BVY 04-106, Vermont Yankee - Technical Specification Proposed Change No. 263 - Supplement No. 18 Extended Power Uprate - ECCS Pump Net Positive Suction Head Margin

Vermont Yankee - Technical Specification Proposed Change No. 263 - Supplement No. 18 Extended Power Uprate - ECCS Pump Net Positive Suction Head Margin

ML042870195
Person / Time
Site:	Vermont Yankee File:NorthStar Vermont Yankee icon.png
Issue date:	10/05/2004
From:	Thayer J Entergy Nuclear Northeast, Entergy Nuclear Operations
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
BVY 04-106, TAC MC0761
Download: ML042870195 (139)

Text

Entergy Nuclear Northeast Entergy Nuclear Operations, Inc.

Vermont Yankee 185 Old Ferry Rd.

'* GEntergy P.O. Box 500 Brattleboro, VT 05302 Tel 802-257-5271 October 5, 2004 Docket No. 50-271 BVY 04-106 TAC No. MC0761 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

Subject:

Vermont Yankee Nuclear Power Station Technical Specification Proposed Change No. 263 - Supplement No. 18 Extended Power Uprate - ECCS Pump Net Positive Suction Head Margin

References:

1) Entergy Nuclear Operations, Inc. letter to U.S. Nuclear Regulatory Commission, "Technical Specification Proposed Change No. 263 -

Supplement No. 8, Extended Power Uprate - Response to Request for Additional Information," BVY 04-058, July 2, 2004

2) Entergy Nuclear Operations, Inc. letter to U.S. Nuclear Regulatory Commission, 'Technical Specification Proposed Change No. 263 -

Supplement No. 9, Extended Power Uprate - Revised Containment Overpressure Envelope," BVY 04-071, July 27, 2004

3) GE Nuclear Energy, "Safety Analysis Report for Vermont Yankee Nuclear Power Station Constant Pressure Power Uprate," NEDC-33090P (Proprietary), September 2003, and NEDO-33090 (Non-Proprietary), September 2003 Reference 1 provided a response to an NRC staff request for additional information (RAI) regarding the application by Entergy Nuclear Vermont Yankee, LLC and Entergy Nuclear Operations, Inc. (Entergy) for a license amendment to increase the maximum authorized power level of the Vermont Yankee Nuclear Power Station (VYNPS) from 1593 megawatts thermal (MWt) to 1912 MWt (i.e., an extended power uprate). Reference 2 updated certain information provided in Reference 1 regarding the revised containment overpressure analysis.

Attachment 1 to this letter provides Revision 8 of Calculation No. VYC-0808, "Core Spray and Residual Heat Removal Pump Net Positive Suction Head Margin Following a Loss of Coolant Accident and an Anticipated Transient Without Scram with Fibrous Debris on the Intake Strainers." An earlier version of this calculation was previously provided to the NRC staff in Reference 1 as Exhibit 1 to Attachment 4. Attachment 2 to Reference 2 provided Calculation Change Notice 06 to calculation VYC-0808. Revision 8 to VYC-0808 is the latest version of the calculation and incorporates changes made since the submittal of Reference 2 (Note: Revision 7 incorporated two change notices previously provided to the NRC staff.) These changes

BVY 04-106 Docket No. 50-271 Page 2 of 3 include a revised input assumption (i.e., condensate storage tank water temperature) and effects on suppression pool temperature associated with power uprate. Attachment 1 does not contain any proprietary information within the meaning of 10 CFR 2.390; disregard any "proprietary" markings.

The changed input assumption also slightly affected the results of the Anticipated Transients Without Scram (ATWS) analysis presented in Table 9-5 of Reference 3 (PUSAR):

• The value for peak suppression pool temperature under CPPU conditions increased from 1901F to 190.50 F.

• The value for peak containment pressure under CPPU conditions increased from 12.5 psig to 12.7 psig.

The results of the ATWS analysis are acceptable and continue to meet the acceptance criteria presented in PUSAR Section 9.3.1 of peak suppression pool temperature less than 281OF and peak containment pressure less than 62 psig.

This supplement to the license amendment request provides additional information to update Entergy's application for a license amendment and does not change the scope or conclusions in the original application, nor does it change Entergy's determination of no significant hazards consideration.

There are no new regulatory commitments contained in this submittal.

If you have any questions or require additional information, please contact Mr. James M.

DeVincentis at (802) 258-4236.

I declare under penalty of perjury that the foregoing is true and correct.

Executed on October 6, 2004.

Sincerely, Jo VSThtayer S Vice President Vermont Yankee Nuclear Power Station Attachments (1) cc: (see next page)

BVY 04-106 Docket No. 50-271 Page 3 of 3 cc: Mr. Richard B. Ennis, Project Manager (w/attachment)

Project Directorate]

Division of Licensing Project Management Office of Nuclear Reactor Regulation Mail Stop 0 8 B1 Washington, DC 20555 Mr. Samuel J. Collins (w/o attachment)

Regional Administrator, Region I U.S. Nuclear Regulatory Commission 475 Allendale Road King of Prussia, PA 19406-1415 USNRC Resident Inspector (w/o attachment)

Entergy Nuclear Vermont Yankee, LLC P.O. Box 157 Vernon, Vermont 05354 Mr. David O'Brien, Commissioner (w/attachment)

VT Department of Public Service 112 State Street - Drawer 20 Montpelier, Vermont 05620-2601

BVY 04-106 Docket No. 50-271 Attachment 1 Vermont Yankee Nuclear Power Station Proposed Technical Specification Change No. 263 - Supplement No. 18 Extended Power Uprate - Response to Request for Additional Information ECCS Pump Net Positive Suction Head Margin Calculation No. VYC-0808, Revision 8 Total number of pages in Attachment 1 (excluding this cover sheet) Is 135.

ATTACHMENT 9.2 CALCULATION COVER PAGE Sheet I of I CALCULCATION COVER PAGE 0 IP-2 El IP-3 D JAF QPNPS E VY ow This revision Incorporates the Calculation No. following MERLIN DRNs or Minor CalcSheIof5 VYC-0808 changes:CCN04 and CCNO6 1Sheet of 58 to Rev. 6

Title:

Core Spray and Residual Heat Removal Pump Net Positive Suction Head Margin following a Loss of Coolant Accident and an QR NQR Anticipated Transient Without Scram with Fibrous Debris on the Intake QR N Strainers Discipline:Fluid Systems I Design Basis Calculation? 0Yes E]No This calculation supersedes/voids calculation: Supercedes VYC-0808, Rev. 7 upon EPU implementation.

Modification NoJTask No/ER No: WDC 2003-008 ED No software used o Software used and filed separately (Include Computer Run Summary Sheet).

If 'YES', Code:

El Software used and filed with this calculation. If 'YES', Code:

System NoJName: 10 RHR. 14 CS Component No.Name: P-10-IA.B.C.D: P-46-1A.B (Attach additional pages If necessary)

Print/Sign REV # STATUS PREPARER REVIEWER/ OTHER APPROVER DATE (Prel, Pend, DESIGN REVIEWERI .

A, V, S) VERIFIER DESIGN VERIFIER 7 A B. C. Slifer P.A.Rainey None J.G.Rogers 9122/04 Pend B.C ier P.A.Rainey None J.G.Roe_

_ tewt~j~.R .fasi

ATTACHMENT 9.6 CALCULATION RECORD OF REVISIONS Sheet I of of I RECORD OF REVISIONS Calculation Number: VYC-0808 Page 2 of 58 Revision No. Description of Change Reason For Change 7 1. Add, as an attachment, an 1. Incorporate CCN01.

evaluation of RHR pump NPSH 2. Incorporate CCN03.

margin in Shutdown Cooling mode.

2. Update Sections 3.2 and 4.2 to reflect current basis for debris and sludge terms and their effect on strainer head loss.

8 Changes reflect higher suppression pool Power uprate and incorporates CCN04 and temperatures associated with power uprate CCN06 to WC-0808 Rev. 6.

and the subsequent Incorporation of containment overpressure credit in the calculation of NPSH margin.

VYC-808, Rev. 8 Page 3 of 58 TABLE OF CONTENTS CALCULATON COVER PAGE ........................... I RECORD OF REVISIONS ......................... 2 TABLE OF CONTENTS ......................... 3 LIST OF EFFECTIVE PAGES ......................... 5 1.0 OBJECTIVE ........................... 6 2.0 METHOD OF SOLUTION ........................... 6 3.0 INPUTS AND ASSUMPTIONS .......................... 12 4.0 CALCULATION .......................... 18 5.0

SUMMARY

& CONCLUSIONS .......................... 31

6.0 REFERENCES

.......................... 35 TABLES 4.1 LOCA-Short Term 4.2 LOCA-Long Term 4.3 ATWS 4.4 General Profile 4.5 Minimum Flow FIGURES 4.2 LOCA Overpressure Required 4.3-1 ATWS Overpressure Required 4.3-2 ATWS vs. LOCA Suppression Pool Temperature 4.4-1 General Profile-1 RHR Pump, Mim. and Max. NPSHr 4.4-2 General Profile-2 RHR Pumps, Min. and Max. NPSHr 4.4-3 General Profile-1 CS Pump, Min. NPSIIr 4.4-4 General Profile-1 CS Pump, Max. NPSHr

VYC-808, Rev. 8 Paue 4 of 58 ATTACHMENTS No. Title No. of Pages I Derivation of Strainer Debris Accumulation Equation 2 2 Innovative Technology Solutions Corporation, "Revised ECCS Suction 3 Strainer Head Loss Assessment for Vermont Yankee," lTS/VY-00-001, Rev. 0 3 Available NPSH for Most Limiting Torus Temperature Transient 10 4 RHR NPSH Margin in Shutdown Cooling Modes 16 5 SulzerBingham Pumps Inc. Document E12.5.561, NPSH/Minimum 19

_ Flow Study-Summary Report, dated May 26, 1998.

6 Core Spray NPSH Evaluation 4 7 Residual Heat Removal (LPCI) NPSH Evaluation 12 8 EXCEL Verification 6 9 ATWS Sensitivity to CST Water Temperature Change 5

VYC-808, Rev. 8 PaNe 5 of 58 LIST OF EFFECTIVE PAGES PAGE REV. PAGE REV. PAGE REV.

1 7 1to58 8 I 8 2 7 3 7 4 7 _

5tolO 6 llto12 7 13 to 17 6_ _

18to20 7 21 6 22 7 23 to 25 6 Attach. 1 6 Attach. 1 6 Attach. 2 6 Attach. 2 6 Attach. 3 6 Attach. 3 8 I s Attach. 4 7 Attach. 4 7 Attach. 5 6 Attach. 5 6 Attach.6 6 Attach. 6 6 Attach. 7 6 Attach. 7 6 Attach. 8 8 I8 Attach. 9 8

VYC-808, Rev. 8 Page 6 of 58 VYC-808, Rev. 8 Page 6 of 58 1.0 OBJECTIVE 1.1 To determine the NPSH margin and containment overpressure required for the Core l

• Spray and Residual Heat Removal (RHR) pump taking suction from the Torus (1) at maximum run out flow during the first 10 minutes following a LOCA, (2) at design flow at the maximum peak post-LOCA suppression pool temperature, and (3) over the long-term post-accident suppression pool heatup and cooldown transient. Attachment 4 also provides NPSH margin while in the shutdown cooling mode.

1.2 To determine the NPSH margin and containment overpressure required for the Core Spray and RHR pumps taking suction from the Torus following an Anticipated Transient Without Scram (ATWS) event.

1.3 Additionally, a basis for readily determining overpressure requirements, when performing RHR and CS pump NPSH evaluation for any other events which cause elevated suppression pool temperatures, will be provided. This will be in the form of a family of curves profiling overpressure required vs. pool temperature.

Revision 8 differs from Revision 7 by introducing the concept of overpressure credit for LOCA and ATWS, which was initially documented in CCN 4 to Rev. 6. Revision 8 also-incorporates CCN 6 to Rev. 6 and changes to the LOCA and ATWS analysis which were -

issued after CCN 4 to Rev. 6 was accepted. Revision 8 will retain the status of PENDING until the license amendment for power uprate is approved, at which time the status will be changed to ACTIVE.

The RHR and Core Spray Systems are Safety Class 2.

2.0 METHOD OF SOLUTION 2.1 Required NPSH can be obtained from the pump curves based on witnessed tests performed by the pump vendor. There is a separate set of test data for each of the two Core Spraypumps and the four RHR pumps delivered to Vermont Yankee. A curve fit bounding the required NPSH data was developed for each pump type. The required NPSH for the RHR pumps is based on the data labeled "Minimum Operable NPSH @

Reduced Head". (The basis for the RHR required NPSH was reviewed during the AE Inspection (Ref. 4)).

VYC-808, Rev. 8 Page 7 of 58 At Vermont Yankee's request, the pump vendor performed additional NPSH evaluations for the RHR and Core Spray pumps in order to provide a more rigorous basis for interpolating between and extrapolating beyond the NPSH data base provided with the pumps. The pump vendor supplemented the data supplied for each pump with additional and more extensive data for the same or similar pumps obtained from their archives. The pump vendor used these data, adjusted as necessary using pump affinity laws, to develop characteristic NPSH curves that complement the original witnessed test data. When pumps have been NPSH tested over a small flow range and NPSH data are required outside of this range, the NPSH curves have to be extrapolated. Only NPSH tests of pumps of similar style, design, specific speed, suction specific speed, number of impeller vanes and suction vane angles can be used for this purpose.

The pump vendor also provided additional information to define allowable times of operation and minimum allowable NPSH for minimum flow conditions and at higher flow rates. The vendor report is included as Attachment 5.

2.1.1 RHR Pumps The original witnessed test data for the four (4) RHR pumps covered a flow range of 6,300 gpm to slightly less than 9,000 gpm. This range is adequate for the RHR pumps since the expected maximum flow rates following a LOCA are between 7,100 gpm and 7,400 gpm.

NPSH tests were also performed on one of the four RHR pumps, prior to the final impeller trimming, at 6300, 8065, and 9502 gpm. Five (5) to eight (8) test points were taken at each of the above capacities to establish the slope and shape of NPSH vs. Total Dynamic Head (TDH) curve. These tests established that the so-called knee of the NPSH vs. TDH curve is gradual, i.e. there is no rapid drop in TDH for a relatively small reduction in NPSH. Data points were taken at TDH reductions of up to 8% relative to the values obtained at higher values of available NPSH. These data were used to develop a family of curves of NPSH vs. flow for TDH drops of 1%, 3%, and 6%. The witnessed test data compared to these curves fell somewhere between 3% and 6% lines, and slightly.

below the 6% line for flow rates above 7,000 gpm for the data points labeled "Minimum Operable NPSH @ Reduced Head". The vendor concluded that the pumps, if operated with the minimum NPSH, are within acceptable limits of the NPSH knee.

Extrapolation of required NPSH to flow rates less than 6,300 gpm was based on data from tests on similar pump designs, but of different sizes (18x24x28 CVIC and 8xIWx21 CVIC vs. 16x18x26 CVIC). Similar pumps are of the same suction specific speed, number of vanes and suction vane angle. The extrapolation is based on estimation and experience from NPSH tests on other styles of pumps performed in recent years, when more detailed NPSH tests were required. NPSH at lower flow rates is of less importance than at higher flow rates since available NPSH will always be higher at lower flow rates because of lower head loss due to flow, and also since core and containment cooling requirements dictate flow rates higher than 6,300 gpm when reactor water level is below

VYC-808, Rev. 8 Page 8 of 58 the elevation of the top of the active fuel. The extrapolated NPSH at flow rates less than 6,300 gpm is not used for the evaluation of design NPSH margins. The required NPSH at low flow rates is mainly of interest in evaluating operating characteristics under minimum flow conditions, when the pumps are operating with the minimum flow bypass valves in their open position until reactor pressure drops low enough to allow the injection valves to open.

The pump vendor also provided an assessment of the potential for permanent pump damage due to cavitation at the minimum NPSH. Their assessment required input from Vermont Yankee on the durations of operation at minimum NPSH conditions. Vermont Yankee provided this information in the form of predicted suppression pool temperature and available NPSH vs. time for the LOCA. Relative to the RHR pumps, when operating for seven (7) hours at 7,000 gpm with an available NPSH of 23 to 24 feet, the pump vendor concluded that, "Depending on water temperature and water chemistry there can be some "frosting (e.g. light pitting) on the impeller suction vanes, but there will be no detrimental pump damage due to cavitation when operating at minimum NPSH for the specified hours of operation." The vendor extended this assessment beyond the seven (7) hours at 23 to 24 feet of NPSH to define the NPSH required based on an impeller life of 8,000 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />. This information is compared to the expected decrease in suppression pool temperature following the peak, and subsequent increase in available NPSH, and it shows that the RIR pump will always operate within the acceptable bounds defined by the vendor.

The vendor recommended minimum flow requirements were given as < 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 350 gpm and > 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 2700 gpm. The corresponding required NPSH values were 30 fR at 350 gpm and 26 ft at 2700 gpm (page 5, Attachment 5).

2.1.2 CS Pumps

.-The original witnessed test data for the CS pumps covered a flow range of 3,000 gpm to slightly more than 3,800 gpm. The expected maximum flow rates following a LOCA are between 3,000 gpm and 4,600 gpm.

More comprehensive NPSH tests were performed on an identical pump for a different customer. These tests were performed at approximately 1780 rpm. Converted to 3582 rpm using affinity laws, the flow rates were 3005, 4037, 5038, 5120, 6000, 6020, and 6524 gpm, thus bounding the flow range of interest. Four (4) to ten (10) test points at each of the above capacities established the slope and shape of the NPSH vs. TDH characteristic curve. Differences in impeller trim diameter were also factored into the developed required NPSH curves. The vendor concluded that these tests were sufficient to develop NPSH characteristics for the pump and are representative of the pumps delivered to Vermont Yankee. The vendor also concluded that Vermont Yankee's pumps, if operated with the minimum NPSH, are within acceptable limits of the NPSH knee.

WC-808, Page 9 of 58 VY-88 Rev. Rev 88 ae9f5 Extrapolation of required NPSH to flow rates less than 3,000 gpm was based on data from tests on similar pump design, but of different size (12x14xl4 '/2 CVDS and 14x16x23 CVDS vs. 12x16x14 CVDS). Similar pumps are of the same suction specific speed, number of vanes and suction vane angle. The extrapolation is based on estimation and experience from NPSH tests on other styles of pumps performed in recent years, when more detailed NPSH tests were required. NPSH at lower flow rates is of less importance than at higher flow rates since available NPSH will always be higher at lower flow rates because of lower head loss due to flow, and also since core cooling requirements dictate flow rates higher than 3,000 gpm when reactor water level is below the elevation of the top of the active fuel. The extrapolated NPSH at flow rates less than 3,000 gpm is not used for the evaluation of design NPSH margins. The required NPSH at low flow rates is mainly of interest in evaluating operating characteristics under minimum flow conditions, when the pumps are operating with the minimum flow bypass valves in their open position until reactor pressure drops low enough to allow the injection valves to open.

The pump vendor also provided an assessment of the potential for permanent pump damage due to cavitation at the minimum NPSH. Their assessment required input from Vermont Yankee on the durations of operation at minimum NPSH conditions. Vermont Yankee provided this information in the form of predicted suppression pool temperature and available NPSH vs. time for the LOCA. The vendor concluded that the CS pumps have more margin than the RHR pumps relative to potential damage from cavitation at the minimum available NPSH predicted for the LOCA. The vendor developed a curve of allowable hours of operation vs. available NPSH for the CS pump similar to that developed for the RHR pump. Comparison of predicted minimum available NPSH for the CS pumps vs. time for the LOCA shows that the CS pump will always operate within the acceptable bounds defined by the vendor based on an 8,000 hour0 days <br />0 hours <br />0 weeks <br />0 months <br /> impeller life.

The vendor recommended minimum flow requirements were given as < 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 300 gpm and > 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 1250 gpm. The corresponding required NPSH values were 32.5 ft at 300 gpm and 27 ft at 1250 gpm (page 5, Attachment 5).

2.2 Since the vendor chose to use a postulated minimum available NPSH rather than the minimum tested NPSH for their evaluation of acceptable durations of operation based on potential cavitation damage to the pump impeller, a reassessment of NPSH margins using minimum available NPSH rather than minimum tested NPSH was performed. The following table compares the values used in the vendors evaluations and comparable values at the same flow rates from the witness tests.

VYC-808, Rev. 8 Page 10 of 58 Minimum Available Minimum Required NPSH assumed by NPSH from Original Vendor for the Impeller Witness Tests' PUMP FLOW (gpm) Life Study (ft)

P(f)

CS 3,000 24.0 24.0 4,600 28.0 No Data RHR 6,400 23.0 23.2 7,000 23.5 22.6 7,600 24.0 23.5 Using the minimum available NPSH values from the impeller life study as required values is conservative since the values are based on the long-term reliability of the pump impellers, and they are equal to or bound the witnessed test data.

NPSH values at other flow rates are based on curve fits developed from the above data points and vendor predicted characteristic curves (NPSH vs. flow rate).

2.2.1 For CS, the curve fit incorporates the witnessed test data points for flow rates between 3,000 gpm and 4,600 gpm.

FLOW NPSH SOURCE (gym) 3003 24.0 Curve No. 27692 3522 24.9 Curve No. 27692 3810 25.0 Curve No. 27692 3000 24.0 Curve No. 27691 3542 24.5 Curve No. 27691 3810 25.0 Curve No. 27691 4600 28.0 SBPI Document No. E12.5.561 (Attachment 5)

Curve Fit:

A following second order polynomial curve fit to conservatively bound the above data was developed:

NPSH = 26.4 - 2.965 x 10-3 Q + 7.191 x 107 Q2

'NPSH is determined from a curve fit that bounds all data points for each pump.

VTC-808, Rev. 8 Page TC-8O8, Rev. 8 Page 11 11 of of 58 58 where Q is Flow Rate in gpm.

Comparison between Data and Curve Fit FLOW DATA FIT 3003 24.0 24.0 3500 none 24.8 3522 24.9 24.9 3810 25.0 25.5 4600 28.0 28.0 2.2.2 RHR A different approach is taken for RHR. The witness test data were not used to develop a curve fit. The SBPI recommended minimum available NPSH bounded the Minimum Operable NPSH @ Reduced Flow data from the witness tests over the flow range of interest, therefore the recommended minimum available NPSH was used exclusively. A simple linear interpolation scheme is used as the curve fit.

Flow range: 6,400 gpm to 7,600 gpm Sources: SBPI Document No. E12.5.561, NPSH/Minimum Flow Study-Summary Report, dated May 26, 1998. (Attachment 5)

Data:

FLOW NPSH 6400 23.0 7000 23.5 7600 24.0 Curve Fit:

NPSH = 23.0 + (Q - 6400) / 1200 2.3 Available NPSH is calculated using the industry standard equation (Ref. 1)

NPSH Available = (pTw. - p,) (144)v + Z - Hf- Hd - H, where p-r,,, = Torus pressure, psia PV = vapor pressure of the pumped fluid, psia v = specific volume of the pumped fluid, cu ft / lb Z = elevation head, torus to pump suction, ft HS = suction strainer loss, ft Hd = strainer debris loss, ft

VYC-808, Rev. 8 Page 12 of 58 Page 12 of 58 VYC-808, Rev. 8 Hf = friction loss in suction piping, ft 2.4 The amount of debris on a strainer will vary with time, starting at zero and increasing to the total value as the debris passes through each strainer and is removed from the water.

Assuming the debris is uniformly dispersed in the suppression pool, the fraction of debris deposited on the strainers at a time, t, after initiation of flow, assuming a constant flow rate, is (see Attachment 1 for the derivation)

D/Dmiea =0(- e 4Q t/ V) where D/Dj1 ,w 1 = fraction of the total debris deposited on the strainer Q = total pump flow rate t = time V = suppression pool volume = 68,000 cu ft minimum (TS 3.7.A.l.e)

This equation is used to determine the amount of fibrous debris deposited on the strainers during the first 10 minutes following a LOCA.

After ten minutes, it is assumed that one Core Spray pump provides cooling to the core, and one RHR pump cools the suppression pool. The remaining debris in the suppression pool and any debris deposited on an active strainer supplying pump(s) in the short-term that is subsequently secured for the long-term is deposited on the two active strainers in proportion to their flow rates. The total debris thus deposited on the two active strainers is used to determine NPSH margin at the peak suppression pool temperature.

2.5 A survey of ECCS single failures was done to identify what single failure resulted in the maximum debris accumulation on the strainers during the first ten minutes and at the peak suppression pool temperature.

3.0 INPUTS AND ASSUMPTIONS 3.1 The suppression pool temperatures used in the analysis are based on Referefee49 l9 General Electric Company calculations for LOCA and ATWS (Ref. 10 and Ref. 1 1). l 3.2 The debris head loss term for the RHR and Core Spray strainers is based on the DBA lt LOCA Base Case documented in VYC-1924, Rev. 0 (Ref. 2).

RHR @ 7400 gpm 0.33 ft RHR @ 14200 gpm 0.48 ft CS @ 3500 gpm 0.21 ft CS @ 4600 gpm 0.32 ft These head loss values are based on debris loads that are different than those calculated in VYC-l 677 (Reference 3), and on a peak suppression pool temperature that is less than

VYC-808, Rev. 8 Page 13 of 58 VYC-808, Rev. 8 Page 13 of 58 calculated in Reference 10. Both of these effects cause a slightly higher calculated head loss, and thus represent additional conservatism in the calculation. The degree of conservatism is indicated in the "Revised ECCS Suction Strainer Head Loss Assessment for Vermont Yankee" (Attachment 2). The calculation of NPSH margin is done at the peak LOCA suppression pool temperatures because the negative effect of vapor pressure on NPSH margin significantly outweighs the slight benefit on the debris head loss term.

As documented in ERC No. 2003-027 (Ref. 12), EPU does not affect the debris source terms.

It should be noted that the limiting head loss due to debris loading on the RHR and CS suction strainers is calculated at a specific temperature. Strainer head loss is essentially inversely proportional to fluid temperature as documented in the sensitivity evaluation in VYC-1924 Rev 0 (Ref. 2). Therefore the calculated limiting head loss, described above, will be conservatively used for all fluid temperatures greater than or equal to that used in the calculation of the limiting head loss. For lower temperatures, the head loss will be increased in proportion to the decrease in temperature.

3.3 The calculation also conservativcly assumes that containment prcssure is equal to 14.7 pi regardless of the temperature and the initial pressure. This assumption is in aecordance 'with Regulatory Guide 1.1 .Note that prior revisions of this calculation assumed torus pressure remains at atmospheric pressure in the evaluation of NPSHa.

However, because of the increased pool temperature at power uprate conditions and resulting increased vapor pressure, there will not be adequate NPSHa for some events without taking credit for some torus air space pressure. If NPSHa is inadequate, then the necessary torus air space pressure, above atmospheric pressure, (overpressure) will be calculated to yield adequate NPSHa. Containment overpressure required and available is determined in accordance with Regulatory Guide 1.82, Rev. 3. For a high temperature, time dependent event, such as a LOCA, the NPSH will be evaluated over the time-temperature profile of the event in lieu ofjust at the maximum temperature. This will allow development of a time dependent profile for required overpressure. The amount of overpressure credited in the evaluation of margin is based on engineering judgment and is selected to be approximately half-way between the overpressure required and the overpressure available.

3.4 The LOCA calculation is done for two conditions called short-term and long-term. l 2 3.4.1 The short-term condition assumes that the suppression pool temperature is at its highest calculated value at 10 minutes, and there has been no operator action to initiate suppression pool cooling or to secure or throttle ECCS pumps. Reactor pressure is assumed to be equal to containment pressure, thus ECCS pumps are operating at their maximum flow rates. The maximum u n pool tempe re at the end of 1 j minutes is assumed to be 164 (page 2, Ref-.49)-.The debris loading on the ECCS pump suction strainers is based on the maximum fraction of the suppression pool volume that

VYC-808, Rev. 8 Page VYC-808, Rev. 8 Pa2e 14 14 of of 58 58 has passed through the strainers during the first 10 minutes of the event. The maximum run out flow for the one RHR pump is 7,400 gpm in one loop, for two RHR pumps in one loop, 14,200 gpm, and for the Core Spray pump, 4,600 gpm (Ref. 7).

8I 3.4.2 The long-term condition is assumed to be anytime after the first 10 minutes represent the conditions when the peak suppression pool temperature is reached, several hours after initiation of the LOGA. The peak suppeso poo -temperature is assumed to be 182.6.'

(Tnabv 2, Rcf. 19). The peak temperatures were selected to bound both short and long term conditions. It is assumed that the ECCS suction strainers have reached their 8I maximum debris loadings by the time the suppression pool reaches its peak temperature.

It is also assumed that, in accordance with operating procedures (Ref. 8), operators have initiated torus cooling with the RHR. Previcus calculations of NPSH for the RHR assumed that the RUDR flow would be thettled to 7,000 gpm, per procedures. In anticipation of a potential change which will eliminate the 7,000 gpm limit on-flow, The present calculation wil-assumes an RHR flow rate of 7,400 gpm, which is the maximum short-term flow rate for one RHR pump in the LPCI mode (see Section 3.3). The actual flow rate is expected to be less than 7,400 gpm.

The Core Spray pump is assumed to be throttled based on Emergency Operating Procedures. Operators will monitor NPSH limit curves in the EOPs and will throttle flow if indicated flow and pool temperature are outside the acceptable operating envelope. In order to assure adequate core cooling, a minimum indicated flow rate of 3,244 gpm will be maintained (Ref. 20). A minimum indicated flow rate of 3,244 gpm could result in a maximum actual flow rate of 3,500 gpm, allowing about 100 gpm for an operator tolerance band and worst case flow instrument uncertainty (Table 10, Ref. 21)..

3.5 The elevation head, Z, is based on the calculated suppression pooltenms volume-at4O intes and at the pealk pool iomperatur-e from VYG l 628 (Rtun 3, Refi 23), anidthee relationship between volume and level from VYC 1251, Rev. 3 (Ref 241)from Revision

7. This term was not revised for power uprate. The corresponding pool volumes from 8 the power uprate analysis are slightly higher than the values used in the calculation.

Therefore, the use of the current elevations is conservative. The pool volumes fei Ref 2Ado not include the volume of water in the downcomers. Therefore, the appropriate relationship between level and volume in Ref. 24 is from Table 4.3-1 using the volumes from the column labeled "downcomers empty". The constants are the elevation of the suction datum for the Core Spray and RHR pumps.

The elevation head, Z, is the difference between the elevation of the suppression pool surface and the pump suction. Key dimensions from Dwg. 6202-1 (Ref. 13):

Torus Centerline Elevation 230 ft 1.5 in Torus I.D. 27 ft 8 in Therefore, elevation of torus invert = 230' 1.5" - 1/2 (27' 8") = 216' 3.5", or 216.29 ft.

VYC-808, Rev. 8 Pag-e Pare 15 of 58 15 of 58 VYC-808, Rev. 8 Pool Volume Torus Water Torus Water Level Elevation Short-term 76,800 ft3 11.93 ft 228.22 ft Long-term 77,640 ft3 12.03 ft 228.32 ft The corresponding pool volumes under uprate conditions are 79,390 fR3 (short-term, at 600 seconds) and 79,620 f3 (long-term, at the time of the peak pool temperature) (Ref.

10).

Core Spray pump suction center line 215' 9" (215.75 ft) Ref. 25 RHR pump suction center line 215' 11" (215.92 R) Ref. 26 Therefore, Z for Core Spray and RHR, Core Spray RHR - -

Short-term 12.47 ft 12.30 ft Long-term 12.57 ft 12.40 ft

VYC-808, Rev. 8 Page 16 of 58 3.6 The strainer head loss is based on the vendor calculated values for the clean strainer and fittings (Ref. 6).

RHR Core Spray 0.33 ft @ 7400 gpm 0.38 fl @ 4000 gpm 1.22 ft@ 14200 gpm 0.51 ftl@ 4600 gpm At flow rates less than 4000 gpm for Core Spray, the head loss is adjusted by the square of the ratio of the flow rate to the reference value, thus H. = 0.38 (Q/4000) 2 .

3.7 The head loss in the suction piping from the torus to the pumps is based on the calculations in Attachment 6 for Core Spray and Attachment 7 for RHR. These calculations are adjusted here to remove the terms for the old strainer tees and other fittings associated with the strainers inside the torus since the guaranteed head loss term for the new strainers includes those fittings already, therefore the adjusted values will represent only the piping runs and fittings from the new strainer to the pumps.

Friction and form losses in-suction piping, including the old strainer tee entrance, are -

from Attachment 6 for Core Spray. From p.3 of Attachment 6, the IJD for the "strainer entrance tee" was given as 30. The total LJD for all fittings was 132. Deducting the strainer entrance tee leaves a revised total LID of 102. The total equivalent length of 12" (STD) pipe is 102 ft plus 35 ft for the pipe run (from p. 2 of Attachment 6), or 137 ft.

This length is then adjusted to 12" Schedule 40 pipe by multiplying by 0.974 (p. 4, Attachment 6), thus 137 fi x 0.974 = 133 ft. of 12" Schedule 40 equivalent. The head loss for 3000 gpm is, from p. 4, Attachment 6, Hfcs = 133 ft (0.731 psiIlO0 ft) (2.31 ft/psi) = 2.25 ft @ 3000 gpm or, generalizing, HfCs = 2.25 (Q/3000) 2 = 2.5 x I0' Qcs2 For RHR, friction and form losses in suction piping, including the old strainer tee entrance, are from Attachment 7. From p. 3 of Attachment 7, the I/D for the "strainer entrance tee" and "Miter Bend" was given as 119 and 6, respectively, in terms of 24" STD pipe. The total I/D for all fittings was 153. Deducting the strainer entrance tee and miter bend leaves a revised total L/D of 28. Converting to the equivalent length of 24" STD pipe, L 24 - = (28)(23.25"/12"TR) 54.25 ft

VYC-808, Rev. 8 Page 17 of 58 This value is added to the 8.73 ft of piping run from p. 2, Attachment 7, for a total length of 62.98 ft. Attachment 7 next adjusted pipe lengths to an equivalent length of 20" Schedule 40 pipe using an equivalent pressure drop basis; The conversion factor is 0.347 from p. 3 of Attachment 7, thus 1,-SchO = 0.347 (62.98 ft) = 21.85 ft.

This value is next added to the equivalent length of 26" pipe in terms of 20"Schedule 40, which is 39.90 ft (p.5, Attachment 7). Thus, the total equivalent length of 20"Schedule 40 pipe from the torus to the tee connection to the RHR pumps is 21.85 + 39.90 = 61.75 ft, excluding the old strainer tee and miter bend. This value can be carried through the remainder of the calculations in Attachment 7, and arrive at the following expressions for single pump and two pump operation.

For single pump operation, refer to p. 11, Attachment 7, Hf.1 R = 4.77 x I0O- Q2 For two pump operation, refer to p. 12, Attachment 7, Hf.2RFJR = 7.836 x 10 Q2 where Q in both cases refers to RHR pump flow per pump in gpm.

3.8 The RHR flow rate evaluated for ATWS is not specified in GE Task Report T0902 (Ref 11). The analyzed flow rate is conservatively taken as 7400 gpm for one RHR pump.

These are the same flows rates used for the LOCA evaluation. Suctions losses and strainer losses are conservatively larger with -larger flow rates.

VYC-808, Rev. 8 Page 18 of 58 4.0 CALCULATION 4.1 Debris Accumulation 4.1.1 The following ECCS combinations, based on single failure (including none), were considered in determining short-term debris accumulation (the use of the designations "A" and "B" is arbitrary).

Single Failure No. of CS No. of No. of No. of Pumps RIMR RHR Active Pumps, Pumps, Suction Loop A Loop B Sites, N, Diesel Generator 1 1 I 3 CS Pump/Injection 2 2 3 Valve LPCI Injection Valve 2 2 0 3 RHR Pump 2 1 4 None 2 2 2 4 4.1.2 The run out flow rates, per pump, using the values from Paragraph 3.4, Single Failure CSA CSB RIIR .Total RUR Total -

per RHR, per RHR, pump Loop A pump Loop B Loop A Loop B Diesel Generator 4,600 0 7,400 7,400 7,400 7,400 CS Pump/Injection 4,600 0 7,100 14,200 7,100 14,200 Valve LPCI Injection Valve 4,600 4,600 7,100 14,200 0 0 RHR Pump 4,600 4,600 7,100 14,200 7,400 7,400 None 4,600 4,600 7,100 14,200 7,100 14200

VYC-808, Rev. 8 _Page 19 of 58 4.1.3 The total flow rate from the suppression pool to the reactor vessel, and the debris fraction at ten minutes, using the equation from Paragraph 2.4, Single Failure Total Flow Rate, Q D/Diota.= (1 - e -QtIV) t=10 min V=68,000 ft x 7.48 gal/ft 3 Diesel Generator 4,600+7,400+7,400=19,400 0.317 CS Pump/Injection 4,600+14,200+14,200=33,000 0.477 Valve LPCI Injection Valve 9,200+14,200=23,400 0.369 RHR Pump 9,200+14,200+7,400=30,800 0.454 None 9,200+14,200+14,200=37,600 0.522 4.1.4 After 10 minutes, all but one Core Spray pump and one RHR pump are assumed to be secured. In addition, the Core Spray pump is assumed to be throttled to 3500 gpm. The distribution of debris on the one active CS strainer and the one active RHR strainer will be the amount initially deposited in the short-term, plus the amount redistributed from the now-inactive strainer(s), plus the amount not removed in the short-term. The distribution of the remaining amounts will be in proportion to the CS and RHR flow rates. The results are summarized below.

Single Failure CS CS RHR RHR A B A B Total Diesel Generator Short Term Flow Rate 4600 0 7400 7400 19400 Short Term Accumulation 0.075 0.000 0.121 0.121 0.317 Long Term Flow Rate 3500 0 7400 *0 10900 Redistributed 0.000 0.000 0.000 0.121 0.121 Long Term Accumulation 0.333 0.000 0.667 0.000 1.000 CS Pumpllnj. Short Term Flow Rate 4600 0 14200 14200 33000 Valve Short Term Accumulation 0.066 0.000 0.205 0.205 0.477 Long Term Flow Rate 3500 0 7400 0 10900 Redistributed 0.000 0.000 0.000 0.205 0.205 Long Term Accumulation 0.300 0.000 0.700 0.000 1.000 LPCI Inj. Valve Short Term Flow Rate 4600 4600 14200 0 23400 Short Term Accumulation 0.073 0.073 0.224 0.000 0.369 Long Term Flow Rate 3500 0 7400 0 10900 Redistributed 0.000 0.073 0.000 0.000 0.073 Long Term Accumulation 0.298 0.000 0.702 0.000 1.000 RHR Pump Short Term Flow Rate 4600 4600 14200 7400 30800

VYC-808, Rev. 8 Page 20 of 58 Short Term Accumulation 0.068 0.068 0209 0.109 0.454 Long Term Flow Rate 3500 0 7400 0 10900 Redistributed 0.000 0.068 0.000 0.109 0.177 Long Term Accumulation 0.300 0.000 0.700 0.000 1.000 None Short Term Flow Rate 4600 4600 14200 14200 37600 ShortTermAccumulation 0.064 0.064 0.197 0.197 0.522 LongTermFlowRate 3500 0 7400 0 10900 Redistributed 0.000 0.064 0.000 0.197 0.261 Long Term Accumulation 0.301 0.000 0.699 0.000 1.000 The above information was used to determine the distribution of each of the various debris species postulated to be deposited in the suppression pool following a LOCA (Ref. 3). However, the above distributions were not used to determine the head loss due to debris used in this calculation as discussed below. The above distributions were used as input to VYC-1677 (Ref 3), and the resulting debris loads were used to assess the head loss due to debris shown in .

4.2 Head Loss due to Debris The maximum predicted head loss for the CS and RHR strainers are based on the vendor calculations (Ref. 2), using conservative debris loads, fluid temperatures, and flow rates. These were discussed in Section 3.2 as Inputs and Assumptions. The head losses so determined are shown in Attachment 2 to be conservative relative to updated information on debris distribution (Section 4.1), debris loads (Ref. 3), flow rates and fluid temperatures. Attachment 2 has not been adopted as the design basis because additional assessments are ongoing regarding the time interval for torus cleaning, which may affect the final specification of the "sludge" term in the head loss calculation.

4.3 NPSH Margin 4.3.1 LOCA - Short Term The temperature and pressure (T/P) profile for the suppression pool during a LOCA is developed in GE-VYNPS-AEP-346, Rev. 2 (Ref. 10). The short term data is provided from 0-600 seconds.

The evaluation of NPSH is documented in Table 4.1 using the peak pool temperature of 165.1XF which occurs at 600 seconds with a corresponding pool pressure of 17.64 psia. The peak temperature results in the largest vapor pressure and lowest NPSHa. Note that the temperature at lowest pool pressure is 161 .20 F / 17.40 psia. At this temperature the gain in vapor pressure more than offsets the reduction in pool pressure, therefore the 165.10 F case governs. The details of the evaluation are presented at the top of the Table followed by a matrix of the NPSH results for CS and RHR. Further discussion of selected terms is presented below.

VYC-808, Rev. 8 ]Page 21 Page 21 of of 58 58 VYC-808, Rev. 8 Suction Elevation Head, Z The values of Z for RHR and CS (12.30' and 12.47'respectively) as calculated in Section 3.5 are conservatively used in this evaluation. The suction elevation head is based on the water elevation in the torus. The EPU suppression pool water volume is slightly larger than the value used in Section 3.5, which would result in a slight increase in water elevation, and therefore Z is conservative.

A water volume comparison at 600 seconds is provided below:

Pre-EPU EPU Ref. (Section 3.5) (Ref. 10)

Short Term 76,800 cuft 79,390 cuft Maximum Debris Losses (hd) 1 RHR: The head loss is taken as 0.33 ft at 173 0 F is used. (Case 1 of Tables 2 and 8 of Ref. 2).

2 RHR: The head loss is taken as 0.48 ft at 170'F (Case 2b of Tables 2 and 8 of Ref. 2) and 14200 gpm.

CS The head loss is conservatively taken as 0.32 ft at 1730 F (Case 3d of Tables 2 and 8 of Ref. 2) and 4600 gpm.

Refer to Section 3.2 for application of head loss at temperatures other than those used in its calculation.

NPSHr- CS Figure 2.2-1 of Attachment 3 provides a plot of Allowable OperatingPeriods@ NPSHa Specified values for various flow rates. This plot shows that at 4600 gpm an allowable NPSH of 28.0 ft is acceptable between 0 and 7 hrs of operation.

NPSHr- I RHR

WYC-808, Rev. 8 Page 22 of 58 VYC-808, Rev. 8 Page 22 of 58 Figure 2.1-1 of Attachment 3 provides a plot of Allowable OperatingPeriods@,NPSHa Specified values for various flow rates. This plot shows that at 7400 gpm an allowable NPSH of 23.8 ft is acceptable between 0 and 7 hrs of operation.

NPSHr- 2RHR With two RHR pumps operating at a total flow of 14,200 gpm this yields a flow of 7100 gpm per pump.

Also per Figure 2.1-1 of Attachment 3, the plot shows that at between 0 and 7 hrs of operation, an allowable NPSH of 23.5 ft is acceptable at 7000 gpm and 24.0 ft is acceptable at 7600 gpm.

Interpolating between plotted NPSH values of 23.5 ft @ 7000 gpm and 24.0 ft @ 7600 gpm yields 23.6 ft @ 7100 gpm.

The interpolation equation is developed as documented Section 2.2.2 and is 23.0+(Q-6400)/1200 8

Evaluation As can been seen from Table 4.1, there is adequate NPSHa and overpressure is not required.

4.3.2 LOCA - Long Term The temperature and pressure (T/P) profile for the suppression pool during a LOCA is developed in GE-VYNPS-AEP-346, Rev. 2 (Ref. 10). The long term data is provided from 0-864,000 seconds.

The evaluation of NPSH is documented in Table 4.2 using a selected T/P points representing the long term profile of the suppression pool. The details of the evaluation are presented at the top of the Table followed by a matrix of the NPSH results for the T/P profile of CS and RHR. The evaluated long term flow rates of 7400 gpm (RHR) and 3500 gpm (CS) are per Section 3.4.2.

Further discussion of selected terms is presented below.

-- ~~~ ---

VYC-808, Rev. 8 Page 23 of 58 Suction Elevation Head. Z The values of Z for RHR and CS (12.40' and 12.57' respectively) as calculated in Section 3 are conservatively used in the evaluation. The suction elevation head is based on the water elevation in the torus. The EPU suppression pool water volume is slightly larger than the value used in Section 3.5, which would result in a slight increase in water elevation, and therefore Z is conservative.

A water volume comparison at maximum pool temperature is provided below:

Pre-EPU EPU Ref. (Section 3.5) (Ref. 10)

Long term 77,640 cu ft 79,620 cu ft Maximum Debris Losses (hd) 1 RHR: Refer to Section 4.1. 8 CS 0.21 ft at 173WF is used. This is based on a conservative CS flow rate of 4000 gpm.

(Case 3b of Tables 2 and 8 of Ref. 2). - -

NPSHr- CS Figure 2.2-1 of Attachment 3 provides a plot ofAllowable OperatingPeriods @ NPSHa Specified values for various flow rates. This plot shows that at 3500 gpm the allowable NPSH increases between 7 and 20 hrs of operation and a value of 29.6 ft is acceptable beyond 20 hrs of operation. This maximum value is conservatively used for the entire long term period (>600 sec).

NPSHr- RHR Figure 2.1-1 of Attachment 3 provides a plot of Allowable OperatingPeriods@ NPSHa Specifjed values for various flow rates. This plot shows that at 7400 gpm the allowable NPSH increases between 7 and 100 hrs of operation and a value of 31.7 ft is acceptable beyond 100 hrs of operation. This maximum value is conservatively used for the entire long term period (>600 sec).

VwYC-808, Rev. 8 Page 24 of 58 VYC-808, Rev. 8 Page 24 of58 Evaluation As can been seen from Figure 4.2 the overpressure required for RHR envelopes that required for CS and the overpressure varies continuously over time. In order to facilitate reporting and presentation of the overpressure required, an enveloping, stepped, overpressure credit is overlaid on Figure 4.2. The basis for overpressure credit is discussed in Section 3.3.

Though the long term flow rates are postulated at time 600 seconds (e.g. CS throttled down from 4600gpm to 3500gpm), it is not the intent of this calculation to imply at what time throttling should commence or how much throttling is required. This is a function of the time dependent NPSHr and pool temperature. This calculation conservatively evaluates the maximum NPSHr as occurring over the entire operating period (>600 sec). The actual NPSHr is lower between 0-7 hrs and increases after 7 hrs.

Note that Section 4.3.4 develops required overpressure for both the CS and RHR pumps as a function of flow, temperature and NPSHr without any debris loading. Refer to Table 4.4 and Figures 4.4-1 to 4.4-4. 8 4.3.3 ATWS Note that NPSH evaluation of the ATWS event was not previously addressed by calculation VYC-080S. The temperature and pressure (T/P) profile for the suppression pool during the ATWS events is developed in GE-Task Report T0902 (Ref. I 1). A sensitivity study on the effects of condensate storage tank water temperature (Attachment 9) has been done and the effects of an increase in CST temperature on NPSH are addressed in this section.

The evaluated events are MSIVC and PRFO with the peak temperatures and corresponding pressures tabulated by GE in Section 3.3.1.2 of the Task Report. Selected data points are extracted from the included T/P profile plots, Figures 3-10 and 3-12 of the Task Report, and are shown below. The two events have essentially the same temperature pressure profile. For convenience, these are combined into one enveloping event with maximum temperatures and minimum pressure at each time step.

VYC-808, Rev. 8 Page 25 25 of of 58 58 VYc-808, Rev. 8 Page MSIVC PRFO Combined Time, Temp, Press, Time, Temp, Press, Time, Temp, Press, sec OF psig sec OF psig sec OF psig 0 90 0 0 90 0 0 90 0 300 160 6.3 300 157 6.3 300 160 6.3 600 175 8.8 600 168 8.2 600 175 8.2 1000 182 11.2 1000 180 10.7 1000 182 10.7 1300 187 11.5 1300 187 11.8 1300 187 11.5 1724 189 12.3 1838 190 12.5 1838 190 12.3 3000 186 11.9 3000 187 12.1 3000 187 11.9 5000 182 11.2 5000 182 11.3 5000 182 11.2 6000 180 10.8 6000 180 11.0 6000 180 10.8 8000 175 10.0 8000 175 10.2 8000 175 10.0 As documented in T0902, Section 3.2.11 and 3.2.2.2, the suppression pool cooling is based on two loops of RHR operating and an initial pool volume of 68,000 cuft. Note that CS does not 8 operate for ATWS events.

The evaluation of RHR pump NPSH is documented in Table 4.3 for the minimum NPSHr (0-7 hrs) The details of the evaluation are presented at the top of the Table followed by a matrix of the NPSH results for RHR. Further discussion of selected terms is presented below.

Since there are no data points available beyond 8000 seconds, margins at intermediate NPSHr (7hrs - 20hrs) and maximum NPSHr (20hrs - lOOhrs) were not evaluated. However, since both RHR loops are available and assumed to be in operation, suppression pool temperatures will continue to drop beyond 8000 seconds and available NPSH will correspondingly increase as suppression pool temperature decreases.

Flow rate- 0 (gym)

The RHR flow rate is assumed to be at the maximum value assumed in the LOCA analysis, i.e.

7400 gpm. Refer to Section 3.8.

VYC-808, Rev. 8 Page 26 of 58 Suction Elevation Head, Z The suppression pool volume addressed in the GE report is 68,000 ftA3. As noted in Section 3.5 the relationship between suppression pool volume and level is documented in Table 4.3-1 of Calc VYC-1254 Rev 3 ( Ref. 24). The suppression pool level corresponding to 68,000 ftA3 is 10.88'from VYC-1254.

This water level is 1.05' less than (1I .93'-1 0.88') that used for calculating the RHR short term Z (12.30') in Section 3.5. Therefore the adjusted Z for the ATWS evaluation is 12.3'-1.05' 11.25'.

Maximum Debris Losses (hd)

This term is not directly applicable for ATWS since there is no high-energy line break (HELB) to dislodge insulation and create debris in the suppression pool. However, there is sufficient margin to accommodate the design basis debris head loss of 0.33 ft for RHR and the evaluation is done accordingly.

Minimum NPSHr - I RHR (<7hrs)

Refer to Section 4.3.1.

Evaluation Minimum NPSHr (<7 hrs)

As can been seen from Table 4.3, overpressure is required from about 1000 to 3000 seconds. An overpressure of 1.27 psig is required to accommodate the peak pool temperature of 190'F at 1838 seconds. A plot of the overpressure required is shown in Figure 4.3-1. Note that for the same time period, this overpressure required is bounded by that required for LOCA.

The sensitivity study for the effect of increased CST temperature estimated a maximum increase of 0.5 'F on peak pool temperature and no more than 0.2 psi in pressure (Attachment 9). Table 4.3 shows that these changes will result in an increase in the overpressure required from 1.27 psig to 1.37 psig. This is well within the overpressure available of 12.3 to 12.5 psig, and below the 2.4 psig overpressure credit requested for LOCA at the time of the peak temperature.

Note that long-term LOCA suppression pool temperatures are higher than ATWS (Figure 4.3-2).

Suppression pool temperature drops relatively soon after the peak occurs at 1838 seconds. RHR pump available NPSH will continue to increase as pool temperature drops and is clearly bounded by LOCA, therefore there is no need to do a long-term NPSH evaluation for ATWS.

VYC-808, Rev. 8 Page 27 of 58 VYC-808, Rev. 8 Page 27 of 58 4.3.4 General Profile - Overpressure Required vs Pool Temperature A wide temperature range is evaluated, up to 2051F, which is about 10F more than the peak LOCA temperature addressed by GE-VYNPS-AEP-346, Rev. 2 (Ref. 10).

The NPSH evaluation of general overpressure requirements for the RHR and CS pumps is documented in Table 4.4 for the minimum NPSHr (0-7 hours of operation) and maximum NPSHr (>7 hours of operation). The details of the evaluation are presented at the top of the Table followed by a matrix of the NPSH results. Further discussion of selected terms is presented below.

Flow rates - 0 (gpm) - RHR 1 RHR: 7400 and 7000*gpm 2 RHR: 14,200 gpm (7100 gpm each) and 12,800 gpm (6400* gpm each)

• these values are conveniently selected, based upon the pump vendor's data, for the purpose of establishing a profile range.

8 Flow rates - 0 (g&m) - CS CS: 4600 gpm and 3500 gpm Suction Elevation Head. Z Based on a minimum suppression pool volume of 68,000 ftA3.

RHR: 11.25' as calculated in Section 4.3.3.

CS: 11.42' based on the evaluation documented in Section 4.3.3 and adjusting for the CS short term Z (12.47'). Therefore the adjusted Z is 12.47'-1.05' = 11.42'.

Clean Strainer Losses (hs)

Refer to Section 3.6 1 RHR @ 7400 gpm= 0.33' 1 RHR @ 7000 gpm = 0.30' = 0.33*(Q/7400)A2**

2 RHR @ 14,200 gpm (7100 each) = 1.22' 2 RHR @ 12,800 gpm (6400 each) = 0.99' = 1.22*(Q/14200)A2**

VYC-808, Rev. 8 Page 28 of 58 VYC-808, Rev. 8 Page 28 of 58

• • head loss at other than the reference flow rate is proportional to the square of the flow ratio CS @ 4600 gpm = 0.51' CS ( 3500 gpm = 0.29 = 0.38*(Q/4000)A2 Maximum Debris Losses (hd)

This term is not applicable since no high-energy line break (HELB) is postulated to dislodge insulation and create debris in the suppression pool.

Minimum NPSHr 1 RHR @ 7400 gpm = 23.8' Refer to Section 4.3.1 1 RHR @ 7000 gpm = 23.5' Refer to Section 4.3.1 2 RHR @ 7100 gpm (each) = 23.6' Refer to Section 4.3.1 2 RHR @ 6400 gpm (each) = 23.0' (see below)

Figure 2.1 -1 of Attachment 3 provides a plot of Allowable OperatingPeriods@ NPSHa Specified values for various flow rates. This plot shows that at 6400 gpm an allowable NPSH of 23.0 ft is acceptable for less than 7 hrs of operation.

CS @ 4600 gpm = 28.0' Refer to Section 4.3.1 CS @ 3500 gpm = 24.8' (see below)

Figure 2.2-1 of Attachment 3 to provides a plot of Allowable OperatingPeriods( NPSHa Specified values for various flow rates. This plot shows that at 3500 gpm an allowable NPSH of 24.8 ft is acceptable for less than 7 hrs of operation.

VYC-808, Rev. 8 Page 29 of 58 VYC-808, Rev. 8 Page 29 of 58 Maximum NPSHr I RHR @ 7400 gpm = 31.7' Refer to Section 4.3.2 I RHR @ 7000 gpm = 29.5' Refer to Section 4.3.3 2 RHR @ 7100 gpm (each) = 30.0' Refer to Section 4.3.3 2 RHR @ 6400 gpm (each) = 28.5' (see below)

Figure 2.1-1 of Attachment 3 provides a plot of Allowable OperatingPeriods@ NPSHa Specified values for various flow rates. This plot shows that at 6400 gpm an allowable NPSH of 28.5 ft is acceptable at greaterthan 100 hrs of operation.

CS @ 4600 gpm = 35.0' (see below)

CS @ 3500 gpm = 29.6' Refer to Section 4.3.2 Figure 2.2-1 of Attachment 3 provides a plot of Allowable OperatingPeriods@ NPSHa Specified values for various flow rates. This plot shows that at 4600 gpm an allowable NPSH of 35.0 ftis acceptable at greater than 100 hrs of operation.

VYC-808, Rev. 8 Page 30 of 58 The Table 1 summarizes the calculated available NPSH at the flow rates and temperatures of interest for a clean strainer. The calculations were done for the design basis flow rates and maximum short term and long term temperatures. Other temperature points were calculated to show the sensitivity of the results. The available NPSH is compared to the required NPSH, and if the margin is greater than the maximum head loss due to debris, then it can be concluded that post accident perfone i cceptable at the design basis points.

Table 4.52 provides similar results for the minimum flow mode. Since Technical Specifications I a require reactor depressurization when suppression pool temperature reaches 120 F, it is unlikely that a CS or RHR pump would be operating in a minimum flow mode for very long at that temperature. Table 2 shows adequate NPSH margin for pool temperatures > 164 F. provides an assessment of the time dependent NFSH margin for the maximum post accident pool temperature transient. The purpose of this calculation was to show the marfgffl available after the peak temperature is reached in light of the vendor recommended increase in minimum available NPSH afier 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />. The minimum available NPSH is shown to be above the vender-r-eeommended minimum at all times duing the most limiting transient. is an evaluation on the NPSH margin for the RHR pumps operating in the Shutdown Cooling mode. This evaluation is not directly related to the topic of post-LOCA ECCS performance, but the methods used are based on the methods in this calculation.

VYC-808, Rev. 8 Page 31 of 58 5.0

SUMMARY

& CONCLUSIONS

SUMMARY

NPSHa is rounded to the nearest 0.Ift and OPR, OPC, and OPA are rounded to the nearest 0.1psig.

LOCA - Short Term (0-600 sec):

NPSHa is adequate for both CS and RHR pumps without crediting overpressure. NPSHa shown below is at the peak temperature.

Pump Total flow, gpm NPSHr, ft NPSHa, R g

CS 4,600 28.0 28.4 1RHR 7,400 23.8 31.1 2 RHR 14,200 23.6 28.8 LOCA - Long Term (>600 sec):

NPSHa is adequate for both CS and RHR pumps with an overpressure credit that varies over time, as shown in Fig. 4.2. NPSHa, OPR, OPC, OPA are shown below, at the peak temperature Pump Total flow, gpm NPSHr, ft NPSHa, ft OPR, psig OPC, psig OPA, psig CS . 13,500 29.6 19.5 4.2 6.1 7.8 1RHR 7,400 31.7 19.6 5.1 6.1 7.8

VYC-808, Rev. 8 Page 32 of 58 VYC-808, Rev. 8 Page 32 of 58 ATWS: I8 NPSHa is adequate for RHR with an overpressure required of 1.3 psig or less between 1000 and 5000 seconds, as shown in Fig. 4.3-1. The overpressure required is bounded by the overpressure credit requested for LOCA.

8 Pump Total flow, gpm NPSHr, ft NPSHa, ft I OPR, psig l OPC, psig IOPA, psig 1RHR 7,400 23.8 20.8 1.3 2.4 12.3 The estimated effect of an increase in CST temperature is to increase the OPR by 0.1 psig.

I General Profile - Overpressure Required vs. Pool Temperature General profiles of "Overpressure Required vs. Pool Temperature", for the scenarios listed below are provided in Figures 4.4-1 through 4.4-4. The profiles are intended to serve as the basis for determining overpressure requirements when performing RHR and CS pump NPSH evaluation for any other events, which cause elevated suppression pool temperatures, without strainer debris loading. A representative flow range is presented based on available vendor data for NPSH.

Profiles Figure Pumps operating Flow range, gpm NPSHr 4.4-1 1 RHR 7000-7400 Minimum (0-7 hrs of operation) 4.4-1 1 RHR 7000-7400 Maximum (>7 hrs of operation) 4.4-2 2 RHR 12,800-14,200 Minimum (0-7 hrs of operation) 8 4.4-2 2 RHR 12,800-14,200 Maximum (>7 hrs of operation) 4.4-3 1 CS 3500-4600 Minimum (0-7 hrs of operation) 4.4-4 1 CS 3500-4600 Maximum (>7 hrs of operation)

VYC-808, Rev. 8 Page 33 of 58 VYC-808, Rev. 8 Page 33 of 58 Conclusions There is adequate NPSH available for operating the RHR and CS pumps at EPU conditions for the DBA-Loss of Coolant Accident (LOCA), short term, without crediting torus overpressure.

Torus overpressure must be credited for operating the RHR and CS pumps at EPU conditions for the following events in order to achieve adequate NPSH available:

• DBA-Loss of Coolant Accident (LOCA), long term (200,000 seconds)

• Anticipated Transients Without Scram (ATWS) 8 The overpressure credit required for LOCA bounds that required for ATWS.

A basis for readily determining overpressure requirements, when performing RHR and CS pump NPSH evaluation for any other events which cause elevated suppression pool temperatures has provided in the form of a family of curves profiling overpressure required vs. pool temperature.

Note that use of overpressure credit must be approved by the NRC as part of EPU.

No specific 50.59 Screening/Evaluation is required since power uprate will require NRC approval.

Available dPSH exceeds required NPSH for the limiting conditions evaluated, short tedm and long tenm. This includes margin to aecommodate the maximum head less-across the Core-Spray and RHR suction strainers due to the predicted aceumulatien of fibrous and other debris following a LOCA.

There is no need to do a Safety Evaluation sinee the results continue to show adequate NPSH margins for the Core Spray and RHR pumps.

The completion of this calculation also satisfies the commitment made in Ref. 16 to revise the NPSH calculation using a corrected curve fit for required NPSH for the RHR pump.

Impact on Other Design Output Documents The results of this calculation will provide input to the power uprate license amendment request.

The need for crediting torus overpressure in the RHR and CS NPSH evaluation, shall also be addressed in the SADBD, UFSAR, and system DBDs for Containment (CPS), RHR, and CS.

Design Basis Documents: The Core Spray, RHR, and CPS DBDs refr-to VYC 808. This revision has no impact on any DBD.

VYC-0019, Rev. 1: Refers to VYC-808 for the Core Spray suction strainer head loss of 0.42 ft at 4000 gpm. Revision 6 to VYC-808 reduced that value to 0.38 ft. but the impact on VYC-0019, Rev. 1, was minimal and no change was required. This revision to VYC-808 does not change that conclusion.

VYC-808, Rev. 8 Page 34 of 58 VYC-808, Rev. 8 Page 34 of 58 VYC-1628, Rev. 0: Refers to VYC-808 in regards to the fact that Vermont Yankee does not credit any wetwell pressure above atmospheric in the calculation of available NPSH. This revision to VYC-808 does not change that fact.

VYC-1670, Rev. 0: Refers to VYC-808 in support of use of 5 ft as a conservative value for RHR suction strainer head loss. This revision to VYC-808 does not change that conclusion.

VYC-1677, Rev. 0: Refers to VYC-808 for the debris distribution based on the short-term and long-term flow splits documented in Section 4.1.4. This revision does not change the flow splits.

VYC-1 803, Rev. 1: Refers to VYC-808 as the basis for the calculation of available NPSH for RHR pumps at elevated suppression pool temperatures. This revision of VYC-808 does not change that statement.

VYPC 96-015, Rev. 2: Refers to VYC-808 as the basis for concluding that there is no need to throttle an RHR pump while operating in the torus cooling mode. This revision to VYC-808 does not change that conclusion.

Design basis documents will be updated upon NRC approval of the power uprate and as part of the power uprate implementation via VYDC 2003-008.

VYC-808, Rev. 8 Page 35 of 58

6.0 REFERENCES

I. American National Standard for Centrifugal Pumps, ANSI/HI 1.1-1.5-1994.

2. VYC-1 924, Rev. 0, "DE&S Calc. DC-A34600.006, 'Vermont Yankee ECCS Suction Strainer Head Loss Performance Assessment, RHR and CS Debris Head Loss Calculations."'

3. VYC-1677, 'Debris Source Terms For Sizing of Replacement Residual Heat Removal and Core Spray Strainers."

4. Letter, USNRC to VYNPC, Vermont Yankee Design Inspection (NRC Inspection Report 50/271/97-201), NVY 97-130, dated August 27, 1997.

5. not usedVYC 1628F, "Limiting Torus Temperature Response, Million Scond Run."

6. VYC-1919, Rev. 0, "DE&S Calc. DC-A34600-01, "RHR and CS Suction Strainer Assembly Clean Head Loss."

7. Memo, R.E.Swenson/P.A.Rainey to M.Mills, "Evaluation of Maximum Expected Flows for ECCS Strainer Replacement," VYS 98/97, dated August 28, 1997.

8. OP-2124, Rev. 52, "Residual Heat Removal System".

9. not usedVYC 1921, Rev. 0, CCN02, "DE&S Calc. DC A31600.006, U'cremont Yankee EGGS Suction Strainer Head Loss Performance Assessment, RHR and S CS Debris IHead Loes Cslculations."'

10. not usedLetter, GE-VYNPS-AEP-346, Rev. 2, dated August 7,2004. l 8

11. notusedGE Final Task Report, Task T0902, GE-NE-0000-0016-3831-01, Rev. 0, l dated July 2003.

12. not-rse4ERC No. 2003-027

13. Drawing 6202-1, Rev. 1, "General Plan--Pressure Suppression Containment Vessel."

14. not used

15. not used

VYC-808, Rev. 8 Page 36 of 58

16. Letter, VYNPC to USNRC, "Reply to Inspection Report No. 50-271/97-201,"

(Appendix B, II 97-201-04), BVY 97-138, dated 10/27/97.

17. not used

18. not used

19. not used DE&S Memo, C. D. Fago to J. R. Hoffian, "Torus Temperaturo Margin Assessment for Confirmatory Analyses," THSAG VY 98 064, dated April 27, 1.998

20. Memo, B. C. Slifer to K. H. Bronson, "NPSH Limits for Emergency Operating Procedures," VYS 98/58, dated May 13, 1998.

21. VYC-717B, Rev. 0, "Core Spray Pump Discharge Flow, Supplemental Addition to Revision 1."

22. not used Letter, USNRC to 3XYNPC, "Summary of Meeting on March 21, 1998, regarding Activities at Vermont Yankee Nuclear Power Station (TAC No.

MA0987)," TWY 98 13, dated March 31, 1998.

23. not used VYC 1628, Rev. 0, "Torus Tcmperature and Pressure Response to Large l Break LOCA and MISLB Accident Scenarios."

24. VYC-1254, Rev. 3, "Containment RPV Volume Calculations."

25. Drawing G-191207, Rev. 10

26. Drawing G-191211, Rev. 17

Table 4.1 YC-0808 Rev 8 LOCA- Short term (1.5 wt. % Containment Leakage 100% Spray Efficiency)

P7 37a15?

LOCA - Short Term NPSHa = (14.7-PgXl44VQ+Z-hf-hs-hd OPR = (NPSHr- NPSHaY(144Vf)

OPA = Over pressure avallable OPC = Over pressure credited Short Tern Flow Rate (orm)

I RHR 0= 7400 CS Q = 4600 2 RHR Q - 14200 Suction Line Losses (M) 1 RHR hf 4.77E-8'QA. CS hf = 2.5E-7'Q2 2 RHR hf = 7.84E-.8'(2)A2 Clean Stralner Losses MI)

I RHR hs = 0.33 ' CS hs- 0.51 2 RHR hs - 1.22 Maximum Debris Losses (I) n >=base temoerature 1 RHR hd = 0.33@173F CS hd = 0.32c173F 2 RHR hd = 0.48@170F Maximum Debris Losses (Rt)(M< base temoerature 1 RHR hd = .33*(173/T) CS hd = .32*(1731T) 2 RHR hd = .48'(1701T) where T = suppression pool temperature, F Elevation Head (fR)

RHR Z= 12.3 CS Z = 12.47 NPSHr (fR) 1 RHR NPSHr= 23.8 CS NPSHr - 28.0 2 RHR NPSHr = 23.6 Short Term (After EPU) - Peak Torus Teme ture - 1.5 wt. % Containment Leak ge & 10 % Spray Efficien _

GE Pool I GE Pool Pump(s) Time Temp Pressure Pg Vf Z hf hs hd NPSHa NPSHr OPR OPA OPC (F) (psla)

I(sec) (ftA3Ilb) (lt) (R4) U.4 4) in4ff j (Rt) (psig) j psg (psig)

CS 600 165.1 [ 17.64 5.349 0.016423 12A7 5.29 0.51 0.34 28.44 28.00 0.00 2.94 0.00 I RHR 600 165.1 17.64 5.349' 0.016423 12.30 2.61 0.33 0.35 31.12 23.80 0.00 2.94 0.00 2 RHR l 600 165.1 17.64 , 5.349 0.016423 12.30 3.95 1.22 0.49 l 28.75 j 23.60 0.00 j 2.94 1 0.00

Table 4.2 WC-0808 Rev 8 LOCA - Long term (1.5 wt. % Containment Leakage 100% Spray Efficiency) f6t SP 6 /578 LOCA - Long Term NPSHa = (14.7-Pg)(144Vf)+Z-hf-hs-hd OPR = Over pressure required (NPSHr - NPSHa)I(1 44Vf)

OPA a Over pressure available OPC = Over pressure credited Lona Term Flow Rate (gym) 1 RHR Q= 7400 Cs Q0= 3500 Suction Une Losses (ft) 1 RHR hf= 4.77E8*QA2 Cs hf = 2.5E-7-Q^2 Clean Strainer Losses (t) 1 RHR hs = 0.33 CS hs = .38'(Q14000)A2 for Q<= 4000 Maximum Debris Losses (R) IZ >= 1731 1 RHR hd = 0.33 Cs hd = 0.21 Maximum Debris Losses tl ( < 173F 1 RHR hd = .33'(173JT) CS hd = .21*(1731T) where T = suppression pool temperatui e, F Elevation Head MR RHR Z= 12.4 CS Z= 12.57 NPSHr (t) 1 RHR NPSHr 31.7 CS NPSHr = 29.6

Table 4.2 VYC-0 808 Rev 8 LOCA - Long term (1.5 wt. % Containment Leakage 100% Spray Efficiency)

CS - Long Term Afer EPU) 1.5 wt. % Containment Lakage & 100% Spray Efficiency 1

Time (sc I IGE Poolj GE Pool Temp F)

Pressure psla Pg j1 (ftAIb

_______)

..k hf (ft J ft jCS hs jhd (f ) (

CS jjCS NPSHa NPSHr OPR (ft) (psig)

OPA (psig)

OPC (PSIg) 786 169.7 17.71 5.951 0.016449 12.57 3.06 0.29 0.21 29.73 29.60 0.00 3.01 2.40 1.096 171.8 17.94 6.245 0.016461 12.57 3.06 0.29 0.21 29.05 29.60 0.23 3.24 2.40 2.033 176.6 18.57 8.962 0.0164891 12.57 3.06 0.29 0.21 27.38 29.60 0.94 3.87- 3.40 2.962 180.0 19.17 7.511 0.016509 12.57 3.06 0.29 0.21 26.10 29.60 1.47 4.47 3.40 4,196 183.4 19.90 8.096 0.016530 12.57 3.06 0.29 0.21 24.73 29.80 2.05 5.20 4.40 5.125 1185.2 20.34 8.420 0.016541 12.57 3.06 0.29 0.21 23.96 29.60 2.37 5.64 4.40 6.275 1187.0 20.82 8.756 0.016552 12.57 3.06 0.29 0.21 23.17 29.60 2.70 6.12 5.10 8,036 189.1 21.50 9.161 0.016566 12.57 3.06 0.29 0.21 22.22 29.60 3.09 6.80 5.10 10,220 191.0 21.86 9.541 0.016578 12.57 3.06 0.29 0.21 21.32 29.60 3.47 7.16 6.10 12.094 192.2 22.06 9.788 0.016585 12.57 3.06 0.29 0.21 20.74 29.60 3.71 7.36 6.10 15,170 193.6 22.31 10.083 0.016594 12.57 3.08 0.29 0.21 20.04 29.60 4.00 7.61 6.10 17.669 194.3 22.43 10.233 0.016599 12.57 3.06 0.29 0.21 19.68 29.60 4.15 7.73 6.10 20,156 1194.6 22.46 10.298 0.016601 12.57 3.06 0.29 0.21 19.53 29.60 4.21 7.76 6.10 23,812 194.7 22.48 10.320 0.016601 12.57 3.06 0.29 0.21 19.48 29.60 -4.23 7.78 6.10 24.495 194.7 22.48 10.320 0.016601 12.57 3.06 0.29 0.21 19.48 29.60 4.23 7.78 6.10 25.120 194.7 22.47 10.320 0.016601 12.57 3.06 0.29 0.21 19.48 29.60 4.23 7.77 6.10 30,095 194.3 22.42 10.233 0.016599 12.57 3.06 0.29 0.21 19.68 29.60 4.15 7.72 6.10 35,065 193.7 22.33 10.104 0.016595 12.57 3.06 0.29 0.21 19.99 29.60 4.02 7.63 6.10 40,020 192.8 22.20 9.914 10.016589 12.57 3.06 0.29 0.21 20.44 29.60 3.83 7.50 5.60 45.637 191.5 22.01 9.644 0.016581 12.57 3.06 0.29 0.21 21.08 29.60 3.57 7.31 5.60 49,406 190.4 21.78 9.420 0.016574 12.57 3.06 0.29 0.21 21.61 29.60 3.35 7.08 5.60 60.551 187.2 21.21 8.794 0.016554 12.57 3.06 0.29 0.21 23.09 29.60 2.73 6.51 4.60 70,342 184.4 20.72 8.275 0.0165361 12.57 3.06 0.29 0.21 24.31 129.60 2.22 6.02 4.10 80.342 181.8 20.28 7.816 0.016520 12.57 3.06 10.29 0.21 25.38 29.60 1.77 5.58 3.60 90.340 1179.3 19.89 7.395 0.016505 12.57 3.06 0.29 0.21 26.37 29.60 1.36 5.19 3.10 100,340 176.8 19.52 6.994 0.016490 12.57 3.06 0.29 0.21 27.30 29.60 0.97 14.82 3.10 110.340 174.8 19.20 6.686 0.016478 12.57 3.06 0.29 0.21 28.02 29.60 0.66 4.50- 2.60 120,306 173.2 18.93 6.447 0.016469 12.57 3.06 0.29 0.21 28.58 29.60 0.43 4.23 2.60 130,302 171.8 18.69 6.245 0.016461 12.57 3.06 0.29 0.21 29.05 129.60 0.23 3.99 2.10 140.302 170.4 18.47 6.048 0.016453 12.57 3.06 0.29 0.21 29.51 129.60 0.04 3.77 2.10 150,302 169.1 18.27 5.870 0.016445 12.57 3.06 0.29 0.21 29.92 29.60 0.00 3.57 1.70 160.302 167.8 18.07 5.696 0.016438 12.57 3.06 0.29 0.22 30.31 29.60 0.00 3.37 1.70 170.302 166.6 17.90 5.539 0.016431 12.57 3.06 0.29 0.22 30.67 29.60 0.00 13.20 1.30 180,302 165.3 17.72 5.374 0.016424 12.57 3.06 0.29 0.22 31.05 29.60 0.00 13.02 1.30 190,302 164.1 17.54 5.225 0.016417 12.57 3.06 0.29 0.22 31.40 29.60 0.00 2.84 1.30 194.052 163.6 17.47 5.164 0.016414 12.57 3.06 0.29 0.22 31.54 .29.60 .0.00 2.77 1.30 196,552 163.3 17.43 5.127 0.016413 12.57 3.06 0.29 0.22 31.62 29.60 0.00 2.73 1.30 197,802 163.2 17.41 5.115 0.016412 12.57 3.06 0.29 0.22 31.65 29.60 0.00 2.71 1.30 200,302 162.9 17.37 5.079 10.016411 F 12.57 3.06 ,0.29 0.22 31.73 29.60 ,0.00 2.67 00

... .t.. . . .

Table 4.2 VYC-0808 Rev 8 LOCA - Long term (1.5 wt. % Containment Leakage 100% Spray Efficiency)

VAgIO #gs5?

RHR - Long Term (After EPU) 1.5 wt. %Containment Leakage & 100% Spray Effclency GE Pool GE Pool I RHR RHR RHR Time Temp Pressure Pg Vf Z hf hs hd NPSHa NPSHr OPR OPA OPC (sec (F) psla (psta) (ftAl3/b) l Ufl) (fj) _ J() (fl) (fl (psig) (psig) 786 169.7 17.71 5.951 0.016449 12.40 2.61 0.33 0.34 29.84 31.70 0.78 3.01 2.40 1,098 171.8 17.94 6.245 0.016461 12.40 2.61 0.33 0.33 29.17 31.70 1.07 3.24 2.40 2,033 176.6 18.57 6.962 0.016489 12.40 2.61 0.33 0.33 27.50 31.70 1.77 3.87 3.40 2,962 180.0 19.17 7.511 0.016509 12.40 2.61 0.33 0.33 26.22 31.70 2.31 4.47 3.40 4.196 183.4 19.90 8.096 0.016530 12.40 2.61 0.33 0.33 24.85 31.70 2.88 5.20 4.40 5,125 185.2 20.34 8.420 0.016541 12.40 2.61 0.33 0.33 24.09 31.70 3.20 5.64 4.40 6,275 187.0 20.82 8.756 0.016552 12.40 2.61 0.33 0.33 23.30 31.70 3.53 6.12 5.10 8,036 189.1 21.50 9.161 0.016566 12.40 2.61 0.33 0.33 22.34 31.70 3.92 6.80 5.10 10,220 191.0 21.86 9.541 0.016578 12.40 2.61 0.33 0.33 21.44 31.70 4.30 7.16 6.10 12,094 192.2 22.06 9.788 0.016585 12.40 2.61 0.33 0.33 20.86 31.70 4.54 7.36 6.10 15,170 193.6 22.31 10.083 0.016594 12.40 2.61 0.33 0.33 20.16 31.70 4.83 7.61 6.10 17,669 194.3 22.43 10.233 0.016599 12.40 2.61 0.33 0.33 19.81 31.70 4.98 7.73 6.10 20,156 194.6 22.46 10.298 0.016601 12.40 2.61 0.33 0.33 19.65 31.70 5.04 7.76 1 6.10 23,812 194.7 22.48 10.320 0.016601 12.40 2.61 0.33 0.33 19.60 31.70 5.06 7.78 6.10 24,495 194.7 22.48 10.320 0.016601 12.40 2.61 0.33 0.33 19.60 31.70 5.06 7.78 6.10 25,120 194.7 22.47 10.320 0.016601 12.40 2.61 0.33 0.33 19.60 31.70 5.06 7.77 6.10 30,095 194.3 22.42 10.233 0.016599 12.40 2.61 0.33 0.33 19.81 31.70 4.98 7.72 6.10 35,065 193.7 22.33 10.104 0.016595 12.40 2.61 0.33 0.33 20.11 31.70 4.85 7.63 6.10 40,020 192.8 22.20 9.914 0.016589 12.40 2.61 0.33 0.33 20.56 31.70 4.66 7.50 5.60 45,637 191.5 22.01 9.644 0.016581 12.40 2.61 0.33 0.33 21.20 31.70 4.40 7.31 5.60 49,406 190.4 21.78 9.420 0.016574 12.40 2.61 0.33 0.33 21.73 31.70 1 4.18 7.08 5.60 60,551 187.2 21.21 8.794 0.016554 12.40 2.61 0.33 0.33 23.21 31.70 3.56 6.51 4.60 70,342 184.4 20.72 8.275 0.016536 12.40 2.61 0.33 0.33 24.43 31.70 3.05 6.02 4.10 80.342 181.8 20.28 7.816 0.016520 12.40 2.61 0.33 0.33 25.50 31.70 2.60 5.58 3.60 90,340 179.3 19.89 7.395 0.016505 12.40 . 2.61 0.33 0.33 26.49 31.70 2.19 5.19 3.10 100,340 176.8 19.52 6.994 0.016490 1 12.40 2.61 0.33 0.33 27.43 31.70 1.80 4.82 3.10 110,340 174.8 19.20 6.686 0.016478 12.40 2.61 0.33 0.33 28.14 31.70 1.50 4.50 2.60 120.306 173.2 18.93 6.447 0.016469 12.40 2.61 0.33 0.33 28.70 31.70 1.26 4.23 2.60 130,302 171.8 18.69 6.245 0.016461 12.40 2.61 0.33 0.33 29.17 31.70 1.07 3.99 2.10 140.302 170.4 18.47 6.048 0.016453 12.40 2.61 0.33 0.34 29.62 31.70 0.88 3.77 2.10 150,302 169.1 18.27 5.870 0.016445 12.40 2.61 0.33 0.34 30.03 31.70 0.71 3.57 1.70 160,302 167.8 18.07 5.696 0.016438, 12.40 2.61 0.33 0.34 30.43 31.70 0.54 3.37 1.70 170,302 166.6 17.90 5.539 0.016431 12.40 2.61 0.33 0.34 30.79 31.70 0.38 3.20 1.30 180,302 165.3 17.72 5.374 0.016424 12.40 2.61 0.33 0.35 31.16 31.70 0.23 3.02 1.30 190.302 164.1 17.54 5.225 0.016417 12.40 2.61 0.33 0.35 31.51 31.70 0.08 2.84 1.30 194,052 163.6 17.47 5.164 0.016414 12.40 2.61 0.33 0.35 31.65 , 31.70 1 0.02 2.77 1.30 196,552 163.3 17.43 5.127 0.016413 12.40 2.61 0.33 0.35 31.73 31.70 0.00 2.73 1.30 197.802 163.2 17.41 5.115 0.016412 12.40 2.61 0.33 0.35 31.76 31.70 0.00 2.71 1.30 200.302 162.9 17.37 5.079 0.016411 1 12.40 2.61 0.33 0.35 31.84 31.70 0.00 2.67 0.00

Table 4.3 VYC-0808 Rev 8 ATWS PAX q1X AtB ATWS NPSHa = (14.7-Pg)(144Vt)+Z-hf-hs-hd OPR = (NPSHr- NPSHa)/(144*Vf)

OPA = Over pressure available OPC = Over pressure credited NPSHcm = NPSH credited margin (NPSHa+OPC(144*vf) -NPSHr)

Flow Rate (aom) 1 RHR Q = 7400 Suction Line Losses (ft) 1 RHR hf = 4.77E-8-QA2 Clean Strainer Losses (ft) 1 RHR hs= 0.33 Maximum Debris Losses (ft) 1 RHR hd = 0.33 Elevation Head (ft)

RHR Z= 11.25 NPSHr (ft) 0-7 hrs I RHR NPSHr= 23.8

Table 4.3 VYC-0808 Rev 8 ATWS

?4e tZ.. 5.8 Minimum NPSHr (0-7 hrs of opration _______ __ _

GE Pool GE Pool f D Pump(s) Time Temp Pressure Pg Vf Z hf hs hd NPSHa NPSHr OPR OPA (e) F) psla l(p)

_(ps__) l (ftA3/lb) (ft) (ft) (ft) (ft) (ft) (ft) (pstg) 1RHR 300 160.0 21.00 4.741 l 0.016394 11.25 2.61 0.33 0.33 31.49 23.80 -3.26 6.30 1RHR 600 175.0 22.90 6.716 0.016479 11.25 2.61 0.33 0.33 26.92 23.80 -1.32 8.20 1 RHR 1,000 182.0 25.40 7.850 0.016521 11.25 2.61 0.33 0.33 24.27 23.80 -0.20 10.70 1 RHR 1,300 187.0 26.20 8.756 0.016552 11.25 2.61 0.33 0.33 22.15 23.80 0.69 11.50 1 RHR 1,838 190.0 27.00 9.340 0.016571 11.25 2.61 0.33 0.33 20.77 23.80 1.27 12.30 I RHR 3,000 187.0 26.60 8.756 0.016552 11.25 2.61 0.33 0.33 22.15 23.80 0.69 11.90 1 RHR 5,000 182.0 25.90 7.850 0.016521 11.25 2.61 0.33 0.33 24.27 23.80 -0.20 11.20 1 RHR 6,000 180.0 25.50 7.511 0.016509 11.25 2.61 0.33 0.33 25.07 23.80 -0.53 10.80 I RHR 8,000 175.0 24.70 6.716 0.016479 11.25 2.61 0.33 0.33 26.92 23.80 -1.32 10.00 Sensitivity to Peak Pool Temperature l GE Pool GE Pool J jJ Pump(s) Time Temp Pressure Pg Vf Z hf l hs lhd NPSHa NPSHr ll OPR OPA ll(sec) (F) l psla 1 (psla) (l311b)

MA J(K) l 5 (ft) ( ft) (ft) 1 (11 (ft) 1 (psig) l(psig) 1RHR l N/A 190.0 27.00 9.340 0.016571 11.25 2.61 03310.33 20.77 l 23.80 1.27 12.30 190.5 27.20 9.440 0.016574 -11.25 2.61 0.33 20.531 23.80 j 1.37 12.50

Table 4.4 WC-0808 Rev 8 General Profile - Overpressure vs Pool Temperature P,4(p V52S General Profile - Overpressure Required vs Pool Temperature NPSHa = (14.7-Pg)(144VQ)+Z-hf-hs-hd OPR = (NPSHr- NPSHay(144*V)

Flow Rate (aom) 1 RHR 2 RHR Cs high Q . 7400 14200 4600 low a 7000 12800 3500 Suction Line Losses (if)

I RHR 2 RHR Cs hf = 4.77E-8'QA2 7.84E-8*(Q/2)A2 2.5E-7*QA2 Clean Strainer Losses (fM)( flow rates tabulated above I RHR 2 RHR Cs (high Q) hs 0.33 1.22 0.51 (low 0) hs .33*(Q17400)A2 1.22'(Q/142 00 )A2 .38'(Q/4000)A2 Maximum Debris Losses MfI)

I RHR 2 RHR Cs hd 0 0 0 Elevation Head (ff)

RHR CS z 11.25 11.42 Minimum NPSHr (fl) ( flow rates tabulated above 1 RHR II 2 RHR CS (High 0) NPSHr 23.8 23.6 I 28.0 (Low 0) NPSHr 23.5 23.0 24.8 Maximum NPSHr (ft) 0 flow rates tabulated above 1 RHR 2 RHR CS (High 0) NPSHr 31.7 30.0 35.0 (Low 0) NPSHr 29.5 28.5 29.6

. . , . . . I. ,, . ,., ,,. ,,I , .. , ., . , ., .. . - . ._ .. ..". . ...

Table 4.4 VYC-0808 Rev 8 General Profile - Overpressure vs Pool Temperature fkS Vf O/ S*

General Profile - Overnressure Reaulred vs Pool Temnerature I RHR (a Min NPSHr (0-7 hrs of operatlon)

Pool Pool I Pump(s) Flow, Q Temp Pressure Pg Vf hf hs hd NPSHa NPSHr OPR

._(gpm) (F) psla (psla) (ftA 31b) ____(_) (ft) (fl) 'ftM (fl (psig)

IRHR 7,400 175.0 14.70 6.716 0.016480 11.25 2.61 0.33 0.00 27.25 23.80 -1.46 1RHR 7,400 180.0 14.70 7.511 0.016510 11.25 2.61 0.33 0.00 25.40 23.80 -0.67 IRHR 7,400 185.0 14.70 8.384 0.016540 11.25 2.61 0.33 0.00 23.35 23.80 0.19 1RHR 7,400 190.0 14.70 .9.340 0.016572 11.25 2.61 0.33 0.00 21.10 23.80 1.13 1RHR 7,400 195.0 14.70 10.385 0.016604 11.25 2.61 0.33 0.00 18.63 23.80 2.16 1RHR 7,400 200.0 14.70 11.526 0.016637 11.25 2.61 0.33 0.00 15.91 23.80 3.29 IRHR 7,400 205.0 14.70 12.770 0.016670 11.25 2.61 0.33 0.00 12.94 23.80 4.52 1RHR 7,000 175.0 14.70 6.716 0.016480 11.25 2.34 0.30 0.00 27.56 23.50 -1.71 1RHR 7,000 180.0 14.70 7.511 0.016510 11.25 2.34 0.30 0.00 25.70 I 23.50 -0.93 IRHR 7.000 185.0 14.70 8.384 0.016540 11.25 2.34 0.30 0.00 23.66 23.50 -0.07 IRHR 7,000 190.0 14.70 9.340 0.016572 11.25 2.34 0.30 0.00 21.40 23.50 0.88 1RHR 7,000 195.0 14.70 10.385 0.016604 11.25 2.34 0.30 0.00 18.93 23.50 1.91 IRHR 7,000 200.0 14.70 11.526 0.016637 11.25 2.34 0.30 0.00 16.22 23.50 3.04 IRHR 7,000 205.0 14.70 12.770 0.016670 11.25 2.34 0.30 0.00 13.25 l 23.50 4.27

Table 4.4 VYC-0808 Rev 8 General Profile - Overpressure vs Pool Temperature 'PIZ Y.F a ti General Prnfile- OvArnresisre Rnanidirrl v5 Pnnl Tamnarnrtura 9 PWRR f Min MNPWr Jf P

1nfl7 hra c4b**S.

Pool Pool I I I_:___H__

Pump(s) Flow, Q Temp Pressure Pg Vf Z hf hs hd NPSHa NPSHr OPR (ppm) (F) psla (psla) (ftA31lb) (K) (ff) l (K) .. L. (ft) (ft) (psig) 2RHR 14,200 170.0 14.70 5.993 0.016451 11.25 3.95 1.22 0.00 26.70 23.60 -1.31 2RHR 14.200 175.0 14.70 6.716 0.016480 11.25 3.95 1.22 0.00 25.02 23.60 -0.60 2RHR 14,200 180.0 14.70 7.511 0.016510 11.25 3.95 1.22 0.00 23.17 23.60 0.18 2RHR 14,200 185.0 14.70 8.384 0.016540 11.25 3.95 1.22 0.00 21.12 23.60 1.04 2RHR 14,200 190.0 14.70 9.340 0.016572 11.25 3.95 1.22 0.00 18.87 23.60 1.98 2RHR 14,200 195.0 14.70 10.385 0.016604 11.25 3.95 1.22 0.00 16.39 23.60 3.01 2RHR 14,200 200.0 14.70 11.526 0.016637 11.25 3.95 1.22 0.00 13.68 23.60 4.14 2RHR 14,200 205.0 14.70 12.770 0.016670 11.25 3.95 1.22 0.00 10.71 23.60 5.37 2RHR 12,800 170.0 14.70 5.993 0.016451 11.25 3.21 0.99 0.00 27.68 23.00 -1.97 2RHR 12,800 175.0 14.70 6.716 0.016480 11.25 3.21 0.99 0.00 26.00 23.00 -1.26 2RHR 12,800 180.0 14.70 7.511 0.016510 11.25 3.21 0.99 0.00 24.14 23.00 -0.48 2RHR 12,800 185.0 14.70 8.384 0.016540 11.25 3.21 0.99 0.00 22.09 23.00 0.38 2RHR 12,800 190.0 14.70 9.340 0.016572 11.25 3.21 0.99 0.00 19.84 23.00 1.32 2RHR 12,800 195.0 14.70 10.385 0.016604 11.25 3.21 0.99 0.00 17.37 23.00 2.36 2RHR 12,800 200.0 14.70 11.526 0.016637 11.25 3.21 0.99 0.00 14.65 23.00 3.48 2RHR 12,800 205.0 14.70 12.770 0.016670 11.25 3.21 0.99 0.00 11.68 23.00 4.72

.. .. ... I .I.

Table 4.4 VYC-0808 Rev 8 General Profile - Overpressure vs Pool Temperature Pflehr6 Als fe General Profile - Overpressure Reauired vs Pool Temnerature ~

-- r- -n - -~-~- -

Min NPSHr CS~*--

In.7 hrsc of nnarntlonn

'- As .be -. ---

Pump(s) Flow,Q J I Pool Temp Pool Pressure I

Pg Vf Z hf hs hd NPSHa NPSHr OPR (gpm) (F) asla (psla) (ftA3/lbj (ft) (ft) (ft) (ft) (ft) (psg)

CS 4,600 155.0 14.70 4.204 0.016368 11.42 5.29 0.51 0.00 30.36 28.00 -1.00 CS 4,600 160.0 14.70 4.741 0.016395 11.42 5.29 0.51 0.00 29.13 28.00 -0.48 CS 4.600 165.0 14.70 5.336 0.016422 11.42 5.29 0.51 0.00 27.76 28.00 0.10 CS 4,600 170.0 14.70 5.993 0.016451 11.42 5.29 0.51 0.00 26.25 28.00 0.74 CS 4,600 175.0 14.70 6.716 0.016480 11.42 5.29 0.51 0.00 24.57 28.00 1.45 CS 4,600 180.0 14.70 7.511 0.016510 11.42 5.29 0.51 0.00 22.71 28.00 2.22 CS 4,600 185.0 14.70 --8.384 0.016540 11.42 5.29 0.51 0.00 20.66 28.00 3.08 CS 4,600 190.0 14.70 9.340 0.016572 11.42 5.29 0.51 0.00 18.41 28.00 4.02 CS 4,600 195.0 14.70 10.385 0.016604 11.42 5.29 0.51 0.00 15.94 28.00 5.05 CS 4,600 200.0 14.70 11.526 0.016637 11.42 5.29 0.51 0.00 13.22 28.00 6.17 CS 4,600 205.0 14.70 12.770 0.016670 11.42 5.29 0.51 0.00 10.25 28.00 7.39 CS 3,500 155.0 14.70 4.204 0.016368 11.42 3.06 0.29 0.00 32.81 24.80 -3.40 CS 3,500 160.0 14.70 4.741 0.016395 11.42 3.06 0.29 0.00 31.58 24.80 -2.87 CS 3,500 165.0 14.70 5.336 0.016422 11.42 3.06 0.29 0.00 30.21 24.80 -2.29 CS 3,500 170.0 14.70 5.993 0.016451 11.42 3.06 0.29 0.00 28.69 24.80 -1.64 CS 3,500 175.0 14.70 6.716 0.016480 11.42 3.06 0.29 0.00 27.01 24.80 -0.93 CS 3,500 180.0 14.70 7.511 0.016510 11.42 3.06 0.29 0.00 25.16 24.80 -0.15 CS 3,500 185.0 14.70 8.384 0.016540 11.42 3.06 0.29 0.00 23.11 24.80 0.71 CS 3,500 190.0 14.70 9.340 0.016572 11.42 3.06 0.29 0.00 20.86 24.80 1.65 CS 3,500 195.0 14.70 10.385 0.016604 11.42 3.06 0.29 0.00 18.38 24.80 2.68 CS 3,500 200.0 14.70 11.526 0.016637 11.42 3.06 0.29 0.00 15.67 24.80 3.81 CS 3,500 205.0 14.70 12.770 0.01667 11.42 3.06 0.29 0.00 12.70 24.80 5.04

. . l. I .

Table 4.4 VYC-0808 Rev 8 General Profile - Overpressure vs Pool Temperature 9tc f? j$500 (l-fljr- Profile

('eneral Pwr

.nf illn

-,OvterPresura

- O nr

__-- Aa .. Reanircef

- - r Agb~ . R ^ [ I r d vsq~ Pnool

- _ Pn Tamnteraftire

_ T \ n rn l r I RHR- Rih May NPSI-r 1>7 hrm nf narationi*6-Cal Pool Pool . _ I Pump(s) Flow, Q Temp Pressure Pg Vf Z hf hs hd NPSHa NPSHr OPR

_ (gpm) (F) psla (psa) (ftA3nb) (ft) hs (ft) (fK) (Psig) 1RHR 7,400 155.0 14.70 4.204 0.016368 11.25 2.61 0.33 0.00 33.05 31.70 -0.57 1RHR 7,400 160.0 14.70 4.741 0.016395 11.25 2.61 0.33 0.00 31.82 31.70 -0.05 1RHR 7,400 165.0 14.70 5.336 0.016422 11.25 2.61 0.33 0.00 30.45 31.70 0.53 IRHR 7,400 170.0 14.70 5.993 0.016451 11.25 2.61 0.33 0.00 28.93 31.70 1.17 1RHR 7,400 175.0 14.70 6.716 0.016480 11.25 2.61 0.33 0.00 27.25 31.70 1.87 IRHR 7,400 180.0 14.70 7.511 0.016510 11.25 2.61 0.33 0.00 25.40 31.70 2.65 1RHR 7,400 185.0 14.70 8.384 0.016540 11.25 2.61 0.33 0.00 23.35 31.70 3.51 IRHR 7,400 190.0 14.70 9.340 0.016572 11.25 2.61 0.33 0.00 21.10 31.70 4.44 1RHR 7,400 195.0 14.70 10.385 0.016604 11.25 2.61 0.33 0.00 18.63 31.70 5.47 IRHR 7.400 200.0 14.70 11.526 0.016637 11.25 2.61 0.33 0.00 15.91 31.70 6.59 1RHR 7.400 205.0 14.70 12.770 0.016670 11.25 2.61 0.33 0.00 12.94 31.70 7.81 1RHR 7,000 155.0 14.70 4.204 0.016368 11.25 2.34 0.30 0.00 33.35 29.50 -1.63 1RHR 7,000 160.0 14.70 4.741 0.016395 11.25 2.34 0.30 0.00 32.12 29.5071 -0.

1RHR 7,000 165.0 14.70 5.336 0.016422 11.25 2.34 0.30 0.00 30.76 29.50 -0.53 1RHR 7,000 170.0 14.70 5.993 0.016451 11.25 2.34 0.30 0.00 29.24 29.50 0.11 IRHR 7,000 175.0 14.70 6.716 0.016480 11.25 2.34 0.30 0.00 27.56 29.50 1.60 IRHR 7,000 180.0 14.70 7.511 0.016510 11.25 2.34 0.30 0.00 25.70 29.50 2.45 1RHR 7,000 185.0 14.70 8.384 0.016540 11.25 2.34 0.30 0.00 23.66 29.50 3.39 IRHR 7,000 190.0 14.70 19.340 0.016572 11.25 2.34 0.30 0.00 21.40 29.50 3.39 1RHR 7,000 195.0 14.70 10.385 0.016604 11i.25 2.34 0.30 0.00 18.93 29.50 4.4 1RHR 7,000 200.0 14.70 11.526 0.016637 11.25 2.34 0.30 0.00 16.22 29.50 5.54 1RHR 7,000 205.0 14.70 12.770 0.016670 11.25 2.34 0.30 0.00 13.25 29.50 6

Table 4.4 VYC-0808 Rev 8 General Profile - Overpressure vs Pool Temperature PrA vomit General Profile - Overnressure Reauired vs Pool Temnerature 2 RHR (a Max NPSHr (>7 hrs of operation)wBB 1 _Pool Pool _ _ 1 1_ __

Pump(s) Flow,Q Temp Pressure Pg Vf Z hf hs hd NPSHa NPSHr OPR WPM) (F) psLa (psla) (ft-3nb) (fh) (ff) (ft) (fl) (f) (ft) (psig) 2RHR 14,200 155.0 14.70 4.204 0.016368 11.25 3.95 1.22 0.00 30.82 30.00 -0.35 2RHR 14,200 160.0 14.70 4.741 0.016395 11.25 3.95 1.22 0.00 29.59 30.00 0.17 2RHR 14,200 165.0 14.70 5.336 0.016422 11.25 3.95 1.22 0.00 28.22 30.00 0.75 2RHR 14,200 170.0 14.70 5.993 0.016451 11.25 3.95 1.22 0.00 26.70 30.00 1.39 2RHR 14,200 175.0 14.70 6.716 0.016480 11.25 3.95 1.22 0.00 25.02 30.00 2.10 2RHR 14.200 180.0 14.70 7.511 0.016510 11.25 3.95 1.22 0.00 23.17 30.00 2.87 2RHR 14,200 185.0 14.70 8.384 0.016540 11.25 3.95 1.22 0.00_ 21.12 3000 3.73 2RHR 14,200 190.0 14.70 9.340 0.016572 11.25 3.95 1.22 0.00 18.87 30.00 4.66 2RHR 14,200 195.0 14.70 10.385 0.016604 11.25 3.95 1.22 0.00 16.39 30.00 5.69 2RHR 14,200 200.0 14.70 11.526 0.016637 11.25 3.95 1.22 0.00 13.68 30.00 6.81 2RHR 14,200 205.0 14.70 12.770b 0.016670 11.25 3.95 1.22 0.00 10.71 30.00 8.04 2RHR 12,800 155.0 14.70 4.204 0.016368 11.25 3.21 0.99 0.00 31.79 28.50 -1.39 2RHR 12,800 160.0 14.70 4.741 0.016395 11.25 3.21 0.99 0.00 30.56 28.50 -0.87 2RHR 12,800 165.0 14.70 5.336 0.016422 11.25 3.21 0.99 0.00 29.19 28.50 -0.29 2RHR 12,800 170.0 14.70 5.993 0.016451 11.25 3.21 0.99 0.00 27.68 28.50 0.35 2RHR 12,800 175.0 14.70 6.716 0.016480 11.25 3.21 0.99 0.00 26.00 28.50 1.06 2RHR 12,800 180.0 14.70 7.511 0.016510 11.25 3.21 0.99 0.00 24.14 28.50 1.83 2RHR 12,800 185.0 14.70 8.384 0.016540 11.25 3.21 0.99 0.00 22.09 28.50 2.69 2RHR 12,800 190.0 14.70 9.340 0.016572 11.25 3.21 0.99 0.00 19.84 28.50 3.63 2RHR 12,800 195.0 14.70 10.385 0.016604 11.25 3.21 0.99 0.00 17.37 28.50 4.66 2RHR 12,800 200.0 14.70 11.526 0.016637 11.25 3.21 0.99 0.00 14.65 28.50 5.78 2RHR 12,800 205.0 14.70 12.770 0.016670 11.25 3.21 0.99 0.00 11.68 28.50 7

- - - r iE

Table 4.4 VYC-0808 Rev 8 General Profile - Overpressure vs Pool Temperature Nil VI er fd4e General Profile - Overnresnure Reouirnd vq Pool Tamneratura Max CM __m_- NMPSqIlr 8 z ~§ 1>7 hmrs f onnarntnnl Pump(s)

IPool Flow, Q

-wrp~~---u-* ----.--.-

Temp Pool1 Pressure Pg Vf z hf hs w*

hd NPSHa NPSHr OPR

"'*1 gPM) (F) psl(ps l a(f^3flb) (Rt) (ft)V (Rt)l- 0 (f) (Kt) (psig)

CS 4,600 125.0 14.70 1.942 0.016225 11.42 5.29 0.51 0.00 35.43 35.00 -0.18 CS 4,600 130.0 14.70 2.223 0.016246 11.42 5.29 0.51 0.00 34.81 35.00 0.08 CS 4,600 135.0 14.70 2.537 0.016269 11.42 5.29 0.51 0.00 34.11 35.00 0.38 CS 4,600 140.0 14.70 2.889 0.016293 11.42 5.29 0.51 0.00 33.33 35.00 0.71 CS 4,600 145.0 14.70 3.282 0.016317 11.42 5.29 0.51 0.00 32.45 35.00 1.09 CS 4,600 150.0 14.70 3.718 0.016342 11.42 5.29 0.51 0.00 31.46 35.00 1.50 CS 4,600 155.0 14.70 4.204 0.016368 11.42 5.29 0.51 0.00 30.36 35.00 1.97 CS 4,600 160.0 14.70 4.741 0.016395 11.42 5.29 0.51 0.00 29.13 35.00 2.49 CS 4,600 165.0 14.70 5.336 0.016422 11.42 5.29 0.51 0.00 27.76 35.00 3.08 CS 4,600 170.0 14.70 5.993 0.016451 11.42 5.29 0.51 0.00 26.25 35.00 3.70 CS 4,600 175.0 14.70 6.716 0.016480 11.42 5.29 0.51 0.00 24.57 35.00 4.40 CS 4,600 180.0 14.70 7.511 0.016510 11.42 5.29 0.51 0.00 22.71 35.00 5.17 CS 4,600 185.0 14.70 8.384 0.016540 11.42 5.29 0.51 0.00 20.66 35.00 6.02 Cs 4,600 190.0 14.70 9.340 0.016572 11.42 5.29 0.51 0.00 1 18.41 35.00 6.95 Cs 4,600 195.0 14.70 10.385 0.016604 11.42 5.29 0.51 0.00 15.94 35.00 7.97 CS 4,600 200.0 14.70 11.526 0.016637 11.42 5.29 0.51 0.00 13.22 35.00 9.09 CS 4,600 205.0 14.70 12.770 0.016670 11.42 5.29 0.51 0.00 10.25 35.00 10.31

Table 4.4 VYC-0808 Rev 8 General Profile - Overpressure vs Pool Temperature 14 47 AJ0 I General Profile - Overoressure Reauired vs Pool Temnerature CS Max NPSHr (>7 hrs of ooeration)

Pool Pool . I Pump(s) Flow, Q Temp Pressure Pg Vf Z hf hs hd NPSHa NPSHr OPR

_(gpm) (F) psa (psla) (ftA3fb) (__) (ft) ,f=, (ft) (ft) (ft) ( sig)

CS 3,500 125.0 14.70 1.942 0.016225 11.42 3.06 0.29 0.00 37.88 29.60 -3.54 CS 3,500 130.0 14.70 2.223 0.016246 11.42 3.06 0.29 0.00 37.26 29.60 -3.27 CS 3,500 135.0 T 14.70 2.537 0.016269 11.42 3.06 0.29 0.00 36.56 29.60 -2.97 CS 3,500 140.0 14.70 2.889 0.016293 11.42 3.06 0.29 0.00 35.78 29.60 -2.63 CS 3.500 145.0 14.70 3.282 0.016317 11.42 3.06 0.29 0.00 34.90 29.60 -2.25 CS 3,500 150.0 14.70 3.718 0.016342 11.42 3.06 0.29 0.00 33.91 29.60 -1.83 CS 3,500 155.0 14.70 4.204 0.016368 11.42 3.06 0.29l 0.00 32.81 29.60 -1.36 CS 3,500 160.0 14.70 4.741 0.016395 11.42 3.06 0.29 0.00 31.58 29.60 -0.84 CS 3,500 165.0 14.70 5.336 0.016422 11.42 3.06 0.29 0.00 30.21 29.60 -0.26 CS 3,500 170.0 14.70 5.993 0.016451 11.42 3.06 0.29 0.00 28.69 29.60 0.38 CS 3,500 175.0 14.70 6.716 0.016480 11.42 3.06 0.29 0.00 27.01 29.60 1.09 CS 3,500 180.0 14.70 7.511i 0.016510 11.42 l 3.06 0.29 0.00 25.16 29.60 1.87 CS 3,500 185.0 14.70 8.384 0.016540 11.42 3.06 0.29 0.00 23.11 29.60 2.72 CS 3,500 190.0 14.70 9.340 0.016572 11.42 3.06 0.29 0.00 20.86 29.60 3.66 CS 3,500 195.0 14.70 10.385 0.016604 11.42 3.06 0.29 0.00 18.38 29.60 4.69 CS 3,500 200.0 14.70 11.526 0.016637 11.42 3.06 0.29 0.00 15.67 29.60 5.81 CS 3,500 205.0 14.70 12.770 0.016670 11.42 3.06 0.29 0.00 12.70 29.60 7.04

.. . I .

TABLE;2'  % S 2

VYC-808, Rovisionk' NPSHA = (14.7- Pg)(144)(vn + Z- hf - h_s - h-d Suction Une Losses 1 RHR h-f - 4.770-80QA2 Cs hj = 2.5OTQ^A2 2 RHR h_f - 7.840-86(QC)A2 C~lean Stralner Losas 1 RHR h-s - 0.3(CQ7400)2 Cs h.s = O.W(Qf4000)A2 2 RHR h-s

• 12Z(Q11 4200)Y2 Reaulved NPSH RHR NPSHR = 30 a 3g50 pm CS NPSHR - 32.5 0 300 gpm RHR NPSHR - 26 O 2700 gpm CS NPSHR - 27 O 120 Dgpm

• , *Clean' O T P_ vf Z h hs NPSHA NPSHR Margin (pm) (F) (psla) (cu fVAb) (K) (ft) (R) (t) (ft) (ft)

I Cs 300 90 . 0.69813 0.016099 12.47 0.0225 0.00 44.9 32.5 12.4 min-flow 300 120 1.6927 0.016204 12.47 0.0225 0.00 42.8 32.5 10.3 S00 34hr 1S0 3.7184 0.016343 12.47 0.0225 0.00 38.3 32.5 5.8 300 184 5.212 0.016410 12.47 0.0225 0.00 34.9 32.5 2.4 300 181.9 7.838 0.016521 12.47 0.0225 0.00 28.8 32.5 -3.7 300 190 9.34 0.016572 12.47 0.0225 0.00 25.2 32.5 -7.3 1 CS 1250 90 0.69813 0.016099 12.47 0.39* 0.04 44.5 27.0 17.5 min-flow 1250 120 1.6927 0.016204 12.47 0.39 0.04 42.4 27.0 15.4

> 4 hr 1250 150 3.7184 0.016343 12.47 0.39 0.04 37.9 27.0 10.9 1250 184 5.212 0.016410 12.47 0.39 0.04 34.5 27.0 7.5 1250 182.6 7.954 0.016530 12.47 0.39 0.04 28.1 27.0 1.1 1250 184 8203 Q016535 12.47 0.39 0.04 27.5 27.0. 0.5 1250 185 8.384 0.016541 12.47 0.39 0.04 27.1 27.0 0.1 2 RHR 700 90 0.69813 0.016099 12.30 0.01 0.00 44.7 30.0 14.7 min-flow 700 120 1.927. 0.016204 12.30 0.01 0.00 42.6 30.0 12.6 S 4 hr 700 150 3.7184 0.016343 12.30 0.01 0.00 38.1 30.0 8.1 700 164 5.212 0.016410 12.30 0.01 0.00 34.7 30.0 4.7 700 181.9 7.838 0.016521 12.30 0.01 0.00 28.6 30.0 *1.4 700 190 9.34 0.016572 12.30 0.01 0.00 25.1 30.0 *4.9 2 RHR 5400 90 0.69813 0.016099 12.30 0.57 0.18 44.0 26.0 18.0 min-flow 5400 120 1.6927 0.016204 12.30 0.57 0.18 41.9 26.0 15.9 ,;Z5

> 4 hr 5400 10 3.7184* 0.016343 12.30 0.57 0.18 37.4 28.0 11A 5400 164 5212 0.016410 12.30 0.57 0.18 34.0 ,"'It 28.0 8.0 5400 182.6 7.954 0.016530 12.30 0.57 0.18 27.6 28.0 1.6 5400 190 9.34 0.016572 12.30 0.57 0.18 24.3 28.0 .1.7 Z:  %

ItA.

_V_

.,, I .... I

Figure 4.2 LOCA - Long Term (1.5 wt. %Containment Leakage & 100% Spray Efficiency)

OPC overpress credit Over Pressure Required for NPSH - LOCA ($90 PSlg)

(1.5 wt. % Containment Leakage with 100% Spray Eff.) 601 2.4 2000 2.4 (based on Long Term NPSHr data) 2001 3.4 4000 3.4 4001 4.4 6000. 4.4 6001 5.1 9000 5.1 9001 6.1 40000 6.1 40001 5.8 50000 5.6 50001 5.1 60000 5.1 60001 4.6 70000 4.6 70001 4.1 80000 4.1 80001 3.6 90000 3.6 90001 3.1 110000 3.1 110001 2.6 130000 2.6 130001 2.1 150000 2.1 150001 1.7 170000 1.7 170001 1.3 180000 1.3 0 60,000 100,000 150,000 200,000 200000 1.3 200001 0 Time (see)

.. . -.,,I

Figure 4.3-1 VYC-0808 Rev 8 Over Pressure Required for NPSH - ATWS (based on minimum NPSHr) A Overpressure available (psig) 13.00-

.--- I RHR Overpressure Req'd (psig)_

12.00 - - +LOCA Overpressure Credit 11.00-10.00-9.00-8.00 -

7.00

, 6.00-5.00 -

400 n 4.00-X 3.00-200 2.00-1.00-0.00-

-1.00-

-2.00

-3.00

-4.00 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 Tlme (sac)

Figure 4.3-2 VYC-0808 Rev. 8 P4'y; oS6L I

Suppression Pool Temperature l +LOCA -- ATWS I 95.0 90.0 0) 0 85.0 80.0 0

a0 75.0 70.0 E 65.0 0

60.0 55.0 0 2,000 4,000 6,000 8,000 10,000 Time (seconds)

8 Figure 4.4-1 VYC-0808 Rev2'

-GGH 0 Page HWof i2 PI; Se?

General Profile - Overpressure Required vs Pool Temperature I RHR pump - Min &Max NPSHr (these curves are based on a clean suction strainer) 1 3

I e9

.2.00 1 1 _ 1 .J I T I I II.I 155.0 180.0 165.0 170.0 175.0 180.0 185.0 190.0 196.0 200.0 205.0 Pool Tamp, F

-e~

8 Figure 4.4-2 VYC-0808 RevR' Page48'of A~'

S FV General Profile - Overpressure Required vs Pool Temperature 2 RHR pumps - Min & Max NPSHr

{these curves are based on a clean suction stralner}

0 1

I 0E 0

9 I

.2.00 1 155.0 160.0 165.0 170.0 175.0 180.0 185.0 190.0 195.0 200.0 205.0 Pool Temp, F

a Figure 4.4-3 VYG-0808 RevZ Page 4' of 4.2

.S7 59 General Profile - Overpressure Required vs Pool Temperature Cs pump - Minimum NPSHr (0-7hrs of operation)

[these curves are based on a clean suction strainer)

'a 4.00 9

1 3.00 I! 2.00 M

I 1.00 0.00

-4.00 I . .lII I l l lI I . l I 155.0 160.0 165.0 170.0 175.0 180.0 185.0 160.0 195.0 200.0 205.0 PoolTemp, F

Figure 4.4-4 WYC.0808 RevA8' Page,42~'of Ae 9g 58' General Profile - Overpressure Required vs Pool Temperature CS pump - Maximum NPSHr (>7 hrs of operation)

II., _

[these curves are based on a clean suction stralner)

10. 00 oo = -- CS @ 4600 gpm I Max NPSHr 9.

00 8.00 _4 CS @3600 gpm I Max NPSHr 7..00 _ I s 6.00 2 5. 0 0 ------

I S 4.00-3.00 4A O 2.00 o 1.00

°00 -- -_ __ -- -== ---- Z--/ -'

0.00.

.1.

00

-2.

.00 --

-3.O0 I

-4.

125.0 130.0 135.0 140.0 145.0 150.0 155.0 160.0 165.0 170.0 175.0 180.0 185.0 190.0 195.0 200.0 205.0 Pool Temp, IT

YANKEE NUCLEAR SERVICES DIVISION CALC. NO. WC 6° REV. DA_

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VYC-808, Revision 6, Attachment 2 ITSIVY00-001 Rev.O ,'

Revised ECCS Suction Strainer Head Loss Assessment for Vermont Yankee Prepared for Vermont Yankee Nuclear Power Corporation Innovative Technology Solutions Corporation

• .rp,, h 600 Uptown Blvd. NE, Suite 300 Albuquerque, NM 871 10 Octobcr 15,2(X)0 Prepared By: Peter K.Mast ltols-too Date Reviewed By. Gilbert L Zipder DAA, lh e,

WC-808, Revision 6,Attachment 2 Revised ECCS Saction Stimner Head LossAssessmenefor Vermont Yankee 1T&WV0Y-001 ReiO An assessment of ECCS suction strainer head loss for the Vermont Yankee plant was completed in August of 1998 (Calculation DC-A34600.006). Since that time, better information has been obtained on a couple of key parameters in the analysis. These changes are as follows:

• The long-term CS flow rate was determined to be 3500 GPM (previously, a parametric range of 4000-4600 GPM had been considered).

• The long-term pool temperature has been determined to be 185 Deg F.

• The quantity of sludge used for the analysis was reduced by approximately a factor of two.

• Minor changes in fibrous debris distribution.

As a result of the first and fourth of these changes, the distribution of debris on the RHR and CS strainers is changed; a greater fraction of the debris now is deposited on the RHR strainer. Thus, this change would be expected to result in a higher RHR strainer bead loss (same flow rate, same temperature, and greater debris quantity) and a lower CS strainer head loss (lower flow rate, same temperature, and lower debris quantity).

The second of these changes, the increased water temperature, and the third of these changes, the reduction in sludge quantity, would tend to reduce head loss for both the CS and RHR strainers, assuming the same assumptions on sludge behavior (filtration) are used in the analysis.

To evaluate the impact of the above changes on strainer head loss, Cases I and 3b (the long-term 1-pump RHR and CS analyses, respectively) were reanalyzed. The following table summarizes the debris quantities used in this analysis along with a comparison to those previously used.

Parameter Units RHR System CS S tern Old Case I . New Case l Old Case 3b New Case 3b Flow Rate GPM 7400 7400 4000 3500 Water Temperature Deg F 173 185 173 185 Nukon Lbm 258 256 152 122 Fibermat Cu-Ft 9.6 10 5.7 5 TempMat Urm 20.5 31 12.1 15 Armaflex Cu-Ft (l)_ _ (_) (l)

Sludge (dry) Lbm 546 271 322 129 Rust . Lbm 35.3 35 20.8 17 Qualified Coat Lbm 61 60 36 29 Unqual Coat - IOZ Lbm 70 70 42 42 Unqual Coat - Epox Sq-Ft 0(Z) O (2 2 J (Z (1) -This material was shown to float and not impact strainer performance.

(2) - ARL testing showed that this coatings debris did not deposit on strainer.

Page 2 of 3

VYC-808, Revision 6,Attachment 2 Revised ECCSSuction Strainer Head Lo Anessmasfor Vermont Ynee ITwY -ooiRevO Using the above distributions of fibrous insulation debris, the total mass of fibrous debris changed from 336 Ibm to 347 ibm for Case I (RHR) and from 198 Ibm to 167 Ibm in Case 3b (CS). Aside from the change in the particulate debris quantities specified above, and the change in flow rate for Case 3b, all other analysis parameters used in this reassessment are identical to those used in the previous calculations. This includes a reduction of 50% in the quantity of sludge, qualified coatings debris, and IOZ debris being deposited on the strainer due imperfect filtration of this material by the relatively thin fiber mat.

The results of these analyses, along with a comparison to the previously calculated results, are presented in the following table.

Calculated Parameter Units RHR ystem CS S stem

__ l_ Old Case 1 New Case 1 Old Case 3b New Case 3b Head Loss Ft 033 0.26 0.21 0.08 water Debris Thickness inches 1.9 2.1 .2.6 2.2 I - -I - II I - - -

iiYt Page3 of 3

Page 1 VYC-808, Revision 6, Attachment 3 Table of Contents 1.0 Introduction ............. 1 2.0 Analysis .... ;1 3.0 Inputs/Outputs .2 4.0 Results ........... 3 4.1 RHRPump ....... . ... 3 4.2 CSPump .6 5.0 Conclusion .8 Attachment - Letter, Sulzer-Bingham to D. E. Yasi, VYNPC, March 26, 1999 . . 9 1.0 Introducti The objec of tis CCN is to ne the available NPResidual Heat Remo (RHR d Core Spray (CS nps at design flow dyg the most limiting torus heascenario and ompare the avail NPSH (NPSHa) to quired NPSH (NPSHr 2.0 An sis For ea ofthe RHR and CS NPSHa as a 's, on of time will be dete based on me s developed in VY -808, Revision 6. NPS a varies with time only use the fui rature does so ng the transient. The Iting torus temperature file from V -

1628F (run15) is for this analysis. SHa for each pump i n plotted anst the vendor's allowa e NPSHa to demons epump operability.

Tevendo' allowable N,1PS~ r hw nFgrs211( Pumps) and 2.2-1 (CS Pumps).

For a complete description of these curves, see VYC-808, Revision 6 and its Attachment 5. In l summary, the curves show the allowable operating period for a given pump at any NPSHa. d jtProvided the calculated NPSHa for a specific flow rate is, at all times, greater than the 5 corresponding curve for the same flow rate, the pump is considered operable regarding NPSEL lThe pump vendor is Sulzer Bingham Pumps, Inc. (SBP1). Their allowable NPSHa are provided for flow rates of 6400,7000, and 7600 gpm for the RHR pump (VYC-808, Attachment 5). The maximum long-term flow rate of the system is 7400 gpm (VYC-808, Section 3A). The first step in this calculation is to develop an allowable NPSHa curve at the maximum flow. This is done using the curve fit from VYC-808, Revision 6, Section 2.2.2 for times between 1 and 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />, and by linear interpolation between the SBPI curves for 7000 gpm and 7600 gpm beyond 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.

The use of a linear interpolation beyond 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> is conservative based on the predicted variations among 6400, 7000, and 7600 gpm.as shown on the SBPI curves. The curve fit from VYCG808 is:

\_ NPSHjqHR ,23.0+ .12400 feet (Eq. l. 1)

The no step is to plot the a lable NPSH for the lir g torus temperature nario. The equ on for NPSHa - de oped in Section 42.2.4 VYC-808 for the pump at 7400 NPSH,* pwR=( - pXI 4 + Z-H-H srer ..2)

/

Page 2 VYC-808, Revision 6, Attachment 3 where, p =torus press re(14.7 psia)

P = vapor p sure of water emperature (ps conveyion factor

/v = s ecific volume of ater at temperai 3 lm)M(ft

/Z =eervation head (1X42 ft)/

(Hf = ction head lo (2.61 ft)

H {strainer debricad loss (0 ft)/

= clea td lo The method of solution for the Core Spray pump is the same as that for the RHR pump, but with the following exceptions. SBPI's allowable NPSHa are provided for flow rates of 3000,3500, and 4600 gpm for the CS pump (attached). The maximum long-term flow rate of the system is 3500 gpm (VYC-808, Section 3.4). Therefore, the minimum allowable NPSH is known and (needn't be derived.

The eq4tion for NPSHa developed in Section 4.2.3.4 o0 C-808 for the pump at 3500 w g is Equation 1.2, but wi e following values: /

pwm = torus sure (14.7 psia) pa = vapr pressure of water at mperature (psia) 144 = nversion factor v specific volume of ter at temperature t3 lbm)

Z = elevation head (I .9 ft)

Hf = friction head lo (3.06 ft)

HD = strainer debris cad loss (0 ft)

H.",,== clean strainer head loss (0.32 3.0 Inputs/Outputs Design inp s used in this calculatie

• the temperature data on VYC-1628F for the tng torus heat-up scenari (runl5), and

• an adder to above temperatures that ccounts for event conditionshat were not modeled. om Reference 19, the t limiting adder is 0.9'F.

The assumptions d in this calculation e same as those in Y , Revision 6.

Page 3 VYC-808, Revision 6, Attachment 3 4.0 Results 4.1 RHR Pump Figure 2.1-1 shows the SBPI allowable times at NPSH for RHR pump flow rates of 6400,7000, and 7600 gpm. The same curve for the design flow rate of 7400 gpm is also shown. It is derived by using Equation 1.1 for times between 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and.7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />, and by linear interpolation between the SBPI curves for times beyond 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />. The data points are:

• NPSHa NPSHa . NPSHa.

@7000gprn @7600gpm- @74.00gpbi (fedt) (feet) (feet) 1N/A 23.8

___.__1 Use Equation 1.1 23.8I. /

7 NIA Use Equation 1.1 23.8 g

13.5 25.0 28.0 27.0 21 28.5 31.6 30.6 100 29.5 32.75 31.7.

gm a )29.5 32.75 31.7.

The Iing NPSHa curve for RHR pump is det ned with Equation 1.2 and th uniting torus ater temperature pro e from VYC-1628F, 15 (Reference 5). The tern atures from n are increased by 0 F to account for even conditions that were not mod d (Reference 19 The data points fo e curve are shown in able 2.1-1. Values forp and are interpolated frmthe saturated st ales.

The 1tiiting NPS falls abov the allow e curve at e design flow rate for ajtimes.

The7 or, the pump's operb is hity not conprom71C /

Page 4 VWC-808, Revision 6, Attachment 3 Table 2.1-1 RHR Pumo NPSHa Durina the Limiting Torus Temperature Transient Time Temperature (OF)

From runlS +O.!F (psia) Abm)_l (f)

(.6 hrs 181.7 182.6 7 0.016525 25.5 8brs 180.9 181.8 7.819 0.016521 25.8 (28,797 sec) ______

9 (36,00 sec) 179.2 180.1 7.529 0.016511 26.5 (72,054h )r1s 168.6 5.807 0.016443 30.5 (75554 166.7 167.6 5.555 0.016432 31.1 0rs 138. 139.0 2.816 0.016288 37.3 Saqilrced~ Oa,

VYC-808, Revision 6, Attachment 3 Page S fture 2.1-1 RHR PumP Allowable Oerating Periods 0 NPSHa Sneciried II' hours I 10 100 1000 8000 I

__ _ I & l . 1 I * - - - - * - . . I I -

7Alowable Operatng _

/I IlI .*1. H Ut----t-1-lifftltf----f--HI-H-Fl

. * * *...I I * * .

I 7

32- Pedods 0 NPSHa _ - 7000 gpm i8ck-hrs -32 Speaced I- 746g0pm @-

-- 6400 gpDm e81c--rs I I 11 11 -

-- I. I- If _..L. . ---- 7600 gpm 0 Sk-hrs v.

I FP - . - . .--................

aa

. _ . _. 11 I I11 Ig11V I - I 8 - _ I H r I H ill I .

28 __

_O _ S Il[-

__-I 11111111 1 ,

II a

a i1 V. I U - wv"11 AOijlVA5 I!14 ttWtE,i-  ! I I XIII I 4 I* I C

,1 i'I I -

26- 1JLt=1 2B '7 0.

z-I i

RHIR Pumps :1 ft 16 x 18 x 26 24VIC 24

.*05la I1 sIn 27083918421 ,i7

't 4 -

. _1l+-lhe Theearenv 1* nNPSHa . l1i vakHM NPtamustbe grealer

. Xnorequal to the valueslhown. Cue No-20-11I! 1  !!  !  !!1,--,E12,5.522-20 1_2 I1 10 100 1000 8000 Operating Time - hours

Page 6 VYC-808, Revision 6, Attachment 3 4.2 CS Pump

/ Figure 2.2-1 shows the SBPI allowable times at NPSH for CS pump flow rates of 30,35,)

and 4600 gpm.J The imt torus ter temperature a curve fpeCS pump is determined with E ile fromnVYC-1628F, run i15 are increa y 0.9°F to acco q g The temperaty from onditi that were not modeleeference

(

9). The data ptsf e sbown in Table -1. Values forp, and einterpolated

/ ea m ~tables.

The limiting NPSHa falls above the allowable curve at the design fib Therefore, the purrp's operbltisntcra bili i Table 2.2-1 CS Pump NPSHa During the Limiting Torus Temperature Translent

. TTepperature (") NP

__ __ From run15 +O.9F (psia) (ft3/lbm)

(3,595 5) 172.3 173.2 6.449 0.014 28.8 2 hrs 1772 178.1 7.204 0.016499 27.0 (7,203 sec) __ _ _ _ __ _ _ _ _ _

4 hrs 181.0 181.9 7 0.016521 25.5 5.6 hrs 181.7 182.6 7.956 0.016525 25.3 (25194 sec); 181.4 182.3 7.904 0.016524 25A (36,050 sec) .2 180.1 7.529 0.016511 . 26.3 (54,05 173A 174.3 6.613 0.016476 28.4 SW) 167.7 168.6 5.807 0.016443 30.3 (108,056 s) 158.7 159.6 4.697 0.016393 32.8 el

Page 7 WC-808. Revision 6. Attachunent 3 Fiure 2.2-1 CS Pump Allowable Operating Periods 0 NPSHa Specifled houm 384 - a m ,- . . f.1.'1 l- -li'l i ~~~~-- Ad)] r' j 1000 8000 11 L L 4n Operating T- -hours ' I

Page 8 VYC-808, Revision 6. Attachment 3 5.0 Conclusion limiting available for RHR and CS p ye been determined t respective esign flow s during the ting torus temperattransient In both cr, the limiting NPSHa fall bove the res: ve allowable NPS or all times. Theref , the pumps' operabily are not compr *sed. /

Page 9 VYC-808, Revision 6, Attachment 3 Attachment - Letter, Sulzer-Bingham to D. E. Yasi, VYNPC, March 26,1999 Telefax - MDwof SPUMPS Rj A SuW Roaq c

Suizer fringham Pumps Inc.

Field Engineerng K*nny Thomson 2800 N.W. Front AvenUo

• Po.tand, OR97210-1502.

• • te, *%*. S*.**.-X:

Fax 8-1-978-663732 Pages: 1 (including this one)

Subject:

Serial #270839J842 -2804181419 F-97-10782 30P59

. Yankee PO QA42125 . ** . . .*

With reference to your letter of 12 March 99, based on oainal NPSHr curve, test data the period of operation vA nearly equal the 3000 opmn cure.

Please sOO cUrVe (E12.8.52-lArl) attached.

A*

Page 10 VYC-808, Revision 6, Attachment 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> 1 10 100 1000 10000 38 - I I 'I ,

• f I - '- r - - . -. i1 ' ,LI r 1 4A j- 1, 'u, -' ,' § 4 ,4 Alowabto Oporating 16 111111 I I II I Periods a NPSfa Sptad r 1111- -11 - I- --

I _ _ .

II I I I HIM m1m ,1 I - i ._

I m III01l1 .t .

" .17 . -f _-

.- I

_.I ! '-;i'

.,*:I

-2 *;

H1C

_t. I-- ..

• ..:'..-.A1--

1.1,,,,,r , ,,,, . ,_ _

1.- . .

.A - t- ,-I 1, v1 I h S. -. _ _

4-

- <_I

,N6^s. j K'. . ?C,A*

I. .. *.

._:4. j :.. t. VllIIWTV

. _- . , ,,,~ 0WF . .,._-V -fz--L V.j 'P- -#L .'4O Goat *. ..

Ie:.;: ;Y - I I 4.1 . .'.- .tSi ,.. .0 * '

-! I;.J.*

'. a2;

. _3>

- F-

~ II I L -. I U.'.

-v

-. -- .. "- ~] * -32.

i .

I'I -

I a-e 4600 pm O Bk-rs I I

=-v 11111--1 I1 I -1111 1: I I I I::

I 030 w:¢ rtfl21 Inl2Tllml rT1 2DI 28 i z 12xl6xl4.6 CVDS 24 sin 280418/19 I

I I

22 22 I

I 20 4P~Ff-20 1 10 100 1000 8000 Operaft Tkme - hours I

Calculation Number: WC-0808 Rev. Number -6. 7 and Residual Heat Removal Pump Net Positive Suction Head Margin Calculation

Title:

Following a Loss of Coolant Accident Initiating Document: STP 2000.021 VYDIC/MMrMpec. Nod other Safety Evaluation Nunber. -NA Superseded Document: N/A Implementation Required: D Yes 0 No Reason for Change:

ST? 2000-021 [1] being performed in support of the reactor water chemistry project and noble metals injection proposes to operate the RHR system in an atypical mode. Specifically, it is proposed to operate both trains of RHR, either with one pump operating in each train or two, taking a suction from the common shutdown cooling line off ofrecirculation loop "A" and injecting back into the vessel via the respective recirculation loop injecdon lines.

These modes of operation are considered a departure from normal shutdown cooling in that shutdown cooling normally utilizes only one train of RHR with a single pump operating as opposed to two trains of RHR (2]. This CCN documents the NPSH margin for shutdown cooling operation using either one or two trains.

Description of Change: See attached.

Technical Justification for Change: See attached.

==

Conclusion:==

Minimum NPSH margins for various modes of SDC are calculated:

- single train of RHR with one pump operating at 7600 gpm is 50.8 ft

- two trains of RHR with one pump operating at 7600 gpm in each loop is 48.2 ft

- two trains of RHR with two pumps (each) operating at 7300 gpm (each) in each loop is -155 ft

- two trains of RHR with two pumps (each) operating at 7300 gpm (each) in each loop with RWCU operating is -16.0 ft

- two trains of RHR with two pumps (each) operating at 6625 gpm (each) in each loop with RWCU operating is 0.5 ft 4 02-Atk LA&A No specific 50.59(aX1) or (a)(2) is required as thisDM only validates existing NPSH margins. This CGN does not justify any additional modes of operation (though may be used as a basis for other documents doing so).

Prepared BY/Date Interdiscipline Review BYDate I Review By/Date ndependent Appro By/Date I NIA VI tJ/3/1/c/ g X_

of. _ Brucec :allaghan i

• SO ~vOt e;, Cw Installation Verification I Final Turnover to DCCQ a e c.

Open Items Associated with CCN D Yes 0 No OClosed 23ct o .~"

Installation Verification (Section 23.4) 0 Calculation accurately reflects plant as-built configuration, OR

[I N/A, calculation does not affect plant configuration Resolution of documents identified in the Design Output Documents f VY 0017.07 (Section 2.3.6)

Carl D. Fago 2/ H /t i/01 Print Name S<KJSignature Date Total number of pages in package including all attachments lb Note: VYAPF 0017.07 should be included immediately following this form. VYAPF 0017.08 AP 0017 Rev. 7 Page I of I

VY CALCULATION DATABASE INPUT FORM VYC0808/I/ -Rv--7 N/A N/A VY CalculationlCCN # Revision # Vendor Calculation # Revision #

Vendor Name: N/A PO Number N/A Originating Departnment Fluid Systems Critical References Impacted- Q PSAR Q DBD 0 Reload ' Check- the appropriate box if any critical documet is identified in the tables below.

EMPAC AsseVEquipment ID Number(s): P-10-IAB/C/D EMPAC Asset/Systemr1D Number(s): 10,14 Keywords: Residual Heat Removal (RHR), Net Positive Suction Head (NPSH), Pump, Shutdown Cooling (SDC)

Por RevisiontCCN onlry Are deletions to Ceneral References, Design Input Documcnts or Design Output Documents required? 0 Yest 0 No General Reterenees

• Rcfence # ** DOC REV # "i RefmncenIdc (including Date, if applicable) (Sce App. A, Secton 32.7 for Guidimce) *** Affected Critical Prognun Refrewe M

1. STP 2000-021 Draft Noble Metals Injection Process ._____ ._.

2. OP-2124 49 Residual Heat Removal System 19 OP-2112

• 30 Reactor Water Clean-Up System VYAPF 0017.07 AP 0017 Rev. 7 4

Page 2 of 2

Design Input Documents - The following documents provide design input to this calculation. (Refer to Appendix A.sectIon 4) 04** Affected trlticai Reference #

• DOC # REV# *".Reference 7ide (including Date, if applicable) (See App. A. Section 32+/-7 for Cudance) Proera} Reference (4)

3. VYC-808 6 Core Spray and Residual Heat Removal Pump Net Positive Suction Head Margin Following a Loss of Coolant Accident

4. 202 VY Technical Specifications, Section 4.5.A

5. G19 1172 59 VY DWG, Flow Diagram - Residual Heat Removal System

6. 5920-3773 Sht 2 12 VY DWG, Assembly-Reactor for Nuclear Boiler

7. 5920-13 2 VY DWG, Arrangement - Primary and Secondary Containment

8. G-191211 16 VY DWO. RHR System Piping

9. N/A N/A Crane Flow of Fluids, Technical Paper No.410

10. 5920-6637 0 VYDWG, Residual Heat Removal Piping - Doc of As-Built Dims

11. 5920-9283 4 VY DWG, Residual Heat Removal (RHR) Part 5, Sheet 1

12. 5920-9284 3 VY DWG. Residual Heat Removal (RHR) Part 5, Sheet 2

13. 5920-9286 4 VY DWG, Residual Heat Removal (1) Part 6, Sheet 2

14. 5920-9285 4 VY DWG, Residual Heat Removal (RHR) Part 6. Sheet I

15. VYC-1628 0 Torus Temperature and Pressure Response to Large Break LOCA and MSLB Accident Scenarios

16. 5920-620 0 VY DWO, Recirculation Loop Piping-Doc of As-Built Dims .

17. VYS 98/97 N/A Memorandum, Swenson & Rainey to Mills. "Evaluation of Maximum Expected Plows for ECCS Strainer Replacement", dated August 28,1997 _

18 G191210 18 VY DWG,RHR SystemPiping Section _ _ _

Design Output Documents - This calculation provides output to the following documents. (Refer to Appendix A.section S)

Reference

• DOC* REV #

.rI I Docament~fle (including Dat if applicable)

_ _ __ Pm Affected Critalc

_ I I .  !

I I I I I I

• Reference # - Assigned by preparer to identify th reference in the body of the calcullatin.

• • Doc # - Identiangnunmber on the document if any (e g. 5920.0264,G191172, VY6.1236)

• w Reference Tide - List the spedfie docmettiodn in this colu Seetmched list"' not acceptble. DesgnptOput Domets sould identfy the spedfi design input document wued in the calculation or the specific document affected by the calculation and not simply reference the document (e&g., VYDC, MM) that the calculation was wrien to support

• 4 4"AffectedProgr.mr- Ust the affected progm or e ro tht reference is related to or pat of If the reference is FSAR. DBD or Relad (ASD or OPL), check Citical Reference column and check PSAR, DBD or Reload, at appropriate, on this form (above).

If Wyes", attach acopy of IVY Calculadon DaW marked-up toreflect deletio (See Secdtn3.1.S for Revision and S23.1S for CCNs).

I-"I VYAPF 0017.07 AP 0017 Rev. 7 Page 2 of 2 p

0 to

,? V3 1

Page of_

VY CALCULATION REVIEW FORM Calculation Number: VYC-0808 Revision Number: P 1 CCN Number: -A

Title:

Core Spray and Residual Heat Removal Pump Net Positive Suction Head Margin Following a Loss of Coolant Accident Reviewer Assigned: .Required Date: NIA 5 Interdiscipline Review 3 Independent Review Coinments* Resolution zolevi d t" a/t /,&W; s47 ,>0, ,,O p/- hpAL ta lr, (ma/ 1, W.,, I Reviewer Sihature Date Method of Review: 0 Calculation/Analysis Review' O Alternative Calculation g11tf 1 o Qualification Testing Reviewer Signature (Comments Resolved) Date

• Comments shall be specific, not general. Do not list questions or suggestions unless suggesting wording to ensure the correct interpretation of issues. Ouestions should be asked of the preparer directly.

VYAPF0017.04 AP 0017 Rev. 7 Page 1of 1

k-1r4LfM&64r fL VYC-808 Rev-e 7 rceNlwt Pg. 5 Table of Contents VY CALCULIATION DATABASE INPUT FORM .................................. 2 VY CALCULATION REVIEW FORM .. 4 1.0 Introduction ........ 5 2.0 Methodology .......... 5 3.0 Assumptions ........ 6 4.0 Analysis .... ;7 1.0 Introduction This purpose of this gAIsito afddan evaluation of RHR pump NPSH margin while in the shutdown cooling (SDC) mode of operation. Several modes are evaluated:

• one R1R train in service with one pump operating

• two RHR trains in service with one pump operating per train

• two RHR trains in service with two pumps operating per train 2.0 Methodology Available NPSH is calculated using the equation:

NPSH. = (pveue, - pX144)v + Z - Hf [Ref. 3, pg. 13]

where: pv..d = Reactor vessel pressure, psia Pr = vapor pressure of pumped fluid, psia v = specific volume of pumped fluid, ftO1bm Z = height of fluid above pump suction, ft Hf = friction head loss in suction line, ft For this particular case, the conservative assumption is pvam = Pv based on the highest possible fluid temperature conditions in the vessel, saturated liquid. Therefore, the NPSH. is simply the difference between the elevation head and the friction loss to the pump suction.

From the shutdown cooling connection on recirculation loop "A" to the RHR pump suction, the friction losses will be calculated by summing the components and pipe lengths from piping isometrics. Simplifying (and conservative) assumptions regarding certain component form losses will be made to simplify the calculation. The total IJD for this section will be determined for each pump. The friction loss for the pump with the highest LJD will be used for the NPSH calculation.

From the water source (reactor vessel) down through the downcomer outside the core shroud, past the jet pumps and into the recirculation suction nozzle at the reactor vessel and through recirculation loop "A" to the shutdown cooling connection, the friction losses will be calculated based on the results from an existing detailed, steady-state RELAP model of the reactor vessel.

The total head loss is calculated as follows:

VYC-0808 Rev..6 7 Pg. 6 hL =0.0029-f L Q [9, pg. 34]

where: hL = head loss, ft f = friction factor, nominally 0.012 for the pipe sizes relevant to this calculation [9, pg. A-26]

L_

D = equivalent length-to-diameter ratio Q = flow rate, gpm d = pipe inside diameter, inches Available and required NPSH for the RHR pumps has previously been calculated in VYC-808 Rev. 6 [3] when taking suction on the torus.

3.0 Assumptions The following assumptions are made to facilitate a simple calculation of NPSH during SDC. The assumed conditions are chosen to bound potential SDC operations when in hot shutdown

(>212 0 F).

1. The pumped liquid is at saturated conditions (i.e. Tr = Thy. This minimizes the NPSH.

which is conservative.

2. Maximum single pump flow of 7600 gpm based on the Technical Specification vessel-to-vessel requirement for RHR pump flow (7450 gpm +/- 150 gpm) (4.5.A. .c) [4].

3. Maximum two pump flow Cm one loop) of 14,600 gpm based on:

• single pump, vessel-to-vessel is 7600 gpm (above) and torus-to-torus is 7400 gpm [17] for a difference of 200 gpm

• two pump, torus-to-torus is 14,200 gpm [17]

• therefore, maximum flow for two pump, vessel-to-vessel is 14,200 + 200 gpm *2

= 14,600 gpm

4. Reactor vessel water level is assumed to be at least 155 inches above TAF. This represents a '"minimum" water level needed to preserve the NPSH margins calculated herein.

5. In calculating the system LD, all 90° elbows are assumed to be short-radius (rid ='1) elbows vice long-radius elbows. This is a simplifying assumption that maximizes the head loss and miiminzes the NPSIL.

6. Component IJD values (used in Tables 1 through 4) are obtained from previously determined values in VYC-0808 Rev. 6, Attachment 7. Also, all valves in the analyzed flow paths are gate valves. [5]

7. Branch lines of a diameter less than half of the main run diameter will be ignored (i.e.

treated as straight pipe). The losses from such a branch line are not significant when compared to the total system losses.

8. Fluid viscosity is taken at standard temperature and pressure. Actual viscosity at the higher temperature will be lower than at standard temperature. Therefore, the form losses are overestimated (conservative).

9. RWCrJ flow is assumed to be 130 gpm (65 gpm for each filter demnineralizer unit) [19].

10. The head loss through the portion of the vessel downcomer above the jet pump nozzles is negligible. This head loss component is very small when compared with the overall head loss and other conservative treatments in the calculation.

/rATTAfUEM64 fi vyC-oO Rev..w 7 Pg.7 4.0 Analysis Elevation Head The elevation head is simply the difference between the water level in the vessel, assumed to be at 155" above TAF and the elevation of the RHR pump suction.

TAF is defined as 351.5" above the vessel invert [61. The vessel invert is at elevation 266'- 1I" [7]. Therefore, the water elevation at 266'-1 1"+ 351.5" + 155" = 309.125 ft.

The elevation of the RHR pump suction is 215'-1 1" [8] (213'-9" + 2'-2").

Therefore, the total fluid elevation head is at least 93.2 ft (309.125 ft - 215.917 ft).

L mniting Pump LID The total IAD for each pump is calculated using a summary of piping lengths and components.

The summary for each pump is provided on Tables 1 through 4. Included in these tables are component I/D values per Assumption #6.

By inspection, the limiting line-up is SDC using the "D" RHR pump with a total suction-side L/D of 712.1.

• Reactor Vessel and Recirculation Line Losses The previously calculated LID does not include any losses in the reactor vessel or recirculation lines. Due to the complex nature of the geometry, the losses are not readily calculated using the standard methods presented in Crane [9]. However, a detailed RELAP model of the reactor vessel and recirculation loops has been previously developed and used for detailed VY LOCA analyses. The model is of sufficient detail that the pressure drop from some arbitrary point in the vessel to some point in the "A" recirculation loop can be approximated based on a steady-state RELAP solution. The static head difference can then be determined and subtracted leaving the unrecoverable form losses for a given flow. The losses can then be scaled to the flow rates of interest and added to the total losses for determining the NPSH.

The steady state run from VYC-1628 Rev. 0 [15] will be used as the baseline case for determining pressure drop. Figure 2.2 from VYC-1628 provides the RELAP nodalization for the baseline case. For convenience, node 274, corresponding to the top of the jet pump will be taken as the upstream location. The SDC suction is nine feet below the recirculation suction nozzle

[16]. Therefore, node 314, extending 11.4198 ft below the recirculation suction nozzle (see Table 5), will be the endpoint for the vessel pressure drop calculation. It is noted that the pressures reported in RELAP5YA output correspond to the center of the given node. Therefore, the total pressure drop and head loss do not correspond exactly to the SDC connection. However, the difference, 2.4198 ft of 28-inch pipe represents a negligible head loss when compared with the total head loss (and the total head loss in the vessel is small to begin with) and can be safely ignored.

The nodalization summary and results are shown in Table 5. The node data (pressure, temperature, flow, elevation) are taken fromr the last major edit of the RELAP output file labeled "r5bavssl.o"contained on microfiche "028YQ". Nodes with a zero elevation difference are not

VYC-0808 Rev.,@ 7 Pg. 8 included in the summary (but their effect on form loss is included in the calculated pressures from RELAP).

The pressure due to static bead is calculated from the equation:

P2 = PI+( +Z) P .g where P = pressure at the node center, psi Z = node elevation difference, ft p = fluid density, lbm/ft3 8 = gravitational acceleration constant, 32.2 ftls2

& = conversion constant, 32.2 ft-lbmtlbf-s2 The flow loss is calculated from the equation:

hL = (pa_ ) 144 The resultant flow loss from the top of the jet pumps to the SDC connection is taken as 9.5 ft for a flow of 7201.6 Ibm/sec or 68310.5 gpm at a density of 47.318 lbrnft3.

Table 5 - RELAP Summary of Vessel Downcomer and Recirculation Line Losses Density= 47.318 lb/ftA3 . Flow= 7201.6 Ibrnsec RELAP Height Head Tressure, Flow Loss Node ft psi ft stati only ft 274 3.796 1051.9 32012 1051.9 0.00 276 3.6417 1053.1 278 3.8542. 1054.4 280 2.58 10532 3205.1 1055.4 6.73 314 1l.A198 1054.6 3209A 1057.7 9.47

• Single-Train Head Loss The resulting maximum suction head loss during SDC using one RHR pump (without RWCU) is:

hL =0.00259-0.012-712.1 -7600 +9.5.( 7600 )

19.254 68S310.5)

= 9.4 ft The resultant NPSH. would be 83.8 ft (93.2 ft - 9.4 ft).

• Dual-Train Head Loss - One Pump per Train For the shutdown cooling with two trains of RHR in operation and one pump operating in each train (without RWCU flow), the NPSH margin is calculated based on double the RHR flow rate for the combined suction portion of the piping. Table 6 provides the take-off summary differentiating between the common suction and the separate loops. For conservatism, the branch

VYC-0808 Revr Pg. 9 connection where the flow separates is assumed to see full flow. The lJID for the combined suction is 311.A and the LID to the pump from the combined suction is 400.7.

The head loss is calculated as follows:

(7600.2y ~~7600 951 (6M2 hL =0.00259-0.012-311.4- 19254 +0.00259-0.012-400.71-9254 +9.5 6810

- 22.0 ft The resultant NPSH, would be 71.2 ft (93.2 ft - 22.0 ft).

• Dual-Train Head Loss - Two Pumps Per Train For the shutdown cooling with two trains of RHR in operation and two pumps operating in each train (without RWCU flow), the NPSH margin is calculated based on a maximum of 14,600 gpm per train or 7300 gpm per pump (see Assumption 3).

Table 7 provides the take-off summary differentiating between the common suction and the separate loops. For conservatism, the branch connection where the flow separates is assumed to see the maximum flow. The IiD for the combined train suction is 311.4 and the L/D for the combined pump suction is 277.3 and the IJD to the pump from the combined pump suction is 123.4.

The head loss is calculated as follows:

hL = 0.00259- 0.012 (31 1.4 .(l4600.2 +277.3.(14600Y + 123.4 (7300 ( 496. 02)V 19.25' +.. 81.

= 76.7 ft The resultant NPSIL would be 16.5 ft (93.2 ft - 76.7 ft).

It is noted that RWCU takes suction off the SDC header inside the drywell [5]. Adding this 130 gpm flow (see Assumption 9) into the combined train suction and vessel and recirculation loop flow yields a-head loss of:

h 000259 .012 (2 1 1.4 .(i4 6 0 0 .2 +1 3 0 Y +277.3.(14600Y +123A-(7300Y) i9.5. (14600.2+130) 2 19.25'6815

=77.2 ft The resultant NPSHa would be 16.0 ft (93.2 ft - 77.2 ft).

• Dual-Train Head Loss - Two Pumps Per Train - Throttled Condition Based on the results to be presented, it will be noted that the above NPSHa is inadequate to maintain a positive NPSH margin to the RHR pumps. Therefore, a throttled condition will be examined that does provide adequate NPSH margin. It will be assumed that the throttled condition results in RHR pump flows of 6625 gpm per pump or 13,250 gpm per train and including RWCU flow.

VYC-0808 RevO 7 Pg. O The head loss is calculated as follows:

h0 = 0.00259-T-+11.4-(13250-2+130Y +277.3-(13250) +123.4;(6625-9.5- (1325o2+I30))

19.25'4 68310.5

= 63.7.

The resultant NPSH. would be 29.5 ft (93.2 ft - 63.7 ft).

NPSH Margin The RHR pump required NPSH for unlimited operation at 7600 gpm is 33 ft. at 7400 gpm is 32 ft. at 7000 gpm is 29.5 ft and at 6400 gpm is 28.5 ft [VYC-0808 Rev. 6, Att. 3 pg. 51.

The minimum NPSH margin for each of the combinations analyzed above is summarized as follows:

Description NPSH1 , ft NPSHK, ft NPSH Margin, ft -

SDC, One Train, One Pump 83.8. 33 50.8 SDC, Two Trains, One Pump 71.2 33 38.2 per Train SDC, Two Trains, Two Pumps 16.5 32 -15.5 per Train, max. flow SDC, Two Trains, Two Pumps per Train, max. flow w/ RWCU 16.0 32 -16.0 SDC, Two Trains, Two Pumps 29.5 29 0.5 per Train, throttled wI RWCU

14r14ehcNt(Vr K~

VYC-0808Rev.,9 7 Pg. ii Table 1 - From Recirc Loop 'A" to RHR Pump "A' Suction Length Valves Elbows Tee Misc Reference (3rjSR9 45SLR Run Branch 20-18 Red.

Component ID - _ 8 20 11 20 60 5920-6637 Rev. 0[10] 10.5 2 2 = 1 63

____ _ _ 3.57 _

G19121ORev. 18 [181 2 6 2_ _

& G191211 Rev. 16 [8] 10 3 8 7_ v_=

5,5 5920-9283 Rev. 4 [11] 5 6 1 2 1

_ 2 8.5 3

_ _ __ __ __ _ _ _ _ 3 6.5 _ _ _

2 1 _=_

-3 2 2 2_ ___

___ __ __ _ _ _ __ _ _ _ _ _ _ 1 3-_

9 6 _ ___

5920-9284Rev.3[12] 8 6 1 2 1 1 2

__ 16 _

-2 6 __

X_______ _ _ 31 47_ _ _=

__._._, 9 6 27_ 7 _

3 Total iD-34185It 11.5i1 321 2001 221 201 180J 21 52.

A70MINeerr P VYC-0808 Revd ?

Pg. 12 Table 2 - From Recirc Loop "A"to RHR Pump "B" Suction

. Length Valves Elbows Tee Misc Refrecet in Gate 90°SR 45°LR Run Branch 20-I1Red.

Component IID - 8 20 11 20 60 5920-637 Rev. 0(101 _ 10.5 2 2 1i 63 _ =

3.57_ _ __ _ _

G19121ORev. 18 [18] 2 6 2

&G191211 Rev.'16 [8] 10 3

__ 8-7 _ _

5920-9283 Rev. 4[] 5 6 16 1 2 1- =

2 8.53_ _

3 6.5 ______

2 1 _ _

2 11 _ __ = - = =

__ __ _ _ _ _ ___ - 8 __ ___ _ _ __ _ _ _ _ _

__ _ -_ 3-8 __ = _ _

__ 9 2 _ -

4 2

_ _ __ _ _ _ _ __ _ _ _ _ 2 9 _ _ _ _ _ _

______-2___ 4 -7 _ __ _ _ -___ ____

_ _ __ __ __ _ _ _ _ 2 7 _ _ _ _ _ _

5920-9286 Rev. 4 [13] 19 3 4 1 71 3 _ = _ = =

_ _ _ _ __ __ _ _ _ _ 7 1 .5_ _ __ _ _

______ ___ _ 1 4.5 ____ _ =

_ _ __ 3 __ . _ _ _0 _ _ _ _

-7 6 =

5920-9285 Rev. 4 [14j 4 3 1 2 2 1 2

__ _ _ 3 10.5 =

3__4 6

_ _ __ __ _ 9 - *6 __ =_ _ _

3 38 __

2 10 Total IYD -198.5 12.1 32 280 33 40 ISO 180 2 677.61 '

677.6j

VYC-0808 Rev.ue 7 Pg. 13 Table 3 - From Recirc Loop "A" to RHR Pump "C" Suction Length Valves Elbows Tee Misc Referenceft in Gate 900 SR 450 LR Run Branch 20-18 Red:

ComponentUJD ___ 8 20 1 1 20 60 5920-6637 Rev. 0 [10] 10.5 2 2 1_

63 _ _ _ _ _ _ _ _ _ _ _

3.57 = __ __

G19121ORev. 18 [18] 2 6 2 _

& G191211 Rev. 16 [8] 1b 3 .

7 _: = ____

5920-9283 Rev.4[II] 5*a 6 1 1 2[ 1

__ __ _ __ __ _ _ 2 8.5 3 _ _ _ _ _ _ _ _

3 6.5 = 3

,2 1 _ = =_

_________ __ 2 -9 _ __ ___ __ ___

2_ 161 36 7

___________X 84 _ _ ____ _

___ 738 __ _ _

3_1]_

__5a8 1 2Y 943.5 60 i 2 5920-9284 Rev. 3[12] 8 61 1 2 2. 2 so___ _? __

___,s1 _

_ _ _ 961

_ __ _ __ _ _ _ ~ i O. j _ _ _ _ _ _ _ _ _6 21 9 Total DD -i 81.0111.7 32 2001 221 0 2401 21 588.8

A7/SMl r ({

vyC-0808 Rcv.ff 7 Pg. 14 Table 4 - Prom Recirc Loop "A" to RHR Pump "I)" Suction Reference Length Valves Elbows T sc ft in Gate 90° SR 450 LR Run Branch 20-18 Red.

Component LID-E _ 8 20 11 20 60 5920-6637 Rev. 0 [10] 10.5 2 2 _ .

___ -63

__ __ _ __ _ _ _ _ _3.57 G191210 Rev.18 [18] 2 6 2

& 0191211 Rev. 16 [8] 10 3 =

__ _ _ - 7 _

-5 _ _

5920-9283 Rev.4 [11] 5 6 1 1 2 - 1 28.5 3_

3 6.5 __ _

2 _

2 11=

_ _ _-3-8 _ _ _

912 412 2 2 9 4 7 _ - _ - = =

2 7_

5920-9286. Rev.4413] 19 3 4 1 I 3 = =

=_ _ 7 1.5

-1 4.5 _ _ =_ =__

_._ . _ - 7 6_

__ __ _ _ _ __ _ _ _1.5 _ _

5920-9285 Rev.4 [14] 4 1.3 1 2 1 2 2 3 10.5 _ _

4-6 6

-4

-3 -4 __ .

- 91 1

_ __ _ _ __ _ _ _ _ __ _ _ I *8 _ _

I 4.5 TotaILID -4935 11.61 321 280[ 331 201 240 21 712.11

VYC-0808 Rev., 7

.Pg. 15 Table 6- From Recirc Loop "A"to RHR Pump "D"Suction Length ValvesI Elbows Te Misc Refcifnce _t in Gate 900 SR 45°1R Run Branch 20-18 Red.

Component IMD _ 8 20 11 20 60 5920-6637 Rev. 0 (10] 10.5 2 2 1 63 _ =

3.57 _ _

G191210Rev. 18 [18] 2 6 2

& G191211 Rev. 16 [8J 1 3 _ _

~5 5 _ _ _ _ __ _ _ _ _ _ _

5920-9283 Rev. 4 (11 5 6 1 1 2 i 8.5 _

3 6.5 __.

_ _ _ __ __ __ _ _ _ _ 21 1 _ _ __ _ _

_ _ _ _ _ 2 _ _ _ _ _ - __ __ _

_2=

3 _ _ __ __ _

9 21 Full FlowIJD 4 38.0 7.3 24 100 22 0 120 0 311.4

__ __ __ _ _ _ 4 2 3 _ _ _

-2 79__3-__=

5920-9286Rev. 4 [131 191 3 = _ 4 _ 1 = =

1 S _ _3

_ _ _ _ 1 4.5_

___-76 = 1=.5

=

5920-9285 Rev. 4 [14] 4 3 1 1

_ _ _ _ __ _ _ _ _ _ - 3 10.5

-4 60 6 1 I 1 1 2 9 18

__ _____ _ _ _ _ _~-

S. 4 .5-

- I41- _ __ _ -_2 0_12C__ _ 2_04 H~alfFlow, JD 4 55.5 42 8 18 11 2 102 4 0.

VYC-0808 Revf.d6 I Pg. 16 Table 7 - From Recirc Loop "A" to RHR Pump "D" Suction Ref Length Valves Elbows Tee Misc

______ ft in Gate 900 SR 45LR Run Branch 20-18Red.

Component IJD - 8 20 11 20 60 5920-6637 Rev. 0 [10J 10.5 2 2 =_ 1

_ __ _ _ __ __ __ _ _ _ _6 3 _ _ _

_ _ _ _ __ __ __ _ _ _ _ 3 .5 7_ _ _ _ __ _ _

G19121O Rev. 18 [18] 2 6 2

& G191211 Rev. 16[8] 10 3 8 7 _

_ __ _ _ _ 5 5_ _

5920-9283 Rev. 4 [I1] 5 6 1 1 2 1 2 8.5 8m ___

38 _ _

9 .2 FuU Flow IJD - 38.0 7.3 24 100 22 0 120 0 311A 4 2 3 7 _ =_.

2, 7 5920-9286 Rev. 4113] 19 3 4 1 =

1 3 7 1.5 .

1 4.5 =__

3 _ -

7___ 6_ __

5920-9285 Rev. 4 [14] 4 3 1 3 10.5 _ _ _ _ _ _ _ _ _

___ _ _ _ _ 4 6 _ _ _ _

HalfFlowILD- 43.0 3.3 0 160 11 0 60 0 277.3 6 1i i 1 1 2 3 4 _

9 1 1 8 _4

_ u___ _Flw _LI -1 4.5 _0_9 .__20

___60_2 QuartcrFlow1IJD-* 12.5 0.9 8 Z2 0 20 602 123.4

. - 4. I of I .I

-4 ' I, I SULZER BINGHAM PUMPS INC.

SULZER BINGHAM PUMPS INC. DOCUMENT ASME CODE QUALITY LEVEL cc/-.frf~

E12.5S61 n Direc NSH J MINIM FLOW STUDY -

SUMMARY

REPORT CLASS NO.

o id F-97-10782 (30P59) CODE EDMON ADDENDA:

SALES ORDER 270839s2 and 280418/9 SEASON YEAR CUSTOMER Yankee Atomic Electrki Co. / Vermont Yankee PROJECT NPSH Stwy ofWHR CS Pumps CUSTOMER P.O. NO. -QA42M2 Na SPECIFICATION NO. NIA REVWSIM t4 CUSTOMER APPROVAL NUMER CUSTOMER APPROVAL REOUIREMENT XYES O NO 0 NeFORMATION ONLY SPACE FOR CUSTOMER APPROVAL STAMP CERTIFIED AS AVALID SULZER BINGIIAM PUMPS INC. DOCUMENT (wben applicablelva2lable) 2 For Outside Vendor El RiskRelease

- Inspection 13 For Manufacture at Report #

SulzerBingham Pumps Inc. 0 Other (specify)

CALCULAION WO-ATTACHMENT S.

INITIAL APPROVALS Date PAGE. 1 OF 19 (SIGNA Engrg. Assurance Q u illt Msluran__ _ _ _ _ _ _ _ _ _

CERTIMCATION (when spplicable) Originating This Document is certified to be in compliance Dept- HQ Engineering with THE APPLICABLE PURCHASE ORDER, SPECIFICATIONS, PROCEDURES, AND By: RolfLueneberg ADDITIONAL REQUIREMENTS LISTED IN THE APPENDICES.

Title:

Hydraulic Design Consultant Initial Date: I May. 1998 Prokcssional Enginecr APPLICABLE S.O. NUMBERS 270839/842 and 280418/9 State Registhvion No.

Date (Sea1) Control OrderNumber Rev.

DOCUMENT IDENTIFICATION

1. gernyfmWs~97-107I2c

CALCULATION WG- S-kv SULZER PUMPS I

t ATTACHMENT 5I OhWmt d War Roleq PAAF I .-_ nL )..

(IF Status Sheet For: DOCUMENT REVISOIN RECORD I I

Revision Issue ECN Location Description J By/Approved i No. Date No. J 1 05-20-98 Page 3 Item 3, Added Paragraph I Graphs Revised granhs to E12.5.522 IB and 2B

)rl &2, Al A

I. z 1<

<W fI i.

i I I I I I Initial Issue Date Status Sheet Pg. Cont. on Pg. _ Doc. I.D.

Kemy/rWndocrcdsYo doc

SULZER BINGHAM PUMPS NPSH

SUMMARY

REPORT: E12.5.561

& RHR PUMPS @YANKEE ATOMIC ELECTRIC CO SUBIJECT: NPSH/Minimum Flow - Study (Summary Report)

Yankee Atomic Electric Company Vermont Yankee F97-10782 ICALCULAT10NWV ATTACHMENT 51 SJOS'm FS Reference - 30P59 PAGE JJ_ 0Lj Detailed Report - See E12.5.522 ORIGINAL PERFORMANCE CURVE No's.:

I) 16 x 18x 26 CVIC: No. 28567 (S.O. No. 270839)

• 27922 (5.0. No. 270840) 28469 (S.O. No. 270841) 28470 (5.0. No. 270842)

SERVICE: Residual Heat Removal MM)

II) 12 X 16 X 14-t CVOS: No. 27691 (S.O. No. 280418) 27692 (5.O. No. 280419)

SERVIcE: Core Spray (CS)

1) Introduction

Purpose:

To determine the pump operability requirements for (a) minimum pump flow and (b) minimum NPSH for the hypothetical design basis accident mode of operation.

The minimum NPSH requirements are based on original pump test data and the application of SBPI knowledge and technology to supplement that data and to extend the range of the original data to higher and/or lower flow rates.

Note: This is a summary report of detailed NPSH report E12.5.522 kennylmiscfl97.10782b

II) Minimum Flowf A. Expected modes of operation under minimum flow conditions (defined by Vermont Yankee).

R - Pumps CALCULATION WC- ati.

Oto < 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 350 GPM ATTACHMENT i61 i 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 2700 GPM PAGE 4 OF Iq CS - Pumps Oto 5 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 300 GPM 2 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 1250 GPM B. Vibration Data at Minimum Flow (supplied by Vermont Yankee).

Following vibration data were supplied to SBPI:

Data for pump and motor in table - form on 14 January 1998, for REIR -Pumps at 425 and 6500 GPM for CS - Pumps at 300 and 3000 GPM Additional vibration signatures for pump and motor on 18 March 1998, for CS - pumps at 300 GPM, to complete data from 14 January, 1998.

C. Evaluation of Vibration Data RHR - Pumps Data from 14 January 1998 are acceptable for the expected modes of operation under minimum flow conditions, although the overall vibration velocities (in/sec) peak readings were taken at a minimum flow of 425 GPM in lieu of 350 GPM.

CS - Pumps Data from 14 January 1998 were not complete and indicated signs of unacceptability.

Additional vibration signatures from 18 March 1998 are acceptable for the expected modes of operation under minimum flow conditions.

tenyhnisdf97-10782b

SULZER BINGHAM PUMPS Ref: F97-10782 Page NPSH

SUMMARY

REPORT: E12.5.561 NPSH Review CS & RHR PumPs @YAWmEE ATOMIC ELECTRIC COMPANY 29 April, 1998 3 D. Basis for Minimum Flow Requirements Continuous minimum flow is a function of pump specific speed 'Ns", head per stage and suction specific speed Nss-3% (at B.E.P.).

Lower minimum flows than continuous minimum flow are possible and acceptable for shorter durations of operation, depending on acceptable vibration levels (on pump and motor) and NPSH-Margin (NPSHA vs. NPSHR-3%).

For the expected modes of operation under minimum flow conditions:

mHR - Pumps NPSHA fm Vermont Yankee NPSHA-Curve. NPSHR-3% from SBPI Curv6 No. Id.

At 350 GPM Xg a NPSHA =35.8 Feet /

NPSHR-3% = 30 Feet CALCULAllON WE 101 D.

At 2700 GPM S IATTACHMENT NPSHA = 34.5 Feet . ATTCOF PAGE 5 NPSHR-3% = 26 Feet CS - Pumps NPSHA from Vermont Yankee NPSHA-Curve. NPSHR-3% from SBPI Curve No. ild.

At 300 GPM NPSHA = 36 Feet.

NPSHR-3% = 32.5 Feet At 1250 GPM NPSHA = 35.5 Feet NPSHR-3% = 27 Feet E. Recommended Minimum Flow Requirements The recommended minimum flow modes are the same as the expected modes of operations.

RHR - Pumps O to

• 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 350 GPM

> 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 2700 GPM CS - Pumps O to

• 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> at 300 GPM 2:4 hours at 1250 GPM

• e WMh7-10782b

SULZER BINGIJHAM PUMPS Ref: F97.10782 Page

. NPSH

SUMMARY

REPORT: E12.5.561 NPSH Review CS & RHR PUmPS @YANKEE ATOMIC ELECTIC COMPANY 29 AprO, 1998 l 4 X1 )PTS A. Expected modes of operation under minimum NPSH conditions (defied by Vermont Yankee).

Based on the operating conditions and the NPSHA per May-Witt Decay heat diagrams the expected modes are as follows:

RUR - Pumps at 7000 GPM CALCULAllON WO 205 t' 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> with NPSHA of 23 to 24 f APTAGEME OF 1 Plus 5 additional hours with NPSHA of 24 to 26 ft.

Plus 5.5 additional hours with NPSHA of 26 to 28 ft Plus 3.5 additional hours with NPSHA of 28 to 29 ft.

CS - PUmpS at 3000 GPM 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> with NPSHA of 24 to 25 ft.

Plus 2.5 additional hours with NPSHA of25 to 26 ft.

Plus 2.5 additional hours with NPSHA of 26 to 27 ft.

Plus 3 additional hours with NPSHA of 27 to 28 ft.

Plus 6 additional hours with NPSHA of 28 to 30 ft.

B. Discuss pump performance based on original test data (included original data and curves)

The RHR - and CS - pumps have been NPSH-tested over a limited flow-range. No head-drop was specified on the original curves.

RIR-um s: B.E.- Flow at 6200 GPM -

The most complete NPSH-Test was performed on Pump No. 270840 at maximum impeller diameter of 26.5 in.. NPSH-tests were performed at 6300, 8065 .and 9502 GPM (See T-270840-A). 5 to 8 tests points were taken at each of the above capacities to establish the slope and shape ofNPSH vs. Head. Purpose of the 'witness' tests were to demonstrate that the pump met the contractual requirements.

Witness - tests for each pump with a trimmed impeller diameter of 25.563 inch, only 2 to 3 NPSH - tests points were taken at capacities of approximately 6300, 7200, 8500 and 8900 GPM.

These tests are not complete enough to determine the exact NPSH-characteristics of the pumps. The duration of the witness - test of each pump, including flow from 0 to runout, pressures, head, RPM, efficiency, power and NPSH took between I and 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

tcnnyiSd97-1C7S2b

SULZER BINGHAM PUMPS Ref: F97-10782 Page NPSH

SUMMARY

REPORT: E12.5.561 NPSH Review CS & RHR PUMPS @YANKEE ATOMIC ELECTRIC COMPANY 29 Apr, 1998 5 This implies that the pumps were running only a few minutes with reduced NPSH. This is sufficient time to observe pump behavior at reduced NPSHA. In addition, no vibration readings were taken during these short duration NPSHA tests. A more thorough representation of the complete NPSHR characteristic is test T-270840-A. See SBPI CurVe 4 1wthc.

The difference in NPSHR due to impeller tpm does not have a significant influence 2 °with these pumps.

CS-Pumps: B.E.P. - Flow at 3750 GPM The most representativeNPSH-Testwas performed during TestNo. 176101 at 13.81 inches and 13.00 inches impeller diameters. It was a pump for a different order, but an identical pump. NPSH - tests were performed at approximately 1780 RPM.

Converted to 3582 RPM, by using the affinity laws, the flow rates were 3005,4037,5038, 5120, 6000,6020 and 6524 GPM (see T-176101-DIG). 4 to 10 tests points were taken at each of the above capabilities to establish the slope and shape of NPSH vs. Head. These tests are sufficient to develop NPSHR characteristics for the pump and are representative of the units delivered on the above serial numbers. Trim diameters have been factored in the developed NPSHR curves.

The most complete and representative test T-176101-D/G. (see also SBPI Curve No.Hc).

1. Relationship to "Knee" of Pump Curve When plotting the results of an NPSH-test (NPSH vs. Head), starting with ample NPSH, the head will either stay constant, vary or drop slightly with reducing NPSH. At some reduced NPSH value, the head will fall off more quickly before falling off totally.

This defines the "Knee" of an NPSH-test.

The knee may be very sharp, that means 1%, 3%, 6%/e, etc. head-drop will occur at about the same NPSHA value. Operation near or close to this type of knee is not recommended. The knee may also bc well-rounded, that means 1%, 3%, 6% etc. head-drop will happen at different NPSHA values. To develop the shape of the NPSHR knee several test points are required.

2. Similarity to Other Pumps Used In Nuclear Application Pump designs provided for the above services are found in other nuclear installations in the same or similar applications. They are basically of similar style and design, but may differ in nozzle and maximum impeller sizes. There are pumps of same specific speed, suction specific speed and impeller inlet design features (NPSH).

3. Relevant Operating Experience of Similar Pumps at Minimum NPSH Operating conditions at various nuclear stations vary, however similar units to those furnished have been supplied to other installations with similar reduced NPSH levels during a nuclear incident. Similar reviews have been conducted for them.

• ey/tfl Sd97-10782b

SULZER BINGHAM PUMPS Ref: F97.10782 Page NPSH

SUMMARY

REPORT: E12.5.561 NPSH Review CS & RHR PUMPS @YANKEE ATOMIC ELECTRIC COMPANY 29 April, 1998 6 Specified "normal" operating conditions (NPSHA) are not that close to NPSHR-3% or NPSHR-6%.

Operating for short durations at NPSHIR-3% to NPSHR-6% should not be detrimental to the pump life in this service.

4. Cavitation-Tests performed on same or similar pumps and conclusion from those tests.

Cavitation (NPSH) - Tests have been performed on same pumps or similar pumps that have been used on the NPSH-study for Vermont Yankee.

NPSH-Test on same pumps is T-270840-A (RHR-Pump) and T-176101-D/G (CS-Pump) for discussion and conclusion see I3B.

NPSH - Tests on similar pumps are used to establish tendencies and extrapolation of NPSH-Curves. (See SBPI Curve No. Id & lId). Similar pumps are of same suction specific speed, number of vanes and suction vane inlet angles.

5. Acceptability of the units in their specified services.

REHR - PumPs:

When operating for seven (7) hours at 7000 GPM with NPSHA of 23 to 24 fee, the pumps will be in the cavitation mode. The head-drop will be above 6% but the NPSHA is still greater than the original minimum operational NPSH (See SBPI Curve No. Ic and Id). The pumps, if operated with the minimum NPSH, are within acceptable limits of the NPSH "knee".

The pumps will remain acceptable following the "Postulated Accident Scenario" and operation under reduce NPSH conditions, providing NPSHA > NPSHR-3%.

CS - Pumps:

When operating for seven (7) hours at 3000 GPM with NPSHA of 24 to 25 feet, the pumps will be in the cavitation mode. The head-drop however will be less than 3% (see SBPI Curve No. rIc and lid). The pumps, if operated with the minimum NPSH limits, have adequate margin prior to the NPSH "knee".

The pumps will remain acceptable following the "Postulated Accident Scenirio" and operation under minimhum NPSH conditions, providing NPSHA > NPSHR-3%.

keMyWSCM7-107 2b

SULZER BINGHAM PUMPS NPSH

SUMMARY

REPORT: E1l25.561 C. . Extrapolation to higher/lower flows using test date from other sources.

1. Technical Basis for Extrapolation When pumps have been NPSH-tested for a small flow-range only (Vermont Yankee) and NPSH-data are required outside this flow-range, the NPSH-curves have to be extrapolated. OnlyNPSH-tests of'pumps of similar style, design, specific speed, suction specific speed, impeller number of vanes and suction vane angles can be used for this purpose.

2. Pump data selected and similarity to Vermont Yankee pumps I H -Pum-p-s:

Following pump sizes have been used to extend NPSHfR to lower flows (see SBPI curve No. Ia):

18 x 24 x 28 CVIC 8 x 10 x 21 CVIC CS'- Pumps-Following pump sizes have been used to extend NPSHR to lower flows (see SBPI curve No. Hla):

12 x 14 x 14'12CVDS 14x 16x23 CVDS

3. Predicted NPSI at lower/higher flow rates as extrapolations of original test data In this case, the minimum flow rates are extremely low:

RHR-Pumps: 350 GPM A 3 5 0 xl 0 0 = 5.6 % of B.B.P. Flow 600 3

CS-Pumps: 300 GPM -3 00 x I 0 0 = 8.0 % of B.E.P. Flow 3 75 0 No NPSH-tests of same or similar pumps are available at these low percentages of BE.P. flow.

Extrapolation to these low flow rates based only on estimation and experience of NPSH-tests on other style ofpumps. Experience comes from NPSH-tests which have been performed in recent years, when more detailed NPSH-tests were required.

Extrapolation for higher flow rate NPSHR is not necessary since sufficient test data exists for these flow rates. If extrapolation for higher flow rates is necessary a similar method will be used.

kenny/misdf97-1072b

SULZER BINGINAM PUMPS Ref. F97*10782 Page NPSH

SUMMARY

REPORT: E12.5.561. NPSH Review CS & RHR Puwps @YANKEE ATOMIC ELECTRIC COMPANY 29 Apri, 1998 8 D. Basis for Minimum NPSH Recommendations

1. No Permanent Pump Damage Due to Cavitation Depending on water temperature and water chemistry there can be some 'frosting' (e.g.

light pitting) on the impeller suction vanes, but there will be no detrimental pump damage due to cavitation when operating at minimum NPSH for the specified hours of operation.

This applies mainly to the RHR-pumps when operating for seven (7) hours at 7000 GPM with NPSHA of 23 to 24 feet. It will apply to a lesser degree to the CS-pumps when operating for seven (7) hours at 3000 GPM with NPSHA of24 to 25 feet.

2. Operation above the "Knee" of the Pump Curve Maintaining the minimum NPSH values is a "must" when operating near or at the NPSHR knee. For continuous operation this is essential, since small variances in product temperature can suddenly reduce the NPSHA. Provided the NPSH values are supplied for the RHR and CS services and durations, at these values limited, operation at the NPSHR "knees" are acceptable.

Short-Term Operation at the "Knee" is acceptable providing temperature is controlled.

3. Conformance to Original Pump Requirements and Extrapolated Requirements, as defined herein These pumps meet the original NPSHR requirements as specified. The original pump NPSH requirements were not well defined. The result was only two (2) NPSH-Test points for each capacity were measured. From two (2) NPSH-test points it is not possible to establish the "knee". At each NPSH-test point (during witness tests) the pumps were operating only a few minutes and the capacity-range was limited. This was not considered critical since similhr pumps of the saxife hydraulics had been comprehensively tested.

The extrapolated NPSH requirements apply mainly to a fiow regime of 350 and 2700 GPM for the RHR-pumps and 300 and 1250 GPM for the CS-pumps as described under lI.c.3. Due to unknown suction vane profile and clean-up onNPSH-margin as described under ILd is required.

kemymscif97-iO7S2b

SULZER BINGHAM PUMPS Ref: F97*10782 Page NPSH

SUMMARY

REPORT:- E12.5.561 NPSH Review CS & RHR PUMPS @YANKEE ATOC ELECTRIC COMPANY Apri, 1998 9 E. Recommended Minimum NPSH Requirements

1. Acceptable durations of operation:

. PJHR-Pumps:

At minimum flow of350 and 2700 GPM: as described under ll.d and ILe.

U; o At 7000 GPM: as shown on SBPI Curve No. E12.5.522-2B CS-Pumps:

At minimum flow of 300 and 1250 GPM: as aescribed under II.d and Uf.e.

At 3000 and 4600GPM: es shown on SBPI CurveNo. E12.5.522-IB c E- 2. Purpose of this report.

This report and ievie* was conducted to clarify test results taken approximately thirty (30) years earlier. It is also intended to provide additi6nal understanding regardfit the limits of these machines both hydraulically and mechanically. These machines are suitable for the services they were originally supplied to, however they must operated within the agreed limits.

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VYC-808, Revision 6, Attachment 6 Page I of 4 YANKEE ATOMIC ELECTRIC COMPAN saxSo Core Spray NPSK Evaluation PPEPARM BY . .DA7,_ FLNEMW BY -DEMWWORKOEDERNO. 4922 5.0

References:

(b) Drawing, 5920-9209, Core Spray (CS) Part 3 Ic) Technical Paper No. 410, Flow of Fluids Through Valves Fittings and Pipe, Crane Co., 2 4 th Printing, 1988 d)Gould. Pump Manual, d Pma Inc., a-II X.Y.,? 1973 \ 9 W

e Curve for Core Spa+ a#20041Bf8 i ngham Pump Co. r ve Mos.

27691 92 -

ME)Drawing lCB ), 6202-233, Torus Pen rations VINPS FSAR, FYig. . 1 (h) D ing, G-191206, Cor ray System Pipig P1 \

(1{l)1Lnu iG-191207, Cre Sp te P Secti

'ping i., \  !

m T he) ropertyed of neyes inan Ste D aed le d So e

\ YX1;<1959 \\. \t (m) Hydraulic Inatitute Engineering Data Book, Ist F4.

VYC-808, Revision 6, Attachment 6 Page 2 of 4 uir1of~tP.~,AtQL~4&(TJ I YANKEE ATOMIC ELECTRIC COMPANY WtNUC~EUJ 4q2 SPURET Core SYray NPSH Evaluaton pyATEDDY V8TE 3tEVIWD By h DA

6.0 Calculation

6.1 Suction Piping Lengths Each Core Spray ptcp takes auction from its own Torus penetration. The two suction piping paths are essentially "mirror images".

6.1;1 Torus to CS Pump piping:

Pipe sire - 12" STD [Ref.(a)]

Piping Lengths lRef.(b)l Feet Inches 0.0 2.5

• 1.5 9.0 6.0 3.0 3.5

-- 0.5 6.0 4.0 6.0 5.0

11. 5 Total 30 5S.5 or 34.875', say 35' 6k]

• VC-808, Revision 6, Attachment 6 Page 3 of 4 YANKEE ATOMIC ELECTRIC COMPANY -

PREPAF8 By o&1ET~._EVMMa BY O&TE,_WCJORK ORO No. 4922 6.1.2 Fittings tRef. (b) I L/D ( Ref. (c) I 900 LR 16"X12- Red. Elbow 14 (Note 1) 450 LR Elbow 11 [Ref. (M)I 67 1/20 LR Elbow 14 (Note 1) g00 LR Elbow 14

,900 LR Elbow 14 TEE (Str. Run) 20 161x12 Reducer (Exp.) 7 Valve, Gate (CS-7A) . a Lfl-L. 1:j a Total Total equiivalent length (12') pipe - 35 4-16-W- /~t30~Z' Nlote 1: Conservatively assumed same *a 900 LR Elbow.

VYC-808, Revision 6, Attachment 6 Page 4 of 4 YANKEE ATOMIC ELECTRIC COMPANY Core Spra NPSH Evaluation PREPAPED DA1E. VEWwDB bY DATEU_ >WORKOrVERNO. 4922 6.1.3 Correction to Sched. 40 [Ref.(c)I 12" STD  : I.b. = 12.00k 12" SCR 40 : I.D. - 11.938" dPa w dP40 ( D4 0 5 t Da 5 ) [Ref.c), e B-153 Therefore, dPSTD - dP40 C 11.9385 / 12.005 3 - dP 4 0 (0.974)

Equivalent length Sched. 40:

L40 - Lam ( 0.974)

- 14C0.974)*

6.2 Friction loss:

f = (L)(hf) [Ref.(c)]

e 3000 gpn, h' 0.731 psi/100l, (60 °F fE3000 ' ft.)f 0.731 pai/100 ft.) 2.31 ft./pai jp. ft.$

For other flow rates:

8fl _ Hfo0 Q 12 Q2 )

Note: This is slightly conaervative for Q1 > Q0 , but difference is insignificant in the range of interest.

VYC-808, Rcvision 6, Attachment 7 Page I of 12 YANKEE ATOMIC EMCTIC COPA StBr Residnal Eoat RPibval (LPC1) UPSH Evaluation

.VI.AFOY DAE .E1D..KVEWWtY *DAl.E WORUDER NO. 4922 5.0 Roferencess v (a) Drawing, G-191172# rlov DLagrm - U*sidual Beat Rmoval System r (b) Drawing, 5920-9284, Residual Beat Removal (RM Part 5.

V (ca) Technical Paper No. 410, now of rluids Through Valves rittings and -Ppe, Crane Co., 2 4 th Printizq, 1988 (d) Goulda 95an ,Gould Pups Inc.

a Seneca Falls K. 1973 (e) p Curve for UR~ 270841, Ding Punp Co., Curve o. 28469 (f) Dr ing (CD S10, 6202 33, Torus Penetra ons (g) Vfl4PS\ AR Fig. 5.2-1 DrawLng, 191211, R Cyst< Piping Sections l)rwin G-90, R8RIM cs ~ Plan\\

t5 s l rte of Ste vbnan an eyauh cy and So 17ea

/ k) ftandook of Hy~draulic Resistance, I.E.Idelchik, 2nd Ed., Nemiphere PublisLhing Co.,, New York, 1986 (1) draulic Institute Engineering Data Book, ~t, Ed.

• l 4

VYC-808, Revision 6, Attachment 7 Page 2 of 12 cQWimic 801t R 4s -~.51 FA ILW YANKEEATOWC ELERIC COMPAY A VMcT PResldual Itat Remowal (LPCI) NPSh Evaluation FWED __ _. WWKOfNOO 4922

6.0 Calculation

6.1 Suction Piping Lengths two bII pumps take auction from one Torus penetration therefore a portion of auction piping In common to both pumps from the Torus to a Tee at which point there is a single branch to each p Both the a and a PRa loops are mirror B.

image Jo the calculation need be done for only one loop. (A and C pump loop.)

'By inspection of the piping isometric drawings it is noted that there are'none asall differenoes in the single auction lines the moat significant of which is that one has a straight run at the Tee while the other il a branch run. The run with the greater loss will be used for conservative results.

6.1.1 Cacon piping Torus to Tee 24- pipe.

Pipe 4ize - 24", 0.375 wall. 1.D. - 23.25; (STD.) [Retf.(a)

Piping Lengths [Ref.(b)l Peot lnches 1 2.62S 3 6.125 T 0.0 t otal S 8.75 or 8.73 ft.

Li^

iI

. I

VYC4O80, Revision 6, Attachment 7 Page 3 of 12 VEW3WMDM=M0WIN YANKEEATOUJCELECMHCCOMPANY CWW~l C16 I~-

WGtT ResIdual Beat Remova1 (1.PC) YPSH Evalaucat-6.1.2 rittings L/D CpRff. (C) I 330 L Elbow 7 (eetimated) 900 SRP Ibow 20 26"x24 Rlducer iExp.) 1 Il t1 Total r or eclt~q~

iraient 6.1.3 Correction to Sched. 40 ( 20) 24" SWD  : I.D. m 23.25" 20" S 40 t I.D. - 18.824" a dP40 ( D4 0 S I D. 5 IRtef. (a) e D-151 Therefore, dPSTD - dP40 ( 18.814 5 1 23.25 5 ) dP 4 0 (0.347)

Equivalent length Sched. 40:

L4 0 C34734)7 1 0Ls*

0 .73 4/ 0.347) 4.

i 4

. I

VYC-808. Revision 6, Attachment 7 Page 4 of 12

• VENWMnOiinovvc-NTOIf 7 jMVFJS YANK A70MCELECRCCOMPAN CMAUT M.

US= Ml1dtal Heat Nwoval (tWcZ) WP$sn Evaluation PfAEP D5Y OMW R WT.SYM .WOfXC. aNO 4922 6.1.4 Common piping Tous to Toe 26- pipe.

Pipe Jize - 26", 0.375 wall. I.D. - 25.250 (Ref. (a)I PIping Lagths ERef. (b) I Feet Inches 1 4.125 2 8.25 17 10.125 5 5.5 2 2.0 6 0.0 4 3.0

• 2 0.0

1. 3.0 Total 40 36 or 43.00 ft.

6.1.5 Fittings LID (Ref. (c) X 450 jj Zlbow 11 tRef. (3)I 450 LR Zbow 11 (Ref. ()3 HoD SR Elbow 20 900 SR Zbow 20 Total 62 or 130.46 ft. equivalent

VYC-808, Revision 6, Attachment 7 Page 5ofl12 CAUU gy' og YANKEEATOMIC ELEMCTRCCOMP Y ueo -r ~

SUSJE= Residual Bleat R~emoval (.P.CX) "PSa fivaluation PFV'~IED SY__________ W mvL W&j .W~fjOADrKaOF 4922 6.1.6 Correction to Scbed. 40 e 20" 1 26" SWD  : I.D. - 25.25" 20' ScM 40  :.D. -18.814" dPa - dP40 (D 40 5 / V) 5 ) i~ef . (c) e B-2si Therefore, dPSTD - d14 0 C 18.814 / 25.25 A dP40 (0.230)

Equivalent length Scbed. 40s L4 0 tSD (0.230)

A C 43.00 4 130.46 ) (0.230) - 39.90' 6.1. 7 SoT t pipiag . . 40 eqplvalent

• zLS t~~t)/.2i\ - -

LOON 0r54W+ 39.90 - (20"-Sch.40) 6.1.6 Single pipizg Tee to Pp A 26' Pipe sise - 26', 0.375 wall. X.D. - 25.25 . CI"C. (a) I Plplizg lengtha [1POf (b) I reot Xnches 3 10.0 2 5.5 2 3.5 Total *1 19 or 8.50 ft.

VYC-808, Revision 6, Attachment 7 Page 6 of 12 YANKEE ATOMIC ELECTRIC COMPANY ______

SUV TResidual Beat Removal (LPC) WPSiH Evaluatlon PIUWP FADAET Y lO WOOAOD6R NO. 4922 6.1.9 Fittings L/D Tee (Str. Run) 20 900 SR Elbow 20 100 LR Elbow 1 (estiated) 261x20 Reducer 17 Total 58 or 122.04 ft. equivalent 6.1.10 Correction to Sched. 40 ( 20w )

26, STD  : I.D. - 25.25w 200 SCH 40 :X.D. - 10.6140 dP, - dP40 D4 0 S / 1, 5 ) (Ref. (cl 6 D-1S5 Therefore,.

dPSTD) dP4 0 ( 18.814 5/ 25.25 S ) dP4 0 (0.230)

Equivalent length Sdled. 40S L40 LjSD (0.230)

( 89.58 + 122.04 ) (0.230) - 30.04'

VYC-808, Rcvision 6, Attachment7 Page 7 of 12

.5 JNI4_5

• YANKEE ATOMIC ELCRC COMPANY CXCULA r.NO1

$LBT Residual Beat rmoval (LPM) WPSH Evaluation FI$IEVIEtW~~ ATEL . .WOnKCODHERNO 4922 6.1.11 Sngl1e Piping Teo to Pump A 200 Pipe size a 20-, 0.375 van. I.b. w 19.25" [(Rf.(a)I Piping Lengths Ref. (b)]

Feet inch"s 1 '8.0 3 7.0 3 5.0 2 11.0 2 7.0 3 5.0 Total 14 43 or 17.538 ft.

.6.1.12 Fittngs LID tRef.(c) I 0

90 SR lWMn 20 Valve (10-13A) ,Gate t Y 900 SR rlbow 20 2 2 Tee ff ( 0x20QStr. rin) 20 T oeo (20x4z20,Str. Run) 1 [Ref. (k)I 0

2 'X18" Reducer 2 (estimated)

Total 71 or 113.90 ft. equiivalent

1-WC-808, Revision 6, Attachment 7 LY Page 8 of l2 VWONM DESIMBMGM.

Cu~g~ Novr, 1$ -

YANKE ATOMIC ELEMIC COMPA VW=T Residual neat H~nwyval (LPCI) "WSH Evaluation FIEPMAlt. ME E . WOWKflENQNO.D8Y 4922 6.1.13 Correction to Sched. 40 X 20' 200 STD' .  : I.D. - 19.25' 200 SCW 40  : Z.D. - 18.814' dPa a dEP40 ( D40 S5 Da 5 [Ref. (c) 90 -153.

Therefore, dPSTD - dP40

• 16.814 5 / 19.25 5 ) dP40'(0.892)

Equivalent length Sched. 40:

L40 LS(T (0.892)

( 17.56 + 113.90 ) (0.S92) - 117.28' 6.1.14 Totar bingla pipingr ee to Pump X 20' 8ched. 40 equivalent .

LT-A - 30.04 + 117.28 - 147.32'.

I

VYC-808, Revision 6, Attachment 7 Page 9 of 12

-VERNO

'

• NWYAM ENIGNO J e, 5 . .

YANKEE ATOMIC ELECTRIC COMPANY CAMU__ __

Vcr Residual Heat Pwemoal (T&M) NWSR Evaluation ARM B _____ . WOFC ORDER

. 4922 6.1.15 Single Piping Tee to Pump C 20" Pipe aize - 200, 0.375 wall. I.D. - 19.25' .Ref.(a))

piping engtb3 Ref.b .

reet Inches 2 3.5 0 9.5 2 10.0

3. 4.0 3 4.0 3 0.0

.1 10.5 2 9.0 Sotal 16 50.5 or 20.21 ft.

1DtRof . (e) I Tee (Br. Run) SO 90° SR Elbow 20 Valve (10-13C),Gate .

0 9O SR Elbow 20 Teo (20x20x20,Str. Run) 20 Tee (20x4x20,Str: Run) 1 CRef.()

20'xlB VAducer 2 (estimated) 10° LR Elbow I Total 132 or 211.75 ft. equivalent

ml VYC808, Revision 6, Attachment 7 Page 10 of 12 CNAMOSGN0N5 1 G cWoitfawc.a AJ1cwa Fr~w~/bE YANKEE ATOMIC ELcTRI COMPANY CNACNUX _

Wl Residual neat Btgwoval (X) WS evaluation pWMAIW gy BOf 4922 6.1.17 Correction to Sched. 40 ( 20" 3 2 0 u SW  : I.D. -19.250 20" Sm 40 sl.D. 18.814' dPA - dP 40 ( D40 5 / D, 5) (Ref. (c) e 9-151 Therefore, CIPSM - dP40 ( 18.814 5 / 19.25 S )

• dP4g (0.892)

Equivalent 1ingth Sched. 40:

140 LSTD (0.892)

- C 20.21 + 211.7S ) (0.892) - 206.91' 6.1.18 Total aingle piping Tee to Pump C 20" Sced. 40 evalent

.LT-c - 206.911  :

6.1.19 Piping Swmary - reuivalent reet 20" Sched. 40 Torua to Tee (Coc), (LoC01) - >

Tee to 1.

p At ( -A) - 147.32' A..

Tee to Plup C, (LC - 206.91' Pump C has the longer rtn ; use for conaervative result.

6.2 ?riction Loss 1 f-omnoa + RE single Head 103l In coOn lIlne wil depend on Mber of ps ooperating. IA33e that If both ptuV are operating they are operating at the aame flow rate.

Consider two configurations : One pum operation (Case I), and two pump operation tCase II).

t.et- ¶. ..

VYC-808. Revision 6. Attachment 7 Page II of 12

• ~VERMffTWMUDE=B=MW

• ' cGu~ OBvo mrr, YANKEE ATOMIC ELECTRIC COMPANY W Residual neat Removal (LPCr) WPSU Evaluation DW~n BY .E VE Y DA1E _ _WCO(fER NO. 4922 Case I friction Loss:

B£ - Of comn + f single and aU fb I Qa22 b2 ) CRef. (c)I as a function of flow where Qwoum ' QOangle for Case I.

(Note: This is slightly conservative for 0Q < Qb , but difference In not sLgnificant in range of interest.)

2 fl - xfco 0 2 to ) + Hgf. (0 2 / QO2 )

where .fco - friction loss at Qg for the coon piping and l Xfo- friction los at 0g for the single piping ror QO 7000 gp9, friction loas for 20" Schod. 40 pipe Ia 0.376 psL per 100',

(Reg.(c)3 9

fcO HJ fO*

(H5vg2 ( 0.376 /100 ) (2.31 ftipai)-t "*,

'T-C

-fo ( f 0)

- ( 206.91 ) ( 0.376./ 100) (2.31 ft/psL) 1.80' zoX "B 0 +fs co 4 0o 1.60 4'M4O 7000g therefore, .

N1 1 Q2, 70002 ) 4O-8 0 g2

/ .

VYC-808, Revision 6, Attachment 7 Page 12ofl2 MUMW. -ycS-YANKEE ATOMIC ELECTIC OMPANY SUW Residual Reat Renaoval (WCI) UPSR Evaluation PPREPBY "VA1E EWt B~DAW.1EWOW eORD *O~ ' 922~

Case II Friction Loss 0

u - 8f coon Of single and Elfa - f ffb oDa2 / QbF2 f WI 0

as a famction of flow wbere ,oXo - 2 °iangle o Case rr-2 "fIIx i cO (C O2 'f3O

+ ( Q2 Q02) where Bfco friction loss at QO for the comon piping and

• fsO friction loss at for the single piping f0 For 00 u 7000 gpW to"e pump flow), friction loss for 20" Sched. 40 pipe La 0.326 psi per 100' *Ref. (c) ror Q0 -14000 gym (two pump flow), friction lose for 20" Scbed. 40 pipe is 1.43 psi per 100' [Ref.(c)l

- Rt 1.43 /190 ) (2.31 ft/psl) afso " Lr-f (B0)o.

- ( 206.91 ) ( 0.376 /100 ) 32.3,£2pri) - 1.80' tfor- 9fcO + HfaO - 4.016-, 1.80 ' e 7000gm per pp tberefore KmI 4 Qc2. / 140002 ) + 1.8O ( QS2 1 70002 )

and for Q;-20O 20 1t gg S )2 / 140002 + 1.80 S2 70002 )

=f-&0-l2 + 3.673.10-8 Q2 i

VYC-0808, Revision6, 4GN 06, Attachment.A 9 ENN-DC-126, Re: 4 I MINOR CALCULATION CHANGE I PAGE 1 OF6 Excel Verification Sample Calculation Table 4.1 CS Verification (Line 40):

Cell G40 =$F$30

= 12.47 Cell H40 = 0.00000025*$F$9A2

= 0.00000025*4600^2

= 5.29 Cell I40 = $F$17

= 0.51 Cell J40 = ROUND(IF(C40<173,0.32*(173/C40),0.32),2)

= 165.1<173 = True

= 0.32*(173/C40)

= 0.32*(173/165.1)

=0.34 Cell K40 =+((14.7-E40)*144*F40)+G40-H40-I40-J40

= ((14.7-5.349)*144*0.016423)+12.47-5.29-0.51-0.34

= 28.44 Cell L40 =$F$33

= 28.00 Cell M40 =IF((+IAO-K40Y(144*F40)>0,(+L40-K40)/(144*F40),0)

=(28.00-28.44)/(144*0.016423) = -0.186<0, False

=0 Cell N40 = +D40-14.7

= 17.64-14.7

= 2.94

Table 4.2 CS Table Verification (Line 50):

Cell F50 = $F$25

= 12.57 Cell G50 = 0.00000025*$F$9A2

= 0.00000025*3500^2

= 3.06 Cell H50 0.38*(($F$9/4000)A2)

= 0.38*((350014000}^2)

= 0.29 Cel] 150 = ROUND(IF(B50<173,$F$18*(173/B50),$F$18),2) 194.3<173 = False (For True outcome see below, Cell 172)

= $F$18

= 0.21 Cell I72 = ROUND(IF(B72<173,$F$18*(173/B72),$F$18),2)

= 162.9<173 =True

= $F$18*(173/B72)

= 0.21*(173/162.9)

= 0.22 Cell J50 = +((14.7-D50)*144*E50)+F50-G50-H50-150

= ((14.7-10.233)*144*0.016599)+12.57-3.06-0.29-0.21

= 19.687 [Worksheet shows 19.68 - Check OK - difference attributed to significant figures used in hand calc vs Excel]

Cell K50 = $F$28

= 29.6 Cell L50 = IF((+K50-J50)/(144*E50)>0,(+K50-J50)I(144*E50),o)

(29.6-19.68)1(144*0.016599) = 4.15>0 True (For False outcome see below, Cell L34)

= 4.15 Cell I34 = IF((+K34-J34)I(144*E34)>0,(+K34-J34)1(144*E34),0)

= (29.6-29.73)/(144*0.016449) = -0.055>0 False

=0 Cell M50 = +C50-14.7

= 22.42-14.7

= 7.72

Table 4.2 RHR Table Verification (Line 78):

Cell P78 = $C$25

= 12.40 Cell G78 = 0.0000000477*$C$9A2

= 0.0000000477*7400A2

= 2.61 Cell H78 = $C$15

= 0.33 Cell 178 = ROUND(IF(B78<173,$C$18*(173/378),$C$18),2) 169.7<173 =True (ForFalse outcome see below, Cell 181)

= $C$18*(173)B78)

= 0.33*(173/169.7)

= 0.34 Cell 181 = ROUND(EF(B8l<173,$C$18*(1731B81),$C$18),2) 180<173 = False

= $C$18 -

= 0.33 Cell J78 = +((14.7-D78)*144*E78)+F78-G78-H78-178

= ((14.7-5.951)*144*0.016449)+12A0-2.61-0.33-0.34

= 29.84 Cell K78 = $C$28

= 31.7 Cell L78 = IF((+K78-J78)/(144*E78)>O,(+K78-J78)1(144*E78),0)

(31.7-29.84)/(144*0.016449)=0.785>0 True (For False outcome see below, Cell LI 16)

= 0.785 [Worksheet shows 0.78 - Check OK - difference attributed to significant figures used in hand calc vs Excel]

Cel L116 = IF((+K116-JI16)/(144*E116)>0,(+K1 16-Ji16)/(144*E116),0)

= (31.7-31.84)1(144*0.01641 1) = -0.059>0 False

=0 Cell M78 = +C78-14.7

= 17.71-14.7

=3.01

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A47rd4 cMyAW)1 r P4 e,10~5 a General Eldci Company GE NuclearEnergy 175 CurtnerAvenue, San Jose CA 05125 September 13, 2004 Action Requested by: NA GE-VYNPS-AEP-363 Response to: Reference 3 DRF 0000-0007-5271 Project Deliverable: NA GE Proprietary Infomation cc: G. Paptzun Y. C. Chu B. Hobbs (ENOI)

To: Craig Nichols (ENOI)

From: Michael Dick Author: Michael Dick

Subject:

VYNPS Extended Power Uprate - ATWS Analysis Sensitivity to Condensate Storage Tank Water Temperature Change

References:

1. Entergy Nuclear Operations Inc., Vermont Yankee Nuclear Power Station, Asset Enhancement Program, GE Proposal No. 208-lJX8XA-HB1, Revision 5, dated November 13, 2002.

2. Entergy Nuclear Operations, Inc. Contract Order No. VY015144 (Asset Enhancement Program).

3. Letter PUPVY-04445, dated September 9, 2004 "Evaluation of EPU ATWS Analysis (T0902) for CST Temperature of 135F" Reference 3 requested GE to perform an evaluation of the sensitivity of the VYNPS ATWS analysis results to a change in CST temperature. The attachment to this letter provides the results of this evaluation.

P1,e-om e v.O1 GE-VYNPS-AEP-363 Revision 0 September 13, 2004 A signed copy of this letter is included in DRF 0000-0007-5271. Supporting technical information and evidence of verification for the attachment to this letter are contained in eDRF Section 0000-0032-4266.

MJD Attachment

1. Vermont Yankee CST Temperature Increase for ATWS Events

Xn-4ealr 9 1yQe-O.Pe' 9.01 8 GE-VYNPS-AEP-363 Revision 0 1o47 e -5 S Page 1 of 7 i

ATTACHMENT 1 GE-VYNPS-AEP-363 Vermont Yankee CST Temperature Increase for ATWS Events

d 7rZ Cll'/d-Xr 9 vye-°Mea /4e'. Rs GE-VYNPS-AEP-363 Revision 0 Attachment I 1/49 '

Page 2 of 7 1.0 Task Objective The object of this evaluation is to assess the impact of increased Condensation Storage Tank (CST) temperature on the ATWS evaluation for Extended Power Uprate (EPU) project. The original CST temperature used in the EPU analysis is 117 0 F (Reference 1).

The ATWS analysis indicates that all acceptance criterion for reactor pressure vessel, peak cladding temperature (PCT), clad oxidation, suppression pool temperature and containment pressure are met. However, the CST temperature was subsequently determined to be 1350 F (Reference 2). This evaluation is to provide justification to support that all the ATWS acceptance criterion can be met with the increased CST temperature.

2.0 Evaluation The preferred high pressure make up water is drawn from CST and delivered to the reactor vessel through High Pressure Core Injection (HPCI) and Reactor Core Isolation Cooling (RCIC) systems after an isolation ATWS event. However, the initiation of the HPCIIRCIC flow starts after the peak vessel pressure and PCT have passed. The increase of CST temperature has no impact to these parameters and the clad oxidation. Therefore, the vessel and fuel integrity is not affected by the CST temperature change.

An increase of 180F in CST temperature can reduce the core inlet subcooling. This causes an increase of the core voiding and the reactor power will decrease during the period when vessel water level is being controlled at Top of Active Fuel (TAF). The steam generation rate is reduced. However, the change in the CST temperature is small and only reduces the steam generation rate slightly. After the hot shutdown boron weight is injected into the vessel and the reactor has achieved hot shutdown, the decreased inlet subcooling allows more steam generation by the decay heat. Similarly, the change of steam generation rate is not significant. These two competing factors tend to cancel each other out. The net change in the peak suppression pool temperature with an 180 F increase in CST temperature is expected to be less than 0.5 0F. Subsequently, the peak containment pressure should change no more than 0.2 psi. With a margin to suppression pool limit of more than 40 F (190"F vs 194.7 0 F limit) and an even larger containment pressure margin, the CST temperature increase poses no significant impact to the containment integrity during ATWS events.

In conclusion, an increase of 18'F for CST temperature in Vermont Yankee has insignificant impact to the ATWS events in EPU conditions.

GE-VYNPS-AEP-363 Revision 0 Page 3 of 7 3.0 References

1. GE-NE-0000-0016-383 1-01, "Project Task Report, Entergy Nuclear Operations Incorporated, Vermont Yankee Nuclear Power Station, Extended Power Uprate, Task T0902 Anticipated Transients Without Scram", Rev. 0, July 2003.

2. Letter, C.J. Nichols to M. Dick, PUPVY-04-455, "Evaluation of EPU ATWS Analysis (T0902) for CST Temp of 135F," September 9, 2004.