ML18040A254

Forwards Proprietary & non-proprietary Repts from GE Re GL 94-03, Intergranular Stress Corrosion Cracking in Bwrs. List of Repts,Encl.Encls Withheld,Per 10CFR2.790(b)(i)

ML18040A254
Person / Time
Site:	Nine Mile Point
Issue date:	04/08/1997
From:	Mccormick M NIAGARA MOHAWK POWER CORP.
To:	NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
Shared Package
ML17059B487	List: ML17059B486 ML17059B488 ML17059B489 ML17059B493 ML18040A254
References
GL-94-03, GL-94-3, NMP1L-1200, NUDOCS 9704100242
Download: ML18040A254 (94)

Text

4,~+r I-CATEGORY 2 REGULAT ZNPORMATZON DISTRIBUTION'STEM (RIDE)

ACCESSION NBR:9704100242 DOC.DATE: 97/04/08 NOTARIZED: YES FACIL:50-220 Nine Mile Point.,Nuclear Station, Unit 1, Niagara Powe AUTH;NAME AUTHOR AFFIL'I'ATION I

MCCORMICK,M.J.

Niagara Mohawk Power Corp.

RECIP.NAME RECIPIENT AFFILIATION Document Control Branch (Document Control Desk)

DOCKET 05000220

SUBJECT:

Forwards proprietary a non-proprietary repts from GE re GL 94-03, "Intergranular Stress Corrosion Cracking in BWRs." List of repts,encl.Encls withheld,per C

10CFR2.790(b)(i).

~A DISTRIBUTION CODE:

APOID COPIES RECEIVED:LTR /

ENCL L SIZE:

TITLE: Proprietary Review Distribution Pre Operating License

& Operating R T NOTES:

RECIPIENT ID CODE/NAME PDl-1 LA HOOD,D COPIES LTTR ENCL 1

1 1

1 RECIPIENT

.ID CODE/NAME PD1-1 PD COPIES LTTR ENCL 1

1 INTERNAL: ACRS OGC/HDS3 EXTERNAL: NRC PDR ILE CENTER 01 1

1 1

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NOTE TO ALL "RIDS" RECIPIENTS:

PLEASE HELP US TO REDUCE WASTE. TO HAVE YOUR NAME OR ORGANIZATION REMOVED FROM DISTRIBUTION LISTS OR REDUCE THE NUMBER OF COPIES RECEIVED BY YOU OR YOUR ORGANIZATION, CONTACT THE DOCUMENT CONTROL DESK (DCD)

ON EXTENSION 415-2083 (P

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ENCL

NIAGARAMOHAWK C E N E RAT I 0 N BUSINESS CROUP NINE MILEPOINT NUCLEAR STATION/LAKEROAD, P.O. BOX 63, LYCOMING,NEW YORK 13093/TELEPHONE (315) 349-2660 FAX (315) 349-2605 MARTINJ. McCORMICKJR. P.E.

Vice President Nuclear Engineering April 8, 1997 NMP1L 1200 U.S. Nuclear Regulatory Commission Attn: Document Control Clerk Washington, DC 20555 RE:

Nine Mile Point Unit 1 Docket 50-220

Subject:

Generic Letter 94-03 "Intergranular Stress Corrosion Cracking (IGSCC) in Boiling Water Reactors" Gentlemen:

By letters dated January 6, 1995 and January 23, 1995, Niagara Mohawk Power Corporation (NMPC) submitted an application for repairs to the Nine Mile Point Unit 1 (NMP1) core shroud. The shroud repairs and use of stabilizer assemblies (tie rods) were submitted as an alternate to the requirements of the ASME Code,Section XI, as allowed by 10CFR50.55a (a)(3)(i). The staff provided approval of the proposed alternate repair by letter dated March 31, 1995.

The approval letter and attached safety evaluation required NMPC to submit re-inspection plans for the shroud and repair assemblies prior to the next refueling outage planned for 1997.

By letter dated February 7, 1997, NMPC submitted plans for re-inspection of the core shroud vertical welds and repair assemblies in accordance with the criteria provided by the "BWR Vessel and Internals Program" (BWRVIP) document BWRVIP-07.

During the 1997 refueling outage, NMPC conducted core shroud vertical weld inspections per the approved documents and observed vertical weld cracking which exceeded the screening criteria. Additionally, inspections of the four tie rod assemblies found the tie rod nuts to have lost some preload and identified damage to the lower wedge retainer clips on three tie rods.

Further details of the as found conditions are provided in Enclosures 1 and 2.

l(

By phone calls on March 20, 1997 and April2, 1997, NMPC informed the staff of the inspection findings and indicated that analysis of the vertical weld cracking and restoration plan of the shroud tie rod assemblies would be submitted to the NRC prior to restart of the unit. This letter and the attached enclosures provide root cause, corrective actions and the final design documentation which establishes the acceptability of the as found vertical weld

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Page 2 cracking for a minimum of 10,600 operating hours (above 200'F), determines an appropriate weld re-inspection schedule, provides details of the actions taken to restore the tie rods to the as designed condition and describes a modification of the lower wedge retainer clip design.

The modified lower wedge retainer clips are part of the tie rod assemblies which, as noted above, are not included under the ASME Code Section XIdefinition for repair or replacement.

As such, the design details of the modified retainer clips are being submitted to the staff for review and approval as an alternative repair pursuant to 10CFR50.55a (a)(3)(i). The enclosed analyses provide justification'for continued operation of NMP1 during the upcoming cycle utilizing the updated 10CFR50.55a approval as proposed herein.

Enclosures 1, 2 and 5 are considered by their preparer, General Electric (GE), to contain proprietary information exempt from disclosure pursuant to 10CFR2.790.

Therefore, on behalf of GE, NMPC hereby makes application to withhold these documents from public disclosure in accordance with 10CFR2.790 (b)(1). An affidavit executed by GE detailing the reasons for the request to withhold the proprietary information has been included in Enclosure

7. A non-proprietary version of these documents has been included with this letter as.

I.

Core Shroud The NMP1 core shroud has four GE core shroud stabilizer assemblies installed.

These assemblies were installed during the RFO-13 (1995) refueling outage.

The installation was done as a pre-emptive repair of the core shroud horizontal welds Hl through H7 in lieu of baseline shroud inspection of these horizontal welds.

The GE shroud stabilizer design requires vertical weld integrity in order for the shroud stabilizers to satisfy the design basis assumption of horizontal welds Hl through H7 being through wall cracked 360'.

The pre-and post-shroud repair installation inspection scope during RFO-13, included a sample inspection of the vertical welds at the intersection of a selected high fluence weld (the H5 weld). The inspection included 6 inches above and below the H5 location along the V9, V10, V11 and V12 welds.

The inspection was an enhanced visual examination performed from the inside diameter (ID). This visual examination was intended as a sample inspection.

This inspection scope was approved by the NRC as part of the safety evaluation report (SER) issued for the NMP1 core shroud stabilizer design.

The inspection of the NMP1 vertical welds in the current refueling outage (RFO-14) was performed consistent with the BWRVIP-07 guidelines for the reinspection of BWR core shrouds.

These guidelines also utilized a sampling

Page 3 approach for the vertical core shroud welds. The option selected by NMPC was to complete a visual inspection of 25% of the equivalent total vertical weld length from either the outside diameter (OD) or ID. As part of the inspection plan, GE defined screening criterion for minimum required uncracked vertical welds on a per weld basis.

The ring segment welds were excluded from the vertical welds requiring inspection based on GE analysis of the ring segment welds submitted to the staff for review by letter dated February 7, 1997.

As a result of inspection findings, the inspection scope was expanded using an enhanced visual inspection method supplemented by ultrasonic inspection (UT).

B.

The initial RFO-14 inspection of the vertical welds identified cracking over the entire OD length of the V10 weld using enhanced visual inspection techniques.

The inspection plans were then expanded to establish minimum required uncracked ligament on the vertical welds which are required to meet the shroud stabilizer repair design basis assumptions.

The vertical weld cracking evident on the OD of both the V9 and V10 welds was extensive.

The extent of cracking identified on the OD had not previously been identified at other BWRs. As a result, a complete baseline inspection of the NMP1 accessible portions of certain core shroud horizontal and vertical welds was performed in order to establish an overall material condition assessment of the NMP1 core shroud.

Detailed descriptions of both vertical and horizontal welds cracking is provided in Enclosure 1. The individual inspection results have received N.D.E. Level IIIreview by GE and NMPC personnel.

The documentation ofinspection results is being compiled for final quality assurance review. This review willbe completed by April20, 1997.

C.

This shroud baseline inspection has enabled NMPC to establish that the cracking at the vertical welds V9 and V10 is consistent with the expected IGSCC cracking ofBWR core shrouds. Both the horizontal weld cracking in the beltline H4 weld and the vertical weld cracking in the beltline V9 and V10 welds is occurring in the heat affected zone (HAZ)of the welds. The assessment of the IGSCC cracking is included in enclosed analyses and reports. Several independent evaluations were also performed for NMPC to obtain an accurate assessment of the cause and acceptability ofvertical weld cracking.

These evaluations have concluded that the cracking noted on the vertical welds V9 and V10 is IGSCC. The stresses that cause cracking in the vertical welds are weld residual and fabrication stresses and to a lesser extent the stress resulting from internal pressure (hoop stress).

The NMP1 shroud horizontal and vertical welds are clearly susceptible to IGSCC.

The high carbon Type 304

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Page 4 stainless steel material was initiallysensitized by the welding process.

The material's susceptibility was further enhanced by surface cold work and surface strains from the fabrication process.

Irradiation would also add to the susceptibility over the operating time. Finally, the tensile surface residual stresses and surface fabrication stresses led to the IGSCC initiation.

The inspection data from UT of these welds has established the cracking depth.

The pattern of crack depth is consistent with the calculated fluence axial and radial profiles, The estimated fluence for these welds is in the 2 to 4.5 x 10" n/cm~ () 1 MEV). This fluence places these welds in a range for which the radiation enhanced IGSCC conditions exist. The evaluations performed have concluded that the observed cracking is associated either with weld HAZor sites where fabrication related welding or grinding was apparent.

The overall conclusion is that this cracking is not unique and can be attributed to welding residual stresses and fabrication fitup induced stresses.

D.

The baseline inspection has identified one location at the intersection of H5 and V9 where a horizontal crack in the HAZofH5 has linked with a vertical crack in the HAZof V9. This case is isolated and has not been identified in other locations. In fact, the majority of the cracking appears to start approximately 6 to 10 inches down from the horizontal H4 weld HAZ. The shroud horizontal and vertical weld baseline inspection of the NMP1 core shroud which has been performed provides a point of reference for future sample inspection of the core shroud. This baseline and future sample inspections willallow NMPC to monitor the actual IGSCC crack growth rate which willbe used to maintain the required design basis margins.

GE has completed analyses regarding the potential impact the core shroud stabilizer assemblies could have on vertical weld cracking. The results have shown that any hoop stress induced at the vertical welds due to shroud stabilizer thermal preload is negligible. The overall conclusion is that the shroud stabilizers had no effect on the shroud vertical weld cracking identified at V9 and V10.

The vertical weld 9 and V10 cracking was reviewed by independent experts in IGSCC cracking ofBWR core shrouds. contains the results of a qualitative assessment of the visually observed cracking on the H4, V9, V10 and H5 welds. This evaluation has concluded that the IGSCC cracking is similar in nature to the cracks seen in other BWRs and that the specific conditions for the particular cracking patterns can be explained by normal fabrication practices used in manufacturing the core shroud.

In an effort to better define how these fabrication processes can explain the cracking, detailed finite element modeling have been performed.

Overall the results show that the

Page 5 welding and fabrication process can explain the cracking pattern observed on the vertical welds.

These analyses calculated through-thickness stress intensity solutions and crack growth studies.

The results clearly support the bounding analysis approach being used to define the proposed operating interval between inspections.

E.

An analysis of the vertical welds used to define the proposed shroud vertical weld reinspection interval has been performed consistent with approved BWRVIP shroud analysis methods.

The criteria applied are those set forth in the BWRVIP core shroud inspection and evaluation document.

The approach being applied for the vertical welds analysis assumed that all horizontal welds are cracked 360'hrough wall consistent with the core shroud stabilizer design basis.

The assumption of horizontal weld 360'racking requires sufficient vertical weld integrity to ensure that the design basis assumption of stacked right cylinders is maintained. The analysis approach relies upon sizing of the through wall vertical weld cracking with UT. These through thickness cracks have been analyzed consistent with the BWRVIP core shroud inspection and evaluation guidelines accounting for ASME Code Section XI safety factors, design basis loads, inspection uncertainty consistent with the BWRVIP-03 guidelines, and the currently bounding NRC core shroud crack growth assumption of 5 x 10 ~

inches/hr.

Based on these assumptions, the required core shroud re-inspection interval has been determined to be at least 10,600 operating hours as described in Enclosure 1.

The attached analysis of the vertical welds includes an assessment of the potential leakage from postulated through wall vertical cracking. The overall thermal hydraulics assessment has concluded that the leakage would be negligible. The overall conclusion is that this leakage has no impact on the design basis for normal upset or accident conditions. The attached Enclosure 1

provides the required detailed discussion on this subject.

In conclusion, the vertical weld cracking condition has been reviewed and been determined to not represent an unreviewed safety question based on applying the NRC approved core shroud inspection and evaluation guidelines. These guidelines provide the analysis basis to define an acceptable inspection interval based on as found IGSCC cracking of core shrouds. The required interval established by the attached analyses is 10,600 hours0.00694 days <br />0.167 hours <br />9.920635e-4 weeks <br />2.283e-4 months <br /> of operation.

Page 6 II.

Core Shroud StabBizer Assemblies (Tie Rods)

A.

During the current refueling outage, post-operational inspections were conducted on the core shroud stabilizer (tie rod) assemblies, Tie rod deficiencies were found, including improper as found torque on the tie rod nuts, and damage to the retainer clips on the lower spring wedges.

These findings resulted in root cause evaluations and additional inspections and testing of the tie rods.

B.

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~ contains the detailed data on the as-found condition, root cause of those deficiencies, validation of the root cause and corrective actions taken.

Gaps were identified on the clevis pin to lower support hook contact and under the tie rod nut to top support contact. It was determined that preload of the tie rods had been lost, to some degree, on each tie rod. Also, the lower spring wedge retainer clip was broken at the 90'ie rod location and visibly damaged at the 270'nd 350'ie rod locations.

The 90'ie rod lower spring wedge was found bottomed on its guide rod, not in contact with the vessel as originally installed.

The remaining contact points, springs and retainer clips were found in their proper positions.

C.

The root cause for the tie rod degradation is attributed to recognition that the tie rod design did not consider the effect of installation tolerances for the lower support bolt holes.

Because of this, the installation procedures did not contain specific criteria for the location of the toggle bolts during installation of the lower support.

The lower support toggle bolts are nominally 4.000" in diameter.

The measured electric discharge machining (EDM) holes in the shroud cone ranged from 4.090" to 4.110".

Since the position of the lower support bolts within the machined holes was not procedurally controlled during installation, the relative position of the bolts within the holes was variable.

During heatup, the expansion of the shroud and tie rods generates a force sufficient enough to overcome the installed friction forces and move the lower support up the shroud cone.

This translates into a vertical movement of the tie rod. This movement was sufficient to apply a load on the lower spring wedge retainer clip such that it failed within one cycle of operation.

Additionally, the lower spring wedge retainer clip was not designed to accommodate differential movement given the frictional loads between the vessel wall and the lower spring wedge during normal and transient conditions.

Page 7 D.

Subsequent to these findings and root cause evaluation, an installation procedure was developed to restore the tie rods to their original design basis condition.

Each tie rod was jacked at three locations during tie rod nut torquing to remove any gaps associated with installation tolerances.

Jacks were placed under the lower support, on the vessel side of the lower support to push it up the shroud cone to remove the clearances between the toggle bolts and the shroud side of the cone holes.

Following performance of the revised installation procedure inspections were completed on each tie rod to verify the absence of gaps, proper contact and position.

As a result of these inspections, it was discovered that the middle support was no longer in contact with the vessel on the 90'nd 166'ie rod.

This was caused as a result of the lower support assembly being moved up the cone towards the shroud.

The middle support dimensions are being retaken and new middle supports willbe installed prior to reload.

Other locations on the tie rod assemblies with the potential for gaps and non-conforming conditions were inspected.

No additional deficiencies were noted. A summary of NMPC's 10CFR50.59 safety evaluation concerning modification to the core shroud repair tie rod assemblies is provided in Enclosure 4.

E.

Calculations were performed to evaluate the maximum potential displacements of the tie rod relative to the lower spring wedge.

This resulted in a redesign of the lower wedge retainer clip. The modified design is described below and accommodates expected movements.

The new retainer clips willbe installed during the current refueling outage.

The clips have been fabricated from X-750, analyzed in accordance with the ASME Code, and meet original design criteria for the tie rods.

F.

The function of the lower wedge retainer clip is to retain the lower wedge in the proper position during installation. It was not designed to experience operational loads.

Lower wedge to vessel contact was assumed to move and accommodate differential thermal expansion between the tie rod assembly and the vessel.

As explained in Enclosure 2, the friction force between the wedge and the vessel was sufficient to prevent movement of the wedge during thermal growth of the tie rod assembly.

The latch portion of the retainer clip became loaded resulting in the overstressed condition of the retainer clip and its subsequent failure.

Page 8 The retainer clip has been redesigned to accommodate movement during normal and transient conditions.

The redesigned retainer clips willbe installed prior to reload., "Design Report for Improved Shroud Repair Lower Support Latches," provides the results of an evaluation performed for the redesigned latch and demonstrates acceptability of the redesigned latch and its use in the original tie rod assembly.

III.

Further Actions NMPC has analyzed the as found condition of the shroud vertical welds and has established that the plant can be operated safely. A conservative interval for re-inspection of the welds has been established as described in Enclosure

1. Re-inspection, including tightness checks of the tie rod nuts, willbe performed after approximately 10,600 hours0.00694 days <br />0.167 hours <br />9.920635e-4 weeks <br />2.283e-4 months <br /> of operation and NMPC will have plans for a contingency repair should one be needed at that time. NMPC plans additional analyses, during the upcoming cycle, which may justify extension of the re-inspection interval for the shroud vertical welds.

The results of these analyses willbe submitted to the NRC, if appropriate.

A boat sample of cracked material willbe mechanically removed from a shroud weld HAZat an appropriate location prior to restart from RFO-14.

As a longer term action, NMPC plans to perform analysis on the sample to establish the presence of IGSCC, the age of the cracking, whether crack growth has arrested and to investigate any other potential contributing mechanisms.

This metallurgical sample is to be used to help NMPC and the industry better understand the IGSCC cracking of the BWR core shroud vertical welds.

IV.

Inspection of Other Internals NMPC has performed inspections over the operating life of the plant to meet several ASME Code, industry, BWRVIP and Augmented Regulatory requirements.

These inspections provide the basis for an overall condition assessment of the RPV internals. Specifically, the inspections performed during the current refuel outage on the internal core spray annulus piping and core spray spargers, showed no crack growth of previously identified indications on the spargers. The annulus piping was found to be without flaws, including the critical welds at creviced locations.

A summary of inspections performed to date of other internals is provided in Enclosure 6.

NMPC has performed an evaluation of the tie rod restoration activities and the as found condition of the vertical welds and found them acceptable for continued service.

NMPC requests approval of the final design documentation for the proposed modification of the tie rod retainer clips by a revision to the existing NRC shroud repair safety evaluation

Page 9 submitted as an alternate repair under 10CFR50.55 (a)(2)(i). Receipt of NRC approval is requested by April20, 1997.

Very truly yours, Martin J. McCormick Jr.

Vice President - Nuclear Engineering MJM/MSL/lmc Enclosures xc:

Mr. H. J. Miller, NRC Regional Administrator, Region I Mr. S. S. Bajwa, Acting Director, Project Directorate I-l, NRR Mr. B. S. Norris, Senior Resident Inspector Mr. D. S. Hood, Senior Project Manager, NRR Records Management

UNITED STATES NUCLEARREGULATORYCOMMISSION In the Matter of Niagara Mohawk Power Corporation Nine MilePoint Unit j.

Docket No. 50-220 Martin J. McCormick Jr., being duly sworn, states that he is Vice President - Nuclear Engineering of Niagara Mohawk Power Corporation; that he is authorized on the part of said Corporation to sign and filewith the Nuclear Regulatory Commission the document attached hereto; and that the document is true and correct to the best of his knowledge, information and belief.

Martin J.

cCormick Jr.

Vice President - Nuclear Engineering Subscribed and sworn before me, in and for the State of New York and the County of Q~~e this 8-day ofApril, 997.

NOTARYPUBLIC JOHN C JOSH Notey Public,8tete ofSee Yo4 No.4837303 CueINed In Gsveeo Cemty Commission Expfres Feb. 28, 19qe

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INDEXOF ENCI OSURES ENCLOSURE 1 Assessment of the Vertical Weld Cracking on the NMP1 Shroud ENCLOSURE 2 Shroud Repair Anomalies, Nine Mge Point Unit 1, RFO14 ENCLOSURE 3 Nine MilePoint Unit 1 Core Shroud Cracking Evaluation ENCLOSURE 4 10CFR50.59 Safety Evaluation 96-018, Revision 1 ENCLOSURE 5 Design Report for Improved Shroud Repair Lower Support Latches ENCLOSURE 6 Inspection History ENCLOSURE 7 Affidavit(GE)

ENCLOSURE 8 Non-Proprietary Version of Reports

ENCLOSURE2 SHROUD REPAIR ANOMALIES NINE MILEPOINT UNIT 1 RFO14

..9704100242

ENCLOSURE 4 10CFRSO. 59 SAFETY EVALUATION 96-018, REVISION 1

0

10 50.59 SAFETY EVALUATIONSU RY MODIFICATIONTO THE CORE SHROUD REPAIR STABILIZERASSEMBLIES Ashroud repair modification was installed in Nine MilePoint 1 Nuclear Power Plant to provide an alternate load path for the Type 304 stainless steel circumferential welds, Hl through H7. The modification ensures the structural integrity ofthe core shroud by replacing the function ofwelds Hl through H7 with 4 stabilizer assemblies and four core plate wedges.

In the course ofthe post-installation inspection ofthe shroud repair, three deviations were identified, evaluated and were found acceptable for continued plant operation through the next cycle. After additional review and evaluation, additional modifications are proposed to provide the long term corrective actions.

During the spring 1997 refueling outage, two additional deficiencies were found on the shroud repair hardware. Each ofthe four shroud repair stabilizer assemblies were found to have less than the original installation preload and one ofthe lower wedge latches had failed inservice. Two other lower wedge latches also appeared to be degraded. The latch is a wishbone shaped piece, that is intended to prevent relative motion between the lower wedge and the lower spring with the assumption that sliding would occur between the lower wedge and the RPV wall. The deviations were found during required augmented In-service Inspections gSI) and du'ring the planned replacement ofthe shroud stabilizer assembly at 270'.

The root cause ofthe stabilizer vertical loss ofpreload was due to clearances between the lower support toggle bolts and the holes in the shroud support cone. The importance ofthe clearance between the toggle bolts and the hole was not recognized and not incorporated into the installation engineering documentation. This allowed the lower support to move up the shroud support cone toward the shroud when the plant reached normal operating conditions. The root cause ofthe latch failure is an incorrect design assumption regarding sliding at the vessel to lower wedge interface. A detailed discussion ofthe as-found condition ofthe stabilizer assemblies and the root cause ofthe deviations is included in Reference 27.

This evaluation considers the addition ofthe three modifications described below and how these modifications afreet the Safety Evaluation for the Core Shroud Repair Design, Reference 23, 31 and 32.

The references in Part E retain the same numbers with additional references applicable to the modifications.

~difzatiga 3. The lower spring ofone stabilizer assembly bears on the blend radius ofthe 270'ecirculation nozzle. The proposed modifications is to replace the tie rod and spring assembly with one having the spring on the opposite side ofthe tie rod. This proposed modification relocates the spring to bear on the RPV as intended.

Madii@~ 2 The lower spring contact with the shroud do not extend beyond weld H6A at any ofthe four locations.

As result, the barrel section between welds H5 and H6A is not laterally restrained during a steam line LOCA combined with a DBE as was intended.

The proposed modification adds an extension piece to extend the spring contact beyond weld H6A and restore this feature to its intended function. The extended contact and the core plate wedges also provide an redundant load path between the core plate and the lower spring as was intended in the in the original design.

Page 1 of17

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The above two noted moa cations have been reviewed and approve by the NRC in Reference 32.

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IP the axial tightness ofthe stabilizer assemblies.

The lower wedge latches may become loaded due to differential vertical displacement greater than intended by the original design ofthe latches.

There are two corrective actions. The first is to remove the clearance between the toggle bolts and the shroud support cone. This has been accomplished with the Reference 28 procedure. The removal ofthe clearances restores the stabilizer assemblies to their originally intended design and does not represent a modification.

The second corrective action was to install new modified latches which are more tolerant ofdifferential vertical displacement.

A.l

~0'ollowing the installation ofthe core shroud repair a visual inspection ofthe as-installed assembly hardware showed the lower spring wedge on the 270'tabilizer assembly bearing on the blend radius of the recirculation nozzle.

The wedge was intended to bear on the RPV wall.

The proposed modification is to replace the tie rod and spring assembly with one having the spring on the opposite side. The modification moves the spring sufficiently such that itwillbear on the RPV originally as intended.

The modification utilizes. existing hardware which was built as a spare along with the other stabilizer assemblies.

Only minor rework is required to relocate the lower spring and the rework has no affect on the hardware function. The modification does not require additional penetrations through the shroud support cone or any additional EDM work. The modification uses the same lower support and upper spring assemblies and there is no change to the actual tie rod location.

Additional analysis has been done to address the design where the lower springs are no longer located 90'part.

The non-uniform lower spring spacing affects the net spring characteristic when the horizontal seismic load is directed between two springs.

The analysis show the loads and displacements remain acceptable for all conditions.

A.2

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The lower spring contacts with the shroud do not extend above the H6A weld as was intended.

The design function can be restored by adding a U shaped extension piece to extend beyond weld H6A. The extension piece fits over the existing lower contact with the legs ofthe U extending around the sides of the existing lower contact.

The steps at the ends ofthe legs fitunder the lower contact to prevent axial movement. Atang at the top extension fits in the gap between the lower contact and the lower spring to restrict the horizontal movement.

The added extension piece is captured in all directions on the existing lower contact.

The legs ofthe extension are spring loaded to provide a positive clamping force against the sides ofthe lower contact.

The spring force is not required to capture the part but is sufficient to prevent any free movement or vibrations. With this arrangement, the added extension piece is captured in all directions and is held secure by the spring loaded clamping force.

The hardware for both modifications is designed and fabricated to the same design basis (Ref. 1) as the original shroud repair hardware.

The design life ofall repair hardware willbe for twenty-five years (the remaining lifeofthe plant, plus life extension beyond the current operating license), to include 20 Effective Full Power Years.

The modified stabilizer assembly includes the same design features as the original hardware. Allparts are locked in place or captured by mechanical devices.

The stresses in the stabilizer do not change and Page 2 of 17

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remain less than the allow e stresses.

The repair hardware is fabricated from intergranular stress corrosion resistant material. There is no welding in the construction or installation ofthe shroud repair hardware.

The fast flux levels at the stabilizers are well below the damage threshold which could result in the degradation ofmaterial properties.

After 25 years ofoperation, the maximum fast fluence at the shroud repair components willbe well below the value to cause damage.

Therefore, it is very unlikely that a component willfail.

A >

LAXCE The design ofthe new improved shroud repair lower support latches have been analyzed in detail in Reference 30. The design ofthe new latches maintains the original design function. The function ofthe original latch was to secure the wedge to the lower spring. This is'primarily needed when the wedge looses contact with the reactor vessel wall. This is an important function since the wedge willotherwise slide down and create excessive gaps.

The new latch design maintains the wedge support capability and can readily support the dead weight and flowforces which could act to push the wedge down. The new latch design incorporates another spring which can tolerate vertical displacements.

Therefore, the original functional requirement is accomplished while adding more flexibilityin the vertical direction to accommodate vertical displacements. Under the most probable operating and sliding conditions the new latch design is expected to perform satisfactorily for the remaining life ofthe plant. Even for worst case postulated conditions, the latch is capable ofoperating without failure throughout the next operating cycle.

The new latches can tolerate a difFerential vertical displacement for the worst case thermal transient event (loss offeedwater event) without experiencing an overstress condition. Also for normal plant operation, the maximum vertical difFerential displacement under probable wedge interaction conditions (assuming no slippage between the RPV and the wedge) is 0.10 inches.

Under this deflection the stresses in the new latches willbe less than the stress limitestablished to prevent stress corrosion in X-750 material for a 40 year lifetime. A comparison ofthe original latch design to the new design has been performed using common finite element modeling methods.

The results show that the new latch is 8 to 12 times more capable oftolerating vertical displacements than the original design.

This order ofmagnitude improvement in the design provides assurance that the new latch willperform satisfactorily in the next operating cycle.

The'removal ofthe clearance between the toggle bolts and the shroud support cone willassure that the tie rod vertical forces willbe as intended in the original design. The vertical clearances in the stabilizer assemblies were eliminated using the procedure included in Reference 28. Each ofthe four stabilizer assemblies were then torqued to the original required installation value. With the tie rod in a tight condition at startup, the proper vertical thermal expansion loads. can be accomplished during the heatup ofthe reactor, and maintain the hold down forces on the shroud through subsequent heatups and cool downs.

A.4 The installed stabilizers tie rods are fabricated entirely from the type 316, 316L stainless steel (both with a carbon content less than 0.02%) or alloy X-750. The added contact extension and modified latches are fabricated from alloy X-750. The replacement components for the 270'ie rod modification willbe fabricated using the same materials as the currently installed stabilizers.

The fabrication requirements for the two proposed tie rod modifications willbe in accordance with the previously approved fabrication requirements for the NMP-1 core shroud stabilizers.

There is no welding required during fabrication or installation.

Fage3of17

B hKLLYSIS:

The applicable criteria and conformance for this analysis is as follows. The criteria is the same criteria that was used for the original Shroud Repair Design Safety Evaluation, Reference 23. The conformance sections specifically address the three proposed modifications.

B.1 Ihsiga LifeKritaig:

The design lifeofall repair hardware willbe for twenty-five years (the remaining lifeofthe plant, plus life extension beyond the current operating license), to include 20 Effective Full Power Years.

B.1.1 Rgmiz Ihsign LiR The hardware for the three modifications is fabricated to the same design basis, including material requirements, as the original shroud repair hardware.

Allrepair hardware has been designed for a design lifeoftwenty-five years (the remaining lifeofthe plant, plus life extension beyond the current operating license), to include 20 Effective Full Power Years. This requirement is documented in reference l.

Assuring an adequate design life is mainly a material selection and process control effort, for this equipment.

The selection oflow carbon stainless steels and high nickel alloys assures'the best available materials for the nuclear reactor environment. Solution annealing and sensitization testing are imposed to guard against inter granular stress corrosion cracking (IGSCC). Process chemical controls are imposed to assure that contamination by heavy metal and chlorine or sulfur compounds willnot occur. This is the same design selections and controls imposed for a standard forty year phnt life. There is nothing in the equipment or installation that puts a specific limiton how long it can be used, such as creep or radiation degradation.

The stresses in the latch are within ASME code limits and the latch is analyzed to be resistant to stress corrosion for a minimum of2 years assuming conservative worst case displacements in the retainer.

It is fullyexpected that the retainer willlast for a significantly longer time based on the factor ofimprovement which has been demonstrated from the original design. For the expected sliding case where the movement is always along the wedgdspring interface, the retainer willlast for a least the remaining lifeof the plant. The retainers willbe inspected at the next outage to determine which type ofsliding is occurring in order to validate the service lifetime ofthe retainers.

B 2 Saki'eHgu Bmh {Crhczig:

I To assure the safety design basis is satisfied and that the safe shutdown ofthe plant and removal ofdecay heat are not impaired, the repair hardware shall assure that the core shroud willmaintain the following basic safety functions:

To limitdeflections and deformation to assure that the Emergency Core Cooling Systems (ECCS) can perform their safety functions during anticipated operational occurrences and accidents.

Maintain partitions between regions within the reactor vessel to provide correct coolant distribution, for all normal plant operating modes.

. Provide positioning and support for the fuel assemblies, control rods, incore flux monitors, and other vessel internals and to ensure that normal control rod movement is not impaired.

Page4of17

.0 l'I

The changes in the lower spring spacing aQects the system spring characteristics for loads acting between two contacts.

Additional seismic analysis (Reference 24) calculated core support displacements for the bounding conditions.

The section below is revised to include the maximum displacements based on modified lower spring spacing and includes the gap between the shroud and the contact extension. All displacements remain acceptable. The new modified latch design on the lower spring wedge does not e6ect the maximum displacements below.

The core spray piping analysis performed to support the shroud repair included a shroud displacement of0.904 in. horizontally and 0.65 in. vertically, caused by a fault condition. This displacement willnot create an unacceptable loading condition in the ECCS piping and therefore willperform its intended safety function. The proposed modifications do not change the maximum displacements calculated for the original shroud repair at the upper shroud. Therefore there is no change in loading ofthe core spray piping.

The proper decay heat removal requires that the shroud to remain as a flowboundary to force water through the fuel and not allow a large leakage into the downcomer region. The maximum permanent horizontal ofFset ofadjacent shell sections, that are not directly supported by either the upper or lower springs, is limited by structural stops to 0.75 in. Since the wall'ofthe shroud is 1.5 in. thick, the shroud willstill function properly as a flowboundary within the reactor.

The safe shutdown ofthe plant is a function ofthe SCRAM capability. The core support plate and the top guide must be kept aligned within test limits so that frictionbetween the control rods and fuel bundles willnot impair proper motion. The worst case condition exists when the top guide moves one direction and the core support moves the opposite.

This creates the maximum angle between the fuel bundles and the guide tubes.

The maximum temporary calculated horizontal displacement ofthe top guide is 0.904 in. and the maximum for the core support is 0.85 in. The corresponding allowable displacement are 1.87 in. and 1.49 in. There is no calculated permanent horizontal displacement ofthe top guide and the maximum permanent displacement for the core support is 0.48 inches.

The corresponding allowable core support permanent displacements is 0.67 inches.

B.3 ZbmDr~iKCilain):

Repairs to the core shroud are not required to totally prevent leakage from the core region into the downcomer annulus.

However, the design shall ensure that cracked welds do not separate under normal operations as a minimum. Design willaccount for leakage from.the region inside the shroud into the annulus region during normal operation.

The leakage should not exceed the minimum subcooling required for proper recirculation pump operation and the core bypass flowleakage requirements assumed in the reload safety analysis shall be maintained.

The design willalso verify acceptable leakage through the flowpartition resulting from weld separation during accident and transient events.

B 31 Elm2'ztithu The original shroud repair design ensured that cracked welds willnot separate under normal operations.

The original shroud repair design accounted for leakage from the region inside the shroud into the annulus region during normal operation.

The leakage does not exceed the minimum subcooling required for proper recirculation pump operation and the core bypass flowleakage requirements assumed in reload safety analyses is maintained.

Page 5 of 17

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There are no requiremen r allowable leakage during the accident OCA and/or seismic). Afterthe accident, the leakage is limited by the allowable deflections such that the shroud section does not displace suf5ciently to open any vertical flowareas.

The maximum permanent horizontal displacement ofa shroud cylindrical section that is not directly supported by either the upper or lower springs is less than 0.75 inch, which is equal to one halfofthe thickness ofthe shroud.

Thus, leakage after an accident will be limited to the leakage through a crack.

Since the pressure difference across the shroud is small, the leakage willbe small.

The three proposed modifications have no affect on the potential weld crack separation or any potential leakage path. The three modifications do not require any new holes or penetrations through the shroud/shroud support. Therefore the leakage calculations and performance predictions in References 23 and 29 remain valid. The added contact extension provides assurance the maximum permanent displacement ofthe shroud cylinder between weld HS and H6A remains less than 0.75 inch.

8.4 ZhxImimaiXihzafhg Cdbxig:

The repair shall be designed to address the potential for vibration, and to keep vibration to an acceptable level. The natural frequency ofthe repaired shroud, including the repair hardware, shall be determined.

The vibratory stresses shall be less than the allowable stresses ofthe repair materials.

Forcing functions to be considered include the coolant flow and the vibratory forces transmitted via the'end point attachments for the repair. Testing may be used as an alternative or to supplement the vibration analysis.

U B4 l B BS IYB~U'KEl{~

The original shroud repair was designed to address the potential for vibration, and to keep vibration to a minimum. The natural frequency ofthe repaired shroud, including the repair hardware, has been determined.

The usage factor due to cyclic stresses caused by vibration willbe less than 1.0 for the design lifeofthe repair hardware. Forcing functions considered included the coolant flow and the vibratory forces transmitted via the end point attachments for the repair. Details ofthe original vibration analysis are provided in Reference 23. The three repair modifications have no affect on the natural

&equency ofthe stabilizer assembly or on the vortex shedding frequency.

Therefore the original vibration evaluation in Reference 23 remains valid for the stabilizer assemblies.

The potential for vibration ofthe new extension pieces has been considered. Forcing functions considered, included the vibratory forces transmitted from the stabilizer assemblies and coolant flow. The stabilizer vibratory forces are low, as demonstrated in the original vibration analysis, therefore vibratory forces imposed on the extension pieces are low. The coolant flowwillnot vibrate the lower contact extensions because the extensions are captured in all directions on the existing lower spring assembly.

The lower contact extension is a "U"shaped part which fits around the existing lower contact.

Steps at the ends ofits legs extend under the lower contact to prevent axial movement. Atang towards the top fits in the gap between the lower contact and the lower spring to prevent horizontal movement. A positive spring force from the legs keep the part tight and prevent random vibrations.

The only time that FIVis ofinterest is when the lower wedge loses contact with the vessel wall. This can occur during hydrotest, maximum seismic conditions, and during the limitingupset thermal feedwater event. These events have short duration with the longest potential duration being 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for the hydrotest event. The loss ofcontact at the lower spring support is not a concern in either the tie rod assembly or-the subassembly ofthe latch and lower wedge for the followingreasons:

Page 6 of 17

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The time when con t is lost is a relative short duration and t e associated number ofcycles is limited.

An independent calculation ofthe new latch and lower wedge assembly shows that the natural

&equency is suKciently high to avoid flowinduced vibration.

The clearance which is created between the wedge and the vessel wall is less than 0.050" which willlimitthe motion ofthe lower wedge in the lateral direction. This prevents any significant contact forces from being produced, and contact would dampen out any excitation ofthe lower wedge. The relative radial movements between the vessel and the shroud are such that surface contact is likelyto remain at one ofthe two surfaces during the postulated events.

Even postulating that no support is present at the lower spring, analysis has been performed for the

'ie rod assembly which demonstrates that flowinduced vibration willnot occur.

)

In conclusion, none ofthe shroud repair components are susceptible to flowinduced vibration when contact is lost at the lower spring contact.

B.S Lmliugm Exidiug Iaimml Increased stress on existing internal components, used in the repair, is acceptable as long as the current plant licensing basis are met. Increases in applied load shall be demonstrated to be acceptable.

The repair shall be designed'so as to produce acceptable loading on the original structure ofthe shroud, consistent with the criteria provided herein.

The repair should minimize stresses introduced into the shroud consistent with the criteria provided so as to not aggravate further shroud cracking.

The repair should minimize the loading on the supporting structures ofthe shroud, such as the shroud support cone and the RPV wall, to stay within the original design allowable stresses of these structures.

~

Supplemental seismic analysis for the proposed modifications shall conform to the same methodology and criteria used in the original shroud repair seismic analysis as documented in the FSAR.

~ ~ I LQKIJHlg911 EXhfhlg I1lfCKBBl Stresses on the original structure ofthe shroud, which are directly impacted by the shroud repair hardware, have been demonstrated to be acceptable.

The results ofthis evaluation are documented in references 4, 5 and 11 for all ofthe postulated accidents.

The original shroud repair was designed to minimize stresses introduced into the shroud consistent with the criteria provided so as to not aggravate further shroud cracking. The addition ofthe contact extensions, the modification to the 270'ie rod and the addition ofmodified lower wedge latches has an insignificant afFect on the component loads and stresses. In addition analyses included in Reference 29 have been completed regarding the potential impact the shroud stabilizer assemblies could have on vertical weld cracking. The results have shown that any hoop stress induced at the vertical welds due to shroud stabilizer thermal pr'eload is negligible. The overall Page 7 of 17

0 e

~

I

~

conclusion is that t shroud stabilizers had no affect on the s oud vertical weld cracking identified at V9 and V10. Therefore the evaluation in Reference 23 remains valid.

~

The original shroud repair design minimized the loading on the supporting structures ofthe shroud, such as the shroud support cone and the RPV wall, to stay within the original design allowable stresses ofthese structures. The results ofthis evaluation are documented in references 4, 5 and 11 for all ofthe postulated accidents. Relocating the 270'ower spring assembly changes the spacing between the adjacent lower spring assemblies.

The change in spacing affects the net spring characteristics and load distribution when two springs share the horizontal seismic load. Analysis show the load on any one spring does not exceed the loads used in the original stress evaluation, Reference 24. The stress evaluation remains valid for the modified 270'tabilizer modification.

B.5.1.1 Rime haalzsh The modifications adding the contact extensions and modified lower wedge latches h'ave no affect on the seismic analysis.

Relocating the lower spring affects the original seismic analysis.

Supplemental seismic analysis was made using the same methodology and criteria as was used in the original seismic analysis.

The changes in the spacing between lower springs and affects the effective spring characteristics when two springs share the horizontal seismic loads.

Springs less than 90'part increase the effective spring constant and springs greater than 90'end to lower the spring constant.

Equivalent spring constants were determined for the bounding conditions and additional seismic calculations were made to determine loads and displacements (Reference 24). The individual spring loads do not exceed the loads used in the original stress evaluation (Reference 25) and the calculated displacements remain acceptable (Part B.2.1).

B6 A

4 H ~IGB The design shall not adversely affect the normal flowofwater in the annulus region, or the normal balance offlowin this region. The design shall not adversely restrict the flowofwater into the recirculation suction inlet.

B61AUH None ofthe three modifications adversely affect the normal flowofwater in the annulus region, or restrict the flowin any way that would adversely affect normal balance offlowin this region. The design does not adversely restrict the flowofwater into the recirculation suction inlet.

B.7 Bwzgazy. Rwzathe Zramluze QZ2Q IC 81:

Inputs to the EOP calculations, such as bulk steel residual heat capacity and reduction ofreactor water inventory shall be addressed based on repair hardware mass and water displacement.

I B.7.1 Z~zgcmy. ~m~gg Zzm~ig~)

n The addition ofthe spring contact extensions and new latches have an insignificant affect on the EOP calculations, such as bulk steel residual heat capacity and reduction ofreactor water inventory since the quantity ofsteel added is negligible as compared to the mass and volume ofthe existing shroud repair hardware and reactor internals.

Page 8 of 17

O.

V 0

The design ofthe repair shall account for the affects ofirradiation relaxation utilizing end-of-life fluence on the materials.

B81RUWEII RcoB The original design ofthe repair accounts for the affects ofirradiation relaxation utilizing end-of-life fluence on the materials.

In accordance with Reference 1, the design considers an End-of-Life preload relaxation for the upper and lower springs.

The radiation level is less than the limitcontained in the UFSAR. The basis for this is documented in reference 11 (design basis for reference 1).

The contact extension has a positive spring loaded clamping force around the lower contact. The initial installation clamping force is not required to keep the part captured or for the part to remain functional.

Radiation relaxation may reduce, but willnot eliminate the positive clamping load. A postulated reduction in the initial clamping load due to radiation relaxation is not a concern because the extension pieces are captured in all directions as discussed in Part B.4.1 and any amount ofpositive clamping load willprevent free movement or random vibrations ofthe extension pieces.

A positive spring force in the latch is achieved by compressing the latch prior to insertion into the hole within the lower wedge. A postulated reduction in the initial compression load due to radiation relaxation is also not a concern for the latches as they are captured by recessed areas in the wedge and the lower spring.

B 9 Timbaltycho Kdtcria):

The repair hardware shall consider the effects ofthermal cycles for the remaining lifeofthe plant.

Analysis shall use original plant RPV thermal cycle diagrams.

The design shall assume a number of thermal cycles equal to or greater than the number assumed in the original RPV design.

Alternatively, thermal cycles defined by actual plant operating data may be employed iftechnically justified. Using this thermal cycle information repair components and the repaired shroud shall be evaluated for fatigue loading along with any other design vibratory loads.

B 91 XhezmalCychz The original shroud repair hardware analysis considered the effects ofthermal cycles for the remaining lifeofthe plant as documented in Reference 5. The analysis considered thermal expansion for the varying temperatures and material combinations ofthe shroud, shroud support cone, reactor vessel and the shroud repair stabilizers for normal and upset thermal conditions. The stresses resulting from the thermal cycles have been evaluated by a fatigue analysis.

The results show that its effect on fatigue lifeofthe plant is negligible. The three modifications have an insignificant effect on previous fatigue analysis.

The analysis provided in Reference 30 has evaluated the modified lower wedge latches for their capability to withstand loading conditions due to thermal differential vertical displacements between the RPV and the stabilizer lower spring. The analysis concluded that for normal plant thermal cycles as well as transient thermal cycles (loss offeedwater event), the new latches when considering the most probable loading conditions willhandle these thermal cycles satisfactorily for at least the remaining plant life. The removal ofthe clearance between the toggle bolts and the shroud support cone willassure that the difFerential vertical displacements are limited to the design values used in the Reference 30 analysis.

Page 9 of 17

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The design shall recognize the use ofexisting and anticipated water chemistry control measures for BWRs and shall consider the affects ofneutron flux on any materials used in the repair.

B.10.1 Since the materials for the three modifications are the same as was used for the installed shroud repair hardware, existing and anticipated water chemistry control measures and the affects ofneutron flux on the materials have been addressed and willhave no effect on the repair hardware.

B.11 L ~~K I hl:

Repair hardware mechanical components shall be designed to minimize the potential for loose parts inside the vessel.

The design repair shall use mechanical locking methods for threaded connections.

Allparts shall be captured and held in place by a method that willlast for the design life ofthe repair.

B

~ I The modified stabilizer assembly has been designed to minimize the potential for loose parts inside the vessel.

The design repair uses mechanical locking methods (such as crimped jam nuts) for threaded connections.

Allparts are captured and held in place by a method such as pinning, staking, spring retainers, interference fits, and crimping that willlast for the design lifeofthe repair.

The lower contact extension is captured in all directions on the existing lower spring assembly.

The lower contact extension is a "U"shaped part which fits around the existing lower contact.

Steps at the ends ofits legs extend under the lower contact to prevent axial movement. Atang towards the top fits in the gap between the lower contact and the lower spring to prevent horizontal movement. Apositive spring force from the legs keep the part tight and prevent random vibrations. The spring force is not required to ensure the extension is secured to the existing lower contact. A positive spring force in the latch is achieved by compressing the latch prior to insertion into the hole within the lower wedge. The latches are captured by recessed areas in the wedge and the lower spring so they can not become a loose part.

Lmm Each Gcauxbd hz the Repaiz Zxmzm:

Special tooling/equipment is being provided that willbe tested and personnel willbe trained on full scale mockups to assure adequate controls exist to minimize the potential for vessel internals damage or loose parts. Protective shields have been designed that can be installed as needed to protect the Feedwater Sparger, Core Spray Line and the Recirculation nozzles. NMPC and GE installation procedures/travelers willbe used to establish Foreign Material Exclusion (FME) controls. Alltools and equipment used in the Vessel and Spent Fuel Pool willbe properly secured.

B.12 Iaquxthu huem Kdhzig:

The repair design shall be such that inspection ofreactor internals, reactor vessel, ECCS components and repair hardware is facilitated. The installed repair hardware shall not interfere with refueling operations and shall permit servicing ofinternal components.

Allparts shall be designed so that they can be removed and replaced.

This is to provide full access to the annulus area for other possible future inspections and/or maintenance/repair activities that may prove necessary in the future.

Page 10 of 17

None ofthe three modifications affect the access for inspections.

Allparts have been designed so that they can be removed and replaced.

Cuxim Kdtezia):

The repair design shall be reviewed for crevices to assure that criteria for crevices immune to stress corrosion cracking acceleration are satisfied.

B.13.1 Qyg~

The selection ofthe materials for the modification hardware is the same as the original hardware and assures that criteria for crevices shown to be immune to stress corrosion cracking acceleration are satisfied.

B 14 M&xinhKribxe}:

Allmaterials used shall be in conformance with the BWR VIP requirements.

B 14.1 IHatcriah Materials for the three modifications have the same requirements as the original shroud repair hardware and are in conformance with the BWR VIP requirements.

B.15

{Cribxig:

The designed repair shall minimize the need for future inspections and maintenance ofthe repair components.

The designed repair shall minimize the requirement for future inspections ofthe affected shroud joints.

B.15.1 The stabilizer assemblies including the three modifications are currently inspected under the NMP1 Augmented Inservice Inspection Program (LDCR No. 1-94-ISI-009, Rev. 3).

B 16 ImtaE&III.Jmm Kdbxig:

Tooling/equipment used for installation ofrepair components shall be evaluated in accordance with Reference 9 and shall consider the following:

Heavy loads Shutdown System Status (N+1)

Rigging Hole Cutting Method B.16.1 gi~~iI11~i~

The modified stabilizer assemblies have the same installation requirements as the original stabilizer assembly with the exception that a special procedure (Reference 28) was developed and performed to Page I I of 17

0

l ensure the clearances werVFemoved between the toggle bolts and the holes on the shroud side ofthe support cone. This procedure ensures that the tie rods remain tight and are restored to their original design mechanical preload. No hole cutting is required for either modification. The installation activities associated with the proposed modifications were evaluated in a separate safety evaluation (Ref. 26).

8.17 Exhfing Reader Inhraah (Czitezi;9:

The design shall not rely on existing reactor internals or components to carry loads that have experienced cracking in the industry (e.g. shroud head bolt lugs, stub tubes).

B.17.l Exhiiag Ruat'abnmh None ofthe three modification rely on existing reactor internals or components to carry loads that have experienced cracking in the industry (e.g. shroud head bolt lugs, stub tubes).

Page 12 of 17

'N

~

e

C.

Could the proposed change or activity increase the probability ofoccurrence ofan accident previously evaluated in the SAR? No. The affected plant systems and components willbe capable ofperforming their intended functions with the three core shroud stabilizer modifications installed.

These modifications restore the shroud repair stabilizers to their intended design condition. As the modifications are being provided to the plant's safety-related design requirements, the probability ofa component failure is not increased.

The three modifications impose a negligible change to the plant operating conditions. Neither modification willinteract with any component assumed to initiate an accident in the UFSAR. Nor willthe failure or presence ofthe modifications initiate an accident evaluated in the UFSAR.

2.

Could the proposed change or activity increase the consequences of an accident evaluated previously in the SAR?

No. The calculated Peak Clad Temperature (PCT) willremain below 2200'F, and all structures, systems and components (SSC) used to mitigate the (radiological) consequences ofthe accidents in the SAR are independent ofthe three proposed modifications, and thus, the consequences ofthe accidents willnot be affected.

The abnormal events in the UFSAR that potentially could be affected by the installation ofthe stabilizers were evaluated, and they remain unchanged.

The three proposed modifications impose no change to the plant operating conditions, and thus, there is no affect on any LOCAand transient analyses.

LOCA-Radiological analysis is based on the plant's engineered safety features (ESF) functioning within design parameters, and the radioactive material source terms. The three modifications will not adversely affect any ESF, and thus, the ESF functions willnot be affected.

The radioactive material source terms are based on the regulatory limitPCT of2200'F.

As the PCT for Nine Mile Point I willremain below this regulatory limit, the source terms willnot be affected.

Therefore, the consequences ofthe LOCA-Radiological analysis willnot change.

The MSLB analysis release is limited by the capacity ofthe MSLFlow Restrictors, and uses UFSAR allowables for source terms.

As the three modifications willnot affect either ofthese, the consequences ofthe MSLB analysis willnot change.

Seismic analyses (Ref. 6) show that the stabilizers willremain functional followingan earthquake 3.

Could the proposed change or activity increase the probability ofoccurrence ofa malfunction ofequipment important to safety evaluated previously in the SAR? No. The three modifications are designed and constructed as safety related components.

No adverse equipment interactions willbe created by installing the three modifications. The Installation Processes and Tooling willnot adversely effect any internal components important to safety discussed in the SAR. Therefore, the probability ofequipment malfunctions is not increased.

4.

Could the proposed activity increase the consequences ofa malfunction ofequipment important to safety evaluated previously in the SAR? No. The installation ofthe three modifications ensures that the shroud stabilizer assemblies willperform their intended functions.

Thus, consequences ofa malfunction ofequipment important to safety is not increased.

The three modifications and the shroud stabilizers perform a passive function that does not interface with any Page 13 of 17

0

equipment that is u to mitigate the radiological consequences ofa malfunction in the UFSAR.

The effects ofthe shroud repair stabilizer assemblies on the consequences ofpotentially affected transients are negligible. As the stabilizer assemblies, including the three modifications, do not adversely affect equipment "Important to Safety," the consequences ofall transients willnot change.

The Installation Processes and Tooling willnot adversely eFect any equipment important to safety, as discussed previously. Therefore, there is no increase to the consequences of component malfunctions.

5.

Could the proposed activity create the possibility ofan accident ofa different type than any evaluated previously in the SAR. No. The stabilizers, including the three modifications, are designed to the structural criteria specified'in the Nine MilePoint 1 UFSAR. Allofthe loads and load combinations specified in the UFSAR, that are relevant'to the core shroud, have been evaluated, and are within design allowables.

The stabilizers, including The three modifications, do not add any new operational/failure mode or create any new challenge to safety-related equipment or other equipment whose failure could cause a new type of accident. In addition, the stabilizers or the three modifications do not create any new component/system interactions or sequence of events that lead to a new type ofaccident.

It has been postulated that ifa core shroud had a 360'rack and a MSLB accident occurred, the upper shroud and the top fuel support could lift. Ifthe top fuel support lifted s'ufficiently, the tops ofthe fuel bundles could move (shift), which might prevent the control blades from completely inserting (partial scram).

This event would be an accident ofa different'type. However, the core shroud stabilizers would limitthe shroud from moving, and thus, prevent the top fuel support from lifting. The proposed changes to the lower spring, the addition ofthe lower extensions and new modified latches have no affect on the abilityofthe stabilizer to perform this function. The three modifications also ensure that the barrel section ofthe shroud between welds H5 and H6A and the core support displacements are limited during a MSLB or recirculation LOCAwhen combined with an earthquake.

Therefore, the modifications do not increase the probability ofoccurrence ofan accident ofa diFerent type than any evaluated previously in the SAR.

6.

Could the proposed activity create the possibility ofa malfunction ofequipment important to safety ofa different type than any evaluated previously in the SAR. No. The stabilizers, including the three modifications, structurally replace the shroud horizontal welds. The three modifications include the same design features as the as-installed stabilizers. Allequipment assumed to operate in the transient analyses, and the safety-related structures, systems and components willnot be adversely affected by the stabilizers, including the three modifications. All components interacting with the stabilizers willperform their intended functions. The stabilizers, including the three modifications, do not increase challenges to or create any new challenge to equipment.

The stabilizers, including the three modifications, do not create any new sequence of events that lead to a new type ofmalfunction. Therefore, the possibility ofa diFerent type of component malfunction than evaluated in the SAR is not created.

7.

Does the proposed activity reduce the margin ofsafety as defined in the basis for any Technical Specification.

No. The Technical Specifications Bases, the UFSAR (including the shroud repair design basis documents listed in the UFSAR) and the NRC safety evaluation (SE) of the NMP1 shroud repair were reviewed.

The USFAR and the NRC SE define the acceptance limits for calculated displacements / stresses as the "design allowable" displacement / stresses.

That is, neither the USFAR nor the NRC SE define the safety margin as the difference between the Page 14 of 17

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previously calculat&edisplacements / stresses and the design aiiowables.

Therefore, increases in displacements / stresses as a result ofthe proposed modifications willnot reduce the margin of safety as defined by the USFAR and the NRC SE, provided the calculated displacements/stresses remain less than the original design allowables.

The analysis completed for the 270'ie rod modification, the lower spring contact modification and the lower wedge latch modification demonstrated that the original shroud repair calculated reactor internals and repair hardware stresses are bounding, therefore the margin ofsafety is not reduced.

The analysis for the proposed modifications also indicate that the calculated maximum core support temporary (0.85") and permanent (0.48") horizontal displacements increased.

These increases do not reduce the margin ofsafety as defined above, because the displacements remain below the design allowable temporary (1.49") and permanent (0.67") displacements.

This evaluation has investigated modifications to the shroud repair stabilizers at Nine MilePoint 1 which willrestore them to their intended design function. The modifications include relocating a lower spring assembly to properly bear against the RPV, adding extensions to assure the spring contacts on the shroud extend beyond weld H6A and installing new latches which are more tolerant ofdifferential vertical displacement. Additionallynew installation requirements were implemented to ensure'the tightness ofthe stabilizer assemblies.

The plant licensing bases have been reviewed.

This review demonstrates that these modifications can be installed (1) without an increase in the probability or cons'equences ofan accident or malfunction previously evaluated, (2) without creating the possibility ofan accident or malfunction ofa new or different kind from any previously evaluated, (3) and without reducing the margin ofsafety in the bases ofa Technical Specification.

Therefore, installation ofthese three modifications do not involve an unreviewed safety question.

1.

GE-NE Specification: 25A5583, Rev. 2, "Shroud Repair Hardware, Design Specification" 2.

GE-NE Specification: 25A5586, Rev. 1, "Shroud Repair Code, Design Specification" 3.

UFSAR, Rev. 12, Nine MilePoint 1

4.

GE-NE Document: 24A6426, Rev. 1, "Reactor Pressure Vessel Stress Report" 5.

GE-NE-B13-01739-04, Rev. 0, "Shroud Repair Hardware Stress Analysis" 6.

GE-NE-B13-01739-03, Rev. 0, "Seismic Design Report ofShroud Repair forNine MilePoint 1

Nuclear Power Plant" 7.

NRC Generic Letter 94-03, July 25, 1994, "Intergranular Stress Corrosion Cracking ofCore Shrouds in Boiling Water Reactors" 8.

Niagara Mohawk Procedure: Nl-MMP-GEN-914, "LiRingofMiscellaneous Heavy Loads" 9.

GE-NE Specification: 386HA852, "Reactor Servicing Tools" Page l5 of 17

10.

GE-NE Document:

~DO-10909, Rev. 7, "SAPG07, Static Dynamic Analysis ofMechanical and Piping Components by Finite Element Method" GE-NE Document: DRF B13-01739, "Nine MilePoint 1 Shroud Stabilization" 12.

GE-NE Procedure: NM-SM-TP&P-04, "EDMActuators" 13.

Niagara Mohawk Procedure: Nl-ODG-11, "Outage Safety Assessment" 14.

Niagara Mohawk Procedure: NIP-OUT-01, "Shutdown Safety" 15.

16.

GE-NE "Post Inspection Plan" GE-NE Specification: 21A1104, Rev. 0, "Specification for Reactor Pressure Vessel" 17.

18.

BWROG VIP Core Shroud Repair Design Criteria, Rev. 1, September 12, 1994 GE-NE Specification: 25A5584, Rev. 1, "Fabrication ofShroud Repair Components" 19.

20.

GE-NE Drawing: 237E434, Rev. 5, "Reactor Vessel Loadings" GE Drawing GE-NE Specification: 383HA718, Thermal Cycles, Reactor Vessel and Nozzle, Description Basis and Assumptions 21.

GE-NE-A0003981-1-13, Rev. 1, "Performance Impact ofShroud Repair Leakage forNMPI",

I2/15/94 22.

Niagara Mohawk Document: SO-EOP-M018, 23.

GE-NEB13-01739-05, Rev. 1, SAFETY EVALUATION,GE Core Shroud Repair Design 24.

Supplement 1, GENE-B13-01739-03, Rev. 0, Nine MilePoint 1, Seismic Analysis, Core Shroud Repair Modification 25.

Supplement 4, GENE-B13-01739-04, Nine MilePoint 1, Shroud Repair Hardware Stress Analysis 26.

27.

28.

NMPC Safety Evaluation No.95-007 Rev.1, Nine MilePoint'1, Core Shroud Repair Installation.

GENE-B13-0173940, Shroud Repair Anomalies, Nine MilePoint Unit 1, RFO14.

NMP-SHD-003, Lower Wedge Latch Replacement and Tie Rod Torque Checks.

29.

GENE-523-B13-01869-043, Assessment ofthe Vertical Weld Cracking on the NMP1 Shroud, April 1997.

30.

GENE B13-01739-22, Design Report for Improved Shroud Repair Lower Support Latches.

31.

NRC Safety Evaluation ofthe NMP1 Core Shroud Repair Dated 3/31/95.

Page 16 of 17

. 0 0

32.

NRC Safety Evaluate Related to Modifications to Correct Shroud Repair Deviations, Dated 3/3/97.

Page 17 of 17

ENCLOSURE 5.--

DESIGN REPORT FOR IMPROVED SHROUD REPAIR LOWER SUPPORT LATCHES

~..9704100242.

ENCLOSURE6 INSPECTION HISTORY

I

Kine MilePoint Unit 1 Invessel Visual Inspection Summary ofInspections Performed Refueling Outage '97 The followingidentifies the invessel visual inspections during the 1997 refueling outage:

"A"core spray piping, welds, and brackets (attachment welds)

"B"core spray piping, welds, and brackets (attachment welds)

There were no relevant indications noted:

Upper spargers "A"and "C" looking at the spargers, sparger welds, including the tee box welds, nozzles, nozzle welds and brackets (attachment) welds.

Lower spargers "B"and "D"looking at the spargers, sparger welds, including the tee welds, nozzles, nozzle welds and brackets (attachment) welds.

Two indications were recorded (1) crack at nozzle 23A and one on nozzle 26A both indications were observed on previous dat'a. There is no apparent difference in the crack length Rom 1995 until 1997.

Allofthe steam dryer, banks and skirts, liftinglugs. Close attention to clips, lower stiffener, and areas with previous indications as noted below:

Bank 2, Clip 5 Bank 2, Clip 2 Locking Channel at 225'ank 2, Lower Stiffener, 1" Hole Bank 4, Clip 5 The previously identified indication was noted with no growth or change.

The previously identified indication was noted with no growth or change.

The previously identified indication was noted with no growth or change.

The previously identified indication was noted with no growth or change.

The previously identified indication was noted with no growth or change.

J

Examination ofthe moisture separator showed no new indications and no growth or change in indications located on the 102 standpipe bracket.

Examined bolting, wedges and verified general cleanliness.

SIIA09-IDTC 1245 no recordable indications noted SIIA09-IDTC3645 one indication was noted and recorded on the dry tube shaft just below the collar.

Evaluated various areas during examination ofall components withinthe vessel this outage.

Allfeedwater spargers, end brackets, pins, wedge blocks and Qow holes were examined with no indications noted. In addition, the blend radius ofall four feedwater nozzles were examined and found acceptable.

ChuL2aiah Located at 180 degrees, 77" down the vessel wall.

Several accessible core locations were inspected for debris, erosion corrosion and seating surfaces.

(wXivirfo97.v~

ENCLOSURE 7 AFFIDAVIT(GE)

P 1

General Electric Company I, George B. Stramba~ being duly sworn, depose and state as follows:

(1) I am Project Manager, Regulatory Services, General Electric Company ("GE") and have been delegated the function of reviewing the information described in paragraph (2) which is sought to be withheld, and have been authorized to apply for its withholding.

(2)

The information sought to be withheld is contained in the GE proprietary reports GE-NE 523-B13-01869-043, Assessment of the Vertical 8'eld Craclang on the NMPI Shroud, Revision 0, Class III(GE Nuclear Energy Proprietary Information),

dated April 1997, GENE B13-01739-40, Shroud Repair Anomalies Nine Mile Point Unit I, RFOI4, Revision 0, Class III(GE Nuclear Energy Proprietary Information),

dated April 1997, and GENE B13-01739-22, Design Report for Improved Shroud Repair Lower Support Retainers, Revision 0, Class III (GE Nuclear Energy Proprietary Information),

dated April 1997.

The proprietary information is delineated by bars marked in the margin adjacent to the specific material.

(3) In making this application for withholding ofproprietary information ofwhich it is the owner, GE relies upon the exemption &om disclosure set forth in the Freedom of Information Act ("FOIA"), 5 USC Sec. 552(b)(4), and the Trade Secrets Act, 18 USC Sec.

1905, and NRC regulations 10 CFR 9.17(a)(4),

2.790(a)(4),

and 2.790(d)(1) for "trade secrets and commercial or financial information obtained Rom a person and privileged or confidential" (Exemption 4).

The material for which'xemption from disclosure is here sought is all "confidential commercial information", and some portions also qualify under the narrower definition of "trade secret", within the meanings assigned to those ferms for purposes of FOIA Exemption 4 in, respectively, ec v C '2 171 QCC'.

9

~v ~, 704F2d1280 (DC Cir. 1983).

(4) 'ome examples of categories of information which fit into the definition of proprietary information are:

a Information that discloses a process, method, or apparatus, including supporting data and analyses, where prevention ofits use by General Electric's competitors without license Rom General Electric constitutes a competitive economic advantage over other companies; GBS-97-3-ahunp1 l.doc AffidavitPago I

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b.

Information winch, ifused by a competitor, would reduce his expenditure of resources or improve his competitive position in the design, manufacture, shipment, installation, assurance ofquality, or licensing ofa similar product; c.

Information which reveals cost or price information, production capacities, budget levels, or commercial strategies ofGeneral Electric, its customers, or its suppliers; d.

Information which reveals aspects of past, present, or future General Electric customer-funded development plans and programs, of potential commercial value to General Electxic; e.

Information which discloses patentable subject matter for which it may be desirable to obtain patent protection.

The information sought to be withheld is considered to be proprietary for the reasons set forthinboth paragraphs (4)a. aud (4)b., above.

(S)

The infozmation sought to be withheld is being submitted to NRC in confidence.

The information is ofa sort customazily held in confidence by GE, and is in fact so held. The information sought to be withheld has, to the best ofmy knowledge and belief, consistently been held in confidence by GE, no public disclosuxe has been

made, and it is not available in public sources. All disclosures to third parties including any required traxisxxiittals to NRC, have been made, or must be made, pursuant to regulatory provisions or'roprietaxy agreements which provide for maintenance ofthe infozxnation in confidence.

Its initial designation as propzietazy information, and the subsequent steps taken to prevent its unauthorized disclosure, are as set forth in paragraphs (6) and (7) following.

(6) Initial approval ofproprietary treatment of a document is made by the manager of the originating component, the person most likely to be acquainted with the value and sensitivity ofthe information in relation to industry knowledge, Access to such documents withinGE is limited on a "need to know" basis.

(7)

The procedure for approval ofexternal release ofsuch a document typically requires review by the staff manager, project manager, principal scientist or other equivalent authority, by the manager ofthe cognizant marketing function (or his delegate), and by the Legal Operation, for technical content, competitive effect, and determination ofthe accuracy ofthe proprietary designation.

Disclosures outside GE are lnnited to regulatory bodies, customers, and potential customers, and their agents, suppliers, and licensees, and others with a legitimate need for the information, and then only in accordance with appropriate regulatory provisions or proprietaxy agreements.

(8)

The information identified in paragraph (2), above, is classified as proprietary because it contains detailed results of analytical models, methods and processes, GBS-97-3-ahmpl l.doc

~ AffidavitPage 2

.4 1

including computer

codes, which GE has developed and applied to perform evaluations ofindications in the core shroud forthe BWR.

The development and approval ofthe BWR Shroud Repair Program was achicvcd at a significant cost, on the order ofone milliondollars, to GE.

The development oF the evaluation process contained in the paragraph (2) document along with the interpretation and, application ofthe analytical results is derived &om thc cxtcnsivc cxpcricncc database that constitutes a major GE asset.

(9)

Public disclosure of the information sought to be withheld is likely to cause substantial harm to GE's competitive position and foreclose or reduce the availability of profit-making opportunities.

'Ihe information is part of GEs comprehensive BWR safety and 'technology base, and its commercial value extends beyond the original development cost.

The value of the technology base goes beyond the extensive physical database and analytical methodology and includes development of the expntise to determine and apply the appropriate evaluation process.

In addition, the technology. base includes the value derived &om providing analyses done withNRC-approved methods.

The research, development, engineering, analytical and NRC review costs comprise a substantial investment oftime and money by GE.

The precise value of the expertise to devise an evaluation process and apply the correct analytical methodology is difBcultto quantify, but itclearly is substantial.

GE's competitive advantage willbe lost ifits competitors are able to use the results of the GE experience to normalize or verify their own process or ifthey are able to claim an equivalent understanding by demonstrating that they can arrive at the same or similar conclusions.

The value ofthis information to GE would be lost ifthe information were disclosed to the public.

Making such information available to competitors without their having been required to undertake a similar expenditure ofresources would unfairly provide competitors with a windfall, and deprive GE of the opportunity to exercise its competitive advantage to seek an adequate return on its large investment in developing these very valuable analytical tools.

GBS-97-3-ahmp11.doc AQidavit Page 3

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STATE OF CALIFORNIA

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COUNTY OF SANTACLARA

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George B. Stramback, being duly sworn, deposes and says:

That he has read the foregoing a6idavit apd the matters stated therein are true and correct to the best ofhis knowledge, information, and belief.

Executed at Sau Jose, Cahfomia, this~ day of 1991.

orge B.

tramback General Electric Company Subscribed and swornbefore me this 7~~ day of 1997.

otary Public, State ofC QKACNO OomnMeP )it3RQ g

.SektCheCeely

&COaa SISIIOet20,3M GBS-97-3-a& mp11.doe AfBfhvitPage 4 s

General Electric Company AIFIDAVXX' George B. Stramback, being duly sworn, depose and state as follows:

(1) I am Project Mazuzgcr, Regulatory Services, General Electric Company ("GE") and have been delegated the function of reviewing the infozmauon described in pazagraph (2) which is sought to be withheld, and have been authonzed to apply for its withholding.

(2)

Thc information sought to bc withheld is contained in the GE proprietary drawings Reactor Modification!Installation Drawing,

107E5679, Revision 7,

and those drawings listed in the attachment.

These documents, taken as a whole, constitutes a proprietary compilation of infozmation, some of it also independently proprietary, prepared by General Electric Company.

The independently proprietazy elements that axc drawings are marked as proprietar information.

(3) In making this application for withholding ofproprietazy information ofwhich it is the owner, GE relies upon the exemption Rom disclosure set forth inthe Fxeedom of Information Act ("FOIA"), 5 USC Sec. 552(b)(4), and the Trade Secrets Act, 18 USC Sec.

1905, and NRC regulations 10 CFR 9.17(a)(4),

2.790(a)(4),

and 2.790(d)(l) for "trade secrets and commercial or financial infozmation obtained &om a person and pzivilcged or confidential" (Exemption 4).

The material for which exemption

&un disclosure is here sought is all "confidential commercial information", and some poztions also qualify under the narrower definition of"trade secret",

within the meanings assigned to those terms for purposes of FOIA Exemption 4 in, respectively, V

C 9

d WCC'.199),

z~Q 704F2d1280 (DC Cir. 1983).

(4)

Some examples of categories of iufozznation which Qt into thc definition of proprietary information are:

.a.

Infozmation that discloses a process, method, or apparatus, including suppoiting data and analyses, where prevention ofits use by General Electric's competitors without license Rom General Electric constitutes a competitive economic advantage over other companies; b.

Infozmation which, ifused by a competitor, would zeduce his expezuHture of resources or improve his competitive position in the design, manufactuze, shipment, installation, assurance ofquality, or licensing ofa similar product; GBS-97-3-afNMP12.doc Af5davitPage 1

NI

c.

Information which reveals cost or price information, production capacities, budget levels, or commercial stxategies ofGeneral Ecctric, its customers, or its suppliers; d.

Information which reveals aspects of past, present, or future General Electric customer-Sided development plans and programs, of potential commercial value to General Hectric; e.

Information which discloses patentable subject matter for which it may be desirable to obtain patent protection.

The information sought to bc withheld is considered to be proprietary for the reasons set forth in both paragapbs (4)a., (4)b. and (4)e., above.

The information sought to bc withheld is being submitted to NRC in con6dencc.

The information is ofa sort customarily held. in con6dcncc by GE, and is in fact so held. The information sought to be withheld has, to the best ofmy knowledge and belief, consistently been held in confidence by GE, no public disclosure has been

made, and it is not avaihble in public sources. All disclosures to third paztics including any required traasmittals to NRC, have bccn made, or must bo made, pursuant to regulatory pzovisions or propzietary agreements which provide for maintenance ofthe infozznation in con6dence.

Its initial designation as proprietary information, and the subsequent steps taken to prevent its unauthorized disclosure, aze as set fozth in paragraphs (6) and (7) following.

hitial approval ofpxopxzctazy treatxnent of a doemM:nt is made by thc zmuugcz of the originating component, the person most likely to be acquainted with the value and sensitivity ofthe iafozxnaxion in rehtion to industry knowledge.

Access to such documents withinGE is hmited on a "need to know" basis.

'Ihe procedure for approval ofexternal release ofsuch a document typically xectuircs review by the staff manager, project manager, pxincipal scicxxtist or other equivalent authority, by the manager ofthc cognizant marketing Rncnon (or his delegate), and by the Legal Operation, for technical content, competitive eEcct, and dctemhetion ofthc accuracy ofthe pxopxictazy designation.

Disclosures outside GE are limitedto regulatory bodies, custormm, and potential customers, and their agents, suppliers, and licensees, and others witha legitimate need. forthc information, and then only in accordance with appzoyciate regulatory provisions or proprietary agrccmcxxts.

The infozxnation identified in paragraph (2), above, is classiGcd as pxopxietaxy because it constitutes a con6dential compilation of information, including detailed design drawing results ofa hardware design modiGcatioa (stabilizer for the shroud horizontal welds) intetMled to be installed in a reactor to resolve the reactor pressure vessel core shroud weM cracking concern.

The development and approval ofthis GBS-97-3wfNMp)2.doc A6idavitPage 2

design modification utilmxisystems, components, and models and computer codes that were developed at a siyCificant cost to GE, on the order of several hundred thousand dollars.

The detailed results of the analytical models, methods, and processes, including computer codes, and conclusions &om these applications, represent, as a whole, an integrated process or approach which GE has developed, and applied to this design modification.

The development of the supporting processes was at a significant additional cost to GE, in excess ofa milliondollars, over and above the large cost of developing the underlying individual proprietary rcport and drawings information.

(9) Public disclosure of the infoanation sought to be withheld is likely to cause substantial harm to GE's competitive position and foreclose or reduce the availabiTity of profit-mahng opportunities.

The information is part of GE's comprehensive BWR safety and technology base, and its commercial value extends beyond the original development cost.

The value of the technology base goes beyond the extensive physical database and analytical methodology and includes development of the expertise to determine and apply the appropriate evaluation process.

In addition, the technology base includes the value derived Rom providing analyses done withNRC~ved methods.

t The research, development, etgineering, analytical and NRC review costs comprise a substantial investment oftime and money by GE.

'Ihe precise value of the Lyeztise to devise an evaluation process and apply the correct analytical methodology is diKcultto quantify, but itclearly is substantiaL GE's competitive advantage willbe lost ifits competitors are able to use the results ofthe GE experience to normallize or verifytheir own process or ifthey are able to claim an equivalent understanding by demonstrating that they can arrive at. the same, or similar conclusions.

The value ofthis information to GE would be lost ifthe information were disclosed to the public.

Making such information availabIe to competitors without their having been required to undertake a similar expenditure ofresources would unSurly provide competitors with a windfall, and deprive GE ofthe opportunity to exercise its competitive advantage to seek an adequate return, on, its large inveshnent in developing these very valuable analytical tools.

GBS-97-3-aSMP12.doc AfDdavitPago 3

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CORI Y OF SANTACUBA

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Geog@ B. Strarnback, being duly~rn @Poses and say:

That hc has read the foregoing aQbhvit and the mLttcrs stared thcrem are true and correct to the best ofhis hnowIcdgc, inforrnations and belief.

Exeurtcd at San Jose, California, this '~ day of l997.

rge B.

back General Electric Company Subsenbexi suti sexoxu befoxexutehis ~X tbsfof I997:.

otazy Public, State o 4l5h Coas gym~O It~

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~~,'. j-P. 26/26 ATTACHMENT

~Drawin 112D6546, Rev. 3, Tie Rod, Spring Assembly 112D6573, Rcv. 3, Upper Support Assembly GB&97-3wfNMP12.doc A6idavitPago S

1 J

CATEGORY 1.

REGULAT INFORMATION DISTRIBUTION.

STEM (RIDS)

ACCESSION 'NBR:9704100242 DOC.DATE: 97/04/08 NOTARIZED: YES DOCKET I FACIL:50-220 Nine Mile Point Nuclear Station, Unit 1, Niagara Powe 05000220 AUTH.NAME AUTHOR AFE' LIATION MCCORMICK,M.J.

Niagara Mohawk Power Corp.

RECIP.NAME RECIPIENT AFFILIATION Document Control Branch (Document Control Desk)

SUBJECT:

Forwards proprietary

& non-proprietary repts from GE re GL 94-03, "Intergranular Stress Corrosion Cracking in BWRs." List of repts,encl.Encls withheld,per 10CFR2.790(b)(i).

DISTRIBUTION CODE:

AP01D COPIES RECEIVED:LTR ENCL SIZE:

TITLE: Proprietary Review Distribution Pre Operating License

& Operating R

E NOTES:

RECIPIENT ID CODE/NAME PD1-1 LA HOOD,D INTERNAL: ACRS OGC/HDS3 EXTERNAL: NRC PDR COPIES LTTR ENCL 1

1 1

1 1

1 1

0 RECIPIENT ID CODE/NAME PD1-1 PD LE CENTER 01 COPIES LTTR ENCL 1

1 1

1 0

D U

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NOTE TO ALL "RIDS" RECIPIENTS:

PLEASE HELP US TO REDUCE WASTE. TO HAVE YOUR NAME OR ORGANIZATION REMOVED FROM DISTRIBUTION LISTS OR REDUCE THE NUMBER OF COPIES RECEIVED BY YOU OR YOUR ORGANIZATION, CONTACT THE DOCUMENT CONTROL DESK (DCD)

ON EXTENSION 415-2083 TOTAL NUMBER OF COPIES REQUIRED:

LTTR 7

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CATEGORY 2 REGULATORY INFORMATION DISTRIBUTION SYSTEM (RIDS)

ACCESSION NBR:9704100242 DQC. DATE: 9'7/04/08 NOTARIZED:

YES.

DOCKET FACIL: 50-220 Nine Mile Point Nuclear Stations Unit ii Niagara Powe 05000220 AUTH. NAME AUTHOR AFFILIATION

" MCCORMICK'. J.

Niagara Mohawk Power Corp.

'-~

REC IP. NAME RECIPIENT AFFILIATION Document Control Branch (Document Control Desk)

SUBJECT:

Forwards proprietary 5 non-proprietary repts from GE re GL 94-03'Intergranular Stress Corrosion Cracking in BMRs. " List of repts> encl. Encls withheldi per 10CFR2. 7'VO(b ) ( i).

DISTRIBUTION CODE:

AP01D COPIES RECEIVED: LTR ENCL SIZE:

TlTLE: Proprietary Review Distribution Pre Operating License

';c NOTES:

l+ 38 Operating R

RECIPIENT lD CODE/NAME PDi-1 LA HOQDi D INTERNAL:

ACRS QGC/HDS3 EXTERNAL:

NRC PDR COPIES LTTR ENCL 1

1 1

1.

1 1

1 0

1 0

RECIPIENT ID CODE/NAME PDi-1 PD FILE CENTER 01 COP IES LTTR ENCL 1

1 0

Y

, D C

E NOTE TO ALL "RIDS" RECIPIENTS:

PLEASE HELP US TO REDUCE WASTE. TO HAVE YOUR NAME OR ORGANIZATION REMOVED FROM DISTRIBUTION LISTS OR REDUCE THE NUMBER OF COPIES RECEIVED BY YOU OR YOUR ORGANIZATION, CONTACT THE DOCUMENT CONTROL DESK (DCD)

ON EXTENSION 415-2083 TOTAL NUMBER QF COPIES REQUIRED:

LTTR 7

ENCL 5

\\

NiAGARAMOHAWK G E N E RAT I 0 N BUSiNESS CROUP MARTINJ. McCORMICKJR. P.E.

Vice President Nuciear Engineering NINE MILEPOINT NUQI.EAR BTATIONJLAKEROAD. P.O. BOX 63. LYCOMING,NEW YORK 13093/TELEPHONE (3I5) 349.2660 FAX(3(5) 349-2605 April 8, 1997 NMPIL 1200 U.S. Nuclear Regulatory Commission Attn: Document Control Clerk Washington, DC 20555 RE:

Nine MilePoint Unit 1 Docket 50-220

Subject:

Generic Letter 94-03 "Intergranular Stress Conosion Cracking (IGSCCl in Boiling 8'ater Reactors" Gentlemen:

By letters dated January 6, 1995 and January 23, 1995, Niagara Mohawk Power Corporation (NMPC) submitted an application for repairs to the Nine MilePoint Unit 1 (NMP1) core shroud. The shroud repairs and use of stabilizer assemblies (tie rods) were submitted as an alternate to the requirements of the ASME Code,Section XI, as allowed by 10CFR50.55a (a)(3)(i). The staff provided approval of the proposed alternate repair by letter dated March 31, 1995.

The approval letter and attached safety evaluation required NMPC to submit re-inspection plans for the shroud and repair assemblies prior to the next refueling outage planned for 1997.

By letter dated February 7, 1997, NMPC submitted plans for re-inspection of the core shroud vertical welds and repair assemblies in accordance with the criteria provided by the "BWR Vessel and Internals Program" (BWRVIP) document BWRVIP-07.

During the 1997 refueling outage, NMPC conducted core shroud vertical weld inspections per the approved documents and observed vertical weld cracking which exceeded the screening criteria. Additionally, inspections of the four tie rod assemblies found the tie rod nuts to have lost some preload and identified damage to the lower wedge retainer clips on three tie rods.

Further details of the as found conditions are provided in Enclosures 1 and 2.

By phone calls on March 20, 1997 and April2, 1997, NMPC informed the staff of the inspection findings and indicated that analysis of the vertical weld cracking and restoration plan of the shroud tie rod assemblies would be submitted to the NRC prior to restart of the unit. This letter and the attached enclosures provide root cause, corrective actions and the final design documentation which establishes the acceptability of the as found vertical weld 9704100242 970408 PDR ADOCK 05000220 P 'DR

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