ML19347E521
| ML19347E521 | |
| Person / Time | |
|---|---|
| Site: | Crane  |
| Issue date: | 05/06/1981 |
| From: | Hukill H METROPOLITAN EDISON CO. |
| To: | Stolz J Office of Nuclear Reactor Regulation |
| Shared Package | |
| ML19347E522 | List: |
| References | |
| RTR-NUREG-0660, RTR-NUREG-0694, RTR-NUREG-660, RTR-NUREG-694 L1L-134, NUDOCS 8105120332 | |
| Download: ML19347E521 (29) | |
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DOCUMENT CONTNMS P
1 P00R QUAUTY PAES u
Metropolitan Edison Company
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Post Cffice Box '30 A --
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%ddletown, Pennsvinnia 17057 Wnter's Direct Dial Nu.moer May 6, 1981 LIT. 134
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Office of Nuclear Reactor Regulation p'
N vx Attn: John F. Stol.;, Chief
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I U. S. Nuclear Regulatory Commission
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Dear Sir:
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s'%' !. g',.U'Y Three Mile Island Nuclear Station, Unit 1 (TMI-1)
Operating License No. DPR-50 Docket No. 50-289 Special Low Power Test Program 3y letter dated sanuary 23, 1981, your office requested that we describe our low power ;ast program for the restart of TMI-1.
In response to your letter we proposed to submit our Restart Test Planning Specification which includes the low power test program. The Restart Test Planning Specification is attached.
The source of the NRC's requirement for a pre-operational and special low power test program is identified in NUREG 0660 and NUREG 0694. No detailed guidance is contained in either NUREG 0660 or NUREG 0694 concerning the expected scope of the program.
Early discussions with the NRC staff indicated that we should review the programs proposed by TVA for Sequoyah and by VE?C0 f or North Anna-2.
It was further indicated to us that the focus of SRC interest was primarily for operator training and plant performance demonstrations during natural circulation. This guidance is incorporated in the TMI-l Restart Program.
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On April 22, 1981, we met with members of the NRC staff's Procedures and Test Stanch. At this meeting we provided a description of our restart test program, and we explained that our Restart Program has three major aspects. The 'irst aspect is our Prc..ntative Maintenance Program. A full-time staff now conducts this on-going program which assures that equipment is maintained and surveilled while shutdown, during operation, and for startup.
Equipment and systems beyond that covered by the plant Technical Specificatiens is included in this program. During the current extended shutdown, a heavy emphasis has been placed on maintaining all plant equipment in a proper,layup condition and ready for return to operating service at any time.
For example, during the shutdcwn, plant systems have been operated within the restrictions of the shutdown order ih/
and Technical Specifications.
All Reactor Coolant Pumps have been run, Control U Rods have been exercised and the secondary system (condensate, condenser, 5
and circulating water systems, etc.) have been run to permit equipment check out I
and operator training. Primary and secondary plant water chemistry procedures and limits that consider long ters shutdown conditions have also been used to minimize chemistry related degradation of systems and compenents.
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John F.-Stolz, Chief 'LlL 134 t
The second aspect.of the Restart Program is the Technical Specifications -
surveillance program. During the shutdown, this program has continued and checks of ' systems required for the shutdown mode have been performad. During restart, the operability of systems and components required. co be operable will'be confirmed in accordance-with Technical Specifications by conducting the' approved surveillance procedures.
The above two programs'are not unique to-this restart; rather they.have'been
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and will. continue to be an integral part of the-operation of IMI-1.
Furthe rmore,
we. anticipate that these programs will continue to be modified as reasonable improvements are identified. The NRC Regional Office of Inspection and Enforce-ment has ' observed and inspected these programs from time.to time 1since TMI-1 was initially. started in 1974 and will continue to do so.
The third aspect of the. overall Restart Program is summarized by the attached Restart Test Planning Specification (RTPS). The RTPS does not include a listing of 'the elements of che' above two programs = unless the timing of the-surveillance or maintenance is important to'the sequence of the restart or testing and surveillance can be conducted in unison.. The RTPS ie controll'-
test listing for the third aspect of restart. Detailed acceptance criteria at
'efined in the actual test procedures. The RTPS may.be changed from time to time and an up-to-date copy will be maintained available to the NRC onsite.
'As explained in our meeting of. April 22, 1981, each of the tests to be conducted
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for the restart will be conducted in accordance with the approved Master Test
.Index (MIX) and specific - Test Procedure (TP). Shny of these procedures will be~ adapted from procedures conducted as part of the original startup of TMI-l in 1974. At this time ~we do not believe that any of the tests to be conducted, constitute an unreviewed safety question or involve changes to the Technical Specifications except for the natural circulation tests done at power (3-4%
power) and those related to modifications which are discussed in Section 11.0 of the TMI-l Restart Report.
Final determination of unreviewed safety questions and Technical Specification Changes will be made as the TP and MTX are approved.
NRC approval will be obtained if needed, as required by Technical Specifications.
The RTPS tables contain one column which requires some clarification. This column is entitled " Commitment Source".
For each test in the RTPS we have attempted to identify the source of CPUN's Co=mitment to perform the test and/or the NRC source document which specifies the test.
In the absence of any external documented commitment / requirement "Startup requires" is inserted in this column reflecting our own management asssessment and commitment.
Part III, Item 14 of the RTPS specifies the natural circulation tests to be per-formed. The tests are further clarified in the attached test abstracts. The safety analyse 3 necessary to justify these tests have not yet been completed.
On'the-basis that si _lar tests have been conducted at Sequoyah and Davis-Besse-1, we anticipa that adequate justification can be provided to demonstrate that.these tests can be safely conducted.
- 4e will make available the necessary safety analyses.and supporting Technical Specifications for NRC review and approval.
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cJohn F.'Stolz,IChief1 LlL 134 The.overall restart program has been reviewed and developed in-light.of tests performed as part of. the original startup program prototypical tests at other-B&W reactors, TMI-2 Lessons Learned and.other' source documents. L'nlesa tm identified need existed such as modifications, need for. training,1need for
. reference data to substantiate operational an lyses, and/or toLexercise revised
. procedures, tests conducted for the original startup have not been repeated.
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-Other factors which influenced the. selection of tests were the value of the test and' the need to minimize unnecessary cycling of the plant or plant systems.
In-many instances plant. components-are designei for a limited number of cycles.
For example, the number of EFW actuations 2ndet hot conditions has,been minimized ;
to as few~ as 'possible by carefully planning the tests and test ' sequences of the.
emergency feedwater modifications and natural circulation training tests.
In conclusion, we'believe that the above program is comprehensive and will assure that TMI-1 is-restarted in a-prudent and acceptable manner.
Sincerely,
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-H. D. H ill Director, TMI-l HDR:LWH:lma Attachments cc:
R. Jacobs w/o Enclosure H. Silver w/o Enclosure D. Fischer w/ Enclosure D. Dilanni w/o Enclosure
'L. Barrett'w/ Enclosure
- 3. Grier' w/ Enclosure Y
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ABSTRACTS OF STARTUP TESTS RELATED TO NATURAL CIRCULATICN t
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ABSTRACT.11 ABSTRACT OF'THE-
' Determination' of Indicated Reactor Power Correction' Factor l
tt Metropolitan Edison Company Three Mile' Island-Unit 1
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- 1.0 Purpose l
1.1 ~ Determine the-effect of reduced cold leg temperatures on indi-cated reactor power in order to produce a-heat. balance correc-tion factor.
1.2 -Plot the heat balance correction factor vs cold leg temperature for use in maintaining a constant reactor power level during.
ll natural circulation testir.g.
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2.0 Prerecuisites
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2.1 Reactor power 1evel at 3 percent of rated power.
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0 2.2 Reactor. coolant temperature at 541 F - 2 F, pressure at 2155psig
- 25 psig.
2.3 Four reactor coolant pumps in operation.
2.4 One main feedwarer pump in operation.
2.5 OTSG levels are at the low level limits (26 inches I 6 inches).
3.0 Test Method' l-3.1 Establish steady state conditions.
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3.2 Manually increase the speed of the main feedwater pump to give a resultant SOF decrease in Tave.
3.3 Move rods as required'to maintain actual power at 3 percent of l
rated' power.
l-0 3.4 Continue to decrease Tave in 5 F increments until Tave is ap-0 i-proximately ~526 F.
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.3.5 Folle. sg each decrease in Tave, plot cold leg temperature versus l
the calculated correction factor.
3.6-When required data has been recorded, return system to initial L
steady state conditions.
-4.0 ' Data Recuired 4.1 -Reactor Coolant Temperatures R
L NI Power Range Reactor Coolant Flow LReactor Coolant Pressure
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5.0 Acceptance Criteria 5.1 Not Applicable.
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- 1 ABSTRACT #2
-ABSTRACT OF THE.
Emergency Feedwater Actuation Test
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Metropolitan Edison Company-Three Mile Island-Unit 1 1.0' Purpose
- 1.1 LVerify upon loss' of both main feedwater pumps, that both motor driven and the turbine driven emergency feedwater-pumps actuate and feed the steam generators-(flow / discharge pressure).
1.2 Demonstrate the use of the newly installed control room flow indicators on the emergency ~feedwater system.
~ 2.0 Prerequisites 2.1 Reactor power level at 3 percent I 2 percent of rated power.
j 2.2 Reactor' coolant temperact're at 5110F t 20F, pressure at 2155 psig : 25psig.
2.3 Four reactor coolant pumps in operation.
- 2.4 One main feedwater pump in operation.
2.5 OTSG 1evels are at the icw level limits (26 inches I 6 inches).
2.6 Technical specification 2.3.1F has been revised so as to allow the overpower trip setpoint to be set at 7 percent of
-rated power while on shutdown bypass.
,3.0 Test Method 3.1 Establish steady state conditions.
-3.2 Trip the operating =ain feedwater pump'from tre control room.
3.3 3y observing individual pump discharge pressures verify that
--t both motor driven and the turbine driven emergency feedwater pumps actuate and accelerate up to speed.
3.4 Once it has been verified that both motor driven Emergency Feedwater pumps have come up to speed, secure the pumps and allow:the turbine driven emergency feedwater pump to feed the OTSG'r 3.5 Verify t..
- feedwater is reaching the OTSG's as shown on the newly installed flow indicators and by OTSG levels maintained at the low level setpoint.
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4.0 Data Recuired 4.1 Emergency feedwater pumps - discharge pressure / Emergency Feedwater Flow Temperature and Makeup Flow OTSG levels
-5.0 Acceotance Criteria 5.1 Motor driven emergency feedwater pumps actuates following loss of both main feedwater pumps 5.2 Turbine driven amergency feedwater pump actuate following loss of both main feedwater pumps 5.3 - ICS maintains OTSG levels at 26 inches I 6 inches on the startup range following loss of main feedwater pumps
ABSTRACT #3 ABSTRACT OF THE Verification of 2 Hour Air Supply Capability of the Bott3ed Backup Air Supply Metropolitan Edison Company Three Mile Island-Unit 1 1.0 Purpose 1.1 Verify upon loss of normal / backup AC dependent air supplies that the bottled air supply is capable of supplying control air to the emergency feedwater system.
2.0 Prerequisites 2.1 Reactor power level at 3 percent I 2 percent of rated power.
2.2 Reactor coolant temperature at 5410F I02 F, pressure at 2155psig
- 25psig.
2.3 4 reactor coolant pumps in operation.
2.4 Turbine driven Emergency Feedwater pump in operation.
2.3 OTSG 1evels are at the low level limit (26 inches I 6 inches).
3.0 Test Method 3.1 Establish steady stata conditions with the emergency feedwater system supplying the OTSC's.
3.2 Manually isolate the normal / backup AC dependent air supplies to the valves on the emergency feedwater system supplied from the bottled air supply.
(MS-V4A/3, MS-V6, EF-V8A/B/C, and EF-V30A/8) l NOTE: MS-74A 3 will be allowed to cycle to verify the air systems l
capacity, however isolation valves MS-V15A/3 vill be closed to avoid discharging steam to the environment.
Steam flow will actually be through the turbine bypass valves MS-V3A, 3, C,D,E,F to the condenser.
3.3 Verify that control of the valves listed above is switched over to the bottled air supply and that OTSG 1evel, EF pump dis-charge pressure and EF pump flow are maintained within accep-table limits.
3.4 Following a period of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, un-isolate the normal / backup air supplies and verify that control reverts to the normal AC dependent air supply.
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4.0 Data Recuired 4.1 R.C. Temperatures R.C. Pressures Emergency Feedvater Flow Emergenc7 Feedwater Pressure OTSG Levels OTSC Pressures NI Power Range Bottle Air Pressure 5.0 -Acceotance Criteria S.1 Bottled backup air supply is capable of controlling the required valves for a period of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
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ABSTRACT #4 ABSTRACT 0F THE Establishment of Natural Circulation Flow Metropolitan Edison Company Three Mile Island-Unit 1 1.0 Purpose 1.1 Demonstrate that-0TSG. level can be controlled manually'from the alternate'EF-V30A/S control stations in the event that ICS power is s the normal EF-V30A/.B control stations.
1.2 Verify that s,. 21e naturel circulation flow can be estcb-lished~through the use.of existing approved plant procedures.
2.0 Prerequisites 2.l' Reactor power level is at 3 percent
- 2 percent of rated power.
2.2 Reactor coolant temperature at 541 F I 20F, pressure at 2155 0
psig
- 25psig.
2.3-5 reactor-coolant pumps in operation.
2.4 Turbine driven e=ergency feedwater pump in operation.
2.5 Turbine header pressure at 855psig
- 15psig.
2.6 Technical specification 2.3.lb has been revised to allow the reactor to' remain critical upon loss of all reactor coolant pumps.
2.7 Technical. specification 2.3.1.f has been revised to allow the overpower trip setpoint to be set at 7 percent of rated power while on shutdown bypass for this test.
2.3 Technical specification 2.3.1.f has been revised to allow the high RCS pressure setpoint to be_ set at 2300 psig while on shutdown bypass for this test. (':0TE: Shutdown bypass removes low pressure trip protection) 2.9 OTSG levels are at the low level limits.
3.0 Test Method 3.1 Establish steady state conditions 3.2. Place control of valves EF-V30A/S in manual at the alternate
-feedstation and manually raise the OTSG levels to 50 percent t 5. percent on the operating range.
s 3.3 Allow conditions to stabilize.
3.4 Trip the operating reactor coolant pumps from the control room and return control of EF-V30A/B to automatic.
3.5 Using existing and approved plant procedures establish natural circulation flev.
3.6 Allow natural circulction flow to stabilize.
3.7 Move rods as required to maintain correct al reactor power at 3 percent t 2 percent.
4.0 Data Required 4.1 RC Temperatures RC Pressures NI Power Range Secondary Steam Pressures OTSG 1evels Energency Feedwate r Flow, Temperature CTSG Dcwncomer Temperat gas Makeup Flow 5.0 Acceptance Criteria 5.1 Manual control of valves EF-730A/3 can be assu=ed at the alter-nate feedstatien and is adequate to control OTSG level.
5.2 ICS maintains OTSG 1evels at 50 percent t 5 percent ca the operating range following loss of cli 4 reactor coolant pumps.
5.3 Stable natural circulation can be established in accordance with existing approved plant procedures.
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5:r ABSTRACT #5 ABSTRACT OF THE
~ Verification of the Adequacy of the Pressurizer Hea,ters on the Emergency Bus Metropolitan Edison Company Three Mile Island-Unit-1 g"
1.0 ' Purpose 1.1 Verify that a 300F '(no pressurizer heater available) - saturation margin can be maintained for at least 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> following loss of all pressurizer heaters.
1.2 Verify that the pressurizer heaters assigned to the emergency bus are sufficient to stabilize RCS pressure / saturation margin.
j 2.0 Pre requisites 2.1 Reactor power level at 3 percent i 2 percent of rated power.
2.2 Stable natural circulation flow exists.
j 2.3 Turbine driven e=ergency feedwater pump operation.
2.4 Turbine header pressure at 855psig 1 15psig.
2.5 Rsaccor coolant pressure at 2155psig i 25psig.
3 2.6 OTSG 1evels at 50 percent i 5 percent on the operating range.
4 3.0 Test Method 3.1 Verify that stable natural circulation flow exists.
i' 1.2 Following 15 minutes of stable natural circulation tiow, de-energize all pressurizer heaters from the control room.
3.3 Record data at specified time intervals and determine the system 1
rate of depressurization. Maintain a minimum of a 300F (no pressurizer heaters available) saturation margin during the time pressurizer heaters are de-energi:ed in accordance with existing /
approved plant procedures. OPEN turbine bypass valves and establish a' steaming rate as required to '.ower RCS Tave to maintain saturation margin > 30 F.
0 13. 4 At the end of the 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ti=e period, determine the amount of available natural circulation flow.
If greater than a 25 percent difference exists between the initial and final natural circulation flow rates; allow the pressurizer heaters to remain de-enargized.
Continue to allow the RCS to depressurize and determine available NCF at each 20psig decrease in primary pressure.
Terminate this step when RCS pressure reaches 1800psig (low pressure trip bypassed) or a 300F (no pressurizer heater available)
saturation margin can no longer be maintained.- If less than a 25 percent difference exists between initial and final flow races, proceed with Step 3.5.
3.5 Activate the pressuri:er heaters on the emergency bus in accordance with existing approved plant procedures and verify that.RCS pressute and saturation mar 3 n stabilizos and/or begins to increase.
1 3.6 Energi e all banks of pressurizer heaters on normal power supply and return RCS pressure to 2155psig i 25paig.
4.0 ' Data Required 1
7 4.1
'R.C.
Temperatures SG Downcomer temperature R.C. Pressures Makeup flov NI Power Range EW temperature 0TSG pressure, level EW flow 5.0 AcceptEnce Criteria 5.1 ~
0 A mini =um of a 30 F (no pressurizer heater available) saturation margin can be =aintained in the RCS for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> following a complete loss of ::ressurizer heaters :hrough the use of existing / approved plant procedures.
i 3.2 Pressurizer heaters assigned to the emergancy bus are sufficient to stabilize RCS pressure and saturation margin.
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ABSTRACT 16 ABSTRACT OF THE Determination of the Effect of Decreased OTSG Levels on Natural Circulation Flow.
Metropolitan Edison Company Three Mile Island-Unit 1 1.0 Purpose 1.1 Deternine the effect that decreasing OTSG 1evels in increments down to the low level setpoint (26 inches t 6 inches on the start up range) has on natural circulation flow.
2.0 Prerequisites
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2.1 Resctor power level at 3 percent - 2 percent of rated power.
2.2 Stable natural ciret'ation flow exists.
2.3 OTSG levels at 50 percent I 5 percent on'the operating range.
2.4 Turbine driven emergency feedwater pump is in operation.
2.3 Turbine header pressure at S55psig t 15psig.
2.6 Reactor coolant pressure at 2155psig I 25 psig.
3.0 Test Method 3.1 "erify that stable natural circulation flow exists.
3.2 Maintain corrected reactor power at 3 percent t 2 percent by moving rods as required.
3.3 Place control of EF-V30A/B in manual at the alternate feed-station and decrease OTSG levels to 30 percent t 5 percent on the operating range. Verify natural circulation still exists and is within an acceotable tolerance band of predicted MC flow.
NOTE:
If at any time positive indication of natural circulation flow is lost, increase the OTSG levels to a point where natural circul,ation ficw is known to be promoted.
3.4 Slowly decrease OTSG 1evels to 10 percent I 5 percent on the operating range and again verify natural circulation flow exists and is within an acceptable tolerance band of predicted NC flow.
3.5 Slowly decrease OTSC levels to 90 inches I 7 inches on the startup range and verify that natural circulation fica exists and is within an acceptable tolerance band of predicted NC flow.
Continue to decrease OTSG 1evels in increments of 15 inches t
7 inches until either the icv level setpoint is reached or insufficient / negligible natural circulation flow exists.
3.6 Manually return OTSG 1evels to 50 per cnnt t 5 percent on the operating range. Do not exceed a primary cooldown rate of 0
100 F/hr.
3.7 With OTSG 1evels at 50 percent t 5 percent on the operating range, start the a reactor coolant pu=ps in accordance with cxisting/ approved plant procedurcs.
3.3 In order to allev all shifts to observe / participate in a smooth transi' ion from forced flow to natural circulation, the following steps will be repeated as required.
3.9 Trip the operating reactor coolant pumps from the control room and place the con *rol of EF-V30A/3 in automatic.
Es-tablish stable natural circulation in accordance with 1 sting / approved plant procedures.
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3.10 Following 15 min res of stable natural circulatien flow, place control of EF-V30A/3 in manual and restart the 4 reactor coolant pu=ps in accordance with existing / approved plant procedures.
3.11 Repeat steps 3.9 and 3.10 as required.
3.12 Manually decrease OTSG 1evels to the low level setpoint.
Return control of EF-V30A/3 to automatic at the alternate feedstation.
3.13 Start one main feedwater pump in accordance with approved plant procadures when it has been verified that main feed-water is reaching the OTSG's, remove the turbine driven amer-gency feedwater pump from service.
f.0 Data Required 4.1 RC Temperatures OTSG Downcomer Temperatures RC Pressures Makeup flow NI Power Range Secordary Steam Pressures OTSG Levels EFW Temperature Emergency Feedwater F1.ow 5.0 Acceotance Criteria 5.1 The effect of decreasing OTSG 1evel on natural circulation flow corresponds to predicted results.
5.2 A minimum of a 500F (pr(ssuri:er heaters available) saturation margin can be maintcined ihile on natural circulation per approved plant procedure.
5.3 operator training requirements have been satisfied, i
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STARTUP IESTS RELATED 4
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ABSTRACT ' l ABSTRACT OF THE Determination of Indicated Reactor Power Correction Factor Metropolitan Edison Company Three Mile Island-Unit 1 1.0 Purpose 1.1 Determine the effect of reduced cold leg temperatures on indi-cated reactor power in order to produce a heat balance correc-tion factor.
1.2 Plot the heat balance correction factor vs cold leg temperature for use in maintaining a constant reactor power level during natural circulation testing.
2.0 Prerequisites 2.1 Reactor power level at 3 percent of rated power.
I02 F, pressure at 2155psig 2.2 Reactor coolant temperature at 5410F 25 psig.
2.3 Four reactor coolant pumps in operation.
2.4 One main feedwater pump in operation.
2.5 OTSG 1evels are at the low level limits (26 inches t 6 inches).
3.0 Test Method 3.1 Establish steady state conditions.
3.2 Manually increase the speed of the main feedwater pump to give a resultant 50F decrease in Tave.
3.3 Move rods as required to maintain actual power at 3 percent of rated power.
3.4 Continue to decrease Tave in 5 F increments until Tave is ap-0 proximately 526 F.
3.5 Following each decrease in Tave, plot cold leg temperature versus the calculated correction factor.
3.6
'n' hen required data has been recorded, return system to initial steady state conditions.
4.0 Data Recuired 4.1 Reactor Coolant Temperatures NI Power Range Reactor Coolant Flow Reactor Coolant Pressure
5.0 Acceptance Criteria 5.1 Not Applicable.
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e ABSTRACT #2 ABSTRACT OF THE Emergency Feedwater Actuation Test Metropolitan Edison Company Three Mile Island-Unit 1 s
1.0 ~ Purpose.
I 1.1 ~ Verify upo'n loss of both main feedwater pumps, that both motor driven and. the turbine driven emergency feedwater pumps actuate and feed the' steam generators (flow / discharge pressure).
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1.2 Demonstrate the use of the newly installed control room flow indicators on the emergency feedwater system.
2.0 Prerequisites 2.1 Reactor power level at 3 percent I 2 percent of rated power.
2.2 Reactor coolant temperature at 5410F 20F, pressure at 2155 psig 25psig.
2.3 Four reactor cociant pumps in operation.
-2.4 One main feed.ater pump in operation.
2.5 OTSG 1evels are at the icw level limits (26 inches I 6 inches).
2.6 Technical specification 2.3.1F has been revised so as to allow the overpower trip setpoint to be set at 7 percent of rated power while on shutdown bypass.
3.0 Test Method 3.1 Establish steady state conditions.
3.2 Trip the operating main feedwater pump from the contfoi room.
3.3 3y observing individual pump discharge pressures verify that both motor driven and the_ turbine driven emergency feedwater pumps actuate and accelerate up to speed.
l 3.4 Once it has been verified that both motor driven Emergency Feedwater pumps have come up to speed, secure the pumps and allow the turbine driven-emergency-feedwater pump to feed the OTSG's.
3.5 Verify that feedwater is reachins the OTSG's as shown on the newly installed flow indicators and by OTSG 1evels maintained Lat the lov level setpoint.
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o 4.0 Data Required 4.1 Emergency feedwater -pumps - discharge pressure / Emergency Feedwater Flow Temperature and Makeup Flow OTSG 1evels 5.0 Acceptance Criteria 5.1 Motor driven emergency feedwater pumps actuates following loss of both main feedwater pumps 5.2 Turbine driven emergency feedwater pump actuate following loss of both main feedwater pumps 5.3 ICS =aintains OTSG 1evels at 26 inches I 6 inches on the startup range following loss of =ain feedwater pumps-
ABSTRACT #3 ABSTRACT OF THE Verification of 2 Hour Air Supply Capability of the Bottled Backup Air Supply Metropolitan Edison Company Three Mile Island-Unit 1 1.0 Purpose 1.1 Verify upon loss of normal / backup AC dependent air supplies that the Lottled air supply is capable of supplying control air to the emergency feedwater system.
2.0 Prerequisites 2.1 Reactor power level at 3 percent I 2 percent of rated pcwer.
2.2 Reactor coolant temperature at 5410F I02 F, oressure at 2153psig
- 25psig.
2.3 4 reactor coolant pumps in operation.
2.4 Turbine driven Emergency Feedwater pump in operatien.
2.5 OTSG levels are at the low level limit (26 inches I 6 inches).
3.0 Test Method 3.1 Establish steady state conditions with the emergency feedwater system supplying the OTSC's.
3.2 Manually isol te the nor=al/ backup AC dependent air supplies to the valves on the emergency feedwater system supplied from the bottled air supply.
(MS-V4A/3, MS-V6, EF-V8A/B/C, and EF-V30A/3)
NOTE: MS-V4A/3 will be allowed to cycle to verify the air systems capacity, however isolation valves MS-VISA /B will be closed to avoid discharging steam to the environment.
Steam flow will actually be through the turbine bypass valves MS-V3A, 3 C,D,E,F to the condenser.
3.3 Verify that control of the valves listed above is switched over to the bottled air supply and that OTSG level, EF pump dis-charge pressure and EF pump flow are maintained within accep-table limits.
3.4 Following a period of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, un-isolate the normal / backup air supplies and verify that control reverts to the normal AC dependent air supply.
o 4.0 Data Required 4.1 R.C. Temperatures R.C. Pressures Emergency Feedwater Flov Emergency Feedwater Pressure OTSG Levels OTSG Pressures NI Power Range Bottle Air Pressure 5.0 Acceptance Criteria 5.1 Bottled backup air supply is capable of controlling the required valves for a period of 2 hottrs.
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ABSTRACT #4 ABSTRACT OF THE Establishment of Natural Circulation Flow Metropolitan Edison Company
.Three Mile Island-Unit i 1.0 Purpose 1.1 Demonstrate that OTSG 1evel can be centrolled manually from the alternate EF-V30A/S control stations in the event that ICS power is lost to the normal EF-V30A/.B control stations.
1.2 Verify that stable natural circulation flow can be estab-lished through the use of existing approved plant procedures.
2.0 Prerequisites 2.1 Reactor power level is at 3 percent
- 2 percent of rated power.
2.2 Reactor coolant temperature at 5410F I 20F, pressure at 2155 psig
- 25psig.
2.3 4 reactor coolant pumps in operation.
2.4 Turbine driven emergency feedwater pump in operation.
2.5 Turbine header pressure at 855psig
- 15psig.
2.6 Technical specification 2.3.lb has been revised to allcw the reactor to remain critical upon less of all reactor coolant pumps.
2.7 Technical specification 2.3.1.f has been revised to allcw the overpower trip setpoint to be set at 7 percent of rated power while on shutdown bypass for this test.
2.8 Technical specification 2.3.1.f has been revised to allow the high RCS pressure setpoint to be set at 2300 psig while on shutdown bypass for this test. (NOTE: Shutdown bypass removes low pressure trip protection) 2.9 OTSG levels are at the low level limits.
3.0 Test Method 3.1 Establish steady state conditions 3.2 -Place control of valves EF-V30A/3 in manual at the alternate feedstation and manually raise the OTSG levels to 50 percent 5 percent on the operating range.
3.3 Allow conditions to stabilize.
3.4 Trip the operating rev or coolant pumps from the control room and return control of I -V30A/B to automatic.
3.5 Uring existing and approved plant procedures establish natural circulation flow.
3.6 Allow natural circulation flow to stabilize.
3.7 Move rods as required to maintain corrected reactor power at 3 percent _t 2 percent.
4.0 Data Required 4.1 RC Temperatures RC Pressures NI Power Range Secondary Steam Pressures OTSG 1evels Emergency Feedwater F'.ow, Temperature OTSG Downcomer Tempezatures Makeup Flow 5.0 Acceotance Criteria 5.1 Manual-control of valves EF-V30A/B can be assumed at the alter-nate feedstation and is adequate to control OTSG level.
i l
5.2 ICS maintains CTSG levels at 50 percent t 5 percent on the l
operating range following loss of all 4 reactor coolant pumps.
l 5.3 Stable natural circulation can be established in accordance with existing approved plant procedures.
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i ABSTRACT #5 f
ABSTRACT OF THE Verification of the Adequacy of the Pressurizer Heaters on the E=ergency Bus Metropolitan Edison Company Three Mile Island-Unit 1 1.0 Purpose 0
1.1 Verify that a 30 F (no pressurizer heater available) saturation margin can be maintained for at least 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> following loss of all pressurizer heaters.
1.2 Verify that the pressurizer heaters assigned to the emergency bus are sufficient to stabilize RCS pressure / saturation margin.
2.0 Prerequisites 2.1 Reactor power level at 3 percent 3 2 percent of rated power.
2.2 Stable natural circulation flow exists.
2.3 Turbine driven emergency feedw&ter pump operation.
l 2.4 Turbine header pressure at 855psig + 15psig.
l 2.5 Reactor coolant pressure at 2155psig'i 25psig.
2.6 OTSG 1evels at 50 percent + 5 percent on the operating range.
l 3.0 Test Method 3.1 Verify that stable natural circulation flow exists.
3.2 Following 15 minutes of stable natural circulation flow, de-energize l
all pressurizer heaters from the control room.
3.3 Record data at specified time intervals and determine the system rate of depressurization. Maintain a minimum of a 30cF (no pressurizer heaters available) saturation margin during the time pressurizer heaters are de-energized in accordance with existing /
approved plant procedures. OPEN turbine bypass valves and establish a steaming rate as required to lower RCS Tave to =aintain saturation margin > 30 F.
3.4 At the end of the 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> time pe.-iod, determine the amount of available natural circulation flow.
If greater than a 25 percent difference exists between the initial and final natural circulation flow rates; allow the pressurizer heaters to remain de-energized.
Continue to allow the RCS to depressurize and determine available NCF at each 20psig decrease in prinary pressure.
Terminate t..is step when RCS pressure reaches 1800psig (low pressure trip bypassed) or a 300F (no pressurizer heater available)
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' saturation margin can no longer be uaintained.
If less than a 25 percent difference exists between initial and final flow rates, proceed.with Step 3.5.
3.5
-Activate the pressurizer. heaters on the emergency bus in accordance with existing approved plant procedures and verify that RCS pressure and saturation sargin stabilizes and/or begins to increase.
3.6 Energize all banks of pressurizer heaters on normal pcwer supply and return RCS pressure to 2155psig + 25psig.
4.0 Data' Required a
i 4.1 R.C. Tenperatures SG Downcomer temperature R.C. Pressures Makeup flow NI Power Range EFW temperature OTSG pressure, level EFW flow 5.0 Acceptance criteria 5.1 A minimum of a 300F (no pressurizer heater available) saturation margin can be maintained in the RCS for 2-hours following a complete loss of pressurizer heaters through the use of existing /spproved plant procedures.
5.2 Pressurizer heaters assigned to the emergency bus are sufficient to stabilize RCS pressure and saturation margin.
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ABSTRACT #6 ABSTRACT OF THE
. Determination offche Effect of Decreased.
OTSG Levels on Natural Circulation Flow.
Metropolitan Edison Company Three Mile Island-Unit 1 l
1.0' Purpose
[
1.1 Determine the effect that decreasing OTSG 1evels in increments down to the low level setpoint (26 inches 6 inches on the start up range);has 'en natural circulation flow.
2.0 Prerequisites 2.1 Reactor power level at 3 percent -+ 2 percent of rated power.
2.2 Stable natural circulation flow exists.
2.3 OTSG 1evels at 50 percent I 5 percent on'the operating range.
2.4 Turbine driven emergency feedwrter pump is in operation.
2.5 Turbiae header pressure at 855psig I 15psig.
2.6 Reactor. coolant pressure.at 2155psig t 25 psig.
3.0 Test Method 3.1 Verify that stable natural circulation flow exists.
3.2 Maintain corrected reactor power at 3 percent i 2 percent by moving rods as required.
3.3 Place control of EF-V30A/3 in manual at the alternate feed-station and decrease OTSG 1evels.co 30 percent 0 5 percent on the operating range. Verify natural circulation still exists 4
and is within an acceptable tolerance band of predicted NC flow.
I NOTE: If at any time positive indication of natural circulation flow is lost, increase the OTSG levels to a point where natural circulation flow is known to be promoted.
r 3.4 Slowly decrease OTSG levels to 10 percent t 5 percent on the operating range and again verify natural circulation flow exists and is within an acceptable tolerance band of predicted i
NC f?ow.
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- 3. 5 - Slowly decrease OTSG 1evels to 90 inches I 7 inches on the startup range and verify that natural circulation flow exists, and is within an acceptable tolerance band of predicted NC flow.
Continue to' decrease OTSG 1evels in increments of 15 inches t
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'7 inches until'either the low level setpoint-is reached or-
~
insufficient / negligible natural ~ circulation flow exists.
3.6 Manually return OTSG 1evels to 50 per cent I 5 percent on the operating range. Do not exesed a prinary cooldown rate of
'1000F/hr.
'3.7 With OTSG 1evels at 50 percent I 5 percent on the operating range, start' th'e 4 reactor coolant pumps in accordance with existing / approved plant, procedures.
3.8 In order to allow all shifts to observe / participate in a smooth transition from forced flow to natural circulation, the following steps will be repeated as required.
3.9 Trip the operating' reactor coolant pumps from the. control room and place the control of EF-V30A/B in automatic.
Es-tablish stable natural circulation in accordance with existing / approved plant procedures.
3.10 Following 13 minutes of stable natural circulation flow, place control of EF-V30A/E in manual and restart the 4 reactor coolant pumps in accordance with existing / approved
. plant procedures.
3.11 Repeat steps 3.9 and 3.10 as required.
3.12 Manually decrease OTSG 1evcis'to the low level setpoint.
Return control of EF-V30A/3 to autenatic at the alternate feedstation.
3.13 Start one main feedwater pump in accordance with approved plant procedures when it has been verified that main feed-water is reaching the OTSG's, remove the turbine driven emer-gency feedwater pump from service.
4.0 Data Required 4.1 RC' Temperatures OTSG Downcomer Temperatures RC Pressures Makeup flow o
NI' Power Range Secondary Steam Pressures OTSG Levels EFW Tempetature Emergency Feedwater Flow 5.0 Acceptance Criteria 5.1 The effect of decrear.ag OTSG 1evel on natural circulation flow corresponds to predicted results.
5.2.. A minimum of a 500F (pressurizer heaters available) saturation margin
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can. be maintained while on natural circulation per approved plant procedure.
5.3 Operator training _ requirements have been satisfied.
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p THFIE MILE ISL.GD NUCLEA?. STATION UNIT 1 RESTART TEST PLANNING SPECITICA!10N REVISICN 0 AF?E0 VAL lW'? u$b
%8-8l sirector, Startup and Tes:
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Section 1 - TML #1 Restart Test Planning Specificction Table Plant Committment Iksd/Syst em/ Subject Status Source Test Scope Acceptance Criteria Remarks
{
1.
Plant Mods RM Pre-op Startup Component Operability and Components and Instru-IIca t Shrink Requires Calibration Checis.
ments meet pre-modifi-Tubing cation requirements.
IllT Startup
- 1) RCS/OTSC Instrinnent
- 1) Instruments meet Included in NNI Ilot op Cal, Requires Channel Checks.
pre-modification TP 657/1 - MrX 152.5.3.6 requirements.
RM Pre-op Startup
- 1) Remote Olling System -
Remote level indication Decay IIcat System Upgrade,.
Upgrade Requires ver ify ability to add oil agrees with reservoir Functional Test - TP 220/1, Decay lleat
& read level remotely.
level.
MrX 72.5.1.6 System
- 2) Automatic Pump Casing Vent valves function Venting - verify ability properly.
to vent pump casing re-motely.
- 3) Vibration Monitoring -
Remote indicators can verify ability to un>nitor be used to monitor vibration and loose parts vibration and loose remotely and record parts during 1)llR Pump baseline vibretion.
operation.
s Page 1 of 35 e*
e
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- ~. -
Section 1 - TMI #1 Restart Test Planning Spscification Table'
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Plant Conuutt tment 2
Mod /Systein/ Subject Status Source Test Scope Acceptance Criteria.
Remarks '
i 101-3 --
Pre-op Restart Re-
- 1) Verify proper caliteration RPS trips on simulated Reactor Protection System Trip-Reactor. Trip port Section and logic and function-react or power. > 10%
on Turbine /Feedwater - Cali-on loss of.
2.1.1.1.6, ality for a reactor trip on a loss of both IN bration.and logic Verification 4
Feed / Turbine Amend. 3 on loss of both feed-pumps-and simulated TP 376/1, MrX 203.5.1.6 Land Trip' water pumps above 10%.
reactor power >20% on a Reactor Protection System Trip "
i power or a turbine trip turbine trip.
on Turbine /Feedwater - Input above 20% power.
Test TP 376/2, MrX 203.5.1.7.-
40%
Startup
- 1) Trip both Main IN pumps -
- 1) Reactor trips, but Reactor Trip on loss of Feed-power requires at 40% reactor power and not on hi pressure.
water / Turbine. Trip - TP 800/2, verify the reactor t rips MrX 800.5.1.7.
[
and record varlons RCS
- 2) IIPI not' initiated.
and secondary plant para-
+
j ceters (including main
- 3) Turbine Bypass valve steam safety valves open setpoint is t rans-to verify RM-6 installa-ferred to 1010 1 tion). Verify RX trip _
10 psig.
Contal unien t isolation and associated bypass /
- 4) OTSC pressure is; reset features.
less than 1155 psig.
- 5) Pressurizer level stays between 80 and 339 inches.
- 6) OTFC level remains between low level limits (26" 16")
and 96% on operating range.
I i
- 7) IN demand is reduced unti1 OTSC's go o'n level control.
Page 2 of-35=
1 1
h 4
Section 1 - T!!! #1 Ecstart Test Plainting Specification Table C
Plant Connai t tment
! kid /Syst em/Subj ect Status Source Test Scope Acceptrace Criteria Remarks 101-3, cont ' d.
- 8) PORV does not lift.
- 9) Turbiae trips.
- 10) Containment Isola-tion and bypass /
reset features function as designed 95-100%
Startup
- 1) Trip the Turbine at 95-Siune as for 40% turbine Reactor Trip on Loss of FW/
power requires 100% reactor power and trip except delete:
Turbine Trip - TP 800/2, verify the reactor trips MTX 800.5.1.7.
h ) Turbine trips, ~and cud record various RCS 9
and secondary plant pa ra-add meters (including main steam safety valves Tf j 9) IV temperature to verify Rfi-6).
Verify remains above 90 F.
RX Trip Containment Iso-lation and associated bypass / reset features.
RM Con-Pre-up Startup
- 1) Pe r ra nn i ncore t he reimi-Thermocouple accuracy Incore Thermocouple Checkout nect Incore requires couple checkout and is within + 5%
and Calibration, TP 346/1, Thermocouples calibration.
MrX 123.5.1.6.
to Computer i
ilFI' Startup I) Compare incore thermo-Thermocouples compare Non-Nuclear Iustrumentation requires couples with T, T, and within 2t>"F tolerance llot Operation and Calibration h
each other.
hand.
- TP 657/1,tirX 152.5.3.6.
1 P.ge 3 of35 I
Section 1 - THI #1 Restart Test Planning Specification Table Plant-Committment "ik>d/Syst em/Subj ec t.
Status
. Source Test Scope Acceptance Criteria' Remarks' 4
RM-4, cont'd.
PET Startup
- 1) ~ Compare incore Ll'iernus-1).Thermocouples agree Incore Thermocouple Testing reipai res couples to power distri-within acceptable at Power - TP 846/1, but ion and. synenet rical.
tolerance of pre-MTX 123.5.1.7.
thermocouples, diction.
5 RM Contain -Pre-op Startup
- 1) Verify selected contain-
- 1) The. appropriate
- 1) Containment Isolation on ment Isolation requires-ment. Isolation valves valves isolate as liigh Radiation - Calibra.
on Reactor-automatically close on
' required and open tion - TP 366/1, Trip and Iligh the appropriate isolation only under the MrX 183.5.1.6.
Radiation sipals of:
appropriate reset "I"
- 1) Reactor Trip liigh Radiation - Valve
- 2) 4 psig Ril pressure
. Functional Test - TP 366/2,
- 3) 30 psig Ri! pressure
- 4) 111 Radiation
- 3) Engineered Safeguards
- 5) Line Break Actuation logic Test -
.TP 334/1, MrX 91.5.1.6.-
- 6) llPI Actuation also verify operation
- 4) Engineered Safeguards of override and bypass Actuat ion logic Test 1
switches.
TP 334/1, KrX 91.5.1.7.
- 2) Calibrate the radiation
- 2) Radiation monitors N NN I""I"'I"" "" I'I ""'""
monitors used as input, isolate appropriate Functional Test - TP 334/3, MrX 91.5.2.6.
valves at i of required setpaint
- 3) Verify proper oper$ tion
- 3) All alarms function 4
of all computer and as required.
I annunciator alarms.
t
- 4) Verify diesel loading
- 4) Sequence times are sequence times.
with
% of set-points.
Page 4 of 35 r-,
v Section 1 - THi il Restart Test Planning Specification Table Plant Couuni t t ment
' '!ksd/Systera/Sul> Ject Status Source Test Scope Acceptance Criteria
. Remarks RM-5, cont'd.
l IIFr/ PET Startup
- 1) Oleserve operation of iso-Acceptable isolat.lon Included lu individual program-reipii res lation valves & capabill-and reset.
ty to reset signals as actuation occurs during program trips.
IIFr/ PET Restart Re-Met-Ed should perform on 1ine Isolation valves close Met-Ed SP-port, Sect.
testing to prove operability on required signals 2.1.1.5.2, and demonstrate reliability, and can be reset under Amend. 21 appropriate conditions.
RM IIFr Startup
- 1) Verify proper operation
- 1) Accoustic monitor Main Steam Safeties Setpoint
~Acco' etic Mon-requires of accoustic monitor for control room indica-and Accoustic Moniters -
Itor for Main each MSS valve.
tor indicates when Functional Test - TP.654/1, Steam Safeties MSS valve is open.
HTX 143.5.1.6.
- 2) Verify
'B' monitor actu-
- 2) ' ll ' monitor actuater, ates wh-n MS-V22A/11 lift, when MS-V22A/B lift, and control room indicator indicates when valve lifts.
PET Startup Verify control room Indica-System functions satis-Various individual PETS will requires tors indicate valves lift factorily, incorporate a check to deter-during various trips at mine safeties have lifted.
power.
i Page 5 of 35 m
y
e Section 1 - TMI.#1 Restart Test Planning Specification Table.
Plant Ct.mmittment Hod / System / Subject Status Source-Test Scope Acceptance Criteria Remarks-hRM Pre-op Startup Computer Group to Checkout Printer operates satis-No Startup involvement or
' Computer Mods-requires operation of high-speed factorily.
procedurer planned.
Illgh-Speed printer.
Printer h RM Raise Pre-op Startup Calibrate per Met-Ed SP per SP Met-Ed SP S t eata Gene ra t o s-requires Level Trans-mitter Ill'r Startsp Compare OTSC level ind'.cators Indicators are within NN1 Ilot op Cal - TP 657/1, requires during heatup.
acceptable tolerance.
HTX 152.5.3.6.
h RM Raise Pre-op Startup Cal ibrat e Pold'J per Met-Ed Setpoint is within Setpoint of requires Puicedu re acceptable tolerance Power Operated of 2450 psig.
Rellef. Valve (PORV)
RM PORV~
111 0 Restart Re-1.ift PORV at hot functional
- 1) PORV Flow Indication and Safety port, Sect.
conditions to:
Functional Test -
Valve Pasition 2.1.1.2.3, TP 664/1, MTX 195.5.1.6.
- 1) secify adequate response
- 1) PORV lift & rescat Indication and Amend. 18 of accoustic monitor is adequately dis-1.M Manual Operation of 12/11/80 E "Y#
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PORV from Con-letter ACHS trol Room and to NRC Com-
,)
wri y a equata msponse
- 2) Elbw tap range and PM PORV missioners ot elbw flow tap en PORV sensitivity are ade-Tailpape Temp.
and lack of resposise on quate to determine 3
code safety valve elbow PORV lift / reseat &
i taps.
Interference with code safety clhow tcps is at accept-ably low level.
Page 6 of 35 M-
Section 1 - Ttti #1 Reetart Test Planning Specification Tabla Plant Con mi t tmesit 11od /Syst em/ Subj ec t Status Source Test Scope Acceptance Crit eria Remarks 8
R11-lu, cont'd.
- 3) verify acceptable t euip-
temperature is with-magnitude of Interfetenet in the allowable response of code safety band on the t empera--
valve tailpipe thermo-ture response curver, couples. Comparat response in Restart Repo r t of t hermocouples during and TDR 238, and valve opening and after effect on code closure against curve safety tailpipe refeienced in Restart thernu> couples 11. at Report, Sup.
1, Part 2, an acceptably low Question 36, and contain-
- level, ed in TDR #238.
- 4) Observe response of RCDT
- 4) RCDT and tailpipe and tailpipe t heruun-thermocouple Instru-couples diaring/af ter POkt mentation can be li f t; d >cumen*_ sens i t ivi ty used to indicate of RCDT and tailpipe l'ORV/saf ety valve thermocouples instru-leakage.
mentation to detect PORV iiit/1eakage.
- 5) Verify operability of
- 5) !!anual switch f unc-manual switch to open/cis tions acceptably.
PORV from control room.
I
- 6) Verify ability of PORV
- 6) Block valve closes I
Block Valve to close, then against an open PORV I
open against an open PURV l
9 RM Pre-up Startule liydrogen Re-reiluires Functionally test the recom-llyd4 ogen Recombiner Functional combiner hiner to verify proper opera-Test, TP 243/1 Lion of:
IITX 285.5.1.6.
Page 7 of 35
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Section 1 - Tell #1 Restart Test Planning Specification Table I
Pilint Committment l
tiod /Syst em/Subj ec t Status Source Test Scope Acceptance Criteria Remarks 13 Rti-13 (c)
Pre-op Res tie rt Re-
' Verify the failure mode of Valves fall open.
EIN-V30 A/B Fail Open i
EF-V30 'A/B port, Sect.
EF-V30 A/B on loss of air.
Functional Test - TP 233/1, Faii Open 2.i.1.7.7, tiTX 85.5.3.6.
Amendment 22 14 'Ril-13 (g)
Pre-up St art up Verify alarm annunciators in Alarms annunciate for Emergency Feedwater System Aminuc ia t o r respa i res control room for each auto each EIN auto start.
Functional Test - TP 233/1, Panel in start of EFW System MrX 85.5.5.6 ConttoL Room h
15 KF1-13 (h) pre-up Restart Re-Verify operability of valves System t.ransfers to 11ackup Instrument Air Func-2-br. air sup-port Sect.
and trancfer points for back-backup air at 70 psig.
tional Test - TP 248/1, ply for EF-V30 2.1.l.7.7 up air system at cold condi-and each valve will MrX 131.5.1.6 t /11, ets-V6 and Amend. 22 tions.
operate properly on EF-V8A,ti,C backup air.
PET Start up Verify the backup air supply
- 1) SG i-rel is main-1.ou Power Natural Circulation requires has t he capability of supply-tained at 26 i 6" Test - TP 700/2, FrfX ing ai r t o t he emergency with pan-700.5.1.7 feedwater system foliming sive system (no AC loss of the AC dependent air power) system.
- 2) EPP flow and dis-clarge pressure are maintained within ac,ceptable limits of design with passive system (no AC power).
s Page 10 of 35 a
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Committment Mott/ System / Subject Status Source Test Scope Acceptance Criteria Remarks s
817 101-1 3 Pre-op Reutart Re-Run all three EFPs in recirc.
All values are within Emergency Feedwater Pumps -
1 port Supple-for 48 hrs. each and monitor:
acceptable limits of 48-hour Run - TP 233/2, ment 1, Part design.
MTX 85.5.5.7.
- 1) flow 1, question
"" ' "" E ' # " " " "' "
10(b) and SER
- 3) discharge pressure 1.a (addition
- 4) bearing and bearing oil g),j tempeiatures
- 5) turbine steam tempera-ture and pressure
- 6) EIN t emperat ure
- 7) tubine, motor and pump vibration
- 8) motor current
- 9) turbine specil
- 10) room temperature and humidity Shutdown pump for 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> anal unti1 system (.20"F of start-ing (cmperatures and run for one additional hour.
18 101-14 IIFT Restart Re-Perform cross connect fune-
- 1) Total flow is liigh Pressure Injection
- 1) 550 nig port Sup.
I, tional test at 550 psig for 2500 gpm and System Functional Test -
liigh Pressure i
Injection 2)1200po i g Part 1, Ques-I ptunp, A t ra i n ; I pump, 6550 gpm at TP 655/1, MTX 144.5.1.6.
Cross Connect 1)1800ps ig tion 36 (c),
il train.
550 psig.
Amentimen t 18.
- 2) Flow split is B 70/30 for three lowest flow legs.
Page 12 of 35
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w Section 1 - TMI #1 Restart Test Planning Specification Table Plant Committment f
flod/Syst em/Sub ine t Statuu.
Source Test Scope Acceptance Criteria Remarks Cont'd.
(lie 1eteil) 26 1.ti-7 A Pre-op Startup Calibrat e and veri fy re-Calibration / response lipgimle Rlt requires sponse of A P Indicator.
is acceptable.
Spray - de-lete Sodium
' thiosulfate IJi-8 A Pre-up Startup Calibrate per manufacturer i.evel Indicates within R11 Sinnp I.evel requires specification manufacturer spec.
IJi-9 Pre-op Startup Calibrate per Met-Ed Survell Per Surveillance Pro-SP Raise PZR requires lance Procedure cedure i.e ve l Xmitter til?r St a rt up Compare instrument channels Channels agree within Perform per PZR Cperation requires during heatup, acceptable tolerance.
Test - TP 664/2, MTX 195.5.2.7.
111-12 Pre-op Startup
- 1) Record baseline vibration llaseline ?
TP 250/1.1, MTX 187.5.1.1.
RB Cooling requires Fan flo t o r Vibration y
Page 17 of 35
4i Section 1 - Tt!I #1 Restart Test Planning Specification Table Plant Commit t ment tlod / System /Subj ec t Status Source
. Test Scope Acceptance Criteria Remarks
'l 30 Nti-I S
' Pre-op Startup 1). Flow balance cooling
- 1) Adequate Ifew Indust ri-requires water al Cooler.
- 2) Verify design air flow.
- 2) +-
- 7. of design.
Industrial Coolers Functional' Test - TP.247/1, trrX 192.5.1.6.
- 3) Verify proper operation.
- 3) Controls operate of controls, satisfactorily.
- 4) flinimum of 2 CPFt &
- 4) Verli.y design blowdown maximum 55 GPet blow
- rates, down rate.
- 5) Verify spray water dis-
- 5) Channels level and trihution channals are function properiy.
leveled and functioning properly.
- 6) Verif y sump water level &
- 6) Sump level & float makeup float valve are are properly properly adjusted.
adjusted.
IIFT Startup Verily that industrial cool-kil design temperature Industrial Coolers Functional requires ers provide sufficient cool-limits are not exceed-Test - TP.247/1, ing to maintain His tempera-ed at ilFT conditions.
11TX 192.5.1.6.
tures less than design limits as RCS in heated up to lil"r.
l i
L u
Page 18 of 35 i
4 4.
Section 1 - Till #1 Restart Test Plainiing Specification Table-
~
Pl4uit Coimni t t men t flod/Syst em/Sub jec t Status Source Test Scope Acceptance Criteria Remarks l.
31 IJ1-18 Pre-up Startup Verify ability of Chemical System operates satis-Industrial Cooler Chemical, Industrial reig ui res Addition system to adequately factorily.
Addition Functional Test -
Cooier Chemi-add chemicals & control water TP 247/2, MfX 192.5.2.6.
cal Addition chemistry.
32 111-21 litT Restarr Re.
- 1) Verify proper performance
- 1) Controls operate RCS Iligh Point Vent Functional Remote Ope r-port, Sect.
of valve controlu.
natisfactorily.
Test - TP 675/1, NfX 195.5.3.6 ated P eu-2.1.2.2.7, surizer Vent Amend. 21
- 2) Verify flow ludication
- 2) Flow verified.
through each veut line during RCS fill / low pres-sure conditions.
- 3) Verify proper operationoi
- 3) Pressurizer vent Pressurizcc vent at norm-can be cycled open al RCS operat N tempera-and closed satis, ture and pressure.
factor 11y at no riin 1 RCS operating temp-erature and pressur
- 4) Verify confirmation of
- 4) Leakage is 1ess shutoff during pre-than 10 cc/ hour.
service hydro testing.
i Page 19 of 3 5 m
+
Section 1 - TMI #1 Reste.it Test Planning Specification Talile
~
Plant Committment tlod/ System /Sulij ec t Status Source Test Scope Acceptance Criteria Remarks l
111-2 3 Pre-op St art up
- 1) Calltsrate Monitor
- 1) Satisfactory Containment. Post-accident requires liigli Range Radiarlon Monitors RM-C22 and RM-G23, TP 366/3, MrX 183.5.2.6.
- 2) Check out alarms, later-
- 2) All operate.
locks, and controls.
h 1J1-24 IIFT Restart Re-
- 1) Analysis will be coupled
- 1) Exposures are cal-RC Post-Accident Sampling Post-Acci-port, Sect.
with dry ruu sampling culated at45 Riht TP 677/1, MrX 170.5.1.6.
dent Samplini 2.1.2.4, times to veri fy radiation whole body and(75 Amend. 22 exposures will lie accept-REM to extremities alile and turnaround time for design basis RC HilREC 0737 is less.than 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />.
activity.
II*U'3' ~
- 2) Sample results are known withlu 3 brs.
of initiating a sample request.
s.s Pre-up Restart Re-
- 1) Functionally test opera-
- 1) Sampling System TP 277/1, MTX 168.5.1.6.
port, Sect.
bility of Contaltunent functions as de-2.1.2.4 Atmospheric Sampilug signed.
System.
i 111-25 Pre-op Startup
- 1) Lairbrate Monitors
- 1) Satisfactory TP 366/4, MTX 183.5.4.6.
Post-Accident requires Monitoring
- 2) Check out alarms, Inter-
- 2) All operate.
locks and controls.
Page 20 of 35
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~
l'l a n t Committment Ekid/Syst em/Sub j ec t Status Source Test Scope Acceptance Criteria hemarks i
- 11. ?lon tiodified Pre-op Startup and Verify electrical interlocks System interlocks and The 17 systems were selected Systems Plant re-and control functions of control functicns per-based on the fact these quires system components, form satisfactorily.
systems were not included in the Surveillance Program to verify performance.
1 Auxiliary ant!
Fuel llanilling 11uilding fleat-ing and Vent 2 Circulating Water Coutlensate
' System 4 Contlenser Ai r Removal - Plain and Auxiliary Fluid tilock System Caseous Wase.-
Disposal In.st rumen t' Ai r System e
8 Intermediate Cooling Water Syst em 9 fiain Steam
/
System Page 23 of 35
Section 1 - T!!! #1 Restart Test Planning Specification Table I'l a n t Coucal t t ment Flod/Syst em/Suh j ec t Status Source Test Scope Acceptance Criteria Remarks l
- 11. Non Modified Pre-op Startup and Verify electrical interlocks System interlocks and The 17 systems were selected Syst ems (cont 'd.1 Plant re-and cont rol funct ions of control functions per-based on the fact these iguires system components.
form satisfactorily.
systems were not included in the Surveillance Program to verify performance.
10 Nuclear Ser-vice Closed Cooling Water 4
11 Nuc lear Se r-vice River Water Penetration C"oling System Peactration Pressurization System D
14 Reclaimed j
' Wat er System Secondary Ser-vice Clos,I Cooli ng 14 er (th Secondary St r-vice River k!a t e r 17 Se rvice Ai r System Page 24 of 35
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(cont'd.)
- 6) Determine "all rods out" Extrapolated to provide isothermal temperature negative moderator co-coefficient.
erficient above 95%.
- 7) Perform shutdown margin
> l%
verifIcatlon.
- 8) Perform ejected rod worth < !% K/K measta1 emen t s.
+
- 9) Verify method of reacti-
- S% of calculations vity measurement VS cal-using doubling time.
culations.
hI.owPower-3% Power 1) THI l
- 1) Verify OTSC level c'mtrol 26" I 6" low Power Natural Circulation Natural Cire-Iw a t i.r t at 30"
..n Sil range with Test - TP 700/2, MTX 700.5.1.7 ulation Test-lies.. I ngs EFPs on trip of main fps.
ing
- 2) NUREC 0737
Design for expected Natural Circulation flow, required NC flow, and effect that various pe urbations have on NC flow.
- 3) Restart
- 3). EIN l' low Indicators in Flow indicators provide Report cont rol room can be used EIN flow indications to Section to monitor EIN flow.
CMus per EP 1202-26A 8.4.9
- 4) 6/16/80
- 4) Veri fy abilit y to cont rol 26" 4 6" NRC memo OTSG level wit h new manu-50 + 5%
(llanauer al EF-V30A/11 control to Eisenhu t) stations.
Page 29 of 35
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Section 1 - Ttli #1 1(estart Test Planning Specification Table m
Plant Committment flod/ System /Subj ec t Status Source Test Scepe Acceptance Criteria itema rks l
h Unit Accept-PET Plant Verify steam output E-NSS 2 10,020,000 f/hr steam Use existing procedure ance Test requires contract warranty at 100%
at 925 psig and 570"F OP 1550-09.
power.
when supplied w!th feedwater at 1020 psig and 450"P.
28 Turbine Over-PET Tech Sp'ec Perform turbine overspeed tiechanical turbine Use existing SP 1303-11.19.
speed Testing 4.1-1.39 testing fullowing shelI warm overspeed 110-111%
requires ing and init.ial loading to (1980-1998 ItPM); backup E 12%.
[gv.>rupeed 112% (2016 i 10 #(EII) 29 ItCS 1.eakage lift Tech Specs Perform 1(CS hot leakrate
- F_IgPfl unidentified Use existing /new Surveillance require measurements and compare leakage.
Procedure wi th comput er program.
f 10gPM identified leakage.
30 1.eakage 1:e-IIFT S Elt, Section 1(eactor livilding Spray and Use new Surveillance Procedure duction Sur-2.1.6.a, FC Sampling System leakage veillance pgs. C8-31 testing and criteria esta-
' resting and 32.
blishment will be acconplish-ed during restart testing at hot shutdown.
31 lill-V22 and tilt TI.l. 137 CF-VSA/ll, CF-V4A/11 and Dll-Use new Surveillance Procedure CF-V 1.eak (llerbein to V22A/li will be tested by Check Eisenhut) placing lu.S pressure on the upstream side of each check valve and moni t oring leakage j
on the downstream side.
b Page 34 of 35
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