ML18082A931
| ML18082A931 | |
| Person / Time | |
|---|---|
| Site: | Salem  |
| Issue date: | 08/07/1980 |
| From: | Public Service Enterprise Group |
| To: | |
| Shared Package | |
| ML18082A922 | List: |
| References | |
| 90.0, NUDOCS 8008190529 | |
| Download: ML18082A931 (34) | |
Text
T, soos1 s o6~H STARTUP PROCEDURE 90.0 UNIT NO. 2 SPECIAL TESTS SEQUENCE DOCUMENT REV.
o PUR!'OSE 1.1 To outline the entire natural circulation test program, defining the sequence in which the individual tests will be performed.
1.2 To specify what conditions should be established and maintained for each test including plant administrative procedures considered in force for each test.
+.3 To specify special instructions and emergency procedures if limits are ex-ceeded for each test.
1.4 To specify for the conduct of each test. and at the conclusion of the special test program which normal technical specifications, license conditions and safety system settings apply.
1.5 To measure the ambient heat loss of the RCS when at hot standby conditions (normal operating temperature and pressure)
- 1.6 To provide a calibration procedure to allow use of the incore flux mapping system to measure reactor power directly during natural circulation.
SUP 90.0 Rev. 2 Salem Unit 2 I
REFERENCE 2.1 Salem Nuclear Generating Station, Unit 2, Safety Evaluation Report, Part II, Section 1.G.l - 1.G.6.
2.2 Salem Nuclear Generating Station, Unit 2, Docket No. 50-311 License for fuel loading and low power testing (DPR-75).
2.3 Salem Unit 2 Special Low Power Tests Safety Evaluation, July 1980.
2.4 Salem Unit 2 Technical Specifications 2.5 Westinghouse Precautions, Limitations, and Setpoints (PLS) for NSSS, Rev. 7, 8/79.
2.6 2.7 Detailed Natural Circulation Test Procedures 2.6.l SUP 90.1 Natural Circulation Test
~.6.2 SUP 90.2 Natural Circulation With LOSS Of All Offsite AC Power 2.6.3 SUP 90.3 Natural Circulation With Loss Of Pressurizer Heaters 2.6.4 SUP 90.4 Effect Of Secondary Side Isolation In Natural Circulation 2.6.5 SUP 90.5 Natural Circulation At Reduced Pressure 2.6.6 SUP 90.6 Cooldown Capability Of Charging And Letdown System 2.6.7 SUP 90.7 Simulated LOSS Of All On Site And Off Site AC Power Station Operating Instructions 2.7.1 EI I-4.0 "Safety Injection Actuation," Rev. 1 2.7.2 EI I-4.9 "Blackout" Rev. 8 2.7.3 EI I-4.3 "Reactor Trip" Rev. 5 2.7.4 EI I-4.4 "Loss Of Coolant" Rev. 9 2.7.5 EI I-4.2 "Recovery From Safety Injection" Rev. 8 2.7.6 OI II-1.3.1 "RCP Operation" Rev. 1 2.7.7 OI II-3.3.1 "Establishing Charging., Letdown, and Seal Injection Rev. o.
2.7.8 OI III-10.3.l "Auxiliary Feedwater System Operation" Rev. 1.
- 2. 7. 9 OI I-3. 3 "Hot Standby To Min Load" Rev *. 1.
2.7.10 OI I-3.5 "MinLoad To Hot Standby" Rev. l.
Flow 2.8 Letters 2.8.l 2.8.2 2.8.3 2.8.4 PSE&G to NRC, 2/8/80 (Mittle, Parr)
NRC to PSE&G, 3/12/80 (Parr, Mittle)
PSE&G to NRC, 3/31/80 (Mittle, Parr)
Anderson/Denton letter NSTMA-224:2 Salem Unit 2 SUP 90.0 Rev. 2
['
2.9 Drawings 2.9.l 220090 B 9538 -
2 2.9.2 220080 -
83 B 9538 2.9.3 220035 B 9537 -
6 220039 B 9537 -
6 2.9.4 220043 B 9537 -
7 220045 B 9537 -
7 Salem Unit 2
"~T wiring diagram Rev. 4 Tav wiring diagram" "S/G pressure protect I" "S/G pressure protect I" "S/G pressure protect II" "S/G pressure protect II" SUP 90.0 Rev. 2
PREREQUISITE 3.1 The following tests from the low power test program have been successfully completed.
- 3. l._l 3.1. 2 3.1. 3 3.1. 4 3.1.5 3.1.6 3.1. 7 SUP 70.4 Pressurizer spray and heater capability and continuous spray setting.
SUP 70.5 Reactor Coolant System flow measurement SUP 70.6 Rod Position Indication System SUP 70.11 Incore Flux Mapping System SUP 80.3 A)
Boron Endpoint Determination B)
Isothermal temperature coefficient measurement SUP 80.4 Rod and Boron Worth Measurements SUP 80.5 RCCA Pseudo-ejection SUP 80.6 Min S/D verification and stuck rod worth.
3.2 Prerequisites particular to each of the special tests are delineated in the section 3.0, prerequisites for the procedure in question.
3.3 The Test Engineer has reviewed the procedure and the applicable precautions and limitations with all *personnel involved in the test.
This review will consist of a series of training seminars with each shift before.the test program is begun.
Such seminars may be conducted in the control room and include "dry-run" walk throughs of certain test evolutions.
3.4 The nuclear instrumentation high power setpoints are set per SUP 80.1 Table 1, section 10. 2,. "zero power".
3.5 A Test Engineers chronological log book is available in the control room.
All major events relating to the test program will be recorded by the Test Engineer on shift.
3.6 The Operational Action points as given in section 9.1.4 of this procedure are posted conspicuously in the control room.
3.7 The technical specifications as shown in Appendix B, has been approved, as special test exceptions.
3.8 The P-250 Incore T/C map program has been modified to permit running the map despite the "RCC" inoperable "a periodic alarm status, with the plant on natural circulation.
3.9 The P-250 summary flux map program has been modified to permit running the Incore Detector System with all six drives selected to emergency paths simultaneously.
3.10 Previsions have been made for recovery of condenser hotwell inventory to the Auxiliary Feed Tank
- Salem Unit 2 SUP 90.0 Rev. 2
INITIAL CONDITION 4.1 Specific initial conditions for each test are delineated in the initial conditions (section 4) of each procedure.
4.2 For conditions that should be established and maintained during each test, toget~er with applicable operating and emergency instructions, see section 9.0, "Precautions and.Special Instructions" in this procedure.
4.3 The condensate polishing system is in operation and condenser water chemistry is acceptable for feeding back to the AF*T.
Determination that this initial condition is met will be made by the Performance Engineer or his designee.
4.4 The attached valve lineup (App. Fl is complete and the transfer of water from the condenser to tl'le AFP has been demonstrated, using the guidelines given in Appendix F.
Salem Unit 2
-s-SUP 90.0 Rev. 2
ENVIRONMENTAL CONDITION 5.1 There are no particular environmental conditiQns required for performance,of any of the test program.
5.2 Atmospheric steam dump may be required in the event that condenser steam dump is not available.
SUP 90.4 (rer. 2.5.4) will require atmospheric steam dump for short periods when returning as isolated stea~ generator to service.
6.0 ACCEPTANCE CRITERIA 1.0
- 6.1 The acceptance criteria for each test are fully described in the section 6.0 of each individual procedure.
SPECIAL TEST EQUIPMENT 7.1 Test equipment employed is recorded in each individual procedure, together with instrument no. and 'calibration date.
7.2 Fluke multimeter*
PD #
Cal. Date 0.0 DATA COLLECTION 8.1 Data collection methods for each test are described fully in the section 8.0 of each test procedure.
8.2 Primary calorimetrics are to be performed using data sheet 1 and the associated associated Table l.
Salem Unit 2 SUP 90.0 Rev. 2.
9.0 PRECAUTIONS, LIMITATIONS, ;.ND SPECIAL OPERATOR INSTRUCTIONS 9.1 All Natural Circulation Tests (SUP's 90.l, 90.2, 90.3, 90.4, 90.5.
9.1.l Pressure Control using auxiliary spray NOTE Due to the ineffectiveness of normal spray, without the forced circulation provided by the RCP's, it may be necessary to utilize auxiliary spray for these tests.
The following.precautions. and special operator instruction are intended to minimize the problem.of thermal shock and thermal cycling of the spray nozzle.
9.1.l.l Precautions 9.1.l.2
- 1)
Minimize the number of auxiliary spray initiations to avoid thermal stress transients on the auxiliary spray piping.and pressurizer nozzle.
Once auxi-liary spray is started, maintain flow until no further need is anticipated.
- 2)
Maintain auxiliary spray temperature at the normal charging flow temperature; i.e. maintain letdown/
charging relative flowrates utilizing the regenera-tive heat exchanger.
- 3)
Avoid operations which will result in isolating either the normal charging or letdown flowpaths when utilizing auxiliary spray while the plant is at hot conditions.
- 4)
Avoid operations which would result in changes in the auxiliary spray temperature.
Suggested Operating Procedure
- 1)
Establish minimum letdown flow (45 gpm) and control of the charging flowrate to ensure pressurizer water level is maintained as desired:
Note:
This will provide ~
25 gpm of charging flow with normal (8 gpm) seal in-jection flow to each RCP.
Verify that the letdown flow is being cooled to below 380°F.
- 2)
Initiate Auxiliary Pressurizer Spray flow by opening the auxiliary spray isolation valve 2CV75.
Note:
Main-tain the normal charging flowpath in the open position.
Close 2PS1 and 2PS3 manually.
Salem Unit 2 SUP 90.0 Rev. 2
9.1. 2
~.
9.1. 3 Salem Unit 2 By maintaining the normal charging flowpath in parallel with the Auxiliary Spray flowpath it is envisioned that the Auxiliary Spray rate will be approximately 10 gpm.
(To estimate auxiliary spray flowrate, pressurizer heater capacity is worth about 24 gpm spray rate).
- 3)
The auxiliary spray should be maintained constant and pressurizer pressure control will be achieved by the heaters, in automatic or manual control.
Pressurizer heater power consumption should be observed during initial auxiliary spray to obtain an approxi-mation of actual auxiliary spray flowrate.
- 4)
Auxiliary Spray flow could exceed the capacity of the, pressurizer heaters. If comparisons of the total charging flow vs flow with auxiliary spray flow indicate that the spray flow exceeds 15 gpm, it may be necessary to throttle the spray flowrate by opening the normal spray valves 2PS1 and/or 2PS3, shunting some of the auxiliary spray flow back to the RCL, and bypassing the pressurizer.
- 5)
If it is desired to increase the spray flow rate, it is permissible to reduce seal injection flow to 4 gpm per pump, and control of the charging flowrate to insure pressurizer water level is maintained as desired.
Note:
This will provide approximately 40 gpm of charging flow with reduced (4 gpm) seal injection flow to each RCP.
RCP Operation 9.1.2.1 9.1.2.2 Observe the precautions and limitations given references 2.4, and 2.6.6.
Before tripping RCP's to go to natural circulation, start all oil lift pumps and leave them running.
9.1.2.3 RCP's should not be restarted for 30 min. after a pump trip, unless safety concerns necessitate the immediate re-establishment of forced circulation.
9.1.2.4 When restarting RCP's ensure that the pressurizer spray valves, 2PS1 aDd 2PS3 are operable but closed and in manual.
Criticality will be maintained observing the precautions and limitations of ref. 2.6.9, and in particular; 9.1.3.l Do not exceed 5% reactor power by any available indication.
NIS Excore Detectors are unreliable in natural circulation if Tc is allowed to change signif i-cantly.
-a-SUP 90.0 Rev. 2
Salem Unit 2 9.1.3.2 Maintain control rod banks above 100 steps.
Boron concentration should be increased should this limit be reached.
Ideally, a rod height of 160 steps, unless specifically called out in the individual test procedure, will mitigate the consequences of an uncontrolled rod/
bank withdrawal.
9.1. 3. 3 Narrow Range temperature indications, and with them the normal Tav and AT displays, become unreliable without forced circulation through the RTD bypass line.
Period-ically calculate the loops AT and Tav using wide range TH and TC' or display these continuously in the control room.
9.1.3.4 Maintain loop TC (W.R.) between 540°F and 550°F, unless specifically directed otherwide by a test instruction.
9.1.3.5 The blocking of automatic safeguards actuation for the duration of these tests requires close operator surveillance of the partial trip indication displayed on 2RP-4: to assure that safety injection is actuated manually within a short time period should the.need arise
- 9.1.3.6 If the test program is suspended for a period foreseen to be greater* than 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, the reactor trip and safeguards actua-tion features defeated in step 10.9 should be restored to normal. SUP 90.0 Rev. 2
9.1.4 Salem Unit 2 Note:
Post this page on the operators desk.
Operational Action Points 9.1.4.l 9.1.4.2 9.l.4.3 9.1.4.4 Maintenance criteria - if the following limits are exceeded and if margin exists between these "maintenance criteria" and the reactor trip action points listed below, operator action shall be to restore the parameter to within limits:
- l.
Primary System Sub-cooling (Tsat Margin)
- 2.
Steam Generator Water Level
- 3.
Pressurizer Water level a)
With pumps running b)
Natural Circulation
- 4.
Loop ~T (Wide Range Calculated)
- 5.
Tavg (Wide Range Calculated)
- 6.
Core exit temperature (highest)
- 7.
Power Range Neutron Flux Low Setpoint and "Intermediate Range Neutron Flux Reactor Trip Setpoints
- 8.
Control Bank D
>20°F
>30% Narr§~a~ange
>22% Span
>Valve when RCP's
-tripped
<65°F
<5B0°F
<610°F
<7% RTP
- _100 steps Reactor Trip and Test Termination must occur if any of the following conditions are met
- l.
Primary System Sub-cooling (Tsat Margin)
<15°F
- 2.
Steam Generator Water Level (equivalent wide-range level of 75%)
<5% Narrow Range Span
- 3.
NIS Power Range, 2 channels
- 4.
Pressurizer Water Level
>10% RTP
<17% Span or an, unexplained decrease of more than 5% not concurrent with a Tavg change.
- 5.
Any Loop ~T (Wide Range Calculated)
>65°F
>578°F
- 6.
Tavg (Wide Range Calculated)
- 7.
Core exit temperatµre (highest)
>610°F
- 8.
Uncontrolled rod motion
- 9.
Control Bank D
<100 steps Safety Injection must be manually initiated if any of the following conditio~s are met:
- l.
- 2.
- 3.
Primary System Sub-cooling (Tsat Margin)
Steail\\ GeneratQ~ Water Level (equivalent wiae-range level of 75%)
Containment Pressure
<10°F
<0% Narrow Range*
- >pan
- _4.7 psig
- 4.
Pressurizer Water Level
<10% Span or an, unexplained decrease of more than 10% not concurrent with a Tavg change.
- 5.
Pressurizer Pressure Decreases by* 200 psi or more in an unplanned or unexplained manner.
Safety Injection should not be terminated until the termination criteria of EI I-4.0 nsafety Injection Actuation" and EI I-4.2 nRecovery from Safety Injection" are met.
- Actuate S.I only if level is decreasing after the reactor trip, beyond that expected due to shrink. SUP'90.0 Rev. 2
9.1.5 Salem Unit 2 Administrative procedures applicable during Natural Circulation tests.
9.1.5.1 9.1.5.2 9.1.5.3 9.1.S.4 9.1.5.S 9.1.5.6 9.1.5.7 9.1.5.8 9.1.5.9 Shift operating practices will be continued as described in AP-5, "Operating Practicesn.
The test procedure is '2Jlder the control of the Test Engineer and is reviewed and approved in accordance with the Salem Startup Manual.
Temporary Changes to the Operating Instructions must be done in accordance with AP-3, "Station Documents" section 8.0, unless the deviation from the normal Operating Instruction is specifically called* for in the approved SUP.
On-the-Spot Changes to this document, or* the SUP's comprising the special* test program will be.executed using the "Phase III on-the-spot change form 4.2-4 and 4.2-4a.
The Test Engineer (T/E) will refrain from giving instructions directly to the R.O., unless a situation requiring prompt operator action is developing.
In general, the T/E will re-quest the SRO to execute each step of the test.
Because of.the operator training aspects.of this test pro-gram, it is expected that the control room will be crowded with observers from at least one or two off-duty shifts, a.s well as cognizant test personnel and other non-shift personnel with a legitimate need to be there.
The SRO and T/E are jointly responsible to.see that order *is maintained in the control room among these people.
Group discussions of test experience should be primarily conducted in the corridor be-tween the control rooms, or if time permits, away from* the control room area altogether.
Non-essential telephone communications with the control room will be avoided.
The Senior Shift Supervisor should assign an assistant in the office area to intercept incoming calls and relay only essential messages to the control room.
Once the required sequence of tests has been accomplished per section 10.0 of this document, re-runs of individual tests for training proposes may be done in any order, at the discretion of the Test Engineer.
Re-runs for training purpose will be done per the approved procedure.
A clean copy of the procedure will be used and signed off as appropriate in each case.
In the "comments" paragraph of section 11.0 the T/E should note that the procedure is a re-run done.for training purposes.
The maximum total number of performances of each procedure are as follows: 90.1 -
5 times 90.2 -
3 times 90.3 -
4 times SUP 90.0 Rev. 2
90.4 - 2 times 90.5 -
4 times 90.6 - 5 times 90.7 - 1 time 9.1.5.10 Data which may be collected during training re-runs need not be retrieved unless specifically mentioned in the pro-cedure.
Data which tends to contradict the acceptability of earlier test runs will be evaluated by the Reactor Engineer and/or SORC before proceeding.
9.2 Additional Precautions for SUP 90.2 (ref. 2.6.2) 9.2.l Maintain CCW and Seal Injection flow to the RCP's during all parts of the test.
9.3 Additional Precautions for SUP 90.3 (ref. 2.6.3) 9.3.l 9.3.2 Monitor power carefully when adjustments are made to TC.
Maintain TC above 531°F.
When RCS pressure is reduced to below the P-11 setpoint, 1915 psig, manu~lly block SI and close the PORV block valves.
If not blocked,*
a reactor trip will result when pressure reaches the low pressure SI trip setpoin:t, 1765 psig.
Re-open the PORV block valves when pressure is increased to above the P-11 setpoint.
9.4 Additional Precautions for SUP 90.4 (ref. 2.6.4) 9.4.1 9.4.2 9.4.3 9.4.4 9.4.5 When power is redistributed among few steam generators, Tav and TH in the operating loops will rise.
Should S/G pressure also rise, in-creased steam dump could result.
Care should be exercised that reactor power and Tc are held roughly constant during these transients.
Should plant parameters fail to stabilize within a few loop transit times (est'd loop transit time is 3 min.) power should be reduced.
If plant fail to stabilize within 30 min. or if responses exceed
- .predictions substantially, terminate the test.
During cooldown maintain RCS Lithium concentration at the upper end of the specified range (2.0-2.2 ppm), if T
<500°F c
Do not allow Tavg to decrease below 485°F 9.5 Additional Precautions for SUP 90.5 9.5.1 Wflen RCS pressure is reduced to below the P-11 setpoint, 1915 psig, manually b.l.ock SI and close the PORV block valves.
If not blocked, a reactor trip will result when pressure reaches the low pressure SI trip setpoint, 1765 psig.
Re-open the PORV block valves when pressure is increased to above the P-11.setpoint.
Salem Unit 2 SUP 90. 0 Rev. 2*
9.6 Additional Precautions for SUP 90.6 (ref 2.6.6) 9.6.1 Before and during this test, verify adequate shutdown margin.
9.7 Additional Precautions for SUP 90.7 (ref. 2.6.7) 9.7.1 9.7.2 9.7.3 The TDAFWP will be operated without benefit of its room cooler.
Closely monitor room temperature, and do not allow it to exceed 140°F.
Avoid periods of operation without containment fan coil units or reactor vessel support ventilation.
Maintain aervices to the RCP's Salem Unit 2 SUP 90.0 Rev. 2
INSTRUCTIONS 10.1 Perform SUP 90.6, "cooldown capability of charging and letdown".
10.2 Reduce the data generated in SUP 90.6 to estimate the RCS ambient heat loss, using the methodology outlined in Appendix E of this procedure.
10.3 Return Tavg to 547°F, re-establish steam dump by opening the MSIV's21-24MS167, and resetting the steam dump controller to operate at 1005 psig in the steam pressure mode of control.
10.4 Take the reactor critical following normal plant procedures (ref. 2.7.9) and raise power to about 3% RTP based on AT indications.
10.5 Establish equilibrium conditions in the RCS with respect to Steam Generator pressures, levels, auxiliary feed flow.
Maintain Tav at 547°F + 1°F.
10.6 Perform the primary calorimetric*measurement as outlined on data sheet 1.
NOTE When taking 'loop AT readings using a Fluke DVM and switch box, take the four readings as rapidly as possible.
10.7 Concurrently with the primary calorimetric, perform the "Core Power Determination" calibration for the single-pass partial core flux map, per Appendix c of this procedure.
10.8 Shutdown the reactor,* following normal plant procedures (ref. 2.7.10).
10.9 Defeat the overpower and overtemperature AT reactor trips.
Defeat the Safety In-jection actuation signals on high steamline AP and on low-low Tav' to eliminate unwanted reactor trips from these functions.
Defeat automatic Safety Injection actuation, using Appendix A of this procedure.
Reset the reactor trip setpoints on low-low, and low Steam Generator Level to 5% (narrow range).
Reduce the NIS intermediate range hi power, and power range high power, low range setpoints to 7% RTP.
Place all the steam line high flow bistab~es in "trip" status.
10.10 Take the reactor critical following normal plant procedures (ref. 2.6.9) and raise power to about 3% RTP, using narrow range AT as the. best indication of reactor power.
The corresponding AT is 3.1°F.
10.ll Perform SUP 90.1, "Natural Circulation" (ref. 2.6.1).
CAUTION Observe the precautions, limitations and special operator instructions in section 9.1 of this procedure as well as in section 9.0 of SUP 90.1.
Salem Unit 2 SUP 90.0 Rev. 2
10.12 Perform a full flux map while on natural circulation.
This need not be re-peated for training runs.
10.13 Review the results of SUP 90.1.
If the results are satisfactory in all respects proceed to step 10.14.
If not, continuance of the program will have to be authorized by SORC.
10.14 Perform SUP's 90.3 and 90.5, "Natural Circulation with LOss of Pressurizer Heaters" and "Natural. Circulation at Reduced Pressure".
(refs 2.6.3 and 2.6.5)
NOTE These SUP's may be performed simultaneously, or separately, at the discretion of the Test Engineer.
10.15 Establish RCS Lithium concentration at the upper end of the allowed range 2.0 - 2.2 ppm.
(precaution 9.4.4).
10.16 Review the results of SUP's 90.3 and 90.5.
If the results are satisfactory in all respects, proceed to step 10.16.
If not, continuance of the program will have to be authorized by SORC 10.17 Perform SUP 90.4, "Effect of Secondary Side Isolation on Natural Circulation."
(ref. 2. 6. 4)
CAUTION Observe the precautions in the procedure sections 9.1 and 9.4, as well as those given in SUP 90.4.
In particular, excore NIS calibrations may have to be adjusted to compensate for the temperature change in the downcomer to 515°F NOTE Ensure that the incore T/C mapping procedure per Appendix D is operable before proceeding with the test.
Use TI-41 to have the hottest T/C reading and location displayed on the P-250 video screen on the main control board.
10.18 Perform SUP *90.2 "Natural Circulation with LOss of All Off-Site AC Power" (ref. 2.6.2) 10.19 Shutdown the reactor, re-establish forced Reactor Coolant Flow with all four RCP's.
10.20 Perform SUP 90.7 "Simulated Loss of All On-Site and Off Site AC Power" (ref. 2.6.7) 10.21 Restore the plant electrical distribution to normal such that technical specifi-cations 3.8.l.l, 3.8.2.1, and 3.8.2.3 are again in force
- 10.22 Review the entire test program for satisfactory test completion, completeness of attached data sheets, etc.
Salem Unit 2 SUP 90.0 Rev. 2
10.23 Perform such re-runs of individual tests as may be required to fulfill the operator training criterion of this program.
Re-runs of SUP 90.1 (to make a total of 5) u __ 112 __ #3 __ H Re-runs of SUP 90.2 (to make a total of 3) u __ #2 Re-runs of SUP 90.3 (to make a total of 4) u __ #2
- 3 __
Re-runs of SUP 90.4 (to make a total of 2)
- 1 Re-runs of SUP 90.5 (to make a total of 4)
- 1
- 2
- 3 SUP 90.7 will be performed only 9nce.
10.24 Restore to normal the reactor protection and safeguards actuation features defeated in step 10.9, in accordance with App. A, section 6.0.
Log restoration in the Test Engineers chronological log.
10.25. Perform any re-runs of SUP 90.6~ as may be required (up to a total of 5) 10.26 Salem Unit 2
- 1
- 2 __ #3 __ #4.
NOTE Re-runs of SUP 90.6 are delayed until after step 10.24, because no special tech spec exceptions for this test have been taken (see App. B and ref 2.3)
On completion of the special test program, control over plant conditions and testing sequence reverts to SUP 80.l "NSSS Startup Sequence".
All technical specifications are again in force except as specified therein.
On completion of this step, no further natural circulation evolutions are permitted unless specifically authorized by the Reactor Engineer by "re-release for test". SUP 90.0 Rev. 2
TEST COMPLETION
- 11. l Comments
- 11. 2 Changes to SPM
- 11. 3 Signature
'l'est Engineer Senior Shift or Shift Supervisor
. Quality Assurance/Quality Control Shift Technical Advisor Sal.em Unit 2 Date Date Date Date SUP 90.0 Rev. 2
PRIMARY CALORIMETRIC Step 10.6 Data Sheet 1 Date Time Unit Power Loop 1 Item #
Calculation Procedure Units R2/TP-411J Test Point 1
LOC'p A T -
Inservice (at t~st poini:.} Volts 2
Loop /':;. T -
( #1) x OF 3
Loop b. H = (#2) x Cp (from Table 1) BTU/lbm 4
Loop RCS Flow (from Table 1) 106lbm/hr 5
Loop Reactor Power = ( #3) x (#4) l0 6BTU/hr 6
Total Reactor Loop 1 + Loop ~ower = <pl
+ Loop
+ Loop 4 lo 68Tu/hr 7
Reactor Power = (#6) x 0.29307 MWT 8
% Reactor Power <= (#7) x 0.02932 Remarks:
Date By:
Checked By:
Salem Unit 2
- Loop 2 R6/TP-421J Tavg --------OF Loop 3 I.oop 4 Rl0/RP-431J Rl3/RP-441J o.o 2
DATA SHEET 1 TABLE 1 Temp Cp (1) m (2)
OF BTU/lbm°F lbm/hr 556
- 1. 260 3.5922 x 107 554
- 1. 255 3.6025 x 107 552
- 1. 250 3.6130 x 107 550
- 1. 245 3.6234 x 107 548
- 1. 240 3.6330 x 107 546
. 1. 236 3.6426 x 107 544
- 1. 231 3.6522 x 107 542 1.226 3.6619 x 107 540
- 1. 221
- 3. 6716 x 107 538
- 1. 217 3.6809 x '10 7 536 1.213 3.6903 x 107 534
- 1. 209 3.6996 x 107 532
- 1. 206 3.7090 x 107 530
- 1. 202
- 3. 7184 x 107 (1) These values are from the 1967 ASME Steam Tables.
Values are for a pressure of 2250 psia.
(2) Based on estimated loop flow of 95600 gpm, best estimate for Salem Unit No. 2.
Salem Unit 2 SUP 90.0 Rev. 2
Appendi;ic A Reactor Protection and Safeguards Actuation Modifications 1.0 Block automatic safety injection (and reactor trip) on high steam line 6P signal.
~.
2.0 1.1 Defe~t the output of PC 514A-B signal comparator by lifting the input wires from terminals 1, 2, 3, and 4, and taping them back (R3 -
3C) 1.2 Defeat the output of PC 534A-B signal comparator by lifting the input wires from terminals 1, 2, 3, and 4 and taping them back (RS -
3C) 1.3 Defeat the output of PC SlSA-B signal comparator by lifting the input wires
- 1. 4 from terminals 1, 2, 3, and 4, and taping them back (R7 -
3C).
Defeat the output of PC 525A-B signal comparator by lifting the input wires from terminals 1, 2, 3, and 4, and taping themiiback (R9 -
3C) 1.5 Verify that the steam line 6P high status lights on the main control board are extinguished.
Block the low Tav signal input to safety injection (Lo Tav 0 1
r Low steam line pressure, coincident with high steam line flow) and to the steam dump interlock.
2.1 Defe~t the output of TC -
412C-D signal comparator by lifting the wires from terminals 1 and 2.
Tape the two black wires together, and the two white wires together.
Apply a 2.0 VDC signal to the input terminals 1 and 2 of TC -
412C-D, using a Performance Department signal generator.
2.2 Repeat step 2.1 for TC -
422C-D Salem Unit 2 Page l of 5
.SUP 90. 0 App. A Rev. 2
2.3 Repeat step 2.1 for TC -
432C-D 2.4 Repeat step 2.1 for TC-442C-D 2.5 Verify that the low T partial trip status lights on the main control av board are all extinguished.
3.0 Method of defeating over-power and over-temperature ~T trips.
3.1 Lift and tape the four leads from the following terminal pairs.
~T bistable 1.0 Terminals Initials TC -
411 G -
H 1/2 TC -
421 G -
H 1/2 TC -
431 G -
H 1/2 TC -
441 G -
H 1/2 4.0 Other Reactor Protection System modifications 4.1 List of steam line high flow bistables to be placed in trip status.
Verify that the corresponding trip status lights on the 2-RP-4 panel are illuminated.
4.2 Salem Unit 2 FC -
512A FC 522A FC -
522A FC -
542A FC -
513A FC 523A FC -
533A FC -
543A This change, together with the defeats executed in para 2.0 above, changes the "Hi steam flow coincident with lo-lo Tav or lo S/G pressure" SI actuation logic to a 2/4 to S/G pressure reactor trip.
List of S/G level bistables to be reset to 5%.
Page 2 of 5 SUP 90.0 App. A Rev. 2
Appendix A 5.0 This step blocks automatic initiation of a safety injection.
The safety injection alarm, manual S.I handswitch, and the reactor trip portion of the protection logic will remain in operation.
If conditions exist that would normally initiate a safety injection; the safety injection alarm will initiate telling the operator that the condition exists and what the problem is, and a reactor trip will take place automatically, unless stemming from steam line 6P, or low Tav*
Also a safety in-jection can be initiated manually from the switch in the control room if conditions warrant. Refer to the Special Operator Instructions in para 9.1.4.1 of this instruction, SUP 90.0.
5.1 Install temporary jumpers to logic cards A216, test point 1, to the logic ground on the logic test panels in the Solid State Protector System, Train A and Train B.
NOTE:
These jumpers will be specially made fQr this purpose and installed by an instrument technician.
SSP {A)
Performed by:
I Verified by:
I T/E SSP (B)
Performed by:
I Verified by:
I T/E Salem Unit No. 2 SUP 90.0 App. A Rev. 4 Page 3 of 5
6 **
storati~n Procedure 6.1 Reconnect the wires removed in paragraphs l, 2, and 3 above and perform a functional check of the bistable circuits.
6.2 3
6.4 PC 514 A-B term 1,2,3,4 PC 534 A-B term 1,2,3,4 PC 515 A-B term 1,2,3,4 PC 525 A-B term 1,2,3,4 TC 412 C-D term 1,2 TC 422 C-D term 1,2 TC 432 C-D term 1,2 TC 442 C-D term 1,2 TC 411 G-H term 1,2 TC 421 G-H term 1,2 TC 431 G-H term 1,2 TC 441 G-H term 1,2 Return the steam line high flow bistables tripped "in para 4.0 above to normal status.
Verify that their corresponding status lights on 2RP-4 are dark.
Reset the steam generator lo and lo-lo level trip setpoints to their correct tech spec settings (25% and 17% respectively)
Remove the temporary jumpers installed in step 5.1 of this Appendix A.
SSP(A) Performed by I
Verified by I
SSP(B) Performed by I
Verified by I
Salem Unit 2 Page 4 of 5 SUP 90.l App. A Rev. 2
Appendix A 7.0 List of SG level bistables to be recalibrated to a trip setpoint of 5% (narrow range) 7.1 Low Level bistables LC 518C LC LC 528C LC LC 538C LC LC 548C LC 7.2 Low-Low Level bistables LC 519B LC 529B LC 539B LC 549B Salem Unit 2 517C 527C 537C 547C Page 5 of 5 SUP 90.0 App. A Rev. 2
Appendix B Technical Specifications Exceptions The table below identifies those technical specification items which are temporarily bypassed or require special test exceptions to the limiting conditions for operations.during the performance of this and all other special tests.
NOTE:
Special test exceptions for test 7, for tech spec 3.3.1 are taken despite the fact that RCP's are operating, because it is.desired to leave the 6T reactor trips inoperative for the resumption of natural circulation tests.
TECHNICAL SPECIFICATION 1234567 Safety Injection - all automatic functions (;3.3.2) x x x x x x
Core Safety Limits (2.1.1) x x x x x OP6T (3.3.l)Inoperable :t::ecause of low flow (2.2.1) x x x x X x*
0T6T (3.3.1) Inoperable because of low flow(2.2.l) X XX XX X
S/G level lo, lo*lO (2.2.1) (3.3.1) x x x x x X
Moderator temperature coefficient (3.1.1.4) x Stearnline 6P SI (3.3.2.1) bypassed x x x x x x
High Stearnflow coincidental w/low stearnline pressure or low-low T SI avg Tavg blocked, high flow tripped x x x xx x
x SG level low AFW start reset (3.3.2.ll x
x
'Pressurizer (3.4.4) x x
x AFW (3.7.1.2) x x
AC Sources (3.8.1.l) x x
Onsite Power Dist. (3.8.2.1) x x
125 VDC Dist. (3.8.2.3) x x
Special Tests Exceptions - physics test (3.10.3) x Minimum temperature for criticality (3.1.1.5) x Salem Unit No. 2 Page 1 SUP 90.0 App. 2B Rev.
Appendix C Core Power Determination M/D Power Monitor Program
- l. Set up the movable detector system for a 1 pass partial core flux map as per TI-53.
- 2.
Select flux *thimbles as per the table below for the fl.ux map.
Det. Normaliz. Const.
Drive 10-Path Position Core Location P-250 Addresses A
10 L-5 K0908 B
10 F-11 K0909 c
10 E-5 K0910 D
10 L-11 K0911 E
6 J-8 K0912 F
8 P-9 K0913 These positions may be altered by the test engineer, based upon low-power physics test-ing results and previous special testing experience.
Determine the detector normalization constants and enter them into the P-250 as follows:
a)
Enter a value of 1.0 into the P-250 for the addresses shown in the table below.
b)
With all 5-path selector switches set to normal, run a flux trace.
c)
With all 5-path selector switches set to Emergency, run a second flux trace.
d)
Determine the detector normalization constants from Data Sheet c.1.
e)
Enter the detector normalization constants in the P-250 addresses shown in the table above.
- 3.
Set the Power Normalization Factor (P-250 address K0901) to a value of 1, and the Iniated Pass Number (P-~50 address K0900) to zero
- Salem Unit 2 Page 1 of 3 SUP 90.0 App. C Rev. 2
Appendix C Core Power Determination (cont'd)
- 4.
Perform a single pass partial core summary-map Records average Tc NIS Excore (reactivity comp.)
Primary Calorimetric (data sheet l)
- 5.
Average the six detector integrals provided in the P-250 summary map printout.
Record (reference integral)
- 6.
For subsequent power determinations during natural circulation testing, obtain another summary map and another average detector integral.
Divide this number by the reference integral obtained.
- 7.
In step*5, and multiply by the primary calorimetric power recorded in step 4 above NOTE This procedure may be repeated as often as desired at the discretion of tbe test engineer.
Be sure that Tc is the same, or apply the correction factor obtained in SUP 90
- Salem Unit 2 Between maps, monitor the NIS excore output on the reactivity computer.
Page 2 of 3 SUP 90. 0 App. C Rev. 2
~=-~=
~=-~=-
NA = l.00 N. =AN
=
NA~
B a;-
~
=
NC =~
=
NB~
CN c;-
=
N = ~
=
NCCE.
D n;-
DN
=
NE = '\\
=
NDDE E.N' t;-
=
NF = '\\
=
NEEE FN
~ =
Definitions:
.Remarks:
APPENDIX C DATA SHEET C. 1
~=--
DN=--
CE = --
DE=
E =
F =
N --
N --
EE=
FE= --
= Normalized integral from summary map for each detector in a normal path in the first pass Normalized integral from summary map for each detector in an emergency path in the second pass Detector normalization factor for each de-tector*
Date
.Data By: ----------------
Checked By:
Salem Unit 2 Date Page 3 of 3 SUP 90.0 Rev. 2
Salem Unit 2 APPENDIX P.
INCORE THERMOCOUPLES The incore thermocouples can be used as an indication of both core flow distribution and power shifts during natural circulation.
Prior to running a thermocouple map or trending the eight quadrant tilts (four center lines and four diagonal tilts) the following should be verified:
K0701-K0765 = 1, For the flow mixing fac:tors K55Ql = O, Indicates the measured core AT is unreliable K0791 = 0.075, Core bypass flow fraction K5010 = 8, Tells thermocouple program how many.readings of thermocouples are required for averaging before calculation is done.
This in turn sets the run-ning frequency of the Thermocouple Averaging Program at 1, 2, *...
X 8 seconds or 64 seconds for us.
The thermocouple.programs breaks the core. down into eight quand-rants--four centerline and four diagonal quandrants (see Figure C-1).
Quadrants 1-4 can be directly correlated with the excore detectors but quadrants 5-8 cannot.
The quadrant tilts are in.dicative of power shifts and should be trended at approximately a 2-minute frequency.
The following addressable values are the quadrant tilts:
Quadrant Addressable Value 1
U1159 2
U1160 3
U1161 4
U1162 5
U1151.
6 U1152 7
U1153 8
U1154 A Short Form Map should be run periodically or upon request from the test engineer as an indication of core flow distribution. It should be put on the Utility Typewriter if possible.
The P-250 Operator's Console Reference Manual provides instructions for ob-
~aining thermocouple maps.
The trend output and Short Form Maps should be attached to this procedure at the end of the test.
Page 1 of 2 SUP 90.0 Rev. 2
N I
I i
i J.ld* /..?~
APPENDIX D.
FIGURE I;l.1
- ceNTER-LINE OUARTER-CORE SYMMETRY Cold t..,9~
2 1
N-43 210°--......
N-42 0
0
- ~(
2 2
)
1 N-31*
N-32 0
J/.
N-35
-; N-36
- '~~'J'
(
4 3
3.*
EXCOAE.
1
/DETECTORS 0....___.. 900.....__.... 0 l'l-41 N-44 4
3 a~1d 1.1.9~
DIAGONAL QUARTER-CORE SYMMETRY 225°
- 11s 0
I
~/
a**
/
7 '*"-,,.
I 1:;5*
45 0
F 1 q"'re D-2 Page 2 of 2 SUP 90.0 Rev. 2
APPENDIX E SUP 90.0 CALCULATIONS FOR DETERMINING AMBIENT HEAT LOSS
- 1.
Use the results of SUP 70.5 to record the corrected power input for each RCP operating in 4 loop operation (tables IV, V, XII and XIII in SUP 70.5).
- 2.
Total RCP power delivered to the RCS is X Total x 0.93 =
RCP I
I
- 3.
Qamb QRCP's - Q CvCS -
C~
Salem Unit 2 Page l 21 RCP 22 RCP 23 RCP 24 RCP Total (sum)
SUP 90.0 Rev. 2
- l.
- 2.
DEFINITIONS
+
0
+~G +
C l:.T PRCS t:.t
=
where QAMB comprises ambient heat loss from the RCS, S/G's, and connected piping, as well as RCP seal heat losses, which are considered constant.
=
- 3.
Since QRCP
& Qamb are identical in both runs
+
and cp can be experimentally verified by cp Ocvcs1 - 0cvcs 2 (t:.T) _ (t:.T) t:.t 2 t:.t l 2
compare this c-~with design val~e*
p Salem. Unit 2 SUP 90. 0 Rev. 2
Appendix F Return of Condensate to the Auxiliary Feed Storage Tank PRECAUTIONS
- l. Monitor Hotwell and AFST levels frequently.
Maintain hotwell levels within the normal operating hand.
Maintain a minimum of 200,000 gallons in the AFST.
(94%)
- 2.
Monitor ~P's across Condensate Pump Suction Strainers and the Feed Full Flow Recirc Strainers.
- 3.
Do not initiate Condensate flow to the AFST without the cognizance and approval of chemistry.
PROCEDURE
- 1.
Lineup The Condensate and Feed System IAW OI III-9.3.1.
- 2.
a)
Open 2BF65 "Feed Full Flow Recirc Stop Valve" b)
Open 21&22 CN48 "SG Feed Pump Bypass Valves" c)
Close 21-24 BF13 "21-24 SG Feedwater Reg Valve Isolations" d)
Verify 3 hoses in place from 21-23CN906 to manifold at elevation 140' Turbine Deck, e)
Verify 2 hoses in place from manifold at 140' Turbine Deck to the Auxiliary Feed Storage Tank.
- 3.
Start a Condensate Pump IAW OI III-9.3.1
- 4.
Establish recirc to condenser through heater string by opening 2BF66.
(Initiate condensate cleanup as necessary through feed and bleed or diverting flow through condensate polishing system as advised by chemistry) *
- 5.
Transfer condensate as necessary to maintain hotwell and AFST levels as follows.
a)
Slowly open one of the CN906 valves.
b)
Survey hoses to AFST for abnormal indications or leakage.
c)
Repeat a) b) for the other two CN906 valves as necessary.
Salem Unit 2 Page 1 SUP 90.0 Rev. 2