks mentioned in the relief request for valves 1(2)NI-1848 and 185A preclude valve operation.
Response: These interlocks no longer prevent valve movement'as they once did.
However to cycle these valves at power to prevent discharging the contents of the FWST, FW 27 would have to be closed.
This would render both trains of ND inoperable.
Therefore the stroking of NI-184B & 185A must be done during cold shutdown when FW27 can be closed.
This will be reflected in the scheduled September 1988 IST program revision.
)
12.
How are valves 1(2)NI-175, 176, 180, and 181 full-stroke exercised during i
cold shutdowns.?
i Response: Current practice is to put 3000 gpm af flow through 2 at a time, per procedures PT/1&2/A/4206/10, Residual Heat Removal Injection Test (Ref, attachments 9 and 10).
[8/17/82 EE.21]
17
13.
The NRC Branch Technical Position, RSB 5-1, establishes requirements for taking reactor plants from power opeation to cold shutdowns using only safety grade equipment.
To comply with this position, credit is normally taken for the safety injection accumulator vent paths and/or the acumulator motor operated isolation valves.
Evaluate the safety function of the following valves to determine if.they should be included in the IST program and tested to the Code requirements:
Valve P&ID Valve P&ID 1(2)NI-50 1(2)S62-2.0 1(2)NI-54A 1(2)562-2.0 1(2)NI-61 1(2)562-2.0 1(2)NI-65B 1(2)562-2.0 1(2)NI-72 1(2)S62-2.1 1(2)NI-76A 1(2)S62-2.1 1(2)NI-83 1(2)562-2.1 1(2)NI-84 1(2)562-2.1 1(2)NI-88B 1(2)S62-2.1 Response: In compliance with BTP, RSB 5-1, no credit was taken for remote manual operation of either the CLA vent valves or the CLA discharge isolation valves.
Credit was taken for local manual operation of valves at hot standby and during cooldown if necessary to achieve cold shutdown.
Valves 1(2) NI5O, 61, 72, 83 and 84 do not perform a safety function and will not be included in our IW program.
However, valves 1(2) NI54A, 658, 76A and 88A do perform a l
safety function.
These valves are Categorized B and will require exercise testing and will be added to our IW program in the scheduled September 1988 IST program revision.
[8/17/82 EE.5]
14.
Review the safety function of the following' valves to determine if they should be included in the IST program and tested to Section XI requirements:
Valve P&IO Valve P&ID 1(2)NI-242B 1(2)S62-4.0 1(2)NI-243A 1(2)562-4.0 1(2)NI-2448 1(2)S62-4.0 1(2)NI-245A 1(2)562-4.0 4
1NI-266A 1562-4.0 Response: Valves 1(2) NI2428, 243A, 2448, 245A and 266A have been deleted by a Nuclear Station Modification (NSM), and are no longer in i
the IW program (ref. the May 6,1988 Unit 1 revision 10/ unit 2 revision 6 IST program submittal).
15.
What type of the valves are the following:
1NI-248 1NI-249 1NI-250 INI-251 INI-252 INI-253 18
Response: Valves 1(2) NI248, 249, 250, 251, 252 and 253 were Upper Head Injection System check valves and were deteted by the NSM mentiuned in question V.14 (ref. the May 6, 1988 unit 1 revision 6 IST program submittal).
2.
PUMP TESTING PROGRAM 1.
The deviations from the Code requirements discussed in Item I.A and B, page I.1-1, have not been indicated on the pump table.
Response: The deviations will be added to the pump table in the scheduled September 1988 IST program revision.
2.
Section XI requires that both flow and differential pressure be measured during the performance of pump testing.
i.e., all quantities required by Table IWP-3100-1 should be recorded and that lack of installed instrumentation is not a suitable long term justification for not performing the required Section XI testing.
Item I.C does not agree with this Staff position.
i Response: 10CFR50.55a governs design requirements for Inservice Inspection and Testing.
Paragraph (g) (4) states:
"Throughout the service life of a boiling or pressurized water-cooled nuclear power facility, components (including supports) which are classified as ASME Code Class 1, Class 2 and Class 3 shall meet the requirements, except design i
and access provisions and preservice examination require-ments set forth in Section XI of the ASME B&PV Code and Addenda... incorporated by reference in paragrcph (b) of this section, to the extent practical within the limita-tions of desian, geometry and materials of construction of the components.,"
An excerpt from, "Part 50 - Statements of Consideration",
(41FR6256, effective 3/15/76) defines the design requirements of paragraph (b) as follows:
"To eliminate the misconception that the design of compo-nents needs to be continually modified and to provide a consistency between the design requirements for inspectability and the design requirements for construction, the provision on design requirements for inspectability of components has been changed to refer to i
the same code edition which is applied to the construction of such components."
The Safety Injection (NI) and the Residual Heat Removal (ND) pumps were constructed in accordance with the Summer 1973 Addenda of Section XI.
This edition specifies that in fixed resistance systems that either differential pressure or flow rate is to be measured, not both.
Since the inspectability 19
requirements of the Summer 1973 Addenda are satisfied for both the NI and the ND pumps, design modifications are not required to add flow instrumentation in order to meet the present section XI code requirements.
3.
Has McGuire Nuclear Station attempted to procure portable vibration instrumentation that meets the accuracy requirements of Section XI?
Response: Investigation into a meter and probe that would give an accuracy range of 5% is in progress now.
Information is being supplied from our Standards Lab on a vendor that can potentially satisfy this requirement.
4.
Is the pump vibration monitoring program conducted utilizing units of vibration displacement or vibration velocity?
Response Displacement.
5.
Relief may be granted from the requirements of Section XI to measure pump bearing temperature annually, however, specific relief must be requested describing the difficulties encountered in each case.
These relief requests will then be reviewed on a case by case basis.
Item I.E. does not agree with this Staff position.
Response: The relief request from the annual bearing temperature requirements described by item I.E. applies to all pumps listed in the IST program.
The yearly measurement of bearing temperature for these pumps does not provide meaningful information for detecting bearing failure.
Several factors such as the temperature of the working fluid, the ambient temperature, the lubricant temperature and the size of the bearing housing will mask any bearing condition change short of a catastrophic bearing failure.
The small probability of detecting bearing failure by temperature measurement does not justify the additional pump i
operating time required to make the measurement.
The quarterly pump bearing vibration displacement measurement required by IWP provides a more reliable indication of pump bearing condition thar, annual temperature measurements.
The i
vibration measurement is not substantially affected by outside
{
influences which can mask the true bearing performance.
6.
Is the flow rate of the diesel generator fuel oil transfer pumps determined while the diesel engine is running?
Response: No, the diesel engine is not running.
Flow is determined by timing the level rise in the day tank and running the diesel engine would be removing unmeasurable fuel oil from the day tank.
20
7.
In'those cases where' instrumentation is not installed to permit monitoring pump performance, individual specific relief must,be requested.
This requirement will affect the pump test program'for the-diesel fuel oil transfer pumps, diesel generator room sump. pumps, and the standby makeup pumps.
Response: McGuire presently has relief requests for each of these pumps.
i 21 r
4,
A rracusrur PT/2/A/4252/02
-0 Pags 5 of g M ", N ik i
Initial /Date 12.2 Valve Stroke Timing for 2CA9B - Aux. FDW Pump 2B Suction Isol.
NOTE:
If valve is administratively controlled in its safety position, then N/A Steps 12.2.1 through 12.2.17.2 and verify Step 12.2.18.
/
12.2.1 Record previous valve stroke time: PVST =
/
12.2.2 Record the date of the last remote position indicator verification. Date 12.2.3 Read the limits and precautions listed below.
/
12.2.3.1 None
/
12.2.4 There is no required unit status.
Record Oper. Mode 12.2.5 Verify the Prerequisite System Conditions listed below.
/
12.2.5.1 CA Pump 2B is not in operation.
/____
12.2.6 Record valve AS FOUND position:
/
12.2.7 If required, place 2CA9B in its INITIAL POSITION: CIOSED
/
IV
_ _ _,\\,
12:7.8^
If it has been greater than 21 months since the last
/-
verification, visually verify that the valve is CLOSED and the OAC and Remote Indicator indicates CLOSED.
Control Room Remote Indicator Aux. Panel TD CA Pump Remote Indicator l
6 Aux. Panel CA Pump B Remote Indicator
/
12.2.9~
SetupforvalvetimingbyusingaPortableValv'eSti'"kE' Timer
~
~*
o (stopwatch).
12.2.9.1 For Portable Valve Stroke Timer record Inst.
j No.
Cal. Due Date
/
12.2.10 Start the Portable Valve Stroke Timer as the Operator presses
/
IV the OPEN button of 2CA9B.
/
12.2.11 Stop the Portable Valve Stroke Timer when the valve indicates OPEN.
/
~ ~ ~~"""'~1'272;11.1 If required, visually verify that the valve is OPEN and the f311owing Remote Indicator indicate OPEN.
Control Room Remote Indicator j
Aux. Panel TD CA Pmp Remote Indicator j
Aux Panel CA Pump B Remote Indicator
i PT/2/A/4252/02 (L,tt4 Pags 6 of () M g
Initial /Date
____/
12.2.12 Record the valve stroke time: VST
/
12.2.13 If required, return the valve to the AS FOUND position in
/
IV Step 12.2.6.
12.2.14 Restoration Action
/
12.2.14.1 None
/
12.2.15 Verify the valve stroke time is less than or equal to the REQUIRED VALVE STROKE TIME:
10 seconds.
If not, record the corrective action work request number THE VALVE SHALL BE DECLARED INOPERABLE.
/____
12.2.16 Calculate the percent change in valve stroke time:
(VST - PVST)/PVST x 100 =
NOTE:
If VST and PVST are less than 5 seconds, N/A the following steps.
/
12.2.17 Verify that there is no increase of 50% or more.
If so, do the following:
/
12.2.17.1 Notify the Performance Test Supervisor to increase
/
Tst. Super.
surveillance to once a month.
/
12.2.17.2 Notify the Performance Staff Ec.gineer with IWV
/
Staff Eng, responsibility.
/
12.2.18 If applicable, verify valve is in PT/2/A/4203/01 (Performance Special Valve Controlling Procedure) so that Acceptance Criteria 11.2 is cet.
J Data Recorded By Date NOTES:
Amewe<sur s ENCLOSURI 13.1 PT/2/A/4200/01C PENF.TRATION DATA SHEET Pag 2 50 of 93 PAGE 1 0F 2 Section 12.1 Penetration: M342 Location: 734' 231*
MC-2554-1.3 Valve Test Direction Relative to Cont. Press.
2NV1002 NORMAL 2NV100L..
REVERSE 2E 849A,C " '}
FORMAL w.
Saction 12.2 Prerequisite Conditions:
/
12.2.1 Verify applicable penetration valve checklist has been aligned and logged in the applicable OP R&R.
/
12.2.2 Standby Makeup Pump to NC Pump Seals may be isolated.
Section 12.4.
Flowmeter #
Cal. Due Date Pressure gauge &
Cal. Due Date Section 12.5 Valve Test Position NJ N/A Vent 2NV1011 (RX Building; pipe chase near cont. wall)
Valve (s):
Leak Rate
+ Inst. Error = Total Leakage 2NV1002 seem +
scem =
FlDJEITATICU 'TE5T MVP.6 :
Section 12.6 N/A Ssetion 12.8 Valve Test Position
/
2NV1011 CLOSED
/
2NV1001 CLOSED Vent 2NV1001 (Annulus; straight down to floor from upper annulus door)
Valve (s):
Leak Rate
+ Inst. Error = Total Leakage 2NV1001 seem +
seem =
, og
,,3,,,
(WWETRADoQ "TETT SE555 URE *. -
./g4
al ENCLOSURI 13.1 PT/2/A/4200/01C PENETRATION DATA SHEET Pass 51 of 93
,l s
i!
i!
il
}
PAGE 2 0F 2 M342 Ssetion 12.8 Valve Test Position
/
2NV1001_
OPEN
/
2NV849A,C CLOSED
)
%e.*~
~
Vent 2NV1001 (Annulus; straiglit down to floor from upper annulus door)
Valve (s):
Leak Rate
+ Inst. Error = Total Leakage 2N m 9A,CA-seem +
seem =
en, 33 p.g.py
%E'TRAT1ou TE57-A55SvRE : -
vmkr.
Section 12.9 N/A
/
Verify valves were leak rate tested per Section 12.0 (procedure) of this test.
Section 12.10
/
Transfer Total Leakages to PT/2/A/4200/01J.
I I
1
W Pt / 7/ A/47tm/n ts:
P. ige S/ of 9l EIOCIDS1IE I 1.2 Penetration Valve CheekI at I n.f pn=lt In.lenet t Red Tag.
Valve Test Position Vrfttn Normal Positinn Vrlain MC Print f TES 10 0 Position laitial Init ial Position Initial Initial Valve Valve Nomenclatute if initialled by SRO.,nd Test Coordinator.
Il Changes s.ay I.c ma.le to this checklist IN)TES:
- 2) Valves may be signed off as beleg aligned by OP.
PACE I 0F 2 p TIOst,M d 42 isolates standby makeup pump to NC pump seals.
NOTE: This thenklist 2NVR49A i stan< thy Itancup out side Cent Isol MC-2554-1.3 100 ~
OITN N/A CIM ED N/A 21t*, 725'2, RM, Front of BW Pops MC-2554-1. 3 YES CLOSF.D N/A OPEN N/A 2NV M Stanelley Mai.*up Pump Disch Isol Annulus 20' tecyond st and by M/U pop MC-2554-1.3 NO OPEN II/A CIDSED N/A 2WVR4A Standby Makeup Filter Test Orsin Annulus 23t'
~ _ _
YES CIMED N/.'.
CLOSED N/A Stadby Mhup Pop - Cat Flr & Estuip Sep Isol ftC-2554-l.1 2WVI012C 2 %', 725+3, R54, P.C. Ossd vaiI 10' op.
MC-2554-1.3 YES CLOSED N/A OPEN N/A Stanalby Makeup Pissp to NC Pump Seals Isol 2NV1013 210* entside wall 10' up MC-2554-1.3 90 0 GPEN N/A CIDSED N/A 2NVloll Standby llekeup Pop Cont Pene Test Drain
- 20* outside wall, 10' up e
1 1
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e
- 1"i/ 2/ A/ 4/tMl/nlt e
Pa ge-
, t of 9 $
ENCIA5tRE 11.2 Penetection Valve Clice klist Indynelt indenett Iled Tag Valve Tess Position Vrfrtn Normal Pos i t ion Vr f a t n 19C Print f TF.S 11 0 Posit ioes Initial Initial Position Initial Inisial Valve Valve Namenc lature if initialled by $180 and Test Coordinator.
plTES:
- 1) Changes may be made to this theiklist
- 2) Valves may be signed off as being aligned by OP.
PACE 2 OF 2 PEHETRATION M-1.42..
IACKED 2WV1001 Standby nkup Centside Cent Isol Test Vent f1C-2554-l.3 NO OPEN CIA 3ED 218' in annulus 8 Attach hose for draining O
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Peg 2 1 of 4 r-DUKE POWER COMPANY McGUIRE NUCLEAR STATION STANDBY MAKEUP PUMP CHECK VALVE TEST - SHUTDOWN s
1.0 Purpose j
To full stroke cycle 2NV844, 2NV1007, 2NV1008, 2NV1009, 2NV1010.
2.0 References 2.1 Duke flow diagram, MC-2554-1.3.
2.2 McGuire IWV Submittal.
- 2. s rees Jru 4.0. 5 cn' 2 9 t-tv rs 3.0 Time Required v
About 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> every cold shutdown, but not more often than once every-three months, using three Performance technicians, on Control Operator and one Nuclear Equipment Operator.
(
4.0 Prerequisite Tests None 5.0 Test Equir ant 5.1 Two 3/4" ID hoses, 15 feet in length, with 1 inch NPT female Connectors.
6.0 Limits and Precautions 6.1 Do not dead-head the standby makeup pump.
This pump is of tha positive displacement type and damage could result.
7.0 Required Unit Status Initial /Date
/
7.1 The unit is in modes 3, 4, 5, or 6.
8.0 Prerequisite System Conditions
/
8.1 Verify an adequate supply of water exists on the spent fuel pool side of the fuel transfer canal (Unit 2).
9.0 Test Method The Standby Makeup Pump, a positive displacement type pump, will be used to full stroke cycle valves 1NV844, 2NV1007, 2NV1008, 2NV1009 and 2NV1010.
The pump will be started, flow will be directed to the Containment Floor and Equipment Sump.
Then each line for each seal water injection will be opened individually and flow will be verified.
f 10.0 Data Requirgd
PT/2/A/4209/09 Pago 2 of 4 None 11.0 Acceptance Criteria 1
11.1 A flow of E26 GPM through check valve 2NV844 (Standby Makeup j:
Pump Discharge Check) to verify proper e,ycling and operation of this valve.
11.2 A flow of E8 GPM through each check valve 2NV1007, 2NV1008, 2NV1009 and 2NV1010 (Standby Mikeup Pump to NC Pumps Seal Check) to verify proper cycling and operation of these valves.
9.
.,_.,...--,-,r
,,m-
f i
PT/2/A/4209/09 Page 3 of 4 12.0 Procedure NOTE:
- 1) This test is coordinated from the Standby Shutdown Facility, f
- 2) IV means independent verification is required.
'I Initial /Date
/
12.1 Perform the valve checklist on Enclosure 13.1.
/
12.2 Start the Unit II Standby Makeup Pump.
Allow the pump to run a few minutes with flow directed to the Containment Floor and Equipment Sump.
/
12.3 Verify a flowrate ge 2NVP6420, located in the I
StandbyShutdownYffff is flowrate verifies cycling and proper operation of 2NV844 (Standby Makeup Pump Discharge Check).
/
12.4 Attach the two hoses with the appropriate connectors to venks 2NV1003 (Standby Makeup Pump to NC Pump 2A Seals Test Vent)~and' j
2NV1004 (Standby Makeup Pump to NC Pump 2B Seals Test Vent).
/
12.5 Open vent 2NV1003.
/
12.6 Open valve 2NV1013C (Standby Makeup Pump to NC Pumps Seals Isolation).
/
12.7 Close valve 2NV1012C (Standby Makeup Pump to Containment Floor and Equipment Sump Isolation).
/
12.8 Verify a flowrate of 38 GPM on gauge 2NVP6420.
This flowrate verifies cycling and proper operation of 2NV1008 (Standby Makeup Pump to NC Pump 2A Seals Check).
/
12.9 Open vent 2NV1004.
/
12.10 Close vent 2NV1003.
/
12.11 Remove hose from vent 2NV1003 and attach this hose to vent 2NV1005 (Standby Makeup Pump to NC Pump 2C Seals Test Vent).
/
12.12 Verify a flowrate of 38 GPM on Gauge 2.WP6420.
This flowrate verifies cycling and proper operation of 2NV1007 (Standby Makeup Pump to NC Pump 2B Seals Check).
/
12.13 Open vent 2NV1005.
/
12.14 Close vent 2NV1004.
/
12.15 Remove hose from vent 2NV1004 and attach this hose to vent j
2NV1006 (Standby Makeup Pump to NC Pro 2D Seals Test Vent).
O PT/2/A/4209/09 1
Paga 4 of 4 lj Il
/
12.16 Verify a flowrate of 28 GPM on gauge 2NVP6420.
This flowrate j
verifies cycling and proper operation of 2NV1010 (Standby Makeup Pump To NC Pump 2C Seals Check).
/
12.17 Open vent 2NV1006.
/
12.18. Close vent 2NV1005.
/
12.19 Verify a flowrate of E8 GPM on gauge 2NVP6420.
This flowrate verifies cycling and proper operation of 2NV1009 (Standby Makeup Pump to NC Pump 2D Seals Check).
/
12.20 Stop the Standby Makeup Pump.
/
12.21 Close vent 2NV1006.
/
12.22 Remove hoses from vents 2NV1005 and 2NV1006.
/
12.23 Realign the valve checklist on Enclosure 13.1.
/
12.24 Remove test hoses and connectors from the Reactor Building and ensure they are properly stored and accounted for.
13.0 Enclosures 13.1 Valve Checklist I
l l
,l Paga 1 of 1
. DUKE POWER COMPANY PT/2/A/4209/09 il
'McGUIRE NUCLEAR STATION 3.1
- i ll NOTES
- 1) IV means independent veriff cation is required.
- 2) Valves may be signed.off as aligned by OP.
TEST INIT.
NORMAL INIT.
i' VALVE NO.
VALVE NAME POSITION INIT.
(IV)
POSITION INIT (IV) 2N/1013C SSF Pump to NC Pump Seals CLOSED N/A CLOSED N/A
, v,,,,, _,,,
2NV1012C Staby Makeup Pump to Sump OPEN N/A CLOSED N/A i
,. 3 2
Staby Makeup Outside C N/A CLOSED N/A 2NV842AC Staby Makeup Pump Inlet OPEN N/A CLOSED N/A Isol.
2NV433 NC Pump A Seal Supply CLOSED OPEN From SSF 2NV435 NC Pump B Seal Supply CLOSED OPEN From SSF 2NV437 NC Pump C Seal Supply CLOSED OPEN From SSF 2NV446 NC Pump D Seal Supply CLOSED OPEN From SSF 2NV845 Standby Makeup Pump OPEN N/A OPEN N/A Discharge Isol.
2KF122 Fuel Transfer Tube Isol.
OPEN N/A OPEN N/A 2NV1003 SSF Pump to NC Pump 2A CLOSED N/A CLOSED N/A Test Vent 2NV1004 SSF Pump to NC Pump 2B CLOSED N/A CLOSED N/A Test Vent 2NV1005 SSF Pump to NC Pump 2C CLOSED N/A CLOSED N/A Test Vent 2NV1006 SSF Pump to NC Pump 2C CLOSED N/A CLOSED N/A Test Vent
Arymmgur 4 m
(1) IO No. PT/1/A/4250/18 Form 34731 ( A3 871 l
CUKE FOWER COMFANY" Charge f s) 0
~3 PROCEDURE PROCESS RECORD o
I"Corcorated PR EPA R ATION (2) STATION McGuire Nuclear (3) PROCEDURE TITLE Unit 1 Main Steam Safety Valves Administrative Controls Procedure I-II"88 (4) PREPARED BY Kevin Kelly DATE M
DATE N' / 2 '
(5) REVIEWED BY q
m-Cross Disciplinary Review By N/R (6) TEMPORARY APPROVAL (If Necessary)
By (SRO) DATE DATE By
//h (7) APPROVED BY DATE V
{
'( "
(8) MISCELLANEOUS Reviewed / Approved By DATE Reviewed / Approved By DATE (9) COMMENTS (For procedure reissue indicate whether additional changes,other tean previously approved changes, are i cluced.
Attach additional pages,if necessary.)
ADDITION AL CHANGES INCLUDED.
Cyes o
(10) COMPARED WITH CONTROL COPY DATE 1
COMPLETION l
(11) DATE(S) PC R FO'tM ED (12) PROCEDURE COMPLETION VERIFICATION C Yes C N/A Check lists and/oe blanks properly initialed, signed, dated or filled in N/A or N/R. as accroor, ate?
C Yes C N/A Listed enctosures attached?
C Yes C N/A Data sheets attached, completed, dated and signed?
Cyes C N/A Charts, graphs, etc. attached and properly dated, identified and marked)
C Yes C N/A Acceptance criteria met?
VERIFIED BY DATE (13) PROCEDURE COMPLETION APPROVED DATE (14) REM ARKS (Attach additional pages,if eccessary.)
PT/1/A/4250/13 Pag 2 1 of 4 3
DUKE POWER COMPANY MCGUIRE NUCLEAR STATION UNIT 1 MAIN STEAM SAFETY VALVES ADMINISTRATIVE CONTROLS PROCEDURE 1.0 PURPOSE To provide administrative controls for insuring that Main Steam Safety Valves are tested in accordance with Section XI of the ASME Boiler and Pressure Vessel Code.
2.0 REFERENCES
2.1 SOURCE DOCUMENTS 2.1.1 ASME Boiler and Pressure Vessel Code Section XI, Paragraph IWV-3500 2.2 RETERENCES NEEDED TO PERTORM PROCEDURE PT/0/A/4250/01 Main Steam Safety Valve Setpoint Test 3.0 PERSONNEL REQUIREMENTS 3 men, 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> per valve 4.0 PREREQUISITE TESTS 4.1 This procedure must be used in conjunction with PT/0/A/4250/01 to perform testing and develop required data.
4.2 PM Work Request must be scheduled to perform this work, when possible. Planning PM Coordinator shall be contacted to call up the required PM/PT code for valve to be tested.
5.0 TEST EQUIPMENT None
~
6.0 LIMITS AND PRtCAUTIONS None 7.0 REQUIRED UNIT STATUS 7.1 See PT/0/A/4250/01.
8.0 PREREQUISITE SYSTEM CONDITIONS 8.1 See PT/0/A/4250/01.
PT/1/A/4250/18 Pags 2 of 4 9.0 TEST METHOD 9.1 Using live steam and test apparatus, valve will be determined co test within acceptable range as required per PT/0/A/4250/01.
10.0 DATA REQUIRED 10.1 Valve test dates 10.2 Valve acceptability 11.0 ACCEPTANCE CRITERIA 11.1 Valve has been tested within allowable time frame, as required by IWV-3500.
11.2 Valve setpoint is within acceptable range.
12.0 PROCEDURE 12.1 PM Work Request has been issued to perform this testing.
PM/PT codes for these valves are as follows:
ISV2 - 5A01 ISV14 - 5A11 ISV3 - 5A02 ISV15 - 5A12 ISV4 - 5A03 ISV16 - 5A13 ISV5 - 5A04 ISV17 - 5A14 ISV6 - 5A05 ISV18 - 5A13 ISYS - 5A06 ISV20 - 5A16 ISV9 - 5A07 ISV21 - 5A17 ISV10 - 5A08 ISV22 - 5A18 ISV11 - 5A09 ISV23 - 5A19 ISV12 - 5A10 ISV24 - 5A20 12.2 Determine the number of valves to be tested.
12.3 This will be accomplished by first determining the number of months from October 1987 until the first scheduling of this procedure, i
12.4 Divide the number of months, as found in Step 12.3, by 60; and 1
sultiply by 20 (the ni.aber of valves in the testing program).
i 12.5 The resultant from Step 12.4, -ounded to the next whole number, is the number of valves which shall be tested during the first cycle.
HOLD: Maintensace Rep. and Mechanical Maintenance Technical Support Rep. sign off Enclosure 13.1, Section A.
e c
I PT/1/A/4250/18
't Page 3 of 4 12.6 For each subsequent refueling, divide the number of months f roe October 1987 until the present by 60; and multiply by 20.
Subtract the number of valves already tested during the current 60 month cycle. (See Enclosure 13.1).
Round to next whole number. This will determine number of valves to.be tested.
+
Example:
If first refueling after October 1987 is January 1989, then (15 X 20 = 5) = 5 valves to be tested 60 If the subsequent refueling is January 1990, twelve months later, or (27 X 20 = 9).
60 Sitee five valves have been tested during the 27 month period (9 - 5 = 4), four valves would require testing at this time.
12.7 When the number of months from October 1987 is greater than 60, any valve which has not been tested during the 60 month cycle shall be tested.
12.8 At such a time that all 20 valves have been tested, or first refueling after October 1992, whichever comes first, a new start date shall be established and substituted for October 1987.
12.9 During each refueling, af ter the new start date, the number of valves to be tested shall be determined per Step 12.6 substituting the new start date.
12.10 No valve may exceed a 60 month period without being tested. Any valve that has not been tested within 60 months, irregardless of start date, must be scheduled and tested as soon as valve can be removed from service.
12.11 When any valve in a system fails to function properly during a regular test, additional valves shall be tested. This will be determined by an arbitrary arsumption that a 12 month operating period has passed to another refueling; and the additional valves shall be tested to make the cumulative total tested at least N_ X 20 where N includes the additional 12 months.
60 Notify'Nechanical Maintenance Technical Support Cognizant individual.
Otherwise, N/A this Step.
h0LD: Maintenance Rep. and Mechanical Maintenance Technical Support Rep. sign off Enclosure 13.1, Section A.
12.12 Upon completion of these Steps, Enclosure 13.1 must be revised per a procedure change to correct last date of test for each valve tested.
4 I
,,n,,,-------
--~, -..,.. - ~ _ - - -
()
U PT/1/A/4250/18 Page 4 of 4
.h.
12.13 Forward completed copy to Mechanical Maintenance Technical Support cognizant individual for sign off and review.
HOLD: Machtnical Maintenance Technical Support Rep. sign of f Enclosure 13.1, Section B.
13.0 ENCLOSL%ES 13.1 Data Sheet J
.i
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, 3.1 PT/1/A/4250/18 Data Sheet W. R. No.
Page 1 of 2 A.
TEST LAST TEST VALVE NO.
PM/PT CODE DATE DATE ISV2 SA01 10/87 ISV3 5A02 10/87 ISV4 5A03 10/87 ISV5 5A04 10/87 ISV6 5A05 10/87 ISV8 5A06 10/47 ISV9 5A07 10/87 ISV10 SA08 10/87.
ISV11 5A09 10/87 ISV12 5A10 10/87 ISV14 SAll 10/87 ISV15 5A12 10/87 ISV16 5A13 10/87 ISV17 5A14 10/87 ISV18 5A15 10/87 ISV20 SA16 10/87 ISV21 5A17 10/87
~
ISV22.'
5A18 10/87 ISV23 5A19 10/87 ISV24 5A20 10/87 12.5 Number of Valves Requiring Testing Maintenance Rep.
Maintenance Technical Support Rep.
~
Enclosura 13.1 PT/1/A/4250/18 Dsta Shset W. R. No.
l Page 2 of 2 1
4 l'
l' 12.11 Number of Additional Valves Requiring Testing Maintenance Rep.
Mechanical Maintenance Technical Support Rsp.
B.
12.13 All testing required by this procedure and in accordance with ASME Boiler and Pressure Vessel Code,Section XI, Paragraph IWV-3500, has been completed.
Mechanical Maintenance Technical Support Rep.
4 f
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E0RMKL0k OLY s -,34nt in3 en (1) 10 No PT/2/A/4250/19J o
'8 DUKE POWER COMPANY Change (s) 0
- 1
~ ' ' '
PROCEDURE PROCESS RECORD
')
n
-taccroorsteo PR EPAR ATION McGuire Nuclear Station (2) STATION (3) PROCEDURE TITLE Unit 2 Main Stepe Safety Valves Administrative Controls Procedura (4) PREPARED BY Kevin Kel1Y r 1TE January 27, 1938 (5) REVIEWED SY N
DATE Cross Disciplinary Review By N/R (6) TEMPORARY APPROVAL (if Necessary)
)
By (SRO) DATE BV DATE i
(7) APPROVED BY DATE
/
c
/
l (8) MISCELLANEOUS Reviewed / Approved By DATE Reviewed / Approved By DATE (9) COMMENTS (For procedure reissue indicate whether additional changen,other than previously acoroved enjnges, are.netuced.
Attach additional pages,if necessary.)
ADDITIONAL CHANG ES INCLUDE 0.
2Yes CNo (10) COMPARED WITH CONTROL COPY DATE COMPLETION (11) DATE(S) PE R FORMED (12) PROCEDURE COMPLETION VERIFICATION C Yes C N/A Check lists and/or blanks properly initialed, signed, dated or filled in N/A or N/R. as aoorooriate)
C Yes C N/A Listed enc'osures attached?
C Yes C N/A Data sheets attached, completed, dated and signed?
C Yes C N/A Charts, graphs, etc. attached and properly dated, identified and marked?
Cyes C N/A Acceptance criteria met?
VEnlFIED BY DATE (13) PROCEDURE COMPLETION APPROVED DATE (14) R EM ARKS (Attach additional Da9es. if necessarY.)
i PT/2/A/4250/19 Page 1 of 4 DUKE POWER COMPANY MCGUIRE NUCLEAR STATION UNIT 2 MAIN STEAM SAFETY VALVES ADMINISTRATIVE CONTROLS PROCEDURE e
1.0 PURPOSE To provide administrative controls for insuring that Main Steae Safety Valves are tested in accordance with Section XI of the ASME Boiler and Pressure Vessel Code.
2.0 REFERENCES
2.1 ASME Boiler and Pressure Vessel Code Section XI, Paragraph IW-3500 3.0 TIME REQUIREL 3 men, 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> per valve 1
4.0 PREREQUISITES j
4.1 This procedure must be used in conjunction with PT/0/A/4250/0k (Main Steam Safety Valve Setpoint Test) to perform testing and develop required data.
)
4.2 PM Work Request must be scheduled to perform this work, when possible.
Planning PM Coordinator shall be contacted to call up the required PM/PT code for valve to be tested.
5.0 TEST EQUIPMENT N/A 6.0 LIMITS AND PRECAUTIONS N/A j
7.0 REQUIRED UNIT STATUS 7.1 See procedure PT/0/A/4250/01 (Main Steam Safety Valve Setpoint Test).
8.0 PREREQUISITE SYSTEM CONDITIONS 8.1 See procedure PT/0/A/4250/01 (Main Steam Safety Valve Setpoint Test).
8; (l
o PT/2/A/4350/19 Page 2 of 4 g
o 9.0 TEST METHOD Using live steam and test apparatus, valve will be determined to test within acceptable range as required per procedure PT/0/A/4250/01 (Main Steam Safety Velve Setpoint Test).
10.0 DATA REQUIRED 10.1 Valve Test Dates 10.2 Valve Acceptability 11.0 ACCEPTANCE CRITERIA 11.1 Valve has been tested within allowable time frame, as required by I'JV-3500, 11.2 Valve setpoint is within acceptable range.
12.0 PROCEDURE 12.1 PM Work Request has been issued to perform this testing. PM/PT codes for these valves are as follows:
2SV2 - SB21 2SV14 - 5B31 2SV3 - 5822 2SV15 - 5B32 2SV4 - 5B23 2SV16 - 5B33 2SV5 - 5B24 2SV17 - 5B34 2SV6 - 5B25 2SV18 - 5B35 2SV8 - 5B26 2SV20 - 5B36 2SV9 - SB27 2SV21 - SD37 2SV10 - SB28 2SV22 - SB38 2SV11 - 5B29 2SV23 - 5B39 2SV12 - 5B30 2SV24 - 5B40 12.2 Determine the number of valves to be tested.
12.3 This will be accomplished by first determining the number of months from May 1987 until the first scheduling of this procedure.
12.4 Divide t5e number of months, as found in Step 12.3, by 60; and multiply by 20 (the number of valves in the testing program).
12.5 The resultant from Step 12.4, rounded to the next whole number, is the number of valves vnich shall be tested during,the first cycle.
HOLD: Maintenance Rep. and Mechanical Maintenance Technical Support Rep. sign off Data Sheet (Enclosure 13.1), Section A.
1
I PT/2/A/425C/19 Page 3 of 4 12.6 -For each subsequent refueling, divide the number of months from May 1987 until the present by 60; and multiply by 20. Subtract i
the number of valves already tested during the current 60 month cycle. (See Enclosure 13.1). Round to next whole number. This will determine number of valves to be tested.
Example:
If first refueling after May 1987 is August 1988, then 15 X 20 = 5) = 5 valves to be tested (M
If the subsequent refueling is August 1989, twelve 27 X 20 = 9).
sooths later, or ( E Since five valves have been tested during the 27 month period (9 - $ = 4), four valves would require testing at this time.
12.7 When the number of months from May 1987 is greater than 60, any valve which has not been tested during the 60 month cycle shall-be tested.
12.8 At such a time that all 20 valves have been tested, or first refueling after March 1992, whichever comes first., a new start date shall be established and substituted for March 1987.
12.9 During each refueling, after the new start date, the number of' valves to be tested shall be determined per Step 12.6 substituting the new start date.
12.10 No valve may exceed a 60 month period without being tested. Any valve that has not been tested within 60 months, irregardless of start date, must be scheduled and tested as soon as valve can be removed froe service.
12.11 When any valve in a system fails to function properly during a regular test, additional valves shall be tested. This will be determined by an arbitrary assumption that a 12 month operating period has passed to another refueling: and the additional valves shall be tested to make the cumulative total tested at least N X 20 where N includos the additional 12 months.
TO' Notify Mechanical Maintenance Technical Support Cognizant individual. Otherwise, N/A this Step.
l HOI.D: Maintenance Rep. and Mechanical liaintenance Technical Support Rep, sign off Data Sheet (Ecciosure 13.1), Section A.
12.12 Upon completion of these Steps, Enclosure 13.1 must be revised per a procedure change to correct last data of test for each J
valve tested.
l i
2 l
i M/2/A/4250/19 Page 4 of 4 12.13 -Forward completed copy to Mechanical Maintenance Technical Support cognizant individual for sign off and review.
HOLD: Mechanical Maintenance Technical Support Rep. sign off Data Sheec (Enclosure 13.1), Section B.
13.0 ENCLOSURES 13.1 Data Sheet
- e I
1 i
0
, 3.1 PT/8/A/4250/19 Data Sheet W. R. No.
Page 1 of 2 i
A.
TEST LAST TEST VALVE NO.
PM/PT CODE DATE DATE 2SV2 5B21 7/87 2SV3 5B22 7/87 2SV4 5B23 7/87 2SV5 5B24 7/87 2SV6 5B25 7/87 2SV8 SB26 7/87 2SV9 SB27 7/87 2SV10 5B28 7/87
~
2SV11 5829 7/87 2SV12 5B30 7/87 2SV14 5B31 7/87 2SV15 5B32 5/87 2SV16 5B33 7/87 2SV17 5B34 5/87 2SV18 5835 5/87 2SV20 5B36 7/87 2SV21 5337 7/87 i
2SV22 5B38 7/87 2SV23 5B39 7/87 2SV24 5840 7/87 12.5 Number of Valves Requirin8 Testin8 Maintenance Rep.
Maintenance Technical Support Rep.
~ _.. _, _, _ _. _
4 Enclosuro 13.1 PT/2/A/4250/19 Data Shast W. R. No.
Page 2 of 2 12.11 Number of Additional Valves Requiring Testing Maintenance Rep.
Mechanical Me,intenance Technical Support Rep.
B.
12.13 All testing required by this procedure and in accordance with ASME Boiler and Pressure Vessel Code,Section XI, Paragraph IWV-3500, has been completed.
Mechanical Maintenance Technical Support Rep.
d a
l l
i i
1
i wwm r s M, 0MT 0% 0D Duke Power Company (i)iD Na PT/0/A/4150/05 o
PROCEDURE PROCESS RECORD Changes; to fra ps.ied PREPARATON (2) Staton McCuire Nuclear (3) Procedure Title PRER Affaf 7tB RAFETY VATMW RETpnf arf Tant (4) Prepared By r.
- 4. r.I1.
Date J -- 22, 19mn b---
c' > -
Date 6 - 2 2 -#
(5) Revmod By Cross-Disoptinary Renew By N/R 8
(6) Temporary Approval (if necessary)
By (SRO) Date By a
Date - _
(7) Appnad By LL W f
4 -
Date b'~2 M 7 (8)Mme aaneous Revmed/Apprtud By Date Rev6ewed/Apprimd By Date (9) Comments (For procedure reessue rdcate whether additional changes, other than prev 6ously appnad changes, are r).
ciuded. Attach additional pages,if nacensary.)
N Changes included.
(10) Compared with Control Copy Date (11) Requres change to FSAR not identrflod h 10CFR50.59 edaanon? O Yes if "yes", attach dotaded expienadon.
BNo Comp 6etion (12) Date(s) Performed (13) Procedure COTG's. Venficanon O Yes O N/A Check lists and/or blanks property inrueled, signed, dated or fined in N/A or N/R, as appropriate?
O Yee O N/A Usted enclosures attached?
O Yes O N/A Data :: hoots attached, completed, dated and signed?
O Yes O N/A Charts, graphs, etc, attached and property dated,identrfied and marked?
Oyes ON/A Procmdurerequrementsmet?
venfied By Date (14) Procedure COTG"wi Appnmd Date (15) Remarks (attach add /tkria/ pages, if necessary) i REVIEWED BY QUAulY ASSURANCE DEPARTMENT OPERATIONS OlVISION Yua A tk ? t
~QA REP $5ENTAlivE DATE
'l PT/0/A/4150/05 Page 1 of 3 t
DUKE POWER COMPANY MCGUIRE NUCLEAR STATION
,u PRESSURIZER SAFETY VALVE SETPOINT TEST 1.0 PURPOSE To provide a method of testing and adjusting the setpoint of the pressurizer safety valves
2.0 REFERENCES
2.1 SOURCE DOCUMENTS 2.1.1 MCM 1205.09-18 2.1.2 MCM 1205.09-01 j
2.1.3 Tech Spec 4.4.2.1 2.1.4 Tech Spec 4.4.2.2
2.2 REFERENCES
NEEDED TO PERFORM PROCEDURE None 3.0 TIME REQUIRED
~
4 Men - 8 Hours T' 4.0 PREREQUISITE TESTS None TEST EQUIPW"'V
?
5.0
- W ~.-
5.1 Test beach 5.2 Heise Digigauge 1
6.0 LIMITS AND PRICAUTIONS 6.1 Ensure valve is securely fastened to test bench.
6.2 Do not stand in front of valve discharge.
7.0 REQUIRED STATION STATUS N/A 8.0 PREREQUISITE SYSTEM CONDITIONS
\\
N/A j
1 i
PT/0/A/4150/05 Page 2 of 3 1
9.0 TEST METHOD i
Valve will be attached to bench and pressurized to test setpoint. Test will be performed three times. Each test must be 2485 PSIG (2461-2509).
If setpoint is incorrect, valve will be adjusted and retested until correct'results are obtained.
10.0 DATA REQUIRED Valve Setpoint 11.0 ACCEPTANCE CRITERIA Valve setpoint shall be 2485 PSIG (2461-2509).
12.0 PROCEDURE 12.1 Verification of calibrated / test equipment, sign off 3.1, Section B.
12.2 Attach valve and test gauge to test bench.
12.3 Remove nozzle ring setscrew.
12.4 Turn nozzle ring counterclockwise until it contacts disc ring.
12.5 Turn nozzle ring clockwise 2 notches.
NOTE: This setting may vary from 1 to 8 notches dependent upon setting which allows for most consistent lift.
12.6 Perform setpoint test.
12.6.1 Pressurize valve with nitrogen until lift (pop) is obtained.
HOLD: Record on Enclosure 13.1, Section A, Q.C. and qualified Maintenance Rep.
or Supervisor.
12.6.2 First test will be documented for "As Found" setpoint.
12.6.3 If first test is within required range the "As Found" setpoint will also be considered as first "Acceptance Test".
Proceed to Step 12.5.5.
12.6.4 If first test is outside required range adjust valve.
Proceed to Step 12.5.4.1.
WARNING THE ADJUSTING BOLT SHOULD NOT BE TURNED UNTIL INLET PRESSURE IS BELOW 1800 PSIG.
12.G.4.1 To adjust setpoint remove cap, spindle out and lifting gear.
12.6.4.2 Release adjusting bolt locknut.
j
.O
i PT/0/A/4150/05 Page 3 of 3 5
12.6.4.3 Turn adjusting bolt clockwise to increase setpoint or turn adjusting bolt counterclockwise to decrease setpoint.
12.6.4.4 Tighten adjusting bolt lock nut after each adjustment.
12.6.5 Wait 2 to 3 minutes between each test. This allows valve spring and gauge to recover from previous test.
12.7 Test valve three times for acceptance. Each test must fall within acceptable range (2485 PSIG (2461 - 2509). Record setpoint on Enclosure 13.1).
HOLD: QC and qualified Maintenance Rep. or Supervisor sign off 3.1, Section A..
12.8 Seat Tightness Test 12.8.1 Blank off discharge with seat leakage test device.
12.8.2 Pressurize valve inlet to 2240 PSIG (2140 - 2250).
l 12.8.3 Determine lesk rate by counting bubbles escaping through seat leakage test device. Leakage criteria is 20 bubbles per minute or less.
HOLD: QC and qualified Maintenance Rep. or Supervisor sign off i 3.1, Section A.
l 12.9 Reset Nozzle Ring 12.9.1 Turn ring counterclockwise until it contacts disc ring.
12.9.2 Lower ring 18 notches by turning clockwise.
HOLD: QC and Maintenance Rep. sign off Enclosure 13.1, Section A.
NOTE:
-18 notches is the number used to represent lowering ring 18 notches.
12.9.3 Replace nozzle ring setscrew.
12.9.4 Seal setscrew.
1 12,10 Reinstall lifting gear, spindle nut and cap if removed.
12.11 Remove valve from test bench.
l 13.0 ENCLOSURES 13.1 Data Sheet 13.2 Valve Drawing 1
_.-.._._r,.
.,,__..m.r9
4 1
Enciesura 13.1 PT/0/A/41SO/05 Data Sheet W. R. No.
l
~
Page 1 of 2 Valve Serial No.
Valve Equip. I.D.
A.
SETp0!NT VERIFICATION 12.6.1 "As Found" setpoint _
QC Rep.
Qualified Maintenance Rep. or Supervisor Gauge No.
Cal. Due Date 12.7 Acceptance Test 1 setpoint QC Rep.
Qualified Maintenance Rep. or Supervisor Gauge No.
Cal. Due Date Acceptance Test 2 setpoint QC Rep.
Qualified Maintenance Rep. or Supervisor Acceptance Test 3 setpoint 1i
)
QC Rep.
Qualified Maintenance Rep, or Supervisor 12.8.3 Seat Tishtness Number of bubbles per minute =
Qualified Maintenance Rep. or Supervisor l
l
Enclesuro 13.1 PT/0/A/4150/01 Data Sheet W. R. No.
Page 2 of 2 Valve Serial No.
Valve Equip. I.D.
A.
(continued) 12.9.2 Nozzle Ring Nozzle ring is reset to -18 notches.
Qualified Maintenance Rep. or Supervisor QC Rep.
B.
VERIFICATION OF CALIBRATED / TEST EQUIPMENT 12.1 All calibrated / test equipment used on the job has been verified within the acceptable range and the procedure used to document the verification is attached to the Work Request.
i 3.2 PT/0/A/4150/05 l'
Valve Drawing 5
Page 1 of 1 ITEM NO.
PART NAME l
i ;,
1 Body i
Nozzla 3
Nozzle Ring 4
Nozzle Ring Setscrew 3 b
, 'x 5
Disc Holder d
Disc Bushing
]
SECTION A*A 7
Disc Ring j
8 Bellows 9
Disc Insert p*
4 10 Disc Insert Pin e
((h 11
,M(
/
g Eductor 12 Adjusting Ring y
h 13 Adjusting Ring Setscrew
,-"=
2#
Wc 14A Spindle Assembly b
14B Spindle Point p
15 Bonnet Adapter ~
16 Spindle Nut 17 Spindle Nut Cotter 18 Bonnet p
19 Spring l
/~ VENT 20 Sprine, Washer o
21 Cap g
y 22 Dog b4' 23 Dog Shaft F
b -
[ ^ggh' 7
26 Dog Lever Nut 24 Dog Shaft Bearing M
4 25 Dog Shaft "0" Ring e
IIS g
q7 M g*[
/
27 Dog Lever Lor.kwasher 28 Lever C'
// _I
//
/
29 Adjusting Bolt
~
e 30 Adjusting Bolt Nut
/
D 7
s 31 Cap Plug e
Nl L
32 Cap Plug Gasket
(
o y
34 Eductor Gasket fO N N
35 Nozzle Ring And Adjusting 3
Ring Set Screw Gasket
!!!!!((
36 Dog Shaft bearing Gasket s
/ s s <
37 Cap Gasket N
38 Bonnet Stud
[fd
(
[j-38A Cap Stud i,,
39 Bonnet Stud Nut 39A Cap Stud Nut STYLE Me-ep 40 Piston (WITH PISTCae 41 Piston Lockclip 42 Gag Screw 43 Gag Top 44 Cap Top Gasket 45 Canopy Ring 46 Gasket (Special) 47 Nameplate And Identification Plate 48 Caution Plate 49 Drive Screws
re y. Armco,q 7 ll e
- )
s cor,a 34731 tr,g.g L' b e 4 d b k s YWd (1) 10 rio. PT/1/ A/4 2 5 2 /01 O' '
ouxe aowea Coua^~<
C a e<sl
~to PROCEDURE PROCESS RECORD g
Inco# porated g
PR EPAR ATION (2) STATION Mecuira hetene (3) PROCEDURE TITLE Auriffarv Fandwarar Pumn Nn.1 Parfnemmnem Tome O
- 03~ O DATE (4) PREPARED B o 9 ~ d~
DATE (5) REVIEWED BY OOM N/R Cross.0;sciplicary Review B/
(6) TEMPORARY APPROVAL (if Necessary)
(SRO) DATE ev DATE BY A
EI DATE (7) APPROVED BY (8) MISCELLANEOUS DATE Reviewed / Approved By
'teviewed/ Approved By DATE (9) COMMENTS (For procedure reissue indicate whether addit;onal changen, other than previously approved changes, are incboed, Attach additional pages,if necessary.)
ADDITION AL CHANGES INCLUDED, des Do (10) COMPARED WITH CONTROL COPY
_ OATE
~
COMPLETION (11) DATE(S) PERFORMED
.~
(12) PROCEDURE COMPLETION VERIFICATiCN C Yes C N/A Check lists and/or blanks properly initialed, signe'., dated or filled in N/A or N!R, as appropriate?
2 Yes C N/A Listed enclosures attached?
C Yes C N/A Data sheets attached, completed, dated a'd signed?
C Yes C N/A Charts, graphs, etc. attached and propuly dated,identif'ed and marked?
C Yes C N/A Acceptance criteria met?
VERIFIED BY DATE (13) PROCEDURE COMPLETION APPROVED DATE (14) REMARKS (Attach additional pages,if necessary.)
ll PT/1/A/6253/01 Page 1 of 12 1
DUKE POWER COMPANY McGUIRE NUCLEAR STATION AUXII,IARY FEIDWATER PUMP #1 PERFORMANCE TEST 1.0 Pu rpo se 1.1 To verify operational readiness of Turbine Driven Auxiliary Feedwater Pump fl.
1.2 To verify ICA22 (Aux. FDWP No. 2 Disch, to Steam Gen. Check) and ICA8 (Aux. FDWP No. 2 Suction Check) are fuliy stroked at design flow.
1.3 To verify ISAS (S/G IC Steam Supply Check Valve) and ISA6 (S/G 18 Steam Supply Check Valve) are sully stroked at design flow.
1.4 To stroke time 1SA48ABC (S/G 1C Steam Supply Isolation Valv'e) and ISA49AB (S/G 1B Steam Supply Isolation Valve).
2.0 References 2.1 Auxiliary Feedwater Systen Flow Diagram, MC 1592-1.0 through MC 1592-2.0 2.2 Main Steam Supply to Auxiliary Equipment Flow Diagram MC 1593-1.2 2.3 Auxiliary Feedwater System Description, MC 1223.42 2.4 McGuire Technical Specifications Sections 4.0.5, 4.7.1.2.a.2, and Table 4.3-2, Section 7A 4
2.5 McGuire Final Safety Analysis Report, Section 10.4.7 2.6 Auxiliary Teedwater System Operating Procedure, OP/1/A/6250/02 2.7 Bingham Pump Manual MCM 1201.05-249 2.8 ASME Boiler and Pressure Vessel Code - Section XI, Subsection IWPand IWV.
3.0 Time Required 3.1 Two hours using three Performance Technicians and one operator.
4.0 Prerequisite Tests None i
1 1
l i
l w
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y-y,
PT/1/A/4252/01 Pcg3 9 of 12
/
12.21 If testing pump using 1SA49, ensure valve fully opens within 50 seconds from starting the pump.
/
12.21.1 If ISA49 valve timing exceeds 50 seconds, declare CA f
Pump No. 1 inoperable, but pump testing may be continued.
/ __,
12.22 Adjust the Turbine Speed potentiometer to achieve a turbine / pump f
speed of 3470 + 25 revolutions oer minute./seus rus/s.<meur us org we estranuew.saven.;~sossa oxhunune os.E n n Masts touwn was used. cparas /u/q :
NOTE: Since Auxiliary Feedwater Pump No. I differential 44r i
pressure is a function of rotational speed, this speed setting ca.e 35
- ((ch*Ndi,.e
""#*h"rN82iASffIt22 W
S 9 66 I?.72flAdjustthemanu[alaYrkoaderfor1CA20ABtoachkeveapump
/
P4
/
12.23 flowrate of 900 gallons per minute as indicated by Control Roon j
gauge ICAP5040.
NOTE: At least 900 spe is required to verify Tech Spec surveillance.
/
12.24 If ICAP5040 is defective or out-of-calibration, install a differential pressure test gauge to the press,ure inputs to ICAFT5040 and use this test instrument to monitor pump suction i
flowrate. Record test gauge calibration information on 3.1.
Adjust ICA20AB to achieve a differential pressure reading of 57.7 INWD on the test gauge. This differential pressare indication correspads to a pump flowrate of 900 gallons per minute.
/
12.25 After the 900 gallons per minute test flowrate is obtained, allow prensure and flowrate conditions to stabilize for approximately five (5) ainutes. Readjust ICA20AB if necessary.
a m ~.,.
/
12.26 If using 1SA48 for steam suppTy source, verfff75A5"Tf/G IC
- = w
--m Steam Supply Check Valve) is fully open by observing normal pump operation and verifying 1SA49 remained closed using Control Room indication.
/
12.27 If using ISA49 for steam supply source, verify ISA6 (S/G 1B Steam Supply Che :k Valve) is fully open by observing normt.1 pump r
1 operation and verifying ISA48 remained closed using Control Room indication.
- - - -.. ~ -
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-m-a Form 34731 (7,g.86) g g 3 j;,'
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(1) ID No. PT/2/ A/4232/(
DUKE POWER COMPANY PROCEDURE PROCESS RECORD Change ts)_0 t o PR EPAR ATION
.. inc or oot s ted (2) STATION McCuire Nuclear (3) PROCEDURE TITLE Auxiliary Feedvater Pump No., Performance Test (4) PREPARED BY3 W
DATE O2*03* M (5) REVIEWED BY DATE AY ~ M~
J Crost Disciplinary Review By N/R MAE, t6) TEMPORARY APPROVAL (if Nece* ary)
By (SRO) DATE By-DATE (7) APPROVED BY 1
_DATE k
(8) MISCELLANEOUS Reviewed / Approved By -
DATE Reviewed / Approved By -
DATE
- 19) COMMENTS (For procedure reissue indicate whether additional changes, other than previously appro 4
ges, are included, ttach additional pages,if necessary.)
ADDITIONAL CHANGES INCLUDED, m Yes C No (10) COMPARED WITN CONTROL COPY DATE-COMPLETION (11) DATE(S) PE RFORMED i
\\
(12) PROCEDURE COMPLETION VERIFICATION 1
C Yes C N/A Check lists and/or blanks properly init,aled, s'gned, dated or fdled in N/A or N/R, as ap C Yes C N/A Listed enclosures attached ?
C Yes C N/A Data sheets attached, completed, dated and signed?
C Yes C N/A Charts, graphs, etc. attached and properly dated, identif ed and marked?
Cyes C N/A Acceptance criteria met?
VERIFIED BY-
.DATE (13) PROCEDURE COMPLE1 ON APPROVED-DATE (14)
REMARKS (Attach additional pages,if necessary.)
6-1 PT/2/A/4252/01 Page 1 of 12 I
b e
I DUKE POWER COMPANY McGUIRE NUCI. EAR STATION AINILIARY FEEDWATER PUMP #2 PERFORMANCE TEST 1.0 Pu rpose 1.1 To verify operational readiness of Turbine Driven Auxiliary Teedwater Pump #2.
1.2 To verify 2CA22 (Aux. FDWP No. 2 Disch, to Steam Gen. Check) and 2CA8 (Aux. FDWP No. 2 Guction Check) are fully stroked at design flow.
1.3 To verify 2SAS (S/G 2C Steam Supply Check Valve) and 2SA6 (S/G 2B Steam Supply Check Valve) are fully stroked at design flow.
1.4 To stroke time 2SA48ABC (S/G 2C Steam Supply Isolation Valve) and 2SA49AB (S/G 2B Steam Supply Isolation Valve).
2.0 References 2.1 Auxiliaty Feedwater Systes Flow Diagram, MC 2592-1.0 through j
MC 2592-2.0 J
2.2 Main Ster.e Supply to Auxiliary Equipment Ylow Diagram MC 2593-1.2 2.3 Auxiliary Teedwater System Description, MC 1223.42 2.4 McGuire Technical Specifications Sections 4.0.5, 4.7.1.2.4.2, and Table 4.3-2 Section 7A 2.5 McGuire Final Safety Analysis Report, Section 10.4.7 2.6 Auxiliary Feedwater Systes Operating Procedure, OP/2/A/6250/02 2.7 Bingham Pump Manual MCM 1201.05-249 2.8 ASME Boiler and Pressure Vessel Code - Section XI, Subsection IWPand IWY.
l 3.0 Time Required 3.1 Two hours using three Performance Technicians aus one Operator.
4.0 Prerequisite Tests None j
.I
1 nw;.au 6us ic4uuat abr ucost tor (LA20AB to scatcyo e pump C cWJ ficwrato of 900 gallen3 par cituto as irdicatcd by Cutral Rion gauge 2 CAP 5040.
l Nggs at least 900 spa is required to verify Tech Spec surveillance.
/
12.24 If 2 CAP 5040 is defective or out-of-calibration, install a differential pressure test gauge to the pressure inputs to 2CAFT5040 and use this test instrument to monitor pump suction flowrate. Record test gauge calibration information on 3.1.
Adjust 2CA20AB to achieve a differential pressure reading of 57.7 INWD on the test gauge. This differential pressure indication correspads to a pump flowrate
)
1 of 900 gallons per minute.
/
12.25 After the 900 gallons per minute test flowrate is obtained, allow pressure and flowrate conditions to stabilise for approximately five (11
=4= tan.
Readiust_2CA20AB if necessary.
f
/
12.26 If using 2SA48 for steam supply source, verify 2SA5 wu e i
Steam Supply Check Valve) is fully open by observing normal pump operation and verifying 2SA49 ressined closed using Control Room f
indication.
I i
I PT/2/A/4252/01 Page 10 of 12 i
f 8
/
12.27 If using 2SA49 for steam supply source, verify 2SA6 (S/G 25 j
I Steam Supply Check Valve) is fully open by observing normal pump operation and verifying 2SA48 remained closed using Control Room Jndigonw_ _, m_,.,.,
. - s,
- - e-;n
/
12.28 Verify 2CA8 (Aux. Feedwater Pump No. 2 Suction Check) and 2CA22 (Aux. Teedwater Pump No. 2 Discharge to Steam Generators Check) are fully open by observing that Aux. Fesdwater Pump No. 2 is opsrating normally.
1
/
12.29 Begin recording inservice data for Auxiliary Feedwater Pump No. 2 r; cry the (5) minutes as required by F.nclosure 13.1 (Inservice Data) and Enclosure 13.2 (Bearing Temperature Readings).
/
12.30 If 2 CAP 5160 is defective or out-of-calibration, install a test gauge to the pressure input to 2CAPT5160 and use this test gauge to monitor pump discharge pressure. Record this test gauge calibration information on Enclost.re 13.1.
/
12.31 After fifteen (15) minutes of pump running time, take and record pump inboard bearing vibration readings as required by r
n
i t
Amicerur 9 V, 4.
^
TOR NORMATION ONLY-Form 34731 (1041) 1 (Formerly CPD 10021)
DUKE POWER COMPANY (1)
ID Not QTit\\@\\QQ(@Q PROCEDURE PREPARATION Change (s)_ O to PROCESS RECORD 3 Incorporated (2) STATION: f(\\t G o s ( e-(3) PROCEDURE TITLE:
RELdOM N Gnk Se fncAld I N Pch m fs
~ \\ 9 hk (4) PREPARED BY: h&O_3dh_m DATE:
MDM3N (5) REVIEWED BY: bM DATE: 07[80!8 /
Cross-Disciplinary Review By:
N/R: bat (6) TEMPORARY APPROVAL (IF MECESSARY):
By:
(SRO) Date:
By:
Date:
(7) APPROVED BY:
M<MA L /
Date:
1/VM W
(8) MISCELLANEOUS:
Reviewed / Approved By:
Date:
Reviewed / Approved By:
Dates This copy has been compared with the Control Copy and is verified correct.
Initial Date Time l
1 i
I; PT/1/A/4206/10 Page 1 of 2 DUKE POWER COMPANY MCGUIRE NUCLEAR STATION RESIDUAL NEAT REMOVAL INJECTION TEST 1.0 Purpose To full stroke exercise the following NI check valves:
INI-60, INI-82, 1NI-71, INI-94, 1NI-134, 1NI-129, INI-126, 1NI-125, INI-175, 1NI-180, INI-181, and INI-176.
2.0 References 2.1 McGuire Technical Specificationa 4.0.5 2.2 McGuire IWV Submittal 1
2.3 McGuire FSAR, Fig, 6.3.2-10 (2 of 3) 3.0 Time Required One Performance Techniciar. and one Nuclear Control Operator for two hours i
4.0 Prerequisite Tests None 5.0 Test Equipment None 6.0 Limits and Precautions Refer to the McGuire Limits and Precautions CP/0/A/6100/08 7.0 Required Unit Status Initial /Date j
3
/
7.1 Mode 4, 5, or 6 8.0 Prerequisite System Conditions
/
M 81 ;'/ /* J n /= 6 /* *S~W s-M./ 4, a a
na dia ira s' #'
9.0 Test Meth"oEl'
' # 4 d'# *^'"'W' i
ND flow will be directed through each of the three injection lines to full stroke cycle the check valves in the injection lines.
10.0 Data Required 10.1 ND flow through each injection line 11.0 Acceptance Criteria 11.1 Not leg inj. flow 1 3590 GPM 11.2 Cold les inj. flow per train 12989 GPM
l' e
PT/1/A/4206/10 Page 2 of 2 12.0 Procedure NOTE:
IV seans independent verification is required.
Icitial/Date
/
12.1 Verify in operation ND pump 18 or ND pump 1A.
12.2 Verify Open the following valves:
/
INDI5, ND RX IB Outlet Crossover Block
/
IND30, ND RX 1A Outlet Crossover Block
/
12.3 Verify Open INI173A, ND to Hdr. to NC Cold Les Loop 1 and 2
/
12.4 Verify Close 1NI183B, ND Ndr. to NC Hot Legs Isolation
/
12.5 Close 1NI1788, ND Ndr. to NC Cold Les Loops 3 and 4
/
IV
/
12.6 Verify a flow of > 3000 GPM on INDP5180 Flow =
GPM NOTE: This full atroke cycles valves 1NI175,1NI176,1NI71, and 1NI60.
/
12.7 Open INI1788, ND Ndr. to NC Cold leg Loops 3 and 4
/
IV
/
12.8 Close 1NI173A, ND Ndr. to NC Cold Legs Loops 1 and 2
/
IV
/
12.9 Verify a flow of 1 3000 GPM on INDP51t0 Tiow =
GPM NOTE: This full stroke cycles valves INI180, IN!!81, 1NI94, and 1NI82.
/
12.10 Open 1NI183B ND Ndr. to NC Hot Legs Isol.
/
IV
/
12.11 Close 1NI1788 ND Mdr. to NC Cold Les Loops 3 and 4
/
IV
/
12.12 Verify a flow of 1 3600 GPM on INDP5010.
Flow =
GPM NOTE: This full stroke cycles valves 1NI125, 1NI126, 1NI134, and 1NI129
,___/
12.13 Realign valves to the "NORMAL POSITION" on Enclosure 13.1.
13.0 Enclosures 13.1 Valve Positions i
>.- o
! 3.1 i
PT/1/A/4206/13 Valve 'tositions r
i NOTE:
IV nesas independent verification is required.
VALVE NORMAL POSITION REALIGN INITIAL INITIAL (IV) i
}
INI173A OPEN INI1788 OPEW 1
t 1N!!838 CLOSED j
i r
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Qggg Cna ge(ii o
to 0
Incorporated i
PREPAR ATION c.bu t h N J 4+ - skJ iL.
(2) STATION N!Mk UC^k b 6.~ F h
W (3) PROCEDURE TITLE _
6C 4)
I do '""ll~ A 1, (4) PREPARE 03v p 7,I N ~
7
" OATE -
G b2/P7 DATE
/*
(5) REVIEWED BY Cross 0;sciplinary Rev w By CM M
N/R.
(6) TEMPORARY APPROVAL,(If Necessary)
DATE By n'
OATE (7) APPROVED BY 9
(8) MISCELLANEOUS Reviewed / Approved By DATE Reviewed / Approved By DATE (9) COMMENTS (For procedure reissue ind,cate whether additional changes, other than previously approved nges, are included.
Attach additional pages,if necessary.)
ADDITION AL CH ANG ES INCLUDE 0, es C No (10) COMPARE 0 WITH CONTROL COPY DATE D
f l
(11) DATEIS) PERFORMED a
(12) PROCEDURE COMPLETION VERIFICATION C Yes N/A Check lists and/or blanks properly initialed, signed, dated or filled in N/A or N/R, as appropriate?
C Yes N/A Listed enclossres attached?
C Yes N/A Data sheets attached, completed, dated and signed?
C Yes C N/A Charts, graphs, etc. attached and properly dated, identified and marked?
C Yes C N'A Acceptance criteria met?
VERIFIED BY DATE (13) PROCEDURE COVPLETION APPROVED DATE _
j (14) REM ARKS ( Attach additional pages,if necessary.1 i
l!
i.
PT/2/A/4206/10 Page 1 of 3 DUKE POWER COMPANY McGUIRE NUCLEAA STATION RESIDUAL HEAT REMOVAL INJECTION TEST 1.0 Purpose To full stroke erarcise the following NI check valves:
2NI-60, 2NI-82, 2NI-71, 2NI-94, 2NI-134, 2NI-129, 2NI-126, 2NI-125, 2NI-175, 2N!-180, 2NI-181, 2NI-176 and 2ND-8.
2.0 References 2.1 McGuire Technical Specificatious 4.0.5.
2.2 McGuire IW Submittal 2.3 McGuire TSAR, Tigure 6.3.2-10 (2 of 3) 2.4 NI Check Valve Movement Test 3.0 Time Required One Performance Technician and one Nuclear Control Operator for 4
two hours.
4.0 Prerequisite Tests None i
5.0 Test Equipment None 6.0 Limits and Precautions Refer to the McGuire Limits and Precautions OP/0/A/6100/08, 7.0 Required Unit Statua
)
Initial /Date
/
7.1 Mode 5 or 6 4
i 8.0 Prerequisite Syrtee Conditions NhN, e riv S V""U'd* f'*
- frw*c.
/
Seer VI Xfh-rfisf.isfs& & ie
?L sws 6ss. es.*
- s cy i exs. g :. n 9.0 Test Method)o ND flow will be directed through each of the three injection lines to full stroke cycle the check valves in the injection lines, j
10.0 Data Required 10.1 ND flow through each injection line 11.0 Acceptance Criteria 11.1 Hot les injection flow 1 3590 GPM 11.2 Cold leg injection flow per train 12989 GPM
\\\\
('
PT/2/A/4206/10 Page 2 of 3 12.0 Procedure NOTE:
IV means independent verification is required.
Initial /Date
/
12.1 Verify in operation ND Pump 25.
/
12.1.1 If necessary shut down N3 Pump 2A.
12.2 Verify OPEN the following valves:
/
2ND15, ND HX 23 Outlet Crossover Block
/
2ND30, ND HX 2A Outlet Crosscver Block
/
12.3 Verify OPEN 2NI173A, ND to Hdr. to FC Cold Les Loop 1 and 2.
/
12.4 Verify CLOSE 2NI1835, ND Edr. to NC Mot Legs Isolation.
/
12.5 Verify CLOSE 2N!1788, ND Ndr. to NC Cold Les Loops 3 and 4.
/
IV
/
12.6 Verify CLOSE 2ND29, ND Pump 2A Discharge Isolation.
Verifyaflowof13000GPMon2h5180.
01
/
12.7 Flow =
GPM NOTE: This full stroke cycles valves 2NI-175, 2NI-176, 2NI-71, and 2NI-60.
/
12.8 OPEN 2NI1785, ND Ndr. to NC Cold Les Loops 3 and 4.
/
IV
/
12.9 CLOSE 2NI173A, ND Ndr. to NC Cold Lega Loops 1 and 2.
/
IV Verifyaflowof13000GPMon2Nh5190.
/
12.10 y
Flov =
GPM NOTE: This full stroke cycles valves 2NI-180, 2NI-181, 2NI-94 j
l' and 2NI-82.
/
12.11 OPEN 2NI1835, ND Mdr. to NC Hot less Isol.
/
IV
/
12.12 CLOSE 2NI1785, ND Ndr. to NC Cold Les Loops 3 and 4.
t
/
IV Q
- c. m -
/
12.13 Verify a flow of 1 3600 GPM on 2N/P5010. $ '
,g Flow =
GPM NOTE: This full stroke cycles valves 2NI-125, 2NI-126, 2NI-134, 2NI-129 and 2ND-8.
l
/
.2.14 R'.*aliga valves to the "NORMAL POSITION" on Enclosure 13.1.
I
tr t
PT/2/A/4206/10 Page 3 of 3 13.0 Enclosures 13.1 Valve Positions 9
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PT/2/A/6206/10 l
Page 1 of 1 i
Inclosure 13.1 Valve Positions i
NOTE:
IV essas independent verification is required.
1 REALIGN VALVE NORMAL POSITION INTITIAL INITIAL (IV) l 2NI173A OPEN i
2Nt1783 OPEN i
2NI1833 CLOSED i
l j
i i
W l
1
)
)
1 j
i j
)
i 1
i 1
i 4
o McGUIRE NUCLEAR STATION VALVE DESIG.1 BASIS SHEETS 1
0 4
4 d
1 i
1 l
VALVE:
CA3 POSITION:
Normally open, upset open.
DESCRIPTION:
Auxillary Feedwater Pumps Supply from Upper Surge Tanks (UST) Discharge Check Valve.
DESIGN BASIS:
Required to provide proper direction of flow when the Hotwell pumps are used to fill the UST. This valve does not provide a safety function.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
IWV backseat testing is not required.
REV: 0, JULY '88.
l
VALVE:
CA4 i
POSITION:
Normally open, upset open.
(
DESRIPTION:
Auxillary Feedwater Pump Supply from Upper Surge Tanks (UST) Discharge Isolation Valve.
DESIGN BASIS:
'Used to isolate the UST as a backup to check valve CA3, to provide proper flow direction alignment when using the Hotwell pumps to fill the UST.
d SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
IWV testing is not required.
REV. O, JULY '88.
e i
l l
VALVE:
CAS POSITION:
Normally closed, upset open.
DESCRIPTION:
Auxiliary Feedwater Pumps Snoply AFW Condensate Storage Tank Dise.iarge Check Valve.
DESIGN BASIS:
Required to provide proper direction of f-)w when the Hotwell pumps are used to fill the Upper Surge Tank. This valve does not provide a safety function.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
IWV backseat testing is not required.
REV. O, JULY '88.
o
VALVE:
CA6 POSITION:
Normally closed, upset open.
DESCRIPTION:
Auxiliary Feedwater Pump Supply from AFW Condensate Storage Tank Discharge Isolation Valve.
-DESIGN BASIS:
Used to open the suction source from AFW Condensate Tank to the AFW Pumps when the normal supply (Upper Surge Tank) ?as been depleted. This is not the safety grado suction source for the AFW pumps.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
IWV testing is not required.
REV. O, JULY '88.
d y ~, 3
~w y
-,,.e--
--n~
w r
- - - -- - e
r---
- -~ -
VALVE:
CA151 POSITION:
Normally closed, upset closed.
DESCRIPTION:
Auxiliary Feedwater' Pump Suction Test Loop Check Valve.
DESIGN BASIS:
Valve CA151 does not perform a safety function since the line is isolated during normal unit operation by manual valve CA152. Operator action can be taken to open CA152 during abnormal conditions. During those abnormal conditions, CA151 should open to provide an additional suction path from the Upper Storage Tank; however, if CA151 did not open, a safety function would not be compromised.
SEISMIC EVENT:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
This valve is Category C, Passive and does not require testing per IWV.
REV. O, JULY '88.
I
VALVE:
KCS, KC8, KC11, KC14 POSITION:
Normally open, upset open.
DESCRIPTION:
Component Cooling Pump Discharge Check Valves.
DESIGN BASIS:
These valvos are required to close when operators manually start pumps one at a time to prevent gross flow diversion.
During a Design Basis Event their safety function is-to open only.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
If one pump failed during a Design Basis Event, then the entire train would be ineffective since two pumps per train are required to obtain the required flow to the RHR Hx train.
TESTING:
These valves are Category C, Active and are required to be movement tested'per IWV.
REV. O, JULY '88.
~
i l
e VALVE:
KC305B, KC3158 POSITION:
Normally closed, upset closed.
DESCRIPTION:
Component Cooling (KC) Supply to Excess Letdown Hx Outside Containment Isolation.
DESIGN BASIS:
Although the safety function of these valves is to provide containment isolation during a Design Basis Event, this penetration is passive during normal operation. The piping and equipment internal to the outer isolation valve is designed ASME III Class 2, and terminates in a closed seismic valve and in a closed loop.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
These valves are Category B, Active and are required to be tested per IWV.
These valves are exemp from Type C leak testing per the SRP and BTP CSB 6-3.
REV.
O, JULY '88.
j 4
I VALVE:
KC972 POSITION:
Normally closed, upset open.
DESCRIPTION:
Component Cooling (KC) Surge Tank Relief Valvt.
DESIGN BASIS:
The function of this valve is to provide over-pressurization protection for the KC Surge Tank due to a ruptored Reactor Coolant Pump thermal barrier.
The original thermal barrier overpressure protection design allowed on each RCP and an automaticvalve which isolated each thermal barrier on exess flow. With the latest design, this new relief valve provides more relief capvsit.
Although this is an important protective feature, it does not provide a safety function for a Design Bases Event.
KC972 is isolated by the non-essential header automatic isolation valves on a safety signal.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
This valve is Category C, Passive and does not require testing per IWV; however, it should be tested periodically as good operational /
maintenance practices.
In addition, j
since North Carolina is an ASME Code state, periodic bench testing is required.
REV. O, JULY '88.
i i
a i
VALVE:
ND18, N02AC POSITION:
Normally closed, upset closed.
DESCRIPTION:
Reactor Coolant System / Residual Heat Removal (ND) System Isolation Valves.
DESIGN BASIS:
These valves provide the boundary isolation between the RCS and the ND systems and remain closed during normal operation. These valves provide a containment function.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
These valves are classified Category A, since they are RCS pressure boundary valves.
Due to NRC concern for a potential Loss of Coolant Accident (LOCA) outside containment, we are now required by Technical Specification 3.4.6.2 (as specified in Table 3.4-1) to be leak testing these and other primary pressure boundary isolation valves.
These valves are exempt from Appendix J, Type C leak testing per the SRP and i
BTP CSB 6-3.
Type C penetration test i
does not apply since it is inappropriate to drain this penetration for pneumatic testing.
REV, 0, JULY '88.
o VALVE:
Nill POSITION:
Normally closed, upset closed.
DESCRIPTION:
Cold Leg injection from the Centrifugal Charging Pumps, Check Valve Test Header Inside Containment Isolation Valve.
DESIGN BASIS:
This valve is opened for Reactor Coolant System pressure boundary check valve testing during unit startup.
However, it is a normally closed, fail closed air operated valve whose safety function is to remain closed during a Design Basis Event.
SEISMIC CONCERN:
The piping downstream of Nill is designed to RCS temperature and pressure but is not seismically designed; however, a 3/8 inch restricting orifice is located at the branch off of the main 3 inch header upstream of this valve to prevent excessive loss of injection fluid if the piping downstream of Nill were to break during a seismic event with the valve leaking or spuriously open. The flow orifice will maintain fluid loss to a minimum such that the safety injection system can perform its intended function.
SINGLE FAILURE:
N/A.
TESTING:
This valve is Category B, Passive and does not require testing per IWV, since valves used for testing are exempt.
'This penetration is exempt from Appendix J Type C leak testing per the Standard Review Plan and BTP CSB 6-3.
REV.
O, JULY '88.
VALVE:
NI12 POSITION:
Ncrmally closed, upset open.
DESCRIPTION:
Cold Leg Injection from the Centrifugal Charging Pumps Inside Containment Isolation Check Valve.
DESIGN BASIS:
The safety function of this valve is to open to provide flow to the cold legs during a Design Basis Event. This valve would not release containment atmosphere durimg a Loss of Coolant Accident even if valve leakage did occur. The piping and equipment external to the outer isolation valve are seismically designed.
The system is designed to ASME III Class 2 standards and designed to atleast primary containment pressure and temperature. The piping is protected from pipo whip, missiles, and jet forces.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
This valve is Category C, Active and should be exercise tested per IWV.
This penetration is exempt from Type C leak testing by the Standard Review Plan and BTP CSB 6-3.
REV.
O, JULY '88, 1
1 I
l
VALVE:
NISO,.NI61, NI72, NI83, NI84 POSITION:
Normally closed, upset closed.
DESCRIPTION:
Cold Leg Accumulation (CLA) Nitrogen Vent Path Isolation Valves.
DESIGN BASIS:
These valves are required when pressurizing or depressurizing the CLA's.
They are air operated, fail closed valves whose safety function is to remain closed during a Design Basis Event.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
These are Category 8, Passive valves and do not require testing per IWV.
REV. O, JULY '88.
)
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'O O
VALVE:
NI54A, NI65B, NI76A, NI88A POSITION:
Normally open, upset open.
DESCRIPTION:
CLA Discharge Isolation Valves.
DESIGN BASIS:
These are active valves whose safety function is to remain open during a Design Basis Event. Technical Specifications require these valves to be open and power removed during normal operation. Automatic closure of these valves is not required, but they are required to be closed during a small break LOCA. These valves do receive IE power and are required to be repositioned during normal and abnormal shutdowns.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
These valves are Category B, Active and are required to be exercise tested per IWV.
REV. O, JULY '88.
i 4
)
i 4
VALVE:
NI121A, NI152B POSITIVE:
Normally open, upset open.
DESCRIPTION:
Safety Injection Hot leg Isolation Valve.
DESIGN BASIS:
The safety. function of this valve is to be remote manually opened by operators after a Loss of Coolant Accident to realign the Safety Injection System to the Hot Leg Recirculation Mode of
.0peration. Although these valves are containment isolation valves, they do not provide an automatic containment isolation function.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
These valves are Category B, Active and are required to be exercise tested per IWV. These valves are exempt from Type C testing per the Standard Review Plan and BTP CSB 6-3.
REV.
O, JULY '88.
VALVES:
NI1228 POSITION:
Normally closed, upset closed.
DESCRIPTION:
Hot Leg Injection from the Safety Injection Pumps, Check Valve Test Header Inside Containment Isolation Valve.
DESIGN BASIS:
This valve is_ opened for Reactor Coolant System pressure boundary. check valve testing during startup.
- However, it is closed during normal operation with power removed.
Its safety function is to remain closed during a Design Basis Event, and it does not perform an automatic Containment Isolation function.
SEISMIC CONCERNS:
The piping dowrstream of NI122B is designed to RCS temperature and pressure but is not seismic; however, 3/8 inch restricting orifices are located at the branch off of the main header to prevent excessive loss of injection fluid such that the Safety Injection System can perform its intended function.
SINGLE FAILURE:
N/A.
TESTING:
This valve is Passive and does not require testing per IWV.
This penetration is exempt from Appendix J, Type C leak testing per the Standard Review Plan and BTP CSB 6-3.
REV. O, JULY '88.
e VALVE:
NI162A POSITION:
Normally open, upset open.
DESCRIPTION:
Cold Leg Injection from the Safety Injection Pumps, Outside Containment Isolation Valves.
DESIGN BASIS:
This valve is opened during unit startup and power is removed per Technical Specifications to insure that the valve is aligned to its safety position. This valve is not required for automatic containment isolation closure to perform a safety function.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
This valve is Category B, Active and does require exercise testing per IWV.
It is exempt from Appendix J, Type C leak testing per the SRP and BTP CSB 6-3.
However, this is an active valve which must be repositioned (closed) for Hot Leg Recirculation.
REV.
O, JULY '88.
C VALVE:
NI163 POSITION:
Normally closed, upset closed.
DESCRIPTION:
Cold Leg Injection from the Safety Injection Pumps, Check Valve Test Header Inside Containment Isolation Valve.
DESIGN BASIS:
This valve is opened for Reactor Coolant System pressure boundary check valve testing during unit startup.
However, it is a normally closed, fail closed air operated valve whose safety function is to remain closed during a Design Basis Event.
SEISMIC CONCERNS:
The piping downstream of NI163 is designed to RCS temperature and pressure but is not seismically designed; however, a 3/8 inch restricting orifice is located at the branch off of the main 4 inch header upstream of this valve to prevent excessive loss of injection fluid if the piping downstream of N1163 were to break during a seismic event with the valve leaking or spuriously open.
The flow orifice will maintain fluid loss to a minimum such that the Safety Injection System can perform its intended function.
SINGLE FAILURE:
N/A.
TESTING:
This valve is Category B, Passive and does not require testing per IWV; since valves used for testing are exempt.
This penetration is exempt from
' Appendix J, Type C leak testing per the Standard Review Plan (SRP) and BTP CSB 6-3.
REV.
O, JUYL '88.
o 0:
l VALVE:
N1173A, NI178B POSITION:
Normally open, upset open.
DESCRIPTION:
Cold Leg Injection from the Residual Heat Removal Pumps, Outside Containment Isolation Valves.
DESIGN BASIS:
The valves are coened during unit startup and powei is removed per Technical Specification to insure that the valves are aligned to their safety position. Thesa valves are not required for automatic containment isolation closure to perform a safety function.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
i TESTING:
These valves are Category B, Active and do require exercise testing per IWV.
It is exempt from Appendix J, Type C leak testing per SRP and BTP CSB 6-3.
However, they are active valves which must be repositioned (closed)-for Cold Leg Recirculation and/or Auxiliary Containment Spray.
REV.
O, JULY '88.
i
VALVE:
NI174, NI179 POSITION:
Normally closed, upset closed.
DESCRIPTION:
Cold Leg Injection from the Residual Heat Removal Pumps, Check Valve Test Header Inside Containment Isolation Valves.
DESIGN BASIS:
These valves are opened for Reactor Coolant System pressure boundary check valve testing during unit startup.
However, they are normally closed, fail closed air operated valves whose safety function is to remain closed during a Design Basis Event.
SEISMIC CONCERNS:
The piping downstream of NI174 and NI179 is designed to RCS temperature and pressure but is not seismic; however, 3/8 inch restricting orifices are located at the branch off of the main 4 inch headers upstream of these valves to prevent excessive loss of injection fluid if the piping downstream of N!174 and NI179 were to break during a seismic event with the valves leaking or spuriously open. The flow orifices will maintain fluid loss to a minimum such that the Safety Injection System can perform its intended function.
SINGLE FAILURE:
N/A.
TESTING:
These valves are Category B, Passive and do not require exercise testing per IWV.
These penetrations are exempt from Appendix J, Type C leak testing
'per the Standard Review Plan (SRP) and BTP CSB 6-3.
REV.
O, JULY '88.
c; D
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VALVES:
NI1848, NI185A i
POSITION:
Normally closed, upset closed.
DESCRIPTION:
Containment Sump Recirculation Outside Containment Isolation Valves.
DESIGN BASIS:
These valves are closed at the initiation of a Design Basis Event and required to remain closed until after the determination is made that Cold Leg i
Recirculation is eminent. Valves i
NI1848 and NI185A are active valves since they must be repositioned (opened) for Cold Leg Recirculation.
These valves are interlocked with the Residual Heat Removal / Refueling Water Storage Tank Suction Isolation Valves to receive an open signal only after ND4B and ND19A are open.
These valves are not required for automatic containment isolation closure to perform a safety function.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
These valves are Category B, Active and do require exercise testing per IWV.
j Therefore, they are exempt from AppenJix J, Type C leak testing per the SRP and BTP CSB 6-3.
REV. O, JULY '88.
l I
VALVE:
NS12B, NS158, NS29A, NS32A, NS388, NS43A POSITION:
Normally closed, upset open.
DESCRIPTION:
Containment Spray (NS) 9 ump Discharge and Conta$nesnt Isolation Valves.
DESIGN BASIS:
The safety function of these valves is to open for initiation of containment spray during a Design Basis Event. The closing of these valves is not a safety function.
The piping and equipment external to the outer isolation valves are seismically designed and terminate in a closed loop system; designed to ASME III Class 2 to at least prinary containment pressure and temperature; and protected from pipe whip, missles and jet forces.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
These valves are Categoy B, Active and are required to be exercised per IVW.
The Standard Review Plan allows
~
exemption from leak testing this penetration.
REV.
O, JULY '88.
j I
i j
VALVE:
NV12 POSITION:
Normally open, upset closed.
DESCRIPTION:
Reactor Coolant Punp Charging Header Containment Isolation Check Valve.
DESIGN BASIS:
The function of this valve is to provide proper flow direction when using the ND System (Residual Heat Removal) for letdown and purification of the RCS. Normal charging is isolated in a Design Bases Event by redundent valves NV244A anu NV2458, the outside isolation valves located upstream of NV12, in order that flow provided by the Centrifical Charging Pumps is directed to the cold leg injection lines.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
This valve should be Category C, Active and does not need to be tested per IWV.
This penetration is exempt from Appendix J Type C leak testing per SRP and BTP CSB 6-3.
REV.
O, JULY '88.
I 4
f f
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VALVE:
NV14, NV15, NV17, NV18 POSITION:
Normally open, upset closed.
DESCRIPTION:
Reactor Coolant System Charging Header Check Valves.
DESIGN BASIS:
These valves are RCS boundary isolation check valves.
Their function is to prevent gross RCS leakage if charging is inadvertently terminated. These valves are not required to be leak tested as RCS boundary isolation valves because they are not required to close unless charging flow is terminated, the valves which provided the safety function for RCS boundary isolation are NV244A and NV2458. The NV system is designed as Class 2 for RCS temperature and pressure up to and including NV244A and NV245B. NV244A and NV245B are closed by the same safety signal which open the safety injection chargt.;g path to the RCS cold legs.
SEISMIC CONCERNS:
N/A SINGLE FAILURE:
N/A.
TESTING:
These valves are Category C, Active and they should be backseat tested.
These are exempt from testing as RCS pressure boundary valves per Technical Specifications.
REV. O JULY '88.
\\
1 i
q VALVE:
NV20 i
POSITION:
Normally' closed, upset open.
DESCRIPTION:
Regenerative Heat Exchange Relief Check Valve.
DESIGN BASIS:
The function of this valve is to provide thermal overpressure protection
-for the Regenerative HX if the charging flow were inadvertently isolated without isolating letdown flow. These valves do perform a safety function to shutdown the reactor or to mitigate the consequences of an accident.
SEISMIC CONCERNS:
Since the piping and valve are designed to ASME III Class 2, there are no seismic concerns.
s SINGLE FAILURE:
N/A.
TESTING:
This valve is Category C, Passive and should be exercised tested per IWV.
REV. O, JULY '88.
1 1
. _ ~, _, - - -. _
m
VALVE:
NV29, NV45, NV61, NV77 POSITION:
Normally open, upset closed.
DESCRIPTION:
NC Pump Seal Supply Containment Isolation Check Valve.
DESIGN BASIS:
These are containment penetration isolation valves; however, this penetration is never isolated during normal operation or accident operation, since NC pump seal flow must be maintained while pumps are running and during an accident to maintain the No.
i 1 Seal integrity. Therefore, these valves do not perform a safety function for Design Basis Events.
During an Appendix R fire, these valves must prevent flow diversion of the Standby Makeup Pump seal supply flow.
Although this is not a Design Basis Event, these valves do perform a reverse flow function.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
Appendix R fire will destroy emergency 1E power to both NV (CCP's) pumps.
TESTING:
Since the NV System is all Class 2 piping outside containment, these valves are not required to be tested per IWV.
This penetration is exempt i
from Appendix J, Type C leak testing i
l Because of the Standby Makeup Pump i
. design capacity, these valves should be backseat tested as good operational / maintenance practice.
REV. O, FEB. '88.
REV. 1, JULY '88.
VALVE:
NV94AC, NV958 POSITION:
Normally open, upset closed.
DESCRIPTION:
Reactor Coolant Pump (RCP) Sea 1 water Return Discharge Header Isolation Valves.
DESIGN BASIS:
The safety function of these valves is to isolate the RCP Sealwater Return to the Volurne Control Tank (VCT). The VCT does not provide the suction source for the Centrifugal Charging Pumps, high I
head safety injection pumps, during a Design Basis Event and the RCP sealwater supply is not isolated; therefore since the VCT can not provide holdup for continuous sealwater return, valves NV94AC and NV95B provide redundant isolation.
Because of the convenience of the phase A containment isolation signal, that signal is used to isolate flow to the VCT which has l
cverflow capacity in the Recycle Holdup Tank (RHT).
These valves do not perform a containment isolation function for the purpose of preventing bypass leakage.
SEISMIC CONCERNS:
These valves are seismically designed.
SINGLE FAILURE:
This design is such that for a single failure of either valve, the other valve will perform the intended safety function.
TESTING:
These valves should be tested per IWV as Category B, Active and should be
' exercise tested per IWV.
This penetration is exempt from i
Appendix J, Type C leak testing per the SRP and BTP CSB 6-3.
REV. O, JULY '88.
i i
VALVE:
NV218 POSITION:
Normally open, upset closed.
DESCRIPTION:
Reciprocating Charging Pump Discharge Check Valve.
DESIGN BASIS:
Required to provide reverse flow when the pump piston is on the inlet stroke.
Also, it is required to prevent gross flow diversion during an accident where the NV (CCP's) safety pumps are required to supply flow to the cold i
legs through the CCP injection path.
SEISMIC CONCERNS:
N/A.
i SINGLE FAILURE:
During an accident, a single failure would not compromise the CCP's safety function since the RCP with its piston j
would also act as a check;.therefore, i
no credit for gross flow diversion would have to be assumed.
i i
TESTING:
This valve is Category C, Active but is j
not required to be tested per IWV, because of the reasons stated above.
REV. O, FEB. '88.
REV. 1, JULY '88.
4 4
a
VALVE:
NV241 POSITION:
Normally open, upset open.
DESCRIPTION:
Charging Flow Control Valve.
DESIGN BASIS:
This valve provides flow control for the Reactor Coolant System charging.
The safety position for this valve is to fail open on loss of power during normal operation; however, it does not provide <t safety function during a Design Basis Event.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
This valve is not required to be tested per IWV.
REV. O, JULY '88.
4 I
I 1
2 4
i
-i i
i
<b VALVE:
NV264 POSITf0N:
Normally closed, upset open.
~
DESCRIPTION:
Boric Acid Tank Discharge Check to Centrifugal Charging Pumps.
DESIGN BASIS:
This valve provides duel functions.
It is normally closed and backed up by a normally closed motor operated valve to insure proper flow direction from various suction sources for'the CCP's.
This valve does not perform a safety function in the closed position.
i However, it is required to open to satisfy the intent of BTP RSB 5-1, which requires the capability to go'to cold shutdown using only safety grade systems.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
This valve is Category C, Active and is required to be exercised tested per IWV.
REV. O, JULY '88.
e l
I l
\\
i
s
- n 1
I r
VALVE:
NV2658 POSITION:
Normally closed, upset open.
e DESCRIPTION:
Boric Acid Tank Discharge Isolation to the Centrifugal Charging Pumps Suction
- Valve, DESIGN BASIS:
In the closed position this valve isolates the BAT from the suction of the CCP's where several water sources are available. This valve does not provide an active safety function in the open position.
However, it receives 1E power and is required to open to satisfy the int 6nt l
of BTP RSB 5-1, which requires the
)
capability to go to cold shutdown using only safety grade systems.
SEISMIC CONCERNS:
N/A.
t SINGLE FAILURE:
N/A.
TESTING:
This valve is Category 8, Active and is required to be exercise tested per IWV.
REV. O, JULY '88.
u 4
l
)
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a l
VALVE:
NV267A t
POSITION:
Normally closed. upset closed.
DESCRIPTION:
Boric Acid Tank Olscharge Isolation to-Boric Acid Blender Valve.
DESIGN BASIS:
This valve isolates the BAT to the BA Blender where several flow paths are available.
However, it recei'fes 1E power and is required to open to satisfy the intent
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of BTP RSB 5-1, which requires the l
capability to go to cold shutdown using i
only safety grade systems.
SEISMIC CONCERNS:
N/A.
SINGLE:
N/A.
TESTING:
This valve is Category B, Active' i
and is to be exercise tested per IWV.
REV. O, JULY'88 l
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, VALVE:
NV411, NV413 POSITION:
Normally closed, upset closed or open.
DESCRIPTION:
Boric Acid Tank Discharge to the Centrifugal Charging Pumps Suction Check Valves.
DESIGN BASIS:
These valves isolate the BAT from the suction of the CCP's and prevents gross flow reversal. There are normally closed manual valves which backup each 1
These valves do not provide a safety function in the closed position.
However, they are required to open to I
satisfy the intent of BTP RSB 5-1, which requires the capability to go to cold shutdown using only safety grade i
systems.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
These valves are Category C, Active and required to be exercise tested per IWV.
REV. O, JULY '88.
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6 VALVE:
NV457A, NV458A, NV459A, and NV7B POSITION:
Normally open, upset closed.
DESCRIPTION:
Reactor Coolant System (RCS) Letdown Containment Isolation Valves.
DESIGN BASIS:
The safety function of these valves is to isolate the RCS pressure boundary during a Design Basis Event to limit the loss of reactor coolant to just the initial break location. The Contifugal Charging Pumps will be refilling and/or repressurizing the RCS in order to prevent the core from being uncovered.
Because of the convenience of the phase A containment isolation signal, that signal is used to isolate flow to the VCT which has limited overflow capacity in the Recycle Holdup Tank.
These valves do not perform a containment isolation function for the purpose of preventing bypass leakage.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
This design is such that for a single failure of either valve, then the other valve will perform the intended safety function.
TESTING:
These valves are Category B, Active and should be exercise tested per IWV.
This penetration is exempt from Appendix J Type C leak testing per the SRP and BTP CSB 6-3.
REV. O, JULY '88.
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l VALVE:
NV472 i
POSITION:.
Normally closed, upset open.
h DESCRIPTION:
Boric Acid Tank Header Discharge Check Valve to the Boric Acid Blender.
DESIGN BASIS:
This valve provides duel functions.
It is normally closed and is backed up by e
a normally closed valve to. insure-proper flow direction and prevent undesired flow to the BAT. '
This valve does not perform a. safety function for a Design Basis Event, however, it is required to open to satisfy the intent of BTP CSB 5-1, which requires the capability to go to cold' shutdown using only safety grade systems.
SEISMIC CONCERNS:
N/A.
1 v
SINGLE FAILURE:
N/A.
l TESTING:
This valve is Category C, Active and is required to be exercise tested per IWV.
4 REV. 0,-JULY '88.
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VALVE:
NV841 POSITION:-
Normally closed, upset closed.
DESCRIPTION:
NO Pump Spray Header Inside Containment Isolation Check Valve.
DESIGN BASIS:
The function of this valve is for the Reactor Coolant System boundary isolation and containment isolation.
Since this valve is-located on the NO Pump / Auxiliary spray line, which is isolated during normal operations, it is normally closed and does not have a safety function to close.
The penetration is passive during normal operation and the outside containment isolation valve NV840 is isolated and power is removed.
SEISMIC CONCERNS:
N/A, SINGLE FAILURE:
N/A.
TESTING:
This valve is a Category C, Passive valve and is not required to be tested per IWV.
REV. O, JULY '88.
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D VALVE:
NV1044, NV1046 POSITION:
Normally closed, upset closed.
DESCRIPTION:
Reciprocating Charging Pump FWST Suction Header Check Valve.
DESIGN BASIS:
These valves are used to prevent gross flow diversion to the FWST if the Reciprocating Pump is not operating but the Volume Control Tank and/or the pump suction becanas r assurized.
In the present configuration, the Positive Displacement pumps are isolated using the manual valve NV1043.
These valves do not perform safety functions.
I SEISMIC CONCERNS:
N/A.
t h
SINGLE FAILURE:
N/A.
r TESTING:
These valves do not require testing par IWV.
REV. O, JULY '88.
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VALVE:
RN28, RN30 POSITION:
Normally open, upset open.
DESCRIPTION:
Nuclear Service Water (RN) Pump Discharge Check Valve.
DESIGN BASIS:
These valves provide a safety function in the open position for discharge of cooling water to Essential RN Header.
These valves do not provide a safety function in the closed position because the pumps are isolated from each other during a Design Basis Event by valves RN40A and RN41B which provide both train separation and isolation of the l
Non-essential Header.
i SEISMIC CONCERNS:
N/A.
$1NGLE FAILURE:
N/A.
i TESTING:
These valves are Category C, Active and require exercise testing per IWV.
REV. O, JULY '88.
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d VALVE:
SV25, SV26, SV27, SV28 POSITION:
Normally open, upset open.
DESCRIPTION:
Steam Generator PORV ! solation Valves.
DESIGN BASIS:
These valves do not receive safety (IE) power and do not perform a safety function during a Design Basis Event.
They provide isolation capability during normal operation for plant reliability only.
SEISMIC CONCRENS:
N/A, SINGLE FAILURE:
N/A.
TESTING:
These valves do not require testing per IWV.
REV. O, JULY '88.
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- v VALVE:
VESA, VE6B POSITION:
Normally closed, upset closed.
DESCRIPTION:
Containment Vessel Hydrogen Purge Out Isolation Valves.
DESIGN BASIS:
These valves are containment vessel isolation valves which provide isolation between inside the containment vessel and the annulus.
The valves are not piped or connected through the reactor building to a piping system outside containment.
Therefore, a through containment bypass leakage path does not exist. These are not containment isolation valves.
SEISMIC CONCERNS:
The piping, which penetrates the containment vessel, between the inside containment vessel isolation valve VESA and outside containment vessel isolation valve VE6E is designed as ASME III Class 2.
However, the piping on either side of these valves, both in the annulus and inside the containment vessrl, is non safety class (non-seismic).
SINGLE FAILURE:
N/A.
TESTING:
These valves should be tested per IWV as Category B. Because secondary containment design, this penetration is exempt from Appendix J. Type C leak testing per the SRP and BTP CSB 6-3.
REV: 0, JULY '88.
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VALVE:
WL1301B, WL1302A POSITION:
Normally closed, upset closed.
DESCRIPTION:
Post Accident Liquid Sample Return to Containment Inside and Outside Containment Isolation Valves.
DESIGN BASIS:
Required per TMI upgrades for return of post accident primary system samples back to containmen'. This modification was coordinated with the deletion of the Upper Head Injection System (VHI) so that the UHI check valve test header containment penetration could be reused for the WL System penetration.
Valve NI264B has been deleted, valve NI267A has been changed to WL1302A, and valve-NI264B has been changed to WL13018.
These new WL valves provide the safety function of Containment Isolation Phase A isolation during a Design Basis Event.
SEISMIC CONCERNS:
Since piping and equipment external and internal to these valves are not designed to ASME III, these penetration isolation valves provide the primary containment boundary.
SINGLE FAILURE:
These valves and piping between them are designed redundant, seismic (ASME
!!! Class 2) and to at least primary containment pressure and temperature in order to satisfy single failure criteria.
TESTING:
These valves are Category A, Active and must be both Type C leak tested as well
'as exercise tested as required per IWV.
REV. O, JULY '88.
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VALVE:
WN3, WN5, WN11, Wh13 POSITION:
Normally closed, upset open.
DESCRIPTION:
Olesel Generator High Capacity Room Sump Pump Discharge Check Valves.
DESIGN BASIS:
These valves must provide a safety function to open in order to discharge sump water, which is postulated to enter the sump due to a cooling water line rupture.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
If a single failure of one of the sump pemps were to occur, these valves also provide the safety function to close to ensure that water will discharge through the header and not run back into the sump. They are required for gross flow diversion only.
TESTING:
These valves are Category C, Active and require movement tssting per IWV IWV backseat testing or alternate testing is required.
REV. O, JULY '88.
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i VALVE:
WN7, WN15 POSITION:
Normally closed, upset open.
DESCRIPTION:
Diesel Generator low Capacity Room Sunp Pump Discharge Check Valves.
DESIGN BASIS:
These valves must open to provide their intended non-safety function to discharge water which will enter the sump during maintenance activities.
However, these non-safety related pumps are tied together with the safety related pumps; therefore, they do provide a safety' function in the closed position to prevent gross flow diversion.
SEISMIC CONCERNS:
N/A.
SINGLE FAILURE:
N/A.
TESTING:
These valves are Category C, Passive and do not require testing per IWV.
However, backseat testing or alternate testing'is required.
REV. O, JULY '88.
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