ML20151M789
| ML20151M789 | |
| Person / Time | |
|---|---|
| Site: | Vermont Yankee File:NorthStar Vermont Yankee icon.png |
| Issue date: | 07/28/1988 |
| From: | Cappuccio G, Kinsey J, Trask T VERMONT YANKEE NUCLEAR POWER CORP. |
| To: | |
| Shared Package | |
| ML20151M786 | List: |
| References | |
| PROC-880728, NUDOCS 8808080005 | |
| Download: ML20151M789 (104) | |
Text
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l INSERVICE TESTING PROGRAM 1
FOR VERMONT YANKEE NUCLEAR POWER CORPORTION Revision 9
- Description, Program, Testing Schedules and Relief Requests Prepared by: _.[mM- C. Ia//
T. C. Trask, A ant Inservice Testing Coordinator f '
' n Lc'lj J. C/K'insey.
/ Assistant,,Pfant
' Inservice Testing Coordinator Reviewed by: > #1/ h ,_, / / 6 G. Ca ccio((eniorMechanicalEngineer / Date li. b, :.,: 5 (f /7/>n'f%b H. M. Metell, Engineering Support Supervisor / Date Q/ h,L"f pLf @W / 7ks/M Plant Operations Review Committee / 0'a t e '
L Approved by: eta- / 7/2.4/f8' J. PVPelletiff4 Plant Manager / 'date '
W. P hM A1 rphy
/ 5YY Y ger of Operations / [ fate '
The Inservice Testing Progam was a section of the Inservice Inspection Program for Revisions 0 through 8.
8808080005 000728 (Q i PDR ADOCK 05000271 ; Rev. 9 G PNU ;dr
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INSERVICE TESTING PROGRAM RECORD OF CHANGES INITIALS INITIALS .
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CHANGE DATE CHANGE DATE NUMBER ENTERED PORC PL MGR M00 NUMBER ENTERE0 PORC PL MGR M00 I i
9 7/29/88 i E
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INSERVICE TESTING PROGRAM Table of Contents.
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A. General Page(s)
Preface v References vi B. Drawings D-1 C.Section I - Pump Testing Program Scope P-1 Quantitative Values P-1 Symbols p.1 Pump Listing p.2 Relief Request Bases:
RR8 No. P1-P6 P-3 to P-8 RRB No. GP GP-3 P-9 to P-15 Notes P-16 Table 1 - Quantitative Values P-17 D.Section II - Valve Testing Program Scope V-1 Quantitative Values V-1 Symbols and Definitions V-1 to V-3 Valve Listings V-4 to V-29 Service Water Reactor Building Closed Cooling Water -
Recirculation Pump Service and Instrument Air Diesel Fuel Oil Nuclear Boiler iii Rev. 9
a a Taole of Contents (Cont.)
Valve Listings (Cont.) Page(s)
Core Spray High Pressure Coolant Injection Control Rod Drive Hydraulic.
Standby Liquid Control Residual Heat Removal Fuel Pool Cooling Reactor Core Isolation Cooling i Primary Containment and Atmosphere Corstrol Radwaste Reactor Water Cleanup System HVAC - Reactor Building Nuclear Boiler Vessel Instrumentation Containment Atmosphere Dilution l TIP Relief Request Bases RRB No. VI to V29 V-30 to V-61 RRB No. GV-1 to GV-3 V-62 to V-70 Notes y-71 1 Table 1 - Quantitative Values V-72 to V-74 Table 2 - Valves Tested During Cold Shutdown V-75 to V-80 l
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PREFACE The program presented herein is written to comply with the requirements of 10 CFR 50.55a(g) published in the Code of Federal Regulations dated January 1,.1982.
The applicable Code edition and addenda is the ASME Boiler and Pressure Vessel Code,Section XI, 1980 Edition through and including the Winter 1980 Addenda.
In accordance with 10 CFR 50.55a(g), the 120 - month inspection interval is as follows:
Start Date End Date November 30, 1982 November 30, 1992 v Rev. 9
e O REFERENCES
- 1. 10 CFR 50.55a(g).
- 2. Vermont Yankee Technical Specifications, Section 4.6 (as revised by :
Admendment 99).
- 3. ASME Boiler and Pressure Vessel Code, 1980 Edition, through and including )
the Winter 1980 Addenda.
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- 4. Letter, Mr. V. L. Rooney, USNRC, to Mr. R. W. Capstick, VYNPC, "
Subject:
I Request for Additional Information - IST Program", Docket 50-271, NVY l 87-01, dated January 5, 1987. l l
- 5. Letter, Mr. V. L. Rooney, USNRC, to Mr. R. W. Capstick, VYNPC, "
Subject:
H Meeting Summary", Docket 50-271 NVY 80-074, dated May 9, 1988. I i
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I vi Rev. 9
, o SYSTEM FLOW DIAGRAMS FOR SAFETY-RELATED SYSTEMS The following drawings are provided with the IST program submittal for NRC review only: (NOT included in In-house copies)
G-1911159 Shts. 1,2,3 & 5 Service Water System G-191160 Shts. 3,4,6 & 7 Service and Instrument Air G-191162 Sht. 2 Miscellaneous Systems G-191167 Nuclear Boiler G-191168 Core Spray System G-191169 Shts. 1 & 2 HPCI System G-191170 Control Rod Drive Hydraulic System G-191171 Standoy Liquid Control G-191172 Residual Heat Removal System G-191174 Shts. 2 &2 RCIC System G-191175 Primary Containment - Atmospheric Control G-191176 Condensate and Demin. Water Transfer i
G-191177 Sht. 1 Radwaste System G-191178 Shts. 1 & 2 Reactor Water Cleanup System i G-191238 HVAC - Reactor Building G-191267 Nuclear Boiler Vessel Instrumentation l
VY-E-75-002 Containment Air Dilution System )
5920-4146 Emergency Diesel Generator Starting Air !
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a C SECTION I INSERVICE OPERABILITY TESTING PROGRAM FOR PUMPS SCOPE:
This program describes the inservice operability testing of pumps to meet the requirements of Section XI of the ASME Code, Subsection IWP, "Inservice Testing of Pumps in Nuclear Power Plants". Inservice operability testing is required for Safety Class 1, 2, and 3 centrifugal and displacement type pumps that are installed in light-water cooled nuclear power plants and that are required to perform a specific function in shutting down a reactor or in miti-gating the consequencas of an accident and are provided with an emergency power source.
All specific required testing and examination procedures required by this program including schedules, the location and type of measurement for each of the required test quantities, records of the results, acceptance criteria, and all corrective action taken shall be developed and maintained by VYNPC.
Relief Requests from certain ASME code requirements are located in the back portion of this section.
QUANTITATIVE VALUES:
In addition to the r eference values and allowable ranges established per IWP-3110 and TWP-3210, respectively, and the Relief Requests contained herein, quantitative values are established for certain test quantities. These values are based on the Plant Safety Analysis and are included in Table 1 of this sec-tion.
S;YMBOLS:
The following symbols are used:
N -
Putop Speed, RPM Pi -
Pump Inlet Pressure, Psig AP -
Pump Differential Pressure, Psid Q -
Pump Flow Rate, GPM V -
Pump Vibration Level, Mils or In/sec. See Relief Request Basis Number RRB-GP-3.
LL -
Pump Lubricant Level, In Lp -
Pump Lubricant Pressure, Psig QT -
Quarterly Testing in accordance with IWP-3400 P-1 Rev. 9
INSERVICE TEST QUANTITIES Pi L or P REFERENCE SAFETY OPERABILITY N INLET AP , Q V LUB LVL PUMP / SYSTEM DRAWING CLASS FREQUENCY SPEED PRESS. PRESS. FLOW VIBR. OR PRESS REMARKS G-191159 See RRB P1, P7-1A-D SW Sht. 1 3 QT - - - -
V -
Notes 1,2,3,/ Table 1 P8-1A-D G-191159 RHRSW Sht. 1/2 3 QT -
Pi AP Q V -
See Notes 1,3/ Table 1 P10-1A-D RHR G-191172 2 QT -
Pi AP Q V -
See Notes 1,3/ Table 1 G-191169 P44-1A HPCI Sht. 1/2 2 QT N Pi AP Q V L See Table 1 P45-1A/B See RRB P2,
._SLC G-191171 2 QT - - -
Q V L Note 1/ Table 1 P46-1A/B CS G-191168 2 QT -
Pi AP Q 'l -
See Notes 1,3,/ Table 1 G-191174 P47-1A_RCIC Sht. y 2 _ 2 QT N Pi AP Q V L See Tanle 1 P59-1A/B G-191159 See RRB P3, P4, RBCCW Sht. 3 3 QT -
Pi AP -
V -
Notes 1,2 See RRB PS, P6, P92-1A/B FO G-191162 3 QT -
Pi - -
V -
Note 1 P-2 Rev. 9
Relief Request Basis NUMBER: P1 SYSTEM: Service Water PUMP - P7-1A-D CLASS: 3 TEST REQUIREMENT: Quarterly testing per IWP-3100 BASIS FOR REQUEST:
1 For these pumps, neither inlet pressure nor flow rate can be directly measured. Inlet pressure can-not be directly measured as these pumps are of the deep well, centrifugal turbine typo which rely on intake structure water level for suction haad.
Flow rate can not be directly measured due to the absence of sufficient stcaight piping to allow for instrument installation.
In lieu of direct measurement, flow rate, differential pressure and total discharge head are calculated using a computer program which fits a j head / capacity curve from the data inputs of intake structure water level and l j
i temperature and pump discharge pressure. The results are evaluated against the j 1
quantitative values given in Table 1.
l Since flow can not be throttled nor differential pressure fixed, (dependent l on river water levels and temperatures and system heat loads) the data received from the computer program may not be a true indication of the pump's perfor-mance. Vibration levels are also subject to change since the referenco para- l meter of differential pressure can not always be achieved.
ALTERNATE TESTINGr Once per operating cycle, one pump will be taken out of service and overhauled for preventive maintenance. Quarterly readings will continue to be taken, recorded, and analyzed for trends to the degree possible.
P - 3 Rev. 9
Relief Request Basis NUMBER: P2 SYSTEM: St7ndby Liquid Control PUMP: P45-1A/B CLASS: 2 TEST REQUIREMENT: Reference values per IWP-3100, Table 3100-1 BASIS FOR RELIEF:
, In accordance with Table IWP-3100-1, flow will be measured from flow element FI-11-1. This parameter will be established as the reference value and trends analyzed per IWP-3100. Differential pressure will not be measured as it is variable since succion is from a vented tank. Inlet pressure will only be measured to assure that there is liquid in TK-21-1A, as not to damage the pumps. I ALTERNATIVE TESTING:
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l Continue testing and analysis of flow and vibration results per IWP-3200.
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h P-4 Rev. 9
Relief Request Basis NUMBER: P3 SYSTEM: Reactor Building Closed Cooling Water PUMP: P59-1A/8 CLASS: 3 TEST REQUIREMENT: Proper lubrication level and or pressure per IWP-3110 Table IWP-3100-1.
BASIS FOR RELIEF:
Pump has grease packed bearings and therefore cannot be checked.
ALTERNATIVE TESTING:
None.
P-5 Rev. 9
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Relief Request R3 sis I l
j NUMBER: P4 SYSTEM: Reactor Building Closed Cooling Water PUMP: P59-1A/B CLASS: 3 ;
TEST REQUIREMENT: Inservice test quantities per IWP-3100, Table IWP-3100-1 1
BASIS FOR RELIEF:
Table IWP-3100-1 specifies the Inservice Test Quantities to be measured or observed. For these pumps, there is no method available for measuring flow.
Differential pressure varies due to the distribution of cooling water to the various loads as regulated by temperature and pressure control valves in the system. Inlet pressure also cannot be measured before the cump test since the pumps are normally running. The vibration levels are also subject to change since the reference parameters cannot always be achieved.
ALTERNATE TESTING:
Quarterly readings will continue to be taken, recorded, and analyzed for i
trends to the degree possible.
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Relief Request Basis NUMBER: P5 SYSTEM: Fuel Oil Transfer PUMP: P92-1A/8 l CLASS: 3 i
TEST REQUIREMENT: Proper lubrication and or pressure per IWP 3110 Table IWP-3100-1 BASIS FOR RELIEF: Pump has grease-packed bearings and therefore cannot be checked. I ALTERNATIVE TESTING: None. l l
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P-7 Rev. 9
I Relief Request Basis l
NUMBER: P6 i SYSTEM: Fuel Oil Transfer !
l PUMP: P92-1A/8 )
CLASS: 3 TEST REQUIREMENTS: Differential pressure and flow measurements per IWP-3100, Table IWP-3100-1.
BASIS FOR RELIEF:
Fuel oil pumps are positive displacement pumps which are in a fixed resistance system. Per Table IWP-3100-1, Note 1, it is required to measure dif-ferential pressure or flow rate. There is no method available for measuring l flow. Differential pressure varies with the amount of fuel in the diesel fuel storage tank, TK-40-1A. The differential pressure is also subject to viscosity changes of the fuel oil due to seasonal temperature variations. These !
variations are not indicative of positive displacement pump performance.
ALTERNATIVE TESTING:
Ensure that each pump is capable of supplying fuel oil to the day tanks at a flow rate greater than that required by the associated diesel generator under 1
full load operation. This shall be verified by an increase in day tank level i during full load operation.
l P-8 Rev. 9
Relief Request Basis NUMBER: GP-1 CODE PARAGRAPH: Table IWP-3100-2 TEST REQUIREMENT: Allowable Ranges for AP and Q BASIS FOR RELIEF:
A thorough review of past operating surveillance data and continuing dif-ficulty in obtaining consistent data indicates a need to re-evaluate the ranges specified in the code paragrapF listed above. There are many causes for the difference in readings which have no relation to pump degradation. Differences in the manner by which gauges or meters are read, accuracies associated with each instrument, the affect on the instrument system due to the inaccuracies of each component all contribute to readings that are out of specification by more than 2% allowed by the code.
The nature of the test method required by ASME XI also contributes to the inconsistent data. When establ' hing the fixed parameter, there can be no tolerance since errors here wiil compound the error in reading the variable parameter. Because of the instrument inaccuracies and the test method, the data often unjustifiably falls into the required action level of ASME XI. These test method induced discrepancies are not syptomatic of a pump failure.
Based on our experience in surveillance testing since commercial operation in 1972, the ranges proposed in the following section represent reasonable and expected deviations of the pump parameters. The proposed changes only expand the range in the more conservative direction, i.e., allowing more flow or a higher differential pressure. These ranges are consistent with our Safety Analysis in that they do not lower the minimum flow or discharge pressure required.
ALTERNATIVE:
The high end of the various ranges will be adjusted upward as indicated in the following table:
Parameter Acceptable Alert Action Q .94 - 1.08 .90 - <.94 <.90
>1.08 - 1.12 >1.12 AP .93 - 1.08 .90 - < 93 < 90
>1.08 - 1.12 >1.12 P -9 Rev. 9
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l RELIEF REQUEST BASIS 1
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1 NUMBER: GP-2 ii '
l CODE PARAGRAPH: IWP-3300 and IWP-4300 f
TEST REQUIREMENT: Measurement of Pump Bearing Temperatures BASIS FOR RELIEF:
Paragraphs IWP-3300 and IWP-4300 require pump bearing temperatures to be ,
measured annually. However, the yearly temperature measurements do not provide j l a viable means of monitoring pump mechanical condition. First, there are l I
several factors, such as working fluid and ambient temperature, that can affect the pump bearing temperature. This would make detection of pump degradation difficult. Second, it has been demonstrated by experience that bearing tem-perature rise occurs only minutes prior to bearing failure. Therefore, the detection of possible bearing failure by a yearly temperature measurement is ;
extremely unlikely. Third, it requires at least an hour of pump operation to achieve stable bearing temperatures. The small probability of detecting bearing i l
failure by temperature measurement does not justify the additional pump l operating time required to obtain the measurements. l This Relief Request Basis is consistent with the requirements of ANSI /ASME l Standard OM-6, "In-Service Testing of Pumps", Draft 11, which does not require I Dearing temperature measurements.
ALTERNATIVE TESTING:
Pump mechanical condition can be determined much more accurately by l measuring bearing vibration. Paragraph IWP-4500 requires at least one vibration !
level be read during each in-service test. The number of readings will be f expanded to a minimum of two in orthogonal directions. These additional readings, in addition to the revised vibration measurement rcethods and accep- ,
tance criteria given in Relief Request Basis GP-3, will provide a viable means of monitoring pump mechanical condition. <
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RELIEF REQUEST BASIS NUMBER: GP-3 CODE PARAGRAPH: IWP-4500 TEST REQUIREMENT: Measurement of Pump Vibration in Mils I I
BASIS FOR RELIEF:
Recent analysis done by the ASME in developing ANSI /ASME Standard OM-6, "Inservice Testing of Pumps", Draft 11, has found that to more accurately moni-tor pump degradation, vibration measurement parameters should be determined by l
pump speed.
Currently, IWP-4500 requires vibration amplitude measurements to be taken in displacement for all pumps, regardless of speed. However, it has been found that although displacement is a representative parameter for low-speed pum'.s
(<600 rpm), vibrational velocity is a more accurate and representative indicator of degradation of higher-speed pumps (> 600 rpm). s'elocity measurements detect not only high amplitude vibrations that indicate a major mechanical problem, but l also the equally harmful low amplitude, high frequency vibrations due to mis-alignment, unbalance, or bearing wear that may be undettreted by displacement measurements.
In addition, due to the physical arrangement of the impe11ers in the HPCI and RCIC pumps, supplemental limits of vibrational velocity have been developed for these two pumps. A summary of the development of these supplemental limits 1
is included in Attachments GP-3-A and GP-3-B. l l
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ALTERNATIVE TESTING:
The requirements consistent with ANSI /ASME Standard OM-6, Draft 11 will be incorporated into the Vermont Yankee IST Program for pumps. These requirements, as well as the supplemental limits referred to above, are included in the attached Table GP-3-1.
As a minimum, all measurements will be taken per the following guidelines:
- a. On centrifugal pumps, measurements shall be taken in a plane approximately perpendicular to the rotating shaft in two orthogo-nal directions on each accessible pump bearing housing.
Measurement also shall be taken in the axial direction on each accessible pump thrust bearing housing,
- b. On vertical line shaft pumps, measurements shall be taken on the upper motor bearing housing in three orthogonal directions, one of which is the axial direction.
- c. On reciprocating pumps, the location shall be on the bearing housing of the crankshaft, approximately perpendicular to both the crankshaft and the line of plunger travel.
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P - 12 Rev. 9
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TABLE GP-3-1 t
RANGES OF TEST PARAMETERS PUMP PUMP TEST ACCEPTABLE ALERT REQUIRED TYPE SPEED PARAMETER RANGE RANGE ACTION RANGE 4
Centrifugal and Vertical Line Sbaft
<600 rpm Vd <2.5Vr >2.5Vr to 6Vr >6Vr or > 22 mils but iiot > 10.5 mils but not > 22 mils
>600 rps Vv <2.5Vr
- >2.5Vr to 6Vr >6Vr or > 0.70 in/sec J
1 but not > 0.325 in/sec but not >0.70 in/sec Reciprocating Vd $2.5Vr >2.5Vr to 6Vr 4
>6Vr or Vv HPCI Vv
$1.2Vr >1.2Vr to 1.5Vr >1,5Vr
- RCIC Vv
<2.5Vr but not >2.5Vr to 6Vr >6Vr or >1.0 in/sec
- j 50.75 in/sec but not >1.0 in/sec
] NOTE: Vd = Vibrational Displacement l
Vv = Vibrational Velocity l
Vr = Reference Vibration (Spectrum Overall Value) i
- Resonance peaks shall also be evaluated during each test and shall have an Acceptable Range upper limit of 1.05 V p and an Alert Range upper limit of 1.3 Vr.
P - 13 Rev. 9
s ATTACHMENT GP-3-A Past testing and analysis performed on the High Pressure Coolant Injection ,
(HPCI) system by Vermont Yankee, the pump manufacturer, and by independent vibration consultsnts has revealed characteristic pump vibration levels which exceed the acceptance criteria stated in ANSI /ASME OM-6, Oraft 11. The root causes of the higher vibration levels have been determined to be:
- 1) Excitation resulting from the blade pass frequency from the presently installed four vane impeller in the low pressure (LP) pump,
- 2) An acousticsl resonance in the piping connecting the low pressure and high pressure (HP) pumps, and
- 3) The presence of a structural resonance in the horizontal direction on the HP pump.
These resonance conditions are design related and have existed since initial pump installation. They have been documented over a number of years of operating experience.
In an effort to reduce / eliminate these conditions, Vermont Yankee is planning to install a fiva vane impellsr in the LP pump during the next refueling outage.
For the interim, it has been concluded that there are no major vibrational con-cerns that would prevent the HPCI pump from performing its intended function, l Although existing vibration levels are higher than the acceptance criteria stated in ANSI /ASME OM-6, Draft 11, they are acceptable and reflect the unique operating characteristics of the HPCI pump. T:lerefore, to allow for practical vibration monitoring of the HPCI pump, alternate vibration acceptance criteria are required. 1 The following criteria will be used:
Test Parameter Acceptable Rance Alert Rance Required Action Range i
Vv 0 $ Vv 5 1.2Vr >1.2Vr < Vv 5 1.5Vr Vv > 1.5Vr In addition, the resonance peaks will be evaiJated during each test and will have an Acceptable Range upper limit of 1.05 Vr and an Alert Range upper limit of 1.3 Vr.
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P - 14 Rev. 9 I
ATTACHMENT GP-3-B Test rig of the Reactor Core Isolation Cooling (RCIC) system by Vermont Yankee has revealed characteristic pump vibration levels which exceed the acceptance criteria stated in ANSI /ASME OM-6, Oraft 11. The vibrational velocity spectra has revealed peaks at two distinct frequencies. These peaks occur at frequen-cies which correspond to the blade pass frequencies of the four and five blade impellers present in the pump.
The RCIC pump consists of five stages. The first stage has a four vane impeller and the remaining stages have five vane impellers. This results in the two blade pass frequencies noted above.
Vermont Yankee is presently performing additional analyses to determine the best ceurse of action to correct this condition. As with the HPCI pump, Vermont Yankee, with the concurrence of an independent vibration consultant, has concluded that there are no major vibrational concerns that would prevent the RCIC pump from performing its intended function.
Although existing vibration levels are higher than tne acceptance criteria stated in ANSI /ASME OM-6, Draft 11, they are acceptable and reflect the unique operating characteristics of the RCIC pump. Therefore, to allow for practical vibration monitoring of the RCIC pump, alternate vibration acceptance criteria are required.
The following criteria will be used:
Test Parameter Acceptable Rance Alert Rance Required Action Rance Vv 0 < Vv 3 2.5 Vr Vv > 6 Vr
>2.5 Vr < VV $ 6 Vr but not > 0.75 in/sec but not > i.0 in/sec or > 1.0 in/sec In addition, the resonance peaks will be evaluated during each test and will have an Acceptable Range upper limit of 1.05 Vr and an Alert Range upper limit (
of 1.3 Vr.
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P - 15 Rev. 9 I
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NOTES
- 1. Non variable speed pump. Speed is not applicable per INP-3110, Table IWP-3100-1.
- 2. Initial suction pressure cannot be taken due to the fact that pumps are nor-mally running. '
- 3. Lubricant level or pressure cbservation is not necessary since pump bearings are lubricated by pu:opage.
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- TABLE 1 IN ADDITION TO THE P5FERENCE VALUES AND ALLOWABLE RANGES ESTABLISHED PER IWP-3110 AND IWP-3210, RESPECTIVELY, THE BELOW QUANTITATIVE VALUES ARE ESTABLISHED BASED ON THE PLANT SAFETY ANALYSIS. IF THESE VALUES CAN NOT BE MET, THE PUMP SHALL BE DECLARED INOPERATIVE.
MINIMUM PUMP / SYSTEM FLOW REQUIREMENTS FLOW PATH OPERABILITY FREQUENCY P7-1A-D SW 2700 GPM AGAINST A TOH OF 250 FEET NORMAL SYSTEM LINEUP PER IWP-3400 k
P8-JA-D RHRSW 2700 SPM AT 70 PSIA
- NORMAL SYSTEM LINEUP PER IWP-3400 P10-1A-D RHR 7450 + 150 GPM VESSEL TO VESSEL EACH REFUELING OUTAGE 4250 GPM AT NORMAL RECIRCULATE TO CONDENSATE P44-1A HPCI REACTOR OPERATING PREFSURE STORAGE TANK ONCE/0PERATING CYCLE RECIRCULATE TO TEST TANK P45-1A/B SLC 35 GPH AT 1275 FSIG USING DEMINE9ALIZED WATER PER IWP-3400 3000 GPM AGAINST A SYSTEM g P4E-1A/B CS HEAD CC ,120 PSIG TORUS TO TORUS EACH REFUELING OUTAGE
! 400 GPM AT NORMAL RErCTOR RECIRCULATE TO CONDENSATE P47-1A RCIC l OPERATING PRESSURE . STORAGE TANK PER IWP-3400
- FRESSURE MEASURED AT THE RHR HEtT EXCHANGER SERVICE WATER OUTLET WHEN THE CORRESPON9ING PAIRS OF RHR SERVICE WATER PUMPS AND STATION SERVICE WATER PUMPS ARE OPERATING.
P - 17 Rev. 9
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l SECTION II INSERVICE OPERABILITY TESTING PROGRAM FOR VALVES SCOPE:
This program describes the inservice operability testing of valves to meet the requirements of Section XI of the ASME Code, Subsection IWV, "Inservice Testing of Valves in Nuclear Power Plants". Inservice operability testing is required for certain safety class 1, 2, and 3 valves land their actuating and position indicating systems) in light-water cooled nuclear power plants, which are required to perform a specific function in shutting down a reactor to the cold shutdown condition or in mitigating the consequences of an accident.
All specific required testing and examination procedures required by this program including schedules, required test quantities and methods, records of the results, acceptance criteria, and all corrective actions taken shall be deve-loped and maintained by VYNPC.
Relief Requests from certain ASME code requirements are located in the back portion of this section.
QUANTITATIVE VALUES:
In addition to the reference values and allowable ranges established per IWV-3417 and the Relief Requests containe(i herein, quantitative maximum stroke times are established for certain valves. These stroke times are based on the Plant Safety Analysis and are included in Table 1 of this section.
SYMBOLS AND DEFINITIONS:
The following symbols and definitions are useo Category A Valves for which seat leakage is limited to a specific maximum amount in the closed position for fulfillment of their function.
(IWV-2200)
Tests Q Exercise the valve to the position required to fulfill its function every 3 months. (IWV-3400) ]
l MT Measure stroke time at the same frequency of the valve !
exercise (not more often than 3 months). See Relief Request Basis Number RRa-GV2.
LT Leak test the valves at least once every 2 years.
(IWV-3420)
V-1 Rev. 9 l
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Category B Valves for which seat leakage in the closed position is incon-sequential for fulfillment of their function. (IWV-2200)
Tests Q Exercise the valve to the position required to fulfill its I function every 3 montha. (IWV-3400)
MT Measure stroke time at the same frequency of the valve exercise (not more than 3 months). See Relief Request Number RRB-GV-2.
I Cateaory C Valves which are self-actuating in response to some system characteristic, such as pressure (relief valves) or flow direc-tion (check valves). (IWV-2200)
Tests CV Exercise to the position required to fulfill its function every 3 months. (IWV-3520)
SRV Test safety and relief valves to the frequency established in Table IWV-3510-1.
ST Test safety and relief vc.1ves in accordance with ASME PTC 26.3-1976 every 2 years. (IWV-3510)
Categorv 0 Valves which are actuated by an energy source capable of only one operation, such as rupture disks or explosive actuated valves. (IWV-2200)
Tests DT For explosive valves--remove, fire and replace 20%of the charges every 2 years. (IWV-3610)
For rupture disks--test in accordance with the manufacturer's instructions. (IWV-3620)
Test ReQuirementt LTJ Leak Rate Test, documentation and analysis will be completed in accordance with 10 CFR 50, Appendix J. See Relief Request Basis Number RRB-GV-3.
RR Exercise valve for operability every refueling outage.
CS Exercise valve for operability every cold shutdown.
RA Rapid Acting Valves. A maximum limiting stroke time of 2 seconds is established. See Relief Request Basis Number RRB-GV-2.
Valv? Tvoes GA Gate valve l
GL Glove valve !
l CK Check valve i V-2 Rev. 9 i
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EFC Excess Flow Check Valve RV Relief or Safety Valve RO Rupture Disk BF Butterfly Valve 8L Ball Valve Actuator Types A0 Air operator M Manual M0 Motor operator EXP Explosive '
SO Solenoid operator HO Hydaulic operator-Active Valves (A) Valves which are required to change position to accomplish '
a specific function.
Passive Valves (8) Valves which are not required to change position to accomplish a specific function.
V-3 Rev. 9
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SYSTEM: Nxlear Boiler DRAWING NO. G-191167 Valve Cate aorv Active / Size Valve Actuator Normal Test Relief Testing valve No. Class Coordinates Passive (in.) Type Type Position Requirements Requests Alternatives Remarks A 8 C D SR2-14E-L 3 M-12 x A 10 CA --
C CS -- --
See Table 2 V2-27A LT LTJ V2-96A 1 F,H-3 x x A 16 CK --
0 --
CV RR See RRS-45 and GV-3 V2-28A/B 1 F.H-4 x x A 16 CK --
0 --
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C --
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See Table 1 and Table 2 N-10 CS V2-54A/8 1 L-9 x A 4 GA MO O MT -- --
See Table 2 SV2-70A/8 1 0.h-8 x A 6x8 RV --
C --
SRV ST See RR8-Vio and Note 1 0,F,C Q RR RV2-71A-0 1 11-8 m x A 6x10 RV --
C --
SRV ST See RRS-V10, V11 and Note 2 Q RR SIA-D 1 08 x A 1 GA SO C --
V2-74 1 0-10 x A 3 GA M0 C MT LT LTJ See RRS-GV3 and Table 1 ~
Q V2-77 1 0-13 x A 3 GA MO C MT LT LTJ See RR8-Gv3 and Table 1 0,F,G. Q V2-80A-0 1 H-10 m A 18 GL A0 0 MT LT LTJ See RRS-GV3, Note 3 and Table 1 0,F.G. Q V2-86A-0 1 H-13 x A 18 GL A0 0 MT LT LTJ See Rhe-GV3. Note 3 and Table 1 V2-278 LT LTJ V2-968 2 F.H-3 x x A 16 CK --
0 --
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CVSTE*J: High Pressure Coolant In ject ion ORAWING NO.s G-191169. Sht. 1 Valve Cateaory Active / Size valve Actuator Normal Test Relief Testing Valve No. Class Coordinates Passive (in.) Type Type Position Requirements Requests Alternatives Reserks A B C D Q
V23-14 2 H-16 x A 10 GA M0 C MT -- --
See Tabie 1 Q
V23-15 1 E-5 x A 10 CA MO O MT LT LTJ See RRS-Gv3 and Table 1 Q
V23-16 1 E-7 x A 10 GA MO O MT LT LTJ See RRS-GV3 and Table 1 Q
V23-17 2 0-11 x A 14 GA Mf' O MT -- --
V23-18 2 H-6 x A 14 CK --
C CS -- --
See Table 2 Q
V23-19 2 H-6 x A 14 GA M0 C MT -- --
See Table i O
v23-20 2 H-7 x A 14 GA MO_ 0 MT -- --
See Table 1 Q
V23-21 2 F-7 x A 10 GL MO C MT -- --
Q V23-57 2 G-11 x A 16 GA MO C MT -- --
~
Q v23-54 2 N-5 x A 16 GA M0 C MT -- --
V23-65 2 K-4 x x A 20 CK --
C CV LT LTJ See RR8-GV3 and Note 11 SSC-23-12 2 K-4 x x A 20 CK --
C CV LT LTJ See RR8-GV3 SL23-37A-0 2 F.G-5 m x A 1 EFC --
C LT CV RR See RRS-V17 V23-61 2 N-7 x A 16 CK --
C CS -- --
See Te91e ?
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SYSTE;3: Residual Heit Remov'1 DRAW 1MG MO. G-191172 Valve Cateaorv Active / Site Valve Actuator horeal Test Relief Testing Valve No. Class Coordinates Passive (in.) Type Type Position Requirements Requests Alternatives Remarks A 8 C D CS V10-17 1 G-8 m A 20 GA M0 C MT LT --
See RR8-V22, Table 1 and Table 2 9
CS VIO-le 1 Fe m A 20 GA M0 C MT, LT E-6 See Table I. Table 7 and Note 10 Q
v10-25A/8 1 12 m A 24 GA M0 O MT -- --
See Table 1 C-7 Q V10-26A/8 2 J1 m A 12 GA M0 C MT LT LTJ See RRS-Gv3 and Table 1 0-6 0 V10-27A/8 1 12 m A 24 GL M0 C MT LT l See RR8-V22 and Table 1 1 l C-8 Q V10-31A/8 2 10 m A 12 GA MO C MT LT LTJ See RR8-GV3 and Table 1 V10-32 1 C-9 m P 4 GA MO C --
17 (TJ
, See RRS-CV3 and Table 1 I
V10-33 1 8-8 m P 4 GA M0 C --
LT LTJ See RRS-GV3 and Table 1 E-4 0 V10-34A/8 7 14 m A 10 GL MO C MT ti LTJ See RRS-GV3 and Table 1 E-4 Q i V10-3sA/8 2 13 m A 4 GL M0 C MT LT L1J See RRe-GV3 and Table 1 0-4 Q V10-394/8 2 14 m _
A 12 CA MO C MT LT LTJ See RR8-GV3 and Table 1 E-1 V10-46A/S 1 11 m a A 24 CK --
C CS LT 3
L-4,13 See RR8-V22 and Table 2
) V10-dea-D 2 J-4.13 m A 16 CK --
C CV -- --
t Q
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See Table 1
- Rev. 9 V-17 i
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SYSTES Residual He-t Remov31 (continued) DRAMING MO.. G-191172 Valve Catem Active / Size Valve Actuator Normal Test Relief Testing Valve No. Class Coordinates Passive (in.) Type Type Position Requirements Requests Alternattwes Seearks A B C D J-3 Q V10-65A/8 2 N-15 m A 20 GL MO O MT -- --
0 V10-66 2 H-13 w A 4 GA MO C MT -- --
See Tetrie 1 M-1 V10-89A/S 3 1-17 w A 12 Gt M0 C 0 MT --
See RRB-V23 I-6, Q V10-16A/8 7 12 m A 4 GA MD C MT .
LT LTJ See RRS-GV3 V10-19A-D 2 J,6-5 m u A 3 CK --
C CV LT L T.3 See RRS-GV3 and Note 5 I J-8, 10 Q V10-13A-D 2 t-8, 10 m A 20 CA MO O MT -- --
See Table 1 1 J-8, 10 Q '
V10-15A-D 2 K-8, 10 m A 20 GA M0 C MT -- --
See Table 1 m
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SYsTEL Primarv Containummt and Atmospher9 Control DRAWING NO.: G-191175 Valve Cate acrv Active / Size Valve Actuator Normal Test Relief Testing Valve No. Class Coordinates Passive (in.) Type Type Position Requirements Requests Alternatives Remarks A B C D V16 CV CS SA-J 2 J-8 x x A 18 CK --
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SYSTEM: Cont 9inment Atmospher* Dilution CF. AWING NO. VY-E-75-002 Valve CategorV Active / Size Valve Actuator Normal Test Relief Testing Valve No. Class Coordinates Passive (in.) Type Type Position Requirements Requests Alternatives Remarks A B C O FSO-109-75 MT RA =
A1,2 2 J-14 x A GA SO 0 LT LTJ 1 C See RR8-GV3 and Table 1 FSO-109-75 MT RA A2 2 I-12 x A 1 GA SO O _0 LT LTJ See RRB-GV3 Table 1 and Note 8 FSO-109-75 MT RA C1.2 2 G-12 x A 1 GA SO O O LT LTJ See RRS-GV3, Table 1 and Note 8 FSO-109-75 MT RA 01,2 2 G-12 x A 1 GA SO O O LT LTJ 54 RR8-GV3 Table 1 and Note 8 FSO-109-76 MT RA A/B 2 L-14 x A 1 GA SO O O LT LTJ See RRB-GV3 and Table 1 MT RA VG-75A-3,4 2 J-14 x A 1 GL SO C 0 LT LTJ See RR8-GV3 and Table 1 MT RA VG-23 2 J-19 x A 1 GL SO O O _
LT LTJ See Rh8-GV3 and Table 1 MT RA VG-24 2 L-11 x A 1 GL SO C 0 LT LTJ See RRB-GV3 and Table 1 MT RA VG-25 2 L-11 x A 1 GL SO C 0 LT LTJ See RAB-GV3 and Table 1 MT RA VG-26 2 J-19 x A 1 GL SO O O LT LTJ See RRB-GV3 and Table 1 MT RA VG-33 2 L-11 x A 1 GL SO C 0 LT LTJ See RRS-GV3 and Table 1 MT RA VG-34 2 L-11 x A 1 GL SO C 0 LT LTJ See RRS-GV3 and Table 1 MT RA VG-9A/B 2 G-12 x A 1 GL SO C 0 LT LTJ See RRB-GV3 and Table 1 _
Q VG-22A/B 2 E 16 x A 1 bL MC C MT LT LTJ See RR8-GV3 Rev. 9 V-27 e
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l NUMBER: V1 SYSTEM: Service Water VALVE: V70-1A-D CATEGORY: C CLASS: 3 FUNCTION: Service Water Pump Discharge Check Valves TEST REQUIREMENT: CV l
BASIS FOR RELIEF: A review of plant operating history has shown that all (4) ;
service water pumps are normally required for plant operation I during approximately seven (7) months of each year. This is due to system heat loads. As such, the shutting down of a pump for check valve testing is not practical.
During the remainder of the year, three (3) of the four (4) l pumps are required for plant operation. The pumps are rout 1-nely rotated when possible. 1 ALTERNATE TESTING: Valves will be exercised as pumps are rotated in service. l Proper pump operation will indicate proper opening of the I check valves. Absence of pump runback or system pressure loss as noted by operations personnel will indicate proper closure of the check valves.
The testing will take place during the period when only three (3) pumps are required. The frequency of such testing will be twice per year with a minimum interval between tests of three (3) months.
Rev. 9 V-30
RELIEF REQUEST BASIS NUMBER: V2 SYSTEM: Service Water VALVE: SE-70-4A,B,C,0 CATEGORY: B CLASS: 3 FUNCTION: RHR SW Pump Motor Cooling Outlet TEST REQUIREMENT: MT BASIS FOR RELIEF:
Valves cannot be independently stroke timed as no manual switch exists for such operation.
ALTERNATE TESTING: SE-70-4A,B,C,D will be exercised during pump surveillance tests and will be considered to be operating satisfactorily upon demonstration of proper RHR SW pump operation and ade-quate motor cooling water flow, i
I I
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Rev. 9 V-31
RELIEF REQUEST BASIS NUMBER: V3 SYSTEM: Recirculation pump VALVE: 2-2-7A/B, 2-2-8A/B CATEGORY: C CLASS: 2 FUNCTION: Excess flow check valves for instrument isolation TEST REQUIREMENT: CV BASIS FOR RELIEF: Valves can only be verified to shut by leak testing which is performed during the refueling outage hydrostatic test. This test cannot be repeated during each shutdown since the reac-tor vessel is not at pressure during cold shutdown. Valves cannot be exercised shut during power operation since shutting these would isolate instrumentation required for power operation.
ALTERNATE TESTING: Valves will be functionally tested each refueling outage.
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1 Rev. 9 V-32
1
. , j RELIEF REQUEST BASIS NUMBER: V4 SYSTEM: Service and Instrument Air, Diesel Generator Air Starting System l
VALVE: ASI and AS2 on each Diesel Generator CATEGORY: 8 CLASS: 3 1
FUNCTION: Emergency Diesel Air Start Solenoid Valves 1
TEST REQUIREMENT: Q l BASIS FOR RELIEF: j It is impractical to measure the limiting value of full-stroke time of these valves. These valves do not have remote position indication. Measuring the stroke time of these valves by observing stem travel would require disassembly of the operator. The safety function of these valves, as a pair, is to open to support the startup of their respective diesel to provide ,
rated frequency and voltage in less than thirteen seconds. Successful startup )
of each emergency diesel generator within the above specified conditions 4 is dependent upon the proper operation and speed of these valves. l Measuring startup time of each emergency diesel generator is an indirect method of verifying the operability of these valves and meets the intent of ,
the Code. Upon failure of the diesel generators to start as required, j corrective action shall be taken to assure proper diesel startup conditions. I l
1 ALTERNATE TESTING: 1 These valves, as a pair, shall be full-stroke tested on a quarterly basis using the emergency diesel generator startup times as an indirect indication of valve operability.
l l
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Rev. 9 V-33
. a RELfEF REQUEST BASIS NUMBER: VS SYSTEM: Nuclear Boiler VALVE: V2-27A, 96A CATEGORY: C CLASS: 1 FUNCTION: Feedwater Checks for HPCI/RCIC Operation TEST REQUIREMENT: CV BASIS FOR RELIEF:
Valves are required to be open during both power operation and HPCI/RCIC operation. The valves are required to close for primary containment isolation. Closure of the valves during power operation will result in loss of feedwater to the vessel. Closure of the valves during cold shutdown would require removing the only mechanism of vessel level control (via reactor water cleanup system).
ALTERNATE TESTING:
Valves will be exercised to the fully open position by the proper operation of the feedwater system at startup. The valves will be exercised to the fully closed position each refueling outage during leak testing in accordance with Relief Request Basis Number GV3.
I i
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Rev. 9 l V-34 !
O e RELIEF REQUEST BASIS NUMBER: V6 SYSTEM: Nuclear Boiler VALVE: V2-28A/B CATEGORY: C CLASS: 1 FUNCTION: Inboard Feedwater Check Valves TEST REQUIREMENT: CV BASIS FOR RELIEF:
Valves are required to be open during both power operation and HPCI/RCIC operation. The valves are not required to close for primary containment isolation as they have been exempted from leak testing as described in the Vermont Yankee Primary Containment Leak Rate Testing Program. However, verification of closure upon cessation of flow will be per-formed as described below.
Closure of the valves during power operation will result in loss of feedwater to the vessel. Closure of the valves during cold shutdown would require removing the only mecha-nism of vessel level control (via reactor water cleanup ;
system).
ALTERNATE TESTING:
Valves will be exercised to the fully open position by the proper operation of the feedwater system at startup. I To verify proper closure upon cessation of flow, the valves ;
will be partially disassembled and inspected to verify clo- :
sure and that valve internals are structurally sound. The I disassembly of each valve will be performed on a staggered sampling basis, one valve during each refueling outage.
1 Inspection on a staggered sampling basis provides reasonable I assurance of the ability of these valves to perform their safety related function. Each valve is of the same design (manufacturer, size, model number and materials of construc-tion) and have the same service conditions. Therefore, the condition and performance of both valves should be similar.
If it is found that the disassembled valve's operability is in question, the alternate valve will also be disassembled and inspected during the same refueling outage.
Rev. 9 V-35
RELIEF REQUEST BAS 2S NUMBER: V7 SYSTEM: Nuclear Boiler VALVE: V2-28A/B CATEGORY: A CLASS: 1 FUNCTION: Feedwater Checks for HPCI/RCIC Operation 7EST REQUIREMENT: LT BASIS FOR RELIEF: The valves need not close to provide primary containment iso-lation. This is based on the Appendix J testing of the out-board feedwater check valves, the water seal on the inboard check valves, and the plant capability to maintain a pressure greater than Pa on the Feedwater System. This basis was approved by the NRC in the SER transmitted by letter, D. G. Eisenhut, NRC, to J. B. Sinclair, VYNPC, dated August 19, 1983.
ALTERNATE TESTING: None I
l 1
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l l
l Rev 9 V-36
RELIEF REQUEST BASIS NUM8ER: V8 SYSTEM: Nuclear Boiler VALVE: V2-37A - 0 CATE60HY: C CLASS: 2 FUNCTION: MSRV Air Supply Accumulator Check Valves TEST REQUIREMENT: CV BASIS FOR RELIEF: Valves are normally closed and open only upon exercising of the Main Steam Relief Valves, RV2-71A-D. Valves can not be exercised seperately from the MSRV's as this would require isolating the control air of the MSRV's.
ALTERNATE TESTING: Valves will be verified to close during leak testing as described in Relief Request Basis Number V9. Valves will be verified to open during exercising of the MSRV's as described in Relief Request Basis Number V10.
Rev. 9 V-37
i .
RELIEF REQUEST BASIS NUMBER: V9 SYSTEM: Nuclear Boiler VALVE: V2-37A-0 CATEGORY: AC CLASS: 2 FUNCTION: MSRV Air Supply Accumulator Check Valves TEST REQUIREMENT: LT (IWV-3426)
BASIS FOR RELIEF:
References:
- 1) Letter, USNRC to VYNPC, dated January 11, 1980, "IE Bulletin 80-01, Operability of ADS Pneumatic Supply".
- 2) Letter, VYNPC to USNRC, dated January 18, 1980, "Response to IE Bulletin 80-01".
- 3) Letter, VYNPC to USNRC, dated January 25, 1980, "Supplementary Information in Response to IE Bulletin 80-01".
- 4) Letter, USNRC to All Licensees of Operating Plants, dated October 31, 1980, NUREG-0737.
- 5) Letter, VYNPC to USNRC, dated May 15, 1981, "NUREG-0737, Item II.K.3.28 "Verify Qualification of Accumulators on Automatic Depressurization System Valves".
- 6) Letter, USNCR to VYNPC, dated May 11, 1983, "Request for Additional Information - NUREG-0737, Item II.K.3.28, Qualification of ADS Accumulators".
- 7) Letter, VYNPC to USNRC, dated December 5, 1983, "NUREG-0737, Item II.K.3.28". .
- 8) Letter, USNRC to VYNPC, dated July 16, 1984, "Request for Additional Information - MPA F-55 (TMI II.K.3.28)
"Qualification of ADS Accumulators per 10 CFR 50.54 (f)".
- 9) Letter, VYNPC to USNRC, dated September 7, 1984, "NUREG-0737, Item II.K.3.28, Request for Additional Information on the Qualification of ADS Accumulators per 10 CFR 50.54()".
- 10) Letter, VYNPC to USNRC, dated January 24, 1985, "NUREG-0737, l Item II.K.3.28, Request for Additional Information on the '
Qualification of AOS Accumulators".
- 11) Letter, USNRC to VYNPC, dated March 4, 1985, "Verify Qualification of Accumulators on ADS Valves (II.K.3.28, MPA F-55)".
Rev. 9 V-38
BASIS FOR RELIEF (Cont.)
The safety function of valves V2-37A-D is to assure that the Main Steam Relief Valve (MSRV) accumulators remain at pressure in the event of a loss of header pressure. This is equal to the nominal system pressure, the time period required for the MSRV to be operable is assumed to be 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />. This is based on the standard practice cooldown rate of 100*F/hr. From a saturation temperature of 544.6*F at 1000 psig to 327.8'F at 100 psig yields a drop of 216.8"F, or 2.17 hours1.967593e-4 days <br />0.00472 hours <br />2.810847e-5 weeks <br />6.4685e-6 months <br /> to shutdown. Assuming 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for operator action prior to depressurization, tne time required for MSRV operability is set at 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />. This time period also bounds all accident scenerios pre-sented in the Vermont Yankee FSAR.
Therefore, 100 psia - 64 psia = 12 psig/hr.
3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> This methodology was approved by the NRC in the SER contained in Reference 11.
ALTERNATE TESTING:
Perform leak testing, analysis and corrective action in accordance l with IWV-3420 with the exception that the maximum acceptable leakage rate shall be equal to 12 psig/hr with a initial test '
pressure of 100 psig.
l Rev. 9 V-39
- . _ _ . _ _ _ ~ - - . . . . - - . - , . - . - . . - . ,. - . . ..__- -
RELIEF REQUEST BASIS NUMBER: V10 SYSTEM: Nuclear Boiler VALVE: RV2-71A-0, SV2-70A/B CATEGORY: C CLASS: 1 FUNCTION: Automatic Depressurization/ Overpressure Protection TEST REQUIREMENT: SRV (IWV-3512, IWV-3513)
BASIS FOR RELIEF:
The present program for testing Main Steam Relief and Safety Valves as described in the Vermont Yankee Inservice Testing Program is more conservative than the test frequency described in IWV-3511. Per the IST Program, all Main Steam Relief and Safety Valves are tested every two refuel outages. .
The valves that are removed each refuel outage for testing I are either tested and returned to service or replaced with a l previously tested spare valve. l In the case where the valves are both tested and returned to '
service during a single refuel outage, additional testing in full compliance with IWV-3513 will be performed should any valve fail to function properly during testing.
In the case where the valves are replaced with a previously tested spare, full compliance with IWV-3513 is not practical.
Should one valve fail to function properly during testing, compliance with the increase in the testing population (N+12) j is performed since 50% of the valves are presently tested each refuel outage. However, should additional valves fail to function properly, testing of all valves is not practical since the removed valves are not tested for as-found con-ditions until a convenient time after the refuel outage.
Therefore, the plant could be operating before it could be determined whether or not the removed valve fails to function within Technical Specifications and Code Requirements.
ALTERNATE TESTING:
The Main Steam Relief and Safety Valves will be tested in accordance with the frequency stated in the IST Program. The analysis and reporting of failures shall be in accordance with the Licensee Event Report System, 10 CFR 50.73.
Rev. 9 V-40
1
. , 1 RELIEF REQUEST BASIS I l
NUMBER: V11 l SYSTEM: Nuclear Boiler VALVE: RV2-71A-D, SIA-D CATEGORY: B l
CLASS: 1 FUNCTION: Automatic Depressurization TEST REQUIREMENT: Q l
BASIS FOR RELIEF: Valves cannot be exercised during power operation since I failure in the open position would require tripping the reac- I tor. Also, live steam would be discharged to the suppression l pool which would heat the water and pressurize the contain- l ment. Valves cannot be exercised during cold shutdowns since steam is required to stroke the main piston in the valve.
Based on the following references, the testing of each relief valve at a frequency of once per operating cycle is assessed to be adequate by Vermont Yankee and the industry. In a j letter from Brian K. Grimes of the NRC to All Boiling Water l Reactor Licensees dated July 16, 1979 regarding relief and I safety-relief valves, it states that "we have concluded that )
implementation of a requirement for increased surveillance testing would not be the most effective way of assuring safety-relief valve reliability." Also referenced is a i letter from Darrel G. Eisenhut of the NRC to All Operating Reactor Licensees dated May 7, 1980 regarding the Five Addi- l tional THI-2 Related Requirements to Operating Reactors.
Item II.K.3.16 entitled Reduction of Challenges and Failures of Relief Valves - Feasibility Study and System Modification states that, "Those changes which are shown to reduce relief valve challenges without compromicing the performance of the relief valves or other systems should be implemented." Ver-mont Yankee's response to an NRC suggested Tech. Spec change dated February 2, 1978 states that "Both General Electric Company and Target Rock strongly recommend that these valves be manually operated only when absolutely necessary. The only time we consider to be absolutely necessary, other than if plant conditions warrant, is once a cycle."
ALTERNATE TESTING: During power ascension after a refueling outage, each relief valve will be manually opened to full stroke with the reactor at low pressure until the thermocouple downsteam of the valve indicates fluid is flowing from the valve. (Note: Proper operation of RV2-71A-D verifies operability of SIA-D).
Rev. 9 V-41
RELIEF REQUEST BASIS 1
NUMBER: V12 SYSTEM: Nuclear Boiler VALVE: V2-278, V2-96B CATEGORY: C CLASS; 2 FUNCTION: Feedwater Checks for HPCI/RCIC Operation TEST REQUIREMENT: CV BASIS FOR RELIEF: Valves are required to be open during power operation. The valves are required to close for HPCI/RCIC operation and pri-mary containment isolation. Shutting these valves will cause a loss of feedsater to the vessel. Testing via the HPCI/RCIC systems would cause thermal shocking of the feedwater nozzles ;
and could result in damage to reactor internals. Testing the ,
valves during cold shutdown would require removing the only )
mechanism of vessel level control (via reactor cleanup 1 system).
ALTERNATE TESTING: Valves will be exercised to the fully open position by the proper operation of the Feedwater System at startup. The valves will be exercised to the fully closed position each i refueling outage during leak testing in accordance with Relief Request Basis Number GV3.
1 Rev. 9 V-42
RELIEF REQUEST BASIS i
NUMBER: V13 I
SYSTEM: Nuclear Boiler i
VALVE: 2-62-A-0, 2-64-A-0, 2-73-A-H, 2-301 C/D, 2-305 A/B l CATEGORY: C CLASS: 2 FUNCTION: Excess Flow Check Valves for Instrument Isolation l
I TEST REQUIREMENT: CV BASIS FOR RELIEF: Valves can only be verified to shut by leak testing which is ,
performed during the refueling outage hydrostatic test. This 1 test cannot be repeated during each shutdown since the reac-tor vessel is not at pressure during cold shutdown. Valves l I
cannot be exercised shut during power operation since shutting these would isolate instrumentation required for power operation.
ALTERNATE TESTING: Valves will be functionally tested each refueling outage.
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Rev. 9 V-43 i
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RELIEF REQUEST BASIS NUMBER: V14 SYSTEM: Core Spray VALVE: V14-12A/S, V14-13A/B CATEGORY: A CLASS: 2 FUNCTION: Pressure Boundary Isolation TEST REQUIREMENT: LT
REFERENCES:
- 1. Generic NRC letter, D. G. Eisenhut, NRC, to D. E. Vandenburgh, VYNPC, dated February 23, 1980.
- 2. Letter, D. E. Vandenburgh, VYNPC, to D. G. Eisenhut, NRC, "LWR Primary Coolant System Isolation Valves", WVY 80-41, dated March 14, 1980.
- 3. Letter, T. P. Ippolito, NRC, to R. L. Smith, VYNPC, dated August 8, 1980. Includes "Technical Evaluation Report (TER), Primary Coolant System Pressure Isolation Valves", dated July 21, 1980.
- 4. Generic NRC letter 87-06, H. R. Denton, NRC, to All Holders of Operating Licenses, dated March 13, 1987.
S. Letter, W. P. Murphy, VYNPC, to T. E. Murley, NRC, "Response to Generic Letter 87-06, Periodic Verification of Loak-Tight Integrity of Pressure Isolation Valves",
FVY 87-64, dated June 11, 1987.
BASIS FOR *EF:
l Pressure isolation valves (PIVs) are defined for each inter- f face as any two valves in series within the reactor coolant l
pressure boundary which separate the high pressure reactor l coolant system (RCS) from the attached low pressure system. l Leakage of such PIVs could result in overpressurization of '
the low pressure system with possible resultant rupture and loss of reactor coolant outside of containment.
In response to References (3) and (4), Reference (5) provided a listing of PIVs at Vermont Yankee. The NRC, via Reference (1), stated that the integrity of such valves is adequately assured either by continuous or periodic monitoring of downstream pressure or by the performance of leak testing.
Rev. 9 V-44
BASIS FOR RELIEF:(Cont.)
For these valves, continuous monitoring of the downstream pressure at this interface is provided by PS-88-47A/8, located downstream of V14-12A/B.
The NRC Committee to Review Generic Requirements (CRGR) currently has under review the requirements for testing / monitoring of PIVs. Pending the findings of the CRGR regarding this matter, the above described monitoring is con-sidered to provide adequate assurance of valve integrity.
ALTERNATE TESTING: None.
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Rev. 9 !
V-45 l
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RELIEF REQUEST BASIS NUMBER: V15 SYSTEM: Core Spray VALVE: V14-31A/B CATEGORY: C CLASS: 2 FUNCTION: Excess flow check valves for instrument isolation TEST REQUIREMENT: CV BASIS FOR RELIEF: Valves can only be verified to shut by leak testing which is performed during the refueling outage hydrostatic test. This test cannot be repeated during each shutdown since the reac-tor vessel is not at pressure during cold shutdown. Valves cannot be exercised shut during power operation since shutting these would isolate instrumentation required for power operation.
ALTERNATE TESTING: Valves will be functionally tested each refueling outage.
i Rev. 9 1 1
V-46 l
RELIEF REQUEST BASIS NUMBER: V16 SYSTEM: Core Spray VALVE: V14-33A/B CATEGORY: C !
CLASS: 2 FUNCTION: Core Spray Pressurizing Line Check Valve '
TEST REQUIREMENT: CV l
BASIS FOR RELIEF:
There is no test loop available to regularly exercise these valves. Their proper operation is assured through continuous Core Spray discharge header pressure monitoring and by veri- I fication of acceptable Core Spray parameters during system I surveillance.
ALTERNATE TESTING:
Proper closure of V14-33A/B is verified during surveillance runs of the Core Spray pumps. This meets the intent of IWV-3522.
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l Rev. 9 V-47
. . l RELIEF REQUEST BASIS NUMBER: V17 SYSTEM: High Pressure Coolant Injection V4LVE: SL23-37A-0 CATEGORY: C CLASS: 2 FUNCTION: Excess flow check valves for instrument isolation l
TEST REQUIREMENT: CV i l
BASIS FOR RELIEF: Valves can only be verified to shut by leak testing which is )
performed during the refueling outage hydrostatic test. This test cannot be repeated during each shutdown since the reac-tor vessel is not at pressure during cold shutdown. Valves ,
cannot be exercised shut during power operation since I shutting these would isolate instrumentation required for power operation.
ALTERNATE TESTING: Valves will be functionally tested each refueling outage.
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Rev. 9 V-48
RELIEF REQUEST BASIS NUMBER: V18 SYSTEM: Control Rod Drive Hydraulic ,
l VALVE: V3-13-114, V3-13-115, V3-13-126, V3-13-127 I CATEGORY: B or C CLASS: 2 l
FUNCTION: Control rod drive scram I TEST REQUIREMENT: Q or CV :
BASIS FOR RELIEF: Exercising these valves during power operation would require scramming the plant or an undesirable reactor transient.
ALTERNATE TESTING: Since scram insertion times are representative of valve operability and stroke times, alternate testing will be per-formed in accordance with Tech. Spec. Section 4.3.C.1 and 2.
This section requires that all control rods be subjected to scram-time measurements on a refueling outage basis. Also, this section requires that 50% of the control rods be measured for scram times every 16 to 32 weeks. An evaluation i is required that provides reasonable assurance that proper control rod drive performance is being maintained. These tests adequately verify valve operability and stroke times.
Rev. 9 V-49 l
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i RELIEF REQUEST BASIS NUMBER: V19 SYSTEM: Control Rod Drive Hydraulic VALVE: V13-162A/B CATEGORY: C CLASS: 3 FUNCTION: . Scram Discharge Volume Vent Check Valves TEST REQUIREMENT: CV BASIS FOR RELIEF: Valves cannot be exercised during power operation since this l would require taking the CR0 system out of service. Operabi- '
lity of these valves is demonstrated by decreasing scram discharge volume water level upon reset from SCRAM.
1 ALTERNATE TESTING: None !
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Rev. 9 V-50
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RELIEF REQUEST BASIS NUMBER: V20 SYSTEM: Standby Liquid Control VALVE: V11-16, V11-17 CATEGORY: C CLASS: 1 FUNCTION: SLC Injection into Reactor TEST REQUIREMENT: CV BASIS FOR RELIEF: Exercising these valves during power operation would require injecting borated water into the reactor coolant system.
This would create a reactivity excursion and potential for reactor trip. Injection of demineralized water would require removing the system from service to clean the borated solu-tion from the piping and replacing the explosive actuated valves. This system is required for power operation.
ALTERNATE TESTING: Valve opening will be demonstrated each refuel outage by the system flow test directly into the reactor vessel. Valve closing will be demonstrated each refueling outage during )
leak testing in accordance with IWV-3420.
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Rev. 9 V-51
.. . . . - _ . - ~ _-
s , l\
RELIEF REQUEST BASIS 1
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NUMBER: V21 ;
Standby Liquid Control SYSTEM:
VALVE: SR-39A/8 CATEGORY: C CLASS: 2 FUNCTION: SLC System Overpressure Protection I
TEST REQUIREMENT: SRV (IWV-3511)
BASIS FOR RELIEF: The present program for testing the SLC relief valves as des-cribed in the Vermont Yankee Inservice Testing Program is more conservative than the test frequency described in IWV-3511. Per i the IST Program, both valves are tested each refuel outage.
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ALTERNATE TESTING: Continue to test the SLC relief valves per the requirements of the Inservice Testing Program.
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1 Rev. 9 V-52 i
RELIEF REQUEST BAS 2S NUMBER: V22 SYSTEM: Residual Heat Removal VALVE: V10-17, V10-27A/B, V10-40A/B CATEGORY: A CLASS: 1 FUNCTION: Pressure Boundary Isolation TEST REQUIREMENT: LT
REFERENCES:
- 1. Generic NRC letter, D. G. Eisenhut, NRC, to D. E. Vandenburgh, VYNPC, dated February 23, 1980.
- 2. Letter, D. E. Vandenburgh, VYNPC, to D. G. Eisenhut, NRC, "LWR Primary Coolant System Pressure Isolation Valves",
WVY 80-41 dated March 14, 1980.
- 3. Letter, T. P. Ippolito, NRC, to R. L. Smith, VYNPC, dated August 8, 1980. Includes "Technical Evaluation Report (TER), Primary Coolant System Pressure Isolstion Velves",
dated July 21, 1980.
- 4. Generic N9C letter 87-06, H. R. Denton, NRC, to All Holders of Operating Licenses, dated March 13, 1987.
- 5. Letter, W. P. Murphy, VYNPC, to T. E. Murley, NRC, "Response to Generic Letter 87-06, Pe-iudic Verification of Leak-Tight Integrity of Pressure Isolation Valves",
FVY 67-64, dated June 11, 1987.
BASIS FOR RELIEF:
Pressure isolation valves (PIVs) are defined for each inter-face as any two valves in series within the reactor coolant pressure boundary which separate the high pressure reactor coolant system (RCS) from the attacned low pressure system.
Leakage of such PIVs could result in overpressurization of the low pressure system with possible resultant rupture and loss of reactor coolant outside of containment.
In response to References (3) and (4), Reference (5) provided a listing of PIVs at Vermont Yankee. The NRC, via Reference (1), stated that the integrity of such valves is adequately assured either by continuous or periodic monitoring of downstream pressure or by the performance of leak testing.
Rev. 9 V-53
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BASIS FOR RELIEF: (Cont.)
For valve V10-17, continuous monitoring of the downstream pressure is orovided by PS-10-118. For valves V10-27A/B and V10-46A/B, continuous monitoring of the downstream pressure at i this interface is provided by PS-10-122A/B, located downstream of V10-27A/B. In addition, monitoring of the pressure downstream of valves V10-46A/B is performed daily by reading P1-10-100A/B. l The NRC Committee to Review Generic Requirements (CRGR) !
currently has under review the requirements for l testing / monitoring of P1Vs. Pending the findings of the CRGR ;
regarding this matter, the above described monitoring is con-sidered to provide adequate assurance of valve integrity, j ALTERNATE TESTING: None. )
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l Rev 9 V-54
, , - - - ----,--,,--,e - , , -n - - - -
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RELIEF REQUEST BASIS NUMBER: V23 SYSTEM: Residual Heat Removal VALVE:' V10-89A/B CATEGORY: B CLASS: 3 FUNCTION: Flow Control TEST REQUIREMENT: MT BASIS FOR RELIEF: Valve is a modulating type valve. Stroke time is not an appropriate reference parameter.
ALTERNATE TESTING: Proper valve operation is verified through normal system operation du'ing the pump tests.
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Rev. 9 i V-55 1 i
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RELIEF REQUEST BASIS NUMBER: V24 SYSTEM: Reactor Core Isolation Cooling VALVE: SL 13-55A-D CATEGORY: C CLASS: 2 FUNCTION: Excess flow check valves for instrument isolation TEST REQUIREMENT: CV BASIS FOR RELIEF: Valves can only be verified to shut by leak testing which is performed during the refueling outege hydrostatic test. This test cannot be repeated during each shutdown since the reac-tor vessel is not at pressure during cold shutdown. Valves cannot be exercised shut during power operation since shutting these would isolate instrumentation required for power operation.
ALTERNATE TESTING: Valves will be functionally tested each refueling outage.
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Rev. 9 V-56 1
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RELIEF REQUEST BASIS ;
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NUMBER: V25 SYSTEM: Reactor Core Isolation Cooling VALVE: Turb. Gov.
CATEGORY: B CLASS: 2 FUNCTION: Modulating Valve TEST REQUIREMENT: MT BASIS FOR RELIEF: Valve is a modulating type valve. Stroke time is not an appropriate reference parameters.
ALTERNATE TESTING: Proper valve operation is verified through normal system operation during the pump tests.
Rev. 9 V-57 N
RELIEF REQUEST BASIS NUMBER: V26 SYSTEM: Primary Containment and Atmosphere Control VALVE: V16-19-5 A to J !
l CATEGORY: A l CLASS: 2 FUNCTION: Torus-drywell Vacuum Breakers TEST REQUIREMENT: CV l
BASIS FOR RELIEF: Testing of valve opening force as required by IWV-3522(b) l can not be' performed during power operation since this testing would cause the loss of the differential pressure between the drywell and the suppression chamber. This DP is a required !
condition of plant operation.
ALTERNAfE TESTING: Once every 3 months and following any release of energy to the suppression chamber each suppression chamber-drywell vacuum breaker shall be exercised. During each refueling outage all suppression chamber-drywell vacuum breakers shall be tested to determine that the applied force at all valve positions does not exceed that equivalent to 0.5 psi acting on the suppression chamber face of the valve disk.
l During each refueling outage at least 2 of the 10 suppression chamber-drywell vacuum breakers shall be disassembled and inspected. If deficiences are found such that Tech. Spec.
Section 3.7.A.6 can not be met, all vacuum breakers shall be inspected and deficiences corrected.
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Rev. 9 V-58 l
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. .. I-RELIEF REQUEST BASIS NUM8ER: V27 SYSTEM: Primary Containment and Atmosphere Control VALVE: V16-19-5 A to J CATEGORY: A CLASS: 2 FUNCTION: Torus-drywell vacuum breakers TEST REQUIREMENT: LT BASIS FOR RELIEF: Valves cannot be leak tested individually ALTERNATE TESTING: Leak test will be done which will demonstrate that with an initial differential pressure of not less than 1.n psi, the differential pressure decay rate shall not exceed the equiva-lent of the leakage rate through a 1-inch orifice.
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I Rev. 3 V-59 1
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RELIEF REQUEST BASIS NUMBER: V28 SYSTEM: Nuclear Boiler Vessel Instrumentation VALVE: 2-3-11, 2-3-13A/8, 2-3-15A/8, 2-3-17A/8, 2 3-19A/8, 2-3-21A-D, 2-3-23A-D, 2-3-25, 2-3-27, 2-3-29A/8, 2-3-31A-H, 2-3-311-Q, 2-3-33, 2-3-35 CATEGORY: C CLASS: 2 FUNCTION: Excess flow check valves for instrument isolation TEST REQUIREMENT: CV BASIS FOR RELIEF: Valves can only be verified to shut by leak testing which is performed during the refueling outage hydrostatic test. This test cannot be repeated during each cold shutdown since the reactor vessel is not at pressure during cold shutdown. ;
Valves cannot be exercised shut during power operation since shutting these would isolate instrumentation required for power operation.
ALTERNATE TESTING: Valves will be functionally tested each refueling outage.
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Rev. 9 V-60
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6 RELIEF REQUEST BASTS NUMBER: V29 SYSTEM: TIP VALVE: Ball A-C CATEGORY: A CLASS: 2 FUNCTION: Primary Containment Isolation TEST REQUIREMENT: Remote Position Indicator Verification (IWV-3300)
BASIS FOR RELIEF:
Direct visual verification of position would require disassembly of the valve enclosures as the limit switches are contained within the enclosures. ;
ALTERNATE TESTING:
Positive verification of full opening of the valves is shown by successful insertion of the Transversing In-Core Probe through the valve. This is performed on a minimum frequency of once per month during operation. Positive verification of full closing of the valve is shown during each refueling outage by successful leak testing in accordance with Relief Request Basis Number GV-3.
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RELIEF REQUEST BASIS NUM8ER: GV-1 CODE PARAGRAPHS: IWV-3417(b) and IWV-3523 concerning corrective action prior to startup, BASIS FOR RELIEF:
The Vermont Yankee Technical Specifications and Administrative Procedures describe various limiting con-ditions for operation and startup prerequisites including verification that all cold shutdown surveillance procedures are complete and acceptable. These controls comply with the above referenced requirements and are more appropriately used as a basis for plant startup.
ALTERNATIVE: The Technical Specifications and Administrative Procedures will be used as the basis for determining plant startup readiness.
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Rev. 9 V-62
8' RELIEF REQUEST BASIS NUMBER: GV-2 CODE PARAGRAPHS: IWV-3417 BASIS FOR RELIEF:
Recent analysis done by the ASME in developing ANSI /ASME Standard OM-10, "Inservice Testing of Valves", Draft 11, has resulted in revisions to the acceptance criteria and correc-tive actions for valve exercise testing.
Pai agraph IWV-0417(a) states the following:
"If, for power operated valves, an increase in stroke time of 25% or more from the previous test for valves with full-stroke times greater than 10 seconds or 50% or more for valves with full-stroke times less than or equal to 10 seconds is observed, test frequency shall be increased to once each month until corrective action is taken ...."
These requirements do not consider the following points:
- 1) By comparing stroke times to the previous test, rather than a fixed reference value, long-term, slow degradation may go undetected until the maximum limiting value for the full-stroke time is reached.
- 2) By considering only increases in stroke times, valve problems which result in decreases in stroke times (i.e.,
detached disk) may go undetected.
- 3) Certain power operated valves have very short stroke l times. The ability to accurately measure these short :
stroke times with a hand-held stopwatch is difficult and !
not repeatable.
- 4) Based on data collected from several PWRs and BWRs, the l operating characteristics of electric motor actuated '
valves are more consistent than those of pneumatic or hydraulically operated valves. Therefore, degradation of electric motor actuated valves can be more accurately determined.
- 5) As defined in the Inservice Testing Program, there is sufficient justification to test certain valves on either a cold shutdown or a refueling outage basis. The test frequency of these valves cannot be increased without l Jeopardizing plant operations. '
Rev. 9 V-63 1
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RRB-GV-2 (Continued)
ALTERNATIVE TESTING:
Valve exercise testing will be performed under the following guidelines:
- 1) STROKE TIME ACCEPTANCE CRITERIA Test results shall be compared to the initial reference values or reference values established in accordance with 4 and 5 below,
- a. Electric motor operated valves with reference stroke times greater than 10 seconds shall exhi-bit no more than 115% change in stroke time when compared to the reference value.
- b. Other power operated valves with reference stroke times greater than 10 seconds shall exhibit no more than 125% change in stroke time when com-pared to the reference value.
- c. Electric motor operated valves with reference stroke times less than or equal to 10 seconds shall exhibit no more than a 125% or il second change in stroke time, whichever is greater, when compared to the reference value.
- d. Other power operated valves with reference stroke times less than or equal to 10 seconds shall exhibit no more than 150% or il second change in stroke time, whichever is greater, when compared to the reference value,
- e. Valves that stroke in less than two seconds may I be exempted from 1c and 1d above. In such cases 1 the maximum limiting stroke time shall be two seconds.
- 2) CORRECTIVE ACTION
- a. If a valve fails to exhibit the required change of position or exceeds the limiting values of full stroke time given in Table 1, the valve shall be immediately declared ineperable,
- b. If a valve stroke time does not meet the accep-tance criteria of la through Id above, the test frequency shall be increased as follows:
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- 1) For valves normally tested quarterly, the l test frequency shall be increased to once ;
each month. !
Rev. 9 V 64
RRB-GV-2 (Continued)
- 2) For valves normally tested during cold shut-down, the test frequency shall be increased to each cold shutdown, but not to exceed once per month.
- 3) For valves normally tested during refueling !
outages only, the test frequency shall remain at each refueling outage.
- c. Valves declared inoperable may be repaired, replaced, or the data may be analyzed to deter-mine the cause of the deviation and the valve shown to be operating acceptably, i
3.
REFERENCE VALUES Reference values shall be determined from the results ;
of pre-service testing or from the results of in-service testing. These tests shall be performed under conditions as near as practicable to those expected during subsequent in-service testing.
Reference values shall only be established when the valve is known to be operating acceptably. If the particular parameter being measured can be s10nifi-cantly influenced by other related conditions, then j these conditions shall be analyzed. !
- 4. EFFECTS OF VALVE OR ACTUATOR REPLACEMENT, REPAIR, APD HAINTENANCE ON REFERENCE VALUES l When a valve has been replaced, repaired or has undergone maintenance 8 that could affect the valve's performance, a new reference value shall be deter- i mined or the previous value reconfirmed by an in- {
service test run prior to the time it is returned to l
service or immediately if not removed from service, i to demonstrate that performance parameters which could I be affected by the replacement, repair or maintenance I are within acceptable limits. Deviations between the previous and new reference value shall be identified and analyzed. Verification that the new value repre-sents acceptable operation shall be documented in the record of tests (IWV-6000).
8 Adjustment of stem packing, limit switches, or control system valves, and removal of the bonnet, stem assembly, actuator, internals, or control system components are examples of maintenance that could affect valve performance parameters.
Rev. 9 V-65
I
( D RRB-GV-2 (Continued)
- 5. TO ESTABLISH AN ADDITIONAL SET OF REFERENCE VALUES If it is necessary or desirable for some reason, other than stated in 4 above, to establish additional reference values, an in-service test shall first be run at the conditions of an existing set of reference values and the results analyzed. If operation is acceptable, a second test shall be performed under the new conditions as soon as practical. The results of the second test shall establish the additional reference values. Whenever additional reference values are established the reasons for doing so shall be justified and documented in the record of tests (IWV-6000).
Rev. 9 V-66
. o l RELIEF REQUEST BASIS NUMBER: GV-3 SYSTEM: See attached listing VALVE: See attached listing CATEGORY: A or A-C CLASS: 1 or 2 FUNCTION: Primary Containment Isolation TEST REQUIREMENT: LT CODE PARAGRAPHS: IWV-3421 through IWV-3427 BASIS FOR RELIEF:
IWV-3421 through IWV-3425:
The applicable leak test procedures and requirements for :on-tainment isolatico valves are determined by 10 CFR 50, Appendix J. Relie ' rom Paragraphs IWV-3421 thorugh IWV-3425 is acceptable since the intent of these paragraphs is met by the Appendix J requirements. This testing will continue to give reasonable assurance that in the event of the postulated loss-of-coolant accident, the total release of fission pro-ducts from the primary containment to the environs is limited I such that off-site doses would be well below the values specified in 10 CFR 100. j IWV-3426: ,
1 Paragraph IWV-3426 states that leakage rates may be specified by the Owner. In this case, 10 CFR 50, Appendix J, Paragraph III.C.3 states that the combined leakage rate for all penetrations and valves subject to Type B and C tests shall be less than 0.60 La.
Additionally, Vermont Yankee Technical Specifications, Section 3.7.A.4, states that the leakage from any one isola-tion valve shall not exceed 0.05 La and the leakage from any one main steam line isolation valve shall not exceed 15.5 scf/hr at 44 psig (Pa).
IWV-3427(a):
Vermont Yankee Technical Specifications, Section 4.7.A.4 states that repair and retest shall be conducted to ensure l compliance. Therefore, the intent of IWV-3427(a) is met. '
Rev. 9 V-37 I
J
i .
l.
RRB-GV-3 (Continued)
IWV-3427(b):
Paragraph IWV-3427(b) requires:
- 1) A doubling of the test frequency upon a reduction of the margin between the measured leakage rate and the maximum permissible rate by 50%, and
- 2) Repair or replacement should a projection based on three or more tests indicate that the leakage rate of the next scheduled test will exceed the maximum per-missible leakage rate by greater than 10%.
The above limits have been compared to previous Appendix J 1eakage rate test data taken since 1976. This comparison ,
suggests that the requirements of IWV-3427(b) do not provide !
accurate predictions of future valve leakage in all cases since ;
increased valve leakage may not be a result of degradation.
When performing periodic Appendix J 1eak testing, factors other than degradation attribute to the final results. These factors may cause either an increase or decrease in the leakage rate, thereby making a determination of the valve condition based solely on trending difficult. These factors are summarized as follows:
- 1) Boundary valves which define tne test envelope have i individual leakage characteristics which can change from use, packing age, and closure force. Since these factors can affect each boundary valve and all resulting leakage is assigned to the tested valve, a repeatable periodic leakage characteristic for the tested valve is difficult to determine. Field test data supports this fact as summarized below.
- 2) Due to operational requirements, boundary configuration changes may be necessary. This can affect leakage and indicate degradation of the tested valve that does not exist.
- 3) Due to operational requirements, testing may be per-formed by different methods. Test method and boundary changes make a repeatable periodic leakage charac-teristic for the tested valve difficult to determine.
The variance of the leakage rate test data and the difficulty in trending such data is shown by a study of the Appendix J 1eakage rate test data for valves 6" nominal pipe size and larger. Data from 1976 to the present was input into a computer program which performed least squares curve fits on the data, t Curves for 25 equations were fitted to the data for each I valve. Equation coefficients, correlation coefficients, and the best fit curve was computed in each case. In addition, I Rev. 9 V-68
l i
- O ll RRB-GV-3 (Continued) projections were made at intermediate points using the best l fit curves. The average deviation between the projected and i actual test results was 145%. In addition, the projections provided early indication of an actual failure only 20% of the time. ,
In summary, strict compliance with IWV-3427(b) may require an increase in valve testing, maintenance, and personnel radiation exposure without a compensating increase in the level of safety since predicting future valve leakage is statistically unreliable.
Relating to the requirement of IWV-3427(b) to conduct testing during cold shutdowns, Relief Request Bases contained within the Inservice Testing Program contain sufficient justifica- l tion to test certain valves only on a refueling outage basis. ,
The test frequency of these valves cannot be increased without jeopardizing plant operations.
ALTERNATE TESTING:
Ferform leak testing, analysis and corrective actions in '
accordance with the Vermont Yankee Primary Containment leak Rate Testing Program, 10 CFR 50, Appendix J and the following additional requirements:
For valves 6" nominal pipe size and larger:
- 1) If a leakage rate exceeds the rate determined by the previous test by an amount that reduces the margin between the measured leakage rate and the maximum permissible rate by 50% or greater, and A review of previous test results indicates that this !
margin reduction may be caused by degradation, the test i frequency shall be increased as follows: '
a) For valves which can be tested during cold shutdown, i the test frequency shall be doubled; the tests I shall be scheduled to coincide with a cold shutdown until corrective action is taken, at which time the original test frequency shall be resumed. !
b) For valves which can only be tested during refueling outages, the test frequency shall remain ,
l at each refueling outage.
- 2) If tests show a leakage rate increasing with time, and a projection based on three or more tests indicates that the leakage rate of the next scheduled test will exceed the maximuu permissible leakage rate by grater than 10%, and A review of previous test results indicates that this projection may indicate actual degradation, the valve shall be replaced or repaired.
Rev.9 V-69
]
, e RELIEF REQUEST BASIS GV-3 .
Listing of Systems and Valves SYSTEM VALVE Service and Instrument Air V72-378, V72-38A/B, V72-898/C V72-103 Reactor Building Closed Cooling Water V70-113, V70-117 Nuclear Boiler V2-27A/B, V2-28A/B, V2-39, V2-40, V2-74, V2-77, V2-80A-0, V2-86A-0, V2-96A/B Core Spray V14-5A/B, V14-12A/B, V14-13A/B, V14-26A/B High Pressure Coolant Injection V23-15, V23-16, V23-25, V23-36, V23-56, V23-62, V23-65, V23-842, V23-843, SSC-23-12, SSC-23-13, Control Rod Drive V3-181 Residual Heat Removal V10-16A/B, V10-17, V10-18, V10-19A-0, V10-25A/B, ,
V10-26A/B, V10-31A/B, V10-32, '
V10-33, V10-34A/B, V10-39A/B, V10-39A/B, V10-46A/B Reactor Core Isolation Cooling V13-15, V13-16, V23-27, V23-29, V13-38 V13-41, V13-50, l SSC-13-9, SSC-13-10 i Primary Containment and Atmosphere SB16-19-6, SB16-19-6A/B Control SB16-19-7, SB16-19-7A/B, SB16-19-8, SB16-19-9, SB16-19-10, SB16-19-11A/B, V16-19-12A/B, V16-20-20, !
V16-20-22A/B, V16-19-23 )
Reactor Water Cleanup V12-15, V12-18, V12-68 I Radwaste V20-82, V20-83, V20-94, V20-95 Containment Atmosphere FS0-109-75A1,2, Dilution FS0-109-75B1,2, FS0-109-75C1,2, FSO-7501,2, VG-75A3,4, FS0-109-76A/B, VG-23, VG-34, VG-25, VG-26, VG-33, VG-34, ;
VG-9A/B, VG-22A/B, NG-11A/B, j NG-12A/B, NG-13A/B TIP Ball A-C Rev, 9 V-70 i
l NOTES
- 1. A minimum of 1/2 of all safety valves shall be bench-checked or replaced l with a bench-checked valve each refueling outage. Both valves shall be checked or replaced every two refueling outages. The lift point of the safety valves shall be set as specified in Technical Specification Section 2.2.8.
- 2. A minimum of 1/2 of all relief valves shall be bench-checked or replaced with a bench-checked valve each refueling outage. All four valves shall be checked or replaced every two refueling outages. The set pressures shall be as specified in Technical Specification Section 2.2.B.
- 3. Prior to quarterly exercise and timing tests, decrease reactor power to less than 75 percent. At least twice a week, the MSIVs shall be oxercised by partial closure and subsequent r eopening.
- 4. During each refueling outage, explode one of the three charges manufactured in the same batch to verify proper function. Then install the untested charges in the explosion valves.
- 5. Proper valve operation is shown both by the decrease in pump discharge pressure upon opening of valves V10-16A-D and by proper automatic closing of V10-16A-D at approximately 2000 gpm.
- 6. Valves are passive unless the pumpback system has operated during the cycle.
- 7. Each refueling outage, each valve will be tested to determine the force required to open each valve from fully closed to fully open.
- 8. Only one valve in each line is required to be operable per Tech. Spec. Table 4.7.2.b.
- 9. Each refueling outage, each valve will be tested to verify that the setting is between 1400 and 1490 psig.
- 10. Valves shall be leak tested each refueling outage. Maximum leakage limit shall be 1.0 gpm at 101815 psid.
- 11. Valves V23-65 and V13-50 will also be disassembled and inspected at least once every 10 years. (LER 87-18 and NRC Inspection Report 50-271/87-21).
Rev. 9 V-71
TABLE 1 In addition to the allowable ranges established per IWV-3417 and modified by relief request basis GV-2, the below quantitative values are established based on the plant safety analysis. If these values can not be met the valve shall be declared inopera-tive.
MAXIMUM CLOSING MAXIMUM OPENING VALVE SYSTEM TIME (SECL TIME _1SE Q _ j V70-117 RBCCW 45 i V72-38A/B Service and Instrument Air 20 -
l V2-39 Nuclear Boiler 5 (RA) f i
V2-40 Nuclear Boiler 5 (RA) l V2-53A/B Nuclear Boiler 33 * !
V2-74 Nuclear Boiler 35 V2-77 Nuclear Boiler 35 !
V2-80A-D Nuclear Boiler 5 ** j i
V2-86A-0 Nuclear Boiler 5 *~*
V14-11A/B Core Spray 8 .
V14-12A/B Core Spray 8 V14-26A/B Core Spray 45 f
V23-14 HPCI 20 V23-15 HPCI 55 ,
V23-16 HPCI 55 l
V23-19 HPCI 20 l
V23-20 HPCI 20 l V23-25 HPCI 10 !
l V10-13A-D RHR 100 24 ,
t t V10-15A-D RHR 24 ' '
V10-17 RHR 28 i i
V10-18 RHR 28 ,
Rev. 9 !
V-72
. . l.
r TABLF 1 (Cont.)
MAXIMUM CLOSING MAXIMUM OPENINO VALVE SYSTEM TIME (SEC) TIME (SEC)
V10-25A/B RHR 120 24 V10-26A/B RHR 70
/
V10-27A/B RHR 120 24 V10-31A/D RHR 70 V10-32 RHR 25 V10-33 RHR 25 V10-34A/B RHR 120 :
V10-38A/B RHR 45 V10-39A/B RHR 70 V10-57 RHR 25 V10-66 RHR 25 ;
V13-15 RCIC 20 V13-16 RCIC 20 V13-39 RCIC 30 )
i V13-41 RCIC 30 SB16-19-6 PCAC 10 SB16-19-6A/B PCAC 10 SB16-19-7 PCAC 10 ***
SB16-19-7A/B PCAC 10 ***
SB16-19-8 PCAC 10 1 1
S816-19-9 PCAC 10 l
S816-19-10 PCAC 10 l SB16-19-23 PCAC 10 V20-82 RADWASir 20 Rev. 9 V-73 l
~_
o s e TABLE 1 (Cont.)
MAXIMUM CLOSING MAXIMUM OPENING VALVE SYSTEM TIME (SEC) TIME (SEC)
V20-83 RADWASTE 20 V20-94 RADWASTE 20 V20-95 RA0 WASTE 20 V12-15 RWCU 25 V12-18 RWCU 25 V12-68 RWCU 45 SGT-1A/B HVAC-Reactor Building 3 SGT-2A/B HVAC-Reactor Building 3 SGT-3A/B HVAC-Reactor Building 3 SGT-4A/B HVAC-Reactor Building 3 SGT-5 HVAC-Reactor Building 3 HVAC-9 HVAC-Reactor Building 3 HVAC-10 HVAC-Reactor Building 3 HVAC-11 HVAC-Reactor Building 5 HVAC-12 HVAC-Reactor Building 3 FS0-109-76A/B CAD 5 (RA)
- The closure time shall not be less than 27 seconds
- The closure time shall not be less than 3 seconds
- Valves SB16-19-7 and SB16-19-7A shall have stops installed to limit valve opening to 50' or less.
RA Rapid Acting Valves. A maximum limiting stroke time of 2 seconds is established.
See Relief Request Basis Number RRB-GV-2.
Rev. 9 V-74
, . I I
TABLE 2 VALVES IDENTIFIED FOR COLD SHUT 00WN EXERCISING DISCUSSION:
IWV-3412 permits valves to be exercised during cold shutdowns when exercising is not practical during plant operation. The ASME code further requires that these valves be specifically identified and full-stroke exercised during cold shutdowns. Since the requirements of the ASME code ,1re being met, a relief request is not required. The below listing provides the required valve identi-fication.
Vermont Yankee differentiates, for valve testing purposes, between the cold shutdown mode and the refueling mode. That is, for valves identified for testing during cold shutdown, testing will be performed during both cold shut-downs and each refueling outage. For valves identified for testing during refueling outages, specific relief requests are provided in the IST Program and testing is performed only during each refueling outage.
TESTING GUIDELINES:
Cold shutdown testing of valves will be performed under the following guidelines:
- 1. Testing will commence as soon as practical after cold shutdown is achieved, but no later than 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> after shutdown.
- 2. Testing shall continue until either all testing is completed or the plant is ready to return to operation. Completion of all valve testing is not a prerequisite to return to operation.
- 3. Increases in valve testing frequency and required corrective actions prior to return to operation shall be in accordance with Relief Request Basis GV-1 and GV-2, respectively.
- 4. Any testing not completed during one cold shutdown will be performed during any subsequent cold shutdowns starting from the last test per-formed at the previous cold shutdown.
- 5. For planned shutdowns, where ample time is available and testing of all valves identified for the cold shutdown test frequency will be accomplished, exceptions to the 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> may be taken.
Rev. 9 V-75
. . i
'l TABLE 2 (Cont.)
SYSTEM VALVE FUNCTION BASIS / ALTERNATE TESTING RBCCW V70-113 RBCCW to Containment Valve is required to be open Check Valve during power operation.
Shutting the valve would stop cooling water flow to vital containment equipment.
Valve will be verified to close I during cold shutdowns and refueling outages, i
V70-117' RCCCW Return Valve cannot be exercised Isolation Valve during power operation since j closing the valve would stop 1 cooling water flow to vital containment equipment.
Valve will be full stroke exer-cised during cold shutdowns and refueling outages.
Nuclear Boiler SR2-14E-L Relief Valve Discharge Valves cannot be exercised Line Vacuum Breaker during power operation since l
valves are inside the drywell I and are inaccessible when at j power.
Valves will be manually exercised during cold shutdowns when the drywell is accessible and during refueling outages.
V2-53A/B Recirculation Pump Valve exercising during power V2-54A/B Discharge and Bypass operation would require a reac-Valves tor trip.
Valves will be full stroke exercised during cold shutdowns and refueling outages.
Core Spray V14-13A/B Injection Check Valves cannot be exercised Valves manually since valves are located inside the primary con-tainment. Valves cannot be exercised with flow since pump discharge pressure cannot over-come reactor pressure.
These valves will be manually full stroke exercised during cold shutdowns when the drywell is accessible and during refueling outages.
R3v.9 V-76 '
/
e w TABLE 2 (Cont.)
SYSTEM aLVE FUNCTION BASIS / ALTERNATE TESTING ,
HPCI V23-18 Injection Check Valve cannot be exercised Valve during power operation since flow through this valve must be injected into the reactor coolant system. This would thermally shock the reactor nozzles. The cold water injec-tion would also cause a reac-tivity excursion. Manual valve operation is not possible during power operation since the valve is located in the steam tunnel which is unac-cessible.
Valve will be manually fully stroke exercised during cold shutdowns and refueling outages. .
1 V23-61 Torus Suction Valve cannot be full stroke Check Valve exercised during power opera-tion since there is no full flow test loop available to recirculate the water back to the torus. There are no means to manually stroke the valve.
Valve cannot be stroked via a system injection into the reac-tor since that would result in a reactivity excursion and potentially thermally shocking the reactor nozzles.
Valve will be verified to open freely and stroke fully during cold shutdowns and refuel outages.
RHR V10-17 Primary Containment Valves cannot be exercised V10-18 Isolation during power operation since there is a 100 psig interlock that prevents opening these valves during power operation.
Valves will be exercised during cold shutdowns and refuel outages.
R3v. 9 V-77
- )
TABLE 2 (Cont.)
SYSTEM VALVE FUNCTION BASIS / ALTERNATE TESTING V10-46A/B LPCI Injection Valves cannot be exercised Check Valves during power operation since the valves are located inside the primary containment.
Exercising the valves by system flow is not possible during power operation since pump discharge is unable to overcome reactor coolant system pressure.
Valves will be manually full stroke exercised during cold shutdowns when the drywell is accessible and during refueling outages.
RCIC V13-22 Injection Check Valve cannot be exercised Valve during power operation since flow through this valve must be injected into the reactor coolant system. This would thermally shock the reactor nozzles. The cold water injec-tion would also cause a reac-tivity excursion.
Valve will be full stroke exer-cised during cold shutdowns and refueling outages.
R:v. 9 V-78
- > e a
TABLE 2 (Cont.)
SYSTEM VALVE FUNCTICN BASIS / ALTERNATE TESTING V13-40 Torus Suction Valve cannot be full stroke Check Valve exercised during power opera-tion since there is no full flow test loop available to recirculate the water back to the torus. There are no means to manually stroke the valve.
Valve cannot be stroked via a
- .ystem injection into the reac-tor since that would rsuit in a reactivity excursion and poten-tially thermally shocking the reactor nozzles.
Valve will be verified to open freely and stroke fully during cold shutdowns and refuel outsges.
PCAC S816-19-8 Primary Containment Valves cannot be exercised V16-19-23 Isolation during power operation since this would cause the loss of the differential pressure bet-ween the drywell and the suppression chamber. This DP is a required condition of plant operation. ,
Valves will be full stroke exercised during cold shutdowns j and refueling outages. l l
V16-19-12A/B Primary Containment Vacuum breaker cannot be exer- '
Isolation cised during power operation since there is no test loop available. There are no means to manually stroke the vacuum breaker.
During cold shutdowns and !
refueling outages, each vacuum '
breaker will be tested to determine that the force required to open the vacuum breaker does not exceed the force specified by Tech. Spec.
Section 3.7 A.5.a and each vacuum breaker will be inspected and verified to meet the design requirements.
R2v. 9 V-79
,, e TABLE 2 (Cont.)
SYSTEM VALV( F4NCTION BASIS / ALTERNATE TESTING CR0 V3-181 Primary Containment Valve cannot be exercised Isolation during power operation si.9ce this wou'id require isolating and venting a portion of the CRD system. This would cause hydraulic instability throughout the system. This situation is potentially unsafe until the system can be re-balanced and the rod strokes retimed. This cannot be done during power operation.
Valve is verified open during normal system operation. During cold shutdown and refueling outages, the valve will be verified to close.
Scrvice and V72-89B/C Primary Containment Valve cannot be exercised Instrument Air Isolation during power operation since closing the valve could cause the air operated main steam isolation valves to close, resulting in a reactor scram.
Valve is verified open during normal system operation. During cold shutdown and refueling outages, the valve will be 1 verified to close.
1 I
l i
I I
d R v. 9 l i V-80 !
1 1
__ _ _ -. -_____,_ . _ __ _ _ _ __ _ __, . . _ _ _ . . _ _ _ _ _ _ __ ._ _ . _ . _ _ _ _ _ _