Text

Loss of Offsite Power Transient Test of Nuclear Svc Cooling Water Sys
	ML20212B144
Person / Time
Site:	Vogtle
Issue date:	10/22/1986
From:	; BECHTEL GROUP, INC., GEORGIA POWER CO., SOUTHERN COMPANY SERVICES, INC.
To:	;
References
	NUDOCS 8612290179
	Download: ML20212B144 (179)
	v • d • e

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LOSS OF OFFSITE POWER TRANSIENT TEST OF THE NUCLEAR SERVICE COOLING WATER SYSTEM V0GTLE ELECTRIC GENERATING PLANT, UNIT 1 Table of Contents 1. Introduction 2. Conclusions 3. LOP Transient Description 4. Test Description 5. Instrumentation 6. Test Results 7. Waterhammer Evaluation 8. References 9. Tables and Figures I l Bechtel Western Power Corporation gt,I"' l October 22, 1986 \\ oP< @ f s$ sa's

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Loss of Offsite Power Transient Test of the NSCW System for VEGP, Unit 1 1. Introduction Transient analyses of the Vogtle Nuclear Service Cooling Water (NSCW) system have predicted that simultaneous tripping of the NSCW pumps following a Loss of Offsite Power (LOP) and subsequent pump restart may result in excessive loading on the piping and pipe supports because of potential waterhammer. To resolve this concern, system. modifications

have lbeen performed"to reduce the severity of this transient (Reference.2).

These modifications include addition of theJ following: 1. Motor operators to the pump ~ discharge valves.and c cooling - toweri return v'al'ves. 2. Check' valves to' heat exchanger _ inlet lines., 3 Train:A/ Train B1 crossties. 4. Pump discharge valve bypass line. 5. System restart logic changestand a capabilitysto throttle the tower return: valves'. A series of tests were performed from June 25, 1986 to July 1, 1986 on Unit 1 Train A NSCW in accordance with special test procedure ST-11. A similar set of tests were performed for Train B from August 12, 1986 to August 18, 1986 in accordance with special test procedure ST-13 These tests were conducted under the direction of Nuclear Operations with assistance from Bechtel Engineering. Data on system performance during the LOP transient restart were reviewed to establish final settings for the tower return valves (Train A valves HV-1668A and B, Train B valves HV-1669A and B). System verification tests were run with final valve settings to demonstrate that restart of NSCW following an LOP transient could be accomplished within the allowable limits of the system design. 2. Conclusions /* ([\\ Tables Al and B1 in Section 9 list the various tests performed on the Unit 1 NSCW system with the conditions and results of each test. For Train A, 35 valid test runs were made: 15 runs on the tower bypass valve HV-1668B and 20 l_ runs on the tower spray valve HV-1668A. For Train B, 21 valid test runs were made: 9 runs-on the bypass valve HV-i U.M./ 1669B and 12 runs on the spray valve HV-1669A. Final valve V;hs positions were confirmed by simulating the complete LOP transient and verifying that the resultant pressur'e f'\\ transients and piping system observations were within I acceptable limits. d l 2

Restart of NSCW after an LOP can be performed automatically using the valve positions indicated above, provided that the design changes made by'CCP B10130M Revision 0, Revision 1 and Revision 2 are implemented. This assures that the valve and pump operations are sequenced to give a slow fill prior to full flow operation. During testing of Train A, two inadvertent waterhammer events were experienced, runs 14 and 15 (Figures A19-A26). One event was caused by an incorrect temporary jumper and another was caused by a premature manual pump start. Transient pressures as high as 400 to 500 PSIG were recorded. However since 4 of the 5 pressure transducers were damaged by the waterhammer, we believe that the recorded pressures are not accurate and the actual transient peak pressure was approximately 900 PSIG. An NSCW transient recovery program was established to resolve concerns on the effects of the waterhammer on Train A of NSCW. The program entails inspections and evaluations to assure that the system can perform its intended design functions. To date, the only identified anomalies resulting from inspections are three potentially damaged snubbers. These snubbers are being examined to determine the cause of failure. Based on the inspections and evaluations completed to date, we recommend that operation of the Unit 1 NSCW system be continued. Upon completion of all the transient recovery program inspections, a final assessment of the Unit 1 NSCW system capability to perform its intended design function for its design life will be made. In summary, the conclusions are that: A. Train A - With HV-1668B set at 12.50 +2.50 in the bypass mode and HV-1668A set at 100 12.50 in the spray mode, the maximum peak pressure is within system allowables and no loss of piping pressure boundary integrity or unacceptable pipe and pipe support movement occurs. B. Train B - With HV-16698 set at 12.50 2.50 in the + bypass mode and HV-1669A set at 7.So [ 2.50 in the spray mode, the maximum peak pressure is within system allowables and no loss of piping pressure boundary integrity or unacceptable pipe and pipe support movement occurs. C. The test demonstrates that with the system setup as described above (A and B), observed transients were of limited magnitude such that the integrity of the piping pressure boundary, pipe support structure and equipment were not affected. 3

~.-. 4 4 13 LOP Transient Description A simplified schematic of the system is shown in Figure 1. Under normal plant operation, one train of NSCW is operating and the other train.is in a standby mode and is kept filled t by the operating train. During an LOP, the pumps on.the operating train trip and the motor operated valves remain open. -A portion of the NSCW piping and components at higher elevations drains through the open tower valve creating voids and water column. separation in the system (Figure 1 3 schematically shows the extent of voiding). After station emergency power. is restored by the diesel generators, the pumps restart and begin to rapidly refill the voided piping. If this process is uncontrolled, the high refilling water column velocity'would produce severe waterhammer (high energy pressure wave initiated at the water columns. impact i point and propagating into the surrounding water filled pipe). An inadvertent event represented by run #15 (Figures A20 - A26) shows the results of this type of waterhammer. Design modifications were made to the NSCW system to mitigate the effects of an LOP transient waterhammer. Logic e changes..and. pump discharge bypass piping were :added-.by1CCP B10130M:to slowly ~ fill-the-voidedJpiping prior to normal 1 s ystem. o per ation. Figure 1 shows the bypass piping, and t Figure 2 shows the restart sequence following an LOP. Hydraulic transient analyses were performed to determine forcing functions based on the modified system design. These forcing functions were used as input to computer models of the piping systems to determine dynamic loads for design of the pipe and pipe supports. Preliminary results / obta_ined_by_both Bechtel and V-SAMU indicated that this may j. le, a_d_ to unnecessarlprofet cWits to - perform the analyser _ l and may also result in a schedule fmpact due to the lengthy i time _ pfiod requiredTTreliminary analytTeal results l obtained also indicated that numerous changes to pipe supports may be required using this approach. Due to the y time, cost and effort involved in continuing with this approach, it was determined that the most cost effective resolution was to perform a series of tests to establish the intermediate position ~~TFt1re tower v alver t!UFing system re' fill and to verify ~that the system in ics final deYtgn configuration can restart arter 3n LOF 1,causieni, with no adverse effects (Reference 3). j j 4. Test Description The scope of this test includes the Unit 1 NSCW system operation in the normal mode (using the cooling tower sprays via HV-1668A for Train A and HV-1669A for Train B) and in the bypass mode (returning flow directly to the basin via i l 4

HV-16688 for Train A and' HV-1669B for Train B). For Train A testing, Special Test Procedure ST-11 " Nuclear Service Cooling Water System Loss of Offsite Power Transient Analysis" was written by Nuclear Operations with assistance from Engineering. The computer model had predicted that throttling of the spray and bypass valves was necessary to slow fill the system in the required time with minimum pressure transients. The test was set up to first run the system with a very conservative valve throttle position (450) and slowly decrease the throttle position until the system refill was accomplished in the required time with the pressure surge minimized. The test consisted of 10 sections as described below. Paragraph numbers correspond to ST-11 section numbers. 6.1 Preliminary Fill Rate Pressure Measurements This section determined the NSCW header pressures measured by a test gage at PT-1636. The data was used as a secondary means of determining the status of system re-fill. The primary means of determining system re-fill status was the pressure transducer readings. 6.2 Train A Tower Bypass Valve HV-1668B Fill Position Determination (Runs 1 through 13, Figures Al-A18) The LOP transient was simulated from loss of power i (t=0 sec) to pump discharge valve opening (t=85 sec) in accordance with the time sequence shown in Figure 2. Bypas: valve intermediate opening position was varied from 450 (run 1) to 7.50 (run 13). 6.3 Train A Tower Spray Valve HV-1668A Fill Position Determination (Runs 14, 20 through 33, Figures A19, A27-A44) The LOP transient was simulated from t=0 see to t=85 sec. Spray valve intermediate opening position was varied from 450 (run 20) to 7.50 (run 33). 6.4 Train A Bypass Valve Loss of Power Transient (Runs 15, 34, Figures A20-A26, A45, A46) The LOP transient was simulated from t=0 see to t=100 sec, which was normal system operation. The bypass valve was set at 12.50 for this test. 5

, _ ~ 6.5 Train A Tower Spray Valve Loss of. Power Transient (Run 35, Figures A47, A48) The LOP transient was simulated from t=0 to t=100 sec. The spray valve was set at 100 for this test. 6.6 Supplemental Train A Spray Valve HV-1668A Fill Position Determination (Run 16, Figure A27) This test supplemented the 6.3 tests by setting the spray valve at 450 and opening the spray valve

5 sec before pump start.

6.7 Supplemental Train A Spray Valve HV-1668A Fill Position Determination (Run 17, Figure A28) This test was similar to the 6.6 test except that a 6 sec delay was used for pump start. 6.8 Supplemental Train A Spray Valve HV-1668A Fill Position Determination (Run 18, Figure A29) This test was similar to the 6.6 test except that a 4 sec delay was used for pump start. 6.9 Supplemental Train A Spray Valve HV-1668A Fill Position Determination (Run 19, Figure A30) This test was similar to the 6.6 test except that a 2 sec delay was used for pump start. 6.10 Bypass Drain Down Time Test i This test was run to find the time required for the system to drain down when the bypass v 1ve i (HV-16688) was opened 12.50 (92.6 sec drain down time). I The original plan was to test the system in the order of test procedure sections 6.1 through 6.5. However, the 2 waterhammer experienced during run 14 (6.3), raised concerns about the sensitivity of the tower spray valve (HV-1668A) position to system refill time. Sections 6.6 through 6.10 I were added to the procedure to test the spray valve in a l more conservative manner than originally planned. For Train B testing, Special Test Procedure ST-13 " Train B Nuclear Service Cooling Water System Loss Of Offsite Power Transient Analysis" was used. This test was based on the ST-11 procedure but was slightly modified using the l 6

experience gained from the Train A testing. The test consisted of sections as described below. Paragraph numbers correspond to ST-13 section numbers. 6.1 Train B Tower Bypass Valve HV-1669B Fill Position Determination (Runs 1 through 8, Figures B1-88) Same as ST-11 section 6.2. Bypass valve intermediate opening position was varied from 250 (run 1) to 7.50 (run 8). 6.2 Train B Tower Spray Valve HV-1669A Fill Position Determination (Runs 9 through 14, 20, Figures 39-B14, B23) Same as ST-11 section 6.3. Spray valve intermediate opening position was varied fron 200 (run 9) to 50 (run 20). 6.3 Train B Bypass Valve Loss of Power Transient (Run 15, Figures B15, B16) Same as ST-11 section 6.4. The bypass valve was set at 12.50 for this test. 6.4 Train B Tcwer Spray Valve Loss of Power Transient (Run 16, Figure B17, B18) Same as ST-11 section 6.5. The spray valve was set at 100 6.5 Train B Spray Valve Loss of Power Drain Down Transient (Run 17, Figures B19, B20) This was similar to the ST-13 section 6.2 test except that the time from LOP to power restoration was revised from 15 seconds to 4 hours. It simulated a station blackout (no offsite power and l no emergency diesel power) for 4 hours. The test determined the effect of an extended drain down l including air in-leakage to the system. This test was run with the spray valve set at 100 6.6 Train B Tower Spray Valve Loss of Power Transient (Runs 18, 19, 21, Figures B21, B22, B24) Same as ST-13 6.4 The spray valve was set at 12.50 (run 18), 7.50 (run 19) and 50 (run 21). l 7 t

A typical test setup was as follows: o NSCW pumps were operated from the Control Room. o NSCW pump discharge valves and tower return valves were operated from temporary test switches in the NSCW pumphouse. o Pressure and flow data were collected and recorded at a station in the NSCW pumphouse. o Test observers were stationed at selected system locations. The NSCW system was placed in a normal operation mode, returning flow to the tower via either the bypass valve (HV-1668B or HV-1669B) or the spray valve (HV-1658A or HV-1669A) depending on the mode and train to be tested. The LOP transient and system restart were simulated by a combination of manual and automatic actions in accordance with Figure 2. After each test, the recorded pressure data (see Figure A1 for a typical example) and test observer observations were reviewed. After this review the next testing step was determined, and a piping system walkdown was performed if a significant transient occurred or the test procedure required a walkdown. Table A1 (Train A) and Table B1 (Train B) list the tests in the order run and indicate when piping system walkdowns were performed. Table A2 (Train A) and Table B2 (Train B) are listings of the test observer records and the piping system walkdown results. t The test observer records and walkdown results showed no significant piping movements except during the Train A waterhammer events, runs 14 and 15. The test observers were trained Bechtel engineers who used the following criteria as bases for their inspections: a. Using marked reference points on piping, look for pipe movement relative to supporting steel members. Measure and record the length and direction of piping movement. By placing tape on the piping in strategic locations, observe shift in tape locations and damage to tape to record pipe movement. b. Look for indications of dented pipe, bent pipe, broken or bent vents, drains and small bore branch i piping. c. For pipe supports, look for indications of cracked welds, bent or damaged support members, loose anchor bolt nuts, loose base plates and other loose hardware. [ l l l

d. Using a pre-test walkdown as a reference, establish baseline data for observation and record any piping or pipe support anomalies noted. An engineering evaluation of the Train A and Train B piping layouts selected pipe supports.and piping isometrics to be included in the. walkdown scope. Criteria used for piping and pipe support selection were that the most significant loads uould be expected in relatively long, straight piping runs of: greater than 50 ft. for 4 in and 6 in. piping; greater than 30 ft. for 8 in. and 10 in, piping; and greater than 25 ft. for 16 in, through 24 in. piping. Table A3 lists the specific items included in the Train A wall: downs and Table B3 lists the Train B items. 5. Instrumentation Locations of instrumentation used in the tests are shown in Figure 1. The types of instrumentation used during the test are described below: a) Pressure transducers Train A, ST-11 Five pressure transducer locations were used (see Figure 1). Test locations wer'e chosen based on the analytical model of Train A NSCW. Piping sections experiencing voiding (CCW Heat Exchanger, ESF Chiller, Containment Auxiliary Cooler) and piping.with potentially high transient pressures (RHR Pump Motor Cooler, Diesel Generator Jacket Water Heat Exchanger) were monitored. For test runs 1 through 15, Microsystems model ME-901-0288, i 0 to 300 PSIA pressure transducers were used. During test run 14, the Auxiliary Cooler pressure transducer was damaged and was replaced with an identical instrument. During test run 15 the Diesel Generator, CCW, ESF and Auxiliary Cooler pressure transducers were damaged and were replaced by Microsystems model ME-901-0289, O to 400 PSIA instruments. Test runs 16 through 35 had no further problems with pressure transducers. Train B, ST-13 Based on the computer model results, the five pressure transducer locations used in Train A plus one additional location (Reactor Cavity Cooler) were used for Train B. Test locations were chosen for all voided piping (CCW, Containment Auxiliary i 9

Cooler, ESF Chiller) and high pressure locations (RHR Pump Motor Cooler, DG Jacket Water Heat Exchanger, Rector Cavity Cooler). To assure that peak pressures could be measured if a waterhammer occurred, a wide range pressure transducer was selected for Train B. For test runs 1 through 17, Microsystems ME-901, O to 5000 PSIA pressure transducers were installed. After test.run 17, concerns were raised as to the accuracy of the instrument readouts in the 0 to 300 PSIA range. The pressure transducer installed at the Containment Auxiliary Cooler was reading as low as -60 PSIG during system drcin down. This instrument was removed from the system and recalib;ated. It was found to be in error for readings below 0 PSIG but read correctly for pressures greater than 0 PSIG. To eliminate the concern of instrument accuracy, all pressure transducers were changed to Statham Model PA418-500, O to 500 PSIA, for test runs 18 through 21. Except for the Containment Auxiliary Cooler negative pressure readings on runs 1 through 17, the pressure transducer readings for runs 1 through 17 were equivalent to those for runs 18 through 21 which indicated that the O to 5000 PSIA transducers were giving reliable results. b) Pressure Records Pressure transducer data were recorded by a high speed chart recorder, Honeywell 7 channel Visicorder, and a magnetic tape recorder, Teae 7 channel cassette recorder. Figures Al-A48 and B1-B24 are copies of the chart recorder outputs. Since use of the cassette tape records requires the special 7 channel tape recorder, Bechtel will maintain the tape records. If additional chart recorder outputs of specific time histories are needed, Bechtel will furnish the chart recorder records on request. c) Test Pressure Gage System pressure was monitored by a test gage installed at PT-1636, Train A and PT-1637, Train B in the NSCW Pumphouses. A 0 to 200 PSIG Heise gage was used. l l l l 10 l l

d) Test Pressure Differential Gage System flow during the refill portion of the LOP transient restart sequence was tonitored by a test pressure differential gage installed at FE-5731, Train A and FE-5732, Train B. e) Stopwatch A calibrated stopwatch was used by the Nuclear Operations test engineer to time the simulated LOP transient (Figure 2). 6. Test Results The test results are presented in two parts: Section I Describes the phenomenon of system drain and refill. Section II - Describes the test results (including field observations), compares differences in the results of the two trains and provides justification for their acceptance. The detailed discussion for these sections is included below: Section I Figure 1 is a simplified schematic of the NSCW system showing elevation of various components and piping. Following an LOP, high points in the system will be voided. The portions expected to be voided in the spray and bypass modes are identified in Figure 1. Theoretically, atmospheric pressure can support a water column of about 30 feet above the water surface. Therefore under steady state conditions after draining the system, the water level should be about 30 feet above the discharge point as indicated in Figure 1 (Elevation 266 feet for spray f mode and 250 feet for bypass mode). This is also called the vapor line. Hm ever, due to the inertia effect of flowing water and the s/ stem configuration, water will not stop at the vapor line elevations on pump trip following an LOP. The water surfaces will oscillate around these points and finally come to rest at some lower elevation. The components and piping located well above these locations do not get filled by this oscillating flow. The components and piping in this region will be subjected to repeated filling and voiding as the water column moves up and down. This is known as " sloshing" behavior. " Sloshing" behavior is not i 11

,,f& ~ ^ sy 2; L expected to occur when operating in the bypass mode because the components and piping in the voided region are above 250 feet elevation (vapor line).. In the spray mode, the CCW Heat Exchanger f alls in the marginal range (260 feet elevation) where " sloshing" is expected following a pump trip. Due to the more extensive horizontal piping runs on Train B, it is expected that the Train B spray mode would have more of the " sloshing" effect pressure surges. A long horizontal piping run in the critical " sloshing" zone is more susceptible to localized column rejoining due to the greater volume of water contained in the piping. Figure 5 is an isometric comparison of the Train A and Train B CCW discharge piping layouts. Section II Figure 2 outlines a restart sequence of the NSCW system following an LOP event. The sequence is divided into four sections: system draining, isolation, slow refill and fast refill. Column rejoining and consequent pressure surges are expected in the slow refill and fast refill modes.' Comparisons of the spray and bypass valve test results are shown in Figure 3 and Figure 4. In Figure 3, the spray valve operating mode shows pressure spikes during system draining (pump trip), slow refill (pump start and fill) and fast refill (discharge valve open). The Train B pressure spikes are greater than Train A due to the " sloshing" effect following a pump trip as discussed earlier. Figure 4 shows a comparison of pressure traces of the Train A and Train B 1 bypass mode operation. Pressure spikes occurred only during the slow refill (fill) and fast refill (discharge valve open) modes. Maximum pressures are summarized in Table 1. At the final valve settings, peak pressures are: Train A Train B Spray valve 100 110 PSIG Spray valve 7.50 - 260 PSIG Bypass valve 12.50 - 160 PSIG Bypass valve 12.50 180 PSIG The acceptance criteria used for Train A was that the maximum peak pressures should be equal to or less than 1.2 1 l times the system design pressure as permitted by the ASME i III code. The1 code allows system-design pressure to be exceeded by,20% for less than 1% of the time. The peak pressure experienced during the restart transient lasts approximately 50 milliseconds or less. The piping design pressure is 200.PSIG and the corresponding acceptance criteria is 240 PSIG (1.2 x 200 = 240 PSIG). The most limiting. component-design pressure 'is 150 PSIG with a 180 l -PSIG acceptance criteria. Since the peak Train A pressure is 160 PSIG, Train A test results meet the acceptance criteria. 12

Three-components (Reactor Cavity Cooler and associated piping, ESF Chiller, and DG Jacket Water Heat Exchanger) in Train B did not meet this acceptance criteria. Additional

testing was performed to establish if valve settings different than those used for Train A would reduce the peak pressures.

Confirmation runs were made for four Train. B spray valve positions (instead of only one confirmation run on the Train A spray valve), and it was determined that a 7.50 setting resulted in the minimum peak pressure of 260 3 PSIG. The, acceptance criteria-for3 r,ain Bmwere-revis ed uto l ~ T be based on component;and+ piping,[~ydrostatic test,pgessures; '""~ ~' based on the followinggationale. o The hydrostatic pressure has a margin of approximately 50%.of material yield strength based on Code requirements. o The overpressure duration is extreaely short. It is a single peak of approximately 50 milliseconds or less and is not enough to lift relief valves. J 9 j o Stresses on piping and components from 20_to 40 ~ 3 cycles of short duration have no effect on the per5sure boundary and are significantly below the material endurance-limit. 'i L o The use of hydrostatic pressures as an acceptance criteria for extremely short duration pressure pulses has been verified by discussions with r,1 vendors and a consultant. Q\\ o The peak pressure is less than the piping minimum b

> wall allowable pressure and there is no danger of pressure burst.

f Therefore using the hydrostatic pressure as an acceptance criteria, the allowable maximum pressures compared to actual pressures are: P Hydro P Actual ESF Chiller 225 -PSIG 200 PSIG DG Jacket Water 225 220 Reactor Cavity Cooler 300 260 For piping, the allowable versus actual pressures are: P Min. Wall P Actual L Piping (at Rx Cavity Cooler) 345 PSIG 260 PSIG Based on the above acceptance criteria, the Train B pressures are acceptable. i Piping and pipe support observations during testine are summarized in Table A2 (Train A) and Table B2 (Tra; B). In Train A tests, the NSCW pump discharge bypass line (isometric 13

T i 'e 1K5-1202-512-01) did not have all pipe supports installed prior to the test and did experience noticeable deflections during pump start. This line was inspected several times during the course of testing and no permanent displacements occurred. On Train B, the similar line (1K5-1202-516-01) also experienced movement. The Train B pipe had the required pipe supports installed and moved approximately 1/4 inch during pump start. This pipe is designed to be flexible due / to the pipe support arrangement, and a 1/4 inch movement was analyzed and found to_be acceotable. The Train A line was also fcund to be acceptable since movements.af ter all-pipe /~' l supports ~are installed are expected to be within acceptable limits as shown on Train B. After testing was completed, it was found that.some of the flow orifice plates FO-5725 through FO-5730) were bent in the direction of flow. This discrepancy was identified in ODRT-1-86-3591, and design changes were made to relocate the orifices to resolve the concern. Additional testing was performed to verify this design change, and it was found that under certain pump trip and quick restart conditions line movements could be greater t'1an the 1/4" measured previously. This condition is i

sssociated with normal pump start and is not a result of the

,-waverhammer or column separation phenomena. The engineering Levaluation is still in progress and will be the subject of separate correspondence. Other minor pipe movements were recorded during testing on Train B. All were analyzed and found acceptable. s Special Test A special test was run on Train B to simulate an NSCW restart after a 4 hour station blackout (Run 17, Figure B19, B20). This test was run with the spray valve (HV-1669A) set at 100 and only ran through the system refill mode. It did not continue through the pump discharge valve opening steps. c After the test, the pump discharge valves were opened manually 120 seconds after the pump start. Comparison of Figures B19, B20 with a normal restart, Figure B13, show that the transient pressures during drain down and refill are dampened out. This is due to air leakage into the system during the 4 hour period when a vacuum is maintained at the niping high points. During refill, air acts to cushion the system and minimizes peak pressures from column rejoining. Therefore sir.ce air enters the system during an extended station blackout, the restart transient is less severe (lower peak pressures) than the normal LOP restart with no air in the system. 7. Waterhammer Evaluation Two inadvertent waterhammers were experienced during Train A testing, not planned by the ST-11 procedure. During run 14 (Figure A19), the test plan was to operate the system in the 14

tower spray mode with the spray valve intermediate position set at 200 open. As a result of a missing jumper in the temporary wiring circuit for HV-1668A, the spray valve did not open at the time required (t=40 see on Figure 2). The NSCW pumps started to fill the system with no simultaneous drain down through the spray valve. The resultant quick filling of the voided piping produced a waterhammer at approximately t=46 sec. Peak pressures recorded by the test instruments were: Test Point Peak Pressure Pressure Vessel Design P1 Diesel Generator 140 PSIG 150 PSIG P2 RHR 190 PSIG 150 PSIG P3 CCW 130 PSIG 200 PSIG P4 ESF Chiller 250 PSIG 150 PSIG PS Aux Cooler >350 PSIG 200 PSIG Test point P5 pressure transducer was damaged by the~ waterhammer and was replaced. Test run 15 (Figures A20-A26) was planned as a test of the system in the bypass mode with a bypass valve position of 12.50 open. Due to premature manual starting of the NSCW pumps at t=15 sec (instead of t=40 sec), the NSCW pumps started to fill the voided system with the pump discharge valves fully open. A waterhammer occurred starting at t=18 sec. Peak pressures recorded by the test instruments were: Test Point Peak Pressure Pressure Vessel Design P1 Diesel Generator >360 PSIG 150 PSIG P2 RHR >350 PSIG 150 PSIG P3 CCWE >350 PSIG 200 PSIG P4 ESF Chiller >380 PSIG 150 PSIG PS Aux Cooler >400 PSIG 200 PSIG Test point P1, P3, P4 and P5 pressure transducers were damaged by the waterhammer and were replaced. An NSCW transient recovery program was established to determine the effects of the waterhammers on system integrity and long term operational capability. The recovery program was divided into a shor ; term investigation (Phase A) and a long term investigation (Phase B). The results of the Phase A review were transmitted in Reference 7 and documented in Reference 6. No abnormal conditions were found in any Phase A walkdown or evaluation. The Phase B program was transmitted in Reference 6 and consists of a one time inspection program to be implemented prior to fuel load to ensure that the system and components can perform their intended design function. System peak pressures due to the waterhammers are estimated to be approximately 900 PSIG. The system was inspected for effects of this pressure by: 15

5 System flow checks comparing post-transient read ing s o l with pre-transient readings o Heat exchanger leak checks [ k o Valve operability checks o Instrumentation reading checks m System piping and equipment walkdowns t o b [ The NSCW piping system was evaluated for waterhammer effects 1 i by: L o System walkdowns for damaged pipe and pipe supports h Analyzing pipe movements recorded during the test E o F [ To date, three snubbers at two support locations (V1-1202-181-H052, H045) have been found to be potentially damaged as I a result of the Phase B waterhammer investigation. There are two snubbers at each of these support locations. The ( snubbers have been sent to the suppliers for inspection and evaluation of the failure mode to determine if these i snubbers failed due to the waterhammer event. After the F Phase B inspection results (Reference 6) are received and [ evaluated, engineering will transmit final recommendations i on the NSCW transient recovery program. The final 2 recommendation is to be completed prior to fuel load and is f scheduled for November 21, 1986. 6 5 8. References 1) BG-33790 dated August 7, 1985 E

Subject:

Manual Start of the NSCW System to Preclude M Waterhammer E 2) BS-6200, dated October 8, 1985 b

Subject:

Design Changes to NSCW to Preclude f Waterhammer 3) PFE-11816, dated June 10, 1986 F g

Subject:

NSCW LOP Transient Verification Test 4) PFE-12101, dated June 29, 1986 b

Subject:

NSCW Transient Recovery Program 5) PEE-12177, dated July 3, 1986 = ?

Subject:

NSCW Train A LOP Transient Test Preliminary E Results 6) ODR T-1-86-2268 dated September 25, 1986 (not enclosed)

Subject:

Train A NSCW Waterhammer 7) PFE-12741, dated September 4, 1966 5

Subject:

NSCW Transient Recovery Program [_ 8) BG-34907 dated October 10, 1986

Subject:

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b b 9 TABLES AND FIGURES .p.y ,.3 ..~ 42 FIG 1 SIMPLIFIED NSCW SYSTEM PROFILE d';.. ,.)[J PI( .I3 2 i43Ct! 'RE-S ART A :TER ..O D N. TAB 1 "RA B A A>3 3 TEST RISJLT FEAK DPFSS. b .( f.y 2'3 3 "RA AAt) 1 -3DRA7 JA _V E T. 3 O!!* DA R :C s fj "N, i.a - .M ' 3 4RA'A A As.' 3YDA3S VA JE IS C.C MPAR S!N b

I3 5 RA } A As : 3 ':CW DIPIN3 _ AY JU' '

y.i,% b FI3 6 NTCW SYSE1 W)TH VA UUM BREWERS 's&

13. ~

.i "A 3 A1 "; A': s A " I3 FJM 1 ? R f he N 3 "A 3 A2 "T A ; s A "I3 :BSI:VER RECOR:5 y% 6.., A 3 A3 ": A A PI*h' BJPDIRTS .f. ;g D TAB A4 TRAIN A INSPECTION REPORTS h !*.. ;*h FIG A1 TRAIN A BYPASS VALVE 45 deg ~[ FIG A2 TRAIN A BYPASS VALVE 40 dog " <4. :, -[ FIG A3 TRAIN A BYPASS VALVE 35 dog d FIG A4 TRAIN A BYPASS VALVE 30 deg d# - ' h' e 'Q FIG A5 TRAIN A BYPASS VALVE 27.5 deg }K FIG A6 TRAIN A BYPASS VALVE 25 deg . k. -*.. /d FIG A7 TRAIN A BYPASS VALVE 22.5 deg ..c e. Q. .gF?e FIG AB,A9 TRAIN A BYPASS VALVE 20 dag

g: Lt.'.,

f.k.; FIG A10,A11 TRAIN A BYPASS VALVE 17.5 deg .,;.g s . g,s FIG A12.A13 TRAIN A BYPASS VALVE 15 deg v',g l. FIG A14,A15 TRAIN A BYPASS VALVE 12.5 deg rl44f s FIG A16,A17 TRAIN A BYPASS VALVE 10 deg ty., . 9 y.\\ FIG A18 TRAIN A BYPASS VALVE 7.5 deg ql .J 3 A19 TRAIN A SPRAY VA.VE 20 deg--WATERHAMMER

/,a fly [

1

3 A20-A?6 TRAIN 4 3YDAiS UALVE 12.5 deg--WATERHAMMER
,)P E, A SDRA/ VA.VI 45 deg 15 SEC 3ELAY: i... 'h :; 3 A27 ' ': A : s md[

A S D RAY VA VI 45 deg 6 SEC LE_AY [M 3 A2' A [ 3 A2; 4A : 4 A SoRAY VA VI 45 deg 4 SEC 3 E AY %;fh.' FL3 A30 RA 4 A So7AY VA.V E 45 deg 2 SEC )E_AY

i. f. y 3{p.

~ F:3 A31 9A:4 A SoRAY VA_VI 45 deg Q,.M F:3 A32 RA 4 A SDRAY VA V E 40 deg g /.t. '9 1, FIG A33 TRAIN A SPRAY VALVE 35 deg 9 Q.s.. .= s,. FIG A34 TRAIN A SPRAY VALVE 32.5 deg i s.g(

I FIG A35 TRAIN A SPRAY VALVE 30 deg

%?. .f3 FI3 A36 TRAIN A SPRAY VALVE 27.5 deg i='.: "t FIG A37 TRAIN A SPRAY VALVE 25 dag

..N.D s.

FIG A38 TRAIN A SPRAY VALVE 22.5 deg k[ FIG A39 TRAIN A SPRAY VALVE 20 deg 'm$ FIG A40 TRAIN A SPRAY VALVE 17.5 deg M.Y [N FIG 441 TRAIN A SPRAY VALVE 15 ceg

T@

1,4 FIG A42 TRAIN A SPRAY VALVE 12.5 deg ,~,) FIG A43 TRAIN A SPRAY VALVE 10 deg ~ ,h FIG A44 TRAIN A SPRAY VALVE 7.5 deg [6.5 3.^ FIG A45,A46 TRAIN A BYPASS VALVE 12.5 deg CONFIRMATION .jklf.$ FIG A47,A48 TRAIN A SPRAY VALVE 10 deg CONFIRMATION r -t$ ,.l j Y j);. f,g TAB B1 TRAIN B TEST

SUMMARY

TAB B2 TRAIN B TEST OBSERVER RECORDS .[ TAB B3 TRAIN B PIPE SUPPORTS ( 7.4j TAB B4 TRAIN B INSPECTION REPORTS b M'>l[ j. f^}{ i: I L, B1 TRAIN B BYPASS VALVE 25 deg ?Q y p Q 36+J n .; y.lll .: 'q. ;: ;, ,. ?

l...p.

?_;-l f(i[.]_f.Q 4f[ n, -g 9.{ g y !g: ; ' ' ll% 7fy J. l.- o.. - ~, ' 9 yf( 7. : %.;;. 7 Q .g ;; ((

- 05-Oct-86 **

FIG B2 TRAIN B BYPASS VALVE 22.5 deg FIG B3 TRAIN B BYPASS VALVE 20 dag FIG B4 TRAIN B BYPASS VALVE 17.5 deg FIG B5 TRAIN B BYPASS VALVE 15 deg FIG B6 TRAIN B BYPASS VALVE 12.5 deg FIG B7 TRAIN B BYPASS VALVE 10 deg FIG Be TRAIN B BYPASS VALVE 7.5 deg FIG B9 TRAIN B SPRAY VALVE 20 deg FIG B10 TRAIN B SPRAY VALVE 17.5 deg FIG B11 TRAIN B SPRAY VALVE 15 deg FIG B12 TRAIN B SPRAY VALVE 12.5 deg FIG B13 TRAIN B SPRAY VALVE 10 deg FIG B14 TRAIN B SPRAY VALVE 7.5 deg FIG B15,B16 TRAIN B BYPASS VALVE 12.5 deg CONFIRMATION FIG B17,B1B TRAIN B SPRAY VALVE 10 deg CONFIRMATION FIG B19,B20 TRAIN B SPRAY VALVE 10 deg 4 HR STATION BLACKOUT FIG B21 TRAIN B SPRAY VALVE 12.5 deg CONFIRMATION FIG B22 TRAIN B SPRAY VALVE 7.5 deg CONFIRMATION FIG B23 TRAIN B SPRAY VALVE 5 deg FIG B24 TRAIN B SPRAY VALVE 5 deg CONFIRMATION t

eY '#6 " 0 i 2 V1 wM Ak 5 _ 1e! e l8 a.l e.' 5 fl i-Vo 6V. 0 R A 2 . RYE 2 ATEAD A X wRA OPE A L lSH E A YE sele* !l!laslI5 AV RL R s PA ES u. s V HS N kA = .a $P Y .n wB V-ea L c Es E s La 5N z E2 fEwr DGsH i T*H _g C E ' X = I g f' E E )-> L I 9 f F 6 i 44 O D of 6' Rrt R o L WT. o ~ CA L Ha o P H 2 CE J Rmc n 7 C AH M A. X L E u_ E E T l,l a e s. S t e i .h i f R S Y E R S r / H E u .M T G w E O N W f A C 2 ' i - MTH S s 3 l a T REX N u u OAC R n M E aI. C 9 2' FHE L 6 g, 'N tag M,o NF C 8 8 D T (1 g# c O R 1 1 E S C d. C 0 L L I r E k .E F h 2 I s - L T P S M E L = .b T S I J L R S ! j. ! a_! j .e R E E G T [ R H N MY R P E R T A 'A O e, E M L OTH TR T g U O r,- FL AC NP O P O SL OEX OS M C g ,l E1 THE C 1tC f# y c E e G cs V0 RE 4 nk E1 I-AV aw L- =g HL cP E8 s CA 1 /iP O 4 2 SV d I 1 D O e$ ) 0 s 1 F A mP 7 2 \\ H 2 2 oV cB LE Wp f l t Cu Su NP s 'Il( l

fl&u25 2 NSCW RESTART AFTER LOP SECONDS li 0 LOSS OF OFFSITE POWER. SYSTEM DRAINING qF 15 DIESELS START AND READY TO ACCEPT LOAD PUMP DISCHARGE VALVES AND TOWER VALVE START TO CLOSE. ISOLATION 30 PUMP DISCHARGE VALVES FULLY CLOSED. at 35 TOWER VALVE FULLY CLOSED. 7c 40 TWO NSCW PUMPS START. TOWER VALVE STARTS TO GPEN. SPARE NSCW PUMP STARTS IF REQUIRED. 45 TOWER VALVE OPEN AND STOPS IN THIS POSITION. SEQUENCER STEPS COMPLETED. SLOW REFILL SYSTEM REFILL COMPLETE. gg 75 MARGIN 85 PUMP DISCHARGE VALVE STARTS TO OPEN. JC TOWER VALVE STARTS TO G0 WIDE OPEN. FAST REFILL JL 100 TOWER VALVE FULLY OPEN. PUMP DISCHARGE '/ALVES FULLY CPEN. 882/188/2

- 26-Aug-06 *+

f/k3L& I NSCW LOP TRANSIENT TEST RESULTS TRAINS A AND D THE FOLLOWING PRESSURES ARE THE NAX1NUM RECORDED AT EACH TEST LOCATION TRAIN A FEA6 FRESSURE DURING REFILL TEST (PSIG) PEAK PRESSURE DURING CONF 1RN. TEST (PSIG) RUN# bvPASS VLV POS DG RHR CCW ESF AUX CAV DG RHR CCW ESF AUX CAV

1. 1. 1. 1. ######NN#NNNN# ######## #N###### ######## ######## #NNNN#48 N#######
      2. NNNN 95N###NN ######## #N#NNNN# t#StNNust sN######

9 17.5 DEG 40 (C) 80 (C) 10 (C) 20 (C) 0 (C) N/A 10 15 40 (C) 75 (C) 30 (C) 50 (C) 10 (C) N/A 11,34 12.5 Sn (C) 90 (C) 40 (C) 50 (C) 30 (C) N/A 70 (D) 110 (C,D) 60 (D) 160 (C) 70 (C,D) N/A 12 10 60 (C) 100 (C) 50 (C) 60 (C) 40 (C) N/A l 13 7.5 100 (C) 140 (C) 70 (C) 120 (C) 70 (C) N/A TRAIN D RUNN B(FASS VLV POS 4 17.5 DEG 10 (C) 50 (C) -5 (C) 10 (C) -10 30 (C) 5 15 10 (C) 60 (C) O (C) 20 (C) -5 (C) 40 (C) 6,15 12.5 20 (C) 60 (C) 0 (C) 20 (C) 20 (C) 40 (C) 100 (D) 140 (C,b) 90 (D) 100 (D) 170 (D) 180 (D) 7 10 20 (C) 70 (C) 5 (C) 20 (C) 20 (C) 50 (C) 8 7.5 20 (C) Bu (C) 10 (C) 40 (C) 65 (C) 90 (C) TRAIN A RUNN SF' RAY VLV F OS NNN#N #NN#24##NN#N#N 29 17.5 DEG 20 (A) 80 (C) 30 (A) 40 (C) -10 (C) N/A 30 15 10 (C) 75 (C) 10 (A) 60 (C) -10 (C) N/A 31 12.5 10 (C) 90 (C) 15 (A) 110 (C) 0 (C) N/A 32,35 10 10 (C) 90 (C) 20 (A) 95 (C) 10 (C) N/A 60 (D) 100 (C,D) 40 (D) 110 (D) 60 (D) N/A 33 7.5 20 (C) 90 (C) 25 (A) 120 (C) 220 (C) N/A TRAIN D RUN# SPRAN VLV FOS

1. 1. 1. 1. ############NM 10 17.5 DEG 110 (B) 110 (A,B) 110 (A) 60 (C)

-10 70 (B) 11 15 110 (B) 120 (A) 110 (A) 60 (C) -10 60 (B) 12,10 12.5 110 (B) 120 (A) 120 (4) 00 (C) 10 (C) 70 (B) 220 (B) 160 (D) 140 (A) 210 (D) 205 (D) 305 (D) 13,16 10 110 (B) 120 (A,B) 120 (A) 80 (C) 60 (C) 70 (B) 120 (D) 140 (D) 120 (A) 220 (D) 230 (D) 200 (D) 14,19 7.5 110 (B) 120 (A) 120 (A) 95 (C) 60 (C) 120 (C) 220 (B) 140 (A.D) 140 (A) 200 (D) 100 (D) 260 (D) 20,21 5 220 (B) 140 (A) 130 (A) 240 (C) 140 (C) 170 (C) 100 (A,B) 130 (A.D) 130 (A) 230 (C) 170 (D) 240 (D) (A) F E Al PRESSURE OCCURS AT CHECl-VALVE CLOSURE (T= 13 SEC) (B) PEA 6 r'RESSURE OCCURS AT PUMP ST ART (T= 40 SEC1 (C) FEAL PRESSURE OCCURS AT SYSTEN FILL (T= 45 TO B0 SEC) (D> PEAT F RESSURE OCCURS AT PMP DISCH VLV OPENING (T= 05 SEC)

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l ++04-Oct-86 ** TABLE A3 PIPE SUPPORTS INSPECTED FOR THE NSCW LOP TRANSIENT TEST TRAIN A PIPE SUPPORT PIPING ISOMETRIC VI~52652[34-H6[5~~~~ 5K2-5565~134 61 ~~~ ~ 2 V1-1202-134-H014 1K2-1202-134-02 V1-12Q2-134-HO41 1K2-1202-134-03 V1-1202-134-H042 1K2-1202-134-03 V1-1202-OO2-H012 1K3-1202-OO2-02 V1-1202-002-HO14 1K3-1202-OO2-02 V1-1202-390-HOO3 1K3-1202-004-04 V1-1202-OO4-H035 1K3-1202-004-04 V1-1202-134-HO23 1K3-1202-134-03 V1-1202-134-HO18 1K3-1202-134-01 V1-1202-134-HO15 1K3-1202-134-01 V1-1202-181-HO44 1K3-1202-181-03 V1-1202-187-HOO2 1K3-1202-187-01 { V1-1202-187-HOO6 1K3-1202-187-01 V1-1202-223-HO17 1K4-1202-223-03 V1-1202-223-HO18 1K4-1202-223-03 V1-1202-223-HO13 1K4-1202-223-03 NEW HANGER 1K4-1202-223-03 V1-1202-223-H012 1K4-1202-223-01 V1-1202-OO7-H002 1K5-1202-007-01 V1-1202-008-HOO2 1K5-1202-008-01 V1-1202-009-HOO2 1K5-1202-009-01 V1-1202-010-HOO2 1K5-1202-010-01 V1-1202-184-HOO2 1K5-1202-184-01 V1-1202-035-H012 1K5-1202-035-02 V1-1202-181-H050 1K5-1202-181-01 V1-1202-181-HO19 1K5-1202-181-01 V1-1202-037-HO23 1K5-1202-037-02 V1-1202-OO4-HG73 1K5-1202-OO4-02 V1-1202-004-h045 1K5-1202-OO4-02 V1-1202-004-HO79 1K5-1202-004-01 V1-1202-037-HOO7 1K5-1202-037-01 V1-1202-037-HO31 1K5-1202-037-03 V1-1202-O!7-H029 1K5-1202-037-03 V1-1202-035-H025 1K5-1202-035-03 V1-1202-035-H021 1K5-1202-035-03

oo11-Jul-86 ** TABLE Al NSCW TRAIN A TEST

SUMMARY

RUN (ST-11 #) TEST DESCRIPTION FIGURE COMMENTS 1 (6.2 #1) TOWER BYPASS VALVE A1 SYSTEM STEADY STATE HV-16688 SET AT 45deg PRESSURE AT PT-1636 INTERMEDIATE POSITION TEST GAGE, 10PSIG DURING SYSTEM REFILL 2 (6.2 #2) BYPASS VALVE AT 40deg A2 PT-1636, 10PSIG 3 (6.2 #3) BYPASS VALVE AT 35deg A3 PT-1636, 10PSIG 4 (6.2 #4) BYPASS VALVE AT 30deg A4 PT-1636, 12PSIG 5 (6.2 #5) BYPASS VALVE AT 27.5deg AS PT-1636, 22PSIG (PRESSURE READING IS QUESTIONABLE. PUMP DISCHARGE VALVES MAY HAVE BEEN SLIGHTLY OPEN). 6 (6.2 #6) BYPAOS VALVE AT 25deg A6 PT-1636, 16PSIG 7 (6.2 #7) BYPASS VALVE AT 22.5deg A7 PT-1636, 18.5PSIG 8 (6.2 #8) BYPASS VALVE AT 20deg A S,9 PT-1636, 24PSIG 9 (6.2 #9) BYPASS VALVE AT 17.5deg A 10,11 PT-1636, 37PSIG SYSTEM FILL INDICATED AT T=695EC. 10(6.2 #10) BYPASS VALVE %T 15 des A12,13 PT-1636, 52PSIG SYSTEM FILL AT T=66SEC. 11(6.2 #11) BYPASS VALVE AT 12.5deg A 14,15 PT-1636, 62PSIG SYSTEM' FILL AT T=643EC. 12(6.2 #12) BYPASS VALVE AT'10deg A16,17 PT-1676, 74PSIG SYSTEM FILL AT 64SEC. 13(6.2 #13)* BYPASS VALVE AT 7.5deg A18 PT-1636, 74PSIG SYSTEM FILL AT 61SEC. TRANSIENT PRESSURES AT ALL TEST POINTS WITHIN ALLOWABLES. HOWEVER THE TRANSIENT CHANGE FROM THE PREVIOUS 10(eg VALVE SETTING WAS SIGNIFICANT AND FURTHER REDUCTION IN VALVE OPENING WAS NOT TESTED.

oo11-Jul-86 ** TABLE A l NSCW TRAIN A TEST

SUMMARY

RUN (ST-11 m) TEST DESCRIPTION FIGURE COMMENTS ~~~~~~ 3TERHEEEEE~~5hRdY UELV5~~ 14(6.3 #1)

TOWER RETURN SPRAY VALVE E19

~ W HV-1668A SET AT 20deg DID NOT CPEN AT PUMP START INTERMEDIATE POSITION DURING SYSTEM REFILL. 15(6.4 #1)

TOWER BYPASS VALVE HV-16689 A20-26 WATERHAMMER. PUMP START SET AT 12.5deg.

BEFORE VALVES CLOSED. 16(6.6 #1) TOWER SPRAY VALVE HV-1668A A27 PT-1636, 13PSIG SET AT 45deg INTERMEDIATE POSITION DURING SYSTEM REFILL. VALVE OPENS 15SEC BEFORE PUMP START. 17(6.7 #1) SPRAY VALVE AT 45deg. A28 PT-1636, 13PSIG VALVE OPENS 6SEC BEFORE PUMP START. 18(6.8 #1) SPRAY VALVE AT 45deg. \\29 PT-1636, 14PSIG VALVE OPENS 4SEC BEFCRE PUMP START. 19(6.9 #1) SPRAY VALVE AT 45deg. Aso PT-1636, 14PSIG VALVE OPENS 2SEC*BEFORE PUMP START. 20(6.3 #2) SPRAY VALVE AT 45deg. A31 PT-1636, 14PSIG VALVE OPENS AND PUMP START SIMULTANECUSLY. 21(6.3 #3) SPRAY VALVE AT 40deg. A2 PT-16.36, 14P3IG 22(6.3 #4) SPRAY VALVE AT 35deg. A30 PT-1636, 14PSIG 23(6.3 #5) SPRAY VALVE AT 32.5deg. A34 PT-1634, 14PSIG 24(6.3 #6) SPRAY VALVE AT 30dag. A35 PT-1606, 14PSIG 25(6.3 #7) SFRAY VALVE AT 27.5deg. A36 PT-1634, 14.5PSIG 26(6.3 #7) SPRAY VALVE AT 25deg. A37 PT-1636, 15PSIG 27(6.3 #9) SPRAY VALVE AT 22.5deg. A38 PT-1636, 15.4PSIG 28(6.3 #10) SPRAY VALVE AT 20deg. A39 PT-1636, 16PSIG 29(6.3 #11) SPRAY VALVE AT 17.5deg. A4o PT-1636, 17PSIG 30(6.3 #12) SPRAY VALVE AT 15deg. A41 PT-1636, 18.4PSIG 31(6.3 #13) SPRAY VALVE AT 12.5deg. A42 PT-1636, 21PSIG

oo11-Jul-86 o+ TABLE Al NSCW TRAIN A TEST

SUMMARY

RUN (ST-11 #) TEST DESCRIPTION FIGURE COMMENTS 32(6.3 #1434 SPRAY VALVE AT 10deg. 643 PT-1636, 23.5PSIG 33(6.3 #15)* SPRAY VALVE AT 7.5deg. A 44 PT-1636, 29.5PSIG TRANSIENT PRESSURES AT ALL TEST POINTS WITHIN DESIGN ALLOWABLES. HOWEVER THE TRANSIENT CHANGE FROM PREVIOUS 10deg VALVE POSITION WAS SIGNIFICANT AND FURTHER REDUCTION IN VALVE POSITION WAS NOT TESTED. 34(6.0 #2)

BYPASS VALVE AT I2.5deg.

A45,46 TRANSIENT PRESSURES AT FULL SIMULATION OF LOP ALL TEST POINTS WITHIN TRANSIENT BACK TO NORMAL ALLOWABLES. SYSTEM OPERATION. SPRAY VALVE AT 10deg. A47,48 TRANSIENT PRESSURES AT 05(6.5 #1)

FULL SIMULATION CF LOP ALL TEST POINTS WITHIN TRANSIENT BACK TO NORMAL ALLOWABLES.

SYSTEM OPERATION. 1 PIPING WALMDCWN FERFCRMCD AFTER.THIS TEST l e

= i' l l TABLE A2 TEST OBSERVER RECORDS l I ATTACHMENTS: 1) CRITICAL HANGER LIST

2) CRITICAL ISO'S 3)WALKDOWN CRITERIA

4) INSPECTION REPORTS l

CRITICAL PIPE SEGMENT 5 AND PIPE SUPPORTS WERE SELECTED FOR OBSERVATION AND EVALUATION IN AREAS WHERE LOADS RESULTING FROM THE WATERHAMMER WERE ANTICIPATED TO BE THE GREATEST. THE SELECTION OF THESE PIPE SUPPORTS AND PIPE SEGMENTS WAS BASED UPON PRIOR EXPERIENCE AND INFORMATION FROM SYSTEM HYDRAULIC AND STRESS ANALYSES. REPRESENTATIVE AXIAL RESTRAINTS IN LONG STRAIGHT RUNS WERE DESIGNATED AS CRITICAL SUPPORTS. FOR LONG STRAIGHT RUNS WITHOUT AXIAL RESTRAINT. THE FIRST LATERAL RESTRAINT AROUND THE END ELBOW WAS ALSO CHOSEN. TAPE WAS APPLIED TO THE STRAIGHT RUNS TO INDICATE AXIAL MOVEMENT. A TCTAL OF 36 CRITICAL SUPPORTS WERE SELECTED AS A R(IULT OF A REVIEW OF ALL IN SCOPE ISOMETRICS. r THE PIPING AND SUPPORTS AT HIGH ELEVATION POINTS IN l THE SYSTEM ALONG WITH OTHER LOCATIONS WHERE SYSTEM REVIEW INDICATED POTENTIAL ACTIVITY WERE VISUALLY OBSERVED DURING THE TEST RUNS. SEVEN ENGINEERS WERE STATIONED AT THESE SELECTED LOCATIONS. IN ADDITION. ( EVERY OBSERVER WAS ASSIGNED SEVERAL CRITICAL SUPPORTS. EACH SUPPORT WAS INSPECTED PRIOR TO THE TESTING TO RECORD BASELINE INFORMATION. ATTACHMENT 1 LISTS THE CRITICAL SUPPORTS ALONG WITH THE RESPONSIBLE ENGINEER. ATTACHMENT 2 PROVIDES ALL ISOMETRICS WITH CRITICAL HANGERS. PERSONNEL INVOLVED IN THE WALKDOWNS AND OBSERVATIONS WERE EXPERIENCED PIPE SUPPORT AND STRESS ENGINEERS OR TRAINED MECHANICAL ENGINEERS. DURING THE TESTING, A TOTAL OF 35 RUNS WERE COMPLETED. THIS EXCLUDES SCRUBBED ATTEMPTS, BUT DOES INCLUDE l THE INADVERTENT WATERHAMMER EVENTS DURING RUNS 14 l AND 15. DURING RUN 15, THE INADVERTENT WATERHAMMER WAS CAUSED BY A PREMATURE PUMP START. THIS WAS BY FAR THE MOST SEVERE WATERHAMMER WITNESSED DURING THE TSETS.'A REPORT ON THIS EVENT IS THE SUBJECT OF SEPARATE CORRESPONDENCE. I IN THE COURSE OF THE SCHEDULED SEQUENCE OF RUNS (EXCLUDING RUN 15). WALKDOWNS WERE PERFORMED AFTER RUNS 13,14,32.33,34 AND 35. SOME PIPING VIBRATION AND ASSOCIATED NOISE WAS DETECTED BY THE OBSERVERS, HOWEVER NO VIOLATION OF THE INSPECTION CRITERIA

TA6LE A2 (ATTACHMENT 3) WAS REPORTED. THE TYPES OF VIERATION AND NOISE RECORDED WERE SIMILAR TO THAT EXPECTED DURING A NORMAL SYSTEM PUMP START TRANSIENT. TWO RECOMMENDED ACTIONS RESULTED FROM A REVIEW OF THE WALKDOWN REPORTS. THE NSCW BYPASS (ISO 1K5-1202-512-01) DID NOT HAVE ALL PIPE SUPPORTS INSTALLED AND DEFLECTED NOTICEABLY DURING PUMP START. NO PERMANENT DISPLACEMENT OCCURRED AS A RESULT OF THE TESTS. AFTER ALL SUPPORTS ARE INSTALLED PER THE DESIGN. WE EXPECT THAT NO UNACCEPTABLE MOVEMENT WILL OCCUR. A CHANGE TO ADJUST THE FLANGE BOLT ON THE 24" RETURN HEADER WILL'BE INITIATED TO RESOLVE A TEST OBSERVATION, IN CONCLUSION. THE TESTING CONFIRMED THAT LOP TRANSIENT RESTART OF THE SYSTEM IS ACCOMPLISHED WITH NO LOSS OF' PIPING PRESSURE BOUNDARY OR UNACCEPTABLE PIPE AND PIPE SUPPORT MOVEMENT. j l l l l l

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26-Aug-86_**
TABLE B1 NSCW TRAIN B TEST
SUMMARY
RUN (ST-13 #) TEST DESCRIPTION FIGURE COMMENTS 1 (6.1 #1) TOWER BYPASS VALVE B1 SYSTEM STEADY STATE HV-1669B SET AT 25deg PRESSURE AT PT-1637 INTERMEDIATE POSITION TEST GAGE, 13.5PSIG DURING SYSTEM REFILL 2 (6.1 #2) BYPASS VALVE AT 22.5deg B2 PT-1637, 14PSIG 3 (6.1 #3) BYPASS VALVE AT 20deg B3 PT-1637, 1SPSIG 4 (6.1 #4) BYPASS VALVE AT 17.5deg B4 PT-1637, 20.5PSIG 5 (6.1 #5) BYPASS VALVE AT 15deg B5 PT-1637, 22PSIG 6 (6.1 #6) BYPASS VALVE AT 12.5deg B6 PT-1637, 27PSIG i 7 (6.1 #7) BYPASS VALVE AT 10deg B7 PT-1637, 31PSIG 0 (6.1 #G)
BYPASS VALVE AT 7.5deg BG PT-1637, 36PSIG 9 (6.2 #1)
TOWER RETURN SPRAY VALVE B9 PT-1637, 16PSIG HV-1669A SET AT 20deg i INTERMEDIATE POSITION DURING SYSTEM REFILL. 10(6.2 #2) SPRAY VALVE AT 17.5deg. Bio PT-1637, 16.5PSIG 11(6.2 #3) SPRAY VALVE AT 15deg. B11 PT-1637, 17.5PSIG 12(6.2 #4) SPRAY VALVE AT 12.5deg. B12 PT-1637, 19.5PSIG 13(6.2 #5) SPRAY VALVE AT 10deg. B13 PT-1637, 20.5PSIG 14(6.2 #6)
SPRAY VALVE AT 7.5deg.
B14 PT-1637, 23PSIG 15(6.3 #1)
BYPASS VALVE AT 12.5deg.
B15,B16 TRANSIENT PRESSURES AT FULL SIMULATION OF LOP ALL TEST POINTS WITHIN TRANSIENT BACK TO NORMAL ALLOWABLES. SYSTEM OPERATION. 16(6.4 #1)
SPRAY VALVE AT 10deg.
B17,B18 PE4K PRESSURE AT CAV FULL SIMULATION OF LOP 280 PSIG TRANSIENT BACK TO NORMAL i SYSTEM OPERATION. 17(6.5 #1)** SPRAY VALVE AT 10deg. B19,,410 PT-1637, 14PSIG THIS RUN SIMULATED A STATION BLACKOUT (LOSS OF OFFSITE PCWER AND EMERGENCY DIESELS) FOR 4 j HOURS. THIS WAS A SYSTEM l REFILL VERIFICATION TEST.
^v, w i t 'A O*20-Aug-86 ** TABLE B1 NSCW TRAIN B TEST
SUMMARY
RUN (ST,-131#) TEST DESCRIPTION FIGURE COMMENTS 18(6.6 #1)
SPRAY VALVE AT 12.5deg.
B2l PEAK PRESSURE AT CAV FULL SIMULATION OF LOP 305 PSIG TRANSIENT BACK TO NORMAL SYSTEM OPERATION. 19(6.6 #2)
SPRAY VALVE AT 7.5deg.
B22 PEAK PRESSURE AT CAV FULL SIMULATION OF LOP 260 PSIG TRANGIENT BACX TO NORMAL SYSTEM OPERATION. 20(6.6C #1) SPRAY VALVE'AT 5deg. B23 PT-1637, 26PSIG REFILL DETERMINATION. I 21(6.6 #3)** SPRAY VALVE AT 5deg. B24 PEAK PRESSURE AT CAV FULL SIMULATION OF LOP 240 PSIG TRANSIENT BACK TO NORMAL SYSTEM OPERATION. s
PIPING WALNDOWN PERFORMED AFTER THIS TEST OF 14 CRITICAL PIPE SUPPORTS AT HIGH POINTS
PIPING WALKDOWN PERFORMED OF ALL 36 CRITICAL PIPE SUPPORTS t
I l l S r l .L h I
o24-Aug-C6 00 TABLE B2 TEST OBSERVER RECORDS TRAIN B ATTACHMENTS: 1) CRITICAL SUPPORT LIST 2)WALKDOWN CRITERIA
3) INSPECTION REPORTS CRITICAL PIPE SEGMENTS AND PIPE SUPPORTS WERE SELECTED FOR OBSERVATION AND EVALUATION IN AREAS WHERE LOADS RESULTING FROM THE WATERHAMMER WERE ANTICIPATED TO BE THE GREATEST. THE SELECTION OF THESE PIPE SUPPORTS i
AND PIPE SEGMENTS WAS BASED UPON PRIOR EXPERIENCE AND INFORMATION FROM SYSTEM HYDRAULIC AND STRESS ANALYSES. REPRESENTATIVE AXIAL RESTRAINTS IN LONG STRAIGHT RUNS WERE DESIGNATED AS CRITICAL SUPPORTS. FOR LONG STRAIGHT RUNS WITHOUT AXIAL RESTRAINT, THE FIRST LATERAL RESTRAINT AROUND THE END ELBOW WAS ALSO CHOSEN. TAPE WAS APPLIED TO THE STRAIGHT RUNS TO INDICATE AXIAL MOVEMENT. AS A RESULT OF A REVIEW OF ALL IN SCOPE ISOMETRICS, THE PIPING AND SUPPORTS AT HIGH ELEVATION POINTS IN THE SYSTEM ALONG WITH OTHER LOCATIONS WHERE SYSTEM REVIEW INDICATED POTENTIAL ACTIVITY WERE VISUALLY OBSERVED DURING THE TEST RUNS. SIX ENGINEERS WERE STATIONED AT THESE SELECTED LOCATIONS. IN ADDITION, EVERY OBSERVER WAS ASSIGNED SEVERAL CRITICAL SUPPORTS. ATTACHMENT 1 LISTS THE CRITICAL SUPPORTS AND ASSOCIATED ISOMETRICS. PRIOR TO THE FIRST TEST RUN, ALL 36 CRITICAL SUPPORTS WERE INSPECTED TO RECORD BASELINE INFORMATION. A SMALLER SCOPE OF 14 SUPPORTS (CHOSEN FROM THE 36 CRITICAL SUPPORTS) WAS SELECTED FOR INTERMEDIATE WALKDOWNS BETWEEN TESTS. TABLE B1 SHOWS THE WALKDOWNS PERFORMED: 36 SUPPORT WALKDOWNS AFTER RUNS 17,21; 14 SUPPORT WALKDOWNS AFTER RUNS 8,14,15,16,18,19. l PERSONNEL INVOLVED IN THE WALKDOWNS AND OBSERVATIONS WERE EXPERIENCED PIPE SUPPORT AND STRESS ENGINEERS OR TRAINED MECHANICAL AND CONTROL SYSTEMS ENGINEERS. DURING THE TESTING, A TOTAL OF 21 RUNS WERE COMPLETED. SOME PIPING VIBRATION AND ASSOCIATED NOISE WAS DETECTED BY THE OBSERVERS. HOWEVER, NO VIOLATION OF THE WALKDOWN CRITERIA (ATTACHMENT 2) WAS REPORTED. THE TYPES OF VIBRATION AND NOISE RECORDED WERE SIMILAR TO THAT EXPECTED DURING A NORMAL SYSTEM PUMP START TRANSIENT. PIPING l MOVEMENTS WERE RECORDED AT THE FOLLOWING LOCATIONS: PUMP BYPASS LINE V1-1202-140-H009, APPROX 1/4" MOVEMENT V1 -1202-088-H040, APPROX 1/16" MOVEMENT V1-1202-036-H010, APPROX 1/16" MOVEMENT ALL MOVEMENTS WERE REVIEWED AND FOUND TO BE WITHIN THE PIPING SYSTEM ALLOWABLES. i .. _... ~., -. _.. _ _ _,. _ - -.. _ - -..
26-Aug-86 **
TAeLE B2 IN CONCLUSION, THE TESTING CONFIRMED THAT LOP TRANSIENT RESTART OF THE SYSTEM IS ACCOMPLISHED WITH NO LOSS OF PIPING PRESSURE BOUNDARY OR UNACCEPTABLE PIPE AND PIPE SUPPORT MOVEMENT. l l l l l n,..n, ,,n,..
26-Aug-86 **
TABLE 63 PIPE SUPPORTS INSPECTED FOR THE NSCW LOP TRANSIENT TEST TRAIN B PIPE SUPPORT PIPING ISOMETRIC Vi~-5202-OO5-HO22 *- 5I(2-12U2-OO5-03 ~ ~~~~~ V1-1202-OO5-HO25 1K4-1202-OO5-01 V1-1202-OO5-HO26 1K2-1202-OO5-01 V1-1202-OO6-HO12 1K5-1202-OO6-01 V1-1202-OO6-HO61 1K5-1202-OO6-03 V1-1202-OO6-HO65 1K5-1202-OO6-02 V1-1202-011-HOO9
1K5-1202-011-01
.V1-1202-012-HOO2
1K5-1202-012-01 V1-1202-013-HOO2

1K5-1202-013-01 V1-1202-014-HOO2

1K5-1202-014-01 V1-1202-036-HO10 1K5-1202-036-01 V1-1202-036-HO38 1K5-1202-036-03 V1-1202-038-HOO2 1K5-1202-038-01 J
V1-1202-038-HO13 1K5-1202-038-01 V1-1202-038-HO26 1K3-1202-OB6-01 V1-1202-038-HO27 1K5-1202-038-03 V1-1202-072-HO2O
1K2-1202-072-02 V1-1202-072-HO24 1K2-1202-072-01 V1-1202-072-H605

1K2-1202-072-02 V1-1202-OB5-HOO3 1K3-1202-086-01 V1-1202-088-HOl6 1K5-1202-088-02 V1-1202-088-HO24 1K5-1202-088-03 V1-1202-088-HO40 1K3-1202-088-O' l
V1-1202-088-HO44
1K3-1202-088-02 i
V1-1202-088-HO56 1K5-1202-088-02 V1-1202-098-HOOO 1K3-1202-098-01 V1-1202-098-HO18 1K3-1202-098-02 V1-1202-099-HO13 1K3-1202-099-01 V1-1202-099-HO23 1K3-1202-099-02 V1-1202-140-HOOB
1K4-1202-140-01 V1-1202-140-HOO9

1K4-1202-140-01 V1-1202-141-HOO8

1K4-1202-141-01 V1-1202-141-HOO9

1K4-1202-141-01 V1-1202-185-HOO2 1K5-1202-185-01
+ V1-1202-229-HO15
1K4-1202-229-04 I
V1-1202-231-HO17
1K4-1202-231-04 i

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bxc C. H. Shinbrot f H. G. Gronroos J. T. Luke E:*:"IO"N'cJobsitei Bechtel Power Corporation Engineers - Constructors T. Z. Richardson (Jobsite) 12440 East Impenal Hshway J. Asfour (Jobsite) Norwalk. California 90650 J. Orchard (Jobsite) m accmss Eu D ii Danao " "" " "5#^# "" " August 7, Il985 ggffKEA)tE I Mr. G. Bockhold, Jr. General Manager, Vogtle Nuclear Operations Department Georgia Power Company Plant Vogtle P.O. Box 282 Waynesboro, Georgia 30830
Subject:
Georgia Power Company Plant Vogtle - Units 1 & 2 Bechtel Job 9510 Startup of Nuclear Service Cooling Water Pumps Filer X4BC05 Loc: ' E Cm @ M O
Dear Mr. Bockhold:
The nuclear service cooling water system (NSCW) consists of two cafety related trains with pumps operating in one train only during normal operating conditions. The NSCW system incorporates a " keep fill" system that consists of check valves and inter-ties between the two safety trains to keep the idle train full and pressurized at all times. During startup it is quite likely that at times only one train will ba operational and that this train will be subject to repeated starts. When the one operational train is not in use the " keep fill" cystem will not be functional and therefore portions of the piping et the higher elevations will be partially drained after the pump in the operational train is shut off. When the operational pump ic re-started, the pump will deliver water to a partially drained cystem. This in turn could result in transient forces that exceed the capability of the pipe supports. I
I Mr. G. Bockhold, Jr. Bechtel Power Corporation Plant Vogtle - Units 1 & 2 August 7, 1985 Bechtel Job 9510 Instructions for Startup of j Nuclear Service Cooling Water Pumps 1 File: X4BC05 Pcge 2 To preclude any possibility of damage we recommend implementation of administrative procedures and/or added precautions to the pre-cperational test procedures to assure that a NSCW pump is only started after it has been verified that the system has been ccmpletely filled. A temporary pump may be used for this purpose. Wa are continuing our review of other upset and abnormal operating conditions for this system and will advise you of the results of our review shortly. The information presented in this letter was previously discussed with PFE and Nuclear Operations personnel during various recent talephone conversations. If you have any questions, please contact us. Very truly yours, BECHTEL POWER CORPORATION ORIG 1N O gy HENRIK ROOS F. B. Marsh Project Engineering Manager p p Western Power Division i i BM/JTL/rsl /g,xc: O. Batum H. H. Gregory, III l M. Bellamy V-RMS s
bxc: C. H. Shinbrot w/att. F. R. Mastroly w/att. Bechtel Power Corporation D. Morrow w/att. Engineers - Construe: Ors W. H. Johnston w/att. R. Johnson w/att. 12440 East Imperial Highway Norwalk. California 90650 J. McLach1an w/att. D. Steinberg (Jobsite) w/att. Q. No re.wm ae.:s ace.as exe saceo C. Kinnsch (Jobsite) w/att. 'tua9" 44 #7 N# R. Braddy (Jobsite) w/att. October 8, 1985 E. Richardson (Jobsite) w/o att. H. G. Gronroos w/att. ggfE26AX 6 L Mr. O. Batum General Manager, Project Engineering, Vogtle Vogtle Project Management Office Vogtle Electric Generating Plant Georgia Power Company P.O. Box 282 Waynesboro, Georgia 30830
Subject:
Georgia Power Company Plant Vogtle - Units 1 & 2 Bechtel Job 9510 Startup of Nuclear Service Cooling Water Pumps File
X4BC05 Loq:
$ Q?OO
Reference:
Letter BG-33790, dated August 7, 1985
Dear Mr. Batum:
In our review of the Nuclear Service Cooling Water System (NSCW), we have identified that an NSCW pump trip following loss of offsite power and subsequent restart will result in excessive loading on the NSCW piping and pipe supports. Our recommendations to preclude the possibility of problems during startup prior to implementation of a fix for this concern were transmitted via the reference letter. l The attachment to this letter delineates the description and l enalysis of the problem, the description of ten alternatives to resolve the problem, and our recommendations. Please note that the recommended modifications can be implemented before fuel load end will not impact the schedule for fuel load. Pre-operational testing can continue using the administrative procedure and precautions outlined in the reference letter.
Bechtel Power Corporation Mr. O. Batum Plant.Vogtle - Units 1 & 2 October 8, 1985 Bechtel Job 9510 Startup of Nuclear Service Cooling Water Pumps File: X4BC05 Page In our review and evaluation of the alternatives, high priority was given to keeping the design simple, and free of the need for operator action and frequent surveillance / adjustments. We recommend that alternative 47 of the attachment be implemented to resolve the problem. This alternative consists of: o The addition of a 4" bypass line with a check valve, manual valve, and orifice around each NSCW pump discharge valve, with the bypasses rejoining the 24" common pump discharge header at an existing 6-inch flanged connection. Modify the NSCW pump discharge valve motor operator to o close in 20 seconds from the present design of 30 seconds. o Logic changes involving time delays for opening of the NSCW pump discharge valves and the isolation valve (tower and bypass valves) in the return line to the cooling tower. The piping lay-out has been designed such that the bypass piping can be assembled in the pump house and separately hydrotested, before being bolted on to the existing piping at existing l flanges. Hence rehydro of the present system is avoided. The piping lay-out involves two core-drilled 10" (approximate) holes per unit, one for eacn NSCW tower. The vendor for the NSCW pump discharge valve has advised us that the required modifications can be accomplished by changing the valve operator, and that these modifications can be made in the field. f The logic modifications are relatively simple. The logic will be i revised such that only the operating train, at the time of loss l of offsite power, will go through the revised automatic start-up coquence. For normal operation, the NSCW pump and valves will l ctart-up in accordance with the present logic sequences. This change is being tracked as CCP SB10130M (PCW Action item 80081-0004, system EF) and these modifications need to be completed prior to fuel load. l l l l
B;chtel Powcr Corporation Mr. O. Batum Plant Vogtle - Units 1 & 2 October 8, 1985 Bechtel Job 9510 Startup of Nuclear Service Cooling Water Pumps File: X4BCOS Page If you have any questions, please contact us. Very truly yours, BECHTEL POWER CORPORATION OR: GIN raiso,,. HEN poog s F. B. Marsh Project Engineering Manager Western Power Division BM/JTL/cb
Attachment:
Analysis of NSCW Pump Startup xc: G. Bockhold, Jr. w/att. H. H. Gregory, III w/att. E. Nickerson w/o att. V-RMS w/att. i
B;chtcl Power Corporation Mr. O. Baeum l Plant Vogtle - Units 1 & 2 October 8, 1985 Bechtel Job 9510 Startup of Nuclear Service Cooling Water Pumps I File: X4BC05 l Page ) l If you have any questions, please contact us. I very truly yours, BECHTEL POWER CORPORATION OR: Gift gg,5 3 -,,. HEN. NROOS - F. B. Marsh Project Engineering Manager Western Power Division j gpp,BM/JTL/cb
Attachment:
Analysis of NSCW Pump Startup xc: G. Bockhold, Jr. w/att. H. H. Gregory, III w/att. E. Nickerson w/o att. V-RMS w/att, i I
E 5 I ATTACHMENT L E E. I k E I 1 s 7 E E 6 ? Y ti F h 7 h NUCLEAR SERVICE COOLING WATER SYSTEM 3 b ANALYSIS OF NSCW PUMP STARTUP t f ^ ec; b iLd W' s W-T t F-L r__ (- P September 26, 1985 Bechtel Power Corporation T = -= E h..
.M Descriotion of the Problem The Nuclear Service Cooling Water (NSCW) system consists of two safety related trains with two pumps operating in one train during normal operation. The idle train is kept full by the operating train via interties and check valves. A simplified NSCW system profile is shown in figure 1. Following a loss of offsite power (LOP) condition, the NSCW pumps in the operating train trip, and the motor operated discharge valves (tower valve and pump discharge) remain as is, in the open position. Once the standby diesels start, these valves start to close (15 seconds after LOP). During this time, the NSCW piping at higher i elevations will drain until the tower valve completely closes. ~ When the NSCW pumps start, (approximately 40 seconds after LOP) water is delivered to a partially voided system. Our analysis ~ indicates that this refilling of a partially drained system results in unacceptable loads on the piping and supports. Please note that this problem is only with the train in operation prior to the loss of offsite power. The idle NSCW train does not drain because its tower valve is closed prior to and during LOP, and hence there are no voids to be refilled when the NSCW pumps start. Analysis of the Problem Computer simulation analysis of the present NSCW system indicates J that pressure spikes of over 1000 psig will be generated due to water hammer. Ten solutions to the problem (listed in Table I) were considered. These modifications can be grouped into three categories. A. Solutions which permit breaking the vacuum in the NSCW ^ piping following loss of offsite power, and then filling ?f1742 the system at a fast rate. The air introduced into the Ihk:PR system cushions the water hammer forces to acceptable 79,MP.~. ]g../.,7 levels. g s g, )*I-B. Solutions which permit " bottling up" of the system so ?fh,..j3 that the system does not drain and form voids.
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};}f "h C. Solutions which permit slow filling of the NSCW system to reduce water hammer forces to an acceptable level. $k lQ$ u@nM 1 'l i 1 I!
- i m d 2 TABLE I ? ALTERNATIVES TO REDUCE WATER HAMMER FORCES IN NSCW SYSTEM A. .lternatives for Breaking Vacuum and Filling the System at Full Pump Flow Rate ^ DESCRIPTION OF SOLUTIONS COMMENTS l. Add vacuum breakets located at high The NSCW system has 5 high points inside l points in the system to let air in the containment (one for each containment following loss of offsite power to break fan coolor and one fot the auxiliary air the vacuum. Air in the system reduces cooling call) plus one high point actside the maximum pressures due to water containment. Six vacuum breakers ara hammer. No changes to the existina pp required per train, twelve per unit. In togic ar~ required for ti.v-solation. the event of LOCA with loss of offsite power, containment air will go into NSCW piping and wil) e celeased to the 7 atmosphere following NECW pump start. i This is a licensing deviation. Alse. ] failure of vacuum breakere will jeopardize cor.tainment sntegritf. Therefore, this solution is not considered to be acroptable. i i 3 2. Add motor opercted valves instead ,f Six motor operated valves are cequired vacuum breakers as described in 1. Jac um per train, or 12 per Jnit. In addition, is broken 'oy opening the vent valve check valves for the vents inside i eutside c o n t a i...a e n t. Valves inside containment will be required to maintain 2 containment open only after pump Start to containment integrity. A signifiont let air /non condensibles out. No changes wiring impact is asssciated with this 1 to the existing pump logic are required solution. Failure of tna valves inside ~ for this solution. containmant will jeopardi2t certainment j
ntegrity.
Simulation analycis enows that some heat exchangers may he g subjected to h).ther than -le s i g n pressure. e Therefore, this solution is not g conaidered to re acceptale-x
1 i DESCRIPTION OF SOLUTIONS COMMENTS l 3. Add surge supressors to damp out the Locating relatively large surge pressure wave. No changes to the supressors inside the containment will be j existing pump logic are required. very difficult, since they would have to i be at high (above el. 280 ft.) elevations 1 inside containment. Therefore, this 1 solution is not considered to be acceptable. ] B. Alternatives Involving Fast Closing of Tower Valves to Prevent Draining of the System DESCRIPTION OF SOLUTIONS COMMENTS 4. Add a fast closure valve in the return Computer simulation analysis indicates line (tower valve) to prevent draw down that the system drains down significantly of the system. The present design .5 seconds after LOP. Therefore, to E provides tower valve closure in 20 ' prevent voiding of the system, the tower seconds following restoration of power, valve will have to close in 1 second or or approximately 35 seconds after-LOP. less. Computer analysis indicates that s No changes to the existing pump. logic are with a valve closure time of 0.5_eeconds, required l water hammer ' forces will occur jhae to fast closing of the valve. In addition, cost, delivery and reliability of these valves are major concerns. Therefore, this solution is not' considered to be l acceptable. \\ ~ l f i i 1 i J,
., + v j y i C. Alternatives Involving Slow Filling of the System to Reduce Water Hammer Forces (a) )i DESCRIPTION OF' SOLUTIONS COMMENTS i 5. Two NSCW pumps are sequenced to start Some heat exchangers are subjected to simultaneously as per the present logic. pressure. pulses in excess of their design All pump discharge valves close to 8 + pressure for a duration of 2001mili-2 and then go wide open after a delay of seconds. This is not acceptable per the 40 seconds. The tower. valve opens to 30 code. Also, the results are very. 2* at the same time as NSCW pump start sensitive to pump discharge valve angle, ~, ) + and then opens fully after a time delay and repeatability of pump discharge j of 40 seconds. valve position is a concern. Therefore, I this solution is not considered to be acceptable. j _~ l 6. Revise the logic so that one pump starts Relatively complicated logic, and on the existing sequencer step and the repgatability of pump discharge valve (8 l second NSCW pump starts after a time +2 ) position is a concern. _ Changes to y delay of 40 seconds. In addition, the the sequencer logic and loading steps j discharge valves for all'NSCW pumps close will require acceptance by the. diesel to 8 +2 open at the same time as the vendor. Changes to the start lo'gic of start of the first NSCW pump, and then go the containment spray pump, control J j wide open after a delay of 40 seconds.2 building filtration unit, etc., a ro' The complete sequence is shown in Figure required. This impacts several safety 4. related analyses. Therefore, this ? I solution is not considered to be acceptable. I (a) Logic modifications for alternatives 5 thru 10 will function such that only t'he operating NSCW safety train at the time of loss of offsite power will start-up per revised start-up sequence. The idle train at the time of loss of offsite power and both trains j during normal operation will start-up with both pump discharge valves and tower valve starting to open at the same time as NSCW pump start and immediately going wide open. n I
DESCRIPTION OF SOLUTIONS COMMENTS 7. Revise piping to provide a 4" bypass line This solution requires relatively minor around the pump discharge valve with a logic changes and there is no impact on manual Q-Class normally open gate valve, several safety related analyses. It does orifice and a check valve (see Figures 2 require procurement of "Q" Class valves. & 3). Two NSCW pumps start Due to limited space to install the simultaneously per the present logic. bypass, new spool pieces must be The pump discharge valve motor operator fabricated at the pump discharge. All is changed to close in 20 seconds instead new piping will connect to existing of the present design of 30 seconds to flanged connections. This is the assure that the pump discharge valve is recommended solution. 1 closed when NSCW pumps starts. The pump discharge valves open after time delay of l 40 seconds after pump start. The tower i discharge valve logic is revised so that ) the valve starts to open simultaneously' with P3CW gump start, and stops when it i is 24 +2 open to throttle system drain down. The tower valve starts to go wide open at the same time the pump discharge valve starts to open. The complete start-up sequence is shown in Figure 5. 1 The bypass lines from the three NSCW pumps join in a header and are connected to the piping downstream of pump j discharge check valve. I i i J i
DESCRIPTION OF SOLUTIONS COMMENTS 8. Revise piping to provide a 4" bypass Comments are the same as that for line, and revise the logic so that one alternatives 6 and 7. pump starts on the sequencer step and the j second NSCW pump starts after a time delay of 40 seconds. This is essentially a combination of solution 6 and 7. i
DESCRIPTION OF SOLUTIONS COMMENTS 9. Drill holes in the pump discharge valve The effect of jet forces on the operation (butterfly type) to serve as an orifice of the valve, i.e., motor operator is of in lieu of a bypass line. Logic changes concern as it may not be able to open the are the same as those for alternative 7. valve. Possible damage due to jet forces on the check valve downstream of the butterfly valve is also a concern. Fine tuning is very difficult. Therefore, this altern.ative is not considered to be i acceptable. We know of no previous precedent for this approach. 1 i
10. Shim the outside surface of pump It is very difficult to control the area discharge valve disc to serve as a of the orifice.
Results of the analysis orifice. Logic changes are the same as are significantly affected if the those for alternative 7. required orifice area can not be obtained. Fine tuning is almost impossible. The effect of jet forces on the check valve downstream is a matter of concern. Therefore, this alternative is not considered to be acceptable. We know of no previous precedent for this approach. 1 l l i i l i i I l l
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f o -- e LOSS OF OFFSITE POWER DIESELS START & READY TO ACCEPT LOAD .u-PUMP DISCHARGE VALVES AND TOWER VALVE START TO CLOSE. $o k $-- *---TOWER VALVE FULLY CLOSED. A ONE NSCW PUMP STARTS. k 0-TOWER VALVE STARTS TO OPEN. ~ m k-- +--- PUMP DISCHARGE VALVE STOPS. IT IS 8' OPEN. i-- *--- TOWER VALVE STOPS. IT IS 18' OPEN. 1 Q g 5 m A k SECOND NSCW PUMP STARTS. SEQUENCER STEPS COMPLETED ~ M PUMP DISCHARGE VALVE FOR NSCW PUMP #1 Ma - *--< TOWER VALVE STARTS TO GO WIDE OPEN. STARTS To Go WIDE OPEN. o-O PUMP DISCHARGE VALVE FOR NSCW PUMP #2 m STARTS TO GO WIDE OPEN. l f - *---TOWER VALVE FULLY OPEN. ' PUMP DISCHARGE VALVE FOR FIRST NSCW PUMP $j a __ w'(PUMP DISCHARGE VALVE FOR SECOND N f FULLY OPEN. o PUMP FULLY OPEN. Y ] u --
dh f rom 0-- ar-- LOSS OF OFFSITE POWER m-o ~$5 'Em "E9 nm DIESELS START & READY TO ACCEPT LOAD PUMP DISCHARGE VALVES AND TOWER VALVE mH g- => y,g START TO CLOSE. rm O O<m mm m mOZ D 0 u__./ PUMP DISCHARGE VALVES FULLY CLOSED. n TOWER VALVE FULLY CLOSED. gm] e t OZE / A 1 TWO NSCW PUMPS START. z 0-TOWER VALVE STARTS TO OPEN. ~ m ) SPARE NSCW PUMP STARTS IF REQUIRED A_ TOWER VALVE 24' OPEN AND STOPS Q G IN THIS POSITION. C T SEQUENCER STEPS COMPLETED. O M % b Mi 2 m PUMP DISCHARGE VALVE STARTS TO OPEN. k O_ TOWER VALVE STARTS TO Go WIDE OPEN. O N $-- ae-- TOWER VALVE FULLY OPEN. ~ PUMP DISCHARGE VALVES FULLY OPEN. = O-mO $-4 E lm "
1 A i u I l l - ll l Ni j 3 l.... h' -{Q NN MPLAM DISTlast MLDED Em FLAf0GE 24" SPOOL PIEW WITH SLIP-4BI FLAlesE - i-.l. O l - A l OltlFIM FLAIIK. P ll ll Ni ,gl p _ _.l. _ U _,1,3. M N i IHlwiloll l P ll ll Ni dl i l j V ..A I TitAIII "S* VALVE 19 -19008. 'N ) i FIGURE 2 NSCW PUMP DISCHARGE BYPASS (SCHEMATIC)
1 J l i l 8"""****"""""""3 l EL.278'-9" INSIDE 8 8 i CONTAINMENT \\8 CTB. AUX 8 l 8 AIR 8 i ~ ~ I COOLING 8 e COIL 8 i a 8 e i EL. 253'-O" l s TOWER 8 8 CONT'MT (NO{E1I TOWER VA VE l 8 I FAN 1 8 COOLER I gppgy HEADER OhH Ou )I 8 I NSCW TRAIN 1-8 I v $Yahs- / qC>C ( DISC ROE a5555m i i 4 NORMAL VALVE 8 h h l V -) NSCW l
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1 PUMP >=g s217'-8") ~ g I t I t EL. 220'-O" e \\ l P o n i ) ELEV 8 l 220 e ha COLD t 8 i, WEATHER S 8 i FROM OTHER BYPASS g e j TWO NSCW e PUh4PS g g g l e 0 t 8 CONT'MT e 8 SPgRY ELEV. I21'-10" I 8 p MOTOR 8 COOLER
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t hpNon NOTES: j t.DURING SYSTEtt OPERATISIG. EITHER THE SPRAY DEADEM MEEP FULL OR COLD WEATHER SYPASS y[S[hMER IS IN OPERATION. NSCM TRAIN i FIG. la SIMPLIFIED NSCW SYSTEM PROFILE
bac: -1. togers C. B. Shinbrat "l2',,"** Bechtel Power Corporation Engineers - Constructors D. Capito D. Seeinberg 12440 East imperial Highway D. Kinnsch. Norwalk. Caldernia 90650
aco'488 Jem nrier
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tuaaos amass asso meeme C June 10, 1986 "YLW%D JUll13 '86 Mr. F. D. Rice REF6cEAKE 3 .; i i Vice-President, Engineering -4 e Georgia Power Company Vogtle Electric Generating Plant hj j h" Foot Office Box 282 ~ 3-' jj Waynesboro, Georgia 30830 ,v., s.-,s t ' ' 'l"' e - v
Subject:
Georgia Power Company Flant Vogtle - Units 1 fi 2 %.7 Bechtel Job 9510 L Nuclear Service Cooling Weten. sveu m
~ a-Filer X4BC05 Los: PFE-118it?
v .o Rafarence: Letter 35-6200, dated October 8, 1985 C'" U, mw ~.., "^~ D r Mr. Rice: As discussed in the reference, simultaneous tripping of the Nuclear Service Cooling Water (NSCW) pump following a loss of offsite power (LOP) and c bsequent restart say result in excessive loading on the NSCW piping and pipe supports because of water hassne r. To resolve this concern, system modifications were performed via CCP B10130M to reduce the severity of the tr:nsient. Additionally, we have performed hydraulic transient analyses to d:tcraine forcing functions based on the modified system design. These forcing functions have been used as input to computer models of the piping systems to determine dynamic loads for design of the pipe and pipe supports. Frolisinary results obtained by both Bechtel and V-SAMU indicate that this may 10:d to unnecessary project costs to perform the analyses and may also result in o schedule impact due to the lengthy time period required. Preliminary cn:lytical results obtained also indicate that numerous changes to pipe suppsets may be required using this approach. Based on the time, cost and offert involved in continuing with this approach we believe that other more cect effective alternatives should be pursued. Tha most cost effective method for determining the impact on pipe supports is to perform a series of tests that consist of re-filling the system in a cc trolled manner to simulate pump re-start following loss of offsite power. Tha initial tests would consist of a slow re-fill of the system by throttling in the bypass line, to preclude damage to piping or supports. The flow rate fsr refilling the system would gradually be increased until the system is refii'ed, within required time limits with no significant water hammer cffcets. Risk to the systen during testing will be minimized by this crutrolled test program.
~- - ptcct vrstl'c - Unito 1 & 2 Bechtel Power Corporation sechtel J:b 9510 meelear Service Coeling Unter System File 14BC05 Log: FFE-Page: 2 l Io a similar situation at Susquehanna, the computer simulation predicted that hardware changes would be required for the pipe supports. The actual test r:selts showed that the esisting pipe supports were acceptable without modification. The piping configuration for Susquehanna is similar, but not as comples as the VEGF piping system for the NSCW system. The basis for conducting this test rather than performing rigorous analysis is c:nsistent with the philosophy of the ASME Code. The Code recognizes the i practicality that there are various short ters transients that may occur in a systse. It allows stresses of 120% of design for periods less than 1% of the time. This water hammer transient generally falls in this category. It is r commended that we verify by this test program that no significant water hammer loads will be present, it is recommended that a test program be implemented as soon as practical to resolve this issue. Toward this end, we cro proceeding to prepare test requirements for your consideration and citic.pate providing these to you by about June 6, 1986. The engineer responsible for this test on Susquehanna is on the project in the home office cod will be assisting the field with the test. g If fou have any questions, please contact us. Very truly yours, l BECHTEL POWER CORPORATION . M SGNEDsy s& & MMISH 1 F. B. Marsh l Project Engineering Manager Western Power Division PM/KW/adg l xc:
0. Batum G. Bockhold, Jr.
V-AMS
sc: R. L. Rogers 5: hofs""" ' Bechtel Power Corporation S. J. Cereghino Engineers - Constructors W. H. Johnston 12440 East frnperial Highway D. W. Morrow Norwalk. California 50650 R. E. Marquart m-J. A. Wehrenberg ((Jobsite) g g g a ms** stat e *== T. E. Richardson Jobsite) D. L. Kinnsch (Jobsite) June 29, 1986 Mr. G. Bockhold, Jr. Vice-President, Vogtle Nuclear Operations Vogtle Electric Generating Plant Georgia Power Company P.O. Box 282 Waynesboro, Georgia 30830
Subject:
Georgia Power Company Plant Vogtle - Units 1 & 2 Bechtel Job 9510 Nuclear Service Cooling Water Transient Recovery Program File: X7J1202 Log: PFE-. ._ /2/0/
Dear Mr. Bockhold:
During special startup testing of the train A NSCW system, a hydraulic transient was experienced which subjected the system to potentially damaging pressures. To resolve concerns on the effects of this water-hanner on train A NSCW, an NSCW Transient Recovery Program was established. This program consists of: Phase A - short tenn evaluation of the system for completion of special startup testing and Hot Functional Test support and Phase B - long term evaluation to assure that NSCW train A can perform its intended design functions. The phase A evaluation has been concluded and is summarized below. No abnormal conditions were found in any walkdown or evaluation.
1) Piping anc pipe supports walkdown were made by trained Bechtel and M Niv personnel.
Piping was inspected for dents; damage to l attached vencs, drains and small bore branches; leakage at flanges, i valves and nozzles; damage to flanges and valves; and pipe defor-l mation or damage at penetrations. Pipe supports were inspected for damaged lugs or stanchions; damaged axial supports; marks on pipe j from supports; pulled or damaged anchor bolts; damaged baseplates; l physical damage to support and components; damage to welds and I damage to structural steel.
Bechtcl Pow;r Corporation June 29, 1986 Mr. G. Bockhold Plant Vogtle Units 1 & 2 8echtel Job 9510 Transient Recovery Cooling Water File: X7J1202 Page two
2) Nuclear Operations performed a system walkdown covering the following components: pipe supports, snubbers, instruments, instrument piping, system piping and system components.
Valve positions were also noted during the walkdown. Instrument readings were compared to previous baseline data or like instruments in the train 8 NSCW system.
3) Nuclear Operations and Engineering prepared a system operability review
( plan wnich was subsequently implemented by Nuclear Operations. This plan involved a general system flow check of 7 points in the system for comparston to previous values; inspecting 12 heat exchangers for leakage from the NSCW side; verifying operability of pump discharge and bypass checks; and stroking motor operated valves and checking for unusual operation. Therefore, based on the results of the Phase A evaluation, we reconnend.-that operation of NSCW train A be continued in support of special testing and Hot Functiona.1 Testing. Our schedule for completion of the Phase B evaluation will be transmitted to you by July 1, 1986. 4 Very truly yours, BECHTEl. POWER CORPORATION M F. B. Marsh i. (Project Engineering Manager i Western Power Division PM/KW;jd xc:
0. Batum R. Moore P. D. Rice R. Pinson V-RMS i
l { i ?
Bechtel Western Power Corporation bxc: R. L. Rogers C. Shinbrot Engineers - Constructors K. Walvekar 12440 East frnpertal Highway D. L. Kinnsch Norwalk. California 90650 SEYxf* """"*" R. W ra y e July 3, 1986 Mr. G. Bockhold, Jr. General Manager Nuclear Operations Georgia Power Company EEE Plant Vogtle P. O. Box 28 2 Waynesboro, GA 30830
Subject:
Georgia Power Company Plant Vogtle - Units 1& 2 Bechtel Job No. 9510-008 Nuclear Service Cooling Water System Loss of Offsite Power Testing File: X4BC05 Log: PFE-12177
Dear Mr. Bockhold:
The Nuclear Service Cooling Water System (NSCW) has been designed to preclude excessive transient loadings on the system due to restart after a loss of offsite power (LOP). The train A NSCW system was tested by Special Test Procedure ST-il to verify that no significant transient loads were present af ter a system restart from LOP. Testing consisted of a planned series of starts with the tower spray valve and the tower bypass valve in several partially open positions to slow fill the system prior to normal operation. Results of the test showed that system transient loadings in the spray mode arg within acceptable limits it 10 during refill. A tower when the tower spray valve is get bypass valve setting of 12-1/2 when in the bypass mode also gives acceptable results. We recommend that these valves settings be used until our final review of the test results is completed. Final design settings for the valves will be given in our test report which is scheduled for issue on July 25, 1986. DesigndocumengchangeswiglbeissuedbyJuly11, 1986 to show the interim 10 and 12-1/2 valve settings. Restart of train A NSCW af ter an LOP can be performed automatically using the valve positions indicated above, provided that the design changes implemented by CCP B10130M Rev. O and Rev. 1 are implemented. This assures that valve and pump operation are sequenced to give a slow fill prior to full opera tio n. Restart of train B of NSCW should always be in the manual mode until testing has confirmed valve positions. Based on the differences in layout between trains A and B, train A test results cannot be used for se tting train B valves with a high confidence level.
Bechtel Western Power Corporation Georgia Power Company Plant Vogtle - Units 1 & 2 3echtel Job No. 9510-008 Nuclear Service Cooling Water System Loss of offsite Power Testing File: X4BC05 Log: PFE-12177 Page 2 We recommend that train B testing be performed as soon as practical. The test would be instrumented like the train A test and if possible, the valve and pump automatic sequencing should be operational. The amount required for testing will be reduced since the number of system runs will be less based on train A experience. If you require any additional information, please let us know. Very truly yours, BECHTEL WESTERN POWER CORPORATION MtO sy - J. R Af g gI F. B. Marsn Project Engineering Manager PM/KW/sl xc: O. Batum R. Moore P. D. Rice R. H. Pinson V-RMS l l l M0686177/S L
bxc: R. L. Rogers, w/a tt. Bechtel Western Power Corporation D. L. Kinnseh, w/att. Engineers - Constructors T. E. Richardson, w/a tt. 12440 East imperial H ay M R. W. Braddy, w/att. Norwalk, Cahfomia ': *: Mi;"':t"a:*t: EE=.-~~ - September 4,1986 CEFEREAZE 7 s =.......m i I 2 3 J d I a
W 23 i i !G ni o
! ts * ~ Mr. (:. Bockhold, Jr. I ~ i \\lg g,*g G neral Manager, Nuclear Operatioi s A r Georgia Power Company Vogtle Electric Generating Plant .), jh j g P. O. Box 28 2 gggg
J
' #4 8 Ml2I Mj 'l3 NII Ccynesboro, GA 30830
Subject:
Georgia Power Company Plant Vogtle - Units 1 & 2 Bechtel Job No. 9510-008 d Nuclear Service Cooling Water i Transient Recovery Program File X4BC05 Log: PFE 19743 Roference: PFE-12101 dated June 29, 1986 Docr Hr. Bockhold: Tho Nuclear Service Cooling Water System (NSCW) train A cxperienced an inadvertent waterhammer during special testing. A recovery program was established to determine the effects of the waterhammer on system integrity and long term operational ecpability. The recovery program was divided into a short term investigation (Phase A) and a long term investigation (Phase B). l Tho results of the Phase A review were transmitted to Tou in the reference letter. Attachment (1) is a description of the Phase A inspections. No abnormal conditions were found in any Phase A walkdown or evaluation. 1' Tho Phase B program, Attachment (2), consists of a one time inopection program to be implemented prior to fuel load to ensure that the system and components can perform their intended design i I function. Any discrepancies found during these inspections i sh uld be evaluated by engineering. We have not received rccommendations from all component suppliers for post waterhammer inspections. We will have a finalized program including all oupplier input by September 19, 1986. l
71Mi*'I*e'_C"U"Y Bechtel Western Power Corporation 7, e 1 s. 2 Bechtel Job No. 9510-008 Nuclear Service Cooling Water Transient Recovery Program File X4sC05 Log: PFE-12741 Page Two If you require any additional information, please le c us know. Very truly yours, BECHTEL WESTERN POWER CORPORATION ^ F. B. Marsh Project Engineering Manager PM/GHF/sl 'e Attachments xc: O. Ba tum, w/a tt. R. Moore, w/att. R. H. Pinson, w/a tt. l P. D. Rice, w/att. V-RMS, W/a tt. i PO986014/5L
ATTACHMEtrF 1 Page 1 of 3 PHASE A INSPECTIONS The Phase A evaluation has been concluded and is summarized below. No abnormal conditions were found in any walkdown or evalua tion. o PIPING AND PIPE SUPPORTS Piping and pipe supports walkdown were made by trained 1 Bechtel and V-SAMU personnel. Piping was inspected for i dents; damage to attached vents, drains and small bore branches; leakage at flanges, valves and nozzles; damage to flanges and valves; and pipe deformation or damage at i penetrations. Pipe supports were inspected for, damaged lugs or stanchions; damaged axial supports; marks on pipe from supports; pulled or damaged anchor bolts; damaged baseplates; physical damage to support and components; damage to welds and damage to structural steel. o GENERAL SYSTEM FI4W CHECK Flow balance data for the NSCW System after the flow i transient testing was compared with that prior to the testing program.
Pressure drop across the following flow elements was evaluated and found within acceptable limits:
1-1202-FE-1640A 1640s 1720A 17208 i 1802 2224 i i' O PUMP MOTOR COOLERS j The shell side drain from the following pumps was opened with no evidence of water being present: I i Component Cooling Water Pumps 1-1203-P4-001, 003, 00 5 Residual Heat Removal Fump 1-1205-P6-001 Centrifugal Charging Pu'mp 1-1208-P6-002 i i l P0986014/SL
r ATTACHMENT 1 Page 2 of 3 o CCW AND ACCW MEAT EXCHANGERS The shell sides of heat exchangers 1-1203-E7-001 and 1-1217-E7-001 were isolated and flow from the shell side vents evaluated. No flow was observed indicating no NSCW tube side leakage. o ESF CHILLER CONDENSER The evaporator and condenser continued to show 15-inch vacuum as from several days prior to the water hammer. The ] evaporator sight glass mid-glass level of freon. Water leaking from the NSCW side would result in a less 15 inch vacuum or abnormal purging operation of the chiller. Neither of these conditions existed, indicating no NSCW tube side i
leakage, o
DIESEL GENERATOR JACKET WATER HEAT EXCHANGER Conditions normal. No over flow from vent at top of stand pipe 24 hours af ter transient. This indicated no NSCW tube side leakage. o LUBE OIL COOLERS - Centrifugal charging pump 1-1208-P6-002 A 50ml sample was drawn from the bottom of the lobe oil tan k. No indication of water was evidenced af ter a three hour settling time. - Safety injection pumps 1-1204-P6-004, 005 No evidence of water contamination in any site glasses. o CONTAINMENT COOLERS Flanged connections on all coolers showed evidence of minor j weeping. This condition was present to some extent prior to the waterhammer event. This is not abnormal considering the fit-up problems associated with these joints. No apparent i damage or leakage from the brazed joints was observed. N
l-l ATTACHMENT 1 Page 3 of 3 f o PUMP DISCHARGE CHECK VALVES, DISCHARGE BYPASS CHECK VALVES Ale MOTOR OPERATED VALVES Operation / performance normal. No abnormalities were evident in motor operated valves 1-1202-HV-1668A & B, HV-ll605 or HV-ll606. o INSTRUMENTATION AND CONTROLS 4 A review of the NSCW system P& ids indicates that the only instruments subject to potential damage as a result of the flow transient testing transients are the AMETEK 1981 pressure gages, 0-200 psig. These are tag numbers: PI-1804 1826 1834 2140 2148 2150 2152 2155 Possible damage would be evidenced by leakage, zero shif t, or + calibration error. No damage is anticipated due tp the short r (millisecond) duration of the transients and the physical connection method to the pipe via; root valve, 3/8 x.065" j tubing, instrument isolation valves and fittings all of which provide significant dampening for a short term transient. Normal calibration procedures will evaluate these items. t P098 6014/S L
5 ATTACHMElff 2 Page 1 of'2 PEASE B IRSPETIOES The Phase B program consists of the following inspections along with some additional vendor recommended inspections. The vendor j recommendations will be finalized by September 19, 1986. o PIPING AND PIPE SUPPORTS A broken snubber (V1-1202-181-H050) has been discovered as a result of the waterhammer investigation. It has not been i confirmed that this damaged snubber was a result of the waterhammer. However, to ensure no other snubbers have been damaged, a review has been made to determine a sample of snubbers that would be susceptible to waterhammer. Ttiese snubbers should be stroke tested and the results transmitted to engineering. ) V1-1202-223-H017 V1-120 2-223-H018 V1-1202-007-H002 Vl-1202-181-H050 Vl-1202-004-H073 Vl-120 2-004-H 045 V1-1202-512-H011 Vl-1202-037-H031 o GENERAL l In addition to the inspections outlined below, obtain and evaluate implementation of vendor recommended inspection guidelines for equipment. 1 o PUMPS Compare vibration levels and discharge pressure with base line data. o HEAT EXCHANGERS Hydro test heat exchangers (subject tube side only to design pressure), or as recommended by vendors per item 1 above. P0986014/S L
ATTACHMENT 2 Page 2 of 2 optional Inspection: ESF Chiller condenser internals (inspect channel side only) or as recommended by the vendor. Lube oil Coolers - Test of oil samples for water contamination. o CHECK VALVES Inspect valve internals (pump discharge and other keep full check valves). o VALVES Stroka all in-line valv'es and verify proper operation. o FLANGES Inspect for leakage (inspect for increased flow on previously identified leaks). o RELIEF VALVES Check set pressure on leaking valves only. o TEs AND ANNUBARG Compare instrument readings with baseline data.5 o ORIFICES For instrumented flow elements, compare readings with l baseline data. O EQUIPHENT NOZZLES NDE nozzle welds of large Heat Exchangers/ Coolers (8" and larger) to the same level as was performed originally by the manufacturer. P0986014/SL
n:: R2 L. Rog rs C. Shinbrot D3 L. Kinnsch (Jobsite) N Bechtel Western Power Corporation Engmeets - Constructors 12440 East Imperial Highway Norwalk. Cahfornia 90650 { eon g.=,=.eten utz:cuoama mo OcLier 10, 1986 gEFGiefaG S Mr. G. Bockhold, Jr. General Manager, Vogtle Nuclear Operations Georgia Power Company P. O. Box 1600 Waynesboro, Georgia 30830
Subject:
Georgia Power Company Plant Vogtle - Units 1 & 2 Bechtel Job 9510 NSCW Valve Setting File: X4B 05 Loo:Mm
Dear Mr. Bockhold:
The Nuclear Service Cooling water (NSCW) system design has been modified by CCP B10130M to throttle the cooling tower return spray valves (HV-1668A and HV-1669A) and bypass valves (HV-16688 and NV-16698). The intermediate positions are identified in IDCN 122 to drawing IX5DN089-3. The valve positions were determined by field testing of the Unit 1 NSCW system. During testing, the valve position switches were set as follows: 1) All valve movements were made by manually operating the handwheels. Each valve was stroked f rom full closed (0* open) to full open (90* open). For each valve, 18 handwheel turns were required to go from closed to open, so each handwheel turn was equal to 5' of valve travel (90*/18 turns = 5*/ turn). 2) To set a valve, the valve was fully closed.
Next, the handwheel was turned until the valve stem was engaged.
From that point, the handwheel was turned the required number of times to attain the desired position. For example, a setting of 12.5* was 12.5*). 2.5 turns (2.5 x 5' =
B cht:1 W:st :rn Power Corporation October 10, 1986 Mr. G. Bockhold Plant Vogtle - Units 1 & 2 Bechtel Job 9510 NSCW Valve Setting File: X48C05 Page 2 3) The limit switch contacts were then adjusted to act' sate at the desired valve position. From discussions with Gary Locke of Nuclear Operations, we understand ti.at the procedures for setting Limitorque motor operator limit switches are being developed. Due to the difficulty in verifying a valve position specified in degrees open, we recommend that your procedures use handwheel turns as the valve swtting criteria. The valve settings given in degrees ir the design documents should be converted to equivalent handwheel turns based on the discussion above for the nuclear service cooling water system. If you have any questions, please contact us. Very truly yours, BECHTEL WESTERN POWER CORPORATION WWND sy )). ' ww W F. B. Marsh Project Engineering Manager i PM/KW/chs ac: G. Locke (Nuc Ops Site) W. Gover (Nuc Ops Site) P. D. Rice NORMS i l i nn- -. -.,. n,_ _. -.- - -. -.. - - _ _ _. - - ,.,,e ,.-_-.-.-_,.n- -,-n-, ,}}

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