ML17227A601
| ML17227A601 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie  |
| Issue date: | 08/11/1992 |
| From: | FLORIDA POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML17227A598 | List: |
| References | |
| JNS-PSL-204, NUDOCS 9209240430 | |
| Download: ML17227A601 (544) | |
Text
FLORIDA POWER and LIGHT COMPANY NUCLEAR ENERGY SERVICES 700 Universe Boulevard t'uno Beach, Florida 33408 FIRST TEN-YEAR INSERVICE INSPECTION INTERVAL INSERVICE TESTING PROGRAM FOR PUMPS AND VALVES ST. LUCIE NUCLEAR POWER PLANT UNIT NO. 2 DATE OF COMMERCIAL OPERATION: AUGUST 8, 1983 FLORIDA POWER & LIGHT P.O. BOX 128 FT. PIERCE, FL. 34954 NRC DOCKET NUMBER: 50-389 DOCUMENT NUMBER: JNS-PSL-204 REVISION 2 ST. LUCIE PLANT REVIEWS AND APPROVALS:
PREPARED BY:
PSL LANT IST ENGINEER DATE'PPROVED BY: DATE:
PS T ST & CODE SUPERVISOR 9209240430 o 5000389 I PDR ADQCK PDR 6
Revision 2 08/01/92 Table of Contents Pacae Table of Contents Record of Revisions 1.0 Introduction 2.0 Applicable Documents 3.0 Inservice Testing Program For Pumps 3.1 Code Compliance 3 ."2 Allowable Ranges of Test Quantities 3.3 Testing Intervals 3.4 Pump Program Table Relief Requests for Pump Testing Inservice Testing Program For Valves 4.1 Code Compliance 4.2 Testing Intervals 4.3 Stroke Time Acceptance Criteria 4' Check Valve Testing 4.5 Valve Program Table 4.6 Relief Requests For Valve Testing A Pump Program Tables B Pump Program Requests For Relief C Valve Program Tables D Valve Program Requests For Relief E Cold Shutdown Justifications
Revision 2 08/01/92 RECORD OF REVISIONS REVISION DESCRIPTION OF REVISION DATE NUMBER REASON FOR THE CHANGE REVISED APPROVALS 0 Initial 10 year submittal 08/08/83 Program Update 01/30/87 Program Update for Generic Letter 89-04 08/01/92
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Revision 2 08/01/92 INSERVICE TESTING (IST) PROGRAM PLAN ST. LUCIE UNIT 2
1.0 INTRODUCTION
Revision 2 of the St. Lucie Unit 2 ASME Inservice Inspection (IST) Program will be in effect through the end of the first 120-month (10-year) interval unless revised and reissued for reasons other than the routine update required at the start of the second interval per 10 CFR 50.55a(g). The first inspection interval is defined as follows:
Beceins Ends August 8, 1983 August 8, 1993 This document outlines the IST Program for St. Lucie Plant, Unit 2, based on the requirements of Section XI of the ASME Boiler and Pressure Vessel Code, 1980 Edition, including all addenda thereto through Winter, 1980 (the Code). References in this document to "IWP" or "IWV" correspond to Subsections IWP and IWV, respectively, of the ASME Section XI, 1980 Edition, unless otherwise noted.
The inservice testing identified in this Plan are to be performed specifically to verify the operational readiness of pumps and valves which have a specific function in mitigating the consequences of an accident or in bringing the reactor to a safe shutdown.
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Revision 2 08/01/92
- 2. 0 APPLICABLE .DOCUMENTS This Program Plan was developed per the requirements -and guidance provided by the following documents:
2.1 Title 10, Code of Federal Regulations, Part 50 2.2 NRC Regulatory Guides Division 1 2.3 Standard Review Plan 3.9.6, "Inservice Testing of Pumps and Valves 2.4 Final Safety Analysis Report, St. Lucie Unit 2 2.5 St. Lucie Plant Unit 2 Technical Specifications 2.6 ASME Boiler and Pressure Vessel Code,Section XI, 1980 Edition and Addenda through Winter, 1980 2'. 7 NRC Generic Letter 89-04, "Guidance on Developing
~Acceptable Inservice Testing Programs" 2.8 Minutes of the Public Meetings on Generic Letter 89-04 2.9 .St. Lucie Unit 1 Interim Relief From the Inservice Testing Program for Pumps and Valves (TAC No. 74794)
- 2. 10 Supplement to Minutes of the Public Meetings on Generic Letter 89-04 by J. G. Partlow, 26 September .1991 2.11 Request for -Industry/NRC-Accepted Interpretation on "Practical" as Applied by ASME Code Section XI, IWV-3412(a) by Martin J. Virgilio, Assistant Director for Regions IV and V.
2.12 St. Lucie Unit 2 Inservice Testing (IST) Program Relief Request, 5 December 1991
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Revision 2 08/01/92 3.0 INSERVICE TESTING PROGRAM FOR PUMPS 3.1 Code Compliance This IST Program for pumps meets the requirements of Subsection IWP of the Code and any interpretations or additional requirements imposed by Generic Letter 89-04.
Where these requirements have been determined to be impractical, conformance would cause unreasonable hardship without any compensating increase in safety, or an alternative test provides an acceptable level of quality and safety, relief from Code requirements is requested pursuant to the requirements of 10 CFR 50.55a(g)(5)(iii) and Generic Letter 89-04.
3.2 Allowable Ranges of Test Quantities The allowable ranges for test parameters as specified in Table IWP-3100-2 will be used for all measurements of pressure, flow, and vibration except as provided for in specific relief requests. In some cases the performance of a pump may be adequate to fulfillits safety function even though there may be a value of an operating parameter that falls outside the allowable ranges as set forth in Table IWP-3100-2. Should such a situation arise, an expanded allowable may be determined, on a case-by-case .basis, in accordance with IWP-3210 and ASME Code Interpretation XI-1-79-19.
3.3 Testing Intervals The test frequency for pumps included in the Program will be as set forth in IWP-3400 and related relief requests.
A band of +25 percent of the test interval may be applied to a test schedule as allowed by the St. Lucie Unit 2 Technical Specifications to provide for operational flexibility.
Revision 2 08/01/92 3.4 Pump Program Table Appendix A lists-those pumps'.included in'the IST Program with .references to parameters to be measured and
- 'pplicable requests for relief.
3.5 Relief Requests for Pump Testing Appendix B includes all relief requests related to pump testing.
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Revision 2 08/01/92 4.0 'INSERVICE.TESTING PROGRAM'OR VALVES.
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- 4. 1 Code Compliance This IST Program for'alves meets 'the requirements of Subsection IWV of the Code and any interpretations or additional requirements imposed by Generic Letter 89-04.
Where these requirements have been determined to be impractical, conformance. would cause unreasonable hardship without any compensating increase in safety, or an alternative test provides an acceptable level of quality and safety, relief from Code requirements is requested pursuant to the requirements of 10 CFR 50.55a(g)(5)(iii) and Generic Letter 89-04.
4.2 Testing Intervals The test frequency for valves included in the Program will be as set forth in IWP-3400 and related relief requests. A band of +25 percent of the test interval may be applied to a test schedule as allowed by the St. Lucie Unit 2 Technical Specifications to provide for operational flexibility. Where quarterly testing of valves is impractical or otherwise undesirable, testing may be performed during cold shutdown periods as permitted by IWV-3412(a). Justifications for this deferred testing are provided in Appendix E.
4.3 - Stroke Time Acceptance -Criteria When required, the acceptance criteria for the stroke times of power-operated valves will be as set forth in Generic Letter 89-04.
4.4 Check Valve Testing Full-stroke exercising of check valves to the open position using system flow requires that a test be performed whereby the predicted full accident condition flow rate through the valve be verified and measured.
Any deviation to this requirement must satisfy the requirements of Generic Letter 89-04, Position 1.
Revision 2 08/01/92 4.5 .Valve .Program Table
-Appendix:C lists'those valves included in-the IST Program with references to required testing, respective test intervals, and applicable 'requests for relief.
4.6 Relief Requests for Valve Testing Appendix D includes all relief requests related to valve testing.
Revision 2 08/01/92 Appendix A Pump Program Tables
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FLORIDA POWER AND LIGHT COMPANY REVISION: 2 PUHP TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 1 INLET DIFF ~ FLOW BEARING PUHP NUMBER DESCRIPTION CL COORD SPEED PRES ~ PRES ~
- - RATE VIBRA. TEMP. REHARKS AFM 2A AUXILIARY FEEDWATER PUMP 3 N-13 NA Y Y Y:PR-4 N:PR-1 AFW 28 AUXILIARY FEEDWATER PUMP 3 M-13 'A Y Y Y:PR-4 Y ':PR-1 AFW 2C AUXILIARY FEEDWATER PUMP 3 K-13 Y Y Y Y:PR-4 N:PR-1 BAH 2A BORIC ACID MAKEUP PUMP 2 8-5 NA Y:PR-8 Y Y:PR-5 Y N:PR-1 BAH 28 BORIC ACID MAKEUP PUHP 2 C-5 NA Y:PR-8 Y Y:PR 5 Y N:PR-1 CCM 2A COMPONENT COOLIHG WATER PUHP 3 F-16 NA Y Y N:PR-1 CCW 28 COMPONENT COOLING MATER PUHP 3 F-17 NA Y Y N:PR-1 CCM 2C COMPONENT COOLING WATER PUMP 3 F-16 NA Y Y Y N:PR-1 CMG 2A CHARGING PUMP 2 C-3 NA Y Y Y Y:PR-12 N:PR-1 CHG 28 CHARGING PUMP 2 E-3 NA Y Y Y:PR-12 N:PR-1 CHG 2C CHARGING PUMP 2 G-3 NA Y Y Y:PR-12 N:PR-1 cscc CONTAINMENT SPRAY PUHP 2 G-4 NA, Y:PR-15 Y Y:PR-6 H:PR-1 CONTAINMENT SPRAY PUMP 2 H-4 HA .Y:PR-15 Y Y:PR-6 N:PR-1 DOT 2A DIESEL OIL TRANSFER PUMP 3 J-12 HA Y:PR-16 Y Y:PR-7 Y N:PR-1 DOT 28 DIESEL OIL "TRANSFER PUHP 3 L-12 NA Y:PR-16 Y Y:PR-7 Y N:PR-1 HPSI 2A HI PRESS SAFETY INJECTION PUMP 2 D-6 NA Y:PR-15 Y Y:PR-9 Y N:PR-1 c
MPSI 28 HI PRESS SAFETY INJECTION PUHP 2 8-6 NA ':PR-15 Y Y:PR-9 N:PR-1 HYD 2A HYDRAZINE PUMPS 2 C-11 Y N:PR-17N:PR-17 Y:PR-17 Y:PR-14 N:PR-1 HYD 28 HYDRAZINE PUMPS 2 D11 Y N:PR-17N:PR-17 Y:PR-17 Y:PR-14 N:PR-1 ICW 2A INTAKE COOLING 'WATER PUMP 3 M-4 NA Y:PR-11 Y Y Y:PR-13 N:PR-1 ICW 28 -" INTAKE COOLING WATER PUMP 3 H-7 NA Y:PR-11 Y Y Y:PR-13 N:PR-1 ICW 2C INTAKE COOLING WATER PUHP 3 H-5 NA Y:PR-11 Y Y V:PR-13 N:PR-1 LPSI 2A LO PRESS SAFETY INJECTION PUMP 2 E-6 NA Y:PR-15 Y Y:PR-10 Y N:PR-1 LPSI 28 LO PRESS SAFETY INJECTION PUHP 2 D 6 NA Y:PR-15 Y . Y:PR-10 Y N:PR-1
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Revision 2 08/01/92 Florida Power & Light Company INSERVICE TESTING PUMP TABLES St. Lucie Nuclear Plant Unit 2 PAGE : 2 LEGEND PUMP NUMBER Numerical designator indicated on the respective flow diagram.
DESCRIPTION Generic name/function of the pump.
CL ISI Classification per the associated ISI boundary drawing(s)
COORD Corresponds to the flow diagram coordinates of the pump.
Test Parameters The -table. indicates-by a "Y" (yes) or "N"-(no) that the specific parameter is measured, evaluated, and recorded per the applicable Code requirement. If a "N" is indicated, the associated relief request number is also noted in the same column.
PR-XX Where indicated this refers to the specific relief request (See Appendix B) related to any deviation regarding the measurement or analysis of a parameter.
Revision 2 08/01/92 Appendix B Pump Program Relief Requests
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-1 COMPONENTS:
All pumps in the Program SECTION XI RE UIREMENT:
The temperature of all centrifugal pump bearings outside the main flow path and of the main shaft bearings of reciprocating pumps shall be measured at points selected to be responsive to changes in the temperature of the bearings. (IWP-3300, 4310)
BASIS FOR RELIEF:
The data associated with bearing temperatures taken at one-year intervals provides little statistical basis for.
determining the incremental degradation of a bearing or any meaningful trending information or correlation.
In many cases the pump bearings are water-cooled and thus, bearing temperature is a function of the temperature of the cooling medium, which can vary considerably.
Vibration measurements are a significantly more reliable indication of pump bearing degradation than are temperature measurements. All pumps in the program are subjected to vibration measurements in accordance with IWP-4500.
Although excessive. bearing temperature is an indication of an imminent or existing bearing failure, it is highly unlikely that such a condition would go unnoticed during routine surveillance testing since it would manifest itself in other obvious indications such as audible noise, unusual vibration, increased motor current, etc.
Any potential gain from taking bearing measurements, which in most cases would be done locally using portable instrumentation, cannot offset the cost in terms of dilution of operator effort, distraction of operators from other primary duties, excessive operating periods for standby pumps especially under minimum flow conditions, and unnecessary personnel radiation exposure.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-1 (cont.)
BASIS FOR RELIEF cont.
Based on the reasons similar to those set forth above,, the ASME deleted the requirement for bearing temperature measurements in ASME OM Code, Subsection ISTB, the revised version of the Code for pump testing.
ALTERNATE TESTING:
None.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-2 COMPONENTS:
Various SECTION XI RE UIREMENT:
The full-scale range of each instrument shall be three times the reference value or less. (IWP-4120)
BASIS FOR RELIEF:
Table IWP-4110-1 requires the accuracy of instruments used to
>>".measure temperature and speed to-be equal.to or better than +5 percent for temperature and +2 percent for speed, both based on the full scale reading of the instrument. This means that the accuracy of the measurement can vary as much as. +15 percent and +6 percent, respectively, assuming the range of the instruments extended to the allowed maximum.
These IST pump- parameters are often measured with portable test instruments where commercially available instruments do not necessarily conform to the Code requirements for range.
In these cases, high quality calibrated instruments will be used where the "reading" accuracy is at least equal to the Code-requirement. for full-scale accuracy. This will -ensure that the measurements are always more accurate than the accuracy as determined by combining the requirements of Table IWP-4110-1 and Paragraph IWP-4120.
ALTERNATE TESTING:
Whenever portable instruments are used for measuring pump speed or bearing temperatures, the instruments will be such that the "reading" accuracy is as follows Temperature +5 percent Speed +2 percent B-3
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-3 COMPONENTS:
Applicable to all pumps in the Program SECTION XI RE UIREMENT:
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1.
(IWP-3300)
Pump inlet pressure shall be measured before starting a pump and during the test. (Table IWP-3100-1) t BASIS FOR RELIEF:
-.If the pumps being tested are in operation as a result .of-plant or system needs, it is unreasonable to reconfigure system lineups simply -to provide for measurement of static inlet pressure.
Inlet pressure prior to pump startup -is not a significant parameter needed for evaluating pump performance or its material condition.
.ALTERNATE TESTING:
When performing a test on a pump that is already in operation
""- ~ due -to system or. plant requirements,: inlet pressure will only be measured during pump operation.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-4 COMPONENTS:
Auxiliary Feedwater (AFW) Pumps 2A thru 2C (2998-G-080, Sh 2)
SECTION XI RE UIREMENT:
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1.
(IWP-3300)
Pump flow rate shall be measured during the test. (Table IWP-3100-1)
BASIS FOR RELIEF:
'There are only two practical flow paths available for performing inservice.testing of the AFW Pumps. These include the primary flow path into the main feed supply lines and thence to the .steam generator, , and the minimum-flow recirculation (mini-recirc*and-bypass test loop) which returns to the condensate storage tank. The former is provided with flow rate measuring instrumentation however the mini-recirc line is a fixed resistance circuit with no flow
.. instrumentation.
Pumping from the auxiliary feedwater system into the steam
,;; generators during ':plant 'ot operation is impractical and undesirable for the following reasons:
During auxiliary feedwater injection via the main feedwater lines while the plant is operating at power, a large temperature differential (approximately 375 deg-F) could exist that would result in significant thermal shock and fatigue cycling of the feedwater piping and steam generator nozzles.
Based on the expected duration of the testing and the flow rate of the pumps (150 to 200 gpm), it is expected that the cooldown of the steam generator would induce cooldown and contraction of the reactor coolant system resulting in undesirable reactivity variations and power fluctuations.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-4 (cont.)
ALTERNATE TESTING:
During quarterly testing of the AFW pumps while the pumps are operating through the fixed-resistance mini-recirc line, pump differential pressure and vibration will be measured and evaluated per IWP-3200 and IWP-6000.
During testing performed at cold shutdown, pump differential pressure, flow rate, and vibration will be recorded per IWP-3200 and IWP-6000. Testing during cold shutdowns will be on a frequency determined by intervals between shutdowns as follows:
For intervals of 3 months or longer each shutdown.
For intervals of less than 3 months testing is not required unless 3 months have passed since the last shutdown test.
This alternate testing agrees with the -requirements of NRC Generic Letter 89-04, Position 9 and, as such, is considered to be approved upon submittal.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-.5 COMPONENTS:
Boric Acid Makeup (BAM) Pumps 2A and 2B (2998-G-078, Sh 121)
SECTION XI RE UIREMENT:
Each inservice test shall include the measurement and observation of all quantities in Table-IWP-3100-1.
(IWP-3300)
Pump flow rate shall be measured during the test. (Table IWP-3100-1)
BASIS FOR RELIEF:
There are three practical flow paths available for performing inservice testing of'the BAM Pumps. These include the primary flow path into the charging pump suction header, a recirculation line leading back to the refueling water tank, and the minimum-flow recirculation (mini-recirc and bypass test loop) which returns to the BAM Tanks. None of these flow paths is totally satisfactory for the following reasons:
- . Operating the BAM -Pumps .discharging into, the, charging pump suction header requires the introduction of highly concentrated boric acid solution from the boric acid makeup tanks to the suction of the charging pumps. This, in turn, would result in'he addition of excess boron to the RCS. This rapid, insertion of negative reactivity would result in a rapid RCS cooldown and depressurization. A large enough boron addition would result in an unscheduled plant trip and a possible initiation of Safety Injection Systems.
During cold shutdown, the introduction of excess quantities of boric acid into the RCS is undesirable from the aspect of maintaining proper plant chemistry and the inherent difficulties that may be encountered during the subsequent startup due to over-boration of the RCS. The waste management system would be overburdened by the large amounts of RCS coolant that would require processing to decrease its boron concentration.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-5 (cont.)
- . -The second circuit:recirculates water to the -Refueling Water Tank (RWT) or the Volume Control Tank (VCT).
During normal plant operation at power it is undesirable to pump to the RWT and deplete the BAM Tank inventory.
One of the two BAM Tanks is maintained at Tech. Spec.
level while the other is used as required for plant operation. The Tech. Spec. BAM Tank cannot be pumped from because it must be maintained at a level near the top of the tank. The other BAM Tank's level will vary from test to test by as much as 15 to 20 feet. This variance in pump suction pressure will have a direct affect on pump head and flow such that test repeatability would be questionable.
- The minimum-flow recirculation flow path is a fixed resistance circuit of one inch pipe containing a flow limiting orifice. No flow rate measuring instrumentation is installed in-this line. Pumping boric acid from tank to tank would be possible but the flow rates would be small,.limiting .pump operation,to, the high head section of the pump curve. In addition, one= of the two BAM Tanks is maintained at Tech. Spec. level. while the other is used as required for normal plant operation. The Tech.
Spec. BAM Tank cannot be pumped, from because it must be maintained at a level near the top of the tank. This narrow band limits the amount that can be pumped to it it to only a few hundred gallons. The other BAM or'rom Tank's level will vary from test to test by as much as 15 to 20 feet. This variance in pump suction pressure will have a direct affect on pump head and flow such that test repeatability would be questionable.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-5 (cont.)
ALTERNATE TESTING:
During quarterly testing of the BAM pumps, while the pumps are operating through the fixed-resistance mini-recirc line, pump differential pressure and vibration will be measured and evaluated per IWP-3200 and IWP-6000.
During testing performed at each reactor refueling outage, jump differential pressure, flow rate, and vibration will be recorded per IWP-3200 and IWP-6000.
-'his >>alternate testing agrees with the requirements of NRC Generic Letter 89-04, Position 9 and, as such, is considered to be approved upon submittal; B-9
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'COMPONENTS:
Containment Spray (CS)= Pumps 2A and 2B (2998-G-088)
SECTION XI RE UIREMENT:
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1.
(IWP-3300)
Pump flow rate shall be measured during the test. (Table IWP-3100-1)
BASIS FOR RELIEF:
.There are two practical flow paths available for performing
.. inservice testing of the .CS Pumps. These include one that pumps borated water from the RWT to the RCS via the low-pressure injection header and the other, minimum-flow recirculation (mini-recirc and bypass test loop) which returns to the RWT The first would require modifying the shutdown cooling lineup while in cold shutdown; however, the shutdown cooling system
...;..cannot -provide sufficient .letdown flow to, the RWT to accommodate full design flow from the RWT while maintaining the necessary core cooling fun'ction. Thus, the only practical time- for testing these pumps =via 'this, flow path is during refueling outages when water from the RWT is used to refueling cavity.
fill the The minimum-flow recirculation flow path is a fixed resistance circuit containing a flow limiting orifice however no flow rate measuring instrumentation is installed.
ALTERNATE TESTING:
The CS pumps are operated through the fixed-resistance mini-recirc line during the quarterly pump testing. Pump differential pressure and vibration are measured and evaluated per IWP-3200 and IWP-6000.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-6 (cont.)
ALTERNATE TESTING: cont.
During the pump testing performed each reactor refueling, pump.
differential pressure, flow rate, and vibration will be recorded per IWP-3200 and IWP-6000.
This alternate testing agrees with the requirements of NRC Generic Letter 89-04, Position 9 and, as such, is considered to be approved upon submittal.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-7 COMPONENTS:
Diesel Fuel Oil Transfer Pumps 2A and 2B (2998-G-086, -Sh 1)
SECTION XI RE UIREMENTS:
Flow rate shall be measured using a rate or quantity meter installed in the pump test circuit. (IWP-4600)
The allowable ranges of inservice test quantities in relation to the referenc'e values are tabulated in table IWP-3100-2.
(IWP-3210)
BASIS FOR RELIEF:
There are two flow paths available for performing inservice testing on these pumps: the normal day tank fill line and the transfer lines used to transfer fuel oil between diesel oil storage tanks. Neither of these flow paths have installed flow instrumentation.
The day tank would have to be drained to use path for a pump flow test.
it as the flow To drain the day tank would require the pump to be disabled and additional diesel
-,generator run.time to use-up the fuel oil or. draining over-200 gallons of fuel oil into 55 gallon drums. Neither. draining method is acceptable. Even if the tank could be drained, the
--'-.length"of the pump"test"would -be limited= by the small volume of the day tank.
The most practical method of determining pump flow rate is by calculating the transfer rate of fuel oil between storage tanks. The pump flow test is divided into two sections. The pump is recirculated for 15 minutes to its own storage tank (A) for the first section of the flow test. During these 15 minutes, the pump is warmed up and vibration measurements are taken. Prior to the end of the 15 minutes, the pump's discharge valve is throttled to a preset value. The pump is stopped and the valve lineup is changed so that flow is now directed to the other storage tank (B).
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Revision 2 08/01/92 RELIEF REQUEST NO PR-7 (cont.)
BASIS FOR RELIEF:
While the pump's lineup is -changed, the pump's storage tank (A) level is measured 'by hand using a tape measure. The pump is then started and allowed to transfer a minimum of 3 inches of fuel oil, 5 to 6 inches is preferred. A final storage tank (A) level is measured at the end of the test. The pump's flow rate is calculated by converting the storage tank (A) level change into a volume change and then dividing it by the number of minutes the pump was run.
ALTERNATIVE TESTING:
During quarterly testing of the Diesel Generator Fuel Oil Transfer Pumps, pump differential pressure, flow rate,, and vibration will be recorded per IWP-3200 and IWP-6000. Flow rate will be based on the storage tank level changes over a measured period of pump operation. The allowable ranges for the test parameters as specified in Table IWP-3200-2 will be used for all measurements except for flow. In accordance with IWP-3200 and ASME Interpretation XI-1-79-19, the new pump flow limits and their calculations will be specified in the record of tests (IWP-6000).
A series of at least .four flow tests will be performed, for each pump to establish a new pump baseline. The calculated average flow rate, F(avg), of these tests will be used for the
" pump's reference value. "The"mean error for the individual flow rates and average flow rate will be calculated and combined by the sum of the squares to form a combined error (Sigma). The combined error will then be doubled (two standard deviations) to achieve a 95.4 4 accuracy that all acceptable flow rate tests will fall within this range. The new pump limits will be as follows:
Required Action [1.02 x F(avg)] + 2 Sigma Upper Alert [1.02 x F(avg)] + 2 Sigma Upper Acceptable [1.00 x F(avg)] + 2 Sigma Lower Acceptable Lower Alert
[0 '6 x F(avg)] 2
[0.94 x F(avg)] 2 Sigma Sigma Required Action [0.94 x F(avg) ] 2 Sigma The Lower Acceptable limit incorporates a 4 0 range for a small amount of pump degradation. This is the same amount that is included in the limits listed in Table IWP-3200-2.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-8 COMPONENTS:
~ Boric Acid Makeup Pumps 2A and 2B (2998-G-078, Sh 121)
SECTION XI RE UIREMENTS:
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1 except bearing temperatures, which shall be measured during at least one inservice test each year. (IWP-3300)
BASIS FOR RELIEF:
The system installation does not provide any mechanism for measuring pump suction pressures, and thus, the requirement for measuring suction pressure and pump differential pressures cannot be satisfied. A measure of pump suction pressure can; however, be determined by a calculation using the height of liquid in the boric acid makeup tanks. Since there is essentially fixed resistances between, the tanks and the pumps this will provide a consistent* value for suction pressures.
Since the tank levels are not expected to vary significantly during the tests, tank levels and associated calculations will
,....,only. be"taken once-during each.testinstead of. prior to..pump operation and during operation as required by Table IWP-3100-1~
'I ALTERNATE TESTING:
The Boric Acid Makeup Pump suction pressures will be calculated based on the height of liquid in the associated
.tank once during each inservice test. Subsequently, these calculated values will be used to determine pump differential pressures for evaluation of pump parameters.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-9 COMPONENTS:
High Pressure =Safety-Injection (HPSI) Pumps 2A and 2B (2998-G-078, Sh 130)
XI RE UIREMENT: 'ECTION Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1.
(IWP-3300)
BASIS FOR RELIEF:
During quarterly testing of the HPSI Pumps, the pumps cannot develop sufficient discharge pressure to overcome RCS pressure. Flow is routed .through a minimum flow test line
..leading to the RWT. This line has no installed flow rate measuring instrumentation and measuring .flow rate during quarterly testing is not practical.
During cold shutdown conditions, full flow operation of the HPSI pumps to the RCS is restricted to preclude RCS system pressure transients that could result in exceeding the pressure-temperature limits specified in the Technical
..Specifications, .Section 3.4.9.3.
NRC Generic Letter 89-04, Position 9, allows elimination of
" minimum flow ~test line- flow rate measurements providing inservice tests are performed during cold shutdowns or refueling under full or substantial flow conditions where pump flow rate is recorded and evaluated.
ALTERNATE TESTING:
During quarterly testing of the HPSI Pumps, pump differential pressure and vibration will be recorded per IWP-3200 and IWP-6000.
During testing performed at each reactor refueling, pump differential pressure, flow rate', and vibration will be recorded per IWP-3200 and IWP-6000.
This alternate testing agrees with the guidelines of NRC Generic Letter 89-04, Position 9 and, as such, is considered to be approved upon submittal.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-10 COMPONENTS:
.. Low -Pressure..Safety Injection (LPSI) Pumps 2A and 2B (2998-G-078, Sh 131)
SECTION XI RE UIREMENT:
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1.
(IWP-3300)
BASIS FOR RELIEF:
During quarterly testing of the LPSI Pumps, the pumps cannot develop sufficient discharge pressure to overcome RCS pressure. Flow is routed through a minimum 'flow test line leading to the RWT. This line has no installed flow rate measuring instrumentation .and measuring flow rate during quarterly testing is not practical.
During cold "shutdown,'the"LPSI 'pumps are used for residual heat removal. The substantial flow tests can be performed at this time. Pump differential pressure and flow rate will be recorded. However, due to the vibrations induced in the
..system, piping while the-. Reactor .Coolant Pumps are running,.
pump vibration readings =will only be measured during cold shutdowns where the RCPs are secured.
B-16
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Revision 2 08/01/92 RELIEF REQUEST NO PR-10 ALTERNATE TESTING:
During quarterly testing of the LPSI Pumps, pump differential pressure and vibration will be recorded per IWP-3200 and IWP-6000.
Substantial flow testing will be performed during cold shutdowns. Pump differential pressure, flow rate, and vibration IWP-6000.
(ifTestingsecured)
RCPs will be will be recorded per IWP-3200 and on a frequency determined by intervals between shutdowns as follows:
For intervals of 3 months or longer, each shutdown.
For intervals of .less than 3 months testing is not required unless 3. months have passed since the last shutdown test.
B-17
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-11 COMPONENTS:
Intake Cooling Water Pumps 2A, 2B and 2C (2998-G-082)
SECTION XI RE UIREMENT:
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1.
(IWP-3300)
Pump inlet pressure shall be measured before starting a pump and during the test. (Table IWP-3100-1)
BASIS FOR RELIEF:
The pumps listed, above. are vertical line shaft pumps submerged in the intake, structure with no practical means of measuring pump inlet pressure. The inlet pressure, however, can be determined by calculation using, as input, the'measured height of water above the pump inlet as measured at the intake.
During each inservice test, the water level in the intake pit remains relatively constant, thus only one measurement of level and the associated suction pressure calculation need be performed.
ALTERNATE TESTING:
During testing of these pumps, one value of inlet pressure will be calculated based on water level at the inlet structure.
B-18
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-12 COMPONENTS:
Reactor Coolant Charging .Pumps 2A, 2B, and 2C SECTION XI RE UIREMENT:
The frequency response range of the readout system (for instrument used to measure vibration amplitude) shall be from one-half minimum speed to at least maximum pump shaft rotational speed. (IWP-4520(b))
BASIS FOR RELIEF:
The reactor coolant charging pumps operate at approximately 210-215 rpm which equates to a rotational frequency of 3.5 Hz.
In accordance with the ASME Code, the frequency response for
.the vibration instruments would have to be one half of this or.
1.75 .Hz. Following an extensive investigation of available and potentially suitable instrumentation, it determined that instruments satisfying this requirement has been for the charging pumps are commercially unavailable.
ALTERNATE TESTING:
During testing of these pumps, vibration will be measured as
'required by IWP-4510, except that the lower frequency response for the instruments will be 10 Hz.
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Revision 2 08/01/92 RELIEF. REQUEST NO. PR-13 COMPONENTS:
Intake Cooling Water-Pumps 2A, 2B, and 2C SECTION XI RE UIREMENT:
The frequency response range of the readout system (for instrument used to measure vibration amplitude) shall be from one-half minimum speed to at least maximum pump shaft rotational speed. (IWP-4520(b))
BASIS FOR RELIEF:
The St. Lucie Plant has recently completed a major upgrade to its ASME pump vibration program to better comply with the Code. As part of the upgrade, new vibration instruments were-purchased. The instruments were chosen for their ease of use and reliability; however,'he instrument's lower frequency response does not comply with the Code when used on the Intake
.Cooling Water pumps.- The intake cooling water pumps operate at a shaft speed of approximately 885 rpm. Based on this speed and the Code requirement, the instrumentation used to measure vibration (displacement) would require a response range down to 7.38 hz. The new instruments are capable of a lower. frequency response to 10..hz, 2.62 Hz higher than the Code. The impact of procuring instruments along with the accompanying re-training that would be required is clearly unwarranted at this'ime simply. to gain a 'slightly better frequency response.
ALTERNATE TESTING:
During testing of these pumps, vibration will be measured as required by IWP-4510, except that the lower frequency response for the instruments will be 10 Hz.
B-20
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-14 COMPONENTS:
Hydrazine Pumps 2A and 2B SECTION XI RE UIREMENT:
The frequency response range of the readout system (for instrument used to measure vibration amplitude) shall be from one-half minimum speed to at least maximum pump shaft rotational speed. (IWP-4520(b))
BASIS FOR RELIEF:
The hydrazine pumps operate as low as 105 rpms. This equates to a rotational frequency of 1.75 Hz. In accordance with the ASME Code, the frequency response for the vibration.
.:instruments would have to be one half of this or 0.875 Hz.
Following an extensive investigation of available and potentially suitable instrumentation, it has been determined that instruments satisfying this. requirement for the hydrazine pumps'are commercially unavailable.
ALTERNATE TESTING:
During testing of these pumps, vibration will be measured as
.<<;.~required by IWP-4510,-except. that the lower frequency response for the instruments will be 10 Hz.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-15 COMPONENTS:
Containment Spray Pumps 2A- and 2B (2998-G-088)
Hi Press Safety Inject. Pumps 2A and 2B (2998-G-078 SH 130)
Lo Press Safety Inject. Pumps 2A and 2B (2998-G-078 SH 130)
SECTION XI RE UIREMENTS:
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1 except bearing temperatures, which shall be measured during at least one inseryice test each year. (IWP-3300)
BASIS FOR RELIEF:
The. system installation does not provide any installed suction gages. A measure of pump suction pressure can, however, be determined by calculation using the height of liquid in the Refueling Water Tank. During the quarterly pump tests, the flow rate, through the. suction-piping.,is very low, therefore, the amount of head loss is negligible. This is not the case during the substantial flow tests. The flow rates used during these tests would cause a noticeable head loss in the suction piping.
Since. the tank levels are not expected'to vary -significantly during the quarterly tests, tank levels and associated
..calculations, will..only be .taken. once. during each quarterly test instead of prior to pump operation and during operation as required by Table IWP-3100-1.
ALTERNATE TESTING:
During the quarterly pump tests, the pumps'uction pressures will be calculated based on the height of liquid in the associated tank. Subsequently, these calculated values will be used to determine pump differential pressures for evaluation of pump parameters.
During the cold shutdown or refueling substantial flow testing of these pumps, temporary suction gages will be installed to measure pump suction pressure.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-16 COMPONENTS:
Diesel Oil Transfer Pumps 2A and '2B '(2998-G-086 SH 1)
SECTION XI RE UIREMENTS:
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1 except bearing temperatures, which shall be measured during at least one inservice test each year. (IWP-3300)
BASIS FOR RELIEF:
The system installation does not provide any installed suction gauges . A measure of pump suction pressure can, however, be determined by calculation using the height of liquid in the
. Diesel Oil Storage Tank. During the quarterly pump tests, the
,flow rate through the suction piping is very low, therefore,=
the amount of head loss is negligible.
Since the tank levels are not expected to vary significantly during the quarterly tests, tank levels and associated calculations will only be taken once during each quarterly test instead of prior to pump operation and during operation as required by Table IWP-3100-1.
ALTERNATE TESTING:
During the quarterly pump tests, the pumps'uction pressures will be calculated based on the height of liquid in the associated tank. Subsequently, these calculated values will be used to determine pump differential 'pressures for evaluation of pump parameters.
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Revision 2 08/01/92 RELIEF REQUEST NO.
PR-17'OMPONENTS:
Hydrazine Pumps 2A and 2B (2998-G-088)
SECTION XI RE UIREMENTS:
Each inservice test shall include the measurement and observation of all quantities in Table IWP-3100-1 except bearing temperatures, which shall be measured during at least one inservice test each year. (IWP;3300)
Symmetrical damping devices or averaging techniques may be
'used "to,reduce 'instrumentfluctuations to within 24 of the observed reading. (IWP-4150)
BASIS FOR RELIEF:
The Hydrazine Pumps are positive displacement pumps with a variable speed drive. They-operate at a very low rpm and flow rate (0.71 to 0.82 gpm). The flow instrument orifice is located in the pump's suction line. Its output signal pulsates sharply with each stroke and cannot readily be averaged. The flow recorder for the hydrazine pumps, FR-07 2, displays a wide trace for flow rate. .The only way to know the true flow rate of the pumps is to collect the pumps output in a container and measure it.
During the 1992 Unit 2 refueling outage, several flow tests per hydrazine pump were performed. The discharge of one pump was directed to a container of a known volume. The amount of time to fill the container was measured and then used to calculate an average flow rate for the pump. Each of the flow tests for each pump were performed at a different pump rpm.
A correlation between pump rpm and average flow rate was developed and compared to the expected value. The measured and the expected correlations between rpm and flow rate were in close agreement. The expected correlation was based upon piston diameter, piston stroke, and pump rpm. Based upon these results, hydrazine pump flow rate .can be accurately set by selecting the proper pump rpm.
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Revision 2 08/01/92 RELIEF REQUEST NO. PR-17 (cont.)
BASIS FOR RELIEF cont.
Frequent performance of the above mentioned flow testing can not be performed. Hydrazine is a highly flammable liquid with cumulative. toxic affects when absorbed through the skin, inhaled, or ingested. It has also been identified as a known carcinogen.
ALTERNATE TESTING:
"" During the .quarterly pump tests, each pump's rpm will be measured to verify the required flow rate of 0.71 to 0.82 gpm.
Pump flow will be recorded but not alert trended and vibration will -be measured during the quarterly tests.
During each refueling outage at least one flow test will be performed for each pump to verify proper performance. Pump vibration. will be .,measured, during this flow test.
B-25
0 Appendix C Valve Program Tables
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Revision 2 08/01/92 Florida Power & Light Company INSERVICE TESTING VALVE TABLES St. Lucie Nuclear Plant Unit 2 PAGE : 1 LEGEND VALVE NUMBER The plant alpha-numerical designator for the subject valve COORD The coordinate location of the valve on the designated drawing CL .The ISI Classification of the valve as per the respective ISI boundary drawings CAT The valve category per Paragraph IWV-2200 SIZE The valve',s nominal size in inches TYPE The valve type A/P The active (A) or passive (P) determination for the valve per IWV-2100.
ACT. TYPE The, valve .actuator type-.as follows:
AO Air-operated DO -.Diaphram-operated MO Electric motor-operated MAN Manual valve PO Piston-operated S/A Self-actuated SO Solenoid-operated NORM POS. Designates the normal position of the valve during plant operation at power REM IND Notes if a valve has remote position indication FAIL MODE Identifies the failure mode (open or closed) for a valve. FAI indicates the valve fails "as is".
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Revision 2 08/01/92 Forida Power & Light Company INSERVICE TESTING VALVE TABLES St. Lucie Nuclear Plant Unit 2 PAGE 2 LEGEND Cont.
EXAM Identifies the test requirements for a valve as follows:
CV/C Check valve exercise to closed position.
CV/0 Check valve full-stroke exercise to open position.
.CV/PO 'Check -valve partial-stroke exercise to open position.
EC Exercise to closed position. For all category A or B power-operated valves stroke times will be measured unless excluded by an associated relief request..
EE Exercise valve to verify proper operation and stroking with no stroke time measurements. Requires observation of system parameters or local observation of valve operation.
EO Exercise to open position. For all category A or B power-operated valves stroke times will be measured unless excluded by an associ'ated relief request.
FS Fail safe test INSP Disassembly and inspection of check valves PEC Partial closure exercise for power-operated valves PI ~
Position indication verification SLT-1 Seat leakrate test per 10 CFR 50, App J SLT-2 Seat leakrate test for pressure isolation valves.
SLT-3 Seat 'leakage test of air accumulator check valves.
SRV Set point check for safety/relief valves
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Revision" 2 08/01/92 Florida Power 6 Light Company INSERVICE TESTING VALVE TABLES St. Lucie Nuclear Plant Unit 2 PAGE : 3 C
LEGEND Cont.
TEST FREQ The required test interval as follows:
QR Quarterly (during plant operation)
CS Cold shutdown as defined by Technical Specification 2Y Every 2 years RF Each reactor refueling outage (cycle). In the case where this is designated for safety/relief valves refer, to Table IWV-3510-1.
SP Other (See applicable Request for Relief)
RELIEF REQ. Refers to the -specific relief request associated with the adjacent test requirement. (See Appendix D)
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FLORIDA PONER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint-Lucie Nuclear Plant - Unit 2 PAGE : 4 P 8 ID: 2998-G-078 SH 107 SYSTEH: REACTOR COOLANT SYSTEH ACT. NORM REH FAIL TEST RELIEF VALVE NUHBER COORD. CL CAT. SIZE TYPE A/P TYPE POS ~ IND MODE EXAH FREQ REQ. REMARKS V-1460 G-6 2 8 F 000 GLOBE A SO LC YES FC EO CS Pl 2Y V-1461 G-6 2 B 1.000 GLOBE A SO LC YES FC EO CS PI 2Y V-1462 E-6 2 8 1.000 GLOBE A SO LC YES FC EO CS PI 2Y V-1463 E-6 2 8 1.000 GLOBE A SO LC YES FC EO CS Pl 2Y V-1464 D-4 2 B 1.000 GLOBE ' SO LC YES FC EO CS Pl 2Y V-1465 E-4 2 8 1.000 GLOBE A SO LC YES FC 'O CS Pl 2Y V-1466 G-5 2 8 1.000'GLOBE A SO LC YES FC EO CS PI 2Y
~ $f FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 5 P 8 ID: 2998-G-078 SN 108 SYSTEM: REACTOR COOLANT SYSTEH ACT ~ NORH REH FAIL TEST RELIEF VALVE NUHBER COORD. CL CAT ~ SIZE TYPE A/P TYPE POS. IND MODE EXAH FREQ REQ. ,
REMARKS V-1474 F-6 1 8 3.000 GLOBE A SO C YES FC EO CS PI 2Y V-1475 D-6 1 B 3.000 GLOBE A SO C YES FC EO CS PI 2Y V-1476 F-5 1 B 3.000 GATE A HO 0 YES FAI EC r PI 2Y V-1477 D-5 '1 8 3.000 GATE A HO 0 YES FAI EC QR PI 2Y
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FLORIDA PONER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE 6 P 8 ID: 2998-G-078 SN 109 SYSTEH: REACTOR COOLANT SYSTEM ACT. NORH REH FAIL TEST RELIEF
.VALVE NUHBER COORD. CL CAT. SIZE TYPE A/P TYPE POS. IND MODE EXAM 'FREQ REQ. - REMARKS V-1200 G-6 1 C F 000 SAFETY A S/A C NO SRV RF V.1201 G 6 1 C 3.000 SAFETY A S/A C NO SRV RF V-1202 G-6 1 C 3.000 SAFETY A S/A C NO SRV RF
FLORIDA POMER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 7 P 8 ID: 2998-G-078 SN 120 SYSTEH: CNEHICAL ANO VOLUHE CONTROL ACT. NORH REM FAIL TEST RELIEF VALVE NUMBER COORS CL CAT. SIZE TYPE A/P TYPE POS. IND HOOE EXAM FREQ REQ. REMARKS V-2522 E-7 2 A 2.000 GLOBE A DO 0 YES FC EC CS FS CS Pl 2Y SLT-1 2Y
FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 8 P II ID: 2998-G-078 SH 121 SYSTEM: CHEMICAL AND VOLUME CONTROL ACT. NORM REM FAIL TEST RELIEF VALVE NUMBER COORD. CL CAT. SIZE TYPE A/P TYPE - POS ~ IND MODE EXAM FREQ REQ ~ REMARKS FCV-2210Y C-2 2 B 1 F 000 GLOBE A DO C YES FC EC QR FS QR PI 2Y V-2177 C-3 2 C 3.000 CHECK A S/A C NO CV/0 RF VR-5 CV/PO CS V-2190 D-6 C 3.000 CHECK A S/A C NO CV/C QR CV/0 RF VR-5 CV/PO CS V-2191 E-3 2 C F 000 CHECK A S/A C NO CV/0 RF VR-5 CV/PO CS V-2443 C-4 2 C 3.000 CHECK A S/A C NO CV/C QR CV/0 RF VR-6 CV/PO QR VR-6 V-2444 B-4 2 C 3.000 CHECK A S/A C NO CV/C QR CV/0 RF VR-6 CV/PO QR VR-6 V-2501 F-4 2 B 4.000 GATE A MO 0 YES FAI EC CS Pl 2Y V-2504 F-3 2 B 3.000 GATE A MO C YES FAI EC CS EO CS Pl 2Y V-2505 G-7 2 A 1.000 GLOBE A DO C YES FC EC CS FS CS Pl 2Y SLT-1 2Y V-2508 C-6 2 B 3.000 GATE
' MO C YES FAI EO QR Pl 2Y V-2509 C-7 2 8 3.000 GATE A MO C YES FAI EO QR Pl 2Y V-2512 F-5 2 B F 000 GLOBE A DO C YES FC EC QR FS QR PI 2Y
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FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 9 CRC CCRC P 8 ID: 2998-G-078 SH 121 (cont) SYSTEM: CHEMICAL AND VOLUHE CONTROL ACT. HORN REM FAIL TEST RELIEF VALVE NUMBER COORD. CL CAT ~ SIZE TYPE A/P TYPE POS. IND MODE EXAM FREQ REQ. REMARKS V-2514 C-3 2 B 3.000 GATE A MO C YES FAI EO QR PI 2Y V-2524 F-7 2 A 1.000 GLOBE A DO C YES FC EC CS FS CS PI 2Y SLT-1 2Y V-2525 E 4 2 8 4.000 GLOBE A MO C YES FAI EC QR PI 2Y V-2526 E 3 2 C 4.000 CHECK A S/A C NO CV/0 RF VR-5 CV/PO CS V-2650 B-4 2 8 1.000 GLOBE A DO C YES FC EC FS PI
'RQR 2Y V-2651 D-4 2 8 1.000 GLOBE A DO C YES FC EC QR FS QR PI 2Y
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FLORIDA POUER AND LIGHT COMPAHY REVISIOH: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE: 10 P 8 ID: 2998-G-078 SH 122 SYSTEM: CHEMICAL AND VOLUHE CONTROL ACT. NORM REM FAIL TEST RELIEF VALVE NUMBER COORD. CL CAT. SI2E TYPE A/P TYPE POS. IND MODE EXAM - FREQ REQ. REMARKS SE-02-01 8-6 1 B 2.000 GLOBE A SO 0 YES FO Ec QR EO QR FS QR PI 2Y SE-02-02 B-7 1 8 2.000 GLOBE A SO 0 YES FO Ec QR EO QR FS QR PI 2Y SE-02-03 D-7 1 8 2.000 GLOBE A SO LC YES Fc Ec CS EO CS FS CS PI 2Y SE-02-04 D-7 1 B 2.000 GLOBE A SO LC YES Fc Ec CS EO CS FS CS PI 2Y V-2167 G-2 2 C F 000 CHECK A S/A C NO CV/C QR CV/0 QR V-2168 E-2 2 C 2.000 CHECK A S/A C NO CV/C QR CV/0 QR V-2169 C-2 2 C 2.000 CHECK A S/A C NO CV/C QR CV/0 QR V-2324 C-2 2 C 1.500 RELIEF A S/A C HO SRV RF V-2325 E-2 2 C 1.500 RELIEF A S/A C NO SRV RF V-'2326 G-2 2 C F 500 RELIEF A S/A C NO SRV RF V-2431 D-8 1 C 2.000 CHECK A S/A C NO CV/0 CS V-2432 C-8 1 C 2.000 CHECK A S/A C NO CV/0 QR V-2433 8-8 1 C 2.000 CHECK A S/A C HO CV/0 QR V-2440 G-2 2 C 2.000 CHECK A S/A 0 NO CV/0 CS V-2462 B-6 2 C 2.000 CHECK A S/A C NO CV/0 QR
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FLORIDA PONER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 11 P 8 ID: 2998-G-078 SN 122 (cont) SYSTEM: CHEHICAL AND VOLUHE CONTROL ACT. NORM REH FAIL TEST RELIEF
---VALVE NUHBER COORD. CL CAT ~ SIZE . TYPE -
A/P TYPE POS. IND 'MODE EXAH - FREQ -REQ. - REMARKS V-2515 F-8 1 B 2.000 GLOBE A DO 0 YES FC EC CS FS CS PI 2Y V-25'16 F-7 1 A 2.000 GLOBE A DO 0 YES FC EC CS FS CS PI 2Y SLT-1 2Y V-2523 B-6 2 8 2.000 GLOBE P DO LO YES FO PI 2Y V-2553 F-2 2 8 2.000 GLOBE A HO 0 YES FAI EC QR PI 2Y V-2554 D-2 2 B 2.000 GLOBE A HO 0 YES FAI EC QR PI 2Y V-2555<< C-2 2 8 2.000 GLOBE A HO 0 YES FAI EC QR PI 2Y V-2598 C-6 2 8 3.000 GATE A HO 0 YES FAI EO
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FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 12 P 8 ID: 2998-G-078 SH 130 SYSTEM: SAFETY INJECTION SYSTEM ACT. NORM REM FAIL TEST RELIEF
-- VALVE-NUMBER COORD. CL CAT. SIZE TYPE A/P TYPE POS. IND MODE EXAM 'FREQ REQ;=- REMARKS FCV-3301 E-2 2 B 10.000 BUTFLY A MO LO YES FAI EC QR PI 2Y FCV-3306 F-4 2 B 10 F 000 BUTFLY A MO LO YES FAI EC QR PI 2Y HCV-3512 E-2 2 B 10 ~ 000 BUTFLY A MO LC YES FAI EO QR PI 2Y HCV-3657 F-4 2 8 10.000 BUTFLY A MO LC YES FAI EO QR PI 2Y SE-03-2A G-2 2 A 2.000 GLOBE A SO C YES FC EC QR FS QR PI 2Y SLT-1 2Y VR-4 SE-03-2B G-2 2 A 2.000 GLOBE A SO C YES FC EC QR FS QR PI 2Y SLT-1 2Y VR-4 SR-07-1A E-7 2 C 0.750 RELIEF A S/A C NO SRV RF SR-07.18 D-8 2 C 0.750 RELIEF A S/A C NO SRV RF V-07000 F-7 2 C 14.000 CHECK A S/A C HO CV/0 RF VR-7 CV/PO QR VR-7 V-07001 E-7 2 C 14.000 CHECK A S/A C NO CV/0 RF VR-7 CV/PO QR VR-7 V.3101 H-3 2 C 2.000 CHECK A S/A C HO CV/0 RF VR-32 CV/PO CS VR-32 V-3102 D-6 2 C 2.000 CHECK A S/A C NO CV/C CS VR-30 CV/PO QR VR-30 INSP RF VR-30 V-3103 D-5 2 C 2.000 CHECK A S/A C HO CV/C CS VR-30 CV/PO QR VR-30 INSP RF VR-30
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FLORIDA POMER AHD LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 13 P & ID: 2998-0-078 SH 130 (cont) SYSTEM: SAFETY INJECTION SYSTEM ACT. NORM REM FAIL TEST RELIEF VALVE NUMBER COORS CL CAT ~ SIZE TYPE A/P TYPE POS ~ IHD MODE EXAM FREQ REQ. REMARKS V-3104 E-6 2 C 2.000 CHECK A S/A C NO CV/C CS VR-28 CV/0 RF VR-28 CV/PO QR VR-28 V-3105 D-6 2 C F 000 CHECK A S/A C NO CV/C CS VR-28 CV/0 RF VR-28 CV/PO QR VR-28 V-3106 F-5 2 C 10.000 CHECK A S/A C NO CV/0 CS V-3107 E 5 2 C 10.000 CHECK A S/A C NO CV/0 CS V-3401 D-7 2 C 6.000 CHECK A S/A C NO CV/0 RF VR-8 CV/PO QR VR-8 V-3410 B-7 2 C 6.000 CHECK A S/A C NO CV/0 RF VR-8 CV/PO QR VR-8 V-3412 C-4 2 C F 000 RELIEF A S/A C NO SRV RF V-3414 8-5 2 C 3.000 S/CHEK A S/A C NO CV/C QR CV/0 RF VR-9 CV/PO QR VR-9 V-3417 D-4 . 2 C 1 ~ 000 RELIEF A S/A C NO SRV RF V-3427 0-5 2 C 3.000 S/CHEK A S/A C NO CV/C QR CV/0 RF VR-9 CV/PO QR VR-9 V-3430 G-6 2 C 1.000 RELIEF A S/A C NO SRV RF V-3431 H-6 2 C 1.000 RELIEF A S/A C NO SRV RF V-3432 E-7 2 8 14.000 GATE A MO LO YES FAI Ec QR PI 2Y V-3439 F-3 2 C 1.000 RELIEF A S/A C HO SRV RF V-3444 E.7 2 8 14.000 GATE A MO LO YES FAI Ec'l QR 2Y V-3456 G-4 2 8 10.000 GATE A MO LC YES FAI EO QR Pl 2Y
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FLORIDA POWER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 14 P B ID: 2998-G-078 SH 130 (cont) SYSTEH: SAFETY INJECTION SYSTEH SRCCtHC ACT. NORH REM FAIL TEST RELIEF VALVE NUMBER COORD. CL CAT. SIZE TYPE A/P TYPE POS. IND HODE EXAH FREQ REQ. REMARKS V-3457 F-2 2 B 10.000 GATE A MO LC YES FAI EO QR PI 2Y V-3463 G-2 2 A 2.000 GATE P HAN LC NO SLT-1 2Y V-3495 G-6 2 B 6.000 GLOBE A SO LO YES FC EC QR FS QR PI 2Y V-3496 G-5 2 B 6.000 GLOBE A SO LO YES FC EC QR FS QR PI 2Y V-3507 F-1 2 C 1.000 RELIEF A S/A C NO SRV RF V-3517 N-6 2 8 12 F 000 GATE , A HO LC YES FAI EO QR PI 2Y V-3522 B-4 2 C 3.000 CHECK A S/A C NO CV/0 RF VR-10 V-3523 A-2 2 B 3.000 GLOBE A 'HO LC YES FAI EC" QR EO QR Pl 2Y V-3540 C-2 2 B 3.000 GLOBE A MO LC YES FAI EC QR EO QR PI 2Y V-3547 C-5 2 C F 000 CHECK A S/A C NO CV/0 RF VR-10 V-3550 C-2 2 B 3.000 GLOBE A MO LC YES FAI EC QR EO QR PI 2Y V-3551 A-2 2 8 3.000 GLOBE A HO LC YES FAI EC QR EO QR PI 2Y V-3570 C-3 2 C 1.000 RELIEF A S/A C NO SRV- RF V-3654 B-5 2 B 6.000 GATE A MO LO YES FAI EC OR PI 2Y V-3656 D-5 '2 B 6.000 GATE A MO LO YES FAI EC QR Pl 2Y
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FLORIDA POWER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 15 P 8 ID: 2998-G-078 SN 130 (cont) SYSTEM: SAFETY INJECTION SYSTEH ACT ~ NORH REH FAlL TEST RELIEF "VALVE NUMBER ,COORD. CL CAT. SIZE .TYPE A/P TYPE 'POS ~ IND HODE EXAM '"FREQ REQ. REMARKS V-3658 G-7 2 8 12.000 GATE A MO LC YES FAI EO QR PI 2Y V-3659 G-6 2 8 3.000 GATE A HO 0 YES FAI EC QR PI 2Y V-3660 G-5 2 8 3 ~ 000 GATE A MO 0 YES FAI EC QR PI 2Y
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FLORIDA PONER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE: 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE: 16 P 8 ID: 2998-G-078 SH 131 SYSTEM: SAFETY INJECTION SYSTEM ACT. NORM REH FAIL TEST RELIEF VALVE NUMBER COORS CL CAT ~ SIZE TYPE A/P 'TYPE 'POS ~ IND MODE 'XAM FREQ 'EQ. , REMARKS HCV-3615 H-7 2 8 6.000 GLOBE A MO C YES FAI EO QR Pl 2Y HCV-3616 G-7 2 8 2 ~ 000 GLOBE A MO C YES FAI EO QR Pl 2Y HCV-3617 G-7 2 8 2.000 GLOBE A MO C YES FAI EO QR PI 2Y HCV-3625 F-7 2 8 6.000 GLOBE A MO C YES FAI EO QR PI 2Y HCV-3626 E-7 2 8 2.000 GLOBE A MO C YES FAI EO QR Pl 2Y HCV-3627 E-7 2 8 2.000 GLOBE A MO C YES FAI EO QR Pl 2Y HCV-3635 D-7 2 8 6.000 GLOBE A MO C YES FAI EO QR Pl 2Y HCV-3636 C-7 2 8 2.000 GLOBE A MO C YES FAI EO QR Pl 2Y HCV-3637 C-7 2 8 2.000 GLOBE A MO -
C YES FAI EO QR Pl 2Y HCV-3645 8-7 2 8 6.000 GLOBE A MO C YES FAI EO QR Pl 2Y HCV.3646 A-7 2 8 2.000 GLOBE A MO C YES FAI EO QR PI 2Y HCV-3647 A-7 2 8 2.000 GLOBE A MO C YES FAI EO QR Pl 2Y V-3113 G-7 2 C 2.000 CHECK A S/A C HO 'V/0 RF VR-11 CV/PO SP V-3114 H-7 2 C 6.000 CHECK A S/A C NO CV/C CS CV/0 CS V-3124 F-7 2 C 6.000 CHECK A S/A C NO CV/C CS CV/0 CS
+4a+ c FLORIDA PONER AND LIGHT COMPANY - ~ REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 17 P 8 ID: 2998-G-078 SH 131 (cont) SYSTEM: SAFETY INJECTION SYSTEM ACT. NORM REM FAlL TEST RELIEF
'VALVE NUMBER COORD. CL CAT. SIZE -
TYPE A/P 'YPE" 'POS. 'IND 'MODE" "
EXAM 'FREQ 'REQ ~ -"REMARKS V-3133 C-7 2 C 2.000 CHECK A S/A C HO 'V/0 RF VR-11 CV/PO SP V-3134 D-7 2 C 6.000 CHECK A S/A C NO CV/C CS CV/0 CS V-3143 A-7 2 C 2.000 CHECK A S/A C NO CV/0 RF VR-11 CV/PO SP V-3144 8-7 2 C 6.000 CHECK A S/A C NO CV/C CS CV/0 CS V-3469 D-5 2 C 0.750 RELIEF A S/A C NO SRV RF V-3480 E-3 1 A 10.000 GATE A MO C YES FAI EO CS Pl 2Y SLT-2 SP VR-29 V-3481 E-4 1 A 10.000 GATE A MO C YES FAI EO CS Pl 2Y SLT-2 SP VR-29 V-3482 E-4 2 C 0.750 RELIEF A S/A C NO SRV 'F V-3524 F-5 'I AC F 000 CHECK A S/A C HO CV/C SP VR-12 CV/0 RF VR-12 SLT-2 SP VR-2 V-3525 F-4 1 AC 3.000 CHECK A S/A C NO CV/C SP VR-12 CV/0 RF VR-12 SLT-2 SP VR-2 8 VR-12 V-3526 C-5 1 AC F 000 CHECK A S/A C NO CV/C SP VR-12 CV/0 RF VR-12 SLT-2 SP VR-2 V-3527 C-4 1 AC 3.000 CHECK A S/A C NO CV/C SP VR-12 CV/0 RF VR-12 SLT-2 SP VR-2 8 VR-12 V-3536 E-8 2 B F 000 GLOBE A MO LC YES FAI EC QR PI 2Y V-3539 C-B 2 8 4.000 GLOBE A MO LC YES FAI EC QR Pl 2Y
FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 18 P 8 ID: 2998-G-078 SH 131 (cont) SYSTEH: SAFETY INJECTION SYSTEM ACT. NORH REM FAIL TEST RELIEF VALVE NUHBER- COORS -CL=CAT. .SIZE- "-TYPE" A/P -"TYPE -POS IND HODE 'EXAM 'FREQ REQ. - REMARKS V-3545 E-4 1 8 10.000 GATE A HO LC YES FAI EO CS PI 2Y V-3571 8-4 1 8 1 F 000 GLOBE A DO C YES FC EC QR FS QR PI 2Y V-3572 F-4 1 B 1.000 PLOBE A DO C YES FC EC QR FS QR Pi 2Y V-3651 D-3 1 A 10.000 GATE A HO C YES FAI EO CS PI 2Y SLT-2 SP VR-29 V-3652 D-5 1 A 10.000 GATE A HO C YES FAI EO CS PI 2Y SLT-2 SP VR-29 V-3664 E-6 2 8 10.000 GATE A HO LC YES FAI EO CS Pl 2Y V-3665 C-6 2 B 10.000 GATE A HO LC YES FAI EO CS Pl 2Y V-3666 D-6 2 C 6.000 RELIEF A S/A C NO SRV RF V-3667 E-6 2 C 6.000 RELIEF A S/A C NO SRV RF V-3766 E-7 2 C 2.000 CHECK A S/A C NO CV/0 RF VR-11 CV/PO SP
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FLORIDA PONER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 19 P.R ID: 2998-G-078 SH 132 SYSTEM: SAFETY INJECTION SYSTEM ACT. NORM REM FAIL TEST RELIEF
..,,.VALVE NUMBER ,.COORD..CL CAT. SIZE TYPE -A/P TYPE POS.-IND.MODE-- EXAM .- FREQ REQ. "-REMARKS HCV-3618 E-7 1 8 1.000 GLOBE A DO C YES FC EC QR FS QR PI 2Y HCV-3628 E-4 1 8 1.000 GLOBE A DO C YES FC EC QR FS QR PI 2Y HCV-3638 8-7 1 8 1.000 GLOBE A DO C YES FC EC QR FS QR PI 2Y HCV-3648 8-4 1 8 1.000 GLOBE A DO C YES FC EC QR FS QR PI 2Y SE-03-1A F-3 2 8 1.000 GLOBE A SO NC YES FC EC CS FS CS PI 2Y SE.03-18 F-7 2 8 1.000 GLOBE A SO NC YES FC EC CS FS CS PI 2Y SE-03-1C C-7 2 8 1 F 000 GLOBE A SO NC YES FC EC CS FS CS PI 2Y SE-03-1D C-3 2 8 1 F 000 GLOBE A SO NC YES FC EC CS FS CS PI 2Y V-3215 F-5 2 AC 12.000 CHECK A S/A C NO CV/C SP VR-13 IHSP SP VR-13 SLT-2 SP VR-2 V-3217 E-6 1 AC 12 F 000 CHECK A S/A C NO CV/C SP VR-14 CV/PO CS VR-14 IHSP SP VR-14 SLT-2 SP VR-2 V-3225 F-2 2 AC 12.000 CHECK A S/A C NO CV/C SP VR-13 INSP SP VR-13 SLT-2 SP VR-2
FLORIDA POMER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE: 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE: 20 P 8 ID: 2998-G-078 SH 132 (cont) SYSTEH: SAFETY INJECTION SYSTEN ACT ~ NORH REN FAlL TEST RELIEF
.VALVE.NUHBER 'COORD..CL CAT ~ SIZE TYPE - A/P -.TYPE - POS. IND NODE EXAN -FREQ - REQ ~ . REHARKS V-3227 E-6 1 AC 12.000 CHECK A S/A C NO CV/C SP VR-14 CV/PO CS VR-14 INSP SP VR-14 SLT-2 SP VR-2 V-3235 F-2 2 AC 12.000 CHECK A S/A C NO CV/C SP VR-13 INSP SP VR-13 SLT-2 SP VR-2 V-3237 E-6 1 AC 12.000 CHECK A S/A C NO CV/C SP VR-14 CV/PO CS VR-14 INSP SP VR-14 SLT-2 SP VR-2 V-3245 F-2 2 AC 12.000 CHECK A S/A C NO CV/C SP VR-13 INSP SP VR-13 SLT-2 SP VR-2 V-3247 E-6 1 AC 12.000 CHECK A S/A C NO CV/C SP VR-14 CV/PO CS VR-14 IHSP SP VR-14 SLT-2 SP VR-2 V-3258 F-2 1 AC 6.000 CHECK A S/A C NO CV/C SP VR-15 CV/0 CS VR-15 CV/PO SP SLT-2 SP VR-2 V-3259 F-5 1 AC 6.000 CHECK A S/A C NO CV/C SP VR-15 CV/0 CS VR-15 CV/PO SP SLT-2 SP VR-2 V-3260 8-5 1 AC 6.000 CHECK A S/A C NO CV/C SP VR-15 CV/0 CS VR-15 CV/PO SP SLT-2 SP VR-2 V-3261 8-2 1 AC 6.000 CHECK A S/A C HO CV/C SP VR-15 CV/0 CS VR-15 CV/PO SP SLT-2 SP VR-2
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FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 21 P 8 ID: 2998-G-078 SH 132 (cont) SYSTEH: SAFETY INJECTION SYSTEH ACT. NORM REH FAIL TEST RELIEF VALVE NUMBER.= COORD. CL CAT. SIZE TYPE- A/P TYPE POS ~ IND HODE " EXAH '"FREQ .REQ. -REMARKS V-3611 F-6 2 8 1.000 GLOBE A AO C YES FC EC , CS FS CS PI 2Y V-3614 F-6 1 B 12.000 GATE A MO LO .YES FAI EC CS PI 2Y V-3621 F-3 2 8 1 F 000 GLOBE A AO C YES FC EC CS FS CS Pl 2Y V-3624 F-3 1 8 12.000 GATE A HO LO YES FAI EC CS Pl 2Y V-3631 B-6 2 B '1.000 GLOBE A AO C YES FC EC CS FS CS Pl 2Y V-3634 8-6 1 8 12.000 GATE A HO LO YES FAI EC CS PI 2Y V-3641 B-3 2 B 1.000 GLOBE A AO C YES FC EC CS FS CS PI 2Y V-3644 B-3 1 B 12.000 GATE A HO LO YES FAI EC CS PI 2Y V-3733 G-7 2 8 1 F 000 GATE A SO C YES FC EO CS Pl 2Y V-3734 G-7 2 B 1.000 GATE A SO C YES FC EO CS PI 2Y V-3735 G 4 2 8 1.000 GATE A SO C YES FC EO CS'I 2Y V-3736 G-4 2 8 1.000 GATE A SO C YES FC EO CS PI V-3737 D-7 2 8 1.000 GATE A SO C YES FC EO CS PI 2Y V-3738 0-7 2 8 1.000 GATE A SO C YES FC EO CS PI 2Y
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FLORIDA POWER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92
.Saint Lucie Nuclear Plant - Unit 2 PAGE : 22 P 8 ID: 2998-G-078 SN 132 (cont) SYSTEM: SAFETY INJECTION SYSTEH ACT. NORH REH FAIL TEST RELIEF
,VALVE NUHBER <<COORS CL CAT ~ SI2E TYPE A/P TYPE =POS. IND HODE .EXAM FREQ -REQ. REMARKS V-3739 0-4 2 8 1.000 GATE A SO C YES FC EO 'CS PI 2Y V-3740 D-4 2 8 1.000 GATE A SO C YES FC EO CS PI 2Y
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FLORIDA PONER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 23 P 8 ID: 2998-G-078 SN 153 SYSTEH: SAMPLING SYSTEM ACT. NORM REM FAIL TEST RELIEF
~BIVALVE NUHBER COORD.'L CAT ~ 'iZE . TYPE 'A/P- TYPE POS ~ "IND HODE --'EXAM 'REQ " REQ. " REMARKS SE-05-1A G-7 2 A 0.375 GLOBE A SO C YES FC EC QR FS QR Pl 2Y SLT-1 2Y SE-05-18 F-7 2 A 0.375 GLOBE A SO C YES FC EC QR FS QR PI 2Y SLT-1 2Y SE-05-1C E-7 2 A 0.375 GLOBE A SO C YES FC EC QR FS QR PI . 2Y SLT-1 2Y SE-05-1D C-7 2 A 0.375 GLOBE A SO C YES FC EC QR FS QR PI 2Y SLT-1 2Y SE-05-1E G-5 2 A 0.375 GLOBE A SO C YES FC EC QR FS QR PI 2Y SLT-1 2Y V-5200 F-6 2 A 0.375 GLOBE A DO C YES FC EC OR FS QR PI 2Y SLT-1 2Y V-5201 E-6 2 A 0.375 GLOBE A DO C YES FC EC QR FS QR Pl SLT-1 2Y V-5202 0-6 2 A 0.375 GLOBE A DO C YES FC EC QR FS QR PI 2Y SLT-1 V-5203 F-5 2 A 0.375 GLOBE A DO C YES FC EC QR FS QR Pl 2Y SLT-1 2Y
FLORIDA POWER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 24 SHCSCCR 55ÃtSHJRCCC 0 Z CQ 555CCR5R5RCHXE 5$ 5RIIR CCRRii RC P 8 ID: 2998-G-078 SN '153 (cont) SYSTEH: SAHPLING SYSTEH ACT ~ NORH REH FAIL TEST RELIEF VALVE, NUHBER ..COORD..CL CAT.- SIZE 'TYPE -A/P POS;-IND NODE" " EXAH -=- FREQ =REQ. REHARKS TYPE V-5204 E-5 2 A 0.375 GLOBE A DO C YES FC EC QR FS QR PI *2Y SLT-1 2Y V-5205 D-5 2 A 0.375 GLOBE A DO C YES FC EC QR FS QR PI 2Y SLT-1 2Y
FLORIDA POHER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92
. Saint Lucia Nuclear Plant - Unit 2 PAGE : 25 P 8 ID: 2998-G-078 SH 160 SYSTEM: llASTE MANAGEMENT SYSTEM CIZKRRCRI SZtO 5500555C 5 C5 C5I 5 1 0 5 ZX ACT. NORM REM FAIL TEST RELIEF VALVE NUMBER . COORD..CL CAT ~ -SIZE .TYPE -
A/P TYPE= POS ~ -IND MODE =.EXAM -FREQ REQ. --REMARKS V-6341 E-7 2 A 3.000 DIAPH A AO 0 YES FC EC QR FS QR PI 2Y SLT-1 2Y V-6342 E-6 2 A 3.000 D IAPH A AO 0 YES FC EC QR FS QR PI 2Y SLT-1 2Y
FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 26 P 4 ID: 2998-G-078 SH 163 SYSTEM: WASTE MANAGEMENT SYSTEM ACT. NORM REM FAIL TEST RELIEF VALVE NUMBER COORS CL CAT. SIZE TYPE A/P TYPE POS ~ IND MODE EXAM FREQ REQ. REMARKS V-6718 E-7 2 A F 000 DIAPH A AO 0 YES FC EC QR FS QR PI 2Y SLT-1 2Y V-6741 8-2 2 A 1.000 GLOBE A AO 0 YES FC EC QR FS QR PI 2Y SLT-1 2Y V-6750 E-7 2 A 1.000 DIAPH A AO 0 YES FC EC QR FS QR PI 2Y SLT-1 2Y V-6792 C-7 2 AC F 000 CHECK A S/A C NO CV/C CS VR-17 SLT-1 2Y
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FLORIDA POWER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 27 P 5 ID: 2998-G-079 SN 1 SYSTEM: HAIN STEAH SYSTEH ACT. NORM REH FAIL TEST RELIEF TYPE . -FREQ -REQ.-
.VALVE.NUHBER . =COORD. CL-CAT ~ SIZE A/P -
TYPE POS." IND MODE
~
EXAM REMARKS NCV-08-1A K-13 2 B 34.000 GLOBE A PO 0 YES EC CS PEC QR PI 2Y HCV-08-18 K-13 2 8 34 F 000 GLOBE A PO 0 YES EC CS PEC QR PI 2Y HV-08-12 N-8 2 8 4.000 GATE A HO C YES FAI EO QR PI 2Y HV.08.13 N-10 2 8 4.000 GATE A HO C YES FAI EO QR Pl 2Y MV-08-14 K-8 2 B 10.000 GATE P HO 0 YES FAI PI 2Y MV-08-15 K-10 2 B 10 F 000 GATE P HO 0 YES FAI PI 2Y HV-08-16 D-10 2 8 10 ~ 000 GATE P HO 0 YES FAI PI 2Y HV-08-17 D-8 2 8 10.000 GATE P HO 0 YES FAI PI 2Y MV-08-18A J-8 2 8 10.000 ANGLE A HO C YES FAI EC QR EO QR PI 2Y MV-08-188 0-10 2 8 10.000 ANGLE A MO C YES FAI EC QR EO QR PI 2Y HV-08-19A J-10 2 8 10.000 ANGLE A MO C YES FAI EC EO
'R QR PI 2Y HV-08-198 D-8 2 8 10.000 ANGLE A HO C YES FAI EC QR EO QR PI 2Y MV-08-1A K-13 2 B F 000 GLOBE A MO C YES FAI EC QR Pl 2Y HV-08-18 C-13 2 8 3.000 GLOBE A HO C YES FAI EC QR PI 2Y
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FLORIDA POWER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 28 P 8 ID: 2998-0-079 SH 1 (cont) SYSTEM: HAIN STEAM SYSTEH ACT. NORH REH FAIL TEST RELIEF
.VALVE,NUMBER "COORS -
CL-CAT. SIZE TYPE .A/P -TYPE POS.'IND HODE 'EXAM "FREQ -REQ. REHARKS HV-08-3 N-'14 3 B 4.000 GLOBE A HO C YES FAI EO QR PI 2Y SR-8201 J-12 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8202 J-12 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8203 J-12 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8204 J-12 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8205 C-11 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8206 C-11 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8207 C-11 2 C 6.000 SAFETY S/A C NO SRV RF SR-8208 C-11 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8209 J-12 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8210 J-12 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8211 J-12 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8212 J-12 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8213 C-11 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8214 C-11 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8215 . C-11 2 C 6.000 SAFETY A S/A C NO SRV RF SR-8216 C-11 2 C 6.000 SAFETY A S/A C NO SRV . RF V-8130 L-10 3 C F 000 CHECK A S/A C NO CV/0 CS CV/PO QR INSP RF VR-31 V-8163 L-10 3 C 4.000 CHECK A S/A C NO CV/0 CS CV/PO QR INSP RF VR-31
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FLORIDA POMER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 29 P 8 ID: 2998-G-080 SH 2 SYSTEM: FEEDNATER SYSTEM ACT. NORH REM FAIL TEST RELIEF
,-VALVE:NUHBER COORD. CL CAT. SIZE -"-TYPE . A/P TYPE POS.'IND 'HODE EXAH FREQ REQ. REMARKS HCV-09-1A 8-14 2 8 20.000 GATE A PO 0 YES FO EC CS FS CS PEC QR PI 2Y HCV-09-18 8-13 2 8 20.000 GATE A PO 0 YES FO EC CS FS CS PEC QR PI 2Y NCV-09-2A E-13 2 8 20.000 GATE A PO 0 YES FO EC CS FS CS PEC QR PI 2Y NCV-09-28 E-13 2 8 20.000 GATE A PO 0 YES FO EC CS FS CS PEC QR PI 2Y HV-09-09 G-16 2 8 4.000 GLOBE A HO C YES FAI EC QR EO QR PI 2Y HV-09-10 I-15 2 8 F 000 GLOBE A HO C YES FAI EC QR EO QR PI 2Y HV-09-'I1 G-12 2 8 4.000 GLOBE A HO C YES FAI EC QR EO QR PI 2Y HV-09-12 I-12 2 8 4.000 GLOBE A HO C YES FAI EC QR EO QR PI 2Y HV-09-13 M-17 3 8 2.500 GATE A HO C YES FAI EO QR PI 2Y MV-09-14 H-17 3 8 2.500 GATE A MO C YES FAI EO QR PI 2Y
M occcssca 5 N CRRRtIR 1 0555iRZCCSl55555 5SRC101a 5>>5R OSCSCC gg FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE: 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 30 P & ID: 2998-G-080 SH 2 (cont) SYSTEM: FEEDWATER SYSTEM RRSSSR 5 0 15 5 5 41CCC01 5 0 I I 0 ZRCSSSS ACT ~ NORM REM FAIL TEST RELIEF VALVE NUMBER COORD. CL CAT ~ SIZE TYPE A/P TYPE POS. IHD MODE EXAM FREQ REGS REMARKS SE-09-2 K-15 3 8 4.000 GATE A SO C YES FC EC CS VR-33 EE QR VR-33 EO CS VR-33 FS QR PI 2Y SE-09-3 J-15 3 8 4.000 GATE A SO C YES FC EC CS VR-33 EE QR VR-33 EO CS VR-33 FS QR PI 2Y SE.09-4 H-11 3 8 F 000 GATE A SO C YES FC EC CS VR-33 EE QR VR-33 EO CS VR-33 FS QR Pl 2Y SE.09.5 l-11 3 8 F 000 GATE A SO C YES FC EC CS VR-33 EE QR VR-33 EO CS VR-33 FS QR Pl 2Y V-09107 M.14 8 C 4.000 CHECK A S/A C NO CV/C CS CV/0 CS V-09119 G-15 2 C 4.000 CHECK A S/A C NO CV/0 CS V.09123 L-14 8 C 4.000 CHECK A S/A C NO CV/C CS CV/0 CS V.09135 1-15 2 C 4.000 CHECK A S/A C NO CV/0 CS V-09139 J 14 8 C 6.000 CHECK A S/A C NO CV/0 CS V-09151 .G-12 2 C 4.000 CHECK A S/A C NO CV/0 CS V-09157 I-12 2 C F 000 CHECK . A S/A C NO CV/0 CS V-09252 8 16 2 C 18.000 CHECK A S/A 0 NO CV/0 QR V-09294 E-16 2 C 18.000 CHECK A S/A 0 NO CV/0 QR
FLORIDA POWER AND LIGHT COMPANY REVI SIGH: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 31 P 8 ID: 2998-G-080 SH 2 (cont) SYSTEM: FEEDWATER SYSTEM ACT. NORM REM FAIL TEST RELIEF
. VALVE NUMBER , COORD.: CL,CAT ~ SIZE =
TYPE'/P "
TYPE 'OS."cIHD MODE EXAM'-." .'FREQ. REQ:" -.- ~ REMARKS V-09303 L-13 3 C 2.000 CHECK A S/A C HO CV/PO QR VR-27 INSP RF VR-27 V-09304 M-12 3 C 1 '00 CHECK A S/A C HO CV/PO QR VR-27 INSP RF VR-27 V-09305 N-'13 3 C 1.500 CHECK A S/A C NO CV/PO QR VR-27 INSP RF VR-27
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FLORIDA POLIER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 32 P 8 ID: 2998-G-082 SYSTEH: INTAKE COOLING UATER SYSTEH ACT ~ NORM REH FAIL TEST RELIEF
-. -- ~VALVE~NUMBER COORD..CL SCAT. --SIZE TYPE A/P -.TYPE 'POS.-IND"HOOE 'EXAH " -FREQ .REQ. -"REHARKS HV-21-2 E-5 3 8 24.000 BUTFLY A HO 0 YES FAI Ec QR PI 2Y HV-21-3 E-4 3 8 24 ~ 000 BUTFLY A HO 0 'YES FAI Ec QR PI 2Y HV-21-4A I-3 3 8 3.000 BUTFLY A HO 0 YES FAI Ec QR PI 2Y HV-21-48 I-3 3 8 ~ 3.000 BUTFLY A HO 0 YES FAI Ec QR PI 2Y TCV-14-4A 8-3 3 8 30.000 BUTFLY A AO 0 NO FO Ec QR VR-34 FS QR TCV-'14-48 8-4 3 8 30.000 BUTFLY A AO 0 NO FO Ec QR VR-34 FS QR V-21162 H-4 3 C 30.000 CHECK A S/A C NO CV/C QR CV/0 QR V-21205 H-6 3 C 30 F 000 CHECK A S/A C NO CV/C QR CV/0 QR V-21208 H-7 3 C 30.000 CHECK A S/A C NO CV/C QR CV/0 QR V-21431 H-5 3 C 1.000 CHECK A S/A C NO CV/C QR CV/0 QR V-21434 H-5 3 C 1.000 CHECK A S/A C NO CV/C QR CV/0 QR V-21523 C 2.000 CHECK A S/A C NO CV/0 QR V-21524 I-7 3 C F 000 CHECK A S/A C NO CV/0 QR
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FLORIDA PSIER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 33 P 8 ID: 2998-G-083 SYSTEM: COMPONENT COOLING SYSTEM ACT. NORM REH FAlL TEST RELIEF
.VALVE.NUHBER...COORD..CL CAT ~ ., SIZE TYPE -A/P TYPE POS ~ :.IND-MODE EXAM '"FREQ 'REQ. 'EMARKS HCV-14-1 C-6 2 A 8.000 BUTFLY A AO 0 YES FC EC CS FS CS PI 2Y SLT-1 2Y VR-4 8 VR-16 HCV-14-10 H-15 3 8 16.000 BUTFLY A AO 0 YES FC EC QR FS QR Pl 2Y HCV-14-2 C-1 2 A 8.000 BUTFLY A AO 0 YES FC EC CS FS CS PI 2Y SLT-1 2Y VR-4 8 VR-16 HCV-14-3A L-3 3 B 14 F 000 BUTFLY A DO 0 YES FO EO . CS FS CS PI 2Y HCV-14-38 M-3 3 8 14.000 BUTFLY A OO 0 YES FO EO CS FS CS Pl 2Y HCV-14-6 0-2 2 A 8.000 BUTFLY A AO 0 YES FC EC CS FS CS Pl 2Y SLT-1 2Y VR-4 8 VR-16 HCV-14-7 D-6 2 A 8.000 BUTFLY A AO 0 YES FC EC CS FS CS Pl 2Y SLT-1 2Y VR-4 8 VR-16 HCV-14-BA G-14 3 8 16.000 BUTFLY A AO 0 YES FC EC QR FS QR, PI 2Y HCV-14-8B G-15 3 8 16.000 BUTFLY A AO 0 YES FC EC QR FS QR PI 2Y HCV-14-9 G-15 3 8 16.000 BUTFLY A AO 0 YES FC EC FS QR PI 2Y
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FLORIDA POWER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE: 34 P 5 ID: 2998-G-083 (cont) SYSTEH: COHPONENT COOLING SYSTEH ACT ~ NORH REM FAIL TEST RELIEF VALVE NUHBER COORD. CL CAT ~ SIZE TYPE A/P TYPE POS. IND HODE EXAM FREQ REQ. REMARKS MV-14-1 D-16 3 8 24.000 BUTFLY A MO 0 YES FAI EC QR EO QR Pl 2Y MV-14-10 C-9 2 8 8.000 BUTFLY A HO 0 YES FAI EC QR PI 2Y HV.14-11 C-10 2 B 8.000 BUTFLY A HO 0 YES FAI EC QR Pl 2Y HV-14-12 C-10 2 8 8.000 BUI'FLY A, HO 0 YES FAI EC QR Pl 2Y HV-14-13 C-8 2 8 8.000 BUTFLY A HO 0 YES FAI EC QR PI 2Y HV-14-14 C-8 2 B 8.000 BUTFLY A HO 0 YES FAI EC QR PI 2Y HV-14-15 C-9 2 B 8.000 BUTFLY A HO 0 YES FAI EC QR PI 2Y MV-14-16 C-8 2 B 8.000 BUTFLY A HO 0 YES FAI EC QR PI 2Y MV-14-17 G-'l3 3 8 12.000 BUTFLY A HO 0 YES FAI EC QR Pl 2Y MV-14-18 G-13 3 B 12.000 BUTFLY A HO LC YES FAI EC QR PI 2Y MV-14-19 G-12 3 8 12.000 BUTFLY A HO 0 YES FAI EC QR Pl 2Y HV-14-2 D-17 3 8 24.000 BUTFLY A MO C YES FAI EC QR EO QR PI 2Y HV-14-20 G-12 3 8 12.000 BUTFLY A MO LC YES FAI EC QR PI 2Y HV-14-3 G-16 3 8 24.000 BUTFLY A HO 0 YES FAI EC QR EO QR PI 2Y
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FLORIDA POWER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 35 P /4 ID: 2998-G-083 (cont) SYSTEH: COHPONENT COOLING SYSTEH ACT. NORH REM FAIL TEST RELIEF VALVE NUHBER . ,COORD...CL: CAT., SIZE TYPE A/P >> TYPE POS." IND HOOE EXAM - FREQ REQ. REMARKS HV-14-4 G-17 3 B 24.000 BUTFLY A HO C YES FAI Ec QR EO QR PI 2Y MV-14-9 C-10 2 8 8.000 BUTFLY A HO 0 YES FAI Ec QR Pl 2Y V-14'l43 E-16 3 C 20.000 CHECK A S/A C NO CV/C QR CV/0 ,QR V-14147 E-17 3 C 20 F 000 CHECK A S/A C NO CV/C QR CV/0 QR V-14151 E-16 3 C 20.000 CHECK A S/A C NO CV/C QR CV/0 QR
FLORIDA POWER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE :'08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE 36 P 8 ID:'2998-G-084 SYSTEH: HAKEUP WATER SYSTEH ACT ~ NORH REH FAIL TEST RELIEF
.VALVE.NUMBER ,COORD. CL CAT.. SIZE TYPE -A/P TYPE POS."IND"HODE "EXAM'FREQ :REQ. ~ -REMARKS NCV-15-1 N-17 2 A 2.000 GLOBE A 00 0 YES FC EC QR FS QR PI 2Y SLT-1 2Y V-15328 I-17 2 AC 2.000 CHECK A S/A C NO CV/C CS VR-18 SLT-1 2Y
FLORIDA PCMER AHD LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 37 P 8 ID: 2998-G-085 SH 1 SYSTEM: SERVICE AIR ACT ~ NORH REH FAIL TEST RELIEF VALVE NUHBER COORS .CL CAT. SIZE TYPE ,A/P ,TYPE -POS..IND MODE -
EXAH -
FREQ REQ. -- REMARKS HCV-18-2 H-6 2 A 2.000 GLOBE A AO C YES FC EC QR FS QR Pi 2Y SLT-1 2Y V-181270 H-5 2 AC 2.000 CHECK A S/A 0/C NO CV/C CS SLT-1 2Y V-18797 G-6 2 A 1.000 BALL P HAH LC NO SLT-1 2Y
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FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 38 P & ID: 2998-G-085 SH 2 SYSTEM: INSTRUMENT AIR ACT. NORM REM FAIL TEST RELIEF
, VALVE NUHBER -COORS CL CAT. SIZE TYPE A/P TYPE POS. IND MODE EXAM FREQ RED. REMARKS HCV-18-1 G-7 2 A 2.000 GLOBE A DO 0 YES FC EC CS FS CS PI 2Y SLT-1 2Y V-18195 G6 2 AC 2.000 CHECK A S/A C NO CV/C 2Y VR-19 SLT-1 2Y V-18279 J-2 2 AC 0.500 CHECK A S/A C NO CV/C CS SLT-3 CS V-18283 J-1 2 AC 0.500 CHECK A S/A C NO CV/C CS SLT-3 CS V-18290 L-1 NC AC 0.750 CHECK A S/A C NO CV/C SLT-3 'S CS V-18291 L-1 2 AC 0.750 CHECK A S/A C NO CV/C CS SLT-3 CS V-18294 M-1 2 AC 0.750 CHECK A S/A C NO CV/C CS SLT-3 CS V-18295 M-1 2 AC 0.750 CHECK A S/A C NO CV/C CS SLT-3 CS
FLORIDA POMER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 39 P & ID: 2998-G-086 SH 1 SYSTEM: MISCELLANEOUS SYSTEMS ACT. NORM REM FAIL TEST RELIEF VALVE NUMBER COORS CL CAT. SIZE TYPE A/P TYPE POS ~ IHD MODE EXAM FREQ REQ. REMARKS FCV-23-3 D-14 2 8 2.000 GATE A DO 0 YES FC EC QR FS PI 2Y FCV-23-5 D-15 2 8 2.000 GATE A DO 0 YES FC EC QR FS QR Pl 2Y FCV-23-7 D-17 2 8 0.500 GLOBE A DO 0 YES FC EC QR FS QR PI 2Y FCV-23-9 D-18 2 8 0.500 GLOBE A DO 0 YES FC EC QR FS QR PI 2Y SR-17221 J-13 3 C 0.750 RELIEF A S/A C HO SRV RF SR-17222 L-13 3 C 0.750 RELIEF A S/A C HO SRV RF V-17204 J-13 3 C 2.000 CHECK A S/A C HO CV/0 QR V-17214 L-13 3 C 2.000 CHECK A S/A C NO CV/0 QR
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FLORIDA PONER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 40 P 8 ID: 2998-G-088 SYSTEM: CONTAINMENT SPRAY SYSTEH ACT ~ NORH REH FAIL TEST RELIEF
.VALVE NUHBER . COORD..CL .CAT. SIZE -'--TYPE:.A/P TYPE 'POS.'~IND'MODE ""EXAM " ~FREQ REQ.'REMARKS FCV-07-1A F-12 2 8 12.000 GATE A DO C YES FO EO QR FS QR PI 2Y FCV-07-18 F-12 2 8 12.000 GATE A DO C YES FO EO QR FS QR PI 2Y LCV-07-11A I-14 2 A 2.000 GLOBE A DO 0 YES FC EC QR FS QR PI SLT-1 LCV-07-118 - > 1-.13 2 A 2.000 GLOBE A DO 0 YES FC EC QR FS QR PI 2Y SLT-1 2Y HV-07-1A E-3 2 8 24.000 BUTFLY A HO LO YES FAI EC QR Pl 2Y HV-07-18 E-2 2 8 24.000 BUTFLY A MO LO YES FAI EC QR Pl 2Y HV-07-2A I-12 2 8 24.000 BUTFLY A MO C YES FAI EO QR Pl 2Y HV-07-28 J-12 2 8 24.000 BUTFLY A HO C YES FAI EO QR Pl 2Y HV-07-3 F-11 2 8 '12.000 GATE A MO 0 YES FAI EC QR PI 2Y HV-07-4 F-11 2 8 12.000 GATE A HO 0 YES FAI EC QR
, PI 2Y SE-07-3A C-9 2 8 F 000 GLOBE A SO C YES FO EC ,
QR EO QR FS QR Pl 2Y SE-07-38 E-9 2 8 2.000 GLOBE A SO C YES FO EC QR EO QR FS QR Pl 2Y
FLORIDA PONER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 41 P 8 ID: 2998-G-088 (cont) SYSTEM: CONTAINMENT SPRAY SYSTEM ACT. NORM REM FAIL TEST RELIEF VALVE NUMBER COORD. CL CAT. SIZE TYPE A/P TYPE POS ~ IND MODE EXAM FREQ REGS REMARKS SR-07-2A 8-10 2 C 1.500 RELIEF A S/A C NO SRV . 'F SR-07-28 C-10 2 C 1.500 RELIEF A S/A C NO SRV RF V-7119 J-7 2 C 24.000 CHECK A S/A C NO CV/PO QR VR-20 CV/PO RF VR-20 INSP RF VR-20 V-7120 1-7 2 C 24.000 CHECK A S/A C NO CV/PO QR VR-20 CV/PO RF VR-20 INSP RF VR-20 V-7129 H-5 2 C 12 ~ 000 CHECK A S/A C NO CV/0 RF VR-21 CV/PO QR VR-21 V-7130 H-6 2 8 12.000 GATE A MAN 0 NO EE QR V-7143 G-5 2 C 12.000 CHECK A S/A C NO CV/0 RF VR-21 CV/PO QR VR-21 V-7145 G-6 2 8 12.000 GATE A MAH 0 NO EE QR V-7170 G-13 2 A F 000 GATE P MAN LC NO SLT-1 2Y V-7172 J-10 2 C 24.000 CHECK A S/A C NO INSP RF VR-22 V-7174 I-10 2 C 24.000 CHECK A S/A C NO INSP RF VR-22 V-7188 G-14 2 A 3.000 GATE P MAN LC NO SLT-1 2Y V-7189 G-14 2 A F 000 GATE P MAN LC NO SLT-1 2Y V-7192 E-14 2 C 10 ~ 000 CHECK A S/A C NO INSP RF VR-23 V-7193 E-14 2 C 10.000 CHECK A S/A C NO INSP RF VR-23 V-7206 G-13 2 A 3.000 GATE P MAN LC NO SLT-1 2Y V-7231 A-13 2 C 2.000 CHECK A S/A C NO CV/0 QR V-7232 A-13 2 C F 000 CHECK A S/A C NO CV/0 QR V-7256 E-8 2 C 1.500 CHECK A S/A C NO CV/0 RF VR-'24 V-7258 F-8 2 C F 500 CHECK A S/A C NO CV/0 RF VR-24
P FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 42 P & ID: 2998-G-088 (cont) SYSTEH: CONTAINHENT SPRAY SYSTEH ACT. NORH REH FAIL TEST RELIEF VALVE,NUHBER .COORD. CL..CAT. -SIZE -TYPE'-A/P TYPE -POS; -IND MODE -EXAM FREQ -REQ. - -REHARKS V-7412 8-10 2 C 1.500 CHECK A S/A C NO CV/0 aR
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FLORIDA POMER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE: 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 43 P 8 ID: 2998-G-091 SYSTEM: MISCELLANEOUS SYSTEMS ACT. NORM REH FAIL TEST RELIEF
, ,,VALVE,NUHBER . COORD..CL CAT. *-.SIZE - TYPE A/P -TYPE POS:"IND'HODE EXAH '-FREQ "REQ.=. ""REMARKS V-00-101 B-6 2 A 8.000 GATE P HAN C NO SLT-1 2Y VR-4 8 VR-16 V.00.139 L-10 2 A 0.375 GLOBE P HAN LC NO SLT-1 2Y V-00-140 M-10 2 A F 000 GLOBE P HAN LC NO SLT-1 2Y V-00-143 M-11 2 A 1.000 GLOBE P HAN LC NO SLT-1 2Y V-00-144 L 11 2 A 0.375 GLOBE P MAN LC NO SLT-1 2Y
C FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE: 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 44 P F ID: 2998-G-092 SH 'I SYSTEM: MISC. SAMPLING SYSTEMS ACT. NORM REM FAIL TEST RELIEF VALVE NUMBER. .COORD. CL.CAT ~ SIZE TYPE -A/P TYPE POS. IHD'MODE- EXAM " "FREQ REQ.- REMARKS FCV-26-1 G-2 2 A 1.000 GLOBE A DO 0 YES FC EC QR FS QR Pl 2Y SLT-1 2Y FCV-26.2 G-4 2 A 1.000 GLOBE A DO 0 YES FC EC QR FS QR Pl 2Y SLT-1 2Y FCV-26-3 H-2 2 A 1.000 GLOBE A DO 0 YES FC EC QR FS QR PI 2Y SLT-1 2Y FCV-26-4 H-4 2 A 1 F 000 GLOBE A DO 0 YES FC EC QR FS QR PI 2Y SLT-1 2Y FCV-26-5 I-2 2 A 1.000 GLOBE A DO 0 YES FC EC QR FS QR PI 2Y SLT-1 2Y FCV-26-6 I-4 2 A 1.000 GLOBE A DO 0 YES FC EC QR FS QR PI 2Y SLT-1. 2Y FSE-27-10 B-13 2 A 0.375 GLOBE A SO C YES FC EC QR EO QR FS QR PI 2Y SLT-1 2Y FSE-27-11 C-13 2 A 0.375 GLOBE A SO C YES FC EC QR EO QR FS QR Pl 2Y SLT-1 2Y
I' FLORIDA POWER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 45 P 8 ID: 2998-G-092 SN 1 (cont) SYSTEH: MISC. SAMPLING SYSTEHS ACT. NORM REH FAIL TEST RELIEF VALVE NUHBER COORS CL CAT ~
. SIZE TYPE A/P 'TYPE POS. 'IND HODE 'XAM 'REQ REQ. REMARKS FSE-27-12 8-15 2 A 0.375 GLOBE A SO C YES FC EC QR EO QR FS QR PI 'Y SLT-1 2Y F SE-27-13 8-15 2 A 0.375 GLOBE A SO C YES FC EC EO QR FS QR PI SLT.1 2Y FSE-27-14 B-15 2 A 0.375 GLOBE A SO C YES FC EC QR EO QR FS QR Pl 2Y SLT-1 2Y F SE-27-15 D-13 2 A 0.375 GLOBE A SO C YES FC EC QR EO QR FS QR Pl 2Y SLT-1 2Y FSE-27-16 0-13 2 A 0.375 GLOBE A SO C YES FC EC QR EO QR FS QR Pl 2Y SLT-1 2Y FSE-27-17 D-14 2 A 0.375 GLOBE A SO C YES FC EC QR EO QR FS QR PI 2Y SLT-1 2Y FSE-27.18 D-14 2 A 0.375 GLOBE A SO C YES FC EC QR EO QR FS QR PI 2Y SLT-1 2Y
FLORIDA POWER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia'Nuclear Plant - Unit 2 PAGE : 46
~ ~~ CAR 5 ~RE 5 C C5 5 CCC 1 0 5 5 ~SR P 8 ID: 2998-G-092 SH 1 (cont) SYSTEM: MISC. SAMPLING SYSTEMS ACT. NORM REM FAIL TEST RELIEF
..VALVE.NUMBER , COORS CL CAT., SIZE TYPE - A/P TYPE POS: IND MODE 'EXAM """FREQ "'REQ. -- 'REMARKS FSE-27-8 A-13 2 A 0.375 GLOBE A SO C YES FC EC QR EO QR FS QR PI 2Y SLT-1 2Y FSE-27-9 8-13 2 A 0.375 GLOBE A SO C YES FC EC QR EO QR FS QR PI 2Y SLT-1 2Y V-27101 8-14 2 AC 0.375 CHECK A S/A 0/C NO CV/C CS VR-25 CV/0 QR SLT-1 2Y V-27102 8-14 2 AC 0.375 CHECK A S/A 0/C NO CV/C CS VR-25 CV/0 QR SLT-1 2Y
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FLORIDA PSIER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucia Nuclear Plant - Unit 2 PAGE : 47 P 8 ID: 2998-G-096 SH 1 SYSTEM: EMERGENCY DIESEL GENERATOR 2A ACT. NORM REM FAIL TEST RELIEF VALVE NUMBER COORD. CL CAT. SIZE TYPE A/P TYPE POS. IND MODE EXAM FREQ REQ. REMARKS FCV-59-1A1 M-6 3 B F 500 GATE A AO C NO Fc EO SP VR-26 FCV-59-2A1 J-10 3 B 500 GATE A AO C NO Fc EO SP VR-26 FCV-59-3A1 C-10 3 B 1 '00 GATE A AO C NO Fc EO SP VR-26 FCV-59-4A1 M-2 3 B 1.500 GATE A AO C NO Fc EO SP VR-26 SE-59-1A1 B-16 3 B F 500 GLOBE A SO C NO Fc Ec QR EO QR FS QR SE-59.1A2 K-1 3 B 1.500 GLOBE A SO C NO Fc Ec QR EO QR FS QR SE-59-3A L-6 3 B ' '00 GATE A SO C NO Fc EO SP VR-26 SE-59-4A L-3 3 B 1 F 500 GATE A SO C NO Fc EO SP VR-26 SE-59-5A J-9 3 B 1.500 GATE A SO C NO Fc EO SP VR-26 SE-59-6A C-10 3 B 1 F 500 GATE A SO C NO Fc EO SP VR-26 SR-59-3A J-12 3 C 0.750 RELIEF A S/A C NO SRV RF SR-59.4A J-11 3 C 0.750 RELIEF A S/A C NO SRV RF SR-59-5A. J-9 3 C 0.750 RELIEF A S/A C NO SRV RF SR.59-6A J-8 3 C 0.750 RELIEF A S/A C NO SRV RF V-59156 M-12 3 C 1.250 CHECK A S/A C NO CV/C QR SLT-3 QR V-59158 M-10 3 C 1.250 CHECK A S/A C NO CV/C QR SLT-3 QR V-59159 M-8 3 C 1.250 CHECK A S/A C NO CV/C QR SLT-3 QR V-59236 M-11 3 C 1.250 CHECK A S/A C NO CV/C QR SLT-3 QR
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FLORIDA POl!ER AHD LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 48 P 8 ID: 2998-G-096 SH 2 SYSTEM: EMERGENCY DIESEL GENERATOR 28 ACT. NORM,REM FAIL TEST RELIEF
,.VALVE,NUMBER . COORS CL'CAT. - SIZE TYPE -A/P "TYPE'OS. *IHD"MODE " EXAM'*'-FREQ REQ. REMARKS FCV-59-181 C-10 3 8 1.500 GATE A AO C NO Fc EO SP VR-26 FCV-59-281 M 2 3 8 1.500 GATE A AO C HO Fc EO SP VR-26 FCV-59-381 J-10 3 8 '1.500 GATE A AO C NO Fc EO SP VR-26 FCV-59.481 M-5 3 8 1.500 GATE A AO C ,
NO Fc EO SP VR-26 SE-59-181 8-16 3 8 1.500 GLOBE A SO C NO Fc Ec QR EO QR FS QR SE-59-182 K-1 3 8 1.500 GLOBE A SO C NO Fc Ec QR EO QR FS QR SE-59-38 L-6 3 8 1.500 GATE A SO C NO Fc EO SP VR-26 SE-59-48 L-3 3 8 1.500 GATE A SO C NO Fc EO SP VR-26 SE-59-58 K-9 3 8 1.500 GATE A SO C HO Fc EO SP VR-26 SE-59-68 D-10 3 8 1.500 GATE A SO C NO Fc EO SP VR-26 SR-59-38 J-12 3 C 0.750 RELIEF A S/A C NO SRV RF SR-59-48 J-11 3 C 0.750 RELIEF A S/A C NO SRV RF SR-59-58 J-9 3 C 0.750 RELIEF A S/A C NO SRV RF SR-59.68 J-8 3 C 0.750 RELIEF A S/A C NO SRV RF V-59203 M-12 3 C 1.250 CHECK A S/A C NO CV/C QR SLT-3 QR V-59204 M-11 3 C 1.250 CHECK A S/A C NO CV/C QR SLT-3 QR V-59205 M-10 3 C 1.250 CHECK A S/A C NO CV/C QR SLT-3 QR V-59206 M-9 3 C 1 '50 CHECK A S/A C HO CV/C QR SLT-3 QR
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FLORIDA PONER AND LIGHT COMPAHY REVISION: 2 VALVE TABLES DATE: 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE 49 P & ID: 2998-G-878 SYSTEM: HVAC ACT. NORM REM FAIL TEST RELIEF
.VALVE.NUMBER ,.COORS CL CAT.- SI2E TYPE A/P .'TYPE -POS. IND'MODE- '"EXAM FREQ REQ. "'REMARKS FCV-25-1 C-2 NC 8 48.000 BUTFLY A PO C YES FC EC CS FS CS PI 2Y FCV-25-2 J-15 2 A 48.000 BUTFLY A PO C YES FC EC CS FS CS Pl 2Y SLT-1 2Y VR-4 & VR-16 FCV-25-3 J-15 2 A 48.000 BUTFLY A PO C YES FC EC CS FS CS Pl 2Y SLT-1 2Y VR-4 & VR-16 FCV-25-4 K-12 2 A 48.000 BUTFLY A PO C YES FC EC CS FS CS Pl 2Y SLT-1 2Y VR-4 & VR-16 FCV-25-5 K-12 2 A 48.000 BUTFLY A PO C YES FC EC CS FS CS PI 2Y SLT-1 2Y VR-16 FCV-25-6 C-8 NC 8 48.000 BUTFLY A PO C YES FC EC CS FS CS Pl 2Y FCV-25-7 L-12 2 A 24.000 BUTFLY A PO C YES FC EC QR EO QR FS QR Pl 2Y SL'7-1 2Y VR-16 FCV-25-8 L-12 2 A 24.000 BUTFLY A PO C YES FC EC QR EO QR FS QR Pl 2Y SLT-1 2Y VR-16 V-25-20 C-13 2 AC 24.000 CHECK A S/A C NO CV/C CS CV/0 CS SLT-1 2Y VR-16
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FLORIDA POWER AHD LIGHT COMPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 50 P 8 ID: 2998-G-878 (cont) SYSTEM: HVAC LL CC ACT. NORM REM FAIL TEST RELIEF
,VALVE NUMBER .COORD.- CL CAT.. SIZE -
TYPE A/P TYPE POS.'.IND.MODE - EXAM'REQ -REQ. 'REMARKS V-25-21 C-13 2 AC 24.000 CHECK A S/A C NO CV/C CS CV/0 CS SLT-1 2Y VR-16
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FLORIDA POMER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 51 P II ID: 2998-G-879 SN 2 SYSTEM: HVAC ACT. NORM REH FAlL TEST RELIEF
.VALVE.NUHBER ,.COORS -CL-CAT. -SIZE ~ TYPE -A/P -~
TYPE POS. -IND"HODE - EXAH -FREQ -REQ; REMARKS FCV-25-14 E-6 3 B 12.000 BUTFLY A MO 0 YES FAI EC QR EO QR PI 2Y FCV-25-15 E-7 3 B 12.000 BUTFLY A MO 0 YES FAI EC QR EO QR Pl 2Y FCV-25-16 E-5 3 B 12.000 BUTFLY A MO O YES FAI EC , QR EO QR PI 2Y FCV-25-17 E-8 ' B 12 F 000 BUTFLY A HO 0 YES FAI EC QR EO QR Pl 2Y FCV-25-18 C-16 3 B 6.000 BUTFLY A HO 0 YES FAI EC QR PI 2Y FCV-25-19 C-17 3 B 6.000 BUTFLY A HO 0 YES FAI EC QR PI 2Y FCV-25-24 A-16 3 B 10.000 BUTFLY A MO 0 YES FAI EC QR Pl 2Y FCV-25-25 A-17 3 B 10.000 BUTFLY A HO 0 YES FAI EC QR PI 2Y
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FLORIDA PONER AND LIGHT COHPANY REVISION: 2 VALVE TABLES DATE : 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 52 P & ID: 2998-G-879 SN 3 SYSTEH: MVAC ACT ~ NORM REH FAIL TEST RELIEF VALVE NUHBER COORD. CL CAT. SIZE TYPE A/P TYPE POS.'ND HODE EXAM FREQ REQ. REMARKS FCV-25-11 N-4 2 8 16.000 BUTFLY A HO C YES FAI EC QR EO QR PI 2Y FCV-25-12 J-4 2 8 16.000 BUTFLY A HO C YES FAI EC QR EO QR PI 2Y FCV-25-13 I-14 2 8 12.000 BUTFLY A HO C YES FAI EO QR PI 2Y FCV-25-20 J-12 2 A 8.000 BUTFLY A PO C YES FC EC FS PI SLT-1 8 VR-16 FCV-25-21 J-11 2 A 8.000 BUTFLY A PO C YES FC EC QR FS QR PI 2Y SLT-1 2Y VR-4 !L VR-16
'CV-25-26 K-16 2 A 8.000 BUTFLY A PO C 'ES FC EC QR FS QR Pl 2Y SLT-1 2Y VR-4 8 VR-16 FCV-25-29 K-3 2 8 F 000 BUI'FLY A HO C YES FAI EC QR PI 2Y FCV-25-30 M-4 2 8 20.000 BUTFLY A HO C YES FAI EC QR EO QR PI 2Y FCV-25-31 J-4 2 8 20.000 BUTFLY A HO C YES FAI EC QR EO QR PI 2Y FCV-25-32 N-4 2 8 30.000 BUTFLY A MO 0 YES FAI EC QR EO QR Pl 2Y FCV-25-33 J-4 2 8 30.000 BUTFLY A HO 0 YES FAI EC QR EO QR PI 2Y
yi FLORIDA POMER AND LIGHT COMPANY REVISION: 2 VALVE TABLES DATE: 08/01/92 Saint Lucie Nuclear Plant - Unit 2 PAGE : 53 P 8 ID: 2998-G-879 SH 3 (cont) SYSTEM: HVAC ACT ~ NORM REM FAlL TEST RELIEF VALVE NUMBER COORS ,CL CAT. SI2E TYPE A/P TYPE POS. IND MODE *EXAM '-FREQ REQ ~ REMARKS FCV-25-34 H-2 2 8 4.000 BUTFLY A MO C YES FAI EC QR Pl 2Y FCV-25-36 K-15 2 A 8.000 BUTFLY A PO C YES FC EC QR FS QR PI 2Y SLT-1 2Y VR-4 & VR-16 V-25.23 J-4 2 C 24.000 CHECK A S/A C NO CV/0 QR V-25-24 H-4 2 C 24 F 000 CHECK A S/A C NO CV/O QR
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Appendix D Valve Program Requests for Relief
0 Revision 2 08/01/92 RELIEF REQUEST NO. VR-1 SYSTEM:
Various COMPONENTS:
Any valves tested during cold shutdown conditions.
CATEGORY Various FUNCTION:
Various SECTION XI RE UIREMENT:
I Valves shall be exercised ... unless such operation is not practical during plant operation. If only limited operation is practical during plant operation, the valve shall be part-stroke exercised during plant operation and full stroke exercised during cold shutdowns. Full stroke exercising during cold shutdowns for all valves not full-stroke exercised during plant operation shall be on a frequency determined by the intervals between shutdowns as follows:
For intervals of 3 months or longer exercise during each shutdown. (IWV-3412, IWV-4315 and IWV-3522)
BASIS FOR RELIEF:
In many instances testing of all valves designated for testing during cold shutdown cannot be completed due to the brevity of an outage or the lack of plant conditions needed for testing specific valves. It has been the policy of the NRC that testing commences in a reasonable time and reasonable efforts if are made to test all valves, then outage extension or significant changes in plant conditions are not required when the only reason is to provide the opportunity for completion of valve testing.
ASME/ANSI OMa-1987, Operation and Maintenance'Of Nuclear Power Plants, Part 10 (Paragraphs 4.2.1.2 and 4.-3.2.2) recognizes this issue and allows deferred testing as set forth below.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-1 (cont.)
ALTERNATE TESTING:
For those valves designated to be exercised or tested during cold shutdown, exercising shall commence as soon as practical after the plant'reaches a stable cold shutdown condition, as.
defined by the applicable Technical Specification, 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 reaching cold shutdown. If the outage is sufficiently long enough for the testing of all the cold shutdown valves, then the 48-hour requirement need not apply. If the 48-hour requirement is waved, then all cold shutdown valves must be tested during the outage.
Valve testing need not be performed more often than once every three (3) months except as provided for in IWV-3417(a).
Completion of all valve testing during a.cold shutdown outage is not required if the length of the shutdown period is insufficient to complete all testing. Testing not completed prior to startup may be rescheduled for the next shutdown in a sequence such that the test schedule does not omit nor favor certain valves or groups of valves..
The program tables identify those valves to -which cold shutdown testing applies. Refer to Appendix E for discussion of the reasons and justification for allowing cold shutdown vs. quarterly testing.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-2 SYSTEM Safety Injection (2998-G-078, Sh. 131 & 132)
COMPONENTS:
V-3217 V-3227 V-3237 V-3247 V-3258 . V-3259 V-3260 V-3261 V-3215 V-3225 V-3235 V-3245 V-3524 V-3525 V-3526 V-3527 CATEGORY:
A/C (Check Valves)
FUNCTION:
These- check valves open -to provide for high-pressure and low-pressure safety injection to the RCS. Each of these valves is designated as a pressure isolation valve (PIV) and provides isolation of safeguard systems from the RCS.
SECTION XI RE UIREMENT:
The leakage rate for valves 6-inches or . greater shall be evaluated per Subsection IWV-3427(b). (IWV-3521)
BASIS FOR RELIEF:
Leak testing of these valves is primarily for the purpose of confirming their capability of preventing overpressurization and catastrophic failure of the safety injection piping and components. In this regard, special leakage acceptance criteria is established and included in, the St. Lucie 2 Technical Specifications (Table 3.4-1) that addresses the question of valve integrity in a more appropriate manner for these valves. Satisfying both the Technical Specification and the Code acceptance criteria is not warranted and implementation woul'd be difficult and confusing. Specifically applying the trending requirements of IWV-3427 would result in frequent and excessive maintenance of these(b)valves.
The continuation of a strict leakrate acceptance criteria and more frequent testing than specified by the Code gives a high degree of assurance that these valves will satisfactory perform their safety function.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-2 (cont.)
ALTERNATE TESTING:
The leakage rate acceptance criteria for"these valves-will be established per the St. Lucie Unit 2 Technical Specifications, Table 3.4-1. Leakage rates greater than .1.0 gpm- are unacceptable.
Each of the Reactor Coolant System Pressure Isolation Valve check valve shall be demonstrated operable by verifying leakage to be within its limits:
- 1. At least once per 18 months.
- 2. Prior to entering MODE 2 whenever the plant has been in COLD SHUTDOWN for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or more and if leakage testing has not been performed in the previous 9 months.'
~ Prior to returning the valve to service following maintenance, repair or replacement work on the valve.
4 ~ Following flow through valve(s) while in MODES 1,2,3, or
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4 A. Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by verifying valve closure, and B. Within 31 days by verifying leakage rate.
- 5. Following flow through valve(s) while in MODES 5 or 6:
A. Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of entering MODE 4 by verifying valve closure, and B. Within 31 days of entering MODE 4 by verifying leakage rate.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-3 SYSTEM:
Various COMPONENTS Various CATEGORY:
Various FUNCTION:
~ This is a generic request for relief SECTION XI RE UIREMENT:
If, for power-operated valves, an increase in stroke time of 504 or more for valves with full-stroke times less than or equal to 10 seconds is observed, the test frequency shall be increased to once each month until corrective action is taken, at which time the original test frequency shall be resumed (IWV-3417 (a) )
BASIS FOR RELIEF:
The stroke time measurements taken during testing of fast-acting valves =(those less than 2 seconds) are subject to considerable variation due to conditions unrelated to the material condition of the valve (eg. test conditions, operator reaction time). In accordance with Generic Letter 89-04, Position 6, an alternate method of evaluating stroke times is considered acceptable.
ALTERNATE TESTING:
The stroke time evaluation for those valves designated in the Plant Test Procedures as "fast-acting" will not account for successive increases of measured stroke time per IWV-3417(a) with the change in test frequency as required. In lieu of this, the assigned maximum limiting value of stroke time will be established at 2 seconds. Upon exceeding the 2-second limit, the valve will be declared inoperable and corrective action taken in accordance with IWV-3417(b).
D-5
l Revision 2 08/01/92 RELIEF REQUEST NO. VR-4 SYSTEM:
Primary Containment COMPONENTS:
PENETRATION NO. DRAWING NO. VALVES 10 2998-G-878 FCV-25-4 and Blank Flange 11 2998-G-878 FCV-25-2 and FCV-25-3 23 2998-G-083 HCV-14-1 and HCV-14-7 24 2998-G-.083 HCV-14-2 and HCV-14-6 41 2998-G-078 Sh 130 SE-03-2A and SE-03-2B 54 2998'-G-091 V-00101 and Blank Flange 56 2998-G-879 FCV-25-36 and FCV-25-26 57 2998-G-879 FCV-25-20 and FCV-25-21 CATEGORY:
A or A/C FUNCTION:
These valves are closed to provide containment isolation.
SECTION XI RE UIREMENT:
Category A valves shall be seat leak tested and a maximum permissible leakage rate shall be specified. Individual'valve leakage rates shall be evaluated per IWV-3426 and IWV-3427.
(IWV-3426, IWV-3427, NRC Generic Letter 89-04)
- -BASIS FOR RELIEF:
For several containment systems, individual leakage rate tests are impractical due to the configuration of the system's piping and components. In these .cases it is customary to perform leakage tests with the test volume between valves in series or behind valves in parallel paths.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-5 (cont.)
BASIS FOR RELIEF cont.
During cold shutdown, the introduction. of excess quantities of boric acid into the RCS is undesirable from the aspect of maintaining proper plant chemistry and the inherent difficulties that may be encountered during the subsequent startup due to over-boration of the RCS. The waste management system would also be overburdened by the large amounts of RCS coolant that would require processing to decrease the boron concentration. Since the boron concentration is increased for shutdown margin prior to reaching cold shutdown, a part stroke exercise of these valves could be performed at that time.
ALTERNATE TESTING:
Check valve V-2190 will be verified closed quarterly.
All of the check valves will be part stroke exercised during each cold shutdown per VR-1 and full stroke exercised during each reactor refueling outage.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-6 SYSTEM:
,Chemical and Volume Control System (2998-G-078, Sh 121)
COMPONENT:
V-2443 V-2444 CATEGORY:
FUNCTION:
These valves open to provide a flow path from the boric acid makeup pumps to the emergency boration header.
SECTION XI RE UIREMENT:
Check valves shall be exercised at least once every 3 months, except as provided by IWV-3522. (IWV-3521)
BASIS FOR RELIEF:
Full-stroke testing these valves requires operating the boric acid makeup pumps at or near rated flow and verifying full accident flow through each valve. Such testing would cause the introduction of highly concentrated boric acid solution from the boric acid makeup tanks to the suction of the charging pumps. This, in turn, would result in the addition of excess boron to the RCS. This rapid insertion of negative reactivity would result in a rapid RCS cooldown and depressurization. A large enough boron addition would result in an unscheduled plant trip and a possible initiation of Safety Injection Systems.
During cold shutdown, the introduction of excess quantities of boric acid into the RCS is undesirable from the aspect of maintaining proper plant chemistry and the inherent difficulties that may be encountered during the subsequent startup due to over-boration of the RCS. The waste management system would be overburdened by the large amounts of RCS coolant that would require processing to decrease its boron concentration.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-6 (cont.)
BASIS FOR RELIEF cont.
A second circuit that- recirculates water to the RWT-has flow-rate measuring instrumentation installed-however it is limited to 30 gpm. During an accident, either pump's discharge check valve must be able to pass a minimum flow capable of matching the demand of the two running charging pumps (greater than 80 gpm.) .
ALTERNATE TESTING:
Each of these valves will be partial stroke exercised quarterly.
During testing of the. boric acid makeup pumps performed during each reactor refueling (See Relief Request PR-5), system flow rate will be measured to verify full stroke of these valves.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-7 SYSTEM:
Safety Injection (2998-G-078 Sh 130)
COMPONENTS:
V-07000 V-07001 CATEGORY:
FUNCTION:
These valves open,to, provide flow paths from the RWT to the suction of the associated low-pressure safety injection pump.
SECTION XI RE UIREMENT:
Check valves shall be exercised at least once every 3 months, except as provided by IWV-3522. (IWV-3521)
BASIS FOR RELIEF:
Full stroke exercising these valves to the open position requires injection -into the,RCS via the LPSI pumps . During plant. operation this= "is- precluded because the LPSI pumps cannot develop sufficient discharge pressure to overcome primary system pressure. At cold shutdown, the shutdown cooling system cannot provide sufficient letdown flow to the RWT to accommodate full design flow from the RWT while maintaining the necessary core cooling function. Thus, the only practical. opportunity for testing these valves is during refueling outages when water from the RWT is used to refueling cavity.
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Revision 2 08/01/92
.RELIEF REQUEST NO. VR-7 (cont.)
ALTERNATE TESTING:
These valves w'ill be partial-flow exercised during-quarterly testing of the LPSI pumps via the minimum flow circuit and full-flow exercised during each reactor refueling-outage. '
D-13
h Revision 2 08/01/92 RELIEF REQUEST NO. VR-8 SYSTEM:
Safety Injection (2998-G-078 Sh 130)
COMPONENTS:
V-3401 V-3410 CATEGORY:
FUNCTION:
These valves open to. provide flow paths from the RWT and the-containment sump to the suction of the associated high-pressure safety injection pumps (HPSI).
SECTION XI RE UIREMENT:
Check valves shall be exercised at least once every 3 months, except as provided by IWV-3522. (IWV-3521)
BASIS FOR RELIEF:
Full stroke exercising these valves to the open position requires injection via the'HPSI pumps= into the RCS. During plant operation this is precluded because the HPSI pumps cannot develop sufficient discharge pressure to overcome primary system pressure. During cold shutdown conditions, operation of the HPSI pumps is restricted to preclude RCS system pressure transients that could result in exceeding the pressure-temperature limits specified in the Technical Specifications, Section 3.4.9.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-8 (cont.)
ALTERNATE TESTING:
These valves will be. partial-flow exercised'during quarterly testing of the HPSI .pumps via the minimum flow circuit and full-flow exercised during each reactor refueling outage.
This alternate testing satisfies the requirement of Generic Letter 89-04, Position l.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-9 SYSTEM:
Safety Injection (2998-G-078 Sh 130)
COMPONENTS V-3414 V-3427 CATEGORY:
FUNCTION:
These valves open to provide flow paths from the respective-HPSI pumps to the high-pressure safety injection headers.
They close to prevent recirculation through an idle pump.
SECTION XI RE UIREMENT:
Check valves shall be exercised at least once every 3 months, except as provided by IWV-3522. (IWV-3521)
BASIS FOR RELIEF:
Full stroke exercising these valves to the open position
~
requires injection -into"the RCS via the "HPSI pumps. During plant operation this is precluded because the HPSI pumps cannot develop sufficient discharge pressure to overcome primary system pressure. During cold shutdown conditions, operation of the HPSI pumps is restricted to preclude RCS system pressure transients that could result in exceeding the pressure-temperature limits specified in the Technical Specifications, Section 3.4.9.
Partial flow exercising of these valves i's performed whenever its associated HPSI pump is used to refill a SI Tank. The acceptable SI Tank level band specified by the Technical Specification is very narrow. The SI Tanks are only refilled on an as needed basis; therefore, the partial flow test cannot readily be incorporated into a quarterly test.
k Revision 2 08/01/92 RELIEF REQUEST NO. VR-9 (cont.')
ALTERNATE TESTING:
These valves will be verified closed quarterly and full-flow exercised to the open position during each reactor refueling outage.
These valves will be part-stroked open while refilling a SIT as plant conditions warrant.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-10 SYSTEM:
Safety Injection (2998-G-078 Sh 130)
COMPONENTS:
V-3522 V-3547 CATEGORY:
FUNCTION:
These valves open to provide flow paths from the high-pressure safety injection pumps to the RCS for hot-leg injection.
SECTION XI RE UIREMENT:
Check valves shall be exercised at least once every 3 months, except as provided by IWV-3522. (IWV-3521)
BASIS FOR RELIEF:
Full stroke exercising of these valves would require operating a high pressure safety injection (HPSI) pump and injecting into the reactor coolant system through the hot leg injection system. At power operation this is not possible because the HPSI pumps do not develop sufficient discharge pressure to overcome reactor coolant system pressure. During cold shutdown conditions, operation of the HPSI pumps is restricted to preclude RCS system pressure transients that could result in exceeding the pressure-temperature limits specified in the Technical Specifications, Section 3.4.9.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-10 ALTERNATE TESTING:
At least once during each reactor refueling outage these valves will be full-stroke exercised to the open position.
This alternate testing satisfies the requirement of Generic Letter 89-04, Position 1.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-11 SYSTEM:
-Safety Injection (2998-G-078 Sh 131)
COMPONENTS:
V-3113 V-3133 V-3143 V-3766 CATEGORY:
FUNCTION:
These valves open to provide flow paths from the high-pressure safety injection headers to the RCS.
SECTION XI RE UIREMENT:
Check valves shall be exercised at least once every 3 months, except as provided by IWV-3522. (IWV-3521)
BASIS FOR RELIEF
., Full stroke exercising of:these valves would require operating a high pressure safety injection (HPSI) pump at nominal accident flow rate and injecting into the reactor coolant system. At power operation this is not possible because the HPSI pumps do not develop sufficient discharge pressure to overcome reactor coolant system pressure. During cold shutdown conditions, operation of the HPSI pumps is restricted to preclude RCS system pressure transients that could result in exceeding the pressure-temperature limits specified in the Technical Specifications, Section 3.4.9.
Partial flow exercising of these valves is performed whenever its associated SI Tank is refilled. The acceptable SI Tank level band specified by the Technical Specification is very narrow. The SI Tanks are only refilled on an as needed basis; therefore, the partial flow test cannot readily be incorporated into a quarterly test.
D-20
Revision 2 08/01/92 RELIEF REQUEST- NO. VR-11 (cont.)
ALTERNATE TESTING:
These valves will be partial flow exercised when ever its associated SI Tank is filled.
At least once during each reactor refueling outage these valves will be full-stroke exercised to the open position.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-12 SYSTEM:
Safety Injection (2998-G-078 Sh 131)
COMPONENTS:
V-3524 V-3525 V-3526 V-3527 CATEGORY:
A/C FUNCTION:
These valves open to provide flow paths from the high-pressure safety injection pumps to the RCS for hot leg injection and close to isolate the safety injection headers from the high pressure of the reactor coolant system.
SECTION XI RE UIREMENT:
Check valves shall be exercised at least once every 3 months, except as provided by IWV-3522. (IWV-3521)
BASIS FOR RELIEF:
Full stroke exercising of these valves would require operating a high pressure safety injection (HPSI) pump at nominal accident flow rate and injecting into the reactor coolant system. At power operation this is not possible because the HPSI pumps do not develop sufficient discharge pressure to overcome reactor coolant system pressure. During cold shutdown conditions, operation of the.HPSI pumps is restricted to preclude RCS system pressure transients that could result in exceeding the pressure-temperature limits specified in the Technical Specifications, Section 3.4.9.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-12 '(Cont.)
BASIS FOR RELIEF cont.
These are simple check valves with no external means of position indication, thus the only practical means of verifying closure is by performing a leak test or back flow test. Performing leak tests of V-3524 and V-3526 involves a considerable effort. The test connection for these valves are located in a high radiation area in the pipe penetration room, and one of the two connections is located over 12 feet above the floor. Testing during operation or at each cold shutdown outage would constitute an unreasonable burden on the plant staff.
The other check valves, V-3525 and V-3527, .have upstream pressure alarms. Should either valve leak by, the pressure instruments would detect the increase and alarm in the control room when the alarm setpoint is exceeded.
ALTERNATE TESTING:
These valves will be full-stroke exercised to the open position at least once during each, reactor refueling outage.
This satisfies the requirements of Generic Letter 89-04, Position 1.
At least once every 18 months these valves will be verified to close in conjunction with PIV leak testing (see VR-2). In addition, V-3525 and V-3527 will be leak tested if the upstream pressure monitors indicate alarm during normal operation.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-13 SYSTEM Safety Injection (2998-G-078 Sh 132)
COMPONENTS:
V-3215 V-3225 V-3235 V-3245 CATEGORY:
A/C FUNCTION:
These valves open to provide flow paths from the safety injection tanks to the RCS and close to isolate the tanks from the high pressure of the reactor coolant system and the safety injection headers.
SECTION XI RE UIREMENT:
Check valves shall be exercised at least once every 3.months, except as provided by IWV-3522. (IWV-3521)
BASIS FOR RELIEF:
Full stroke exercising of. these valves would require injecting from a tank under nominal pressure into a de-pressurized reactor coolant system'. At power operation this is not possible because the SI Tank pressure is insufficient to overcome reactor coolant system pressure.
Under a large break LOCA accident conditions, the maximum (peak) flow rate through these valves would be approximately 20,000 gpm. During cold shutdown or refueling the required test conditions for developing this full accident flow cannot be established.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-13 (Cont.)
BASIS FOR RELIEF cont.
The SIT discharge isolation valves are motor operated valves with a nominal stroke "time of 52 seconds. Therefore, the isolation valve cannot be used to simulate the LOCA flow conditions by opening it with a full or partially pressurized SIT. The discharge. flow rate would only increase gradually due to the long stroke time of the discharge isolation valve.
The flow rate would not be anywhere near the expected peak blowdown rate of 20,000 gpm. expected during a large break LOCA.
FP&L has reviewed the operating and maintenance history of these valves and similar valves used throughout the industry-under comparable conditions. Based on these reviews, there is no evidence of valve degradation with respect to their ability to open and apparent satisfactorily from the failure pass the required flow. It data that the primary mode of is failure is related to valve leakage both past the seat and external through the body-bonnet and hinge pin gasket joints.
It should also be noted that these valves are not subjected to significant flow during plant operation any as well -as maintenance periods; thus it is unlikely that these valves would experience any service-related damage or wear.
Although check valve disassembly is a valuable maintenance tool that can provide,a great deal of information about a valve's internal condition, due to the difficulties associated with these maintenance activities, it'should only be performed under the maintenance program at a frequency commensurate with the valve type and service. In this light, FP&L considers the frequency of=inspection for these valves of once each 10-year inspection interval to be adequate to ensure the continued operability of these valves.
These are simple check valves with no external means of position indication, thus the only practical means of verifying closure is by performing a leak test or back flow test. The back flow tests are performed as part of the pressure isolation testing per VR-2.
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Revision 2
. 08/01/92 RELIEF REQUEST,NO. VR-13 (cont.)
ALTERNATE TESTING:
At least once during each ISI (10 year) inspection interval each of these valves will be disassembled, inspected, and manually stroked to verify operability. Should a valve under inspection be found to be inoperable, then the remaining three valves will be inspected during the same outage. Assurance of proper reassembly will be by performing a leak test
'or partial-flow test priorprovided to returning a valve 'to service following disassembly.
These valves will be verified closed in conjunction with PIV leak testing. See VR-2 for PIV testing frequency.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-14
-SYSTEM Safety Injection (2998-G-078 Sh 132)
COMPONENTS:
V-3217 V-3227 V-3237 V-3247 CATEGORY:
,A/C FUNCTION:
These valves open to provide flow paths from the safety injection headers to the RCS and close to isolate the headers from the high pressure of the reactor coolant system.
SECTION XI RE UIREMENT Check valves shall be exercised at least once every 3 months, except as provided by IWV-3522. (IWV-3521)
BASIS FOR RELIEF:
Full stroke exercising of these, valves would require injecting from a tank under nominal pressure into a de-pressurized reactor coolant system. At power operation this is not possible because the SI Tank pressure is insufficient .to overcome reactor coolant system pressure.
Under a large break LOCA accident conditions, the maximum (peak) flow rate through these valves would be approximately 20,000 gpm. During cold shutdown or refueling the required test conditions for developing this full accident flow cannot be established.
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Revision 2 08/01/92 RELIEF REQUEST NO. VR-14 (Cont.)
BASIS FOR RELIEF cont.
The SIT discharge isolation valves are motor operated valves with a nominal stroke time of 52 seconds. 'herefore, the isolation valve cannot be used to simulate the 'LOCA flow conditions by opening it with a full or partially pressurized SIT. The discharge flow rate would only increase gradually due to the long stroke time of the discharge isolation valve.
The flow rate would not be anywhere near the expected peak blowdown rate of 20,000 gpm. expected during a large break LOCA.
FP&L has reviewed the operating and maintenanc'e history of these valves and similar valves used throughout the industry under comparable conditions. These four valves have been in operation in Unit 2 since the'lant startup in 1983. A total of 2 plant work orders have been initiated for work .on these valves. Of the two work orders, one was to repair seat leakage identified by a seat leakage test and the other was for disassembly and inspection per Generic Letter 89-04. A search of the Nuclear Plant Reliability Data System for problems with valves similar to these revealed 12 reports 7 due to seat leakage and the remaining 5 were related to gasket leaks. Based on these reviews there is no evidence of valve degradation with respect to their ability to open and satisfactorily pass the required flow. It is apparent from the failure data that the-primary mode of failure is related to valve leakage both past the seat and external through the body-bonnet and hinge pin gasket joints.
In order to disassemble and inspect these valves, the reactor coolant system must be placed in mid-loop or "reduced inventory" condition for several days. In response to issues raised in NRC Generic'Letter 88-17, FPS<L is concerned about continued operations with the plant in a condition of "reduced inventory." During these periods, the risk of over-heating the core is increased due to the higher probability of an incident where shutdown cooling is lost. This risk is compounded by the reduced volume of water available to act as a heat sink should cooling be lost. Since 1982 there have been at least six (6) reported events in the industry where cooling flow was lost while a .plant was in a "reduced inventory" condition.
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- Revision 2 08/01/92 RELIEF REQUEST NO. VR-27 SYSTEM:
- 3. Leakage rates greater than 5.0 gpm are unacceptable.
- A valve whose failure in a position other than its normal position could jeopardize the immediate safety of the plant or system components;
- A valve whose failure in a position other than its normal position could cause all trains of a safeguard system to be inoperable;
- A valve whose failure in a position other than its normal position that might cause a transient that could lead to a plant trip; or
- When test requirements or conditions are precluded by system operation or access.
SUMMARY
IX. TEST DISCUSSION 2 A. Description of the Containment '2 B. Description of ILRT Instrumentation 4
- 1. Temperature Instrumentation 6
- 2. Humidity Xnstrumentation 7
- 3. Pressure Instrumentation 8
- 4. Flow Instrumentation ~ ~ ~ 8
- 5. Instrument Selection Guide (ISG) Ca lculat son 9 Containment Pressurization Equipment 9 Description of the Computer Program 10 Description of the Testing Sequence 11 III. ANALYSIS AND XNTERPRETATION ~ ~ 16 A. Instrumentation System Performance ~ ~ 16 B. Temperature Stabilization Phase ~ ~ 18 C. Leakage Survey Phase ~ ~ 19 D. Integrated Leakage Rate Phase ~ ~ ~ ~ ~ ~ 20 E. Verification Controlled Leakage Rate Phase ~ ~ 21 SECTION IV FIGURES ~ ~ ~ ~ ~ 22 A. RTD Locations and Volumes ~ ~ ~ ~ ~ 23 B. RHD Locations and Volumes ~ ~ ~ ~ ~ 24 C. Flow Diagram for Pressure Sensing and Controlled Leakage ~ ~ ~ ~ ~ 25 D. Data Collection Output, and Storage ~ ~ ~ ~ ~ 26 E. Flow Diagram for Pressurization System ~ ~ ~ ~ ~ 27 F. St. Lucie Unit 2 ILRT Sequence ~ ~ ~ ~ ~ 28 SECTION V APPENDICES 29 APPENDIX A. TABULATION OF nAS FOUNDn AND i<AS LEFTn ILRT RESULTS ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 31 A Correction of ILRT Result for "AS -FOUND" Case 31 B. Correction of ILRT Results for "AS-LEFT" Case 32 Appendix B: ILRT Raw Data and Graphical Interpretations
~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 33 Stabilization Data 34 Figure G Stabilization Period Air Mass & Vapor Pressure 64 Figure H Stabilization Period Average Temperature & Vapor Pressure 65 Figure I Historical vs Latest ILRT Vapor Pressure Trends 66 Figure J 4RH by Elevation During Stabilization 67 Figure K Temperature By Elevation During Stabilization 68 ILRT DATA ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 69 Figure L ILRT Containment Absolute Pressure 86 Figure M ILRT Weighted Average Temperature 87 Figure N ILRT Weighted Average Vapor Pressure 88
Figure 0 ILRT Calculated Air Mass 89 Figure P ILRT Bn-Top Rates Relative To Limits ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 90 Figure Q Local Sensor Deviations Affects Air Mass Calculation Figure R ILRT CLRT Air Mass and Fitted Leakage R ates 92 CLRT DATA . . . . . . . . . . ~ . ~ ~ 93 Figure S CLRT Containment Absolute Pressure 103 Figure T CLRT Weighted Vapor 104 Weighted Average Temperature Pressure'igure U CLRT 105 Figure V CLRT Calculated Air Mass 106 Figure W CLRT Bn-Top Rates Relative to Limits 107 APPENDIX C LOCAL LEAKAGE RATE TESTING CONDUCTED SINCE 1989 108 VI. LOCAL LEAKAGE RATE PROBLEMS SINCE LAST ILRT . . . . . . 119 A. Main Purge Exhaust (FCV-25-5) . . . . . . . . . . . 119 B. Personnel Air Lock . . . . '. . . . . . . . . . . . 120
I I
I
I. INTRODUCTION AND
SUMMARY
A periodic Type "A" Integrated Leakage Rate Test (ILRT) was successfully conducted on the primary containment structure of the Florida Power & Light Company St. Lucie Plant Unit No. 2 Pressurized- Water Reactor. This test was performed at full pressure in accordance with the facility Technical Specifications.
This ILRT test was performed using the "Absolute Method" of testing in accordance with the Code of Federal Regulations, Title 10, Part 50= Appendix J, "Primary Reactor Containment Leakage Testing for Water-Cooled Power Reactors," in accordance with ANSI N45.4 1972, American National Standard, "Leakage Rate Testing of Containment Structures for Nuclear Reactors," and the methodology and calculational requirement of Topical Report BN-TOP-1, Revision 1, "Testing Criteria for Integrated Leakage Rate Testing of Primary Containment Structures for Nuclear Power Plants." The ILRT was performed at a pressure in excess of the calculated peak containment internal pressure related to the design basis accident as specified in the Final Safety Analysis Report (FSAR) and the Technical Specifications. This report describes and presents the results of the periodic Type "A" leakage rate testing, including the supplemental test method utilized for verification. In addition, Florida Power & Light Company performs types "B" and "C" testing in accordance with the requirements of 10CFR50, Appendix J, and the Technical Specifications. The results of types "B" and "C" testing performed since the last ILRT are provided in this report.
I The resulting reported "as-found" Type "A" containment leakage at 42.3 psig is 0.052 percent of the contained mass per day. This value includes the difference between the as-found and as-left minimum pathway Types "B" and "C" local leakage measurements as required by the NRC I6E Information Notice 85-71. The resulting reported "as-left" Type "A" containment leakage at 42.3 psig is 0.052 percent of the contained mass per day. The acceptance criteria for this test as contained in the facility Technical Specifications is that leakage cannot exceed 0.375 percent of the contained air mass per day for either the "as-found" or "as-left" case.
II. TEST DISCUSSION A. Description of the Containment The containment. vessel completely encloses the entire reactor and reactor coolant system to ensure no leakage of radioactive
'materials to the, environment in the unlikely event of a loss of coolant accident.
The containment system design incorporates a free-standing containment vessel surrounded by a low-leakage concrete shield building. A four-foot annular space is provided between the outer wall of the containment vessel and the inner wall of the shield building to allow filtration of containment vessel leakage during
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accident conditions to minimize off-site doses.
The free-standing containment vessel is a two-inch thick r'ight circular cylinder with a one-inch thick hemispherical dome and two-inch thick ellipsoidal bottom. The overall vessel dimensions are 140-foot diameter by 232-foot high. The vessel wall thickness is increased to a minimum of four inches adjacent to all penetrations and openings. The vessel is fabricated of ASME-SA 516 Grade 70 fully kilned pressure vessel quality steel plate. The net free volume of the containment vessel is 2.5 x 10~ cubic feet.
The containment vessel structure includes one personnel airlock, one emergency escape lock, one fuel transfer tube, one equipment maintenance hatch and one seal-welded construction hatch.
All process piping and electrical penetrations are welded directly to the containment vessel nozzles with the exception of the main steam, main feedwater, and fuel transfer tube penetrations. These penetrations are provided with testable multiple ply expansion bellows to allow for thermal growth or building differential motion.
The containment vessel is designed and constructed in accordance with the requirements for Class MC vessels contained in Section IZZ of the ASME Code. The containment vessel is code stamped for a design internal containment pressure of 44 psig at a temperature of 264 'F. The containment vessel and all penetrations
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are designed to limit leakage to less than 0.5 percent by weight of the contained air per day at the above design conditions. The calculated peak accident pressure for the design basis accident for the St. Lucie Plant No. 2 is 41.8 psig, in accordance with Technical Specification 3.6.1.2.a.1 B. Description of ILRT Instrumentation The containment system was equipped with instrumentation to permit leakage rate determination by the "absolute method."
Utilizing this method, the actual mass of dry air within the containment is calculated. The leakage rate becomes the time rate of change of this, value. The mass of air (Q) is calculated according to the Perfect Gas Law as follows:
where: P - Containment Total Absolute Pressure Pv Containment Water Vapor Pressure (Average)
V Containment Net Free Volume R Gas Constant T Containment Absolute Temperature (Average)
The primary measurement variables required are containment absolute pressure, containment relative humidity, and containment temperature as a function of time. During the supplementary verification test,. containment bleed-off flow is also recorded.
Average containment absolute temperature is determined by measuring discrete local temperatures throughout the containment and applying a mass and volume weighted averaging technique. The volume fraction for each sensor is determined based upon solid geometrical calculations:
=E- vs T Tx where: T - Containment Absolute Temperature (Average) for Sensor ii T>
Local Temperature Vf; Volume Fraction for Sensor Average containment water vapor pressure is determined by measuring discrete local relative humidities throughout the containment, converting these to local vapor pressures using local group temperatures and applying a mass and volume weighted averaging technique. The volume fractions for the relative humidity sensors are determined in the same manner as for the temperature'ensors above.
Pv>=SRH>*Psat for T>
where: 4RH; - Relative Humidity for Sensor j Psat for T; Steam Table Saturation Pressure for local group average temperature near sensor j Pv Calculated local vapor pressure for sensor j Pv Containment Water vapor pressure (Average)
Containment Absolute Temperature (Average)
VF) Volume Fraction for sensor j Local temperature for sensor j The Instrument Selection Guide or ISG is used to determine the ability of the instrumentation system to measure the leakage rate.
The calculated ZSG for this test met all acceptance criteria for all test instrumentation systems.
- 1. Temperature Instrumentation Forty precision Resistance Temperature Detectors (RTDs) were located throughout the containment to allow measurement of the weighted average air temperature. The location of the temperature detectors in the containment is depicted in Figure A. Each RTD sensor was supplied with a calibrated resistance versus temperature curve accurate to +0.5 'F. The sensitivity and repeatability of each RTD sensor is less than +0.01 'F.
The signal conditioning circuit and readout for the RTD
sensors was a Fluke 2280B data logger operating in a constant current mode. The operating parameters for the RTD constant current card are accurate to +0.16 'F and has a resolution of +0.01 oF Each RTD was in situ calibration checked after installation to verify correct operation. The data logger operating as a total loop with an RTD in the circuit has a repeatability of +0.01 'F and a resolution of +0.01 'F.
- 2. Humidity Instrumentation Ten Resistance Humidity Detectors (RHDs) were located throughout the containment to allow measurement of the weighted average containment vapor pressure. The location of the RHDs in the containment is depicted in Figure B. The calibrated accuracy of the RHDs is +2.5 percent RH, the repeatability of the RHDs is
+0.01 percent RH, and the sensitivity of the RHDs is +0.1 percent The readout device used for the RHDs was a Fluke 2280B data I
logger. The repeatability*of this device is +0.01 percent RH while the resolution of the device is +0.01 percent RH.
Each RHD was in situ calibration checked after installation to verify correct operation.
- 3. Pressure Instrumentation Two precision vibrating cylinder element pressure sensors were used to determine containment absolute pressure. The arrangement of tubing connections between the pressure sensors and the containment is shown in Figure C. Either pressure sensor could be used as the primary pressure sensor for leakage rate calculations with the remaining sensor being considered. as a backup. The calibrated accuracy of the manometers is +0.015 percent of reading.
The sensitivity, repeatability, and resolution of the pressure sensors is +0.002 psi. Binary Coded Decimal (BCD) output from both pressure sensors was connected to the Fluke 2280B data logger.
- 4. Flow Instrumentation A variable area float-type rotameter was used to superimpose leakage during the supplementary CLRT. The piping connection between the'otameter and the containment is shown in Figure C.
The accuracy, repeatability, and sensitivity for the rotameter in units of SCFM and converted to equivalent leakage values is given below:
Equivalent SCFg Laa~acae Peak Pressure Rotameter Accuracy +0 20
~ +0.0031 4/day Repeatability +0.05 +0.0008 4/day sensitivity +0.05 +0.0008 4/day
- 5. Instrument Selection Guide (ISG) Calculation The Instrument Selection Guide is a method of compiling the instrumentation sensitivity and resolution for each process measurement variable used during the ILRT and evaluating the total instrumentation system's ability to detect leakage rates in the range required. The ISG formula is described in American National Standard ANSI/ANS 56.8-1987. Although the ISG is a very conservative measure of sensitivity, the general industry practice for this test has been to require sensitivity at least four times better than the containment allowable leakage or ISG < 0.25La.
The calculated ISG for the instrumentation used for this test was 0.0078 percent per day, for'n 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> test. The allowable value for this test is 0.25La or 0.125 percent per day, for an 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> test. The ISG calculation met all recommended criteria and demonstrated the ability of the ILRT instrumentation system to measure containment leakage with a sensitivity exceeding that required by the appropriate industry standards.
C. Containment Pressurization Equipment The equipment used to pressurize the containment is shown in Figure D. The 'nine oil-free industrial diesel-driven air compressors had a total nominal capacity of 13,200 SCFM. The compressed air was then routed to water-cooled aftercoolers,
moisture separators, and refrigerant air dryers. This equipment assured that clean and dry air was used to pressurize the containment.
D. Description of the Computer Program The Ebasco ILRT computer program is an interactive program written specifically for fast, easy utilization during all phases of the ILRT and CLRT. The program iq written in a high-level, compiled, structured language and is operated on portable MS-DOS personal computer. The program has been verified and meets all requirements of the Ebasco and Florida Power & Light Quality Assurance Programs.
As necessary, data entry and modifications are readily accomplished by the data'cquisition team. In addition to extensive data verification routines, the program calculates, on demand, total time and mass point leak rates as well as the 95 percent Upper Confidence Level for these leakage rate calculations.
Calculations and methodology of the program are derived from American National Standard ANSI N45.4-1972, ANSI/ANS 56.8-1987 and Topical Report BN-TOP-1, Revision 1.
Input data may be deleted for a given instrument in the case of a sensor malfunction. The deletion of a given instrument is performed on all samples in the data base. Weighting factors, if applicable, are then recalculated for the remaining instrument 10
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sensors of that type (see section III.A).
Data evaluations are enhanced by the flexible display of either sensor variables or various computed values in tabular or graphical form on the computer screen or printer. Data is recorded on magnetic media to prevent loss during the testing. All data is stored on the computer system in use, with retrieval capability to any desired data base throughout the testing.
Ancillary portions of the program assist the user in determination of temperature stabilization, determining the ILRT termination criteria, performing ISG calculations, performing in situ instrument loop performance calculations and determination of acceptable superimposed CLRT leakage verification.
Temperature, pressure and humidity data are transmitted from the ILRT instrumentation system to the computer via an RS-232 link at 20 minute intervals. Computer verification and checking routines supplement data verification by the data acquisition team.
Modifications are promptly made when errors are detected.
E. Description of the Testing Sequence Preparations to pressurize the containment for the conduct of the ILRT included internal and external inspections of the containment structure; installation and check out of the ILRT 11
instrumentation; Types "B" and "C" Local Leakage Rate Tests; alignment of valves and breakers for test conditions; and the installation and check out of the temporary pressurization facilities. These preparations were completed on June 15, 1992.
I All ILRT in5trumentation was declared operable with performance within manufacturers'olerances, with the exception of TE-20 and TE-38. These were deleted from computer calculations and the volume fractions adjusted accordingly. Pressure sensor No. 1 was selected to be the primary pressure instrument, as it had exhibited better repeatability and stability during the in situ testing.
Three penetrations were required to be in service during the ILRT and were not lined up to simulate accident conditions; P-7 (Primary Makeup Water), P-52D (ILRT Pressure Sensing Line), and P-52E (ILRT Controlled Bleed off Line).
Primary water to the containment is required for fire protection, and the two ILRT penetrations are used to conduct the test. The minimum pathway leakage for these penetrations, determined during Type "C" local testing, is added to the measured ILRT leakage to account for these penetrations being in service during the test.
(P-54 ILRT pressurization line is normally isolated with a blank flange and one valve. During the Test the only isolation is the valve outside containment is shut. As a conservative measure the leakage for this penetration is also used in Appendix A for 12
calculation of the "as-left" condition.)
Pressurization of the containment started at 10:10 hours on June 15,1992. Figure E pictorially depicts the sequence of testing at pressure. The pressurization rate was maintained at 4.4 psi/hr, and a target pressure of 58.48 psia was achieved at 20:00 hours on 6/15/92. This target pressure was 1.98 psi above the minimum test pressure to account for the expected pressure decrease due to temperature stabilization and to allow for some leakage margin during the test sequence. Data acquisition and analysis during the temperature stabilization phase began at 20:00 hours at. 20 minute intervals.
j During pressurization, Leak Survey Teams found no indication of any significant leakage on any of the leak chase points The containment temperature stabilization criteria was met at 00:00 hours on June 16,1992, after acquisition of four hours of data. During this period, the temperature and pressure decreases followed predictable trends. Because of high relative humidity readings, and indications of instability in the vapor pressure calculations stabilization was conservatively continued until 15:20 on '/16/92. For more detailed discussion see Analysis and Interpretation Section.
The 8.67 hour7.75463e-4 days <br />0.0186 hours <br />1.107804e-4 weeks <br />2.54935e-5 months <br /> period of leakage measurements started at 15:20 hours on June 16,1992, and was successfully terminated at 00:00 I
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hours on June 17,1992, with acceptable leakage values determined.
The data accumulated displayed the following leakage rates:
Simple BN-TOP-1 Leakage Rate = -0.0232 4/day Fitted BN-TOP-1 Leakage Rate = -0.0104 4/day 954 Upper Confidence Level (UCL) = 0.0516 4/day The leakage plot had a negative skew after 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. The acceptance criteria for this test is 0.75 La or 0.375 4/day.
To verify the results of the ILRT, a verification Controlled Leakage Rate Test (CLRT) was conducted. Using the variable area full-pressure rotameter, a superimposed flow of 17.79 SCFM was added to the leakage already present in the containment. This superimposed flow is equivalent to leakage of 0.264 percent per day. A one-hour stabilization period was allowed to lapse after addition of this leakage in accordance with the requirements of Topical Report BN-TOP-1. Data accumulation for the CLRT was started at 01:00 hours on June 17,1992 and the CLRT was conducted for a 4.4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> period. The measured CLRT leakage rates for this period were:
Simple BN-TOP-1 Leakage Rate = 0.2524 4/day Fitted BN-TOP-1 Leakage Rate = 0.2529 4/day Target CLRT Leakage Rate = 0.253 4/day 14
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The target CLRT leakage for this test was 0.253 +0.125 percent per day, or within the criteria as measured. As shown in figure g the calculated air mass and fitted leakage rate quickly changed when the controlled leak rate was introduced. The ILRT and CLRT were declared successful at 05:30 hours on June 17,1992.
At 05:31 hours on June 17,1992, depressurization of the containment was initiated at a rate of 6 psi/hr. Containment entry for post-test inspection purposes occurred when the containment pressure was approximately 1.6 psig at 14:00 hours on June 17,1992.
The post-test inspection detected no anomalies or damage other than several broken lighting fixture covers. Particular attention was paid for evidence of any leakage that may have contributed to high humidity levels, none was found.
Corrections were made to the measured ILRT leakage to account for the three penetrations which were in service during the ILRT and to account for the difference between the as-found and as-left minimum pathway local leakage values as required by NRC I&E Information Notice 85-71.
954 Upper Confidence Level (UCL) during ILRT = 5.16 x10~ 4/day Corrections for Local Leakage Measurements = 8.5 x 10~~~a Total Reported Containment UCL = 5.25 x 10~ 4/day This value satisfies the acceptance criteria for the test of being less than 0.375 percent per day.
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III. ANALYSIS AND INTERPRETATION A. Instrumentation System Performance All of the 38 temperature detectors inservice at the start of the test performed as expected with no anomalous behavior detected by the Ebasco ILRT computer program error checking routines during the conduct of the test. This computer program also determines the in-situ temperature loop repeatability which consists of process measurement variations as well as sensor noise.
The average in situ loop repeatability for the 38 operating temperature sensors was 0.0104 'F. This performance compares well with the vendor-claimed temperature sensor loop repeatability, excluding process variations, as given in Section II.B.1. However several RTD's showed a significantly higher calculated repeatability than the group as a whole. A detailed review of the data gathered reveals that between test samples 85 and 100 there were some oscillations in RHD-6, RHD-7 and TE-13, TE-21, TE-22, TE-
- 27. These deviations are believed to indicate a density turnover and are not believed to indicate any sensor failure. However this data also shows the sensitivity of leakage calculations when small leakage rates are being measured. This does not necessarily indicate a sensor malfunction, but may indicate local variations in process as well, see figure P.
Ten relative humidity sensors were installed in the 16
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containment for the ILRT. All ten channels for humidity operated as expected with no anomalous behavior detected by the ILRT computer program error checking routines, except as noted above.
The average in situ loop repeatability for the relative humidity sensors was 0.07 percent RH. At the start of the stabilization period group average humidity ranged from 444 at the lowest elevation to 644 at the upper elevation. Because of the high humidity levels experienced during the test the humidity group at the top elevation reached saturation levels as the containment atmospheric temperatures equalized with the structure temperatures.
Also because of the stratification of humidity by elevation; mixing and stabilization were slow to occur. Sensor response was monitored during the test, phase and depressurization phase. All sensor trends followed group trends and expected response based on pressure and temperature changes.
Two pressure sensors were installed for the ILRT, with one utilized for testing and one considered as a spare. Prior to containment pressurization, computer analysis demonstrated that pressure sensor 1 was more stable over an eight-hour period than the other sensor. During the ILRT, the in-situ pressure loop repeatability for both sensors was 0.0002 psi. This performance compares well with the vendor-claimed pressure sensor loop repeatability, excluding process variations, given in Section II.B.3.
The variable area rotameter performed as expected with no 17
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evidence of unstable reading, float sticking, or moisture in the float. tube.
In summary, all of the ILRT test instrumentation performed in an adequate manner to allow determination of containment leakage rates to the sensitivity required, as verified by the controlled leakage rate test.
B. Temperature Stabilization Phase Prior to pressurization of the containment, the atmospheric conditions were very unstable. In-situ humidity checks varied from 59% to 75%, depending on the day they were performed. For several days prior to the ILRT the site had experienced severe afternoon thunder storms with high temperatures in the 90's. Prior to pressurization the containment was purged with two of the pressurization compressors and dryers for several hours in an attempt to reduce average humidity levels. Average humidity was reduced from approximately 754 to 604 . During pressurization, the cool and dry air introduced at the bottom of containment acts as a "piston" and compresses and heats the air at the top of containment. At the end of pressurization, the average temperature was 102.9 'F with a maximum spread of temperature from the highest reading sensor to lowest reading sensor of 24.4 'F.
The results of the temperature stabilization phase are presented in Appendix B.l. The acceptance criteria given in Topical Report 18
BN-TOP-1, Revision 1, are described in Note 2 in that appendix.
However as seen in figures F, G, and H vapor pressure did not stabilize as quickly as temperature. This shows that modeling the containment with a discrete number of sensors can overstate the effects of the vapor pressure correction to the Ideal Gas Law, during periods of high unstable humidity. The data presented shows that a smooth and predictable temperature stabilization occurred.
At the end of stabilization, the average temperature was 91.1 'F with a maximum spread of temperature from the highest reading sensor to the lowest reading sensor of 7.4 'F. This demonstrates that the heat sinks of concrete and steel in the containment were returning the containment atmosphere to a stable temperature condition.
C. Leakage Survey Phase Leakage survey teams found no indications of any significant leaks during the test at any of the leak chase detection points.
Since the total type B & C minimum path leakage was 1.17 SCFM (1.75X10~ 4/day) this result was not unexpected. Leakage rate measurements on the containment were started after the temperature stabilization phase using the total time leakage rate methods of Topical Report BN-TOP-1, Revision 1. As an additional diagnostic tool, mass point leakage rate measurements, -as described in ANSI/ANS 56.8-1987, were conducted in parallel. The mass point leakage calculations are not sensitive to the starting point of the 19
I test and will detect changes in containment leakage more rapidly than the total time method.
D. Integrated Leakage Rate Phase Leakage measurements were started at. 15:20 hours on June 16, 1992. The total time BN-TOP-1 results for 8.67 hours7.75463e-4 days <br />0.0186 hours <br />1.107804e-4 weeks <br />2.54935e-5 months <br /> of .leakage measurements are presented in Appendix B.3. A summary of the measured leakage after eight hours is:
BN-TOP-1 Total Time Simple Leakage Rate -0.0232 4/day Fitted Leakage Rate -0.0104 4/day Upper Confidence Level 0.0516 4/day Type B&C Minimum Path 0.0175 4/day The higher Upper Confidence Level of the BN-,TOP-1 measurements is due to the nature of performing regression analysis on simple leakage rates instead of regression analysis on masses and the more conservative statistics utilized by BN-TOP-1.
. A conservative calculation of the minimum path leakage based on the Type "B" & "C" test'program is 0.0175 4wt/day. This small value combined with the instabilities described in section III.B help explain the very small calculated leakage rates. If the temperature sensor with the largest sample to sample deviation is deleted the new calculated leakage rates are: fitted leakage rate 0.0193, and UCL of 0.0810.
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As all acceptance criteria for a Reduced Duration BN-TOP-1 ILRT were met after 8.67 hours7.75463e-4 days <br />0.0186 hours <br />1.107804e-4 weeks <br />2.54935e-5 months <br /> as presented in Appendix B.2, the lLRT was declared acceptable. Appendix A presents the corrections to the measured ZLRT leakage rates for local leakage rate measurements for both the "as-found" and "as-left" cases.
E. Verification Controlled Leakage Rate Phase Subsequent to the acceptance of the ILRT results, a superimposed leakage equivalent to 0.264 percent per day was added to the existing containment leakage using the variable area rotameter. A one-hour stabilization period was allowed to lapse
,after addition of this leakage in accordance with the requirements of Topical Report BN-TOP-1.
Leakage measurements were initiated to verify the results of the ZLRT. The minimum duration for the Controlled Leakage Rate Phase was determined to be 4.33 hours3.819444e-4 days <br />0.00917 hours <br />5.456349e-5 weeks <br />1.25565e-5 months <br /> in accordance with Topical
'eport BN-TOP-l. As presented in Appendix B.3, the leakage measurements met the acceptance criteria for the verification phase.
BN-TOP-1 Total Time Simple Leakage Rate 0.252 4/day Fitted Leakage Rate 0.253 4/day 21
SECTION IV FIGURES 22
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RTD LOCATIONS AND VOLUMES 3 RTD's el.194 VOLUME 242,055 CU FT.
9 RTD'S el.
453,235 171'OLUME CU FT 10 RTD'S el.
669,627 130'OLUME CU FT
'l0 RTD'S el.
600,926 84'OLUME CU FT 8 RTD'S EL.
534,157 40'OLUME CU FT Figure A
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RHP LOCATIONS AND VOLUMES 3 RHD'S el 1,049,347 171'OLUME CU FT 4 RHD'S el 900,640 CU FT 84'OLUME 3 RHD'S el 550,0'l3 CU FT 40'OLUME Figure 8
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FLOW DIAGRAM ILRT PRESSURE SENSING Bc CONTROLLED LEAKAGE INSTRUMENTS preclsfon vtbrotfng cyffn der presswe sensor INSIDE OUTSIDE CONTAINMEQ CONTAINMENT monitored vent precfsfon vfbratfng CO DE/SATE PO fan% ~" ~B~
L5p CO DE SATE P YARIABL AREA ROTAMETER L
ILRT INSTRUMENTATION DIAGRAM DATA COLLECTION, OUTPUT, AND STORAGE Volumetrics IBM PC Pressure EBASCO Sensor Software Fluke Data Logger 40 RTD Hum etc Diskette Humidity 10 p Data Col}ection IBM PC Detector EBASCO
- Data Analysis Software II Diskette
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ILRT PRESSURIZATION Bc l3EPRESSURIZING SYSTEM TO ATMOSPHERE I i
I outside containment I inside containment TO UNIT NO. 1 I I
ILRT l I I
PENEIRATION I I
I Pl PI 8" blind flange removed I for ilrt P54 dl Ip pot Diesel driven industrial 100Fo oil free 0 ir corn p ress ors
// (13.200 aim total)
(9 COITlpl'BSSWS) 5 refrigerant dryers wig a gc l
moisture seperators ~a/c
~a/d
St. Lucie Unit 2 ILRT Sequence A B C D E 60 55 50 6)
L.
N 40 U) 0 A. Pressurization .4. psi/ r CL tQ C B. ContainrrIent Stab lization erio ca I C 30 C., Integrated Leakag Rate Th st (~ RT)
D. Verification Test 0 Controlled Leakag Rate T st (I LRT}
C O
0 20 E. Depressurizaiion 6 psi/
10 20 40 60 Hours into Test
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SECTION V APPENDICES 29
APPENDIX A TABULATIONOF "AS-FOUI'6) 326) "AS-LEFT" ILRT RESULTS 30
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APPENDIX A: TABULATION OF "AS-FOUND" AND "AS-LEFT" ILRT RESULTS A Correction of ILRT Result for "AS -FOUND" Case In accordance with NRC I&E Information Notice 85-71, additions are required to the ILRT results due to repairs and/or adjustments made due to Local Leakage rate testing during an outage in which an ILRT is conducted. The corrections include only repairs or adjustments made to containment leakage boundaries which were made prior to the ILRT. These corrections are the difference between the pre-repair and post-repair leakages calculated in the minimum pathway case and corrected for uncertainties in the measurements. During the 1992 refueling outage, three such corrections are necessary.
Total Minimum ILRT Penetration Pathwa Re ai Uncertaint Total P-28A SIT Sample P-50 Spare 40 sccm 55 sccm 1
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'9 41.79 56.79 Personnel Airlock 20,000 sccm 347 20,347 The total local minimum pathway leakage plus uncertainty must be added for the penetrations which are in use during the ILRT and whose containment isolation valves are not tested during the ILRT:
Total Minimum ILRT Penetratio Pathwa Leaka e Unce tai t Total P-52D ILRT Test 100 sccm 1.79 101.79 P-52E ILRT Test 80 sccm 1.79 81.79 P-7 Primary Water 400 sccm 12.8 412. 8 P-54 ILRT Test 900 sccm 109 1009 31
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The total "as-found" correction can be found adding the above ILRT to both corrections.
Correction of ILRT results for "as-found" case 22,051 sccm or 1.167 x 10~ 4/day Measured ILRT leakage at a 954 UCL + 5.16 x10 4/day Reported "as-found" ILRT results 5.172 x10~ 0/day Acceptance Criteria (75% La) 0.375 4/day B. Correction of ILRT Results for "AS-LEFT" Case The only correction for the "as-left" ILRT case involves the penetrations which were in use during the test, P-52D, P52E, P-54, and P-7. From the above section, the ILRT "as-left" correction can be determined. (Note: A conservative simplification was made by not performing a root-mean-scpxare summation of the local uncertainties.)
Correction of ILRT results for "as-left" case 1605.4 sccm or 8.49~ 4/day Measured ILRT Leakage at a 95 4 UCL + 5.16x 10'/day Reported "as-left" ILRT results 5.25x10'/day Acceptance Criteria (754 La) 0.375 4/day 32
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Appendix B: ILRT Raw Data and Graphical Interpretations 33
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Stabilization Data Sample TEST RTD 1 RTD 2 RTD 3 RTD 4 Number TIME DEG F DEG F DEG F DEG F 31 9 ~ 817 89.344 91.791 88. 971 88.296 32 10.15 88.093 89.792 87.741 87.239 33 10.483 87.891 89.108 87.494 87.013 34 10.817 87.750 88.830 87.409 86.896 35 11.150 87.653 88.647 87.378 86.831 36 11.483 87.557 88.540 87.324 86.777 37 11.817 87.483 88.423 87.270 86.724 38 12.150 87.429 88.338 87.217 86.692 39 12.483 87.387 88.262 87.185 86.639 40 12.817 87.344 88.209 87.143 86.596 41 13.150 87.310 88.155 87.098 86.565 42 13.483 87.290 88.101 87.067 86.520 43 13 '17 87.257 88 '70 87.044 86.500 44 14.150 87.232 88; 034 87.019 86.484 45 14.483 87.203 87.994 86.993 86.446 46 14 '17 87.178 87.958 86.966 86.430 47 15.150 87.149 87.943 86.939 86.403 48 15.483 87.140 87.889 86.928 86.381 49 15.817 87.106 87.867 86.894 86.361 50 16.150 87.095 87.835 86.885 86.350 51 16.483 87.075 87.813 86.874 86.327 52 16 817 87.053 87.793 86 '63 86.318 53 17.150 87 '39 87.797 86 '4@ 86.314 54 17.483 87.032 87.770 86.820 86.285 55 17 '17 87.010 87.748 86.798 86.274 56 18.150 86 '79 87 '17 86.798 86.265 57 "18.483 86.990 87.706 86.778 86.253 58 18.817 86.967 87.685 86.778 86.253 59 19.150 86.967 87.685 86.766 86.231 60 19.483 86.967 87.652 86.755 86.220 61 19 '17 86.956 87.643 86.746 86 '11 62 20 '50 86.947 87.621 86.735 86.200 63 20.483 86.947 87 '21 86.724 86.200 64 20 '17 86.925 87.609 86.724 86.188 65: 21.150 86.925 87 '89 86.713 86.168 66 21.483 86.893 87.578 86.701 86.157 67 21.817 86.893 87.567 86 '92 86.157 68 22.150 86.893 87.556 86.681 86.157 69 22.483 86.871 87.547 86 '81 86.146 70 22 '17 86.878 87.531 86 '77 86 '41 71 23.150 86.860 87.524 86 '48 86.135 72 23.483 86 '49 87.524 86.659 86.124 73 23 '17 86.828 87.502 86.648 86.115 74 24.150 86.866 87.489 86 '45 86.110 75 24.483 86.840 87.482 86.627 86 '03 76 .24.817 86 '28 87.460 86.627 86.092 77 25.150 86.828 87.471 86.639 86.092 78 25.483 86.828 87.448 86.616 86.081 34
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Stabilization Data Sample TEST RTD 1 RTD 2 RTD 3 RTD 4 Number TIME DEG F DEG F DEG F DEG F 79 25. 817 86 '17 87.439 86.616 86.081 80 26. 150 86.806 87.428 86 '05 86.070 81 26.483 86.806 87.428 86.596 86.070 82 26 '17 86.797 87.417 86.596 86.070 83 27.150 86.786 87.406 86.605 86.061 84 27.483 86.801 87.413 86.601 86.068 85 27 '17 86.763 87.397 86.585 86.050 86 28.150 86.786 87.386 86.596 86.050 87 28.483 86.752 87.375 86.596 86.050 88 28.817 86.763 87.375 86.596 86.050 35
Stabilization Data Sample TEST RTD 5 RTD 6 RTD 7 RTD 8 Number TIME DEG F DEG F -
DEG F DEG F 31 9. 817 88.001 88.815 89.150 88.280 32 10. 150 87.061 87.991 88.188 87.187 33 10.483 86.825 87.733 87.972 86.985 34 10.817 86.729 87.648 87.856 86.888 35 11.150 86.610 87.583 87.759 86.823 36 11.483 86.536 87.509 87.672 86 '69 37 11.817 86.503 87.433 87.587 86.727 38 12.150 86.482 87.370 87.533 86.693 39 12.483 86.440 87.316 87.479 86.650 40 12 '17 86.417 87.262 87.425 86 '08 41 13.150 86.386 87.219 87.394 86.588 42 13.483 86.364 87 '75 87.340 86.543 43 13.817 86.343 87.143 87.308 86.511 44 14.150 86.328 87.118 87.273 86.496 45 14.483 86 '90 87.069 87.223 86.469 46 14.817 86.285 87.042 87.185 86.453 47 15.150 86 '67 87.004 87.158 86.415 48 15.483 86.236 86 '73 87.125 86.404 49 15 '17 86.225 86.950 87.104 86.383 50 16.150 86.225 86.928 87.073 86.361 51 16.483 86.202 86.896 87.051 86.350 52 16 '17 86.193 86.876 87.028 86.330 53 17.150 86.177 86.860 87.026 86 '36 54 17.483 86.160 86.831 86.997 86.307 55 17.817 86 '48 86.811 86.974 86.287 56 18.150 86.139 86.789 86.965 86.276 57 18.483 86 '28 86.769 86.943 86.265 58 18.817 86.117 86.757 86.932 86.253 59 19 '50 86.106 86.735 86.923 86.242 60 19..483 86.097 86.726 86.912 86.222 61 19.817 86.097 86.703 86.889 86 '11 62 20 '50 86.086 86.692 86.878 86.199 63 20.483 86.074 86 '81 86.869 86.191 64 20.817 86.074 86.672 86.858 86 179
~
65 21.150 86.063 86.661 86.835 86.168 66 21.483 86.052 86.650 86.826 86,168 67 21.817 86.043 86.638 86.815 86 '57 68 22.150 86.032 86.627 86.804 86.146 69 22.483 86.043 86.618 86.793 . 86.137 70 22.817 86.027 86.614 86.788 86.132 71 23.150 86 '09 86.607 86.773 86.125 72 23.483 86.020 86.596 86.773 86.114 73 23.817 85.998 86.596 86.761 86.103 74 24.150 85.996 86.582 86.757 86.110 75 24.483 85.989 86.576 86.739 86.094 76 24.817 85.989 86.564 86.728 86'094 77 25.150 85.978 86 '53 86.728 86.083 78 25.483 85.967 86.542 86.719 86.072 36
Stabilization Data Sample TEST RTD 5 RTD 6 RTD 7 RTD 8 Number TIME 'DEG F DEG F DEG F DEG F 79 25 817
~ 85.978 86.542 86.708 86.072 80 26.150 85.955 86.531 86.696 86.060 81 26.483 85.955 86.531 86.685 86.049 82 26.817 85.947 86.522 86.676 86.049 83 27.150 85.947 86.511 86.676 86.040 84 27.483 85.942 86.517 86.672 86.047 85 27 '17 85.935 86.499 86.654 86.040 86 28.150 85.924 86.499 86.654 86.029 87 28.483 85.924 86.488 86.643 86.029 88 28.817 85.924 86.499 86.643 86.018 37
I Stabilization Data Sample TEST RTD 9 RTD 10 RTD 11 RTD 12 Number TIME DEG F DEG F DEG F DEG F 31 9. 817 107.34 105.85 107.57 107.52 32 10 150 105.33 103.61 105.41 105.12 33 34
~
10.483 10.817 103.91 103.09 102 '5 101.55 103.80 102.94 103.62 102.78 35 36 11.150 11.483 102.51 102.08 100.92 100.49 102 '0 102.03 102 '1 101.90
.37 11.817 101.70 100.07 101 '9 101.53 38 12.150 101.38 99.696 101.44 101.18 39 12.483 101.08 99.318 101 '9 100.88 40 12 '17 100.89 98.986 100.95 100.59 41 13.150 100.63 98 '07 100 '3 100.35 42 13.483 100.'46 98.448 100.51 100.13 43 44 13 '17 14.150 100 '1 100.02 98.221 98.003 100.25 99.980 99.867 99.573 45 14 '83 99.749 97.781 99.695 99.276 46 14 '17 99.520 97.574 99.424 99.036 47 15.150 99.255 97.363 99 '49 98.762 48 15.483 99.009 97.170 98.902 98.546 49 15 '17 98.796 96.985 98.656 98 '19 50 16 '50 98.558 96.803 98.409 98.052 51 16.483 98.302 96.630 98.183 97.859 52 16.817 98.107 96 '59 97.948 97.632 53 17.150 97.878 96.316 97.742 97.403 54 17.483 97.690 96.147 97.520 97.181 55 17 '17 97.486 96.019 97.328 96.976 56 18.150 97.293 95.869 97.135 96.806 57 18.483 97.120 95.729 96.952 96.613 58 18.817 96.950 95.579 96.770 96.440 59 19 '50 96.766 95.448 96 '98 96.269 60 19.483 96.596 95.309 96.439 96.076 61 19.817 96.446 95.201 96.266 95.934 62 20 '50 96.295 95.085 96.105 95.775 63 20.483 96 '23 94.954 95.955 95.613 64 '5 20 '17 95.984 94.858 95.805 95.463 21.150 95.845 94.761 95.667 95.313 66 21.483 95.695 94.653 95.539 95.216 67 21.817 95.576 94.546 95.389 95.054 68 22.150 95.426 94.440 95.250 94.947 69 22.483 95.309 94.332 95.132 94.796 70 22 '17 95.208 94.242 95.011 94.664 71 23.150 95.074 94.139 94.885 94.538 72 23.483 94.966 94.009 94.767 94.410 73 23 '17 94.847 93.912 94 '50 94.302 74 24.150 94.746 93.834 94.539 94.201 75 24.483 94.623 93.719 94.424 94.078 76 24.817 94.527 93.622 94 '17 93.959 77 25.150 94 419 93.537 94 '12 93.862 78 25.483 94.312 93.429 94.104 93.777 38
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Stabilization Data Sample TES'9 RTD 9 RTD 10 RTD 11 RTD 12 Number TIME DEG F DEG F DEG F DEG F 79 25. 817 94 '15 93.333 94.008 93.681 80 26.100 94.119 93.256 93.912 93.551 81 26.483 94.011 93.149 93.816 93 '65 82 26. 817 93.915 93.075 93.708 93.358 83 27.150 93.830 92.989 93.612 93.272 84 27.483 93.740 92.920 93.532 93.194 85 27.817 93.626 92.828 93.429 93.099 86 28.150 93.539 92.742 93.344 92.994 87 28.483 93.465 92.677 93.270 92.906 39
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Stabilization Data Sample TEST RTD 13 RTD 14 RTD 15 RTD 16 Number TIME DEG F DEG F DEG F DEG F 31 9. 817 107. 14 107.64 106.96 106.33 32 10.150 104.86 105.32 104.60 104.80 33 10.483 103.37 103.74 103.22 103.33 34 10.817 102.55 102.74 102.24 102.39 35 11.150 101.96 102.16 101.64 101.70 36 11.483 101.52 101.70 101.17 101.21 37 38 11.817 12.150 101 '3 100.82 101.43 101.16 100.80 100.51 100.82 100.49 39 12.483 100.56 100.90 100.23 100.19 40 12 '17 100.29 100.63 99.947 99.910 41 13.150 100.07 100.35 99.711 99.643 42 13.483 99.905 100.07 99.462 99.407 43 13 '17 99.658 99.817 99.238 99.18 44 14.150 99.460 99.565 99.009 98.972 45 14.483 99.283 99.257 98.809 98.752 46 14.817 99.054 98.982 98.623 98.554 47 15 '50 98.790 98 '19 98 '12 98.354 48 15.483 98.532 98.503 98.239 98.170 49 15.817 98.316 98.267 98.046 98.042 50 16.150 98.103 98.029. 97.907 97.977 51 16.483 97.857 97.793 97.842 97.903 52 16 '17 97.661 97.525 97.661 97.722 53 17.150 97.433 97 '05 97.591 97.578 54 17.483 97.244 97 '40 97.414 97.410 55 17 '17 97.029 96.900 97.264 97.228 56 18 '50 96.868 96 '96 97.091 97.055 57 18.483 96.675 96.482 96.909 96.873 58 18 '17 96.482 96.298 96.748 96.701 59 19.150 96.321 96 '38 96.577 96.539 60 19.483 96.139 95.988 96.405 96.380 61 19 '17 95.978 95.792 96.254 96 '18 62 20.150 95 '18 95.632 96.093 9,6. 034 63 20.483 95.668 95.448 95.954 95.906 64 20.817 95.538 95.320 95.792 95.767 65 21.150 95.379 95 '38 95.653 95 '17 66 21.483 95.238 95.008 95.514 95.478 67 21 '17 95.110 94.857 95.375 95.339 68 ,22.150 94.982 94.729 95.245 95.198 69 22.483 94.841 94.599 95.106 95.070 70 22.817 94.720 94.488 95.005 94.937 71 23.150 94.628 94.309 94.871 94 '12 72 23.483 94.521 94.169 94.752 94.704
- 73. 23.817 94.402 93.987 94.635 94.576 74 24.150 94.281 93.886 94.535 94 '75 75 24.483 94.155 93.803 94.409 94.361 76 24 '17 94.166 93.729 94.301 94.253 77 25.150 94.144 93.601 94.196 94.157 40
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Stabilization Data Sample TEST RTD 13 RTD 14 RTD 15 RTD 16 Number TIME DEG F DEG F DEG F DEG F 78 25.483 94.059 93.502 94.089 94.049 79 25.817 93.940 93.374 93.992 93.944 80 26.150 93.889 93.277 93.884 93.848 81 26.483 93 '12. 93.158 93.788 93.771 82 26 '17 93.705 93.053 93.703 93.686 83 27.150 93.620 92.954 93 '04 93.601 84 27.483 93.541 92.833 93.515 93.520 85 27.817 93.458 92.752 93.423 93.428 86 28.150 93.351 92.687 93.338 93.354 87 28.483 93.254 92.601 93.252 93.247 88 28 '17 93.192 92.451 93 ~ 176 93.159 41
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Stabilization Data Sample TEST RTD 17 RTD 18 RTD 19 RTD 20 Number TIME DEG F DEG F DEG F DEG F 31 9. 817 107.85 107.98 101.58 Deleted 32 10.150 105.55 105.65 99.533 Deleted 33 10.483 103.93 104.01 98.492 Deleted 34 10.817 102.90 103.03 98.041 Deleted 35 11.150 102.41 102.44 97.451 Deleted 36 11.483 101.98 102.05 97.108 Deleted 37 11.817 101.57 101.71 96.764 Deleted 38 39 12.150 12.483 101 '7 100.84 101.43 101.18 96.603 96 '10 Deleted Deleted 40 12 '17 100.58 100.95 96.206 Deleted 41 13.150 100.31 100.74 96.035 Deleted 42 13.483 100.07 100.41 95.885 Deleted 43 13.817 99.865 100.08 95.712 Deleted 44 14.150 99.590 99 '15 95.569 Deleted 45 14.483 99.316 99.539 95.412 Deleted 46 14.817 99 '96 99 '90 95 '91 Deleted 47 15.150 98.841 99 '14 95.145 Deleted 48 15.483 98.562 98.745 95.026 Deleted 49 15 '17 98.304 98.520 94.898 Deleted 50 16.150 98.056 98.296 94.768 Deleted 51 16.483 97.829 98.049 94.661 Deleted 52 16 '17 97.519 97 '45 94.555 Deleted 53 17.150 97.332 97 '48 94.454 Deleted 54 17 '83 97.110 97.437 94.340 Deleted 55 17.817 96.874 97.233 94.244 Deleted 56 18 '50 96.658 97.051 94.136 Deleted 57 18.483 96.422 96.867 94.028 Deleted 58 18.817 96.066 96.686 93.943 Deleted 59 19.150 95.904 96.513 93.847 Deleted 60 19.483 95.734 96.331 93.750 Deleted 61 19.817 95.549 96.170 93.654 Deleted 62 20 '50 95.387 96 '20 93.589 Deleted 63 20.483 95.228 95.870 93.493 Deleted 64 20 '17 '5.023 95 '19 93 '19 Deleted 65 21.150 94 '15 95 '80 ,93.331 Deleted 66 21.483 94.765 95.430 93.246 Deleted 67 21.817 94 637 95.291
'5. 163 93 '70 Deleted 68 22.150 94.506 93.096 Deleted 69 22.483 94.378 95.033 93.022 Deleted 70 22.817 94.234 94.933 92.952 Deleted 71 23.150 94.108 94.787 92.872 Deleted 72 23.483 94.012 94.659 92.795 Deleted 73 23.817 93.895 94.552 92.730 Deleted 74 24.150 93.749 94.440 92.674 Deleted 75 24.483 93.645 94.316 92 '91 Deleted 76 24.817 93.583 94.220 92.549 Deleted 77 25.150 93 '63 94.112 92 '64 Deleted 78 25.483 93.378 94.005 92.410 Deleted 42
I Stabilization Data Sample TEST RTD 17 RTD 18 RTD 19 RTD 20 Number TIME DEG F DEG F DEG F DEG F 79 25.817 93 '81 93.897 92.345 Deleted 80 26.150 93.185 93.790 92.280 Deleted 81 26.483 93.097 93.693 92.217 Deleted 82 26 '17 92.980 93.608 92.163 Deleted 83 27.150 92.904 93.512 92.110 Deleted 84 27.483 92.825 93.422 92.051 Deleted 85 27 '17 92.722 93 '19 91 '91 Deleted 86 28.150 92.648 93.234 91.937 Deleted 87 28.483 92.529 93.158 91.883 Deleted 88 28.817 92.452 93.061 91.820 Deleted 43
Stabilization Data Sample TEST RTD 21 RTD 22 RTD 23 RTD 24 Number TIME DEG F DEG F DEG F DEG F 31 9. 817 99.575 99.300 100.09 99.832 32 10. 150 97.817 97.800 98.112 98.133 33 10.483 96.926 96.760 96.956 96.911 34 10.817 96.335 96.247 96.324 96.449 35 , 11.150 95.916 95.850 96.097 96.159 36 11.483 95.455 95.624 95.831 95.912 37 11 '17 95.220 95.411 95.723 95.687 38 12.150 95.036 95.230 95.573 95.483 39 12.483 94.865 95.046 95.360 95.333 40 12 '17 94.737 94.896 95.199 95. 171 41 13.150 94.618 94.768 95 '80 95.032 42 13.483 94.490 94 '41 94.941 94 '81 43 13 '17 94.371 94.511 94.825 94.785 44 14.150 94.237 94.387 94 '10 94.682 45 14.483 94.136 94.275 94.610 94.592 46 14.817 94.028 94.168 94.502 94.484 47 15.150 93.911 94.063 94.386 94.376 48 15.483 93.815 93.955 94.321 94.291 49 15 '17 93.718 93.859 94.244 94.194 50 16.150 93.620 93.772 94 '71 94.098 51 16.483 93.535 93.666 94.063 93.981 52 16.817 93 '18 93.579 93.978 93.916 53 17.150 93.330 93.494 .93.882 93.820 54 17.483 93.234 93.409 93.785 93.734 55 17 '17 93.149 93.324 93.720 93.615 56 18.150 93.063 93.236 93.624 93.561 57 18.483 92.967 93.162 93.550 93 '65 58 18 '17 92.891 93 '77 93 '85 93.368 59 19 '50 92.805 92.927 93.411 93.314 60 19 '83 92.769 92.838 93.342 93 '13 61 19 '17 92.689 92.755 93.261 93.153 62 20 '50 92.619 92.677 93 '72 93.117 63 20.483 92.538 92.596 93.100 93 '14 64 20 '17 92 '69 92.526 93.042 92.946 65 21.150 92.388 92.446 92.950 92.863 66 21.483 92.280 92.338 92.885 92.778 67 21 '17 92.233 92.291 92.838 92.753 68 22.150 92 '41 92.200 92.746 92.670 69 22.483 92.088 92.135 92.703 92.616 70 22 '17 92.011 92.070 92 '18 92.531 71 23.150 91.980 92.007 92.576 92.500 23.483 91.915 91.942 92.511 92.446
'2 73 23 '17 91.852 91.877 92.446 92.361 74 24.150 91.794 91 '30 92.390 92.334 75 24.483 91.744 91.761 92.329 92.253 76 24.817 91.702 91.696 92".265 92 '10 77 25.150 91.637 91.642 92.211 92.156 78 25.483 91.583, 91.600 92.137 92.102 44
Stabilization Data Sample TEST RTD 21 RTD 22 RTD 23 RTD 24 Number TIME DEG F DEG F DEG F DEG F 79 25. 817 91.520 91.526 92.083 92.049 80 26.150 91.466 91.461 92.029 91.963 81 26.483 91.424 91.407 91.987 91 '10 82 26.817 91 '79 91.365 91.933 91.867 83 27.150 91 '16 91.322 91.879 91.802 84 27.483 91.262 91.280 91.848 91..739 85 27.817 91.208 91.237 91.806 91 '63 86 28.150 90.746 91. 183 91.761 91.620
'15 87 88 28.483 28.817 90 90.672
- 91. 150
- 91. 096 '1.'18 91 676 91.566 91.501 45
Stabilization Data Sample TEST RTD 25 RTD 26 RTD 27 RTD 28 Number TIME DEG F DEG F DEG F DEG F 31 9. 817 105.78 99. 629 98.998 99. 187 32 10.150 103.61 97.940 97.357 97.664 33 10.483 102.45 96.834 96.501 96.485 34 10.817 101.74. 96.297 96 '30 95.606 35 11.150 101.22 95.899 95.804 95.286 36 11.483 100.80 95.620 95.537 95 '71 37 11 '17 100.48 95.405 95.344 94.869 38 12 '50 100.19 95.234 95.183 94 '19 39 12.483 99.924 95.083 94.990 94.580 40 12 '17 99.677 94.975 94.851 94.450 41 13 '50 99 '31 94.793 94.701 94.311 42 13 '83 99.206 94.685 94.583 94 '50 43 13.817 98.991 94.589 94.444 94.011 44 14.150 98.769 94.443 94.309 93.877 45 14.483 98.563 94.319 94.197 93.787 46 14.817 98.379 94.191 94.092 93.691 47 15.150 98.197 94.072 93.973 93.583 48 15.483 98.005 93.966 93.854 93.518 49 15 '17 97.834 93.870 93.758 93.422 50 16.150 97.650 93.805 93.673 93.294 51 16.483 97.491 93.685 93.556 93 '09 52 16.817 97.307 93.580 93.480 93.122 53 17.150 97.137 93.526 93.395 93.048 54 17.483 96.987 93.429 93.319 92.951 55 17.817 96.825 93.321 93.223 92.844 56 18.150 96.666 93.236 93.149 92.801 57 18.483 96.516 93 '71 93.073 92.727 58 18.817 96.366 93.095 92.999 92.694 59 19.150 96.205 93.009 92.914 92.609 60 19.483 96.061 92 '19 92.833 92.519 61 19 '17 95.893 92.838 92.752 92.481 62 20 '50'0.483 95.772 92.791 92.674 92.412 63 95.615 92.751 92.602 92.340 64 20 '17 95.483 92 '15 92.544 92.262 65 21.150 95.337 92.591 92.452 92.192 66 21.483 95 '19 92.506 92.378 92.127 67 21.817 95.098 92.448 92.342 92 '91 68 22.150 94.963 92.344 92.239 92.000 69 22.483 94.833 92 290 92.174 91.946 70 22 '17 94.705 92.236 92.121 91.881 71 23.150 94.587 92.194 92.024 91.827 72 23.483 94.481 92.117 91.971 91.773 73'4 23 '17 94.374 92.066 91.906 91.708 24 '50 94.251 92.018 91.850 91.664 75 24.483 94.139 91 947 91.778 91 '92 76 24.817 94.042 91.881 91 '93 91 '49 77 25.150 93.944 91.839 91 '17 91.496 78 25.483 93.839 91.774 91 '43 91.420 46
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'Sample TEST RTD 25 RTD 26 RTD 27 RTD 28 Number TIME DEG F DEG F DEG F DEG F 79 25 817
~ 93.731 91.742 91.478 91;377 80 26.150 93.635 91.668 91. 413 91.334 81 26.483 93.538 91 '14 91.339 91.303 82 26 '17 93.453 91.571 91.286 91.227 83 27 '50 93.357 91.506 91 '12 91. 196 84 27.483 93.261 91.475 91 '58 91 ~ 131 85 27 '17 93 '73 91.441 91.082 91 '88 86 28 '50 93.088 91.378 91.008 91.034 87 28.483 93.003 91.356 90.932 90.981 88 28 '17 92 '18 91.282 90.835 90 '07 47
Stabilization Data Sample TEST RTD 29 RTD 30 RTD 31 RTD 32 Number TIME DEG F DEG F DEG F DEG F 31 9 ~ 817 110.36 112.32 112. 16 112.40 32 10. 150 107.61 109.41 109.35 109.53 33 34 10.483 10 '17 105.73 104.44 107 '1 105.82 107.29 105.68 107.35 105.92 35 11.150 103.67 104.73 104.56 104.82 36 11.483 102.99 103.80 103.75 103.94 37 11. 817 102.52 103.10 103.00 103.28 38 39 12.150 12 '83 101.90 101.49 102 '1 101.93 102.38 101.79 102.67 102.11 40 12.817 101.04 101.47 101.27 101.63 41 13 '50 100.70 101.06 100.85 101.11 42 13.483 100.39 100.65 100.47 100.73 43 13.817 100.08 100.25 100.09 100.41 44 14.150 99.774 99.886 99.718 100.08 45 14 '83 99.502 99.581 99 '13 99.788 46 14.817 99.222 99.237 99.082 99.509 47 15.150 98.955 98.959 98.793 99.220 48 15.483 98.697 98.669 98.471 98.950 49 15.817 98.439 98.422 98.204 98.692 50 16 '50 98.192 98.175 97.862 98.456 51 16.483 97.978 97.928 97.669 98.200 52 16 ~ 817 97.743 97.715 97.392 9'7. 962 97.559 97.488 97.049 97.738
'7 53 ~ 150 54 17.483 97.323 97.275 96.812 97.513 55 17 '17 97.119 97.059 96.599 97.287 56 18.150 96.937 96.855 96.331 97.094 57 18.483 96.744 96 '62 96.107 96 '12 58 18 '17 96.562 96.491 95.946 96.739 59 19 '50 96.390 96.298 . 95 '33 96.546 60 19 '83 96.215 96.132 95.548 96.382 61 19 '17 96.037 95.966 95.337 96.203 62 20.150 95.914 95 '11 95.161 96.050
.63 20.483 95.757 95 '31 94.962 95.870 64 20 '17 95.604 95.499 94.798 95.760 65 21.150 95.456 95.322 94.630 95 '92 66 21.483 95.329 95 '82 94.481 95.430 67 21.817 95.207 95 '70 94.349 95.309 68 22.150 95.039 94 '13 94.203 95.163 69 22.483 94.911 94.774 94.011 95.013 70 22 '17 94.804 94.666 93.872 94.905 71 23.150 94.676 94.550 93.680 94.778 72 23.483 94.557 94.399 93 '19 94.659 73 23.817 94 '38 94.291 93.349 94.551 74 24.150 94.328 94.179 93 '26 94.430 75 24.483 94 '14 94.076 93.134 94 '15 76 24 '17 94.095 93.959 92.995 94.208 77 25 '50 93.999 93.852 92 '88 94.134 78 25.483 93.893 93.744 92.749 93.994 48
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Stabilization Data Sample TEST RTD 29 RTD 30 RTD 31 RTD 32 Number TIME DEG F DEG F DEG F DEG F 79 25. 817 93.797 93.636 92.642 93.887 80 26.150 93.700 93.529 92.535 93.768 81 26.483 93.593 93.443 92.430 93.683 82 26 '17 93.496 93.347 92.334 93.683 83 27.150 93.400 93.250 92.238 93.575 84 27.483 93.312 93.154 92.141 93.490 85 27 '17 93.227 93.057 92.043 93.351 86 28 '50 93.142 92.972 91.916 93.265 87 28.483 93.057 92.896 91. 819 93 '12 88 28 '17 92.969 92.822 91 681
~ 93.147 49
Stabilization Data Sample TEST RTD 33 RTD 34 RTD 35 RTD 36 Number TIME DEG F DEG F DEG F DEG F 31 9. 817 112.76 111.99 111.14 111.66 32 33 10.150 10.483 109.82
'107.57 109.44 107.56 108.53 106.63 109 '6 106.94 34 10.817 106.12 106.06 105.36 105.62 35 11.150 105.10 105.02 104.27 104.47 36 11.483 104.18 104.12 103.40 103.71 37 11 '17 103.44 103.42 102.70 103.01 38 12.150 102.82 102.77 102.12 102.36 39 12.483 102.18 102.19 101.65 101.81 40 12 '17 101.70 101.73 101.22 101.27 41 13.150 101.27 101.30 100.82 100.93 42 13.483 100.88 100.91 100.45 100.61 43 13 '17 100.46 100.54 100.11 100.11 44 14 '50 100.09 100.20 99.792 99.826 45 14.483 99.777 99 '08 99.475 99 '12 46 14 '17 99.465 99.584 99.165 99.200 47 15.150 99.167 99.306 98.864 98 '64 48 15.483 98 '98 99.027 98 '74 98.717 49 15.817 98.608 98.780 98.273 98.461 50 16.150 98.361 98 '21 98.038 98.169 51 16.483 98 '14 98.274 97.779 97.924 52 16 '17 97.890 98.049 97.555 9.7. 709 53 17.150 97.654 97 '33 97.319 97.493 54 17.483 97.450 97 '19 97.081 97.257 55 17.817 97.246 97.404 96.879 97.053 56 18.150 97.031 97.210 96.664 96.871 57 18.483 96.849 97.006 96.459 96.667 58 18 '17 96.678 96.835 96.266 96 '96 59 19.150 96.485 96.651 96 '62 96.303 60 19.483 96.308 96.487 95 '09 96.160 61 19.817 96 '51 96 '09 95 '18 95.991 62 20.150 95.987 96 '54 95 '12 95.827 63 20.483 95.830 95.985 95.323 95.670 64 20.817 95.687 95.842 95.211 95 493 65 21.150 95.669 95.684 95.023 95.381 66 21.483 95.510 95.556 94 '07 95.208 67 21. 817 95.366 95.435 94.675 95.098 68 22.150 95.209 95.278 94.506 94.961 69 22.483 95.079 95 '36 94.367 94.802 70 22 '17 94.974 95 '30 94.251 94.694 71 23.150 94.844 94.900 94.109 94.564 72 23.483 94.727 94.783 93.970 94.436 73 23.817 94.597 94.664 93.874 94.339 74 24 150 94.487 94.554 93.741 94.218 75 24.483 94.362 94.439 93.627 94.104 76 24.817 94 254 94.320 93 '10 93.985 77 25.150 94.115 94.224 93.360 93.877 78 25.483 94.072 94.107 93.252 93.781 50
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Stabilization Data Sample TEST RTD 33 RTD 34 RTD 35 RTD 36 Number TIME DEG F DEG F DEG F DEG F 79 25.817 93.953 94.019 93.187 93.675 80 26.150 93.848 93.903 93.048 93.567 81 26.483 93.740 93.806 92.963 93.491 82 26 '17 93.633 93.709 92.824 93.386 83 27.150 93.548 93.622 92.727 93.289 84 27.483 93.440 93.516 92.619 93.193 85 27.817 93.355 93.420 92.512 93.116 86 28 '50 93.258 93.332 92.404 93.020 87 28.483 93 '86 93.247 92.202 92.935 88 28.817 93.023 93.161 92.061 92.850 51
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Stabilization Data Sample TEST RTD 37 RTD 38 RTD 39 RTD 40 Number TIME DEG F DEG F DEG F DEG F 31 9. 817 112.37 Deleted 111.64 112. 16 32 10. 100 109.63 Deleted 108.70 109.81 33 10.483 107.43 Deleted 106.54 107.66 34 10 '17 106.12 Deleted 105.06 106.27 35 11.150 105.02 Deleted 103.94 105.13 36 11.483 104.29 Deleted 102.97 104.22 37 11.817 103.38 'eleted 102.23 103.48 38 12.150 102.78 Deleted 101.50 102.88 39 12.483 102.21 Deleted 100.92 102.17 40 12 '17 101.68 Deleted 100.35 101.63 41 13.150 101.23 Deleted 99.861 101.20 42 13.483 100.82 Deleted 99.443 100.75 43 13.817 100.46 Deleted 99.024 100.37 44 14.150 100.09 Deleted 98.653 100.01 45 14.483 99.772 Deleted 98.285 99.698 46 14 '17 99.449 Deleted 97.951 99.382 47 15.150 99 '48 Deleted 97.653 99 '63 48 15.483 98.850 Deleted 97.363 98.742 49 15 '17 98 '12 Deleted 97 '94 98.473 50 ,16.150 98 '76 Deleted 96.836 98.217 51 16.483 98.109 Deleted 96.601 97.959 52 16.817 97.917 Deleted 96.343 97.744 53 17.150 97.681 Deleted 96 '18 97.526 54 17.483 97.454 Deleted 95 '03 97.304 55 17. 817 97.241 Deleted 95.690 97.068 56 18.150 97.046 Deleted 95.486 96.875 57 18.483 96.853 Deleted 95.304 96.671 58 18 '17 96.683 Deleted 95 '23 96.487 59 19.150 96.468 Deleted 94.939 96 '17 60 19.483 96 '15 Deleted 94.775 96 '44 61 19 '17 96.158 Deleted 94.596 95.982 62 20 '50'0.483 95.981 Deleted 94.432 95.812 63 95.835 Deleted 94.275 95.662 64 20. 817 95.692 Deleted 94.132 95.480 65 21. 150 95.503 Deleted 93.963 95.361 66 21.483 95.376 Deleted 93.836 95.189 67 21.817 95.263 Deleted 93.724 95.049 68 22.150 95.106 Deleted 93.558 94.922 69 22.483 94.979 Deleted 93.439 94.792 70 22 '17 94.840 Deleted 93.300 94.648 71 23.150 94.721 Deleted 93.172 94.536 72 23.483 94.582 Deleted 93.053 94.386 73 23.817 94.474 Deleted 92.926 94.278 74 24.150 94.364 Deleted 92.813 94.166 75 24.483 94.239 Deleted 92.699 94.052 76 24 '17 94 '42 Deleted 92.592 93.935 77 25.150 94.035 Deleted 92.486 93 '16 78 25.483 93.927 Deleted 92.379 93.666 52
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Stabilization Data Sample TEST RTD 37 RTD 38 RTD 39 RTD 40 Number TIME DEG F DEG F DEG F DEG F 79 25. 817 93.811 Deleted 92.282 93.569 80 26. 150 93.703 Deleted 92.175 93.442 81 26.483 93.607 Deleted 92.078 93.354 82 26. 817 93.521 Deleted 91.982 93.249 83 27.150 93.414 Deleted 91.886 93.161 84 27.483 93.329 Deleted 91.789 93.083 85 27.817 93.253 Deleted 91.704 92.980 86 28.150 93.156 Deleted 91 '08 92.895 87 28.483 93.071 Deleted 91.520 92.787 88 28.817 92.986 Deleted 91.435 92.722 53
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Stabilization Data Sample TEST RHD 1 RHD 2 RHD 3 RHD 4 Number TIME RH RH 31 9. 817 41. 75 47.51 39 31
~ 52.19 32 10. 150 42.60 48.52 39.88 57.21 33 10.483 42.87 49.26 40.88 60.08 34 10.817 43.25 49.82 41.62 56.52 35 11.150 43.54 49.99 43.43 63.05 36 11.483 43.66 50.39 45.27 66.99 37 11.817 43.79 51.00 46.34 72.35 38 39 12 '50 12.483 43.90 44.06 51.55 52.11 47.18 47.77 72 '8 72.48 40 12 '17 44.23 52.68 48.29 73.80 41 42 13.150.
13.483 44 '1 44.59 53 '1 53.84 49.02 49.59 74.53 75.36 43 13 '17 44.82 54.32 50.18 76.06 44 14.150 45.06 54.76 50.76 77.24 45 14.483 45.33 55.10 51.28 77.87 46 14.817 45.55 55.49 51.77 77.90 47 48 15.150 15.483 45 46
'3
'1 55.84 56.22 52.27 52.78 78.58 79.08 49 50 15 '17 16.150 46.30 46 '8 56.47 56.80 53.20 53.63 79 '1 79.60 51 16.483 46.81 57.09 54.04 79.82 52 53 16 '17 17.150 47.12 47.43 57 '0 57.82 54.45
.54.85
'79. 96 80.11 54 17.483 47.69 58 '1 55.21 80.23 55 17.817 47.86 58.57 55.55 80.13 56 57 18.150 18.483 48.15 48.54 58 '6 59 '7 55 '1 56.20 80.18 80.24 58 18.817 48.73 59.54 56.52 80.55 59 19.150 49.02 59 '1 56.80 80 '7 60 19.483 49.26 60.09 57.06 80.51 61 19.817 .49.61 60.39 57.44 80.51 62 20.150 49.76 60.67 57.79 80.67 63 64 20 20
'83
'17 49.92 50.15 60.96 61.25 58.18 58 '0 80 '8 80.89 65 21.150 50.48 61.55 58.81 80.80 66 21.483 50.71 61.84 59.15 81 00 59 '5 F
67 21.817 50.98 62.11 80.92 68 22.150 51.19 62.36 59 '6 81.08 69 22.483 51.45 62.63 60.04 81. 14 70 22.817 51.62 62.88 60.36 81 24
~
71 23.150 51.96 63.17 60.64 81. 30 72 73 23.483 23.817 52.22 52.51 63 63
'9
'6 60.91 61.20
- 81. 28
- 81. 29 74 24.150 52.76 63.88 61.49 81. 26 75 24.483 52.93 64.13 61.77 81. 38 76 24 '17 53.18 64.35 62.03 81. 30 7.7 78 25.150 25.483 53 '6 53.69 64.62 64 '1 62.29 62.57 81.36
- 81. 42 54
Stabilization Data Sample TEST RHD 1 RHD 2 RHD 3 RHD 4 Number TIME RH RH % RH RH 79 25 ~ 817 53.90 65.04 62.80 81. 58 80 26. 150 54.06 65.25 63.07 81. 54 81 26.483 54.26 65.46 63.30 81. 52 82 26.817 54.50 65.69 63.55 81. 45 83 27.150 54.68 65.92 63.82 81. 56 84 27.483 54.94 66.13 64.06 81. 55 85 27.817 55.10 66.31 64.28 81. 57 86 28.150 55.31 66.49 64.53 81. 57 87 28.483 55.50 66.68 64.77 81. 48 88 28.817 55.67 66.84 64.99 81. 46 55
Stabilization Data Sample TEST RHD 5 RHD 6 RHD 7 RHD 8 Number TIME RH RH RH RH 31 9. 817 80.28 83.1 78.05 57.56 32 33 10.150 10.483 81.47 81.89 84.53 85.28 81 '3 82 '6 60.93 62.88 34 10 '17 86.56 82.33 83.05 64.83 35 36 11.150 11.483 79.84 87.83 81 '4 80.85 82.63 82.19 68.41 72.70 37 11.817 87.52 77.83 81.61 78.79 38 12 '50 86.81 77.10 81.21 82.49 39 40 12.483 12 '17 87.23 87 '9 76.87 76.08 80.86 80.95 84 '1 86 F 00 41 13 '50 86.74 76.04 80.90 86.47 42 13.483 86.28 74.69 81.00 86.69 43 13.817 85.77 73.63 81.01 87.35 44 14.150 85.98 73.36 81.02 87.84 45 14.483 85.65 73.16 81.05 88.24 46 14. 817 85.51 72.83 81.25 89.00 47 15 ~ 150 85. 71.72 81. 17 89.96 48 15.483 51'5.67 71.48 80.90 89.84 49 15.817 85.71 70.03 80.90 90.36 50 16.150 85.49 69.53 80.88 91.56 51 16.483 85.38 70.43 80.82 91.28 52 53 16 '17 17.150 84.77 84.55 69.85 69.31 80 '2 80.69 91.71 92.23 54 55 17.483 17 '17 84.29 84.19 70 '8 70.00 80.86 80.57 92.46 93 '1 56 18.150 84.18 70 '2 80.42 93.38 57 18.483 84.30 70 '9 80.44 93.54 58 18.817 84.60 70.58 80.66 93.95 59 19 '50 84.47 70.60 80.70 95.04 60 19 '83 84.36 71. 12 80.68 94.61 61 19 '17 84.41 71. 61 80.56 94.79 62 63 20 '50 20.483 84.56 84.36
- 71. 85 70.81 80 '3 80.69 95 '3 95.42 64 20 '17 84.39 71.56 80.71 95 '8 65 21.150 84.50 71.63 80 '8 96 '2 66 21.483 84.60 72.04 80.47 96.30 67 21.817 84.63 71.93 80.49 . 96.57 68 22.150 84.96 71.60 80.57 97.68 69 22.483 85.22 71.68 80.21 97.08 70 22 '17 85.27 71.26 80.09 97.27 71 72 23.150 23.483 85 '4 85.01
- 71. 39
- 71. 12 80.09 80.37 97.44 97.67 73 74 23 '17 24.150 85.15 85.18 70 '8 71.22 80.42 80.41 97.90 98.02 75 76 24.483 24.817 85.16 85.08 71.32 71.36 79 '8 79.51 99.12 99.12 77 78 25.150 25.483 85 '2 84.81 71.11 72.24 79.59 79.64 98.60 99.27 56
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Stabilization Data sample TEST RHD 5 RHD 6 RHD 7 RHD 8 Number TIME RH RH RH 79 80
- 25. 817
- 26. 150 84 '1 84.97 72.35 71 64
~
79.42 79.42 99.. 38 99.25 81 26.483 84.95 72.48 78.96 99.28 82 26 '17 85.05 71.23 78.96 99.74 83 27.150 85.12 72.67 78.92 99.72 84 27.483 85.17 72.54 78. 93. 100.12 85 86 27.817 28.150 85 '5 85.16 72.30 72.20 79.07 79.35 101.01 100.42 87 28.483 85.20 72.84 79.29 100.46 88 28.817 85 '4 72.85 79 '1 100.70 57
Stabilization Data Sample TEST RHD 9 RHD 10 Number TIME RH 4 RH 31 9. 817 60.04 64.60 32 10.150 61.87 65.83 33 34 10.483 10.817 65.53 68.20 63 '6 63.91 35 11.150 69.58 64.54 36 11.483 71.49 66.73 37 11 '17 73; 00 70.76 38 12 '50 75.58 73.93 39 12.483 78.44 76.61 40 12.817 79.66 77.74 41 13.150 80.77 78.78 42 13.483 81.77 79.80 43 13 '17 82.67 80.83 44 14.150 83.42 81.65 45 14.483 84.13 82.41 46 14.817 84.80 83.14 47 15.150 85.39 83.75 48 15.483 85.99 84.35 49 50 15.817 16.150 86 '7 87.04 84.94 85.46 51 52 16.483 16 '17 87.57 88.07 85 '7 86.46 53 17.150 88.57 87.04 54 17.483 88.93 87.37 55 56 17 '17 18.150 89.39 89.84 87 '6 88.32 57 18.483 90.27 88.70 58 18.817 90.63 89.07 59 19.150 90.96 89.55 60 19.483 91.34 89.92 61 19;817 91.73 90.26 62 20.150 92.02 90.46 63 20 '83 92.43 90.95 64 20.817 92.73 91.17 65 21 '50 93.06 91.49 66 21.483 93.34 91. 89 67 21.817 93.72 92.22 68 22.150 94.05 92.38 69 70 22.483 22.817 94 '1 94.69 92.60 92.95 71 23.150 95.01 93.25 72 23.483 95.28 93.73 73 23.817 95.58 93.98 74 24.150 95.94 94.31 75 24.483 96.26 94.67 76 24 '17 96.61 95.02 77 25.150 97.02 95.44 78 25.483 97.34 95.66 58
Stabilization Data Sample TEST RHD 9 RHD 10 Number TIME RH 4 RH 79 25 ~ 817 97.66 95.87 80 26 ~ 150 97.99 96.14 81 26.483 98.33 96.61 82 26.817 98.61 96.80 83 27.150 98.91 97.23 84 85 27.483 27 '17 99 '7 99.44 97.44 97.72 86 87 28.150 28.483 99.67 99.89 98 '7 98.45 88 28.817 100.12 98.57 59
Stabilization Data Sample TEST VAPOR CONT.
Number TIME PRESSURE PRESSURE PSIA PSIA 31 9. 817 0. 7121 58.480 32 10.150 0 '879 58.219 33 10.483 0.6673 58.095 34 10.817 0.6543 58.014 35 11.150 0.6484 57.954 36 11.483 0.6606 57.905 37 11.817 0.6700 57.863 38 12 '50 0.6739 57.827 39 12.483 0.6777 57.794 40 12 '17 0.6767 57.765 41 13 '50 0 '751 57.737 42 13.483 0.6723 57 '12 43 13 '17 0.6700 57.689 44 14 '50 0.6689 57.667 45 14 '83 0.6669 57 '46 46 14 '17 0.6651 57.626 47 15.150 0.6632 57.607 48 15.483 0.6607 57.589 49 15.817 0.6581 57.571 50 16.150 0.6568 57.554 51 16.483 0.6550 57.538 52 16.817 0.6525 57.522 53 17 '50 0.6507 57.507 54 17.483 0.6493 57.493 55 17.817 0.6475 57 '78 56 18.150 0.6466 57.465 57 18.483 0.6452 57.452 58 18 '17 0.6442 57.439 59 19.150 0 '435 57.426 60 19.483 0.6418 57.414 61 19 '17 0.6407 57.402 62 20 '50 0.6404 57.391 63 20.483 0.6378 57.380 64 20 '17 0.6375 57.369 65 21 0.6365 57.358
'83
'50'1 66 0.6360 57.348 67 21 '17 0.6353 57.338 68 22.150 0.6352 57.328 69 22.483 0.6332 57.318 70 22.817 0.6323 57.309 71 23.150 0.6314 57.300 72 23.483 0.6306 57.291 73 23.817 0 '296 57.282 74 24.150 0.6294 57.273 75 24.483 0.6295 57'.265 76 24.817 0.6286 57.256 77 25.150 0.6274 57.248 60
Stabilization Data Sample TEST VAPOR CONT.
Number TIME PRESSURE PRESSURE PSIA PSIA 78 25.483 0.6280 57.240 79 25.817 0.6274 57.232 80 26.150 0.6260 57.224 81 26.483 0.6259 57.217 82 26 '17 0.6248 57.209 83 27.150 0.6254 57.202 84 27.483 0.6251 57.195 85 27.817 0.6252 57.187 86 28.150 0.6241 57.180 87 28.483 0.6238 57.174 88 28 '17 0.6235 57.167 61
Stabilization Data Sample TEST CONT. DELTA T/HR DELTA T/HR 1HR to 2HR Number TIME AVERAGE LAST 2 HRS LAST 1 HR DELTA T/HR TEMP CHANGE 31 9. 817 102.892 32 10. 150 100.892 33 10.483 99.603 34 10 '17 98 '10 -4.082 35 11.150 98.253 -2.639 36 11.483 97.813 -1.790 37 11 '17 97.451 -2.721 -1.359 38 12.150 97.139 -1.877 -1.114 0. 763 39 12 483 96.847 -1.378 -0.966 0. 412 40 12.817 96.590 -1.110 '-0.861 0.249 41 13.150 96 '62 -0 '46 -0.777 0.169 42 13.483 96.147 -0.833 -0.700 0.133 43 13.817 95.940 -0.756 -0.650 0.106 44 14.150 95 '39 -0.700 -0 '23 0.077 45 14.483 95.549 -0.649 -0.598 0 '51 46 14. 817 95.367 -0.612 -0.573 0.039 47 15.150 95 '85 -0.589 -0.554 0.035 48 15.483 95.014 -0.567 -0 '35 0.032 49 15.817 94.855 -0.543 -0.512 0.031 50 16.150 94.700 -0.520 -0 '85 0.035 51 16.483 94.550 -0 '00 -0.464 0.036 52 16.817 94.402 -0.483 -0.453 0.030 53 17.150 94.265 -0.460 -0.435 0.025 54 17.483 94 '20 -0.447 -0.430 0.017 55 17.817 93.983 -0.436 -0 '19 0.017 56 18.150 93.854 -0.423 -0.411 0.012 57 18.483 93.726 -0 '12 -0.394 0.018 58 18.817 93.604 -0 '99 -0.379 0.020 59 19.150 93.483 -0.391 -0.371 0.020 60 19.483 93 '69 -0.376 '0.357 0.019 61 19.817 93.255 -0.364 -0.349 0.015 62 20.150 93 '48 -0.353 -0.335 0.018 63 20.483 93 '41 -0.343 -0.328 0.015 64 20 ~ 817 92.942 -0 '31 -0 '13. 0.018 65 21 150
~ 92.838 -0.323 -0 '10 0.013 66 21.483 92.737 -0.316 -0.304 0.012 67 21.817 92.652 -0 '02 -0 '90 0.012 68 22.150 92.551 -0.299 -0.287 0.012 69 22.483 92.461 -0.290 -0 '76 0.014 70 22.817 92.377 -0.283 -0.275 0.008 71 23.150 92.289 -0.275 -0.262 0.013 72 23.483 92.204 -0.267 -0 '57 0.010 73 23.817 92.119 -0.,267 -0 '58 0.009 74 24.150 92 '46 -0 '53 -0.243 0.010 75 24.483 91 '63 -0.249 -0.241 0.008 76 24.817 91.892 -0.243 -0.227 0.016 77 25.150 91.820 -0.235 -0 '26 0.009 62
Stabilization Data Sample TEST CONT. DELTA T/HR DELTA T/HR 1HR to 2HR Number TIME AVERAGE LAST 2 HRS LAST 1 HR DELTA T/HR TEMP CHANGE 78 25.483 91.743 -0 '31 -0.220 0.011
- 79 25.817 91.672 -0.224 -0.220 0.004
- 80 26.150 91.597 -0.225 -0.223 0.002
- 81 26.483 91.531 -0 '16 -0.212 0.004
- 82 26 '17 91.465 -0.214 -0.207 0.007
- 83 27.150 91.399 -0.211 -0.198 0.013 84 27.483 91.338 -0.203 -0.193 0.010
- 85 27.817 91.269 -0.202 -0.196 0.006
- 86 28.150 91. 195 -0.201 -0.204 0.003
- 87 28.483 91. 130 -0.201 -0 '08 0.008
- 88 28.817 91. 066 -0.200 -0.203 0.004
- NOTES
- 1) THE 1 HOUR AND 2 HOUR DELTA TEMPERATURE VALUES ARE NOT VALID UNTIL 1 HOUR AND 2 HOURS'ESPECTIVELY'AVE PASSED IN THE TEST 2), THE STABILIZATION CRITERIA IS MET WHEN:
-THE HOURLY AVERAGE DELTA T FOR THE PRECEDING HOUR DIFFERS FROM THE HOURLY AVERAGE DELTA T FOR THE PRECEDING 2 HOURS BY LESS THAN 0.5 DEGREES F. OR
-THE HOURLY AVERAGE DELTA T FOR THE PRECEDING 2 HOURS IS LESS THAN 1.0 DEGREES F.
-THE STABILIZATION PERIOD IS A MINIMUM OF 4 HOURS
- 3) THE "*" INDICATES THAT THE STABILIZATION CRITERIA HAS BEEN MET.
63
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M &M M M M M M M M M Stabilization Period St.Lucie Unit 2 June 1992 Ibs psia 693,100 0,7 693,000 P
Temperature Stabilization ILRT Start 0.68 692,900 ~ ~
Criteria met 692,800 I
0.66 Z) 692,700 Ch Q 692,600 0.64 692,500 692,400 0.62 10 15 20 25 30 Test Time Air Mass Weighted vapor pressure Note inverse trends of airmass vs vapor pressure
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Stabi ization Period St. Lucie Unit 2 June 1992 Deg E PS I CI 104 0.72 102 0.7 Temperature Stabilization 100 Criteria met 0.68 98 0.66 96 ILRT Start cn C 9.64 94 0
~ A 4
92 0.62 90 0.6 10 15 20 25 30 Test Time Avg. T~era erature Avg. Vapor Pressure wamaQe~
Stabilization extended after temperature criteria met due to vapor pressure affects
Comparison of Different Vapor Pressure Trends Historical vs Latest ILRTs at St. Lucie Vapor Pressure (psia) 0.5 0.8 OA5 0.75
~~
~~
~
0.7
~~
OA ~
~~
~~
~~
~~
~ t~~
1 ~~
~~~~1
~ ~yy ~ 1 ~ ~
~ F 4 ~ ~ OlttO ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ Oyy ~ ~ ~ ~ '
~1~~0~~~
ill yy
~ ~~ ~ ~~~~1~~~0~
~g Z) ~y
~y
~0 goto
~ g4
~~~ ~0
~
~0~
(D 0.35
~ g~ ~ ~ ++
~+~ ~+~+
0.65 0.3 ~ %%%a~~~~~~W&W~W&WAWW&&&%%%%&%%&&&%a~~~&%%%%%%&&AM&%&&%%%w&%&ma&AM&&~%&ww&%&
0.6 0.25 0.55 89 8c 90 Stabilization Sample number 92 PSL 2 1989 PSL 1 1990 PSL 2 1992 PSL 2 1992 Yopor PressUre Scole Offset
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% RH by Elevation During Stabilization Period St. Lucie Unit 2 June 1992 e
- Saturation reached at upper elevation as temperature stabilized 100 90 80 0
-ri 70 0 60 0)
~ 50 40 10 15 20 25 30 Test Time RH 40 f't. % RH 84 ft. % RH 17 ft..
---o--- 1 Note minimal of mixing of water vapor by elevation
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Temp by Elevation During Stabilization Period St. Lucie Unit 2 June 1992 DEG F 115 110
'l05 L~
100
~~
~~
WAN
~ ooo ~
O~ ~
oooo Z) 95 ~~~~~
os ~ ~ ~ ooooo
~~o ~ ~~O~O o
~ ~ ooo ~ oo oo ~ ~ ~ ooo
~O~ ooooo ~~ ~~~~~ ~
~~o~o~o~~~o~
~o~~o~o ~~~~~
~o~o~~~O o~o~~o~o~o~~o~~
~~~~~~~~~~
cD 90 85 10 15 20 30 Test Time DEG F 40 ft. DEG F 84 ft. DEG F 130 ft.
DEG F 171 ft. DEG F 194 FT.
Note convergence of all groups above 62 ft.
operating deck
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ILRT DATA 69
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ILRT Dat:a Sample TEST RTD 1 RTD 2 RTD 3 RTD 4 Number TIME DEG F DEG F DEG F DEG F 89 29. 150 86.770 87.370 86.592 86.045 90 29.483 86.752 87 '52 86.585 86.038 91 29.817 86.743 87.343 86.585 86.027 92 30 '50 86.752 87.343 86.574 86.018 93 30.483 86.752 87.343 86.574 86.027 94 30. 817 86.732 87.321 86.585 86 '18 95 31 150
~ 86.743 87.321 86.574 86.018 96 31.483 86.743 87 '10 86.562 86.018 97 31. 817 86.743 87.310 86.574 86.018 98 32.150 86.710 87.299 86 '74 86.007 99 32.483 86.732 87.290 86.562 86.007 100 32 '17 86.721 87.290 86.562 86.007 101 33.150 86.732 87.278 86.562 85.996 102 33.483 86.721 87.278 86.574 85.996 103 33 '17 86.721 87.278 86 '62 85.996 104 34 '50 86.721 87.267 86.562 85.996 105 34.483 86.728 87.263 86.558 86.003 106 34 '17 86.728 87.263 86.558 86.003 107 35.150 86.705 87.252 86.558 86 '03 108 35.483 86.710 87.247 86.542 85.985 109 35.817 86.716 87.243 86.558 85 '91 110 36.150 86.698 87.225 86.551 85.985 111 36.483 86.698 87.225 86.542 85.985 112 36 '17 86.698 87.214 86.551 85.973 113 37.150 86.689 87.214 86 '42 85.985 114 37.483 86 '05 87.209 86.549 85.991 115 37 817
~ 86 '98 87.202 86.542 85.985 70
ILRT Data Sample TEST RTD 5 RTD 6 RTD 7 RTD 8 Number TIME DEG F DEG F DEG F DEG F 89 29.150 85.931 86.484 86.638 86.024 90 29.483 85.924 86.479 86.622 86.007 91 29.817 85.913 86.479 86.622 86.007 92 30.150 85.913 86.468 86.622 86.007 93 30.483 85.913 86 '57 86.611 85.995 94 30.817 85.902 86.457 86.600 85.986 95 31.150 85.902 86.457 86.600 85.995 96 31.483 85.913 86.457 86.600 85.995 97 31.817 85.902 86.446 86.589 85.986 98 32.150 85.893 86.446 86.589 85.995 99 32.483 85.893 86.434 86.589 85.975 100 32.817 85.893 86.434 86.578 85.975 101 33.150 85.882 86.425 86.578 85.964 102 33.483 85.882 86.425 86.578 85.975 103 33.817 85.882 86.425 86.569 85.975 104 34.150 85.882 86.414 86.569 85.964 105 34.483 85.899 86.421 86 '75 85.971 106 34.817 85.888 86.421 86.575 85.959 107 35.150 85.888 86.421 86.564 85.959 108 35.483 85.882 86.403 86.557 85.953 109 35.817 85.888 86.410 86.564 85.959 110 36.150 85.882 86.403 86.546 85.953 111 36.483 85.882 86.403 86.546 85.953 112 36.817 85.882 86.392 86.546 85.953 113 37.150 85.882 86.392 86.546 85.944 114 37.483 85.877 86.398 86.542 85.948 115 37.817 85.870 86.392 86.526 85.944 71
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ILRT Data Sample TEST RTD 9 RTD 10 RTD 11 RTD 12 Number TIME DEG F DEG F DEG F DEG F 89 29. 150 93.268 92.511 93.104 92.774 90 29.483 93.187 92.419 93.013 92.660 91 29 '17 93.111 92.345 92.937 92.586 92 30.150 93.026 92.268 92.863 92.500 93 30.483 92.949 92.194 92.787 92.424 94 30.817 '2.876 92.118 92.713 92.359 95 31. 150 92.799 92.055 92.637 92.285 96 31.483 92.737 91.979 92.563 92.200 97 31 817
~ 92.629 91.905 92.498 92.135 98 32.150 92.564 91.84b 92.433 92.081 99 32.483 92 '10 91.763 92 '71 91.995 100 32.817 92.437 91.709 92.295 91.930 101 33.150 92.372 91.658 92.221 91.856 102 33.483 92.318 91 '93 92.156 91.803 103 33.817 92.253 91.539 92.102 91.726 104 34.150 92.179 91.474 92.037 91.652 105 34.483 92 '32 91.415 91.993 91.605 106 34.817 92.067 91.352 91 917
~ 91.540 107 35.150 92 '13 91.299 91.863 91.486 108 35.483 91.953 91.238 91 '03 91.394 109 35.817 91.897 91.202 91.745 91.367 36.150 91.836. '53 91.686 91.298 ill 110 112 36.483 36.817 91.771 91.729 91 91.110 91.130 91.633 91.579 91.244 91 '79 113 37.150 91.664 91.065 91.525 91.136 114 37.483 91.628 90.998 91.490 91.089 115 37.817 91 '79 90.895 91.429 91.028 72
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ILRT Data Sample TEST RTD 13 RTD 14 RTD 15 RTD 16 Number TIME DEG F DEG F DEG F DEG F 89 29.150 93.102 92.370 93.087 93.069 90 29.483 93.042 92.257 92.983 92.978 91 29.817 92.965 92.192 92.898 92.892 92 30.150 92.858 92.096 92.833 92.816 93 30.483 92.827 92 '19 92.748 92.753 94 30 '17 92.750 91.934 92.672 92.677, 95 31.150 92.676 91.806 92.598 92.561 96 31.483 92.600 91.752 92.533 92.334 97 31.817 92.526 91.687 92.459 92.238 98 32.150 92.119 91.622 92.383 92.195 99 32.483 92 '15 91.548 92.309 92.099 100 32 '17 92.204 91.494 92.244 92.034 101 33.150 92.152 91.408 92.179 91.949 102 33.483 92.087 91.343 92.125 91.895 103 33 '17 92.011 91.267 92.062 91 '30 104 34.150 91 '80 91.235 92.009 91.767 105 34.483 91.998 91 '77 91.928 91.729 106 34 '17 91 '79 91.080 91 '65 91.720 107 35.150 91 '48 91 '18 91.823 91.655 108 35.483 91.798 90.934 91.751 91.594 109 35 '17 91 '40 90.876 91.704 9'1. 547 110 36 '50 91.659 90.827 91.632 91.498 111 36.483 91.637 90.784 91.578 91.433 112 36.817 91.606 90.710 91.525 91.370 113 37.150 91.518 90.645 91.482 91.325 114 37.483 91.494 90.575 91.426 91.278 73
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ILRT Data Sample TEST RTD 17 RTD 18 RTD 19 RTD 20 Number TIME DEG F DEG F DEG F DEG F 89 29.150 92.405 92.992 91. 785 Deleted 90 29.483 92.313 92.889 91. 724 Deleted 91 29 '17 92.227 92.815 91. 670 Deleted 92 30 '50 92.162 92.739 91.616 Deleted 93 30.483 92.088 92.665 91.574 Deleted 94 30 '17 91.992 92.580 91.540 Deleted 95 31.150 91.938 92.504 91.498 Deleted 96 31 '83 91.852 92.450 91.455 Deleted 97 31 '17 91 '07 92 '65 91. 413 Deleted 98 32.150 91.744 92.300 91.370 Deleted 99 32.483 91.691 92.257 91.327 Deleted 100 32.817 91 '14 92.194 91.262 Deleted 101 33 '50 91.540 92.107 91.231 Deleted 102 33.483 91.432 92.044 91. 197 Deleted 103 33 '17 91.401 92 F 000 91. 166 Deleted 104 34.150 3'4. 483 91.324 91.946 91 '35 Deleted 105 91.288 91.890 91.108 Deleted 106 '34 ~ 817 91.223 91. 814 91'034 Deleted 107 35 ~ 150 91.160 91.751 90.980 Deleted 108 35.483 91.077 91.690 90.951 Deleted 109 35.817 91 '30 91.643 90 Deleted 110 36 '50 90.981 91.560 '15'0.877 Deleted 111 36.483 90.884 91.507 90.843 Deleted 112 36 '17 90.830 91.444 90 '12 Deleted 113 37.150 90.819 91.390 90.781 Deleted 114 37.483 90.763 91.343 90.787 Deleted 115 37.817 90 '91 91.303 90.727 Deleted
ILRT Data, Sample TEST RTD 21 RTD 22 RTD 23 RTD 24 Number TIME DEG F DEG F DEG F DEG F 89 29.150 90.576 91.065 91.591 91.458 90 29.483 90.522 91.011 91.559 91.4'05 91 29 '17 90.457 90.968 91 '17 91.373 92 30.150 90.394 90.926 91.483 91.308 93 30.483 90.329 90.883 91.452 91.277 94 30.817 90.287 90.841 91 '98 91.212 95 31.150 90.222 90.798 91.356 91.149 96 31.483 90.159 90.765 91.324 91.115 97 31 '17 90.105 90.722 91.302 91.061 98 32.150 90.029 91.011 91.226 90.998 99 32.483 89.962 91.083 91. 127 90.972 100 32.817 89.890 91.076 91.055 90.922 101 33.150 89.793 91.107 90.959 90.859 102 33.483 89.708 91.096 90.894 90.848 103 33 '17 89.515 90.980 90.874 90.826 104 34.150 89.435 90.953 90 '70 90.790 105 34.483 89.385 90.926 90.841 90.718 106 34.817 89.257 90.872 90.789 90.687 107 35.150 89.204 90.798 90.744 90.622 108 35.483 89.215 90.765 90 '13 90.579 109 35.817 89.183 90.776 90 '70 90.516 110 36.150 89.150 90.722 90.639 90.516 111 36.483 89 '76 90.648 90.585 90.505 112 113 36.817 37 '50 89.033 89.011 90.606 90.561 90.552 90.520 90 '4 90.301 114 37.483 88.979 90.510 90.498 90.278 115 37 '17 88 '14 90 '76 90 '78 90.247 75
l ILRT Data Sample TEST RTD 25 RTD 26 RTD 27 RTD 28 Number TIME DEG F DEG F DEG F DEG F 89 29.150 92.864 91.205 90.782 90.918 90 29.483 92.788 91 '63 90 '19 90.875 91 29.817 92.692 91.109 90.676 90.822 92 30.150 92.618 91.066 90 '12 90.779 93 30.483 92.542 91 '35 90.538 90.746 94 30. 817 92.468 90.992 90.493 90.714 95 31 150
~ 92.392 90.947 90.430 90.672 96 31.483 92 '18 90.904 90.334 90.618 97 31 817
~ 92.242 90.873 90 '91 90.533 98 32.150 92.179 90.830 90.108 90.511 99 32.483 92.098 90.803 90.061 90.486 100 32 '17 92.040 90.765 89.553 90.392 101 33.150 91.975 90.722 89.349 90.372 102 33.483 91.899 90.700 89.188 90.349 103 33.817 91.836 90.657 89.081 90 '87 104 34 '50 91.778 90.633 89.013 90 '60 105 34.483 91 '18 90.594 88.899 90 '99 106 34.817 91.655 90.561 88 '14 90 '90 107 35 '50 91.601 90 '41 88.642 90 '37 108 35.483 91 536 90.507 88.579 90 '94 109 35.817 .91.471 90.475 88 '72 90.072 110 36 '50 91 '18 90 '44 88.407 90.061 111 36.483 91.355 90.422 88.364 90.029 112 36.817 91.301 90.390 88.299 89.987 113 37.150 91.259 90.359 88.248 89.975 114 37.483 91 '94 90 '14 88 '18 89.922 115 37 '17 91 '51 90.305 88.056 89.890 76
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ILRT Data Sample TEST RTD 29 RTD 30 RTD 31 RTD 32 Number TIME DEG F DEG F DEG F DEG F 89 29 ~ 150 92.873 92.725 91 '73 93.082 90 29.483 92.788 92.651 91.489 93 '19 91 29.817 92.702 92.553 91.381 92.922 92 30 '50 92.649 92.467 91.328 92.846 93 30.483 92.541 92.393 91.220 92.750 94 30.817 92.456 92 '17 91.135 92.664 95 31.150 92.359 92.243 91.039 92.590 96 31 '83 92.294 92.189 90 '12 92.503 97 31.817 92.220 92.104 90.889 92.406 98 32.150 92.124 92.039 90.804 92.290 99 32.483 92.066 91.972 90.735 92.296 100 32.817 91.985 91.889 90.590 92.225 101 33.150 91 920 91.835 90.548 92 '71 102 33.483 91.846 91.761 90.516 92.097 103 33.817 91.781 91.696 90.451 92.021 104 34.150 91.723 91.637 90.331 91.953 105 34.483 91.631 91.557 90.259 91.882 106 34.817 91.566 91.503 90 '85 91. 817 107 35.150 91.503 91.449 90 '21 91. 754 108 35.483 91.416 91.375 90.036 91. 700 109 35.817 91.353 91.332 89.993 9'1 ~ 64 6 110 36.150 91.277 91.267 89 '17 91.570 111 36.483 91 '23 91.213 89.864 91.527 112 36.817'7.150 91.169 91 '48 89.801 91.473 113 91.095 91.106 89.725 91.431 114 37.483 91.030 91.052 89 '62 91.368 115 37.817 90.988 90.998 89.555 91.323 77
ILRT Data Sample TEST RTD 33 RTD 34 RTD 35 RTD 36 Number TIME DEG F DEG F DEG F DEG F 89 29.150 92.958 93.096 91. 955 92.762 90 29.483 92.873 92.999 91.859 92.688 91 29 '17 92.797 92.925 91.794 92.603 92 30 '50 92 '12 92.840 91.709 92.526 93 30.483 92.615 92.764 91.601 92.452 94 30.817 92.519 92 '78 91.525 92 '65 95 31.150 92.465 92 '13 91.235 92.302 96 31.483 92.411 92.528 91 '73 92.217 97 31.817 92.400 92.463 91 '08 92.141 98 32.150 92.292 92.389 91.043 92.087 99 32.483 92.203 92.330 90.995 92.020 100 32.817 92 '33 92.258 90.892 91.937 101 33 '50 92 '91 92.195 90.829 91.874 102 33.483 92.015 92 '41 90.776 91.809 103 33.817 91. 941 92.065 90.722 91.744 104 34.150 91.947 92.009 90.643 91.676 105 34.483 91.737 91 '48 90 '03 91.616 106 34.817 91.737 91.894 90.540 91.551 107 35 '50 91.714 91.829 90.464 91.486 108 35.483 91.768 91.766 90 '10 91.434 109 35.817 91.683 91.712 90.356 91.380 110 36 '50 91.575 91.659 90.294 91.304 111 36.483 91.521 91.593 90.271 91.273 112 36.817 91.459 91.540 90 '17 91.208 113 37.150 91 '83 91.497 90.163 91.154 114 37.483 91. 318 91.443 90.089 91 '00 78
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ILRT Data Sample TEST RTD 37 RTD 38 RTD 39 RTD 40 Number TIME DEG F DEG F DEG F DEG F 89 29.150 92.901 Deleted 91. 361 92 '32 90 29.483 92 '13 Deleted 91.265 92.54 91 29.817 92 '17 Deleted 91 ~ 189 92.464 92 30.150 92.632 Deleted 91 ~ 104 92.368 93 30.483 92.567 Deleted 91. 039 92.305 94 30.817 92.493 Deleted 90 '53 92.229 95 31 '50 92.428 Deleted 90.879 92.164 96 31.483 92.343 Deleted 90 '14 92.079 97 31 '17 92.278 Deleted 90.738 92 '14 98 32.150 92.204 Deleted 90.653 91.951 99 32.483 '92.168 Deleted 90.595 91.863 100 32.817 92.085 Deleted 90.525 91.801 101 33.150 92.022 Deleted 90.460 91.724 102 33.483 91.957 Deleted 90.396 91.662 103 33.817 91.892 Deleted 90.322 91 '17 104 34.150 91.836 Deleted 90.274 91.565 105 3'4. 483 91.776 Deleted 90.203 91. 518 106 34. 817 91.722 Deleted 90 '40 91. 442 107 35.150 91.668 Deleted 90 '86 91.377 108 35.483 91.614 Deleted 90 '21 91 '08 109 35 '17 91.561 Deleted 89.979 91.261 110 36.150 91.507 Deleted 89.894 91.200 111 36.483 91.453 Deleted 89.840 91.135 112 36.817 91.399 Deleted 89 '18 91.081 113 37.150 91.357 Deleted '89.744 91.027 114 37.483 91.314 Deleted 89.690 90.992 115 37 '17 91.240 Deleted 89.658 90.900 79.
ILRT Data Sample TEST RHD 1 RHD 2 RHD 3 RHD 4 Number TIME RH RH RH 89 90 29.150 29.483 55 '1 56.11
- 67. 03
- 67. 18 65.25 65.45
- 81. 60 81.38 91 29 '17 56.29 67. 34 65.67 81.58 92 30.150 56 '6 67.51 65.90 81.62 93 94 30.483 30.817 56.61 56.81 67.65 67.82 66.11 66.31 81 '1 81.38 95 31.150 56.97 67.97 66.53 81.48 96 31.483 57.21 68.11 66.73 81.27 97 31 '17 57.42 68.27 66.91 81. 24 98 32.150 57;73 68.42 67.11 81 42
~
99 32.483 57.90 68.56 67.31 81 24 100 101 32.817 33.150 58.18 58.44 68 '1 68.86 67.52 67.73
~
81 11
~
- 81. 36 102 33.483 58.63 69.03 67.93 81. 26 103 33 '17 58.92 69.16 68.12 81. 15 104 105 34.150 34.483 59.14 59.32 69 '9 69.43 68 '7 68.58
- 81. 28
- 81. 10 106 34 '17 59.56 69 '7 68 '4 81 12 107 108 35.150 35.483 59 '1 59.99 69 '1 69.83 68.95 69.17
~
- 81. 09
- 81. 00 109 35.817 60.23 69.97 69.36 '81. 04 110 36.150 60.46 70.10 69.53 81 02
~
111 36.483 60.62 70.21 69.67 81. 06 112 36 '17 60.85 70.35 69.90 81 07
~
113 37.150 61.06 70.48 70.06 80.68 114 37.483 61.27 70.60 70.24 80.92 115 37.817 61.48 70.73 70.35 80 '8 80
ILRT Data Sample TEST RHD 5 RHD 6 RHD 7 RHD 8 Number TIME RH RH RH RH 89 29.150 85. 13 72.85 79.85 100.85 90 29.483 85.08 72.82 79.89 101.47 91 29.817 85.05 73.34 79.79 101.50 92 30 '50 85.04 73.54 79.89 101.68 93 30.483 84.99 73.57 79.78 101.08 94 95
- 30. 817
- 31. 150 84.95 84.99 74.75 74.52 79.58 79.61 102 '9 102.25 96 31 '83 84.92 75.20 79.35 101.35 97 31. 817 84.93 76.14 81.98 102.36 98 32.150 84.92 77.06 79.88 102.16 99 32.483 84.80 77.07 79.67 102.19 100 32 '17 84.75 76.80 79.43 101.93 101 33.150 84.77 77.37 79.59 102.77 102 103 33.483 33 '17 84.77 84.62 76.71 77.93 81 '8 80.29 102.02 101.88 104 105 34.150 34.483 84.61 84.58 78 '0 78.65 79.80 79.56 102.00 102.76 106 34 '17 84.47 '8.98 79.50 103.18 107 35.150 84.50 79.21 79.44 102.44 108 35.483 84. 79.40 79.49 102.72 109 35.817 37'4.33 78.97 79.30 102.20 110 36.150 84.25 79.72 79.36 102.22 111 36.483 84.17 79.45 79.18 102.35 112 36 '17 84.11 79.85 79.22 102,15 113 114 37.150 37.483 84.00 84.03 79.82 79.90 79.29 79.17 102 '1 102.39 115 37.817 83.75 79.80 79.06 102.80 81
I ILRT Data Sample TEST RHD 9 RHD 10 CONT. VAPOR Number TIME RH RH PRESSURE PRESSURE 89 29. 150 100.33 98.86 57.160 0.6233 90 29.483 100.51 98.96 57.154 0.6228 91 29.817 100.76 99.11 57.147 0.6226 92 30 '50 100.91 99.42 57 '41 0.6224 93 30.483 101.03 . 99.09 57.135 0.6203 94 30.817 101.17 99.63 57.128 0 '217 95 31 '50 101.32 99.63 57.122 0.6206 96 31.483 101.41 99.94 57.116 0 '191 97 31.817 101.53 100.04 57.110 0 '219 98 99 32.150 32.483 101.66 101.79 100 99
'4
'3 57.105 57.099 0 '201 0.6186 100 32.817 101.82 99.68 57.094 0.6171 101 33 '50 102.02 100.42 57.088 0.6189 102 33.483 102.07 100.56 57.083 0.6180 103 33 '17 102.11 100.78 57.077 0.6174 104 34.150 102.22 100.65 57.072 0.6168 105 34.483 102.24 100.98 57.067 0.6171 106 107 34 '17 35.150 102.31 102.41 100 '1 100.99 57.062 57.057 0.6169 0.6157 108 35.483 102.44 101.00 57.052 0.6153 109 35.817 102.50 101.10 57.047 0'. 6140 110 36.150 102.55 100.87 57.042 0.6134 111 36.483 102.57 101.17 57.038 0.6129 112 36.817 102.58 101.35 57.033 0.6125 113 37.150 102.62 101.41 57.029 0 '119 114 37.483 102.71 101.43 57.024 0.6116 115 37.817 102.66 101.24 57.020 0.6105 82
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ILRT Data Sample TEST AVERAGE AIR LEAK SIM LEAK FIT UCL Number TIME TEMP MASS 4/DAY 4/DAY 4/DAY 89 29 '50 91. 010 692744 90 29.483 90.945 692757 -0 134
~
91 29.817 90.888 692747 -0.015 92 30.150 90.830 692747 -0.011 0.009 0 ~ 467 93 30.483 90.777 692767 -0.059 -0.020 0.282 94 30.817 90.720 692735 0.019 0.013 0.204 95 31.150 90.662 692750 -0.009 0.014 0.168 96 31.483 90.604 692766 -0.033 0.002 0. 145 ~
97 31.817 90.554 692722 0.028 0.020 0 ~ 144 98 32.150 90.497 692754 -0 '12 0.017 0 ~ 132 99 32.483 90.456 692750 -0.006 0.016 0. 123 100 32.817 90.392 692789 -0.042 0.003 0. 112 101 33.150 90 '39 692760 -0.014 0.002 0. 104 102 33.483 90.291 692769 -0.020 0.000 0.096 103 33 '17 90.239 692768 -0.018 -0.002 0.090 104 34 150 90.197 692767 -0.016 -0.003 0.085 105 34.483 90.153 692758 -0.009 -0.002 0.081 106 34 '17 90.103 692763 -0.011 -0.002 0.078 107 35.150 90.055 692775 -0.018 -0.003 0 '74 108 35.483 90.011 692775 -0.017 -0.004 0 '70 109 35 '17 89.974 692776 -0 '17 -0.005 0.067 110 36.150 89.927 692781 -0.018 -0.'006 0.064 111 36.483 89.887 692789 -0.021 -0.008 0.061 112 36.817 89.848 692780 -0.016 -0.008 0.059 113 37.150 89.807 692791 -0.020 -0.009 0.056 114 37.483 89.768 692783 -0.016 -0.009 0.054 115 37 '17 89.724 692802 -0 '23 -0 '10 0.052 83
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CONTAINMENT INTEGRATED LEAKAGE RATE TEST LEAKAGE RATE IS MEASURED USING THE ABSOLUTE METHOD AND IS COMPUTED USING THE TOTAL TIME METHOD IN STRICT ACCORDANCE.
WITH TOPICAL REPORT BN-TOP-1 ( REV 1 )
TEST PERIOD STARTED AT 15:20 HOURS ON 6/16/92 TEST CONDUCTED FOR 8.67 HOURS FREE SPACE VOLUME OF CONTAINMENT IS 2500000 CU FT CONTAINMENT WAS PRESSURIZED TO 57.16 PSIA FITTED TOTAL TIME ILRT LEAKAGE RATE Lam -0.010 % /DAY UPPER LIMIT OF 95% CONFIDENCE LEVEL UCL 0.052 % /DAY CONTAINMENT DESIGN LEAKAGE RATE La 0.500 % /DAY ILRT ACCEPTANCE CRITERIA 75% La 0.375 % /DAY BN-TOP REDUCED DURATION ILRT TERMINATION CRITERIA
-THE TREND OF THE TOTAL TIME CALCULATED LEAKAGE RATE SHALL INDICATE THAT THE MAGNITUDE OF THE LEAKAGE RATE IS TENDING TO STABILIZE AT A VALUE LESS THAN OR EQUAL TO 75% OF La.
La = 0.500 % /DAY 75% La = 0.375 % /DAY Lam = -0.010 % /DAY with a Negative Skew
-AT THE END OF THE ILRT THE UPPER LIMIT OF THE LEVEL SHALL BE LESS THAN OR EQUAL TO 75% OF La.
95%'ONFIDENCE UCL = 0.052 % /DAY
-THE MEAN OF THE MEASURED LEAKAGE RATES OVER THE LAST 5 HOURS OR 20 DATA SETS, WHICHEVER PROVIDES THE MOST POINTS, SHALL BE LESS THAN OR EQUAL TO 75% OF La.
MEAN OF SIMPLE LEAKAGE FOR SAMPLES = -0.016 % /DAY 84
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DESCRIPTION OF VARIABLES AVE TEMP - CONTAINMENT MEAN TEMPERATURE CALCULATED FROM VOLUMETRICALLY WEIGHTED RTD SENSOR INDICATIONS; PRESSURE PRIMARY CONTAINMENT PRESSURE INDICATION.
VAPOR PRES CONTAINMENT VAPOR PRESSURE CALCULATED FROM VOLUMETRICALLY WEIGHTED HUMIDITY/DEWPOINT SENSOR INDICATIONS.
LEAK SIM SIMPLE TOTAL TIME MEASURED LEAKAGE RATE.
LEAK FIT LEAKAGE RATE CALCULATED FROM FIRST ORDER REGRESSION OF SIMPLE TOTAL TIME LEAKAGE RATE DATA.
954 UCL UPPER LIMIT OF THE 954 CONFIDENCE LEVEL OF FITTED LEAKAGE RATE DATA.
AIR MASS CONTAINMENT AIR MASS.
NOTES FOR TABULAR DATA
- 1. TABLE VALUES OF ZERO SIGNIFY THE DATA IS NOT APPLICABLE TO THE CALCULATION.
- 2. "DELETED" SIGNIFIES THE SENSOR WAS DELETED.
SENSOR VOLUME FRACTIONS TEMPERATURE SENSORS 1 to 5 0. 026708 0.026708 0.026708 0.026708 0 '26708 6 to 10 0.026708 0.026708 0.026708 0.026785 0.026785 11 to 15 0.026785 0 '26785 0.026785 0.026785 0.026785 16 to 20 0.026785 0.026785 0 '26785 0 '26708 0.000000 21 to 25 0 '26708 0 '26708 0.026708 0.026708 0.026708 26 to 30 0.026708 0.026708 0.026708, 0 '20144 0.020144 31 to 35 0.020144 "
0 '20144 0.020144 0 '20144 0.020144 36 to 40 0.020144 0.020144 0 F 000000 0.048409 0.048409 HUMIDITY/DP SENSORS 1 to 5 0.073335 0.073335 0.073335 0.090064 0.090064 6 to 10 0.090064 0.090064 0.139913 0.139913 0.139913 NOTE: VALUE OF ZERO INDICATES A DELETED SENSOR.
85
ILRT Containment Absolute Pressure
)SlG 57.2
- 57. 1 cO rm < 5/
I 56.9 56.8 30 34 Test Time Containment Pressure
IL RT Weighted Average Temperature St. Lucie Unit 2 June 1992 Deg F 92
~ 90 Zt 88 86 30 Test Time Average Containment TemperatUre El
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ILRT ~A~eighted Average Vapor Pressure St. Lucie Unit 2 June 1992 ps IG 0.7 0.68 0.66 0.64 u3 c 0.62 (D
0.6 0.58 0.56 30 34 Test Time Vapor Pressure
iLRT Ca culated Air Mass St. Lucie Unit 2 June 1992 Lbs 693,400 693,200 693,000 692,800 a3 c 692 600 692,400 692,200 692,000 30 34 Test Time Containment Air Moss
ILRT Bn Top Rates Relative To limits St. Lucie Unit 2 June 1992.
wt. 7 /day 0.6 0.5 0.4 0.3 0
0.2 ~ 10
~0
~0
~0
~~0 ~ ~~0 F 000F 000 ' 00 ' '
0 0~~~~
0.1 POOO 05$ '000 ~~ ~ 00
~~~0 ~~0
~0~~~0~~~~
~~0~~~~~~0
~~0~0~~~~~0
~0~~ 0 ~~ 00 ~ 0
~ 0 ~ 0 ~ ~ ~ ~ ~ ~ ~ 0 ~ 0 ~ ~ ~ ~ ~ ~
~
0 (o. <)
30 34.
Test Time La 0.75 La Bn Top UCL Fitted Leakage Type B8cC min path Note Type 8 8c C expected Minimum path leakage
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k~
~
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Calculation Local Sensor Deviation Effect on Air Mass Deg F 94 91 ~ Os ~ (jss+0,~ ~
90 89 88 87 38 30 RTD 13 RTD-21 RTD-22 RlD-22
% Relative HurT1idity 84 82 80 78 76 74 72 32 36 30 RHD-DS RH+OT Lbs 692,900 692,850 692,800 692'75 c 692,700 30 West Time34 1LR~TAi Mass Figure Q 91
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LRT 2 CLRT Air mass and Fitted Lecikage Rates Pounds Mass 692,900 wt.%%uo / 04Day 692,800 0.3 692,700 t 0.2 tJ I
692,600 C
II 0.1 1
II 692,500 XI 692 400 (o.~)
28 .30 34 36 38 40 Test Time Air mass Fitted I eakage OWP% ~ &~0 Note rapid change in calculated mass and leakage rate when known leak of 17.79 SSCM
/
(0.264 wt.% Day) added at hour 37.9
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CLRT DATA 93
I CLRT Data Sample TEST RTD RTD RTD 3 RTD 4 Number TIME DEG DEG DEG F DEG 118 38.8170 86.678 87 '71 86 '31 F'5.965 119 39.150 86.685 87.167 86.527 85.960 120 39.483 86.674 87.167 86.527 85.971 121 39.817 86.674 87.155 86 '27 85 '71 122 40.150 86.656 87.151 86.509 85.953 123 40.483 86.667 87 '40 86.509 85.953 124 40 '17 86.674 87.147 86 '15 85.960 125 41.150 86 '56 87.129 86 '20 85.953 126 41.483 86.656 87.129 86.520 85.953 127 41.817 86.656 87.129 86.520 85.953 42.150 86.654 87.124 86.515 85 949 128'29 42.483 86.654 87.124 86 '04 85.949 130 42.817 86 '36 87.106 86.509 85.942 131 43.150 86.631 87.113 86.515 85.949 132 43.217 86.'642 87.113 86 '04 85 '49 Sample TEST RTD RTD RTD 7 RTD 8 Number TIME DEG DEG DEG F DEG F 118 38.817 85.870 86 '71 86.515 85.921 119 39.150 85.877 86.378 86.510 85.939 120 39.483 85..866 86.373 86.510 85 '29 121 39.817 85 '77 86 '78 86.510 85 '28 122 40.150 85.859 86 '71 86.492 85.921 123 40.483 85 '48 86.371 86.492 85.921 124 40 '17 85.866 86.378 86.499 85.917 125 41 '50 85.859 86.360 86.492 85.910 126 41.483 85.828 86.360 86.492 85 '10 127 41.817 85.848 86.360 86.481 85.910 128 42.150 85.855 86.367 86.488 85.917 129 42.483 85.855 86.356 86.479 85 '17 130 42.817 85.848. 86.349 86.472 85 '99 131 43.150 85.846 86.356 86.488 85.917 132 43.217 85.846 86.356 86.479 85.906 94
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CLRT Data Sample TEST RTD 9 RTD 10 RTD 11 RTD 12, Number TIME DEG F DEG F DEG F DEG F 118 38. 817 91.429 90.776 91. 268 90.867 119 39.150 91.370 90.740 91. 221 90.820 120 39.483 91 '17 90.686 91. 179 90.763 121 39 817
~ 91.285 90.643 91 136
~ 90 '14 "122 40.150 91.236 90.605 91.087 90.674 123 40.483 91.193 90.679 91 '33 90.631 124 40.817 91.146 90.675 90.998 90.573 125 41.150 91.097 90.540 90.948 90.535 126 41 '83 91.063 90.497 90.904 90.504 127 41.817 91.010 90 '62 90.872 90.461 128 42.150 90.974 90.439 90.837 90.423 129 42.483 90 '31 90.396 90.794 90.371 130 42.817 90.882 90.358 90.754 90.320 131 43.150 90.846 90.320 90 '18 90.284 132 43 '17 90.835 90.320 90 '18 90.284 Sample TEST RTD 13 RTD 14 RTD 15 RTD 16 Number TIME DEG F DEG F DEG DEG F F'1.
118 38 817
~ 91. 283 90.321 215 91 059
~
119 39.150 91. 267 90.265 91.168 91. 012 120 39.483 91 '67 90.200 91.115 91. 035 121 39.817 91.247 90 '69 91 '72 90. 935 122 40 '50 91 '98 90 '19 91.012 90.940 123 40.483 91.155 90.054 90.969 90.908 124 40 '17 91.108 89.931 90.911 90.893 125 41.150 91.059 89.924 90.882 90.855 126 41.483 90 '63 89 '04 90.828 90.801 127 41.817 90.929 89 '61 90.797 90.770 128 42.150 90.851 89.834 90.761 90.743 129 42.483 90.808 89.791 90.707 90.700 130 42 '17 90 '59 89,.688 90.669 90.608 131 43.150 90 '12 89.641 90.599 90.572 132 43 217 90.701 89.641 90.633 90.572 95
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CLRT Data Sample TEST RTD 17 RTD 18 RTD 19 RTD 20 Number TIME DEG F DEG F DEG F DEG F 118 38.817 90.594 91.110 90.566 Deleted 119 39.150 90.547 91.063 90.550 Deleted 120 39.483 90.504 91.021 90 '13 Deleted 121 39 '17 90.462 90.967 90.454 Deleted 122 40 '50 90.433 90.906 90.404 Deleted 123 40.483 90.433 90.864 90.373 Deleted 124 40.817 90.354 90 '17 90.337 Deleted 125 41.150 90.325 90.768 90.297 Deleted 126 41.483 90.271 90.725 90.297 Deleted 127 41.817 90.239 90.705 90.254 Deleted 128 42.150 90.192 90.678 90 '07 Deleted 129 42.483 90.149 90.635 90.176 Deleted 130 42.817 90.154 90.586 90.095 Deleted 131 43.150 90.118 90.562 90.079 Deleted 132 43 '17 90.127 90.55 90.068 Deleted Sample TEST RTD 21 RTD 22 RTD 23 RTD 24 Number TIME DEG F DEG F DEG F DEG F 118 38.817 88.849 90 '69 90.371 89.946 119 39 150 88.840 90.326 90.339 89.818 120 39.483 88.813 90.295 90.305 89.742 121 39 '17 88.814 90.279 90.281 89.675 122 40 '50 88.796 90.252 90.252 89.626 123 40.483 88.764 90.230 90.221 89.583 124 40.817 88.764 90.198 90.189 89.518 125 41.150 88.782 90.174 90.162 89.482 126 41.483 88.753 90.145 90 124 89.453 127 41.817 88.753 90 '22 90 '04 89.433 128 42.150 88.771 90.066 90.100 89.417 129 42.483 88.722 90.049 90.059 89.390 130 42 '17 88.760 90.044 90.035 89.386 131 43.150 88.749 90.013 90.003 89.352 132 43 '17 88.749 90.013 90.003 89.352 96
CLRT Data Sample TEST RTD 25 RTD 26 RTD 27 RTD 28 Number TIME DEG F DEG F DEG F DEG F 118 38. 817 90.979 90.208 87.906 89.794 119 39.150 90.927 90.175 87.830 89.772 120 39.483 90.882 90.154 87.797 89.772 121 39.817 90.847 90 '27 87.762 89.747 122 40.150 90.786 90.100 87.745 89.729 123 40 '83 90.744 90.067 87.702 89.687 124 40.817 90.690 90.035 87.617 89.655 125 41.150 90.643 90.020 87.601 89.662 126 41.483 90.605 89.981 87.521 89.602 127 41.817 90.562 89.961 87.476 89.579 128 42.150 90.526 89.934 87.463 89.575 129 42.483 90.477 89.907 87.425 89.548 130 42.817 90.450 89.880 87 '98 89.521 131 43.150 90.408 89.849 87.355 89.501 132 43 '17 90.397 89.849 87.344 89.501 Sample TEST RTD 29 RTD 30 RTD 31 RTD 32 Number TIME DEG F DEG F DEG F DEG F 118 38.817 90.826 90.839 89.405'9.330 91'153 119 39.150 90.775 90.796 91. 056 120 39.483 90.721 90.742 89.287 91. 003 121 39 '17 90.663 90.704 89.229 90. 978 122 40.150 90.602 90.646 89.191 90. 917 123 40.483 90.537 90.601 89.160 90.863 124 40.817 90.494 90.559 89 '28 90.863 125 41.150 90.459 90.523 89.082 90.794 126 41.483 90.409 90.473 89.041 90.767 127 41.817 90.344 90.419 89 '21 90.702 128 42.150 90.320 90.384 88.974 90.677 129 42.483 90.281 90 '34 88.945 90.617 130 42.817 90.223 90.298 88 '13 90.592 131 43.150 90.181 90.265 88.706 90.547 132 43.217 90.201 90.256 88.695 90.538 97
CLRT Data Sample TEST RTD 33 RTD 34 RTD 35 RTD 36 Number TIME DEG F DEG F DEG F DEG F 118 38 ~ 817 91.297 91.272 89.832 90.898 119 39.150 91.266 91 '07 89.778 90.833 120 39.483 91. 212 91.153 89.639 90.802 121 39 '17 91.111 91.129 89.580 90.755 122 40.150 91. 019 91.057 89 520 90.705 123 40.483 90.955 91.034 89.435 90.672 124 40.817 90.890 90.992 89.423 90.618 125 41 '50 90.854 90.944 89.356 90.571 126 41.483 90.901 90.895 89.276 90.533 127 41.817 90.836 90.852 89.222 90.501 128 42.150 90.769 90.805 89 '52 90 '54 129 42.483 90.719 90.767 89 '29 90 '14 130 42 ~ 817 90.692 90 ~ 731 89.002 90.378 131 43.150 90.630 90.709 88.982 90.335
'32 43 '17 90.618 90.688 88 '71 90.324 Sample TEST RTD 37 RTD 38 RTD 39 RTD 40 Number TIME DEG F DEG F DEG' DEG F 118 38 '17 91.079 Deleted 89.486 90.738 119 39.150 91.025 Deleted 89.432 90.702 120 39 '83 90.983 Deleted 89.390 90.649 121 39 '17 90.947 Deleted 89.354 90.606 122 40.150 90 '06 Deleted 89 '05 90.557 123 40.483 90.864 Deleted 89 '62 90.492 124 40 '17 90.810 Deleted 89 '08 90.456 125 41 '50 90.785 Deleted 89.184 90.418 126 41.483 90.725 Deleted 89 '32 90.364 127 41 817 90.694 Deleted 89.101 90.322 128 42.150 90 '58 Deleted 89.054 90.-283 129 42.483 90.629 Deleted 89.016 90.252 130 42.817 90.593 Deleted 88.989 90 '14 131 43.150 90 '50 Deleted 88.946 90.187 132 43 '17 90.550 Deleted 88.946 90 '78 98
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CLRT Data Sample TEST RHD 1 RHD 2 RHD 3 RHD 4 Number TIME RH RH RH RH 118 38.817 62. 01 71 ~ 04 70.78 80.33 119 39.150 62. 19 71. 13 70.89 80.39 120 121 39.483 39 '17 62.35 62.53
- 71. 27
- 71. 39 71 71
'4
'1 80.13 80.30 122 40.150 62.73 71. 52 71.37 80.07 123 40.483 62.92 71. 66 71.50 80.12 124 40.817 63.08 71. 75 71.67 80.11 125 41.150 63.28 71 ~ 89 71.88 79.89 126 41.483 63.42 71. 98 71.96 79.83
'2 127 41. 817 63.64 72.11 72 79.90 128 42.150 63.76 72.23 72.22 79.81 129 130 42.483 42.817 63.95 64 '4 72 '3 72.46 72.37 72.54 79.48 79.73 131 43.150 64.38 72.67 72.77 79.56 132 43.217 64.42 72.70 72 '6 79.65 Sample TEST RHD 5 RHD 6 RHD 7 RHD 8 Number TIME RH O'H RH RH 118 38.817 83.33 79.48 78. 15 102.31 119 39.150 .
83.29 79.45 78.22 102.25 120 121 39.483 39 817 83 '7 83.24 79.47 79.37 78.43 78.42 102.62 102.38 122 40.150 83.22 79.34 78.39 101.99 123 40 '83 83.12 79.31 78.35 103.04 124 40.817 83.02 79.21 78.46 102.58 125 126 41.150 41.483 82.92 82.78 79.13 79.06 78.29 78.03 102 '1 102.26 127 128 41.817 42.150 82.69 82.55 78.98 78.96 77 '0 77.98 102.70 101.91 129 42.483 82.43 78.92 78.15 101.27 130 131 42.817 43 '50 82.39 82.50 78 '0 78.97 77.98 78.35 100.70 99.75 132 43 '17 82.52 79.00 78.40 100.70 99
CLRT Data TEST RHD 9 RHD 10 TIME RH RH 38 '17 102.6 101. 19 39.150 102.61 101.29 39.483 102.63 101-.31 39 '17 102.66 101.47 40.150 102.70 101.44'01.41 40.483 102.79 40 '17 102.76 101.46 41.150 102.76 101.47 41.483 102.82 101.63 41.817 102.89 101.49 42.150 ,
102.87 101.80 42.483 102.91 101.43 42.817 102.87 101.53 43.150 102.89 101.69 43 '17 102.92 101 '1 100
CLRT Data Sample TEST VAPOR CONT. , AIR LEAK FIT Number TIME PRESSURE PRESSURE MASS 4'/DAY PSIA PSIA 118 38.817 0.6068 57.000 692753 119 39.150 0.6062 56.994 692734 120 39.483 0.6060 56.987 692694 121 39 '17 0.6054 56.981 692668 0 '152 122 40 '50 0.6042 56.975 692657 0.2845 123 40.483 0.6048 56.969 692615 0.2924 124 40.817 0.6038 56.963 692595 0.2888 125 41 '50 0.6027 56.957 692574 0.2827 126 41.483 0.6020 56.951 692552 0.2763 127 41.817 0.6018 56.945 692512 0.2787 128 42.150 0.6007 56 '40 692502 0.2743 129 42.483 0.5989 56.934 692491 0.2666 130 42.817 0.5978 56.928 692471 0.2600 131 43.150 0.5970 56.923 692455 0.2534 132 43.217 0 '981 56.922 692433 0.2529 101
FITTED TOTAL TIME ILRT LEAKAGE RATE Lam -0.010 4 /DAY CONTAINMENT DESIGN LEAKAGE RATE La 0.500 4'DAY SUPERIMPOSED CLRT LEAKAGE RATE Lo 0.264 4 /DAY FITTED CLRT TOTAL TIME LEAKAGE RATE Lc 0.253 4'DAY Lo + Lam - La/4 <= Lc <= Lo + Lam + La/4 0.264 +-0.010 0.125 <= 0.253 <= 0.264 +-0.010 + 0.125 0.129 <= 0.253 <= 0.379 102
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CLRT Containment Abso ute Pressure St. Lucie Unit 2 1992 PslG
- 57. 'i 57.05 l
C:
O CA 56.95 56.9 38 40 4't Test Time Containment Absolute Pressure
CLRT Weighted Vapor PressUre St. Lucie Unit 2 June 1992 psia 0.615 0.61 0.605 0.6 0.595 0.59 0.585 38 40 41 Test Time Vapor Pressure
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CLRT Weighted Average Temperature St. Lucie Unit 2 June 1992 Deg F 90 89.8 89.6 89A Z) 89.2 O
Q 89 88.8 88.6 40 41 Test Time Containment Average Temperature
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CLRT CalcUlated Air Mass St. Lucie Unif 2 June 1992 Lbs 692,800 692,750 692,700 692,650 692,600 692,550 692,500 692,450 692 400 38 40 41 Test Time Air Mass
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CLRT Bn Top Rates Relative to Limits St. Lucie Unit 2 June 1992 wt.r.
Oo5
/ Day 0.4
%%%%%%%%%aaaa 0.3 %%%% aaa aaa %a%@
a%a@a%a%~ aa Oo2
~ oooosoo ~ ~ ~ ~ so ~ ooooo Qo ~~~~~ oQoo ~ ~ oo ~ oOooo ~~~ oQo ~ oooo+sos ~ ~ ooQooo ~ oooQo ~ ~~~o Qo ~ ooo ~ oQo ~ ~
oooo' os ~ ooQo ~~~~~ oQo ~ ~ oosOooooo ~ o(iP ~~s ~~
0.1 0
38 40 41 Test Time CLRT~Up er Limit Fitted l eqkage Rate CLRT Lovter Limit aaa ~ oooooQo bassos
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APPENDIX C LOCAL LEAKAGE RATE TESTING CONDUCTED SINCE 1989 108
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TYPE B TESTING BETWEEN REFUELING OUTAGES SINCE 1989 REFUELING AS FOUND AS LEFT DESCRIPTION DATE SCCM SCCM REMARKS PERSONNEL AIR LOCK 09-11-89 46000 6500 See Section VI 02-20-90 20000 20000 08/20/90 20000 20000 11-17-90 20000 20000 05-07-91 70000 37000 See Section VI 10-31-91 57000 22000 See Section VI 06-11-92 22000 17000 See Section VI EMERGENCY ESCAPE HATCH 09-11-89 3000 3000 02-20-90 160 160 08-20-90 3000 3000 02-12-91 2000 2000, 08-07-91 3000 3000 06-06-92 2000 2000 Maintenance Hatch 01-12-90 20 20 109
TYPE C TESTING BETWEEN REFUELING OUTAGES SINCE 1989 REFUELING AS FOUND AS LEFT DESCRIPTION DATE SCCM SCCM REMARKS MAIN PURGE VALVES 06-05-89 3, 171, 840 200 See Section VI P-10 EXHAUST 08-30-89 20 20 11-28-89 908,970 400 See Section VI 01-05-90 2,500 2500 02-16-90 122,000 400 See Section VI 03-29-90 60,000 400 See Section VI 07-08-90 2200 2200 10-01-90 10,000 10,000 11-12-90 1500 1500 01-17-91 3000 3000 04-03-91 17 ' 17.9 10-09-91 2800 2800 04-21-92 4500 4500 06-13-92 800 800 P-11 INLET 06-05-89 20 20 08-30-89 20 20 11-28-89 20 20 02-15-90 20 20 08-15-90 20 20 10-01-90 20 20 01-17-91 9000 9000 07-01-91 300 300 01-07-92 20000 20000 04-22-92 600 600 06-11-92 200 200 110
TYPE C TESTING BETWEEN REFUELING OUTAGES SINCE 1989 REFUELING AS FOUND AS LEFT DESCRIPTION DATE SCCM SCCM REMIGES HYDROGEN PURGE VALVES 06-06-89 400 400 P-56 INLET BYPASS LEAKAGE 08-28-89 250 250 11-27-89 700 700 02-21-90 820 820 05-16-90 880 880 08-15-90 800 800 11-20-90 5,000 5,000 02-07-91 8,400 8,400 05-22-91 9,600 9,600 08-06-91 10,900 10,900 11-08-91 20,000 20i000 02-04-92 20,000 20,000 06-13-92 600 600 HYDROGEN PURGE VALVES 06-09-89 20 20 P-57 EXHAUST BYPASS LEAKAGE 08-28-89 20 20 11-27-89 20 20 02-21-90 20 20 05-16-90 20 20 08-15-90 20 20 11-07-90 20 20 02-07-91 20 20 05-22-91 130 130 08-06-91 100 100 11-08-91 20 20 02-04-92 300 300 06-07-92 20 20 111
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TYPE C TESTING BETWEEN REFUELING OUTAGES SINCE 1989 REFUELING AS FOUND AS LEFT DESCRIPTION DATE SCCM SCCM REMAMCS P-48A H~ Sample 08-22-89 20 20 Replace FSE-27-10 P-26 Letdown 01-06-90 55 25 Repack V2516 112
REFUELIHG OUTAGE TYPE 8 TESTING SINCE 1989 REFUEL IHG 1990 REFUELING PEH. TYPE VALVE AS FOUND AS LEFT AS FOUND AS LEFT HO. SERVICE HO. DATE SCCN SCCN SCCN SCCN RENARKS NIH.PATH NIH.PATH NAX.PATH NAX.PATH HAIN STEAN BELL TAP ¹1 10.03.90 20 20 20 20 2A TAP ¹2 HAIN STEAN BELL TAP ¹1 10-03-90 35 35 35 35 28 TAP ¹2 FEEDNATER BELL TAP ¹1 10-03-90 20 20 20 20 2A TAP ¹2 FEEDNATER BELL TAP ¹1 10-03-90 20 20 20 20 2B TAP ¹2 25 FUEL TRAHS BELL TAP ¹1 10.12-90 20 20 20 20 FUEL TRANS TUBE FLANGE 10-04.90 20 90 20 90 0 RIHG 50 OUTAGE AUX PEN BLANK 11-09-87 20 20 20 20 FLANGES NAINT HATCH GASKET 10-01-90 20 20 20 20 INTER-SPACE A-1 ELEC. PEN. NA 09 29-87 6125 6195 6125 6195 THRU E-10 TOTAL 6300 6300 6370 TYPE B LEAKAGE (SCCN) 113
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E FUELING OUTAGE TYP E C TESTING SINCE 1989 REFU EL ING 1990 REFUEL ING till*1***llltltlll*111111*llllltl**tliltllllllt* 1****11*l*11*t**1*** *11*11*it*111111111 PEH. TYPE VALVE AS FOUND AS LEFT AS FOUND AS LEFT NO. SERVICE HO. DATE SCCH SCQI SCQI SCCH REHARKS HIH.PATH HIN.PATH HAX.PATH HAX.PATH
~ llllltt1111111111***llttl**1* 1*****i**
- 11*1 PRIHARY HAKEUP V-15-328 10.03-90 20 20 3000 3000 BYPASS MATER HCV-15-1 8 STATION AIR HCV.18.2 10-1.90 1000 1000 4&00 4800 BYPASS V-18-1270 SH-18-797 9 IHSTRUHEHT AIR V-18.195 11.03-90 270 270 600 600 BYPASS HCV-18-1 14 HITROGEH SUPPLY V.6792 10-12-90 20 20 35.7 35+7 BYPASS V.6741 23 RCP COOL IHG HCV.14-1 10.26-90 20 20 20 20 BYPASS HCV.14.7 24 RCP COOLING HCV-14.2 10-26.90 20 20 20 20 BYPASS HCV.14.6 26 LETDOMH LINE V-2516 11-08.90 20 20 200 1500 BYPASS V-2522 2&A SIT SAHPLE I - SE-05.1A 10.10.90 20 20 80 80 BYPASS I SE.05.18 I SE-05-1C I-SE 05 1D I-SE 05-1E 288 HOT LEG SAHPLE V.5200 10-05.90 20 20 30 30 BYPASS V.5203 29A PRESS SAHPLE V.5201 10-08-90 20 20 55 55 BYPASS V.5204 298 PRESS SAHPLE V-5202 10 05-90 20 20 200 200 BYPASS V-5205 31 RCB VENT HEADER V-6718 10-11-90 155 155 200 200 BYPASS V.6750 41 SIT TEST LINE I-SE-03 2A 10.05-90 300 300 300 300 BYPASS 8
I.SE.03.28 V-3463 42 CONT SNIP LCV-07 11A 10.05-90 20 20 45 45 BYPASS LCV.07.118 43 RDT PNIP SUCT V-6341 11-12.90 740 740 20000 200 BYPASS V.6342 RCP BLEED-OFF V 2524 10 05 87 20 20 20 20 BYPASS V-2505 FUEL POOL V-7189 10-05-90 20 20 100 100 BYPASS CLEANUP V.7206 FUEL POOL V-7188 10.05.90 70 20 -
150 150 BYPASS CLEANUP V-7170 114
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REFUELING OUTAGE TYPE 8 TESTING SINCE 1989 REFUEL IN 1992 REFUELING lltll*ill1111111111*111111*1111***11*11**11**1111*1111*11*1111111111 **11111*1111***11111*lltlt*111111 PEN. TYPE VALVE AS FOUND AS LEFT AS FOUND AS LEFT NO+ SERVICE NO. DATE SCCH SCCN SCCH SCCA REHARKS HIN.PATH HIN.PATH HAX.PATH HAX.PATH ll*lltt11111111111*11*11*111tlllt**11*t***1*11111*1111*1***1*****1*111*11**tll *t**1**1111***
HAIN STEAN BELL TAP ¹1 5-22-92 20 20 20 20 2A TAP ¹2 HAIN STEAN BELL TAP ¹1 5-22.92 20 20 20 20 28 TAP ¹2 FEEDNATER BELL TAP ¹1 5-22-92 20 20 20 20 2A TAP ¹2 FEEDNATER BELL TAP ¹1 5-22-92 20 20 20 20 28 TAP ¹2 25 FUEL TRANS BELL TAP ¹1 5-22-92 20 20 20 20 FUEL TRANS TUBE FLANGE 4-28-92 20 20 20 20 O.RING 50 OUTAGE AUX PEN BLANK 4-23.92 38 20 20 FLANGES HAINT HATCH GASKET 4-22-92 20 20 20 20 INTER-SPACE A-1 ELEC. PEN. NA 4-28-92 7800 7800 7800 THRU I E-10 TOTAL 8015 TYPE 8 LEAKAGE 116
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REFUELIHG OUI'AGE TYPE C TESTING SINCE 1989 REFUEL IN 1992 REFUELING
- tt*tt*****tt*ttt*
PRIHARY HAKEUP V-15-328 4-27.92 400 400 2800 2800 BYPASS HATER HCV 15 1 STATIOH AIR SH.18-797 6-13-92 1300 1300 16,000 1300 BYPASS HCV-18.2 V-18-1270 IHSTRQLEHT AIR V.18.195 6.11.92 650 650 900 900 BYPASS HCV-18-1 14 NITROGEN SUPPLY V-6792 4-25-92 20 20 50 50 BYPASS V-6741 RCP COOLING HCV 14-1 5- 1-92 20 20 20 BYPASS HCV 14-7 24 RCP COOLING HCV.14-2 5-19-92 20 20 20 20 BYPASS HCV-14-6 26 LETDOHN LINE V-2516 6.12.92 20 50 20 BYPASS V.2522 SIT SAHPLE I-SE.05.1A 6-14-92 40 20 185 20 BYPASS I-SE 05-18 I-SE-05-1C I-SE-05-1D I-SE 05 1E 288 HOT LEG SAHPLE V-5200 4-24-92 20 20 BYPASS V-5203 V-5201
'-12-92 29A PRESS SANPLE 20 20 20 BYPASS V.5204 298 PRESS SANPLE V-5202 4-27-92 20 20 500 500 BYPASS V-5205 31 RCB VENT HEADER V-6718 4-27-92 20 20 20 20 BYPASS V-6750 41 SIT TEST LINE I-SE-03-2A 4-27-92 20 20 20 20 BYPASS 8
I-SE-03-2$
V.3463 42 CONT SINP LCV-07-11A 4-27-92 20 20 70 BYPASS LCV.07-118 43 RDT PUHP SUCT V-6341 5-21-92 350 350 400 400 BYPASS V-6342 RCP BLEED-OFF V-2524 5-20-92 20 20 20 20 BYPASS V-2505 FUEL POOL V-7189 4-25.92 20 20 20 20 BYPASS CLEANUP V.7206 47 FUEL POOL V-7188 4-25.92 20 20 20 110 BYPASS CLEANUP V.7170 117
REFUELIHG OUTAGE TYPE C TESTING SINCE 1989 REFUELIHG 1992 R FUELIHG 111*11111 F 11111111111111*111111111111*llllll*111 11***1************11 111*111111 111111111 1111111*11*111 PEN. TYPE VALVE AS FOUND AS LEFT AS FDUHD AS LEFT NO. SERVICE NO. DATE SCCH SCCH SCCH SCCH REHARKS HIN.PATH HIN.PATH HAX.PATH HAX.PATH 11111111 111111*llllllllll 1 1 1*11 1 1 1 1 1 11111111111111111111 *111*1*1****1111**11***111*1*1**1 48A H2 SAHPLE FSE-27-8 5- 5.92 20 20 80 80 FSE-27-9 FSE-27-10 FSE.27.11 FSE-27.15 488 H2 SAHPLE V-27-101 5- 5.92 20 20 3000 3000 FSE-27-16 51A H2 SAHPLE FSE.27.12 5- 5.92 20 20 60 FSE 27-13 FSE-27-14 FSE-27-18 51$ H2 SAHPLE V.27-102 5- 5-92 20 20 . 500 500 V-27-17 RCB ATHOS FCV-26-1 5- 1-92 950 950 1200 1200 BYPASS RAD HOHITORS FCV-26-2 528 RCB ATHOS FCV-26-3 5- 1-92 110 110 130 '30 BYPASS RAD HOI I TORS FCV-26-4 52C RCB ATHOS FCV-26-5 5- 1-92 20 20 BYPASS RAD HONITORS FCV-26-6 ILRT TEST V-00140 5- 6-92 100 100 300 BYPASS COHNECTIOH V-00143 52E ILRT TEST V-00139 5- 6-92 20 20 100 100 BYPASS CNNECT I ON V-00144 ILRT TEST V.00101 04-24-92 900 900 1800 1800 BYPASS CNHECT IOI 67 COHTAINHENT V-25-20 6- 6-92 40 40 350 20 VACUUH RELIEF FCV-25.7 COHTAIHHENT V-25-21 04-24-92 20 20 200 200 VAml RELIEF FCV.25.8 TOTAL 5240 5240 29,985 14,030 TYPE C LEAKAGE TOTAL 5100 5100 25,795 25,465 BYPASS TYPE LEAKAGE 118
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VI. LOCAL LEAKAGE RATE PROBLEMS SINCE LAST ILRT A. Main Purge Exhaust (FCV-25-5)
During routine testing on June 5, 1989 FCV 25 5 (48" butterfly valve on main purge exhaust P-10) was found to be leaking in excess of the Technical Specification limits, see LERs 389-89-004, 389-89-009, and 389-89-009 Revl. Improper adjustment of valve closure stop was.originally thought to be the cause of the excessive leakage. On November 28, 1989 the valve again failed LLRT. After adjusting the valve closure stop again to stop leakage the testing frequency was increased. After another LLRT failure a blind flange was installed per Engineering Safety Evaluation JP¹PSL-SEMJ 039. Because the flange is outside the shield building this makes leakage from this penetration now bypass leakage, and plant procedures were changed to correctly account for the Technical Specification limit on bypass leakage. During the 1990 refueling outage repair and root cause determination was not done due to personnel safety concerns over performing maintenance on the 48 inch. butterfly valve without a jacking device for the actuator available to hold the valve open. An Engineering Request has been submitted to make the blind flange permanent.
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B. Personnel Air Lock Between the 1989 and 1992 refueling outage the personnel air lock exhibited high leakage during the "overall leakage test" (strong-back test) of Tech Spec 4.6.1.3.b on September 20, 1990. The air lock was repaired by replacing the outer door reach rod shaft packing. Reducing the overall leakage from 46,000 sccm to 6,500 sccm, the limit being 47,250 sccm. After successful tests on February 20, 1990, August 20, 1990, and t,
November 17,1990, the personnel airlock failed the strong back test on May 7, 1991. Repairs were again made to reach rod shaft seals before the Limiting Condition for Operation (LCO) 3.6.1.3 time limit was exceeded. Similar problems were experienced after the 1990 refueling on October 31, 1991.
During the 1992 refueling outage (prior to the ILRT) the reach rod shafts were rebuilt and seal again replaced.
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