ML20076E093

Forwards Response to 830725 Request for Addl Info Re Main Transformer Failures.Two Oversize Drawings Encl.Aperture Cards Available in PDR

ML20076E093
Person / Time
Site:	North Anna
Issue date:	08/17/1983
From:	Stewart W VIRGINIA POWER (VIRGINIA ELECTRIC & POWER CO.)
To:	Clark R, Harold Denton Office of Nuclear Reactor Regulation
References
449, NUDOCS 8308240121
Download: ML20076E093 (8)

Text

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VINUINIA ELEcTMIC AND POWER COMPANY NICHMONIs VIMOINIA 2H261 f

W.L.NTEWART Vses Poseensar Nrctuan Oramations August 17,1983 L

Mr. Harold R. Denton, Director Serial No. 449 Office of Nuclear Reactor Regulation N0/JHL:acm Attn:

Mr. Robert A. Clark, 9hief Docket Nos. 50-338 Operating Reactors Branch No. 3 50-339 Division of Licensing License Nos. NPF-4 U. S. Nuclear Regulatory Commission NPF-7 Washington, D. C. 20555 Centlemen:

VIRGINIA ELECTRIC AND POWER COMPANY i

NORTH ANNA POWER STATION UNIT NOS. 1 AND 2 RESPONSE TO THE REQUEST FOR INFORMATION CONCERNING MAIN TRANSFORMER FAIL.URES AT NORTH ANNA POWER STATION In the NRC letter dated July 25, 1983, Vepco was requested to provide additional information concerning the main transformer failures that had occurred at North Anna Unit Nos. I and 2.

Enclosed are the responses to the questions that were provided in your July 25, 1983 letter.

Very truly yours, k! L_M 3Ny W. L. Stewart Enclosure cc:

Mr. James P. O'Reilly Regional Administrator Region II Mr. M. B. Shymlock NRC Resident Inspector

~

North Anna Power Station l

foot 8308240121 830817 PDR ADOCK 05000338 S

PDR l

ENCLOSURE RESPONSE TO THE REQUEST FOR INFORMATION CONCERNING MAIN TRANSFORMER FAILURES AT NORTH ANNA POWER STATION QUESTION 1: Submit a summary of the tests performed by Vepco on each of the seven transformers prior to their failure.

The summary should include type of test, test results, and test acceptance criteria (noting at what point Vepco would consider the transformer suspect).

Also address all other

, test types which may be a part of Vepco's normal routine

' maintenance procedures.

ANSWER 1:

Before energizatio. and af ter any major incident involving these transformere the following routine tests were performed and all results were satisfactory.

Also listed is our acceptance guide.

These are the values which require further investigation.

They do not necessarily indicate a problem exists, but we do investigate and explain results outside of this range.

TEST ACCEPTANCE GUIDELINE Insulation Power Factor Less than 1%

Bushing Insulation Power Factor Less than 1%

Transformer Excitation Less than 120% of previous data Transformer Turns Ratio Less than 1.5%

deviation from previous data Bushing Capacitance Less than 110% of previous nameplate data Lightning Arrestors Doble Engineering guidelines

(

Oil Dielectric

• more than 26kV ASIM 1816 40 mil gap

(

Oil Moisture Content

• Less than 25 ppm l

Oil Power Factor

• Less than.1%

Dissolved Gas-In-Oil

• Less than 240 ppm H 160ppmCd 115 ppm C26 190 ppm C H 2q l

trace C,H 580 ppm'Cb

• American Nuclear Insurer's Guide l

l l

l

In addition to the routine tests listed above induced voltage tests were performed on all units on generator #2 after the fourth failure.

The tests were conducted from August 2 through August 6, 1981.

Tests were performed on two Westinghouse transformers and one General Electric transformer.

The maximum test voltage was 150% of the nameplate rating. We duplicated the one hour corona test as closely as field conditions allowed.

All test results were satisfactory and all scheduled tests were performed with the exception of the last Westinghouse transformer sertal no.

7002099.

The failure of the test equipment prevented

, completion of the last portion of tests on this unit.

~ Because this unit had just been factory repaired and complete factory tests performed and the test set was unavailable the remaining portion of the induced voltage tests was not required. The transformers were energized and operated satisfactorily for approximately 1 year without incident.

After the sixth failure we again decided to perform induced voltage tests.

The tests were performed on the 3

transformers on Generator #1, which included one McGraw Edison transformer and two Westinghouse transformers.

The maximus test voltage was 135% of the nameplate rating.

Again we duplicated the one hour corona test as closely as field conditions allowed.

All test results were satisfactory.

After these tests the transformers were energized on backfeed and the B phase transformer failed approximately 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> after energization.

QUESTION 2: Westinghouse Drawing HAM 707.03 indicates the main transformer is shipped on its side.

Submit a summary of Vepco's shipping procedures and practices.

ANSWER 2:

The Westinghouse generator step-up transformers at North Anna Power Station were designed to be shipped on their sides.

The only additional support required inside the transformer tank are the shipping braces for the bridge structure inside the tank and the internal shipping wedge retainers around the inside of the tank, Items #44 and #45 on the Drawing No. HAM 707-03. The Westinghouse Drawing No.

HAM 707-75, "Inside Assembly" has instructions on installing and removing the shipping supports for the bridge structure.

Whenever one of these transformers is shipp2d, supports are installed using the shipping bracing which came in the transformers from the factory or a shipping brace fabricated from clean kiln dried boards as specified in the manufacturers' instruction leaflet.

The shipping supports and bolts are painted yellow before installation so that they can be spotted easily and removed af ter shipping is complete and the transformer is back in an upright position.

A copy of the Drawings No. HAM 707-1, 3,

and 75 are attached.

QUESTION 3: Submit a summary of the modifications to the main trans-former and generator systems completed and planned as a result of the failures. The summary should also include any additions or changes in the administrative, maintenance, and fire protection procedures.

ANSWER 3:

All of the Westinghouse GSU transformers at North Anna have been replaced with General Electric (Unit #2) and McGraw 2

Edison (Unit #1) transformers.

Each of the replacement GSU transformers incorporate the manufactures latest design features including their conservator tank oil preservation system.

All of these transformers were delivered and installed in the first half of 1963.

The following modifications were recommended as a result of Vepco's analysis of the 22 KV main generator failure:

1.

Install 24 KV surge arresters on the isolated phase bus.

2.

Install stress cone terminations (15 KV minimum) on the generator neutral grounding cable. This cable should be shielded cable.

It should be isolated, with foam sealant, from metallic edges.

The neutral grounding transformer should have at least a 125 KV BIL rating.

3.

The generator frame grounding should be equivalent to 1, 1000 MCM copper conductor at two points, terminated in compression lugs.

4.

The generator frame connection to.ne neutral enclosure should be 1 - 2000 MCM copper conductor terminated with compression lugs.

5.

Clearance between the isolated phase bus flexible elbows and the bus duct should be increased to the manufac-l turer's recommended value.

l l

6.

Continuous monitoring recorders should be installed to record generator and isolated phase bus electrical parameters.

-Modifications 2-5 have been completed on North Anna 1.

Modifications 1 and 6 are being engineered for installation.

Modifications 2-5 have been completed on North Anna 2.

Modification 6

is being engineered for installation.

Modification 1 is being evaluated.

l Also recommended was the cleaning and inspecting of,the isolated phase bus, ducts and insulators during refueling outages.

l A study has been completed of possible fire protection modifications for the transformer area. The recommendations of the study include the following:

a) Raise the height of the dike which surrounds the transformer area.

l l

~

{

waWam b) Add firewalls at each end of the transformer area.

c) Modify the drainage system to accommodate larger flow rates.

These recommendations are being evaluated for possible installation in 1984.

No procedural changes have been recommended.

QUESTION 4:

Submit a summary on the amount of shutdown time incurred as

, a result of the main transformer failures.

ANSWER 4:

Failure Dates Date Replacement Re-energized 11-29-80 12-10-80 11 days 06-19-81 07-02-81 13 days 07-03-81 07-25-81 22 days 07-25-81 08-12-81 18 days 08-22-82 08-30-82 8 days 11-16-82 12-05-82 19 days

• 12-05-82 03-08-83 93 days

• The shutdown time for tLe December 1982 failure included time for concurrent generator repairs.

QUESTION 5:

Submit the results of Vepco's investigation on the seventh main transformer failure.

ANSWER 5:

This transformer was one of seven units purchased from Westinghouse in February 1971. This transformer was shipped in September 1973; installed by February 1974 serving North Anna Unit #1.

Af ter the failure of the "C" phase unit in this bank (see #6 report) constant oil pressure system (COPS) was installed; barrel insulation cylinder around HV bushing was removed, top of transformer internals were carefully inspected, oil processed per Westinghouse cold weather re-impregnation rules, and prepared for service.

After 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of energization, including 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> carrying load, transformer failed at 12:38 p.m., December 5, 1982.

Internal inspection disclosed two burn marks which may have been the terminals of an are under oil.

One point was on the HV bushing lead 6 1/2" below the spun copper corona shield.

In the HV bushing lead there was a 1/2"-3/4" diameter hole burned through 1"-1 1/4" crepe tape.

The second are burn was on LV winding 41" from the HV burn mark.

The transformer was returned to the factory for inspection and teardown. A third are mark even more remote from the HV bushing was found on the side of the second LV coil.

The factory engineers could find no reason for this failure even after the teardown inspection.

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