ML20195D868
| ML20195D868 | |
| Person / Time | |
|---|---|
| Site: | Comanche Peak  |
| Issue date: | 12/31/1983 |
| From: | TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC) |
| To: | |
| Shared Package | |
| ML20195D806 | List: |
| References | |
| FOIA-85-59 NUDOCS 8606050146 | |
| Download: ML20195D868 (990) | |
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COMANCHE PEAK STEAM ELECTRIC STATION
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[s"_) REACTOR CONTAINMENT BUILDING fo UNIT ONE PREOPERATIONAL
.a 1983 DOCKET NUMBER 50-445 l
TEIAS UTILITIES GENERATING COMPANT l 9
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s ILRT Test Summary
~f l.0 Introduction 1.1 General Data:
The Comanche Peak Steam Electric Station (CPSES) Unit 1 preoperational . Containment Integrated Leakage Rate Test was conducted during the period -
*, from January 18, 1983 to February 2, 1983. Both a reduced pressure and a peak pressure test were conducted in accordance with 10CFR50, Appendix J.
Reactor Containment Leakage Testing for Water Cooled Power Reactors. 1.2 Technical Data: The containment building at CPSES is a reinforced concrete structure with a carbon steel liner. The structure contains a net free volume of 2,919,893 cubic feet. The design pressure is 50 psig and the calculated . peak accident pressure is 48.1 psig. The design temperature is 120*F and the calculated peak accident temperatu're is 280*F. The Technical Specification limit for the containment leakage (La) is 0.1 percent by weight of the containment air per 24 hours at pressure Pa (48.1 psig). I 2.0 Test Su m rv The Comenche Peak' Steam Electric Station Unit One preoperational containment Integrated Laak Rate Test (ILRT) was conducted concurrently with the Structural Integrity Test (SIT) as shown on Figure 1. Immediately prior to closing the containment building for the SIT /ILRT test, a pre-test containment survey was 4 conducted to ensure the building was properly prepared for the tests. No deficiencies were found during this inspection. The conen h==nc was pressurized for the SIT in five (5) increments to a peak pressure of 57.5 psig. The containment was subsequently depressurized to 12.5 psig to allow personnel entry to check for leakage on the steam generators. A number.of, instrument. valves _we_re A und to be 1== W g_snd.were v=eiased to better_ seat the valves and s y the_ leakage. ' - ~ ' After completing the entry, the containment was pressurized to Pt (24.05 psig) for the reduced pressure test. Both reduced pressure and full pressure tests were conducted to meet 10CFR50 Appendix J requirements. A temperature stabilization period of approximately five hours preceded the reduced pressure
' leakage measurement.- Laakage data was taken for 25 hours at Pt to ensure
- sufficient data was contained for a reliable test indication. At the end of the reduced pressure test, a verification test was performed by superimposing a known leak of Le for approximately eight hours. -
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The containment pressure was next increased to Pa (48.1 ps'ig) for the peak ! pressure ILRT. A temperature stabilization period of five hours was allowed
.,, prior to taking leakage data. The leakage measurement was started but was
, 2, terminated after about nine hours when it became apparent the leakage rate was f
excessive. The containment was again depressurized to 12.5 psig to allow entry. A number of valves, packings, and fittings on the steam generators were found_ to be ladine and were tightenea. ' The containment was repressurized to Pa to start another leakage measurement. Another five hour temperature stabilization preceded the leakage measurement
and the test was once again terminated after about 20 hours due to an excessive :
leakage rate. The containment was completely depressurized this time to allow more time for leak repairs. All four steam generators were choroughly checked
',, and various leaks repaired on them. Also, the ventilation penetrations were local tested to ensure that leakage through them was not the problem.
After about sixteen houts at staospheric pressure, all checks and repairs were completed and the containment once again pressurized to Pa. This time a six hour temperature stabilization period preceded the leakage messurement. The, leakage data was taken for 25 hours and then the verification test was started by super-imposing a known leakage of La. The verification test was delayed about three hours due to a computer software error which incorrectly limited the super-imposed leak. This error was found and corrected and the verification test completed after six hours. The containment was then depressurized to 5 psig for a Hydrogen Purge System preoperational test and ,
'then to atmospheric pressure to complete the ILET.
%; After complace depressurization of containment, a post-test survey was conducted to check for any possible damage or abnormal conditions. No -
deficiencias were found during this inspection. c During the reduced pressure test, an electrical penetration was observed to be leaking excessively and its vent p1TTi was isolated. This penetra_ tion was lefe _ isolated during the peak pressure test also. Additionally, two; acre, electrical penetrations were found leaking during the peak pressure test and their vent,
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paths isolated. Af ter the ILRT, the penetrations were pre-repair local leak
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tested. Penetrations E-49 and L-gL,showed a =4n1==1 leakage rate, while - penetration E d was 118 SCCM. Penetration E-62 was repaired and the l post-repair leakage was less than 2 SCCM, which is acceptable. Fenetrations E-49 and E-68 lov leakage rates indicate a uni-directional leakage path since the local. leak rate test is conducted in the opposite direction of the ILRT. These two penetrations have high voltage power cables in them whereas the other penetration E-62, which was repaired, has smaller control cables in it. - A determination of the leakage mechanism in~these two penetrations has as yet not been determined. Further testing is forth coming and the results and necessary repairs will be a supplement to this report. _No other penetrations, electrical _ . or mechanirsl. required isolation during the conduct of the TT ny
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3.0 Plant Conditions E During the ILRT, the plant was maintained in a mode similar to that which would be expected during a. periodic ILRT. To simulate post accident conditions, all l systems that would not be expected to be fluid filled post accident were drained and vented to the contain= ant atmosphere. The containment recirculatibn cooling units were in service.to support ILRT testing and their corresponding penetrations were not drained or vented. The local leakage rate. values for these two penetrations are additions to the measured UCL. The reactor coolant system (RCS) was filled to a level of 35 percent in th.e pressurizer and the RCS was vented to, containment through the pressurizar power operated relief valves. One train of the residual heat removal (RER) system was in recirculation to the RCS to sinnlace core cooling and to provide letdown for the reactor coolant pump seal injection system which was in service. i During the entire test, the containment recirculation fans, whose blade pitch had been reset for the denser air, were in operation to provide containment atmosphere miring. This resulted in a very small variation between temperature and dewpoint readings throughout the containment. To prevent the introduction of temperature variances-during the ILRT, the chillers for the cooling water to the containment recirculation fans were secured. All pressurized tanks, i.e. accumulators were depressurized and vented during the ILRT. Also, all compressed gas sources were removed from the containment, i including fire extinguishers.
~ The electrical penetrations, which normally have 60 psig nitrogen gas applied between their seals, were depressurized to ensure no leakage of the nitrogen into the containment building. Each penetration was vented to atmosphere to provide a leakage path should the seals in the penetration assembly leak.
As an added precaution against possible fires, all equipinent in the containment building not needed for the test was de-energized from outside the containment i building. Also, all lighting in containment was turned off during the test. 4.0 Pressurization Svstem The containment was pressurized through an ILRT dedicated penetration, MIII-30.
, This is a twelve inch penetration through which the containment was both pressurized and depressurized. See Figure 2 for an illustration of the pressurization system.
A rental fleet of air compressors was used to supply the pressurization air. . The air compressors were arranged in two banks, each of which connected to a
' coalescing filter for hydrocarbon removal. These were connected to a pair of '
air dryers which conditioned the incoming air to maintain a 40*F dowpoint. The two dryers were connected to a common desister and then through an eight inch line to penetration MIII-30. Also attached to this eight inch line is a blowdown silencer for use when depressurizing the containment. Inside the g,, contain= ant, a flow diverter was attached to the penetration to prevent the g high velocity air flow from impinging on any equipment.
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. 9 5.0 Instrumentation System The instrumentation system for ILRT was based around a mini-computer contround
/ ~ data acquisition system (DAS), see Figure 3. The DAS is capable of reading.au sensors rapidly, storing the information and then outputting to the mini-computer for conversions and calculations on the data.
A system of 13 deweens and 42 resistance thermometer devices (RTD) was installed throughout the containment as shown on Figures 4 through 8. These locations were selected to provide through coverage of the containment in order to provide an accurate representation of wet bulb and dry bulb temperatures. Each sensor was assigned a volume fraction and the containment average wet bulb and dry bullr temperatures were then computed. Just prior to closing the contahumat building for the ILRT, .a . temperature survey was conducted. This survey verified that the location of the temperature sensors was correct for each of the assigned volume fractions.
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Connected to contah==nt penetration MV-7 were two precision qdrcz pressure : gauges to provide the containment total pressure. The total pressure less the ' vapor pressure, with temperature corrections, provides a corrected containment pressure. Also connected to the DAS were an RTD, a devcen and a barometer for monitoring the atmospheric conditions outside the containment building. Two mass flowmaters were connected to the DAS to provide an indication of the superimposed leakage during the flow verification test, see Figure 9. H There were no instrument failures during the ILRT. i 6.0 Instrument Selection Guide The guidelines of ANSI /ANS-56.8-1981, Containment System Leakage Testing Requirements, were used to select the instruments for the ILRT. In addition, the formula from the Instrumentation Selection Guide (ISG) was used during the i ILRT to ensure that the data acquisition system accuracy was sufficient to provide reliable test results. This formula utilizes the systematic error of each sensor to determine an overan value for the system. At the start and and of each test, the ISG value was acceptable if it did not' exceed 0.25 La. 7.0 Calculation of Leakate Rate . 7.1 Laakage Rate Test: - The method chosen for leakage rate calculation was the Absolute Method as ' recommended by both ANSI N45.4-1972 and ANSI /ANS-56.8-1981. This calculational technique was applied to the " mass-plot method" to determine - the containment leakage race. g
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In the mass-plot method the air mass inside containment is determined absolutely, utilizing the ideal gas law, at each time point and a least
/ squares analysis is used to estimate the leakage rate. For each time point (ti), the corresponding mass of contained air (Wi) is determined directly from the ideal gas law:
Wi = 144V (Pi - Pvi) R T1 V - Containment free air volume
.. R - Gas constant for air P - Containment total absolute pressure Pv - Containment water vapor partial pressure T - Containment mean absolute temperat.ure The linear least squares fit of the total number (n) of mass points is given by:
Wi = Ati + B Where the slope (A) and intercept (B) are given by: A = n GWiti) - MWi) (Sti) " n(2t1 ) - (s.ti)' and B = (IWi) (Itg a ) (ygggg) geg) n(Eti") - Sti)^ The leakage rate is then expressed as the ratio of the rate of change of mass and the mass in cone =4a=-at at time ti=0: Las = (-2400) (A/B) %/ day A = Mass rate of change B = Initial contained mass
- 2400 Converts to %/ day The Upper Confidence Limit (UCL) is established such that there is only a five percent probability that the actual leakage rate exceeds the UCL value. This value is approximated by:
UCL = Las + 2400 c.95,SA/B' t.95 = 95th percentile of Student's e distribution SA = Estimate of the standard deviation of A E ~ gg: 7--...y- . a %. .. ., i .. ; u; ;, ,i ~ 5
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, 7.2 Supplemental Test:
4 . r/ " The supplement test was conducted by superimposing a known leak onto the
/* existing leak. The known leak. (Lo) was in the range of Lt or La as appropriate. The supplemental test is acceptable provided that the composite 1cakage (Lc) is within 20.25Le or 20.25La of the sum of the measured leakage Les or Lam and the superimposed leakage Lo.
8.0 Data Analysis The results of both the reduced pressure and peak pressure ILRT's .tre tabulated in Appendix A and B respectively. D.aring the test, data was taken at fifteen minute intervals'to provide sufficient data for a good confidence level. 8.1 Reduced Pressure Test: After pressurization to 24.05 + 1 psig a temperature stabilization period was started which lasted approximately five hours. The containment atmosphere was considered to be stable when the last hourly average temperature was less than 20.5*F different from the average temperature over the last four hours. The ILRT measurement was begun and lasted for 25 hours. J The reduced pressure test resulted in a measured leakage rate (Ltm) of 0.02026%/ day with an upper confidence limit (UCL) of 0.02559%/ day. Adding the penalty leakages. Appendix D, does not alter the UCL since the penalty leakages are so small. The UCL of 0.02559%/ day is less than the allowable ' leakage 0.0272%/ day (0.75Lc).
, Lt was determined by the formula from 10CFR50, Appendix J:
Lt = La (Lta/ Lam) Le = 0.1%/ day (0.02026/0.05579) Le = 0.036315%/ day The reduced pressure test is therefore acceptable since the UCL is less " ~ than 75 percent of the allowable reduced pressure leakage (Lt). A verification test was subsequently performed by superimposing a leakage rate (Lo) of approximately Lt. The resulting Lo was 0.06864%/ day with a composit's leakage (Lc) of 0.09482%/ day. The acceptance criteria f'or the composite leakage (5.c) is: - Le = (Lo + Lea) 2 0.25Le %/ day . - Le = (0.06864 + 0.02026) 2 0.25 (0.036315) %/ day. -
- Le = 0.08890 1 0.0091%/ day
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The verification test is therefore accept.able since the composite.laskage Lc (0.09482%/ day) is within the required values, and this then provides
.F c'nfidence o that the data acquisition system is functioning properly.
8.2 Peak Pressure Test: ' The contain= ant was pressurized to 48.1 + 1.4 - 0.0 for the peak pressure i test. The first test was terminated early due to excessive steam system boundary leakage. The containment was again pressurized and during the conduct of the second peak pressure test it was noted that there were
. large variations in containment air mass occurring. Upon ensining the raw data. 1; was observed that humidity element (E) number 10 was varying several degrees. These changes were occurring at the same times as the-
. large air mass changes. Upon checking the volume fraction assignments, it was noted that E-10 was assigned 56.8 percent of the total containment volume. This large volume fraction was causing the large air mass changes to occur in accordance with E-10 changes. The volume fraction was reassigned such that four other groups received a portion of the volume fraction leaving HE-10 with a more representative volume. The computer program was updated to rsflect these changes and no further problems were observed. See Appendix C for the volume fractions.
The second peak test was also terminated early due to an excessive leak rate. After complete depressurization for repairs, the containment was again repressurized to peak test pressure and the temperature stabilization period begun. The containment atmosphere was considered to 6 be stable after approximately eight hours. The extra time for
@,,. stabilization was allowed to ensure a good mixing of the containment atmosphere because of the prior depressurization to zero psig. The average temperature change at this time was less than 0.1*F.
The peak pressure leakage rate measurements lasted for approximately 24 hours resulting in a measured leakage rate (Lam) of 0.05579%/ day and a UCL i of.0.05936%/ day. The allowable leakage rate (La) is 0.075%/ day so the j leakage rate appears to be acceptable. The penalty leakage Appendix D, has not been added to the UCL pending the results of the post-repair leakage rate for the three electrical penetrations which were isolated during the conduct of. testing. However, the test results appear acceptable since the difference between La and UCL is 0.01564%/ day which is greater than 3.8E06 SCCM. This is far more leakage than would be added since each electrical penetration is allowed only about 2 SCCM leakage.
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UtaIFICAllDN LEANACE VESI REAL TIME.83sel.29 83 39 05 , CDHrulEs DAIA s. seeeetestsee TIME 8080040000s0000 000 IEHrERAIUAE se seat raESSumE este tegegesessees Ltngagg negg gaggggga ,,,,,,,,,,,,,,,
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3.750 15.000 73.115 57.573 63.509 0.2374
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73.409 57.599 63.549 9.2354 .99&26 .87744 g lt 08 29 31 39 06 4.250 85.000 73.830 57.745 63.509 .32704 (= . 8 6611 (= .87704 89 08 29 11 54 05 4.500 85.000 0.23&3 .99627 .1270s to .86191 (= 20 73.872 57.495 63.511 0.2348 .49627
.87705 og 08 29 12 09 06 4.750 15.000 73.875 58.252 .12706 (= .15006 (= .47706 28 08 29 12 24 05 5.000 63.588 0.2406 .09&28 .12706 to .86050 (=
85.000 73.183 57.598 63.511 0.2350 .57706 ) 22 31 29 12 39 06 5.250 .09630 .12709 (= .26489 (= 23 15 90s 73.806 57.506 63.588 0.2349 .99630 .37789 St.29 12 54 05 5.500 15.000 73.891 57.572 63.541
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25 73.214 57.489 63.588 0.2335 .89633
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! 15.000 73.286 $7.656 63.511 .44954 (= .477t3 4.2355 .99635 .42714 (= .84828 (= 17784 CONIAINMLMI MASS = 935745.555847 LDM -
= , 83
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i i VetleME FBACIIslee i42 IE t = 1 .54. 5 3 . Utst teME FRACTIcel iOA iE 2 = 25794 ( Utet tleqE TRACilllet f aM IE 2 = 257u4 . Utte tfME BRArlluse f em IE 3 l 90ListE FRACil006 FOR IE 3 = 37399 1 [ . = 37390 .. ,- UGLUME fRAcilest [Os JE 4 = 3e953 Unl uME I R Ac t ifies i nn IC 4 = 3e953 WettiME FRACileet 8 81R IE 5 = 43202 Una ssett ( R ACI E82e I silt IL 5 = 43202 WKlaME taACIIDM 9 04 IE & = i ' ' 9tM tNG $ 3 ACllitet S tut IE & = 154 % ,
$5456 1
veattait IRArsllW8Its It. 7 = 36456 wet tame $ 3 AC 8 3080 I DR IE 7 = 3&456 j j VHStaME IPAC688W Ipe IE 9 = 45919 UtntatE fAACiluesIese IE S = 45959 UniteME FRAcil000 f ta IE 9 = 19403. 4 s UW unr iRArisins lie iE 9 = 194 3 UOLuME FRAC: low f ue E le = i Usel llME IRAt:IltN4 f ees 8L 18 = 36ees lasse I Utettett :fRActities'Ite IE 98 = 24e325 UOlletE fBACIIDN IGR SE 88 = 29325
; eMst Intt Iltactitue least IE 32 = VUlleME FRACileN 80R lE 12 = $940
' 894e3 VOLlaME FRACileet ten IE 33 = (94.33 j
i i Unitseit IRACIll44 IIe IE 13 = 19403 e VOlHME FRACIInet (888 IE 14 = 2480% . g Usillegit fifACllHet f eet IE 84 = 24tes l'
- Utst isent IRAClllwa lose IE is = 194e2 4 UOLlaME FRACIIOed 5 0s iE 45 = $9402
~
Usel esse f e ACitIIe8 I tset 3C 36 = tuttJ WOLlaME f RAciteel f elt IE 16 = i S6ts3 Uts = 42865 VettaME FRACTIcel FOR IE 17 = 42005 W.t H,tu,t ,I R At,t itil,l S tin ic SL 17 = UOLl8ME fRACIlust (O = o te l - iE it IS, Yeto, ,oC R AC i i tM t. .ille f . iE i, = 4.ie.3 .5 m i= 5RACii ,F.R. i = .s.s.3 UeM uttE TRACIIIIe8 I tal It' 20 = 55393
= ue.E f =Cri.c 08 iE 2. = ss393 i
g 90t tht[ IRAClltNG It2 1[ 26 = 50052 UOLtlHE fRACil0N IGR iE 28 = 58852 i utst isME I R ACi t HH f ten IE 22 = UOttaME f RAciteet FDA IE 22 = 48803 p venticht IRACileN4 I Her l[ 23 = 4e.le
. VOLlaME FRAcileN FOR IE 23 = 180888 N
*
- 11 0883 UOLt3ME FRACiteel FOR iE 24 = 19403 "8 g WIIIIME f rAcitt#4 file IE 24 = 90Ll8ME FRAtil0el F0s TE 25 = 594e3 Ut4 twar (Retilius ItM IE PS = 894e.3 894 3 UntHME FRACII0ttEUR IE 26 = 86000 @
0 VeN INtE O PAC R Il48 a dMt if &*6 = S&See VOLifME FRACileet 5 01t it 27 = 19403 g Uts letti I Rht;lIllet f ull IE 27 = VIII tRIE I R ACI IlH8 I sis IE 2e 19403
- UtntaME fRACll0N 00R IE 28 = 207249 Q
= '2e7249 UOLL8ME FRACll0st IDet IE 29 = 288905 l Uqit teit IRArlitwe Ient IL 29 = 288905 UtElaME fRAcitelt TOR it 3e =
n i uttelmE tRAClllW fain IE 38 211985 i g = 281905 . UGLlaME FRACIION IDE TE 38 = 2066L4 ' Ysit te E FRACillW4 f te IE 38 = 2e&&e6 . 90LuttE f RActlitet fim 1E 32 Utn esteC IItActStus (De IE 32
= $78676
= 178876 .. WollaME FRAciteet FOR IE 33 = $78876
' Uts uME IRAClltile Its IE 33 = 178 76 VOLilME FRACTIOel f05 IE 34 s uen teME B RAClitWe f akt BE 34 = 171e0
, =
' 178 76 VOLUME FAACTIced FOR TE 35 = 473e76 1
! Veel t 8BAClitue IIIe IE 35 = .179.76 76 , , _
= 98594 Utst iRACIltW (De IE 36 = 98991 j ;
UsalutE IRACIIEN4 IIS IE 37 = 73465
. WOLUMEWOLUME FRACileet (RAcisset FOR Ik 3750R DE 36 '=~73465
) l Uut ifME TRACilING f em IE 3e WellIIEE f R4C11000 FOR DE 30 = ' 73465 j
= 7J465 VOLINE FRattless FOR IE 39 = 14869
% Ustt HMF FRACilen8 EUR 1E 39 = 848&T l Uen TIME IRActinH f em IE 40 = 14869 WOLUME FIBACil0st f ee IE 40 =~14869 Viillent IRACillut 812 SE 48 = 98895
- VOLMME FRACileet FOR 1E 44 ' = flett
.m -g s UseI HMt letActInst Ftes IE 42 WOLUME SRACileet FOR DE 42 = 73465
= '73465 UGLUME FRACTIcel FOR K 1 = $3653 gg VIIe Out I RACIlhee I DR K t = 53653
*"* g UIN INE IRACilHH IIIR K 2 = 63152 WOL LIME GRAciteet (OR DE 2 = 63882
% Utg 644 I RAC8 8Het I tm M 3 = D2855 WitustE FRACIION $081 DE 3 = S2855 90t time F R AC g less i Ese 3E 4 = 20325
= . - - .
VIM HttE I R ACf flME IINt K 4 = 28325 r*
* 's Ute We sRACIllus s ok mE $ = m2375 -
UtKUME FRACitostitM DE 5 VetunE sRACilun f ue oE & = eas7s
= $2375
. u VIN I8ME IN ACilt44 I tan SE & = 86575 *#
- I' T t
- Wst eleet IRACIIbet i tNI K7 = 98708 VettaME FRAC 3 5tset f us K 7 = 987et
;i< , g UHLUME IRACll0H f uR DE S = 647e70 Vieillett 51 AC8 8124 f ue DE S = 315561 i ,* v UIN INif IFAt;llt44 B ust DE 9 = 15456
,, VOLlaME G RAC fleel f ue DE 9 = 15456
'$ UsN HttE I RAC f Illel i test K 8 0 = 1.65754JE*6 VOLleME FRACitost it2 DE 80 = 3335 7 908 40str 8 R6Clllled I tiet K i1 = 382296 UOttaME FRACiteet FOR K 13 = 643795 41 ven IINE F R AC lllNe i tm K 12
WKINtE f RACileN FOR DE 12 = 406384 y
W. W E rR AC:line e in K 3 3
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74795 96206 [~ l VOLifME FRACIIDe0 FOR DE 13 = 427785 ul= 42 ucV- 43 Hr= 3
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, APPENDII D
,. g PENALTT LEAKAGE LIST Pentration Service Type C Leakage (SCCM)
MV-12 Chilled Water Supply 80 to Conesimmant Coolers MV-13 Chilled Water Return 500 from Containment Coolers MIII-30 ILRT Pressurization 20 Pipe Penetration MV-7 ILRT Pressure Sensi*ng- 10 , Penetration E-49 Electrical
- E-62 Electrical 2 .
~
E-68 Electrical *
*To be determined after further evaluation l
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INTEGRATED LEAK RATE TEST DATA ACQUISITION SYSTDi o ~ T.I. WEED GENERAL KURZ MODEL 145 INSTRUMENT EASTERN MODEL 505-9
- . PRESSURE MDL. SP 101-13 MODEL 653/611A MASS FLOW CAUGES RTD'S DEW CELLS METERS HEWLEIT PACKARD MODEL 3497A DATA ACQUISITION
# CONTROL UNIT HEWLETT PACKARD MODEL 3456A D
'IGITAL VOLTMETER -
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.n 5 LOCATION OF TEMPERATURE & DEW POINT SENSORS -
COMANCHE PEAK STEAM ELECTRIC STATION -UNIT 1 l Figure'7 .
* * . . LOCATION OF TEMPERATURE & DEW POINT SENSORS COMANCHE PEAK STEAM ELECTRIC STATION l Figure 8 .
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9 ' C* Supporting Documentation
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ICP-PT-75-02, Rev. 0
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- 1) Volume 2 - Computed & Raw Data (See binder)
Computed Data Summary Reduced Pressure ILRT
, First Peak Pressure ILRT Second Peak Pressure ILRT Third Peak Pressure ILRT .
Raw Data for Reduced Pressure ILRT
. Pressurization & Temperature Stabilization Reduced Pressure ILRT Verification Flow Test Raw Data for Third Peak Pressure ILRT Pressurization
, Temperature Stabilization Third Peak Pressure ILRT Verification Flow Test Depressurization
- 2) Volume 3 - Computed & Raw Data (See binder)
Structural Integrity Test Data Raw Data for First Peck Pressure ILRT Pressurization & Temperature Stabilization First Peak Pressure ILRT Depressurization Raw Data for Second Peak Pressure ILRT Pressurization & Temperature Stabilization Second Peak Pressure ILRT Depressurization
- 3) Volume 4 - ILRT Computer Program. Verification, System Operability
& Error Analysis Support Deca (See binder)
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ADDENDUM '
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JULY, 1983
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DOCKET NUMBER 50-445
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t During the Comanche Peak Steam Electric Station Unic One preoperational containment Integrated Leak Este Test (ILRT), two electrical penetrations, E-49 and E-68 were isolated due to excessive leakage. A special. test program was developed to
- investigate the reason for the leaking penetrations. The program has been completed, the reason for the leakage identified, and the penetrations have been
~
successfully repaired. j h special test program consisted of a two phase plan. Phase I tested a spara i electrical penetration and Phase II repaired the two leaking penetrations based on,.x -" I the Phase I results. -
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i A spara electrical penetration assembly (EPA), identical to the ones'in penetrations E-49 and E-68, was selected from the warehouse. The U A was local leak rate tested i (Type B) first and its leakage rate was minimal. A special test chamber was then I attached to the DA, see attached figure, so that the UA could be pressurized in i the same manner as it was during the ILRT (Type A test). When pressurized, the D A's leakage race was in excess of the asasuring capability of the leak rate monitor. j h leakage was coming out from the nitrogen charge cube indicating leakage around - l the module Q-seals. , h DA was removed from the test chamber and disassembled for inspection. No defects,were found and the Q-sesis around the modules were decernined acceptable for reuse.%e unit was reassembled and upon inspection the Q-seal retaining rings were
- found to be seated to a greater depth chan before disassembly. The UA was attached i to the test chamber and again leak tested. Both the Type A and Type B tests were ,
j _ completed satisfactorily. This concluded the Phase I testing. *
, 3 1 -
l . N test results from the special i:est' program indicated that improper assembly of ' the DA was th's most likely cause of the leakage. Based on this, it was decided to l
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proceed to Phase II of the program. f.s}i.( N IPA's in penetrations I-49 and E-68 were determinated and unbolted from their i . i respective containment penetration header places. Each one was Type A tested using
- the special test chamber and found to be leaking excessively. Both were subsequently disassembled and inspected and no defects were found. The Q-seals were j determined to be acceptable.for reuse. Upon reassembly, the Q-seal retaining rings j were again found to be seated to a greater depth than before disassembly. A Type A
{ test was performed on each EPA using the special test chamber and each one's leakage
- l l
rate was satisfactory, less than 2 SCCM. After reassembly into chair respective penetrations, a Type B test was conducted and. each EPA showed less than 2 SCCM leakage. l l This concluded the special test program and shows that improper assembly was the i, cause of leakage in penetrations E-49 sad E-68. Since a simulated Type A test was { successfully conducted on each penetration af ter reassembly, no further Type A 1 testing is warranted. I if ~ l M % G R ?. G y y y
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n s Appendix D to the ILRT report can now be completed by adding the 2 SC3 leakage to D.g , penetrations E-49 and E-68. Adding the total penalty leakage from Appendix D, 616 SC M or 4.0 E-06%/ day to the UCL value of 0.05936%/ day does not change the value of
. the UCL as already reported. Therefore, there are no changes to the leakage rate
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B h . Annex 3 CONVERSATION RECORD Allegation Number AT-7 date: August 3, 1983 Type Visit Conference X Telephone __X__ Incoming Outgoing Name of Person (s) Contacted Organication Telepnone Number or in Contact With You Chang Li NRC Research FTS 492-9464 James Shapaker Manager, NRC Containment FTS 492-94?O
SUBJECT:
Integrated Leah Rate Test (ILRT) of Comanche Peak Unit . Centainment Structure.
SUMMARY
- The two principle areas of concern were al the tilr ee taciated electrical penetrations and b) the relative merits of the two methods of calculating containment leak rate from the ILRT data.
Mr. Li explainad that the purpose of the pre-operational ILRT is to establish reference values for both total containment leah rate (type A test) and for each individual penetration itype B lest). It is necessary to know hcw isolation af the three electrical penetrations ses accomplished. Mr. Mackley e::p l ai n e d the construction of the penetratices and indicated that isolation was accomplished by c1caing 2 v21ve the.t vented the space between the inner and autor seal rings of the seal assembl,. He could nct e;: plain details of val.e layout and sligrment. He premised to send more detail.
#egaritng the method cf calculating containment leah rate from the
*ype A test data, ANSI M45.4-1972 (referenced in 10 CFR 50, Appendix J) it--attes a method called total time method based on computing tne Continued on page :
Name of Person Documenting Conversation: Arthur D. Mackley 3tonature 8* @ . Date: 4 '/-J'9 c7
'Isme(s) of Other Persons Who Were Present During Conversation
_ A /. A N. A* I have reviewed the summary of the conversation with the individual (s) camed belou and agree that it accurately represents the conversation. Signature of Person Providing Information #44 /I' File! Allegation Work Pachsge T
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0 (. ts' CCNVERSATION RECORD Page 2 Charg Li and James Shapaker August 3, 1934 centained air mass at the beginning and at the end of the measurem'ent period. The leak rate consists of the mass difference divided by the length of the neasurement period. ANS!!ANS 56.3-1981 (used by the appli: ant) describes a least squares fit method (frequently called the Msts plot methed? in which the :cntained air mass is computed at regular latervals throughcut the measurement period. A straight line is fit by least squares technique to the mass peints. The slope of the line is the leak rate cf the structure. Mr. Shapaker asserted and Mr. Msett!ey agreed that the results of the two methods of calculation are essenti2!!;' equivalent when the centainment temperature is stable during the measurement period. .
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'.' FOLDER NO. 35 Draft No. Date COMANCHE PEAK ALLEGATION WORK PACKAGE
.A TEST PROGRAM Category ) - Unit 2 Testing Allegation Numbers: AT-12 Statement of Allegation: Separate tests (HFT) should be required for Unit 2 since Unit 1 Tests will not identify construction / design problems in Unit 2.
Reference Documents: See source documents marked'on attached pages from allegation list. Source of Allegation: CASE motion for admissior, cf contention 26, oage 3, Item 10. Date Received: 10/13/83 The above information prepared by D. M. Hunnicutt/R. G. Taylor 6/5/84 Name Date Group Leader 2 2 6 ,,in 7 B +/ Name Date Assigned - Team Members KZMimia 7-9-64 Date Assigned Date Assigned Date Assigned Date Assigned lI', .,, F.y;, .,m. 3.; o A}of
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. ' COMANCHE PEAK OPEN ISSUE ACTION PLAN Task:
Ref. No.: AT-12
- Characterization: CASE contends that HFT for Unit I will not demonstrate the performance of Unit 2 in a like test.
Initial Assessment of Significance: CASE apparently believes there will not be an HFT for Unit 2. Source: Motion filed October 13,198 '; see folder 33 for copy of motion. Approach to Resolution:
- 1. Review FSAR for commitments.
- 2. Review licensee test plan and schedule for Unit 2.
Related Open Issues See folder 33 1 e 4 4 O
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! TEST PROGRAM ALLEGATION REVIEW CATEGORIES Cetagory Est. Mandays Allegation Package Assigned Schedule Subject to Complete Nos. Prepared to Open Close Remarks No.
- 1. Hot functional AT-1, AT-2, AT-3,
. testing AT-4, AT-5, AT-6, AT-7, AT-8 . 2. NRC inspection of AT-9, AT-10, AT-11 test program / AT-13 reporting
- 3. Unit 2 testing AT-12 l
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m. DOCKET NO. 5256 o - APPLICATION OF DALLAS [ PUBLIC UTILITY COMPANY POWER AND LIGHT COMPANY FOR AUTHORITY TO CHANGE ,, 0F TEXAS RATES [ EXAMINER'S ORDER CONCERNING MOTIONS DISCUSSED AT PREHEARING CONFERENCE HELD SEPTEM8ER 29, 1983 A Motion to Intervene was filed by Office of Public Counsel (OPC), represented byM The Motion was granted. The OPC also presented a Motion to Dismiss, which, af ter full argument, was denied, because the motion showed no leg'al reason why this case should be dismissed. The. OPC filed a Motion for Continuance which was also denied because the company refused to extend its effective date, and the case must therefore.be heard at the present time to meet statutory deadlines contained in the Public Utility Regulatory Act (PURA), Tex. Rev. Civ. Stat. Ann. art.1446c, 543(1980). Finally, CASE's Motion to Compel, angl applicant's Motion for a Protective Order were discussed. The Motion to Compel was granted. Applicant's Motion for a Protective. Order was denied because applicant did not show good cause for entry of such an Order and because no showing was made that exception should be made to the provisions of Texas Open Records Act, Tex. Rev. Civ. Stat. Ann. art. 625217a(1981) which generally provides, for open access'to public records. The answers which are to be p-ovided to CASE's RFI's are public records, and subject to the Open Records Act. Therefore, applicant's Motion is DENIED. [ ENTERED AT AUSTIN, TEXAS on this. the M day of September, 1983. PUBLIC UTILITY COMMISSION OF TEXAS
- ~
&hM ANC2ELA MARIE DEMERLE su,uL ADMINISTRATIVE LAW JUDGE
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4 okay, in the upcoming reorganization, O a .hae positi- w m y - ha d2 . 4 g I wi11 be the
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4 In reading your. vitae, I don't see that you have 7 ever been employed by DPEL. Have you ever been? l 8 A No, I have not. i 9 4 Since you are not, how did Dallas Power & Light ! l Q 10 decide to have you give the update on Comanche Peak? Why 11 did they choose you? ' 12 L Because of my current organizational responsibilitie:i i i 13 with regard to Comanche Peak. ' 14 currently, which 3.s thg. licensee. 15 Okay. G And what would your relationship be to 16 Dallas Power & Light? 17 A Now? 18 4_ I guess I am regarding in terms of interface. You 19 are not part of them, but you deal with them. Is that correct? I 20 A Yes. TUGCO is agent for Dallas Power & Light, ! 1 21 Texas Power,& Light and Texas Electric Service Company in the 22 construction and operation of Comanche Peak', as well as in 23 the* operation.of other lignite facilities around the state. 24 ' 4 So in a sense, you are indirectly employed by
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25 Dallas Power & Light, if you are their agent? KENNEDY REPORTING SERVICEINC. 7800 SHOAL.CREEX BLv0. 346 W AUSTIN. TEXAS 78757 15 tM 4u.137 _ ; _ ; 4 .. ~ _. % .m 1 -- , .; . .~..,----.m. ~ :. cam- e
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- crosd 9 'A iB14 m 1 4 That is just the report, and not the inspection.
. c, 2 Am I correct? l c
O 3 A I am not sure what inspection you are talking about.
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4 . 4 The ' independent assessm.ent. 5 A That is the report on the results of his independent! l 6 assessment. l i 7 4 okay. You should have a copy of a letter in front : 8 of you. , 9 I am about to pl&ce one in front of you. The h 10 pertinent identification is up in the upper left-hand corner. L1 Is that 8332? 12 ' A It is apparently referring to. Docket 50-44 5/8'3-32. i 13 4 okay. I would like(to call your attention to the l l 14 last page of that, page 8. Have you seen that page before?
)
d 15 A No, sir. 16 4 In your. testimony you talked about plant systems 17 being turned over, and then you talked about a number of ! l i e 18 successful tests being completed. i e 19 Page 8 basically gives an overview of all of the I 20 tests done .and tests yet to be done. Am I correct? l Well, page 8 refers to manning status, refers to
; 21 A 22 plant testing status.
23 4 Could you please briefly describe what an acceptance a 24 test is? 1 l g 25 A Yes, sir, if I could get my notes. 1 1 XENNEDY REPORTING SERVICE INC.
- 7800 SHCAL CREEx BLvo.- 346 W
(
) AUSTIN. TEXAS 78757 (5121 458 3297 1
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135
- cronn 1815 m t The question was to, describe an acceptance test?
1 2 4 Yes, sir. O 3 A An,accep m ca test is one form of test that we are - 4 performing at Comanche. Peak. The other type of test is a pre-5 operational test. 6 Q I was wondering if you could explain the difference l
< 7 between the two? '
i , 8 A An acceptance test is the kind of test that we 9 would normally perform on components or systems within a non-g 10 nuclear, a fossil-type power plant.
- 11 And this means that the individual components and !
12' their performance would be verified as to their operation, j 13 and, then, the system would be placed into service to provide l i l 14 initial system operation. l 1 . i
, 15 There,are no formal verbatim procedures required by i
- 1 l 16 NRC regulations to perform an acceptance test, as they are d
) 17 required on a pre-operational test of a safety-related system.
1 9 18 4 Are acceptance tests-l 4 19 A. Excuse me. I was not quite finished.
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l l j 20 , Mandatory plant testing is not required prior to l i 21 initial plant operation for those systems that require only
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) nd T6 22 acceptance tests.
t i l 23 l 1 l 4 24 ' l . l l - i l KENNEDY REPORTING SERVICEINC. l ; . 7800 SHOAL CAEEK BLvo. 346 W i AUSTIN. TEXAS 78757' j (512) 454-3297 l
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- Crocs 136 DPEL 1 4 Are acceptance tests,done only on turned over 2 items or turned over systems?
O 3 A Yes, by definition, if a system has not been turned . 4 over from construction to startup into operations, then ,
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5 startup in operations can't test them. They don't have 6 control of it. t 7 Could you please briefly explain what the term 4 l: 8 turnover means? l i 9 A Yes, sir. A turnover takes place when a system l l$ i 10 or a subsystem within the plant has essentially completed I 11 its construction phase and construction turns the 12 responsibility for that system over to startup in operations. 13 4 Let's assume it's a system work done by Brown & 14 Root and they complete it. So when they turn it over they i 15 give it to TUGCO. Is that correct? i 16 A That's correct. . 17~ Does this mean, then, that once it's turned over
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18 that all constructien is finished on that particular piece
~ 19 of hardware or system?
l 20 A No. There may.be a punch list on it, and after
- l 21 the particular test that's required for that system, whether ;
i 22 it be a pre-operational test or acceptance test, has been 23 performed, that test may identify additional construction 24 That's the reason you do the work that needs to be done. 1 test - is to validate that system's performance in accordance l ! XENNEDY REPORTING SERVICEINC: 7800 SHOAL CREEK BLVO. 346 W AUSTIN. TEXAS 78757 ($12) 458-3297 i . b . h4
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- crnen I with design specifications. * ,
2 4 I see. Is there some sort of criteria that TUGCO O 3.
- has that they ,would feel that a ' system - -
4 Let me withdraw.that. Lat.ma say has TUGCO.ever 5 rejected a system from a contract on the basis of the test? 6 A. You mean some Constructions craft? i s 1 I G.- Yes, sir. j 8 l .A Yes, I'm certain that over the course of the I 9 project there have been systems that Construction felt like 10 were. ready to be turned over.and'TUGCO wanted something 11 else done on that system by Construction before it was i 12 turned over, perhaps a valve handle was not as accessible i. 13 as the operator needs it to be so he can conveniently ,'
.i I4 operate the valve'. !
- 15 4 Is that. turnover - I 16 MS..DEMERLE: M I'm sorry to I -
interrupt, but this seems like an awfully general discussion 18
, about operations at the plant. Can you tell me how this 1
19
. s going to ultimately relate to the rate case?
20 y,,, 7.m just getting to the 21 ! cost right now. You are anticipating me. 22 MS. DEMERLE: Go ahead. 23 You stole my thunder. 24 MS. DEMERLE: I hope not. , O. 2s KENNEDY REPORTING SERVICE INC.
' 7800 SHOA1.CREEX BLVO. 346 W AUSTIN. TEXAS 78757 (5121 458-3297
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. 1 2 O In dealing with thesa' turnover operations, if O 3 TUGC0 accepts it and more construction w'ork needs to be ,
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4 done, who pays the cost for that extra construction or , 5 repair? 6 3, gem not sure what you mean by extra construction. t e l I Well, let's say that we have Systen X and.it's
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8 turned over and the tests find that there are five problems l l l 9 that need to be resolved and you have accepted it. Does' j i fh 10 this mean, then, that TUGCo pays for it - for the repair 11 and rework as a normal construction cost? I i 12 A. 6 I'm trying to. answer you and I want i ! 13 to be responsive, but you just introduced a whole new concept 14 that we haven't been h1H ng about of rework and repair. 15 What I'm talking about - you asked me, I believe, what is 16 turnover. g a 17 0 Yes. 18 A. Turnover takes place when Construction passes a ! i 19 system to Operations and says, "Here. We built it according l 20 to specifications. It is now ready for you to test and to . 21 operate." Occasionally, Operations will say, "No, we're 22 not ready to turn it over because there is an adjustment 23 that we would J.ike you to make or modifications we want you 24 to make before we take responsibility for the system, because j h 25 we don't have the capability to modify the construction. , KENNEDY REPORTING SERVICE INC-7800 SHOAL CREEK BLVO. 346 W
- AUSTIN. TEXAS 78757 (512) 458-3297 l
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- I That's your job, not ours." 'And I used in my example maybe t
l' 2 the accessibility to the valve in a piping system. Once l 3 -
! that has, been .taken care of to TUGCO's satisfaction, they i
4 accept the. system as being turned over .to them and they I 5 g begin their tests, whether it's a pre-operational test or 6 l an acceptance test, as the casa may be, dependine on the 7 . system. ,
~
8 And let's assume that these tests are being done 4 9 and we find out something that is drastically wrong with 1 h 10 the systam that has been turned over and it needs expensive 11 repair. l 12 would a contractor assume those costs because they were U remiss in their construction, or perhaps a vendor inadvertently. 14 was remiss, or does TUGCO have to pay those costs? U A. It would depend on the nature of the work that 16 had to be done and what its cause was. l'i g - Q. Let's talk about our valve. Let's say our valve 18
- was faulty and it wasn't caught in the operational test
~
18 or the acceptance test.
"O A. I,was not talklng about a faulty valve. I was .
21 talking about a valve that maybe the operator, who is 5' 9'" i : 22 tall, can't reach a . valve handle that is 6' 6" off the 23 ground. If they have built and designed to specs, but once 24 it was physically in place it became obvious to all in my g- 25 example that the valve needed to be moved down a little,.I e e
- KENNEDY REPORTING SERVtCE INC;-
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- Cross 140 Ypb5 I wouldn't characterize that as a major problem. It's just 2 the type of event that occurs when you are involved in a O 3 major construction project. Everything doesn't fit all the 4 eimg. -
5 0 Okay. I guess ny concern was is turnover an 6 economic term as well as an engineering one? Is there a l i I coint'in time when TUGCO basically - I'm sorry.
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Go on ahead j 8 and answer. i L No, it is not an economic term. It is a technical 10 term used in the progression and the statusing of the 11 physical development of the project. It was one among a 12 number of tracking mechanisms we have to track progress. i The fact that we have turned over 90 percent of the systems I 13 14 from Construction to Operations indicates the approaching I 15 completeness of the construction proce s', as an example, 16 as I testified to in my direct testimony. t M CASE would like to submit this 17 - l 18 document, 83-2,. as evidence in this case, as Exhibit No. 6. 1 i II MS. DEMERLE: This is the letter we were 20 previously talking about which refers to Docket No. 50-445 21 83-32. Are there any objections? 22 Mr. Wooldridge, do you have an objection? 23 MR. WOOLDRIDGE: No. l 24 MS. DEMERLE: Anyone else? 5 The. letter will be admitted. , KENNEDY REPORTING SERVICEINC; 7800 SHOAL CREEK BLVO. 346-W AUSTIN. TEXAS 78757 (512) 458-3297
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2 4 And this has to be ratested? That is what that says? O 3 A I don't know whether it has to be tested or not. , 4 G The steam generator No. 2 requires rehydro. That's 5 a test? I 6 A Assuming that- , 1 7 MS. DEMERLE: That's.on the 9--on both reports, j 8 .right? i 9- THE WITNESS: Yes. l 10 0 What would be the cost of a review test? Do you 11 happen to know?
- 12 A No, sir.
13 4 , Okay .' Isn't it true that the nuclear indust.y is , 14 having problems with the steam generator of the same type as 15 was planned to be used at Comanche Peak? 16 A. Yes, sir. There have been some problems with the 17 Westinghouse steam generators. o 18 4 Isn't it true that you are going to be required to l 19 either modify or run the generator at only 70 percent of power 20 if the modifications can be done?
- 21 A The modifications have been done.
22 4 They have been done? 23 A Yes, sir. 24 G When were they done? 25 A In July and August, I believe. Modifications to , i - XENNEDY REPORTING SERVICE INC. 7800 SHOAL CREEK BLVO. 346 W l . AUSTm. TEXAS 78757 (5121458 3297 . II
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*j 9-2M4m t eliminate the tube vibration in the ' steam generation in turn
- 2. was done in the summer of '33.
O 3 r quite frankly have forgotten the exact date because, 4 it was in the June, July, August time frame. About 120 tubes 5 per steam generator were expanded to reduce the vibration.
< i I
6 4 Was that done under a warranty?
. i 7 A. It was done by Westinghouse under warranty.
8 4 Does this now mean that the plant no longer has 1 9 that 70 percent restriction on it? i g 10 A The plant never did have the 70 percent restriction. 11 4 Never did? 1 , 12 A Well, if we had not addressed the tube vibration 13 problem,.there is.some reason to suspect that 17RC would have 1 14 put some limitation on our operating license, cut we were able : 15 to address-the problem, get an' engineering fu: and fix it in I i . . 16 the field before we' received a license. ! l 17 ! Now we expect a supplemental safety evaluation O 18 report frcm NRC just momentarily that signifies that they are 1 a 19 concurring with the fix. We reviewed it with'them, technical l, I
', 20 review of the modifications done.
i 5 21 4 Isn't it true that this is the first generator-22 that's been so modified by Westinghouse? j 23 A. I'm not sure'if.that's correct or not. I believe 24 there is a unit in Yugoslavia. g 25 4 Let me re-ask my question--first American unit?
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; KENNEDY REPORTING SERVICE INC.
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152 M Crono l-2M5m t A It may be. I'm not sure it would be the first one 2 in operation with this modification, though. There are a 3 number of others. , 4 The point that I wanted to conclude my answer with
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- 5 is the resolution of the tube vibration problem which was 6 identified in Westinghouse steam generators is not going to 7 have an impact on Comanche Peak, either cost-wise, . schedule- ,
8 wise, or any limitation on operations. . 9 4 It almost sounds like I have your personal guarantee g 10 that we can expect it to run at more than 70 percant capacity? gg A I have my testimony here for this proceeding that 12 . we have addressed the problem and have resolved any reason for j i 13 low limitation from the-steam generator tube vibratiore. I 14 4 By what capacity do you expect Comanche Peak to 15 run at? 16 A What capacity? l
. I 17 4 Yes, sir. ;
18 A In terms of capacity factor? gg 4 Uh-huh. 20 A Well, the average for Westinghouse pressurized 4 21 water reactors with full loop systems similar to ours is in
'22 the 60 percent capacity factor range.
~23 Quite frankly, I'm expecting TUGCO to do at least
' that well with Comanche Peak, hopefully somewhat better.
24
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g 25 . 4 Let me just direct your attention to one other item
-; . KENNEDY REPORTING SERVICE INC.
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. (512) 454 3297.
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Crom 153 1-2M6m on this punch list. 1 This is. item 477 S. i 2 A Excuse me. Which list are we on?
] 3 4 on the ,9/23 list. - .
4 A on the .last page?
! 5 4 Second to last page.
6 A. Excuse me. Would you tell me the item number, again? i 7
.4 0477 S.
I i 8 A Okay. 9 4 And I will give you a second to read that, g 10 Have you read it? 11 A I read the descrip' tion. 12 Yes, sir 7 I read it. i i i 13 4 My question is: What is TUGC0 doing at this late 14 date after the h'ot function test with a big hole in the pipe 15 in the main steam line? . I 16 A Well, if you go over to the " Remarks" column, it 17
, ~ would indicate to me that that has been repaired. I den't
.O 18 know when it was repaired, but I would have to assume it was l 19 repaired before hot functionals.
l Otherwise, you would'have i 20 lost all your steam out of the hole in the pipe. 21 4 I would agree with that, too, except this is an open 22 punch list. 23 A well, I'm not sure if it is or not. By,and large, 24 I would suspect that most of the items on here are open, but g 25 some may have been closed in the data base and not updated. KENNEDY REPORTING $UVICEINC 7800 SHOAL CREEX BLVD. 346-W AUSTIN. TEXAS 78757 l (512)458-3297 7 . . l p .:';n:c ;:: ;9 4;:,.g.;;j.{<.q;;p;,;p;;pg.;g(;;y,.,y:,;-w;p._
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. - Cross 134 9-22nm 1 This 'one indicates it has been repaired. Is it on 2 this list?
9 3 g Yes, it is, where 1.t says it's open. - 4 MS. DEMERLE: Once aga whet;her 5 it's open or not is 'of no concern to me. 6 well, if it's open it means that 7 we are going to have not only a big expense of repairing it, l i s : 8 but the hot functional test has to be redone . $ 9 MS. DEMERLE: About six months after the tests g 10 are run. 11 A If it's open, it just indicates that there's some f 12 finish work lefti to be done and in no way indicates any big 13 expense or repair work. That is a supposition. 14 4 To repair something like that, would you have any
.15 idea how much it would cost?
16 A No, sir. ! l 17 - 4 Do you keep track at all of cost of repairs done at ! O 18 Ccmanche Peak? ! 19 A We keep track of the expenditures required to start 20 up and operate the project. j 21 4 But you have no records showing if something has 22 been reworked or repaired; you have no way of knowing what the ,
- 23 expense is?
l 24 A Rework and repair is just a fundamental part of a l i 25 massive, complex construction project like a nuclear power plant l _
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2 physical undertaking. There are going to be occasions where fT
- 3 human endeavor *is involved that things, for whatever reasons, 4 aren't done right the first time.
And it would in no way be 5 supportive of the project to try to set up a massive accounting 6 system just to keep track of what it would cost you to fix 7 something or change something or modify something.
- cide 2 8 g So the ratepayers really have no way of knowing if
, 9 ethere have been reworks that have been done and how much they ! I
(} 10 pay for them?.
, 11 A By specific item, ho, sir.
12 a Total by system? 13 A Well, the total -- I think the thing to put into l 14 proper perspective is when the plant is completed, you look i e l 15 at the completed cost of the plant and compare that to the norm I 16 as I have done in my testimony on page-- l I 17 0 I believe it's on page 10. We 're going to get that 18 in a little bit. 19 L Well, if I could finish my answer to your question. i 20 The ultimate conclusion is the completed cost of 21 the project. And, based on its high level status of completion li 22 now, the anticipated completed cost of Comanche Peak based on I i 'l 23 current cost and schedules is well below the industry average i' 21 for nuclear plantg cqi)in.l4ll1 1jm j, i . , ([] .1 ' cran =3 ;.- - _ l - t i - WNEDY REPORTING $ERVICE INC l . D M.A4 ".744 i ..- :4.,
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9/24/83 DOCXET NO. 5256 APPLICATION OF - l BEFORE THE PUBLIC UTILITY DALLAS POWER & LIGHT CIMPANY COM ISSION OF TEXAS FOR A RATE INCREASE , , CASE'S SUPPLEMENTARY MOTION TO COMPEL APPLICANT TO PROVIDE PHOTOCOPIES OF DOCUMENTS BEIN8 MADE AVAILABLE TO CASE AT CPSES'IN RESPONSE ':. TO CASE'S'RFI'S"NOS. 6-12 ' AND 20
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NOW COMES CASE (Cit 1zens Association for Sound Energy), Interven$r herein, and files, this, its Supplementary Motion to Compel Applicant to Provide Photo-copies of Doctments Being Made Available to CASE at CPSC in Response to CASE's RFI's Nos. 6-12 and 20.
Background
On September 12, 1983, CASE filed its Motion to Compel Applicarit to Pemit Photocopying of Documents Being Made Availa ble to CASE at'CPSES in Reponse to CASE's RFI's Nos. 6-12 and 20. In a prehearing conference call on September 20, 1983 (set oh Monday, September 19 to discuss'its 9/12/83' Motion to Compel anii its 9/12/83 Motion to Compel Applicant to Supply Complete Information and Answers to CASE's First Set of Interrogatories and Requests for Information from Applicant), CASE's representative and Applicant's representatives discussed the granting of a protective order on the material at CPSES to which CASE had been granted access in the 8/22/83 Examiner's Order Ruling on DP&L's Objections to CASE's FRI's. . CASE had no knowledge of Applicant's request for such protective order I prior to the 9/20/83 conference call'and was, in fact, put in the position of having to argue against the protective order before Applicant even presented its grounds for the issuance of it (such grounds being that CASE might use the infomation obtained in the operating license hearings for Comanche Peak). The- conference call was exceedingly brief and was not recorded. In addition, Applicant's responses to CASE's motion on more complete answers wsn also briefly presented and orally ruled upon. Subsequent to .thagora( ruling order _,. _.-
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ing the granting of a protective order, the Hearing Examiner <has held the order t* &+;+~-
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.' Docket No. 5256 CASE'S SUPPLEMENTARY MOTION TU CMPEL PAGE 1 without signing it, pend.ing the prehaaning conference set now for Thursday, Septem-ber 5. At this. time tiie issues. of copying and c'f the possible granting of a pro-tactive order'on this. material will be argued by the' parties.
. CASE'S' REQUEST CASE hereby- requests that Applicant be compelled to provide CASE with a com-plate copy of each of the requested pages of documents appearing on a list that CASE will hand-deliver to DP8L on Monday morning. Apdlicants should be compelled to
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I provide.a etsplete computer orintout of the Master Punchcard List as up-to-date as - ! possible.1 (It is CASE's understanding that a computer printout of this docunent will be easier to run and cheaper to run than xeroxing the docunent.) CASE further requests that Applicant be compelled to provide CASE with all of these docuents at the beginning of the preheaHng conference which is set for Thursday, Septauber 29 at 10:30 a.m. in Austin. . (ItSis CASE's understanding that . in order for CASE to argue that it is entitled to such copies under the rules,for discovery that,these copies need to be at the prehearing confernoce. Also, should the Hearings Examiner rule in CASE's favor, CASE's repmsentativeiwould need to return to Dallas upon the close of the prehearing conference with the cooies in l hand in order to use then in preparation for cross-examination and to make the l l requisite number of copies to enter into evidence on Monday.)
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CASE intends to generate a sunsnary3 of the lengthy (approximately 2,500 page) camputer printout, listing' deficiencies, reworks, etc. by system. CASE intends
- 1 leien CASE's representative and an assistant- viewed documents at the site on 9/22, they were told that the Master Punchcard Li.st which they werd shown went only thmugh 5/25/83--and that this was the most current. list avaTlable. Based on other information, it is CASE's belief that many pitblems. have come to light at the plant since 5/25--and it is also CASE's understanding that the punchlist should be more
_ current than 5/25--i.e. it should be almost current. If Applicant insists that the la. test computer run goes only thnough 5/25, CASE requests that Applicant be compelled to provide CASE with.a sworn, written statement to that effect on 9/29 at the pre-hearing conference. -
-7 CASE's representative', Mrs. Juanita Ellis will begin this suumary on Monday,
- l. 9/26 in the DP&L offices in Dallas.
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'DOCXET NO. 5256
. CASE'S SUPPLEMENTARY MOTION TO COMPEL PAGE 3 to request Applicant ..;to stipulate to. the accuracy of that sumary on Monday, October 3 at the beginning. of the hearing. (It is CASE's understanding as'well
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that CASE can submit a summary of a document into evidence only'if the copy of the entire document is available at the hearing for the other pa,rties to review. Then, if anotheh p' arty so desire it may mye tha't the entire document, instead of CASE.'s prepared summary, be admitted"into eviderice.) CASE feels that this doctaient i - is essential as. it delineates many (but:not all) of the pmblems which are costing the ratepayers money--money which they should not have to pay in this or any future rate requrst by the Ccapany. CASE'S RIGHT TO COPIES In addition to the reasons that were listed in CASE's 9/12' Motion to Compel
. Applicant to Permit Photocopying of Documents Being Made Available to CASE at CPSES in Response to CASE's RFI.'s Nos. 6'-12 and 20 (see pages 3 and ff.), CASE would offer the following additional reasons why it is entitled to copies of the
_ requested documents by the rules:
- 1. The information contained in these documents is relevant in these croceedings.
This is. the ' central issue: either the documents are discoverable here or they are not. Clearly, as is stated in the Examiner's Order Ruling on DP&L's 05dections to CASE's RFI's (8/22/83) on page.1:
"Therefore, the examiner will presume outright that CASE is not merely gathering information at this Commission for use at the NRC. Even if this were so, as long as the information is relevant here, CASE's use of it at the NRC, as long as the data is not subject to a protective order, would be' of no concern to the Coeurission. The real inouiry here rust be: Is the infonnation relevant to this ratamaking oroceeding? -
The answer is yes, as explained below." (Emphasis added.) On pageh2 df the same order, the examiner continues: .
"The documents are relevant'in terms of the general issue of onJdency f -
of expenditures at the olant. Results of past tests may lead to some - conclusion on wnetner DP&L ratepayer dollars have been well spent at the ! . . . _ . _ _ plant. This imoacts the issue of CWIP and is relevant to the issue of the ,,,, i -- - _
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. - - - . . . . .-- . l DOCKET NO. 5256 ~
CASE'S SUPPLEMENTARY M) TION TO COMPEL PAGE 4 amount the Comerission should ultimately allow to be capitalized for ' Comanche Peak, which amy be addressed now, or at some time in the tae. future.7, (Emphasis added'.) ' -
. CASE simply notes that problems cost money to solve; reworks cost:: money, redesign costs money, reconstruction costs money. If the ratepayers are ex-pected to bear the burden of any 'or all of these problems being corrected, then .
the ratepayers have a right to know what they are being charged for and how , much it is costing them.
- 2. The fact that CASE might also'. choose to use any or all of this information in th's continuing NRC operating licensing hearings for Comanche Peak is irrele-vant. 'As the Exmainer has already stated on page 1 of her 8/22 orden: .
"Therefore, the examiner will presune outright that CASE is not merely gathering information at this Commission for use at the NRC. .Even it th.is were so, as long as the data is relevant here, CASE's use of it atrthe NRC, as long as the data is not subject to a.. protective order, would be of no concern to the Comurtssion." (Emphasis added.)
CASE, as the only remaining Intervenor in the operating license hearings for Comanche Peak before the U. S. Nuclear Regulatory Conurission, has an obligation to report anything which we believe may detrimentally affect the public health and safety. Further, we are under a continuing Board Order-(as are all parties in those proceedings) to report to the Atomic Safety and-Licensing Board anything which we believe may be significant pertain,ing to the matters under consideration in those hearings. For example, in a Board Order dated January 4,1983, the Board stated, regarding a CASE exhibit, the decision by the Department of Labor A&rinistrative Law Judge thatM had been fired illegally by Brown & Root for reporting nonconfaming conditions at Comanche Peak:
"Such decision contains important additional evidence directly connected with testimony already in our record. In fact, we are surprised that only the Intervenor called this matter to the Board's attention on December 14, 1982 and filed a copy on that date. We have previously admonished both the Applicants and the Staff that they have an affirma-tive duty to infom the Board promptly of new facts or developments.
/12/ (Footnote H2/ Order dated October 20, 1981.)" % ,
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00CXET NO. 5256 ' CASE'S SUPPLEMENTARY MOTION TO COMPEL PAGE 5 . The responsibility to report any matters which are potentially significant was again confirmed in the Licensing Board'c 9/1/83 Memorandum and Order.(footnote 3)., We am attaching copies of' the Licensing Board's Orders of January '4,1983, and September 1,1983. , It should be noted thati CASE has attempted to keep separated the operating license hearings and theiDP&L rate hearings for the most part, and we had ' 8 planned to introduce into evidence and question Applicant's witnesses regard-ing only a handful .of documents from the operating license hearings. However,
; Applicant's continual. allegations that CASE only wants documents in the DP&L rate hearings in order to use them in the operating license hearings for ! Comanche Peak forces us to bring these matters to the Hearing Examiner's attention. .
Applicant would have CASE gagged froar reporting any potentially significant matters discovered during the rate hearings -- cacced from reoortine them to the very agency (the U. d. Nuclear Regulatory Cosmission) which has been mandated by Congress to protect the oublic health and safety and to see tha~t nuclear-oower plants are designed and constructed in such a manner that the oublic health and safety will not be Jeocardized. CASE subarits that Applicant's efforts in this regard are for one purpose and one purpose only - to protect Applicant's from having to deal with deficiencies in management for which they should have, to answer in these proceedings, while
. at the same time assuring that they will not have to deal with those deficiencies i
in the NRC operating license hearings for Comanche Peak.
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- To place CASE in such an ubtenable position is bad enough.' However, to attempt to make the PUC a party to such unnecessary.. illogical, and perhaps even fliegal withholding of information from the NRC is even worse, and CASE urges that the Hear'ing Examiner and the PUC not fall for Applicant's ploy and thus become a
- party to such a questionable and perhaps even illegal maneuver., ... cyp l
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_ __ - _ _ _ _ _ . _ _ _ - _ ~ . 00CXET N0. 5256 CASE'S SUPPLEMENTARY ICTION TO COMPEL
. PAGE 6 CASE simply cannot both comply with the proposed Protective Order and at the same time. fulfill its abiigations as an Intervenor in the operating licensing hearings for Comanch' e Peak. It is. gmssly unfair to ask that we attempt to do so..
Futher, Applicant has not and cannot show adequate grounds for a protective order, because noisuch grounds exist. _ Applicant has ignored the fact that CASE was an Intervenor in all DP&L rate hearings since 1974, locally before the PUC was formed and in every rate case after-wards.. This was some five years before we wem accented as an-Intervenor in the operating licensing hearings for Comanche Peak. Thus, it is clear that oue concerns regarding rates predates our intervention in the operating licensing hearings; j and a review of the record of those earlier rata hearings reveals that we have actively participated in all of then-not only regarding Comanche Peak but also regarding other areas such as. rata structures, ete. Although we have been forced to severely limit our participation in the present DP&L rate case because of our l other caemittments and will have to concentrated on the one area about which we have more knowledge than probably anyone else in the State (even- the PUC)--Comanche. Peak--our concerns reganiing rates and rate-setting are still as gnat. In conclusion, CASE should not be penalized and placed in such an untenable position because we are concerwd not only' with rate-setting but also with public health and safety., There are two distinct and separate foruns for expressdng these concerns-the PUC for rate-setting and the NRC for public health and safety. The j PUC should not be a party to assisting the Applicant to hide any safety-related problems which may be uncovered during discovery in these proceedings-problems i ! which (if uncovemd) should properly be called to the attention of the Atomic Safety and Licensing Board of the Nuclear Regulatory Commission in order to safe-
- guard the public health and safety. Nor should the public be kept from knowing how much any repairs,.' redesign, modifications, mconstruction, etc. are costing l th em. -/ - - - -
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. DOCKET NO. 5256 CASE'S SUPPLEMENTARY MOTION TO COMPEL PAGE 7 Additional Arguments Against the Granting of a Pmtective Orcer on Documents In addition to.the arguments, against the granting of a. protective order on these discovery documents in CASE's 9/12 Motion to Compel Applicant to Pennit Photocopying of Doctaients Being Made Available to CASE at CPSES in Response to CASE's RFI's Mcs 6-12 and 20-and in addition to those argunents given on pages 3 and following, CASE would offer 1:he following additional reasons why such a protective order on this material should not be granted:
1 Applicant has shown no good cause nor oroner groundt for the granting of a protective order. According to ble 186b of the Texas Rules of Civil Procedure (1981 edition) it states that:
. . . that secret processes, developments or research need not he disclosed, or . . . ta protect the party or witness from undue annoyance, enbarrassment, oppression, or expense "
At no time did Applicant cite any of the reasons listed above for the reason for granting their request for a protective order--either in the August 18 prehearing conference in discussing objections to these RFI's, or in any written motion following the Hearing Examiner's 8/22 order, nor in the prehearing i conference call of 9/22. They merely reiterated the same assertion which was I ruled against by the Hearings Examiner in her 8/22 onier that CASE intended to i i use the infonnation rin the NRC operating licensing hearings--and that it would ta too burdensome to produce... (See Order dated 8/22, page 1.) The argiment regarding relevancy and irrelevancy is covered in this motion on prior pages. The argument regarding cost is covered in our 9/12 motion. (And, . it should be noted, the cost of a computer mn of the printout desired is supposed to be much lower than the cost oit xeroxing it.) While it may wel:1 be annoying , for Applicant to have to produce these copies--or even moreso, embarrassin'g-these reasons hardly have bearing in a hearing regarding rates when the Applicant is . a corporation-not ansindividual. ,
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. DOCKET NO. 5256 CASE'S SUPPt3ENTARY MOTION TO CCWEl. PAGE 8 Nor is the information or the documents proprietary in naturit. These are not secret " processes, deve'lopments, or'research." These are tests and
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lists of tests and reworks, etc. It is neither patented nor a 'trad's secret. Nor, since DP&L and its sister cogadies are regulated monopdlies with _n_o, o
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competition in its service area for electric service (unlike Southwestern Bell who has competition in the long-distance area from other companies), does - the idea of camercial information that would be of use to competitors apply here. Applicant has not stated in any forus or motion or answer to any of these RFI's regarding these documents that the problems associated with these tests, etc. are associated with costs which are being capitalized--and thus do not appear in this rate filing package'. Therefore, CASE and the other parties to this pro-cedding must assume that these costs for modifications, reworks, etc. jjo_ appear in this rate request-and that, therefore CASE has the right to these copies and the public has the right to know about the infonnation therein-without the gag of a protective order being placed on them.
- 2. Applicant's request for a protective order is illogical. Not only does Appli-cant have no showing of good cause for the issuing o'f such an order, their request would be hunerous if the issue were not so serious.an attempt to block the ratepayers
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from knowing vital information related to the amount of CWIP being requested in , this hearin'g. By their contorted logic. Applicant's are requesting thatthe very docunents cited by their own witness as evidence proving Applicant's case in prefiled testimary(which is itself public record) be placed ~under this protective o rder. Therefore, if CASE were to have to cross-examine Mon th6se documents in the hearing, it would have to do so sealed from public view if such an order were granted--but.his testimony characterizing them would not! In addition. Applicant's request raises a point of . simple. logic: If the
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. 00CXET NO. 5256 CASE'S SUPPt.EMENTARY MOTION TO COMPEL PAGE 88, tests am indeed proof of Applicant's position, then surely Applicant's would went to ensuWthat the tests and the test results be mada public. If they are
' evidence for Applicant's position, why would Applicant wish to hide them7 In addition, if the tests are what' Applicant claims them to be-how could CASE
. possibly use them to support its contention in the operating licensing hearings of shoddy workmanship, ignoppe engineering, etc. in the NRC hearings? For, i f the tests are indeed OK, they could, not possibly pnave CASE's contentions, and CASE could not use them.there.
Only if the tests are -not alright--only if there are indeed.. problems either in the tests themselves or problems uncovered during the tests does Appl.icant's request begin to make sense.' Only if the. tests do not prove Applicant's points would Appifcant's then seek to keep them from public viewt ' And only if the tests am not alright could CASE use them to advantage in the NRC hearings. Therefore, if Applicant's insist thab these documents not be made public and that a protective order be granted, the general public is - free to speculate that these tests do not support Applicaat's position, but may, in fact, contradict i t.
- 4. The request for the granting of a protective order is untimely. As of the date of the Hearings Examiner's 8/22 Order, Applicant' chad not filed a motion requesting a. protective order on this material. Nor did Applicant ask for one on this infomation duMng- the prehearing conference of 8/18. (Applicant did, however, arg'ue that tHe contracts' requested by CASE in RFI No.114 were proprietary in nature and that they would move for a protective order to be
,, granted _ on them. Therefore, CASE rewrote'RRENo. '114 to ' avoid the" necessity ,
of signing such a protective order.) Nor did Applicant file a motion for a protective order upon receipt of the Hearings Examiner's 8/22 order--the logical latest time for them to have done o. ' ~ . .-- __ _ ~ s ee. < ....ase.-- , _ 'a% y .e. ,ew k l y . , p&., . w sm ee . - yy. _.e. u.~.a.o.a. . m. m . m e .. . m
DOCKET NO. 5256 CASE'S SUPPLEMENTARY MOTION TO COMPEL PAGE 9 .
.No, nor did Applicant file- for such an order prior to CASE's representatives first visit to the..plant to view the documents in question. ~When CASE's .
representatives viewed the doctments on 9/5'(and again on 9/22) they were not under any protective order. CASE could have called a press conference based on 1 its notes of at least tha.first day of vieving documents there without 'having violated aporder. CASE believer that Applicant is attempting to get such pro-taction retroactiyely. Nor can Applicant argue that there is any qualitative difference in the
~
doctments which CASE's representatives viewed.on either day--nor of any which they have not yet viewed. It was only upon leaniing that CASE had filed and mailed on 9/12 its Motion to Compel regarding photocopying that Applicant apparently verbally indicated its intent to request a protective order on the doctments from the HeaMngs . Examiner. Quoting our 9/11 Motion on photocopying CASE reiterates its response to this:
"If Applicant chooses to do so now, it merely highlihhts Apolicant's attamot (to) prevent this information from being presented in this hearing ano from being placed under the scrutiny of its ratepayers. CASE's reply to this
- calculated foot-dragging on this essential data is
- What does DP&L have to hide?"
- 5. CASE is a citizens' group. As a citizens group comprised wholly of volunteers, CASE has long been concerned with the public's right to know. CASE has avoided becoming entangled in protective order agreements in the past (even in this very hearing on RFI No.114), feeling that the public's right to know that which affect's it either in its pocketbook or regarding its safety and health is paramount. CASE has always been primarily concerned about infaming the public of the problems and the associated costs of those problems at Comanche Peak--thus we would oppose any. curtailing o'f the public's right to know what they are paying for and why.
. 9 a "
-- . _ _ . . -.~ . _ . . . . _ . _ _ _
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- e 00CKET NO. 5256 CASE'S SUPPLEMENTARY MOTION TO COMPEL PAGE la .
CASE feels 'that Applicant has a history of denying the existence of problems at the plant--much less the existance of the costs associated with' solving those ppchless. CASE. needs these documents--copied and accessible to the public- to establish the existence of those problems in the 'public record; only then can CASE move on to establishing the costs of these neworks, redesigns, etc. Each redesign, each rework, etc. has a corresponding pricatag attached. The public needs to knoW what these are. . CONCLUSION For all of the reasons. listed in this motion and in CASE's 9/12 Motion to Compel Applicant to Permit Photocopying of Doctsnents Being Made Available at. CPSES to CASE ~ in Response to RFI's Nos. 6-12 and 20, CASE requests that Applicant be compelled'to: -
- 1. Provide CASE with a complete copy of each of the requested pages of ,
doctarAnts appearing on a list which' CASE will handdeliver to OP&L on Monday morning, September 25 (and will mail to all parties the- same day)--including
. a complete computer printout of the Master Punchcard List as up-to-date as possible. .
- 2. Provide CASE with al.1 of the documents listed in Ite I above at the beginning of the prehearing confernence on Thursday, September 29 at 10:30 a.m.
CASE wot$1d also request that Applicant's request for a protecti've order be denied. , Respectfully submitted, h h (A k ' (Ms.) Barbara N. Boltz, Boardnamber D CASE (Citizens Association for Sound Energy 1426 S. Polk. - Dallas, TX. 75224 (214)339-4979 (home); (214)243-6191, ext. 521 (work)
~
Dr. David H. Boltz, Boardnember _ __ T _ . _T ~_ ~P W * M~'^^~*"*
e . CERTIFICATE OF SERVICE By my signature below, I hereby. certify that a true and correct cocy of CASSit .suopcm swness n com/fc. Aafeten- o7vi pwi c4. Amm/Mof Docume MtM Mos /9vAccam fc/sfr w A19Aut D c+t< /Mhttr n/ac.s. tta~4.; in Docket No 5256 was mailed this s2./ day of 8M , 1983, first class United Sritas mail, except for the names marked *(*) which ware sent by Cartified Mail. Rdeurn Receipt Raquested, to:
- Mr. Robert A. Wooldridge Worsham. Forsytha & Samplee 2001 Bryan Tower. Suiza 2500 Dallas, Texas 75201
- Mr. Galan Sparka - Assistant City Attorney 7DN Dallas City Hall 1500 h eilla Scrset Dallu . Texas 75201 Peggy Wells Dobbins St.,Regis Corporation 237 Park Ave.
- New York, New Tork 10017 Ma. Martha.V. Terry Actorney for Texas Retailers Association Davis & Davis. P.C..
P. O. Box 1588 Austin, Texas 78767 ; Mr. Allen H. King General Counsel Public Utility Commission of Texas 7800 Shoal Creek Blvd. Suite 400 N Austin, Texas 78757 Mrs. Juanita Ellis CASE - Citizens Association for Sound Energy 1426 S. Polk - Dallas Texas 75224 (original) Ms. Angela Demarla Williams Hearings.Fwm=iner . Public Utility Commission of Texas 7800 Shoal Creek Blvd. Suite 400 N Austin. Texas 73757 __ _ / //4fM r < g CASE Boa'rd Member , 2012 S. Polk l Dallas. Texas 75224 [ 214/339-4979 214/243-6151 X. 521 (Ms. Boltz) 1 . _m m _" ]*__ D E _ D_ h **"d _g
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ATTACHMENT A CP-SAP-16 h ~ Rsvision 6 QA TEST DEFICIENCY REPORT Page 8 of 8 qD C System Name: O Mf M leal V/)/_t)/yld CO/Y7f0(_ ** Page / of / {} Component Tag No: CS-I- 1 OR - 7 07-642R Safety Non-Safety Startup System No.:MfC/ Test Instruction / Procedure No.: 16[-M7~- M-// DESCRIPTION OF DEFICIENCY: WlAfA <f J##C& fA;4C, NOT I M AT-A I I r:n ~PR u n g 7'n H 1:T-I I I Component Operation May _ May Not continue until Corrective Action is complete: CORRECT 1VE ACTION: fu gi isLt - Lp;+ar Aerci2 /-/FT {l REQUIRED RETEST: NONf Initiated By: [M NANE / Date: 8-M- 83 Engineering Evaluation of Deficiency Required: Yes [ No . Reference Documents for Engineering Evaluation: k, e-Corrective Action / Retest Approved By: -- */ Date: ["I/- O gead Startup Engineer Corrective Action Completed: ((, Ar 2w Date: 7 %-I3 Systemj,estEnggneer T Retest Satisfactorily Completed: /f## Date: ( Scrap Verified By: System Test Engineer o /4 TUGC0 QA Startup7 Turnover Surveillance Supv. Date: /1/A-Distribution: Original to Log TUSI Engidnering Manager Initiating STE TUCCO QA $Tartup/Turnov'errSurvje ilance Supervisor MSP Group O p e r a t ilo n s' .S u p'p'o r t' E n gi n ae #
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Initiated By: f.(f. M M Date: 2 7.,7-93 Engineering Evaluation of Deficiency Required: Yes { No . Reference Documents for Engineering Evaluation: . . Corrective Action /Recest Approved By: Av Date: MDU L d Startu/ Engineer i Corrective Action Completed: (( d Date: 9 M 3
$ystem Test Enginepr Retest Satisfactorily Completed: d//J Date: A-System Test Engineer l
(, ..- Scrap Verified By: Of 4 Date: .lf f TUGC0 QA Startup/ Turnover 'Survenfance ,SupvQ l Distribution: Original to Log TUSI Engineering Fanai;ep * ' 5 l Initiating STE TUCCO QA Startup/ Turnover Surveillance Supervisor i* 1 SAP-16-1 . it
N qD\ Rsvision 6 4A TEST DEFICIENCY REPORT Page 8 of 8 D qO ** System Name: O Rf th IeAL Vol_D/vf N d.ON7fOC. Page / of /
} Component Tag No: CS-I- I OR - 7 07-d42R Safety Non-Safety StartupSystemNo.:df0/ Test Instruction / Procedure No.: ,3'd[-M 7~~ ff~-//
DESCRIPTION OF DEFICIENCY: W l/*. m g>##Cd7"' fu 4c. NoT I tiWA I i 1:rs P R rn 2. Tn l-l W. 4 Component Operation May _May Not continue until Corrective Action is complete: CORRECTIVE ACTION: [n r/ fsu bpp-a/- NpTra M(( i REQUIRED RETEST: NONf Initiated By: N M b /I' N E [ Date: 8 -M' 83 Engineering Evaluation of Deficiency Required: Yes No . Reference Documents for Engineering Evaluation: k, Corrective Action / Retest. Approved By: I +
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Date: I~".I/-(( gead Startup Engineer Corrective Action Completed: d [. A r :- w -; Date: 7 74-P3 SystemjTest Engj[neer ~ Retest Satisfactorily Completed: A#M Date: ( Scrap Verified By: System Test Engineer o /o
/ Turnover Surveillance Supv.
Date: /l "//]- TUGC0 QA Startup' Distribution: Original to Log "D TUSI Engineering % nag pp e r.,^f a ;< % C Initiating STE TUGC0QAStartup/TdrnoverSurveillance.O ~ Tu
' pervisor MSP Vroup Operations Support Engineer
i . 9 SEP 2 71983 In Reply Refer To: . .' Docket: 50-445/83-36 . L Texas Utilities Generating Company ATTN: R. J. Gary, Executive Vice President & General Manager 2001 Bryan Tovier Dallas, Texas 75201 Gentlemen: This refers to the inspection conducted under the Resident Inspection Program by Mr. D. L. Kelley during the period August 1 - August 31, 1983, of activities authorized by NRC Construction Permit CPPR-126 for the Comanche Peak facility, Unit 1, and to the discussion of our findings with 7.essrs. J. T. Merritt, J. C. Kuykendall, and other members of your staff at the conclusion of the inspection. , Areas examined during the inspection included Initial Startup Test Procedure Review, Penetration Seal Installation, System Walkdown, Plant Tours, and Plant Status. Within these areas, the inspection consisted of procedures and repre-sentative records, interviews with personnel, and observations by the inspector. These findings are documented in the enclosed inspection report. Within the scope of the inspection, no violations or deviations were ident-ified. In accordance with 10 CFR 2.790(a), a copy of this letter and the enclosure will be placed in the NRC Public Document Room unless you notify this office, by telephone, within 10 days of the date of this letter, and submit written application to withhold infonnation contained therein within 30 days of the date of this letter. Such application must be consistent with the require-ments of 2.790(b)(1). l N .L M' NN NY-o"c > . S.8 I. ...
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Texas Utilities Generating 2 SEP 2 71983 Company : Should you have any questions concerning this inspection, we will be pleased to discuss them with you. t Sincerely,
**Co laina t signa.;. a y, W. A. CRossMAN G. L. I'.adsen , Chief Reactor Project Branch 1
Enclosure:
Appendix - NRC Inspection Report 50-445/83-36 cc w/ encl: Texas Utilities Generating Company ATTft: H. C. Schmidt, Project Manager 2001 Bryan Tower Dallas, Texas 75201 Texas Utilities Generating Company ATTil: B. R. Clements Vice President, Nuclear 2001 Bryan Tower, Suite 1735 Dallas, Texas 75201 bcc to DMB (IE01) bcc distrib. by RIV: RPB1 D. Kelley, SRI-Ops RPB2 R. Taylor, SRI-Cons TPB Section Chief (RPS-A) J. Collins, RA J. Gagliardo, DRRP&EP C. Wisner, PA0 M. Rothschild, ELD - MIS SYSTEM RIV File TEXAS STATE DEPT. OF HEALTH Juanita Ellis David Preister . g -s emm> c""> .................. ..................... ..................... ..................... ..................:. ........ ... .... ...... .. .
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4 l APPENDIX t U. S. NUCLEAR REGULATORY COMMISSION REGION IV . , NRC Inspection Report: 50-445/83-36 - L Docket: 50-445 Category: A2 Licensee: Texas Utilities Generating Company (TUGCO) 2001 Bryan Tower Dallas, Texas, 75201 Facility Name: Comanche Peak Steam Electric Station (CPSES), Unit 1 Inspection At: Glen Rose, Texas Inspection Conducted: August 1 - August 31, 1983 Inspectors: o1 ff 4/zt./8) 0.L'.'Klley,'SeniorRefidentInspector Da.te w Y72/YJ W. B. Jones, EngineefirKJ Aide Date ' Approved: bD. f$c.sh h)t }&M Hunnicutt', Chief T 7f83 Ofte / Reactor Project Section A Inspection Summary Inspection Conducted August 1 - August 31, 1983 (Report 50-445/83-36) Areas Inspec'ted: Routine, announced inspection of (1) Initial' Startup Test Procedure Review, (2) Penetration Seal Installation, (3) Systen Walkdown; . (4) Plant Tours; and (5) Plant Status. The inspection involved 119 inspector-hours by the NRC inspector. Results: Within the five areas inspected, no violations or deviations were ident-ified. 999. -..-. . . . ..
1 2
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l Details
- 1. Persons Contacted (
Principle Licensee Emoloyees J. T. Merritt, Assistant General Project Manager i *J. C. Kuykendall, Manager, fluclear Operations
*R. A. Jones, Manager, Plant Operations
*R. E. Camp, Startup Manager
*0. E. Deviney, Operations Quality Assurance Supervisor
*T. L. Gosdin, Public Relations Coordinator The Senior Resident Reactor Inspector (SRRI) also interviewed other licensee employees during the inspection period.
- Denotes those persons present during the exit interview.
- 2. Initial Startup Test Procedure P,eview The NRC inspector reviewed two draft initial startup test procedures.
The procedures will be reviewed in their final form af ter approval by the
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station operations review committee (SORC). When the preoperational tests are perfomed, a brief review will be conducted of the latest revision to note any changes that may affect the test results. The procedures are reviewed with specific emphasis on the following:
- a. Management review.
- b. Fomat clearly defines testing to be performed.
- c. Test objectives are clearly stated.
- d. Prerequisites are identified.
l
- e. Special conditions (if any) are specified.
- f. Acceptance criteria are identified and requirements are specified for comparison of results with the acceptance criteria. .
- g. Source of acceptance criterion is identified,
- h. Initial test conditions are specified.
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- 1. Reference to appropriate FSAR sections, drawings, specifications, and
- codes are included.
- j. Reactor operating mode and applicable Technical Specifications are identified. .
I I
- - ._ _4._ .
4
1 3 t k.- Step-by-step instructions of sufffcient detail are include'd to ensure j that conduct of the test will result in valid conclusions, i L
- 1. Provisions of documenting that requires steps have been performed and space for recording data are included,
- m. Temporary circuit change's, installation of jumpers, and restoration of circuits after testing are properly documented.
- n. Technical Specification "Special Testing Exceptions" are listed.
- o. Independent verification of critical steps or parameters is addressed.
The following draft procedures were reviewed and returned ~with the following comments. l ISU-023A ' Reactor Coolant flow t',easurement i Comments: None ! ISU-025A RCCA Control System Test i Comments: None
! ISU-024A Reactor Coolant System Flow coastdown Test Comments: None ISU-002A Precritical NIS Alignment
- Comments: None
! ISU-206A Auxiliary Feedwater Perfonnance
; Comments: Licensee should settle on the use of " atmospheric 4
relief valve" or S/G PORV. At present they are used inter-changeably. No violations or deviations were identified. l
- 3. System Walkdown .
' During this inspection period, the NRC inspector completed walkdowns of the component cooling water system and containment spray system. In addition, i the NRC inspector began the walkdown of the chemical and volume control , ] system. The following flow diagrams were used during the walkdowns: i Flow DDgram 2323-i-1-0229, Sheet 1 of 3 , Rev.12, 2323-111-0230, . Sheet 2 of 3. Rey.11, 2323-M1-0231, Sheet 3 of 3, Rev.12. " Component
- Cooling Water System" Flow Diagram 2323-t11-0232 Rev.10, " Containment Spray System" f ~
Flow Otagram 2323-M1-0253, sheet 1 of 4, Rev. 8, 2323-i11-0254, sheet 2 l of 4. Rev. 8, 2323-M1-0255, Sheet 3 of 4, Rev. 8, 2323-111-0256, Sheet 4 l of 4, Rev. 9, 2323-M1-0257, Common, Rev. 8 " Chemical and Volume Control l System"
- a. . . a _ . - - - -- -
=. = . . -- -
4 t The NRC inspector used the above drawings to verify that: (1) valves, pumps, instruments, and other components were shown on the flow diagram; (2) design changes associated with the. system were reviewed, processed, and implemented according to procedure; and (3) changes to the system did not or will not alter its safety function. The NRC inspector noted the following discrepancies and incomplete items during the walkdowns:
- a. Component Cooling Water System (1) The following pipes have not been completed:
1/2-CC-1-936-152-3 1/2-CC-1-940-152-3 1/2-CC-1-939-152-3 1/2-CC-1-935-152-3 3/4-CC-1-918-151-3 1/2-CC-1-932-152-3 1/2-CC-1-930-152-3 1/2-CC-1-929-152-3 1/2-CC-1-939-152-3 3-CC-1-232-152-3 3-CC-1-234-152-3 . 3-CC-1-222-152-3 3-CC-1-230-152-3 3-CC-1-259-152-3 3-CC-1-269-152-3 - 3-CC-1-230-152-3 3-CC-1-236-152-3 4-CC-X-117-152-5 Suction and discharge lines to CCW drain tank pumps 01 and 02. This item is considered open. (8336-01) (2) The motors have been removed from CCW drain tank pumps 01 and 02. This item is considered open. (8336-02)
~
- b. Containment Spray System (1) Check valve ICT-145 internal has been removed.
This item is considered open. (8336-03) (2) The following motor operated valves have not been completed: 1-HV-4872 1-HV-4783 . This item is considered open. (8336-04) edme De seB A .6 mm.'m , .o -
5 8
- c. Chemical and' Volume Control System -
(1) The following air operated valve limit switches have not been completed: 1-HCV-182 1-FCV-121 This item is considered open. (8336-05) (2) The following remote valve operators are not complete: 1-CH-8527A 1-CH-8526A 1-CH-8522A 1-CH-85278 1-CH-8526B 1-CH-85228 1-CH-7014A 1-CH-7014B 1-CH-7014C 1-CH-70140 1-CH-7014E 1-CH-7078A 1-CH-70788 This item is considered open. (8336-06) While performing NRC inspector the walkdown observed of the component that the residual heat removalcooling (water RHR) pump 01system, had been the removed. This item will be considered an open item in addition to the two open items (8332-04 and 8332-05) noted in NRC Inspection Report 50-445/8332 for the residual heat removal heat system. This item is considered open. (8336-07) These items (8336-01 through 8336-07.) will remain open pending: Review of " find as-built" flow diagrams against identified discrepancies. '~ Completion of identified incomplete items. The NRC inspector observed that numerous valves and instruments have not been marked with permanent identification tags. This item was identified as Open Item 8332-10 in NRC Inspection Report 50-445/8332. This item will remain open pending completion of permanent tagging. d
" N ***** *-- s-** e. - ---- , . . . . . . .
9
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- 4. Penetration Seal Installation - .
The NRC inspector reviewed the BISCO installation procedures, quality control / quality assurance (QC/QA) procedures, and QC/QA records relating to the installation of floor and wall fire stops and pressure seals. The following documents were reviewed to verify that the installation procedures contained the necessary instructions 'to correctly install an acceptable fire stop/ seal, personnel had been properly instructed in the use of .the equipment and' material, and that the inspection procedures contained the appropriate steps to verify that the installed fire stops / seals met the acceptance criteria to insure they would perform their design function: Dow Corning 3-6548 Silicone RTV Foam information sheet SP-103, R2,12/17/80, Damming Installation SP-104, R1, 2/14/80, formulation of Silicone Foam Material SP-105, R2, 6/2/82, Installation - Silicone foam Material QCP-103, R2, 9/5/82, Damming Depth and Penetration In~spection QCP-104, R1, 2/4/80, Sample Evaluation QCP-105, R1, 2/4/80, Standardization for Density Measurements The NRC inspector also reviewed a random selection of test and inspection records lation. plus In . training addition,records the NRCofinspector personnel made involved with periodic the seal instal-observations of the seal installation. No violations or deviations were identified.
- 5. ' Plant Tours During this reporting period, the NRC inspector conducted several inspection tours of Unit 1. In addition to the general housekeeping activities and gen-eral cleanliness of the facility, specific attention was given to areas where
~
safety-related equipment is installed and where activities were .in progress involving safety-related equipment. These areas were inspected to ensure that:
- a. Work in progress was being accomplished using approved procedures.
- b. 5)ecial precautions for protection of equipment was implemented, .
w1ere required, and additional cleanliness requirements were being adhered to, where required, for maintenance, flushing and welding activities. .
- c. Installed safety-related equipment and components were being protected and maintained to prevent damage and deterioration.
Also during these tours, the NRC inspector reviewed the co'ntrol room and shift supervisors' log books. Key items noted in the log review were:
- a. Plant status - -
6 .
, c . , - o 7
- b. Changes in plant status -
- c. Tests in progress l
- d. Documentation of problems which arise during operating shifts t
No violations or deviations were identified.
- 6. Plant Status The following is a status of TUGC0 manning levels for operations and plant testing activities as of August 31, 1983:
- a. Operations Manning Status Authorized Personnel Level' (including maintenance, operations, administration, quality assurance, and ' engineering) - 473 Number Presently Onboard 455
- b. Plant Testing Status Total Number of Preoperational Tests - 146 Number of Preoperational Tests Through Draf t - 144 Number of Preoperational Test Approved Joint Test Group (JTG) - 136 Total Number of Acceptance Tests - 51 Number of Acceptance Test Through Draft - 50 Number of Acceptance Test Approved - 47 Test Completion Status Preoperational Tests - 79 -
Acceptance Tests - 43 No violations or deviations were identified.
- 7. Exit Interview An exit interview was conducted September 7, 1983, with licensee representa- -
tives (identified in paragraph 1). During this interview, the SRRI reviewed the secpe and discussed the inspection findings.
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0
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MAY 2 51983 In Reply Refer To: -
- _ . - Docket: 50-445/83-22g %
) .
A C ATTH: Texas Util[ ties Generating Company R. J. Gary, Executive Vice g// / President & General Manager . 2001 Bryan Tower Dallas, Texas 75201 Gentlemen: This refers to the inspection conducted under the Resident Inspection Program by Messrs. D. L. Kelley and S. L. McCrory, during the period April 1-30, 1983, of activities authorized by NRC Construction Permit CPPR-126 for the Comanche Peak facility, Unit 1, and to the discussion of our findings with Messrs. J. T. Merritt, J. C. Kuykendall, and other members of your staff at the conclusion of the inspection. : Areas examined during the inspection included (1) Preoperational Test Results Evaluation; (2) Fuel Receipt Preparation; (3) Hot Functional Test; (4) Plant Tours; and (5) Plant Status. Within these areas, the inspection consisted of procedures and representative records, interviews with personnel, and obser-vations by the inspectors. These findings are documented in the enclosed inspection report. Within the scope of the inspection, no violations or deviations were ident-ified. In accordance with 10 CFR 2.790(a), a copy of this letter and the enclosure will be placed in the NRC Public Document Room unless you notify this office, by telephone, within 10 days of the date of this letter, and submit written application to withhold infonnation contained therein within 30 days of the date of this letter. Such application must be consistent with the require-ments of 2.790(b)(1). s p aqr**f . m amaa me em CNS n e t=n \Y H. SRI 4. heS.-AgY.....;.Re.81..p.).RRe.seP R ..... t. . . . E .W. .).C.'+.i. !.4.s.:.W -m.0X.e!.1.9y/. anW5/g/83 5I 3 /83 lac.[mest.e.ma.n... i 5/d/83 .!.GMad.sen
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Texas Utilities Generating 2 MAY 2 51983 Company s Should you have any questions concerning this inspection, we will be pleased to discuss them with you. Sincerely, oristnet sra nw 63 a,1:. MAosrac G. L. Madsen, Chief Reactor Project Branch 1
Enclosure:
Appendix - !!RC Inspection Report 50-445/83-22 cc w/ enc 1: Texas Utilities Generating Company ATTN: H. C. Schmidt, Project Manager 2001 Bryan Tower Dallas, Texas 75201 A
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bec to DFB (IE01) bec distrib. by RIV: - RPB1 Resident Inspector RPB2 Section Chief
- TPS S. L. McCrory MIS SYSTEM RIV File
- RA C. Wisner M. Rothschild, ELD TEXAS STATE DEPT. OF HEALTH Juanita Ellis -
David Preister e 1 em r > ................... ..................... M$U$
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APPENDIX
-" U. S. NUCLEAR REGULATORY COMMISSION REGION IV NRC Inspection Report: 50-445/83-22 ,
Docket: 50-445 Category: A2 Licensee: Texas Utilities Generating Company (TUGCO)
. 2001 Bryan Tower- -
Dallas, Texas, 75201 Facility Name: Comanche Peak, Unit 1 - Inspection At: Comanche Peak, Unit 1 Inspection Conducted: April 1-30,1983 Inspectors: h s ik /d /JA P 3
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D.L.Kelley,SenidrRsident[nspector Date 'g v i ij.L cCrorf, Reactor' Inspector [ k&/ Oate'/ b <J b ' Rea tor Project Section A r, ,. Approved: / ]4 IL' i/// '//f.3 T. F. Westerman, Chief Date l Reactor Project Section A* Inspection Sumary Inspection Conducted April 1-30, 1983 (Recort 50-445/83-22) Areas Inspected: Routine, announced inspection of (1) Preoperational Test Results Evaluation; (2) Fuel Receipt Preparation; (3) Hot Functional Test; (4) Plant Tours; and (5) Plant Status. The inspection involved 128 inspector-hours by two NRC inspectors. Results: Within the five areas inspected, no violations or deviations were ident-4 ified. grON, A - nyp.
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Details 32
- 1. Persons Contacted J. T. Merritt, Startup Manager
*J. C. Kuyken_dall, Manager, Nuclear Operations
*R. E. Camp, Lead Startup Engineer
*R. A. Jones, Manager, Plant Operations R. B. Seidel, Operations Superintendent
*T. L. Gosdin, TUGC0 Public Infomation Coordinator
*D. E. Deviney, Operations Quality Assurance Supervisor D. W. Braswell, Engineering Superintendent -
W. Nixon, Reactor Engineer The Senior Resident Reactor Inspector (SRRI) also interviewed other licensee employees during the inspection period.
- 2. Precoerational Test Results Evaluation The NRC inspectors reviewed the completed Preoperational Test (PT) packages listed below to determine that: (1) the licensee had adequately evaluated test results; (2) test data, met acceptance criteria and that deviations were properly identified and resolved; (3) review procedures were heing followed; and (4) licensee's administrative practices with respect to test execution and data evaluation were adequate.
The following PT's were reviewed: 1CP-PT-02-01 118 Volt Class 1E AC Inverters 1CP-PT-02-02 118 Vac RPS Inverters 1CP-PT-02-08 345 kV Startup Transfomer and 6.9 kV Class 1E Switch-gear 1CP-PT-02-10 480 Volt Class 1E Switchgear and Motor Control Center 1CP-PT-10-01 Demineralized Water System XCP-PT-24-02 Primary Plant Ventilation Supply System Cooling Coil 1CP-PT-24-04 HVAC Component Response Time 1CP-PT-28-02 Feedwater Isolation Valves 1CP-PT-31-01 Safety Chilled Water System ~ ICP-PT-32-01 Auxilliary Building HVAC ICP-PT-36-01 Safeguards Building HVAC 1CP-PT-36-03 SG Building Electrical Area Supply and Exhaust ICP-PT-36-04 ESF Pump Room Fan Coolers 1CP-PT-37-02 Condensate Storage and Transfer System 1CP-PT-39-01 Diesel Generator Area HVAC 1CP-PT-45-01 Containment Purge Supply and Exhaust ICP-PT-45-02 Containment Recirculation Cooling System ICP-PT-45-03 CDRM Ventilation ICP-PT-45-04 Pre-Access Filtering and RCS Pipe Penetration Cooling . ICP-PT-45-05 Neutron Detector Well Cooling , 1CP-PT-46-01 Containment Hydrogen Purge System - ICP-PT-47-02 Refueling Cavity Cooling and Purification
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,, Additionally, the following startup administrative procedures (SAP) were # reviewed:
CP-SAP-6, R9 Control of Work on Station Components after Release from Construction to TUGC0 CP-SAP-11, R5 Review, Approval and Retention of Test Results CP-SAP-14, R8 Design Change Processing CP-SAP-16, R6 Test Deficiency & Non-Conformance Reporting w/ interim change 4/07/83 . CP-SAP-18, R3 Control of System / Component Problems The NRC inspectors interviewed TUGC0 startup personnel to detennine how the administrative systems tracked the status of open or unresolved items 4 that were identified or generated during preoperational testing. The description and demonstration of the tracking methods were consistent with SAP's. SAP 18 required that all problems associated with a system be entered on the master system punchlist (MPS). However, there are several other tracking systems for problems which fall under various catagories. Deficiency reports, design change requests, and design change authoriza-tion each have separate tracking system. The SAP's governing these systems do not prompt the person identifying a problem to make an entry to the punchlist or refer him to SAP 18. However, there is no evidence that there is a problem with getting entries onto the itSP. Many of the procedures governing these tracking systems do not assign responsibility for periodic review of outstanding and completed items. There appears , to be no lack of adequate reviews by management and engineering personnel. There were no violations or deviations identified in this area of the inspection.
- 3. Fuel Receipt Preparation The NRC inspectors conducted a review of the licensee's fuel receipt and
, handling procedures. In addition, an inspection of the Fuel Building was conducted. The following procedures were reviewed and comments transmitted to the licensee: t RFO-101, R0 Refueling Organization RFO-104, R2 Receipt and Shipment of New Fuel RFO-201, R0 Receipt, Inspection and Storage of New Fuel RFO-202, RO Offsite Shipment of New Fuel RFO-208, RO Instructions for Completing New Fuel Receipt i and Inspection Forms (RFO-201-1, RFO-201-2, RFO-201-3) RFO-209, RO Instructions for Completing New Fuel Shipment Forms j (RFO-202-1,RFO-202-2) RFO-301, R2 Handling New Fuel and Shipping Containers During Fuel 4 Receipt Operations , i . _ ~ - . . _ . _ , - -- .
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RFO-303, R1 Handling of Rod Cluster Control Assemblies and Core
.=i*- Components RFO-304, R0 Handling of New Fuel and Shipping Containers During Fuel Shipment Operations RFO-403, R0 Operating and Checkout Instructions for the Fuel Hand-ling Tools.
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In addition, preoperational tests 1CP-PT-40-01, " Fuel Handling Tools & Fix-tures," and XCP-PT-81-01, " Fuel Building Overhead Cranes," were reviewed and the testing status verified. . The fuel handling procedures were reviewed and discussions with licensee personnel to ascertain that the following topics had been incorporated:
- a. Fuel building cleanliness
- b. Radiation control
- c. Personnel access control Security control
- d. '
- e. Work authorization control In addition to the broad topics above, the detailed methods of accomplish-ing these tasks and adequacy of the fuel receipt, inspection, handling, and storage procedures were assessed.
Comments made to the licensee by the NRC inspectors were:
- a. General Fuel Building cleanliness levels, and specifically, the cleanliness level of the fuel ir spection station and storage a
locations.
- b. Cleaning requirements for the fuel shipping containers and truck.
- c. Type of activities to be allowed in the Fuel Building, other than fuel receipt and inspection. -
- d. Methods of control over these activities. ~
- e. Authorization requirements.
- f. Control and authorization of personnel access to the Fuel 1 Building.
An inspection was conducted by the NRC inspectors to ascertain the readi-ness of the fuel handling and storage facilities to receive and store fuel. At the time of the inspection, cleaning operations had not been completed. Prior to the receipt of the first fuel shipment, an additional inspection will be made. -
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.. It is the NRC inspectors intent to monitor, on a continuing basis, the first fuel assemblies. The remainder of the fuel shipments will be monitored l on a random basis until all of the Unit I core has been received and inspected.
No violations or deviations were identified.
~4 . Hot Functio ~nal Test The NRC inspectors are continuing to monitor the progress of the Hot Functional Test (HFT). Major milestones accomplished during this reporting period were:
- a. Turbine generator testing
- b. Setting of main steam safety valves
- c. Testing of the pressurizer level and pressure control No violations or deviations were identified.
- 5. Pladt Tours During this reporting period, the SRRI conducted several inspection tours of Unit 1. In addition to the general housekeeping activities and general cleanliness of the facility, specific attention was given to areas where safety-related equip,ent is installed and where activities were in progress involving safety-related equipment. These areas were inspected to ensure that:
- a. Work in progress was being accomplished using approved procedures.
- b. Special precautions for' protection of equipment was implemented, where required, and _ additional cleanliness requirements were being adhered to, where required, for maintenance, flushing and welding activities.
- c. Installed safety-related equipment and components were being protected and maintained to prevent damage and deterioration. .
Also during these tours, the NRC inspectors reviewed the control room and shift supervisors' log books. Key items noted in the log review were:
- a. Plant status
- b. Changes in plant status
- c. Tests in progress
- d. Documentation of problems which arise during operating shifts No violations or deviations were identified.
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. 6. Plant Status The following is a status of TUGC0 manning levels fo'r operations and plant testing activities as of April 30, 1983:
- a. Operations Manning Status Authorized Personnel Level (including maintenance, operations, administration, quality assurance, and engineering) - 473 Number Presently Onboard 416
- b. Plant Testing Status Total Number of Preoperational Tests - 142 Number of Preoperational Tests Through Draft - 138 ,
Number of Preoperational Test Approved (JTG) - 130 Total Number of Acceptance Tests - 48 Number of Acceptance Test Through Draft - 47 , Number of Acceptance Test Approved - 46 Test Completion Status Preoperational Tests - 55 Acceptance Tests - 37 No violations or deviations were identified.
- 7. Exit Interview An exit interview was conducted May 2,1983, with licensee representa-tives (identified in paragraph 1). During this interview, the SRRI reviewed the scope and discussed the inspection findings.
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s W JUN 151983
, .. . In Reply Refer To:
Cocket: 50-445/83-26 [l [/ j [y [ u 7 - Texas Utilities Generating Company f f ATTN: R. J. Gary, Executive Vice President & General Manager 2001 Bryan Tower Dallas, Texas 75201 Gentlemen: This refers to the inspection conducted under the Resident Inspection Program by Messrs. D. L. Kelley and S. L. McCrory, during the period May 1-31, 1983, of activities authorized by flRC Construction Pennit CPPR-126 for the Comanche Peak facility, Unit 1, and to the discussion of our findings with Messrs. J. T. "erritt, J. C. Kuykendall, and other members of your staff at the conclusion of the inspection. Areas examined during the inspection included Preoperational Test Review, Initial Startup Procedure Review, Fuel Receipt. Hot Functional Test, Part 21, Plant Tours, and Plant Status. Within these areas, the inspection consisted of procedures and representative records, interviews with personnel, and observations by the inspectors. These findings are docunented in the enclosed inspection report. Within the scope of the inspection, no violations or deviations were ident-ified. In accordance with 10 CFR 2.790(a), a copy of this letter and the enclosure will be placed in the flRC Public Document Room unless you notify this office, by telephone, within 10 days of the date of this letter, and submit written application to withhold infonnation contained therein within 30 days of the date of this letter. Such application must be consistent with the require-ments of 2.790(b)(1). \ I I L3-f-9-f>#
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s Texas Utilities Generating 2 JUN 151983 Company t r. Should you have any questions concerning this inspection, we will be pleased to discuss them with you. Sincerely, .
"Crialnsl signed hYa G. L:. MAesD(*
- G. L. !'adsen, Chief Reactor Project Branch 1
Enclosure:
Appendix - NRC Inspection Report 50-445/83-26 cc w/ encl: Texas Utilities Generating Company ATTN: H. C. Schnidt, Project I*.anager 2001 Bryan Tower Dallas, Texas 75201 bec to CMS ('IEDI) bec distrib. by RIV: RP81 Resident Inspector RPB2 Section Chief TPS S. L. itcCrory MIS SYSTEM RIV File RA C. Wisner M. Rothschild, ELD TEXAS STATE DEPT. OF HEALTH Juanita Ellis David Preister . l [
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, APPENDIX U. S. NUCLEAR REGULATORY COMMISSION REGION IV
-:.. NRC Inspection Report: 50-445/83-26 Docket: 50-445 Category: A2 Licensee: Texas Utilities Generating Company (TUGCO) 2001 Bryan Tower Dallas, Texas, 75201 Facility Name: Comanche Peak, Unit 1 , Inspection At: Comanche Peak, Unit 1, Glen Rose, Texas
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Inspection Conducted: May 1-31, 1983 Inspectors: )
- 0. 'L. Telley, Senior Resident Inspector
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M Date
//////3 I s a&- A WV.4cCroff, ReactCnspector Odte /
Reactor Project Section A Approved: ,[ 4// M//3 T. F. Westerma'n, Chief ' Da te' Reactor Project Section A Inspection Sumary Inspection Conducted l'ay 1-31, 1983 (Recort 50-445/83-26) Areas Inspected: Routine, announce'd inspection of (1) Preoperational Test Review; ~ (2) Initial Startup Procedure Review; (3) Fuel Receipt; (4) Hot Functional Test; (5) Part 21; (6) Plant Tours; and (7) Plant Status. The inspection involved 132 inspector-hours by two NRC inspectors. Results: Within the seven areas inspected, no violations or deviations were ident-tfled. e e
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2 4 fi- - Details 2
- 1. Persons Contacted Principle Licensee Dnployees J. T. Merritt, Startup Mana
*J. C. Kuykendall, Manager, gerNuclear Operations R. E. Camp, Lead Startup Engineer
*R. A. Jones, Manager, Plant Operations
*D. E. Deviney, Operations Quality Assurance Supervisor S. L. Ellis, Engineer C. E. Scott, Electrical Maintenance Engineer The Senior Resident Reactor Inspector (SRRI) also interviewed other licensee employees during the inspection period.
- Denotes those persons present during the exit interview.
- 2. Preooerational Test Procedure Revimg The NRC inspectors reviewed one draft preoperational test procedure.
Comments were made where appropriate. The procedure will be reviewed in its final form after approval by the joint test group (JTG). When the preoperational test is performed, a brief review will be conducted of the latest revisions to note any changes that may affect the test results. The procedure was reviewed with specific emphasis on the following:
- a. Management review.
- b. Format clearly defines testing to be performed,
- c. Test objectives are clearly stated.
- d. Prerequisites are identified,
- e. Special conditions (if any) are specified. '~
f. Acceptance criteria are identified and requirements are specified for comparison of results with the acceptance criteria.
- g. Source of acceptance criterion is identified,
- h. Initial test conditions are specified.
i. Reference to appropriate FSAR sections, drawings,, specifications, and codes are included. .
- j. Step-by-step instructions of sufficient detail are included to ensure that conduct of the test will result in valid conclusions.
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- k. Provisions for documenting that required steps have been perfomed and space for recording data are included.
- 1. Temporary circuit changes, installation of jumpers, and restoration of circuits after testing are properly documented.
- m. Independent verification of critical steps or parameters is addressed.
During this reporting period, the following draft procedure was reviewed and commented on: . 1CP-PT-70-01 Radiation Monitoring System Functional Test Comments: The procedure has no provision for perfaming or verifying radiation source strength tests nor swipe su'veys r to ensure sufficient source strength for test validity and source -integrity to prevent contamination. No violations or deviations were identified durkng this review.
- 3. Initial Startup Test Procedure Review -
The NRC inspectors reviewed six draft initial startup test procedures. Coments were made where appropriate. The procedures will be reviewed in their final form after approval by the station operations review committee (50RC). When the preoperational tests are performed, a brief review will be conducted of the latest revision to note any changes that may affect i the test results. ' The procedures are~ reviewed with specific emphasis on the following:
- a. Management review.
- b. Fomat clearly defines testing to be perfomed.
- c. Test objectives are clearly stated.
- d. Prerequisites are identified. .
- e. Special conditions (if any) are specified. .
- f. Acceptance criteria are identified and requirements are specified for comparison of results with the acceptance criteria.
- g. Source of acceptance criterion is identified.
- h. Initial test conditions are specified.
- i. Reference to appropriate FSAR sections, drawings, specifications, and codes are included. -
- j. Reactor operating mode and applicable Technical Specifications are -
identified.
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- k. Step-by-step instructions of sufficient detail are included to ensure a that conduct of the test will result in valid conclusions, t
- 1. Provisions. of documenting that required steps hrve been perfomed and space for recording data are included,
- m. Temporary circuit changes, installation of jumpers, and restoration of circuits after testing are properly documented,
- n. Technical Specification "Special festing Exceptions" are listed.
- o. Independent verification of critical steps or parameters is addressed.
During this reporting period, the following draft procedures were reviewed and returned with the following coments except where noted. ISU-223A Remote Shutdown Capability Test Ccments: Precaution 7.1.3 states, "A source range channel should be in operation before beginning cooldown." The intent of this statement is not clear. Does it mean that at least one source range channel shall be OPERABLE per Technical Specification definitions? Or, does it mean that it is prefer-able but not necessary to begin cooldown when neutron flux has decayed into the source range? Statements referring to the OPERABILITY of source range channels must use the tem "shall"
, or "must" vice "should" or "may".
1 ISU-222A Turbine Generator Trip With Coincident loss of Offsite Power Coments: There is no requirement to verify turbine auxiliary feedwater pump operation nor steam generator level coritrol within a specified band. Since the plant is in natural circu-lation, maintaining steam generator level is essential to creating a themal driving head for natural circulation. Prerequisite 8.8 directs that the main feedwater regulating valves be in automatic. At power levels below 15"., autematic S/G level control using the main feedwater regulating valves on Westinghouse plants are generally unstable and large level oscillations may occur. Manual or automatic by-pass control is generally the more effective means of stable level control - below 15', power. Since level control will shift to the aux-iliary feedwater system shortly after the reactor trip, the method of level control prior to the trip will not affect test validity if the steam generator level is within the pre-scribed band at the time of the reactor trip. ISU-224A Themal Power Measurement and Statepoint Data Collection Coments: None ISU-241A Inserted (PSEUDO Dropped) Rod, Test - Coments: Precaution 8.1.5 calls for Rod Bank Selector ~ Switch (1/1-RDSS) to be in~ the "CBB" position. It should read "CBD" position.
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' . Precaution 8.1.8 requires that " . . . steam generator pressure control (1-PK-455A)" be placed in the AUTO position.
There is no automatic steam generator pressure control. The
, step should read " pressurizer pressure control (1-PK-455A)".
- Step 9.1.10. "Contro1 Bank D Position", is read on 1-SC-CBD1 and 1-SC-CBD2 vice 1-SC-SBE1.
Step 9.1.12.1 directs the operator to " dilute" RCCA H-12 out to 228 steps. Rods are " borated" out and " diluted" in. Additionally, the method of boration to be used is not speci-fied. After Step 9.1.12.3, the operator is not directed to place the rod bank selector switch (1/1-RBSS) in the manual or auto positions to restore proper rod control sequence and s overlap operation. ISU-234A Main Steam Isolation Valves Operability and Response Times Comments: None ISU-226A Operational Alignment of Process Temperature Instruments Conments: None . No violations or deviations were identified during this review.
- 4. Fuel Receipt The first shipment of fuel for Unit.1 Reactor arrived on site ."ay 4,1983.
The shipment consisted of six shipping containers containing two fuel assemblies each. The fuel receipt is authorized under NRC Special Nuclear Material License SNM-1912. The license authorizes receipt, possession, inspection and storage of uranium enriched in the U-235 isotope contained in fuel assemblies for use in Unit 1 Reactor. The NRC inspectors witnessed the arrival and the licensee's physical inspec-tion of Fuel Assemblies A-14 and C-24. Prior to arrival of the fuel shipment, the NRC inspectors reviewed the SNM License to assure 'that compliance with the license conditions had been , met. These conditions included:
- a. Security control of the fuel storage area.
- b. Radiation protection control when necessary,
- c. Minimum spacing requirements at the inspection station and storage areas.
- d. Provisions for water drainage from storage area. -
- e. Storage and inspection area cleanliness.
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6 During actual receipt, the flRC inspectors v'erified that the licensee's approved procedures were being followed and that the required shipping document were in order. The NRC ihspectors physically verified that the fuel assembly shipping container for Fuel Assemblies A-14 and C-24: r a. had no external damage;
- b. the security seals were intact; .
- c. the shock indicators had not tripped; and
- d. there were no loose materials or parts in the containers.
In addition, during this reporting period, several other fuel shipments have been received. The NRC inspectors has randomly witnessed receipt
. and inspection of Fuel Assembles A-01, A-59, C-29 and C-27. This random inspection activity will continue until all of Unit 1 fuel has been re-ceived.
No violat[ons or deviations were identified.
- 5. Hot Functional Test The licensee completed the last evolution of the hot functional test (HFT) on fiay 27, 1983. This evolution required cooldown to ambient condition and demonstration of plant control from outside of the control room.
The plant is presently in a solid water condition and the licensee is proceding with preoperational testing. The tests that are scheduled do not require the plant to be at elevated pressures and temperatures. No violation or deviations were identified. i
- 6. Part 21 Followup Closed (0 pen item 8308-02). Westinghouse issued Technical Bulletins NSD-TB-83-02 and NSD-TB-83-03 on March 24, 1983 providing recomendations for the maintenence and testing of DB and DS series breakers used as reac-tor trip breakers (RTB). Subsequently, the licensee reported that ~
existing maintenence and test procedures complied with the intent of the applicable technical bulletins. l l' The NRC inspectors verified that the RTB's installed in the licensee's fac-ility are D5-416 type breakers. Therefore, Technical Bulletin, 83-02 does l not apply to the maintenance requirements of the installed RTB's since it l only addresses DB series breakers. The NRC inspectors reviewed the licen-l see's Procedure EGT-706A RO, " Engineered Safeguards System Safety Injection Actuation Testing". The procedure wai: determined as meeting the intent of Technical Bulletin 83-02 for independent verification of the operability of the under voltage trip relay and the shunt trip. -
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7 Further revision to comply with the technical bulletins is not necessary. The NRC inspectors further reviewed the licensee's Procedure EUi-302, "480 Volt Air Circuit Breaker Inspection", to determine compliance with the maintenance requirements of the applicable Westinghouse furnished techni-cal manual. The licensee procedure incorporates the intent of the manual or refers the technician to specific parts of the manual for procedural compliance. Further revision to comply with the technical manual is not necessary. There were no apparent violations or. deviations for this part of the in-spection.
- 7. Plant Tours -
During this reporting period, the SRRI conducted several inspection tours of Unit 1. In addition to the general housekeeping activities and general cleanliness of the facility, specific attention was given to areas where safety-related equipment is installed and where activities were in progress involving safety-related equipment. These areas were inspected to ensure that: a. Work in progress was being accomplished using approved procedures.
- b. Special precautions for protection of equipment was implemented, where required, and additional cleanliness requirements were being adhered to, where required, for maintenance, flushing and welding activities.
- c. Installed safety-related equipment and components were being protected and maintained to prevent damage and deterioration.
Also during these tours, the NRC inspectors reviewed the control room and shift supervisors' log books. Key items 'noted in the log review were:
- a. Plant status
- b. Changes in plant status
- c. Tests in progress .
- d. Documentation of problems which arise during operating shifts No violations or deviations were identified.
- 8. Plant Status The following is a status of TUGC0 manning levels for operations and plant testing activities as of May 31, 1983:
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- a. Operations Manning Status .
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g Authorized Personnel Level (including maintenanc'e, operations, administration, quality assurance, and engineering) - 473 Nunbar Presently Onboard 431
- b. Plant Testing Status Total Number of Preoperational Tests - 144 Number of Preoperational Tests Through Draft - 141 ilumber of Preoperational Test Approved (JTG) - 130 Total Number of Acceptance Tests - 48 Number of Acceptance Test Through Draft - 47 Number of Acceptance Test Approved - 47 Test Completion Status Preoperational Tests - 69 Acceptance Tests - 38 No violations or deviations were identified. -
- 9. Exit Interview .
An exit interview was conducted June 2,1983, with licensee representa-tives (identified in paragraph 1). During this interview, the SRRI reviewed the scope and discussed the inspection findings. l l I l l l l l
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Docket: 50-445/83 l
- JUN 3 01983 Texas Utilities ~ Generating Company ATTN: R. J. Gary, Executive Vice r f
President & General Manager ,
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2001 Bryan Tower j i
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/ T Dallas, Texas 75201 Gentlemen:
bd/ Thank you for your letter of May 25, 1983, in response to our letter and Notice of Violation dated April 29, 1983. We have reviewed your reply and find it responsive to the concerns raised in our Notice of Violation. We will review the implementation of your corrective actions during a future inspection to determine that full compliance has been achieved and will be maintained. Sincerely, "Ortstnet srsamt hvt G.!!. MADSEN" G. L. Madsen, Chief Reactor Project Branch I cc: Texas Utilities Generating Company ATTN: H. C. Schmidt, Project Manager 2001 Bryan Tower Dallas, Texas' 75201 Texas Utilities Generating Company ATTN: B. R. Clements, Vice President, Nuclear 2001 Bryan Tower, Suite 1735 Dallas, Texas 75201 bec to DMB (IE01) bec distrib. by RIV: D. Kelley, SRI-Ops R. Taylor, SRI-Cons Section Chief (RPS-A) RPB1 RIV File Enforcement Assistant TEXAS STATE DEPT. OF HEALTH RPS-A T .- RPB1 DRRP&EP/RIV TWesterman' GMadsen JGagliardo 6/A/83 6/p/83 6/f$/83 ~
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R. J. GARY
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May 25, 1983 TXX-3676. .i T. l p kB t.C MAY : i IS83 .. : Mr. G. L. Madsen, Chief 3 'i
' d;I Reactor Project Branch 1 U.S. Nuclear Regulatory Comission Office of Inspection and Enforcement 611 Ryan Plaza Drive, Suite 1000 Docket No.: 50-445 Arlington, Texas 76012 COMANCHE PEAK STEAM ELECTRIC STATION RESPONSE TO NRC NOTICE OF VIOLATION INSPECTION REPORT NO. 83-08 FILE NO.: 10130
Dear Mr. Madsen:
We have reviewed your letter dated April 29, 1983 on the inspection. conducted by Mr. D. L. Kelley of activities authorized by NRC Construction Permit CPPR-126 for Comanche Peak, Unit 1. We have responded to the finding listed in Appendix A of that letter. To aid 'in the understanding of our response, we have repeated the requirement and your finding followed by our corrective action. We feel the enclosed information to be responsive to the Inspector's finding. If you have any questions, please advise. Very truly yours, dw , J. J. Gary l RJG:ln Enclosures cc: TRC Region IV - (0 + 1 copy) i
. Director Inspection & Enforcement (15 copies)
U. S. Nuclear Regulatory Comission l Washington, DC 20555 1 - A,ca
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' TXX-3676 APPENDIX A NOTICE OF VIOLATION ,
Texas Utilities Generating Company Docket: 50-445/83-08 Comanche Peak Steam Electric Station . Permit: CPPR-126 Based on the results of an NRC inspection conducted during the period of March 1-31, 1983 and in accordance with the NRC Enforcement Policy (10 CFR Part 2, Appendix C), 47 FR 9987, dated March 9,1982, the following violation was identified: Failure to Review Chances to Acoroved Procedures Criterion VI of Appendix B to 10 CFR 50, requires that changes to documents shall be reviewed by the same organizations that performed the original review and approval unless the licensee designates another responsible organization. FSAR Section 17.r.6 requires that the licensee, in his Quality Assurance Program, assure that document changes are reviewed and approved by the same organization performing the original review and approval unless the licensee designates another organization. Contrary to the above, the Senior Resident Inspector-Operations determined through review of logs, procedures, and discussions with licensee personnel ~ that eight chances to IP0-001A, Rev. O, were made without the proper review and approval as required. This is a Severity Level V Violation. (Supplement II.D.) Discus t3n I
; All safety-related procedures at CPSES TUGC0 Operations are approved i by the Station Operations Review Canmittee (50RC) and can be changed only by revision or a Temporary Change Form as described in station
, procedure STA-205. The Violatio_n occurred during preoperational !
startup test activities which plant personnel support by operating l installed equipment. l One purpose of the Startup Test Program is to demonstrate the ef-fectiveness of operating procedures and provide a means for detecting any errors requiring correction prior to normal operations. In ~ addition, operating personnel are afforded the opportunity to work and become familiar with the procedures under non-operating conditions. To enable necessary corrections and adjustments to be made in a timely manner, all Integrated Plant Operating Procedures (IPO's), except IPO-001A, nave intent 1onally been kept in craft rorm.
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The actual preoperational tests are conducted by Startup Test Engineers utilizing approved Preoperational Test Procedures which can be changed, if required, by Test Procedure Deviations described in Startup Administrative Procedure. CP-SAP-12. Since the draft IPO's are not approved, shift supervisors have been . instructed to use them to the maximum extent during preoperational testing to check their accuracy. The shift supervisers are therefore accustomed to changing draft procedures to improve them before final review and approval by the SORC. As previously stated, the one exception occurred because IPO-001A was approved by the 50RC on June 23, 1982, for the sole purpose of supporting Cold Hydro activities. This exception was overlooked by control room personnel who made changes to approved procedure IPO-001A as they would normally change a draft procedure. When the Senior Resident Inspector-Operations informed plant management of this Violation on March 2,1983, Special SORC Meeting No. 83-04 was called to discuss actions required to correct and prevent its recurrence. The following actions are a result of this meeting: Corrective Action The Operations Superintendent initiated Deficiency Report, DR-83-023 which was reviewed and issued by the Operations QA Supervisor. The deficiency report documented the fact that IPO-001A, Rev. O, was changed in noncompliance with STA-205, " Temporary Changes to Procedures." Final disposition to the deficiency was made by the Operations Superintendent on March 8, 1983. The deficiency report now documents that all appropriate changes to IPO-001A, Rev. O, improving it for use during normal operations, are made in accordance with STA-205. Preventive Action CPSES Special Order #1-50-83-005,'" Operating Procedures - Use and Changes During Testing," was issued by plant management on March 4, 1983, in accordance with STA-207. The Special Order outlines requirements for the use of operating procedures during preoperational testing that are intended to prevent recurrence of the Violation. These requirements are:
- 1. Operating procedures (SOP's, IPO's, ALM's, ABN's, STA's, 00A's) 2 are to be used to the maximum extent possible during testing in order to check their accuracy.
- 2. Changes to operating procedures are to be made only if the change is to correct an error in the procedure, or if the change ,
will improve the procedure for use during normal operation.
- 3. Changes to aooroved operating procedures are to be made in accordance with STA-205. Oraft procedures may be changed by simply making the change on the procedure. .
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.. 7XX-3676
- 4. Operating procedures are not to be changed for the sole purpose of testing, or because special conditions exist due to testing.
. 5. With the exception of valve lineups, operating procedures are not part of the PT data package and do not need to be checked off or signed off. They do need to be used as provided in item 1 above. .
- 6. No marks, changes, check's or sign-offs are to be made on controlled procedures.
Corrective and Preventive Action steps taken to resolve the Violation were completed on March 8, 1983.
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In Reply Refer To: E 2I Docket: 50-445/83-08 - Texas Utilities Generating Company ATTN: R. J. Gary, Executive Vice . President & General Manager 2001 Bryan Tower Dallas, Texas 75201 Gentlemen: This refers to the inspection conducted under the Resident Inspection Program by our Senior Resident Reactor Inspector, Mr. D. L. Kelley and Reactor Inspec-tor, Mr. S. L. McCrory, during the period Parch 1-31, 1983, of activities authorized by NRC Construction Perini.t CPPR-126 for the Comanche Peak facility, Unit 1 and to the discussion of our findings with Mr. J. T. Perritt and other members of your staff at the conclusion of the inspection. Areas examined during the inspection included: (1) Initial Startup Procedure Review; (2) Hot Functional Test; (3) Part 21; (4) Plant Tours; and (5) Plant Status. These findings are discussed.in the enclosed inspection report. Within these areas, the inspection consisted of selective examination of pro-cedures and representative records, interviews with personnel, and observations by the inspectors. During this inspection, it was found that certain of your activities were in violation of NRC requirements. Consequently, you are required to respond to this violation, in writing, in accordance with the provisions of Section 2.201 l of the NRC's " Rules of Practice," Part 2, Title 10, Code of Federal Regulations. l Your response should be based on the specifics contained in the Notice of Violation enclosed with this letter. In accordance with 10 CFR 2.790(a), a copy of this letter and the enclosures will be placed in the NRC Public Doctanent Room unless you notify this office, by telephone, within 10 dr.ys of the date of this letter, and submit written . application to withhold information contained therein within 30 days of the date of this letter. Such application must be consistent with the require-monts of 2.790(b)(1). 9' 9g. - S OftfoYa2 FiIe cony
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Texas Utilities Generating 2 APR 2 91983 Company The responses directed by this letter and the accompanying Notice are not subject to the clearance procedures of the Office of Management and Budget as required by the Papemark Reduction Act of 1980, PL 96-511. Should you have any questions concerning this inspection, we will be pleased to disc' ass them with you. Sincerely, i 8Crtginal S1sned DER !
'g, g, MAQssNe l G. L. Madsen, Chief Reactor Project Branch 1
Enclosures:
- 1. Appendix A - Notice of Violation 2 Appendix B - NRC Inspection Report 50-445/83-W cc w/encis:
Texas Utilities Generating Company ATTN: H. C. Schmidt, Project Manager ' 2001 Bryan Tower. Dallas, Texas 75201 bec to Die (IE0I) bec distrib. by RIV: RPB2 Resident Inspector TPB Section Chief l MIS SYSTEM ' RIV File. RIV Reading File Br. Reading File RA C. Wisner M. Rothschild, ELD TEXAS STATE DEPT. OF HEALTH Juanita Ellis - David Preister l =r > S R, . . ,, . . . . . . .RP.5 . .... ...... .RP.B. . . . ,.,.... DRR.&EP/.,,V.,,,,,,,,,,,, .. ,,
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1 APPENDIX A - ! l NOTICE OF VIOLATION 1 Texas Utilities Generating Company Docket: 50-445/83-08 l Comanche Peak Steam Electric Station Pemit: CPPR-126 Based on the results of an NRC inspection conducted during the period of March 1-31,1983 and in accordance with the NRC Enforcement Policy (10 CFR Part 2, Appendix C), 47 FR 9987, dated March 9,1982, the following violation was identified: Failure to Review Changes to Acoroved Procedures Criterion VI of Appendix B to 10 CFR 50, requires that changes to documents shall be reviewed by the same organizations that performed the original review and approval unless the licensee designates another responsible organization. FSAR.Section 17.1.6 requires that the licensee, in his Quality Assurance Program, assure that document changes are reviewed and approvec by the same organization perfoming the original review and approval unless the licensee designates another organization. Contrary to the above, the Senior Resident Inspector-Operations detemined through review of logs, procedures, and discussions with licensee person-nel that eight changes to IPO-001A, Rev. O, were made without the proper review and approval as required. This is a Severity Level V Violation. (Supplement II.D.) Pursuant to the provisions of 10 CFR 2.201, Texas Utilities Generating Company is hereby required to submit to this office, within 30 days of the date of this Notice, a written statement or explanation in reply, including: (1) the corrective steps which have been taken and the results achieved; (2) corrective steps which will be taken to avoid further violations; and (3) the date when full canpliance will be achieved. Consideration may be given to extending your response time for good cause shown. APR 2 91983 e i i 4-i
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. APPENDIX B U. S. NUCLEAR REGULATORY C0tHISSION REGION IV Report: 50-445/83-08 Docket: 50-445 Category: A2 Licensee: Texas Utilities Generating Company (TUGCO) 2001 Bryan Tower Dallas, Texas, 75201 Facility Name: Comanche Peak, Unit 1 Inspection At: Comanche Peak, Unit 1 Inspection Conducted: March 1-31, 1983 Inspectors: %) p//n D. L. Kelley, Senior Res iiint I pector g/2,7/g L, Data e Y.f. s T S. L. ticCrory, Reactor Inspector "
W V/3 8/9 3 Cate Reactor Project Section A Approved: 2[ T. F. Westennan, Chief Date ft/2s/rs Reactor Project Section A Insoection Sumary Inscection Conducted March 1-31, 1983 (Recort 50-445/83-08) l Areas Insoected: Routine, announced inspection by the Senior Resident Inspector l (Operations), including: (1) Initial Startup Procedure Review; (2) Hot Functional - 1 Test; (3) Part 21: (4) Plant Tours; and (5) Plant Status. The inspection in-volved 170 inspector-hours by two NRC inspectors. - Results: Within the five areas inspected, one violation was identified. (Failure to Review Procedure Change, paragraph .3). 1 ap-
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2 Details
- 1. Persons Contacted
*J. T. Merritt, Startup Manager
*J. C. Kuykendall, Manager, Nuclear Operations R. E. Camp, Lead Startup Engineer
*R. A. Jones, Manager, Plant Operations R. B. Seidel, Operations Superintendant
*T. L. Gosdin, TUGC0 Public Information Coordinator C. Killough, TUGC0 Operations Quality Assurance The Senior Resident Reactor Inspector (SRRI) also interviewed other licensee employees during the inspection period.
- 2. Initial Startup Test procedure Review (Isu) ,
The NRC inspectors reviewed twelve draft initial startup test procedures. Conments were made where appropriate. The procedures will be reviewed in their final form after approval by the station operatiens review cannittee (SORC). When the preoperational tests are performed, a brief review will tue conducted of the latest revision to note any changes that may affect the test results. The procedures are reviewed with specific emphasis on the folTowing:
- a. Management review.
- b. Format clearly defines testing to be performed.
- c. Test objectives are clearly stated.
- d. Prerequisites are identified.
- e. Special conditions (if any) are specified.
- f. Accepta'nce criteria are identified and requirements are 'specified for canparison of results with the acceptance cr,itaria. ,
- g. Source of acceptance criterion is identified.
- h. Initial test conditions are specified.
- 1. Reference to appropriate FSAR sections, drawings, specifications, and rodes are included.
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. 4 ISU-204A Operational Alignment of Nuclean Instrumentation Comments: None ISU-20SA Dynamic Automatic Steam Dump Control Comments: The intent of Prerequisites 8.1.11 and 8.2.11, and Steps 9.1.15, 9.1.18, 9.2.22, 9.2.26 and 9.2.30 is un-clear. What is to be filled in on Data Sheets 11.1.1.1 and 11.1.2.1 prior to test start, and what, if anything, will be recorded during the conduct of the test? If recording is required during testing, the procedural steps do not direct that data be recorded but imply that it has been prerecorded and provides the intermediate settings to be used. ISU-207A Steam Generator Level Control Test - Comments: None ISU-208A Radiation Survey Tests Comments: None ISU-209A Area Radiation Monitoring System Comments: None-ISU-228A Pressure and Level Control System Performance Test Comments : None ISU-229A Main Steam and MSR Performance Connents: Each major test phase requires a system restor-ation at the completion of the phase. However, the initial test lineup and 1.nstrument hookup is the same for each phase. As written, the procedure does not allow progress-ing directly from one phase to the next without first disconnecting and then reconnecting the test equipment. An applicability clause may be appropriate to allow progressing from one phase to the next without disturbing the test equip-ment lineup. ISU-230A Condensate and Feedwater System Performance Test Comnents: Step 9.1.3.1 incorrectly lists temperature in-strument 1-TI-2220 as the sensing point for heater drain pumps. Step 9.1.3.2 lists the correct instruments. ISU-232A PSEUDO Rod Ejection Test Comments: None No violations or deviations were identified during this review. (8308-03) N=m ewe age m uur gm mgym, h e e h- - -
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- 3. Hot Functional Test The licensee authorized performance of the Hot Functional Test (HFT) sequence procedure (PT-55-02, Rev. 2) on. February 20, 1983. The licensee completed filling and venting and established solid water pressure control on March 2, 1983. The NRC inspector has been monitoring the performance of the HFT since its start.
The plant conditions as of the close of this reporting period (March 31, 1983) was: . RCS Temperature - 5570 F RCS Pressure - 2235 psig (bubble in the pressurizer) 4 - Reactor Coolant Pumps Running Steam Dump System in pressure control mode for RCS temperature control. The HFT sequence procedure (PT-55-02, Rev. 2) lists the following tests that are to be performed at the temperatures and pressures specified by the various tests: PT-02-12 Bus Voltage and Load Survey PT-02-13 Power Transformer Load Test PT-02-14 480V Switchgear Transformer Load Test PT-22-01 Process Sampling AT-22-02 Secondary Sampling PT-22-03 Post-Accident Sampling System AT-28-01 Feedwater System PT-34-01 Main Steam Isolation Valves
- PT-34-02 Steam Generator Safety and Relief Valves AT-34-03 Steam Dump Control AT-34-05 Steam Generator Narrow Range Level Verification PT-37-03 Auxiliary Feedwater Turbine-driven Pump i AT-44-02 Steam Generator Blowdown Hot Functional PT-45-06 Containment and Pump Room Coolers PT-49-02 Sea 1 water and Letdown Flow PT-49-05 Boron Thermal Regeneration AT- 54-01 Gland Steam PT-55-03 Pressurizar Relief Valves PT-55-05 Pressurizer Level Control PT-55-06 Pressurizar Spray and Heaters '
PT-55-09 Reactor Coolant Pumps PT-55-10 Pressurizer Pressure Control PT-55-11 Thermal Expansion PT-57 -09 Safety Injection Check Valves PT-58-02 Residual Heat Removal at Hot Functionals AT-62-05 Turbine Roll ) PT-74-02 Incore Thermocouple and RTD Cross Calibration PT-91-01 Loose Parts Monitoring G e .. .%. , . e =*=-
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. 6 The NRC inspectors are periodically witnessing these tests to verify the following:
- a. Procedures in use are approved and being fellowed.
- b. Changes to procedures are made and approved in accordance with the procedures , controlling change.
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- c. There are an acMquata number of personnel assigned to perform the test. ,
- d. There is adequate coordination between members of the test group.
- e. Necessary support systens are operational to conduct the pre-scribed tests.
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- f. That the test procedures, operation of equipment and results achieved, approximate the operating Characteristics and data that
. would result if the plant were operating with fuel in the reactor I vessel and at normal operating parameters. Several problem areas have been encountered. The major areas are:
- a. Erratic behavior of RCP seal flows
- b. Thennal expansion l c. Letdown orifice size These items are presently being evaluated by the licensee.
1 ( The licensee is using the station operating and initial operating proce-dures to perfonn steps in conjunction with the preoperational test procedures, such .as valve lineups and equipment sequence operation. This performs two major functions. First, to give the necessary detail to perform specific preoperational test functions by referencing plant procedures and to verify that the plant procedures are valid. Where this cannot be done using a plant procedure or preoperational procedure due to unforeseen conditions, procedure changes are made. The methods available are to change the pre < garational test procedure using CP-SAP-12,. Rev. 2, " Deviations To Test Instructions / Procedures," or STA-205, Rev. O, " Temporary Changes to Procedures" (i.e. , plant procedures). On March 7,1983, during a review of the logs and procedures used to draw a bubble in the pressurizer on the previous day, the VRC inspector noted ten steps of IPO-001A, Rev. O, " Plant Startup From Cold Shutdown To Hot Standby," had been changed. Further review revealed thectwo changes had been accanplished using the appropriate change procedure but the remain-ing eight had not. - l
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. 7 These changes could have been made to IPO-001A to make the steps appli-cable to the functions being performed using STA-205, Rev. O. Temporary.
changes to procedures, or the changes could have been made to PT-55-02, Rev. 2, " Hot Functional Test Sequence" using CP-SAP-12 Rev'. 2, " Deviation To Test Instructions / Procedures," to include the steps necessary to per-form the functions. However, neither of these options were used, therefore the required reviews of the changes were not performed. This is considered a violation of Appendix B to 10 CFR 50. (8308-01) 4 Part 21 Followuo The licensee has received a 10 CFR 21 report from Westinghouse Electric Corporation concerning reactor trip circuit breakers, type DB-50. The NRC inspector will review the licensees response to this item. (8308-02)
- 5. Plant Tours During this reporting period, the SRRI conducted several inspection tours of Unit 1. In addition to the general housekeeping activities and general cleanliness of the facility, specific attention was given to areas where safety-related equipment is installed and where activities were in progress involving safety-related equipment. These areas were inspected to ensure that:
- a. Work in progress was being accomplished using approved procedures.
- b. Special precautions for protection of equipment was implemented, where required, and additional cleanliness requirements were being adhered to, where required, for maintenance, flushing and welding activities.
- c. Installed safety-related equipment and components were being protected and maintained to prevent damage and deterioration.
Also during these tours, the NRC inspector reviewed the control room and shift supervisors' log books. Key items noted in the log review were:
- a. Plant status
- b. Changes in plant status
- c. Tests in progress
- d. Documentation of problems which arise during operating shifts No violations or deviations were identified.
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- 6. Plant Status The following is a status of TUGC0 manning levels for operations and plant testing activities as of March 31, 1983:
- a. Operations Manning Status Authorized Personnel Level (including maintenance, operations, adninistration, quality assurance, and engineering) - 473 Number Presently Onboard 412
- b. Plant Testing Status Total Number of Preoperational Tests - 141 Number of Preoperational Tests Through Draft - 139 Number of Preoperational Test Approved (JTG).- 128 Total Number of Acceptance Tests - 48 Number of Acceptance Test Through Draft - 47 Number of Acceptance Test Approved - 46
, Test Completion Status Preoperational Tests - 52 Acceptance Tests - 33 No violations or deviations were identified.
- 7. Exit Interview .
An exit interview was conducted March 31, 1983, with licensee representa-tives (identified' in paragraph 1). During this interview, the SRRI reviewed the scope and discussed the inspection findings. i G em .e ae m --.M ,h+e 8 W- -- - - "
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- nel that eight changes to IP0-001A, Rev. O, were made without the proper i review and approval as required.
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' TEST DEFICIENCT REPORT Revision 6 Systen senas.
Page 8 of 8 hxAinaomfa_ TDK No.:___ ja/ f.
, Composent Tag Bo M/- ##@-d / Fase / of /
4 Safety Esafety
, Startup System No.: $~M T I Test Instruction / Procedure No.:
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8 Startup Systaa No.:WC i Tsat Imatruction/ Procedure No.: 25 u .
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Omses.urassiseensa '" m e simet.42t,u s e m s - A O'*VS COEctny Maf 19, is83 GTN 65740 Ta'xas Utilitian Cana:ating Company Post Offica Box 1002 WGMTioff n" Glen Rose, Texas 76043 Attention: Mr..J. 3. Gaerga . Vico Presidant/ Project Gan. Manager Centlemens. TEXAS UTILITIES GENERATING COXPANY . I CCMANCHE PEAX STEAM ILZ::nIC STATION GG PP.CJEC7 NC. 2322 i TUGCQ TEST DEFICIENCY 23 PORT No. 1017 l REF: CPPA-30.131 l Th6 Turbine Driven Auxd 14 ary readwater Pur:p (TDAFP) is provided in conjunction with two (2) Motor criven Auxiliary Feedwats: Pumps (MDATP as diverse =eans of supplying vaser to the secondary side d) f the Steam Generator during Plu: , Upsat of Faultad conditions. The TOA7P is nee intanded to opente during plant Nor=cl Oparating Canditions excopt for short paricds maaaurai in minutaa during tasting. The IIVAC Systa= p cvidad for Roca 474 is designed to operate only during Plant U0 -41 l Cht'ditions . The six hour test perfc::3d by TUGO '#12 t.*1:efere greatly in. excass of the test tir.a :5.!uiraf anj the t2sys:sture data are invalid fer 71&nt Ucrr.a1 Cyaret:.ng C:nditions. . (.. _ j t, < 3 . a y Q A' *=~ /2 7) i I a*=.- * . = . * * - - - _ - I, p . .. ~ 1.- g y.g. .
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W fN GTN- 65740 May 13, 1981 ( g. . . .
-l-f During Plant Upset Conditicas the EVAC System is not 8p operating and the TCATP will only start in the unlikely event a " Blackout" occurs. When this occurs the on-sitt Emergency Diosal-Ganerators will be available to power the TDAFP's within one minute. Assuming a singla failure of a TDMP as well as the off-sits bisckcut, the remaining HDAFP and the TDA?P centinues to op6:ste. Within thirty minutes the Staam Canarator water demands havo decreased to the point whera only one auxiliary feedWater pump is required to operate, and the TDAFP can and should he shut down.
Tho heat loss from the TDAFP -is assumed to be dis-sipated into the conerste heat sink allowing a small camparature excursion. s In the case of Plant raulted condition auch as a Main 7eedwater Line Rupture or a Main steam Line Break, the TDAFP will automatically start. As soon as the cors stabilitos, the water demand decrease and the TDAFP can be shus down as described. The tisa duration in this ~ r:se =ayr hcwever, he sc=owhat greater due to the "# e required to, stabilize the core and possible delay ist operator action. sased on nELE considerations please note that a commitment to theiNRC to limit.tha.use of the TD1JP also precludes operating this pump for any long period of time.* It is therefore concluded that although the II instru=en-tation located within Roca #74 is qualified for a temperatura of 104*? for nor=al plant operacion and 122*r for accident ccnditions, excursions in temperature above 104*F for a short time will not derate this instrumentation. Based on the abcVe statements regarding ths Operation of the TDAFD and the .?IAC systams we see ' the nVAC System design for Roca $74. no concern with l Very truly yours, GI33S & HILL, UTC. J I\T h ' h.'1, pfh di g Rr23-M70-Di'G , BN-EN: a c f i r. aster Robert E. 3allard, Jr. Prefect utnager
%j CO2 1.D.3 (3SR Sits) OL M. McBay (TCS Sito) IL e p , f. p K. McDonsid (Tesz site) 1L R.D. Caldce (TrJSI Site) IL g gg y
WE EXHIBET 863 ITDI 25 Informacion provided as requested l l m, .o s:an F U ff t v v v i
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' Preoperational Test Summary
- Containment Integrated Leak Race Test ICP-PT-75 Rev. 0
. .. . STE. ,
This test satisfied all acceptance criteria and successfully demonstrated the structural integrity and leak tightness of the unit one containment. The reduced pressure test was successfully completed on the first attempt, however, the peak pressure test was not successfully coupleted until the third attempt. The three attempts at the peak pressure test were a result of numerous laaks that were encountered in - the steam generators and associated piping and instruments. The ==v4 == allowable leakage rate at reduced pressure (LC) was determined to be
.03631%/ day. Both the reduced pressure measured leakage race (Lea =
.02559%/ day) and the peak pressure measured leakaga rate (Lan=.05936%/ day) were less than 75% of their respective maximum allowable leakage rates (Lc & La) . The accuracy of the peak and reduced pressure test were successfully verified using the superimposed leakage verification method.
Restoration is complace from integrated leak rate testing and measured leakage valves demonstrated that Unit .1. Containment is ready for operation. A total of 24 test procedura deviations were written, of which two . required JTG approval. There were six test deficiencias identified which are discussed below. There are no open items at the conclusion of testing. TDR 562 4 574 These deficiencies were issued as a result of measured leakage races greater than acceptance criteria during tihe las and 2nd attempts at the peak pressure test. The cone =4 - ne was depressurized and entries made to correct leaks and valve lineups associated with the steam - generators and connecting piping. After making corrections, a third peak pressure cast t'as sucessfully performed. TDR 587,566 These deficiencies were issued as a result of leakage
& 565 through electrical penetrations E62. E49, and E68. Each penetration was isolated during the peak pressure test to reduce overall peak pressure test leakage. Penetration E62 leakage mechanism was readily identified and successfully corrected. However, penetrations E-68 and E-49 exhibited uni-directional leakage and required performance of a special test (1CP-SPT-5) to identify the leakage mechanism and substantiate the repair as satisfactory. E62, E49's E68 were all successfully repaired and local leak race tested.
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TDE 567 This deficiency was issued as a result of leakage through l personnel airlock interior end differential pressure switch vent valve. The-valve vaa replaced. prior to the ) third peak pressure test. The syntes test engineer recommends approval of the test as performed. 22 Date W93 rtup est g se t u,,,t s IMuK .e. .J ,u m ./ D' , . O DATA EXTRACTED FROM TEST INPROGRESS OR UNDER REVIEW , .~ . .
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-- ColfIAINtENT IlffECRATED LIAK RATE TEST 1.0 TEST OBJECTIVES
.- Note . . ,
Appendix A to this test procedure contains a list of abbreviations and mnemonics used in this procedure
- and their associated
. definitions.
1.1 Verify to a confidence level of 95% chat the primary reactor cont =4=aant overall leakage race (Lam) is less than 75% of ths. =ar4== allowable leakass rate (La) at the calculated peak pressure related to the design basis loss of coolant accident. 1.2 Determine the reduced pressure test maximum allavable leakage rate (Lc). The computed value of Le shall be used as the basis for subsequent periodic test acceptance criteria. 1.3 verify to a confidence laivel of 95% chat the primary reactor containment overall leakage race (Lem) is less than 75% of the maximum allowable leakage rate (Lt) at one-half the calculated peak pressure related to the design basis loss of coolant accident. 1.4 Provide the controlling procedure for pressurization of the primary reactor containment to satisfy the require-sehts of the Integrated Leak Race Test (ILRT) 1-CP-PT-75-02. Structural Acceptance Test (SAT) and the Containment Rydrogen Purge Supply and Exhaust System Test 1-CP-PT-46-01. 2.0 ACCEPTANCE CRITERIA
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sfLJ 2.1 Raduced Pressure Test 2.1.1 The 95% upper confidence limit (UCL) of the measured leakage rate (Lem), plus all local . leakage rate additions, shall be less than 752 of the ==v4=2= allowable leakage rate (Lc) at a containment pressure of 24.05 (+L.O. -1.0) psig where: Le = La (Lem/ Lam) for Lem/ Lam 0.700 M 1P0W T Le = La (Pt/Pa) , forLcm/Lamh0.700 This criterion is based upon CPSES Technical Specification 3.6.1.2 and 10CTR.50 Appendix J. Verified in Section 7.2.1. - DATA EXTRACTED FROM TEST INPROGRESS OR UNDER REVIEW
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ev=c Tag Not M - d2 Sdety ] - Non-Sdety'"~ _ f Startup System No. TEN Test Instruction /Frocedure No.: /(/7. M- 7C. 02 DESCIIFTION OF DITICIDCT: F1rs/ / T /t rJ L /9?N'F7"X'#-r/(' rV 6-L3- /4 L C-AWi m/ t 77htfer/ A H. k' t 01;r-t Operation May _May Not continue until Corrective Action is couplete:
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Ina lated By: Date: / ')I~- M Engin'eering Evaluation of Deficiency Required: ] Yes { No Reference Documents for Engineering Evaluacion: N Corrective Action / Retest Approved By: Date: /'3["l~/ Corrective Action Compteted: Date: 7[-f3 1stest Satisf actorily Completed: Dace, 2 -P f 3 er /
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Oc w r,s . ),n c,.W w CC11ECflTE ACTION: h cecmMc s rH c $ ps.( ) - d** 1 MTecaseoe ATC e4o 6 o po. a r s Ar ~/,,$ p s . , t,' ) 2. r,i g Fot 3 t 'I" g Wf M % -o I p o m p o e. n u e t- , w sw Ccuh3)C oc, ptess.::.ert o A M ANON.PCN. '8857- ' T #* A a.h ?easrwec , o a xP..c r- pne L.cn w+e.c -) Qc(o.c Ic2kO. ius ew an. Sce's ka Psurnansa ro tsc wryrc~ so ^~o \ a pa.eco g f grqao . kcPctcarf YY "II-01 f:* 2 - ElWO W4 % f fin $ I. 4 EIQUIZID RITEST: kc92csnuC.'tcc C'.eu-A U
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- A" " CF-5AP-L6 8 F l f Ravision 6
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- N Startup Systet No.:M Test Instruction / Procedure No.: /d-k- 7f- 2.
DESCRIPTION OF DEFICIZ3CT: IA.h-sn ,a tt F1W GOT VAIN Qars,
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he 0 P- coat-ool FIer u ee @to l'21-J P Camponent Operation 1May _May Not continue until Corrective Actiers is complete: CORRECTIVE AC" ION: hedl Ac t IA sh U Alvs 90cm tiO*r 81 9e ttweel MR. eu ' ('i .< n, r , - m . , , , , - . . . , a un un usu.anaturJ udtl l szquuzD nErzsT: Ic9- VT- 7s~-I %I Lsn Raw T557 - os+s si k Initiated By: Date: / ~ b '"I3 Engineering Evaluation of Deficiency 1 squired: ]Tas No Esference Documents for Engineering Evaluation: M /. Corrective Action /Estest Approved 37: Date: / .2M/~f Corrective Actica Completed: Datie: J4fpsy Systes se sin Estest Satisfactorily Completed: Date: s2foWf83 Systea .
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