ML081200869

Request for Additional Information Regarding Proposed License Amendment Request One-Time Five-year Extension to Type a Test Interval

ML081200869
Person / Time
Site:	Surry
Issue date:	04/24/2008
From:	Gerald Bichof Virginia Electric & Power Co (VEPCO)
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
08-0176, RG-1.163
Download: ML081200869 (27)

Text

VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND. VIRGINIA 23261 April 24, 2008 10 CFR 50.90 u.s. Nuclear Regulatory Commission Serial No. 08-0176 Attention: Document Control Desk NL&OS/ETS R1 Washington, D.C. 20555 Docket No. 50-281 License No. DPR-37 VIRGINIA ELECTRIC AND POWER COMPANY (DOMINION)

SURRY POWER STATION UNIT 2 REQUEST FOR ADDITIONAL INFORMATION REGARDING PROPOSED LICENSE AMENDMENT REQUEST ONE-TIME FIVE-YEAR EXTENSION TO TYPE A TEST INTERVAL In a December 17, 2007 letter (Serial No. 07-0802), Dominion requested an amendment, in the form of a change to the Technical Specifications (TS) to Facility Operating License Number DPR-37 for Surry Power Station Unit 2. The proposed change will permit a one-time five-year exception to the ten (10) year frequency of the performance-based leakage rate testing program for Type A tests as required by Regulatory Guide (RG) 1.163. This one-time exception to the requirement of RG 1.163 will allow the next Type A test to be performed no later than October 26, 2015.

In a March 20, 2008 letter, the NRC staff requested additional information to complete their review of the proposed TS change. The attachments to this letter provide the information requested by the NRC staff.

The information provided in this letter does not affect the conclusion of the significant hazards consideration discussion provided in Dominion's December 17, 2007 letter.

Serial No. 08-0176 Docket No. 50-281 Page 2 of 3 Should you have any questions or require additional information, please contact Mr. Thomas Shaub at (804) 273-2763.

Very truly yours, t!~Z~~6 Vice President - Nuclear Engineering Commitments made in this letter: None.

Attachments

1. Response to Request for Additional Information Regarding Proposed License Amendment Request, One-Time Five-Year Extension to Type A Test Interval, Containment Test and Inspection

2. Type 8 and C Penetrations Test Results and Current Test Schedule

3. Containment Mechanical Penetration Test History and Current Test Frequency COMMONWEALTH OF VIRGINIA )

)

COUNTY OF HENRICO )

The foregoing document was acknowledged before me, in and for the County and Commonwealth aforesaid, today by Gerald T. Bischof, who is Vice President - Nuclear Engineering, of Virginia Electric and Power Company. He has affirmed before me that he is duly authorized to execute and file the foregoing document in behalf of that Company, and that the statements in the document are true to the best of his knowledge and belief.

Acknowledged before me this .:2£.I....::.. 4'

'11171'day of. ~ ,2008.

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Clil. MULL NaIaIY NIle Notary Public C. . . .,**- 01 'i1J1I511O C......I.n

Serial No. 08-0176 Docket No. 50-281 Page 3 of 3 cc: U.S. Nuclear Regulatory Commission Region II Sam Nunn Atlanta Federal Center 61 Forsyth Street, SW Suite 23T85 Atlanta, Georgia 30303 State Health Commissioner Virginia Department of Health James Madison Building - i h floor 109 Governor Street Suite 730 Richmond, Virginia 23219 NRC Senior Resident Inspector Surry Power Station Mr. S. P. Lingam NRC Project Manager U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 0-8 G9A 11555 Rockville Pike Rockville, Maryland 20852

Serial No. 08-0176 Docket No. 50-281 Attachment 1 RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING PROPOSED LICENSE AMENDMENT REQUEST ONE-TIME FIVE-YEAR EXTENSION TO TYPE A TEST INTERVAL CONTAINMENT TEST AND INSPECTION Virginia Electric and Power Company (Dominion)

Surry Power Station Unit 2

Serial No. 08-0176 Docket No. 50-281 Attach ment 1 Request for Additional Information Regarding Revision of Technical Specification Pertaining to the Containment Leakage Rate Testing Program Surry Power Station Unit 2

Background

By application dated December 17, 2007, Virginia Electric and Power Company (the licensee) proposed a license amendment to change Surry Power Station, Unit NO.2 (Surry 2) Technical Specifications (TS). The proposed change would permit a one-time 5-year exception to the 10-year frequency of the performance based leakage rate testing program for Type A tests, as required by Regulatory Guide (RG) 1.163. To complete their review of the proposed TS changes, the Nuclear Regulatory Commission (NRC) staff requests the licensee's response to the following:

NRC Question 1 Please provide a summary list of those containment penetrations (including their test schedule intervals) that have not demonstrated acceptable performance history in accordance with the primary containment leakage rate program.

Dominion Response Electrical Penetrations In accordance with the guidance of NEI 94-01, Rev. 0, electrical penetrations with acceptable performance may be placed on a 10 year testing interval after passing three consecutive refueling outage tests. If the penetration fails a test, it is returned to the short interval (every outage) until it again passes three consecutive refueling outage tests.

Under Option B testing, the electrical penetrations can go up to 10 years without a Type B test. The historical test results at Surry Unit 2 support this increased interval.

However, Surry Unit 2 limits the extended interval to 5 years. Furthermore, if during routine electrical preventative maintenance an electrical penetration is found with the nitrogen charge out of tolerance, the penetration is also tested during the next refueling outage. This testing between the extended intervals provides additional assurance that containment integrity is maintained.

Surry Unit 2 has no electrical penetrations with an unacceptable Type B performance history. Attachment 2 includes tables that provide the test history for the electrical penetrations and the current required test frequency.

Page1of10

Serial No. 08-0176 Docket No. 50-281 Attachment 1 Mechanical Type C Penetrations In accordance with the guidance of NEI 94-01, Rev. 0, mechanical penetration valves with acceptable performance may be placed on a 60-month testing interval after passing two consecutive refueling outage tests. If the valve fails a test, it is returned to the short interval (every outage) until it again passes two consecutive refueling outage tests. includes tables that provide the test history and the current required test frequency for the mechanical penetrations. The unacceptable leakage rate test results for the mechanical penetrations are identified in bold type in the tables. These penetrations were placed on the shorter interval and have been or will be tested each refueling outage until two acceptable tests were/are performed.

The 5-year extension to the Type A test interval will have no effect on the Type Band C test programs or the test frequencies.

NRC Question 2 Please provide a summary table for Type B and Type C tests (including the interval schedule dates) that are planned to be performed prior to and during the requested 5-year extension period of the integrated leak rate test (ILRT) interval.

Dominion Response As noted above, Attachments 2 and 3 include tables that provide the test history and the current test frequency for Unit 2 electrical and mechanical penetrations, respectively.

Currently, the electrical penetrations are on a 60-month test schedule.

With few exceptions, the mechanical penetrations are also on a 60-month test schedule.

Bold entries in the table are the penetration/valves with "as-found" leakage results that exceeded the acceptance criterion and required an increased frequency in testing.

NRC Question 3 Regulatory Position C.3 of RG 1.163 recommends that visual examinations should be conducted prior to initiating a Type A test, and during two other refueling outages before the next Type A test based on a 10-year ILRT interval. Please describe, with a schedule, how you would supplement this 10-year interval-based visual inspections requirement for the requested 15-year ILRT interval.

Page 2 of 10

Serial No. 08-0176 Docket No. 50-281 Attachment 1 Dominion Response Per Section 9.2.1 of NEI 94-01, Rev. 0, and Regulatory Position C.3 of RG 1.163, the normal inspection frequency requires three examinations in the 10-year interval. Two examinations are required during the 10-year interval with a third examination just prior to the Type A test.

In accordance with NEI 94-01, Rev. 0, a general visual examination is performed of the accessible interior and exterior surfaces of the containment and components, including the liner plate, for structural problems that may affect either the containment structure leakage integrity or the performance of the Type A test. Surry Unit 2 has completed general visual examinations during the current 10-year Integrated Leak Rate Test (ILRT) interval in:

• October 2003

• October 2006 Based upon approval of the 5-year extension to the ILRT interval, two additional examinations will need to be completed, one of which will be during the outage of the Type A test (October 2015). The other examination will be scheduled during one of the following outages:

• October 2009

• October 2012 In addition to these examinations, general visual examinations of the containment liner are performed in accordance with the IWE Section of the ASME Code.

NRC Question 4 Please provide information relative to the findings (if any) and actions taken where existence of or potential for degraded conditions in inaccessible areas of the containment structure and metallic liner were evaluated based on conditions found in accessible areas as required by Title 10 of the Code of Federal Regulations (10 CFR), Part 50, Section 50.55a(b)(2)(viii)(E) and 10 CFR 50.55a(b)(2)(ix)(A).

Dominion Response No evaluations per 10 CFR 50.55a(b)(2)(viii) (E) or 10 CFR 50.55a(b)(2)(ix)(A) were required for Surry Unit 2 from the conditions found during examinations.

Page 3 of 10

Serial No. 08-0176 Docket No. 50-281 Attachment 1 NRC Question 5 In Section 4.6 of Attachment 1 to the licensee's letter dated December 17, 2007, it is stated that no augmented Category E-C examinations are planned for the second 10-year interval IWE examinations. Please provide a summary of areas that were identified for augmented examination in the first 10-year interval IWE. Considering the proposed TS change per the licensee's letter dated December 17, 2007, to allow a 5-year extension of Type A test interval, please provide specific information to justify discontinuing the augmented examination of suspect area(s) during the second 10-year IWE interval.

Dominion Response A review was conducted for Surry Unit 2 per IWE-1241, Examination Surface Areas (1992 Edition with 1992 Addenda of ASME Section XI) for the initial 10-year Category E-C examination requirements. No areas were deemed susceptible to accelerated degradation and aging; therefore, augmented examinations per Category E-C were not required. This information is documented in the first 10-year Containment lSI Plan for Surry Unit 2. The examinations performed during the first 10-year interval identified no concerns with the containment metallic liner or other IWE components. Based upon the IWE-1241 evaluation and the first 10-year examination results, the second 10-year inspection interval again has no Category E-C (2001 Edition through 2003 Addenda of ASME Section XI) examination requirements.

NRC Question 6 Please provide a summary of any degradation identified during past inspection of the containment moisture barrier (e.g., between liner and concrete floor)? If any, please describe the condition, corrective actions, and additional monitoring program.

Dominion Response The design of the containment structure features a concrete cylinder and dome. The interior carbon steel liner is attached to and supported by the reinforced concrete, and the liner and concrete floor were coated during original construction. The concrete floor slopes away from the liner toward a center drain, minimizing the potential for water to stand in the vicinity of the liner-to-concrete interface. Inspections of the containment liner have been conducted on a regular basis as a part of the preparation for containment integrated leak rate testing (Type A). As a result of these inspections, corroded areas of the liner have periodically been cleaned and recoated. Recoated areas have been limited to the zone beginning at the liner to floor interface extending approximately eight inches above the basement floor.

Additional inspections were conducted in 1998 (Unit 1) and 1999 (Unit 2) to document acceptability of the liner as a part of the ASME 1992 Addenda of Subsection IWE Page 4 of 10

Serial No. 08-0176 Docket No. 50-281 Attachment 1 "Requirements for Class MC and Metallic Liners of Class CC Components of Light-Water Cooled Power Plants ". The initial assessment found only cracking and blisters in the liner coating, loose surface rust below the coating defects, and slight gaps (1/32" maximum at the surface) between the liner and concrete at the interface joint. No distress was observed in the adjacent concrete, and no evidence of extruded corrosion product was observed. The gaps were filled with a tight scale. The corrosion product required to fill a 1/32" gap corresponds to a material loss of approximately 4 mils (assuming a volumetric expansion of 7 to 1). Ultrasonic testing (UT) data verified the liner plate thickness just above the interface joint and served as a baseline for visual evaluation of the crevice area. It was concluded that the liner condition down to the interface joint had no significant deterioration based upon UT measurement. It was further concluded that the liner extending below the concrete surface had no significant deterioration based upon the absence of distress in the concrete and the lack of extruded corrosion product from the joint. Review of the initial inspection findings determined that a more thorough assessment of the containment liner was required below the concrete floor.

Visual inspection of the Unit 2 containment steel liner to concrete floor interface joint was performed in 2000 by representatives from Materials/lSI Engineering and Civil Design Engineering. The majority (97%) of the steel liner to concrete floor slab interface was free from defects or had only minor surface cracks and blisters of the coating system. Opening these areas revealed little or no corrosion of the steel and a tight joint between the concrete and liner surface. The remaining areas (-3%) of the steel liner to concrete floor slab interface had longer cracks (-6" to 18") in the coating system. These areas typically had rust discoloration around the crack. Opening these areas revealed some loose surface rust. At the worst point, a gap of less than 1/32" was observed between the concrete and the liner plate. This gap was completely filled with a tight scale. No distress was observed in the concrete and no moisture was evident in or around the joint. Based upon these inspection findings, no additional destructive testing or inspection was warranted. It was evident that the steel liner in close contact to the concrete floor slab showed no evidence of significant corrosion.

Furthermore, in areas with slight gaps, corrosion continued only to the point of contacting the concrete before passivation arrested further corrosion. This is expected as concrete usually provides protection against rusting because of the highly alkaline environment of the Portland cement paste.

In addition, seven two-feet long sections of concrete were excavated in the Unit 1 containment to determine the depth and extent of corrosion below the interface joint, and UT measurements of the liner thickness were performed in these areas. None of the seven areas that were excavated and investigated showed evidence of significant liner thinning at or below the joint. Based upon the results of the Unit 1 inspection, excavation and UT and the visual inspections performed in Unit 2, it was concluded that the Unit 2 liner below the concrete floor and the interface joint between the containment steel liner and concrete floor were in good material condition. No additional actions were recommended and no other issues were identified during or subsequent to the inspection.

Page 5 of 10

Serial No. 08-0176 Docket No. 50-281 Attachment 1 It was also concluded that the condition of the containment liner below the concrete floor could be accurately assessed through visual examination of the interface joint and adjacent concrete. Therefore, in the absence of distress in the adjacent concrete, and with a lack of extruded corrosion product from the interface joint, no concerns exist.

In the fall 2003, an inspection of the Unit 2 containment liner to concrete interface was performed and revealed that the concrete edge at the interface to the liner had a round bevel (approximately 1/4 inch) applied during concrete installation. At some point in the past, this small gap between the liner and the concrete was filled with silicone caulk.

Although the caulk serves no design related function, the caulk was essentially installed around the entire containment perimeter. Although the caulk had some cracks, it was in relatively good condition, was elastic, and was firmly adhered to the concrete. The caulk was estimated to have been installed at least 10 to 15 years prior. Small sections of the caulk were removed in approximately 12 different locations. Only minor surface rust was noted behind the caulk. Two areas of the liner that had visible rust and exfoliation just above the caulk were inspected. The caulk was removed and the loose surface rust was also removed. The liner was then UT inspected. One area measured 0.399 inches, and the other area measured at 0.417 inches. (Nominal thickness for the liner is 0.375 inches).

In summary, it was concluded that the existing caulk was firmly adhered to the concrete and was not expected to dislodge and become debris. In addition, the liner was in good condition with only minor surface rust behind the caulk. A Plant Issue Report was issued to document the condition. In response to the Plant Issue Report, the Unit 2 containment steel liner to basement concrete floor (Elevation - 27'-7") interface joint was restored. The work scope included removal of the caulk and approximately 2" x 2" of concrete around the liner perimeter; cleaning and coating of the exposed liner; and restoration of the concrete floor.

NRC Question 7 Relative to the results of the last three Type A tests included in section 4.2 of Attachment 1 to the licensee's letter dated December 17, 2007, there is a significant reduction in measured as-found leakage from 0.414 LA (May 1991) to 0.05 LA (October 2000). Please provide further information relative to this reduction. Also, provide the actual as-left leakage results and their comparison with the allowable leakage rate specified in the plant TSs.

Dominion Response Many factors may affect the results of a Type A test as indicated below.

• The fundamental approach to testing has changed since 1995. Prior tests extensively drained and vented the systems that penetrated the containment boundary. However, since 10 CFR 50 Appendix J, Option B, went into effect, the containment is isolated and the intent is to measure leakage from the structure, Page 6 of 10

Serial No. 08-0176 Docket No. 50-281 Attachment 1 not from leakage paths that are already included in the local leak rate test (LLRT) program.

• As indicated by the results of the past three As-Found leakage tests, Surry Power Station is committed to maintaining containment LLRT leakage values very low by maintaining equipment condition.

• Integrated Type A leakage rates are not conducive to trending due to the many variations that occur when conducting the tests and analyzing the data.

• During the 2000 Unit 2 integrated leakage Type A test, Unit 1 tripped from full power during Unit 2 pressurization. This caused changes to Surry's cooling water system (common to both units), which affected the steady state conditions on Unit 2. The indicated value of induced leakage rate settled at a very stable value slightly above the upper limit. Seven hours and six minutes after the induced leak rate test began, the leak was secured. Following a brief stabilization period, the Type A test was restarted. This extended test time caused a significant reduction in measured as-found leakage from 0.59 La for the first test to 0.061 La for the second test.

Per ANSI/ANS 56.8 - 1994 and NEI 94-01, "the As-Found Type A test leakage rates must be less than the acceptance criterion of 1.0 La given in the Plant Technical Specifications. Prior to entering a mode where containment integrity is required, the As-Left Type A leakage rate shall not exceed 0.75 La."

Unit 2 As-Found Type A History Dates: Nov 1986 May 1991 Oct 2000 Type A Test Result 0.638 La 0.418 La 0.060 La Total Leakage Savings 0.090 La 0.034 La 0.001 La As-Found Type A Total: 0.728 La 0.452 La 0.061 La Unit 2 As-Left Type A History Dates: Nov 1986 May 1991 Oct 2000 Measured Leak Rate with UCL (Upper Confidence Limit) Margin 0.635 La 0.414 La 0.050 La Type C Penalty 0.003 La 0.004 La 0.010 La As-Left Type A Total: 0.638 La 0.418 La 0.060 La Page 7 of 10

Serial No. 08-0176 Docket No. 50-281 Attachment 1 NRC Question 8 If bellows are used on penetrations through containment pressure-retaining boundaries at Surry 2, please provide information on their location, inspection, testing and operating experience with regard to detection of leakage through the penetration bellows.

Dominion Response The single fuel transfer tube for the Surry Unit 2 containment structure is the only penetration that utilizes a bellows arrangement to establish seals between the containment liner, transfer cavity, spent fuel pool, and the penetration itself. Pressure test channels are installed on the weld interface between the penetration piping and the containment liner and were used to verify weld quality during initial construction. There are no other test devices installed on the penetration piping and bellows. Therefore, the ability to perform local leak rate testing is not available. Penetration integrity is verified during the performance of the ILRT (Type A). Surry has no record of bellows leakage.

Visual inspection is impossible because two of the three bellows are enclosed in sleeves in the fuel building and between the fuel and containment buildings. The third bellows is located between the containment and the fuel transfer canal, which is a three foot opening, covered by permanent shielding. The fuel transfer tube is sealed inside the containment building with a blind flange, equipped with a double o-ring seal, which is Type B tested.

NRC Question 9 Please provide an overview of the containment liner coating inspection program at Surry 2 including inspection intervals, findings and corrective actions identified during recent inspections.

Dominion Response Engineering visually inspects the accessible areas of the containment liner coating each refueling outage. Indications of coating damage include cracking, peeling, wear, mechanical damage, and blisters. Coating defects, along with locations, are recorded, and Engineering determines which areas require repair. A Condition Report is generated for the inspection results. Blisters and loose coating are removed to sound and adherent coating material for follow-up base metal assessments during the same refueling outage.

The three most recent inspections of the Surry Unit 2 containment liner coating (November 2003, May 2005, and October 2006) identified indications of mechanical damage to the coating.

Mechanical damage to coating usually results from the impact of heavy equipment (typically scaffolding) as workers lift and move the equipment. This is the most common type of coating damage to the liner.

Page 8 of 10

Serial No. 08-0176 Docket No. 50-281 Attachment 1 If assigned repair areas can not be repaired during the current outage due to time constraints or inaccessibility, an engineering review is conducted, the repairs are deferred for future refueling outages, and a Condition Report is written.

NRC Question 10 In Section 4.6 of Attachment 1 to the licensee's letter dated December 17, 2007, the following is stated:

'The second ten-year interval IWE program for Surry meets the requirements of the 2001 Edition through the 2003 Addenda of [American Society of Mechanical Engineers] ASME Section XI. Categories E-D and E-G are no longer part of the Code. The relief requests above are not needed for the second ten-year interval since examination of seals and gaskets and bolt torque or tension tests are no longer addressed by ASME Section XI. As such, the extension request will no longer impact the ASME Section XI program upon second interval start for each unit.

Given the short time period remaining in the first ten-year IWE 151 interval for Surry Unit 2, and the Type Band C tests performed during the first ten-year IWE lSI interval, the Appendix J, Type A extension is seen as having a negligible impact."

Please provide clarification for the following:

a. The licensee's letter dated December 17, 2007 is for Surry 2. It is not clear to the NRC staff why both units are being discussed in the above paragraph.

b. Please discuss the examination method(s) in Surry 2 to ensure leak-tight integrity of penetrations with seals and gaskets, and bolted connections.

c. Please clarify the last sentence of the subject paragraph (Given the short time period remaining .. .).

Dominion Response to 10a The second ten year IWE programs are identical for both Surry Units 1 and 2. Although the introductory sentence in the paragraph included a discussion of both units, the extension request is for Unit 2 only.

Dominion Response to 10b Category E-D (seals, gaskets, and moisture barriers) examinations were alternatively addressed by relief request RR-IWE2 approved by NRC letter dated April 14, 1999 (first 1O-year interval). The alternative request addressed Item Nos. E5.10 (seals) and E5.20 (gaskets). Surry Unit 2 has no Item No. E5.30 (moisture barriers) items. The alternative basis takes credit for the Appendix J, Type B test to adequately address the integrity of the seals and gaskets. The Appendix J, Type B test remains unaffected by the proposed Appendix J, Type A test frequency extension and continues to ensure the integrity of the seals and gaskets.

Page 9 of 10

Serial No. 08-0176 Docket No. 50-281 Attach ment 1 the proposed Appendix J, Type A test frequency extension and continues to ensure the integrity of the seals and gaskets.

Category E-G (pressure retaining bolting) examinations were alternatively addressed by request RR-IWE5 approved by NRC letter dated April 14, 1999 (first 10-year interval).

Item No. E8.10 was not addressed by the alternative requirement and the required visual VT-1 examinations have been performed in accordance with the Code. Item No.

E8.20 required a bolt torque or tension test and was the subject of the alternative request. The acceptability of the alternative request was based upon the Appendix J, Type 8 test which indirectly proved the adequacy of the bolt torque or tension by maintaining acceptable leak rates. The Appendix J, Type 8 test remains unaffected by the proposed Appendix J, Type A frequency extension. The proposed alternatives, the visual VT-1 examinations and the acceptable performance of Appendix J, Type 8 tests continue to ensure bolting integrity.

Testing is performed using the "Make-up" method and evaluated against station established administrative limits. If any of the limits are exceeded, then an engineering evaluation is performed and repairs completed if necessary.

• Equipment hatch, escape air lock, and interface between the air lock and hatch - The escape air lock is pressurized to Pa which simultaneously tests door seals, actuation rod penetrations, electrical penetrations, and port holes. The equipment hatch and interface is equipped with a double o-ring seal and the test pressure is applied between the two o-rings.

• The fuel transfer tube is sealed inside the containment building with a blind flange, equipped with a double o-ring seal. Test pressure is applied between the two o-rings to perform the Type 8 test.

• The personnel air lock is pressurized to Pa which simultaneously tests door seals, actuation rod penetrations, electrical penetrations, and port holes.

• Electrical penetrations use a double o-ring to seal the flange and double compression seals for the feed-throughs. Surry maintains nitrogen pressure on the seals at all times. These pressures are monitored and Type 8 leak tested during the next refueling outage if pressures are outside specified limits.

Dominion Response to 10c The remaining examinations (visual, VT-3) for Surry Unit 2 are associated with wetted surfaces of submerged areas (Item No. E1.12 Category E-A, ASME 2001 Edition through the 2003 Addenda). These examinations are scheduled for completion by the end of the spring 2008 refueling outage.

Type Band C testing will continue during the extension in accordance with NEI 94-01, Rev. 0, ensuring the integrity of the penetrations.

Page 10 of 10

Serial No. 08-0176 Docket No. 50-281 Attachment 2 TYPE BAND C PENETRATIONS TEST RESULTS AND CURRENT TEST SCHEDULE Virginia Electric and Power Company (Dominion)

Surry Power Station Unit 2

Serial No. 08-0176 Docket No. 50-281 Attachment 2 TYPE B PENETRATIONS TEST RESULTS AND CURRENT TEST SCHEDULE Appendix J - Option 8, Type 8 testinq commenced in 1995. All electrical penetrations were tested in 1995 and scheduled for testing within 60 months (1999 next scheduled tests) to meet the 60-month frequency. The bold test dates indicate the scheduled dates to meet the 60-month criterion. However, the individual testing schedule for each penetration was/is adjusted if a Type 8 test was/is performed early if a nitrogen charge is found out of tolerance during the operating cycle.

All electrical penetrations have a < 2 scfh (total) acceptance criterion.

UNIT 2 ELECTRICAL PENETRATIONS - (AMPHENOL TYPE)

LLRT AS-FOUND TEST RESULTS (SCFH)

YEAR TESTED Current Test PEN Frequency 1995 1997 1999 2000 2002 2003 2005 2006 from Most NO.

Recent Test 4A 0.006 0.012 0.023 - - 0.000 0.000 60 months 5A 0.003 - 0.023 - - 0.000 0.000 0.000 60 months 6A 0.001 - 0.000 0.021 0.000 - 0.000 0.000 60 months 7A 0.002 - 0.000 - - 0.000 0.000 - 60 months i

8A 0.016 0.014 0.008 0.034 0.000 0.000 0.000 0.060 60 months 9A 0.004 - 0.000 - - 0.000 0.000 0.000 60 months i

10A 0.002 - 0.004 - - 0.000 0.000 0.000 60 months 11A 0.002 - 0.000 - - 0.000 0.000 - 60 months I 12A 0.000 - 0.025 - 0.000 - 0.000 - 60 months i

I 13A 0.000 - 0.023 0.000 - - 0.000 - 60 months 1

I I

14A 0.000 - 0.019 - - 0.000 0.000 0.000 60 months I

i 58 0.002 - 0.000 - - 0.000 0.000 0.000 60 months 68 0.000 - 0.000 0.011 0.000 - 0.000 0.000 60 months 78 0.000 - 0.000 - - 0.000 0.000 0.000 60 months 88 0.000 - 0.000 0.017 - - 0.000 - 60 months 98 0.000 - 0.000 - - 0.000 0.000 - 60 months i 108 0.002 - 0.000 - - 0.000 0.000 - 60 months i, 118 0.000 - 0.000 - - 0.000 0.000 0.000 60 months 128 0.000 - 0.019 0.019 0.000 - 0.000 0.000 60 months 138 0.000 - 0.019 - - 0.000 0.000 - 60 months Page 1 of 4

Serial No. 08-0176 Docket No. 50-281 Attachment 2 UNIT TWO ELECTRICAIL PENETRATIONS - (AMPHENOL TYPE)

LLRT AS-FOUND TEST RESULTS (SCFH)

(continued)

YEAR TESTED Current Test PEN Frequency from 1995 1997 1999 2000 2002 2003 2005 2006 NO. Most Recent Test 148 0.000 - 0.017 0.019 0.000 - 0.000 - 60 months 1C 0.006 - 0.000 0.021 - - 0.000 - 60 months 6C 0.003 - 0.049 0.015 0.000 - 0.000 0.000 60 months 7C 0.004 - 0.000 0.013 0.000 - 0.000 0.000 60 months 9C 0.003 - 0.000 - - 0.000 0.000 0.000 60 months 10C 0.002 - 0.000 - - 0.000 0.000 0.000 60 months 11C 0.000 - 0.000 - - 0.00 0.000 - 60 months 12C 0.004 - 0.017 - - 0.000 0.000 0.000 60 months 13C 0.002 - 0.023 0.021 0.000 - 0.000 0.000 60 months 14C 0.000 - 0.017 0.011 - - 0.000 0.000 60 months 60 0.003 - 0.021 - - 0.000 0.000 0.000 60 months 70 0.000 - 0.000 - - 0.000 0.000 0.000 60 months 80 0.000 - 0.000 - - 0.000 0.000 - 60 months 100 0.002 - 0.000 0.017 - - 0.000 0.000 60 months 110 0.003 - 0.000 - - 0.000 0.000 0.000 60 months 130 0.001 - 0.023 - - 0.000 0.000 0.000 60 months 140 0.154 0.318 0.248 0.150 0.140 0.100 0.180 0.110 60 months 150 0.002 - 0.012 - - 0.000 0.000 0.000 60 months 5E 0.000 - 0.000 - - 0.000 0.000 - 60 months 6E 0.000 - 0.006 - - 0.000 0.000 0.000 60 months 7E 0.004 - 0.000 0.028 0.000 0.000 0.000 0.000 60 months 8E 0.008 - 0.006 - - 0.000 0.000 0.000 60 months 10E 0.002 - 0.000 0.028 0.000 - 0.000 0.000 60 months 11E 0.004 - 0.000 - - 0.000 0.000 0.000 60 months 12E 0.000 - 0.023 - - 0.000 0.000 0.000 60 months 13E 0.000 - 0.017 0.015 0.000 - 0.000 0.000 60 months Page 2 of 4

Serial No. 08-0176 Docket No. 50-281 Attachment 2 UNIT 2 ELECTRICAL PENETRATIONS - (OLD CONAX TYPE)

LLRT AS-FOUND TEST RESULTS (SCFH)

YEAR TESTED Current Test PEN Frequency from 1995 1997 1999 2000 2002 2003 2005 2006 NO. Most Recent Test 1A 0.000 - 0.000 0.000 - 0.000 0.000 0.000 60 months 2A 0.000 - 0.000 0.000 0.000 0.000 0.000 0.000 60 months 3A 0.002 - 0.000 0.000 0.000 - 0.000 0.000 60 months 15A 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 60 months 16A 0.001 - 0.000 0.000 0.000 0.000 0.000 0.000 60 months 18 0.002 0.000 0.000 0.000 0.000 0.000 0.000 0.000 60 months 28 0.000 0.000 0.000 0.000 - 0.000 0.000 - 60 months 38 0.000 - 0.011 0.008 0.000 0.000 0.000 0.000 60 months 158 0.000 - 0.000 0.000 - 0.000 0.000 - 60 months 168 0.007 - 0.013 0.006 0.000 0.000 0.000 - 60 months 188 0.000 0.000 0.000 0.000 0.000 0.000 0.000 - 60 months 3C 0.000 0.007 0.015 0.008 0.000 0.000 0.000 0.000 60 months 4C 0.000 - 0.000 0.000 0.000 - 0.000 - 60 months 5C 0.000 - 0.000 0.000 - 0.000 0.000 0.000 60 months 16C 0.000 - 0.000 0.000 0.000 0.000 0.000 - 60 months 18C 0.002 - 0.000 0.000 - - 0.000 - 60 months 40 0.001 0.000 0.006 0.000 0.000 0.000 0.000 60 months 90 0.002 0.000 0.000 0.000 - 0.000 0.000 - 60 months 160 0.000 - 0.000 0.000 0.000 0.000 0.000 - 60 months 180 0.000 - 0.000 0.000 - 0.000 0.000 - 60 months 3E 0.001 - 0.000 0.000 0.02 0.000 0.000 0.000 60 months 4E 0.000 - 0.000 0.000 - 0.000 0.000 - 60 months 15E 0.004 0.000 0.000 0.000 0.000 0.000 0.000 0.000 60 months 16E 0.020 0.019 0.019 0.019 0.02 0.000 0.000 0.000 60 months 17E 0.015 - 0.023 0.011 0.02 0.000 0.000 0.000 60 months Page 3 of 4

Serial No. 08-0176 Docket No. 50-281 Attachment 2 UNIT 2 ELECTRICAL PENETRATIONS - (NEW CONAX TYPE)

LLRT AS-FOUND TEST RESULTS (SCFH)

YEAR TESTED Current Test PEN Frequency 1995 1997 1999 2000 2002 2003 2005 2006 from Most NO.

Recent Test 17A 0.000 - 0.000 0.000 - 0.000 0.000 - 60 months 18A 0.000 .. 0.000 0.000 0.000 0.000 0.000 0.000 60 months 4B 0.01 .. 0.036 0.019 .. .. 0.000 .. 60 months 17B 0.000 .. 0.000 .. .. 0.000 0.000 .. 60 months 2C 0.000 .. 0.000 0.000 .. .. 0.000 .. 60 months 15C 0.017 .. 0.068 .. .. 0.000 0.000 .. 60 months 17C 0.000 0.000 0.000 .. .. 0.000 .. 60 months 10 0.000 .. 0.000 .. .. 0.000 0.000 0.000 60 months 20 0.000 .. 0.000 0.000 .. .. 0.000 .. 60 months 30 0.000 .. 0.000 0.000 .. 0.000 0.000 .. 60 months 50 0.004 .. 0.038 0.028 0.000 0.000 0.000 0.000 60 months 120 0.014 0.02 0.047 0.017 0.03 0.000 0.000 0.000 60 months 170 0.002 .. 0.000 0.000 .. 0.000 0.000 .. 60 months 1E 0.000 .. 0.000 0.000 0.000 .. 0.000 0.000 60 months 2E 0.000 .. 0.000 0.000 - .. 0.000 0.000 60 months 14E 0.008 .. 0.013 0.008 0.000 0.000 0.000 .. 60 months 18E 0.000 0.000 0.000 0.000 .. 0.000 0.000 0.000 60 months 1F 0.007 - 0.000 0.015 .. .. 0.000 0.000 60 months UNIT TWO ELECTRICAL PENETRATIONS - (WESTINGHOUSE TYPE)

LLRT AS-FOUND TEST RESULTS (SCFH)

YEAR TESTED Current Test PEN Frequency 1995 1997 1999 2000 2002 2003 2005 2006 NO. from most recent test 8C 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 60 months 9E 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 60 months Page 4 of 4

Serial No. 08-0176 Docket No. 50-281 Attachment 3 CONTAINMENT MECHANICAL PENETRATION TEST HISTORY AND CURRENT TEST FREQUENCY Virginia Electric and Power Company (Dominion)

Surry Power Station Unit 2

Serial No. 08-01 76 Docket No 50-281 Attachment 3 Page 1 of 7 Containment Mechanical Penetration Test History and Current Test Frequency - Surry Unit 2 Bold entries are the valve/penetration "as-found" failures. Each penetration/valve with an as-found failure is then placed on an accelerated test schedule.

System Name Pen Nominal Valve Numberrrype/Operator LLRT As- Found Test Results (SCFH) Current Test Maximum Allowable No. Valve Size Inside Outside 1995 1996 1997 1998 1999 2000 2002 2003 2005 2006 Frequency LeakageNalve UNIT 2 SAFETY INJECTION CONTAINMENT PENETRATIONS (CHECK AND/OR TRIP VALVES) -Inside Valve data - first row / Outside Valve data - second row.

Accumulator 50 1" 2-SI-TV-201A 2-SI-TV-201 B 0.66 0.0 0.0 0.86 1.9 0.78 1.33 1.82 24 months 1" = 1.0 SCFH Vent Header Globe/Air Pilot Globe/Air Pilot 1.72 0.0 0.2 0.0 0.25 0.0 0.0 0.0 60 months Nitrogen to PRT 53 1" 2-SI-304 2-SI-TV-200 0.1 0.55 0.4 0.1 0.0 0.1 0.1 0.0 60 months 1" = 1.0 SCFH Check Globe/Air Pilot 0.1 0.41 0.1 0.0 0.15 0.05 0.0 0.0 60 months UNIT 2 SAFETY INJECTION CONTAINMENT PENETRATIONS (MANUAL VALVES)

SI Accumulator 20 1" None 2-SI-32 0.0 0.0 0.07 60 months 1" = 1.0 SCFH Makeup Globe/Manual SI Test Line 106 3/4" None 2-SI-73 0.04 0.0 0.0 60 months 3/4" = 1.0 SCFH Globe/Manual UNIT 2 CHEMICAL AND VOLUME CONTROL CONTAINMENT PENETRATIONS (MOTOR OPERATED VALVES)

Seal Water 19 3" None 2-CH-MOV-2381 0.0 0.0 0.0 0.0 0.0 60 months 3" = 1.0 SCFH from RCPs Gate/Motor UNIT 2 CHEMICAL AND VOLUME CONTROL CONTAINMENT PENETRATIONS (FLOW CONTROL AND TRIP VALVES) -Inside Valve data - first row / Outside Valve data - second row.

Reactor Coolant 28 2" 2-CH-TV-2204A 2-CH-TV-2204B QO 0.0 QO 0.0 0.0 0.0 0.0 0.0 60 months 2" = 1.0 SCFH Letdown Globe/Air Pilot Globe/Air Pilot QO 0.0 Q18 0.0 0.0 0.0 0.0 0.0 60 months

Serial No. 08-0176 Docket No 50-281 Attachment 3 Page 2 of 7 Containment Mechanical Penetration Test History and Current Test Frequency - Surry Unit 2 System Name Pen Nominal Valve NumberfType/Operator LLRT As- Found Test Results (SCFH) Current Test Maximum Allowable No. Valve Size Inside Outside 1995 1996 1997 1998 1999 2000 2002 2003 2005 2006 Frequencv LeakaqeNalve UNIT 2 CONTAINMENT AND RECIRC SPRAY CONTAINMENT PENETRATIONS (MOTOR OPERATED AND/OR CHECK VALVES) - Inside Valve data - first row / Outside Valve data - second row;

• In-parallel valves - tested together.

'B' CS Pump 63 8" 2-CS-24 2-CS-MOV-201 C* 0.45 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.3 60 months 8" = 3.5 SCFH Discharge Check Butterfly/Motor 0.3 0.0 0.33 0.33 1.1 0.18 0.0 2.02 2.9 60 months to Spray Ring 2-CS-MOV-201 D*

Butterfly/Motor

'A' CS Pump 64 8" 2-CS-13 2-CS-MOV-201 A* 0.1 1.4 6.5 0.0 0.0 0.0 0.0 0.0 60 months 8" = 3.5 SCFH Discharge Check Butterfly/Motor 0.1 0.1 6.8 1.34 0.42 0.0 0.0 2.3 60 months to Spray Ring 2-CS-MOV-201 B*

Butterfly/Motor

'B' ORS Pump 70 10" 2-RS-11 2-RS-MOV-2568 0.0 0.0 0.0 0.0 0.0 0.0 0.2 0.12 60 months 10" = 45 SCFH Discharge Check Butterfly/Motor 13.02 3.8 10.4 4.8 18.04 3.02 2.9 1.21 60 months to Spray Ring

'A' ORS Pump 71 10" 2-RS-17 2-RS-MOV-256A 0.25 0.0 0.0 0.35 0.0 2.72 3.4 3.86 5.47 24 months 10" = 4.5 SCFH Discharge Check Butterfly/Motor 12.5 21.8 7.5 0.25 1.4 5.75 5.0 0.0 1.9 60 months to Spray Ring UNIT 2 SAMPLING CONTAINMENT PENETRATIONS (TRIP VALVES) - Inside Valve data - first row / Outside Valve data - second row.

RCS Hot Leg 56A 3/8" 2-SS-TV-206A 2-SS-TV-206B 0.1 0.0 0.35 0.0 0.0 0.0 2.14 0.0 0.0 60 months 3/8" = 1.0 8CFH Sample Globe/Air Pilot Globe/Air Pilot 0.0 0.0 1.2 0.12 0.0 0.0 4.3 0.0 0.0 60 months RCS Cold Leg 568 3/8" 2-SS-TV-202A 2-SS-TV-202B 0.1 0.0 1.67 0.0 0.0 0.0 0.0 1.04 0.67 24 months 3/8" = 1.0 8CFH Sample Globe/Air Pilot Globe/Air Pilot 0.0 0.0 2.0 0.0 0.0 0.0 0.15 0.58 0.56 60 months Pressurizer 56D 3/8" 2-SS-TV-200A 2-SS-TV-200B 0.03 0.0 0.0 0.12 0.0 0.04 0.0 290.0 0.0 24 months 3/8" = 1.0 SCFH Liquid Sample Globe/Air Pilot Globe/Air Pilot 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.22 0.0 60 months Pressurizer 57A 3/8" 2-8S-TV-201A 2-SS-TV-201 B 0.05 0.0 0.0 0.21 0.0 0.0 0.0 0.19 0.0 60 months 3/8" = 1.0 8CFH Steam Sample Globe/Air Pilot Globe/Air Pilot 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.14 0.0 60 months PRT Sample 57D 3/8" 2-88-TV-204A 2-SS- TV-204B 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.03 60 months 3/8" = 1.0 8CFH Globe/Air Pilot Globe/Air Pilot 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60 months RHR Sample 97B 3/8" 2-SS-TV-203A 2-SS-TV -203B 0.0 0.0 0.0 0.16 0.0 0.0 0.44 0.11 0.0 60 months 3/8" = 1.0 8CFH Globe/Air Pilot Globe/Air Pilot 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.21 0.2 60 months

Serial No. 08-0176 nocket No 50-281 Attachment 3 Page 3 of 7 Containment Mechanical Penetration Test History and Current Test Frequency - Surry Unit 2 System Name Pen Nominal Valve Numberrrype/Operator LLRT As- Found Test Results (SCFH) Current Test Maximum Allowable No. Valve Size Inside Outside 1995 1996 1997 1998 1999 2000 2002 2003 2005 2006 FreQuencv LeakaaeNalve UNIT 2 LEAKAGE MONITORING CONTAINMENT PENETRATIONS (TRIP VALVES)

Leakage 55D 3/8" None 2-LM-TV-200G 0.0 0.0 0.0 0.0 60 months 3/8" = 1.0 SCFH Monitoring Globe/Air Pilot 2-LM-TV-200H 0.0 0.0 0.0 0.01 60 months Globe/Air Pilot Leakage 57C 3/8" None 2-LM-TV-200E 0.0 0.0 0.0 0.0 60 months 3/8" = 1.0 SCFH Monitoring Globe/Air Pilot 2-LM-TV-200F 0.0 0.0 0.0 0.01 60 months Globe/Air Pilot Leakage 97C 3/8" None 2-LM-TV-200A 0.0 0.0 0.0 0.0 60 months 3/8" = 1.0 SCFH Monitoring Globe/Air Pilot 2-LM-TV-200B 0.0 0.0 0.0 001 60 months Globe/Air Pilot Leakage 105B 3/8" None 2-LM-TV-200C 0.0 0.0 0.0 0.0 60 months 3/8" = 1.0 SCFH Monitoring Globe/Air Pilot 2-LM-TV-200D 0.0 0.0 0.0 0.01 60 months Globe/Air Pilot UNIT 2 GASEOUS WASTE CONTAINMENT PENETRATIONS (REMOTE MANUAL TRIP VALVES) - ** Inside Valve data - first row / Outside Valve data - second row.

Gaseous Waste 32 3/8" None 2-GW-TV-202 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60 months 3/8" = 1.0 SCFH H2 Analyzer Globe/Air Pilot 2-GW-TV-203 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60 months Globe/Air Pilot Gaseous Waste 92 3/8" None 2-GW-TV-204 0.0 0.0 0.0 0.17 0.0 0.05 0.0 0.16 0.12 60 months 3/8" = 1.0 SCFH H2 Analyzer Plug/Air Pilot 2-GW-TV-205 0.0 0.0 0.0 0.12 0.0 0.0 0.0 0.16 0.13 60 months Plug/Air Pilot Gaseous Waste 93 3/8" None 2-GW-TV-200 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60 months 3/8" = 1.0 SCFH H2 Analyzer Plug/Air Pilot 2-GW-TV-201 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60 months Plug/Air Pilot Gaseous Waste 100 3/8" None 2-GW-TV-206 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60 months 3/8" = 1.0 SCFH H2 Analyzer Globe/Air Pilot 2-GW-TV-207 0.0 0.0 0.0 0.0 0.0 0.02 0.0 0.0 0.0 60 months Globe/Air Pilot Containment Grab 105C 3/8" 2-GW-TV-211A** 2-GW-TV-211 B** 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60 months 3/8" = 1.0 SCFH Sample Globe/Air Pilot Globe/Air Pilot 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60 months

Serial No. 08-0176 Docket No. 50-281 Attachment 3 Page 4 of 7 Containment Mechanical Penetration Test History and Current Test Frequency - Surry Unit 2 System Name Pen Nominal Valve NumberlType/Operator LLRT As- Found Test Results (SCFH) Current Test Maximum Allowable No. Valve Size Inside Outside 1995 1996 1997 1998 1999 2000 2002 2003 2005 2006 Frequency LakageNalve UNIT 2 PRIMARY VENT & DRAIN CONTAINMENT PENETRATIONS (TRIP VALVES) - ** Inside Valve data - first row / Outside Valve data - second row.

PDn Pump 33 2" 2-DG- TV-208A** 2-DG-TV-2088** 0.1 2.47 133.0 - 0.2 7.92 0.9 0.0 0.0 0.0 60 months 2" = 1.0 SCFH Discharge Globe/Air Pilot Globe/Air Pilot 0.21 1.44 1.15 1.15 0.0 0.0 0.0 0.0 0.4 60 months Cont. Sump Pump 38 2" 2-DA-TV-200A** 2-DA-TV-2008** 0.0 0.35 305.0 0.0 0.0 0.0 0.0 0.0 60 months 2" = 1.0 SCFH Discharge Ball/Air Pilot Ball/Air Pilot 0.0 0.2 7.66 0.2 0.0 0.0 0.0 0.0 60 months Primary Vent 48 2" 2-VG-TV-209A** 2-VG-TV-2098** 0.0 0.0 0.0 0.0 0.0 60 months 2" = 1.0 SCFH Header Globe/Air Pilot Globe/Air Pilot 0.0 9.6 0.0 0.0 0.0 60 months Post Accident 578 2" None 2-DA-TV-203A 1.43 0.2 0.12 0.0 0.0 60 months 2" = 1.0 SCFH Sample Return Globe/Air Pilot 2-DA-TV-2038 2.99 0.2 0.16 0.0 0.0 60 months Globe/Air Pilot UNIT 2 PARTICULATE & GAS RAD MONITOR CONTAINMENT PENETRATIONS (TRIP AND/OR CHECK VALVES) - Inside Valve data - first row / Outside Valve data - second row.

Particulate and 43 1" 2-RM-3 2-RM-TV-200A 0.47 0.0 0.25 166.0 0.0 0.0 0.0 0.0 60 months 1" = 1.0 SCFH Gaseous Check Globe/Air Pilot 0.0 0.0 0.16 0.0 0.43 0.0 0.0 0.03 60 months Rad Monitoring Return Particulate and 44 1" 2-RM- TV-200C 2-RM-TV-200B 0.0 0.0 0.0 0.0 0.0 60 months 1" = 1.0 SCFH Gaseous Globe/Air Pilot Globe/Air Pilot 0.0 0.0 0.0 0.0 0.0 60 months Rad Monitoring Supply UNIT 2 SERVICE AIR & INSTRUMENT AIR CONTAINMENT PENETRATIONS (VARIOUS VALVES) -

• In-parallel valves - tested together; ** Inside Valve data - first row /

Outside Valve data - second row; Service Air 42 2" None 2-SA-81 0.0 16.0 0.21 30.1 0.0 1.33 0.0 24 months 2" = 1.0 SCFH Supply Gate/Manual 2-SA-82 0.0 0.0 0.14 27.6 0.0 1.33 0.0 24 months Gate Manual Instrument Air 47 2" 2-IA-864** 2-IA-TV-200*j** 14.0 0.0 0.3 0.08 0.0 0.0 0.0 0.0 60 months 2" = 1.0 SCFH Supply Check Globe/Air Pilot 6.0 6.8 0.45 1.8 1.19 0.0 0.0 0.0 60 months 2-IA-704*j**

Gate/Manual Instrument Air 58 2" 2-IA-868** l-IA-704** 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60 months 3 = 1.0 SCFH from Unit 1 Check Gate/Manual 0.0 0.0 0.0 2.0 0.35 6.3 0.24 0.0 60 months Containment 112 3" 2-IA-TV -201A** 2-IA- TV-201 B** 0.0 0.0 0.0 0.0 60 months 3" = 1.0 SCFH Instrument Air Plug/Air Pilot Plug/Air Pilot 0.0 0.0 0.0 0.0 60 months

Senal No. 08-0176 Docket No 50-281 Attachment 3 Page 5 of 7 Containment Mechanical Penetration Test History and Current Test Frequency - Surry Unit 2 System Name Pen Nominal Valve NumberfType/Operator LLRT As- Found Test Results (SCFH) Current Test Maximum Allowable No. Valve Size Inside Outside 1995 1996 1997 1998 1999 2000 2002 2003 2005 2006 Frequency LeakaqeNalve UNIT 2 PURGE & VACUUM CONTAINMENT PENETRATIONS (VARIOUS VALVES) - *** Inside & Outside Valves tested together; ** Inside Valve data - first row / Outside Valve data - second row.

Containment 90 8" 2-VS-MOV-200C*** 2-VS-MOV-201 *** 64.0 0.64 0.0 0.0 0.0 2.5 0.25 0.0 0.55 30 months 8" =3.5 SCFH Purge Exhaust Butterfly/Motor Butterfly/Motor --- Must test every 30 months per Reg Guide 1.163 ---

Ventilation System 2-VS-MOV-200D***

Butterfly/Motor Containment 91 18" 2-VS-MOV-200A*** 2-VS-MOV-200B***19.5 0.0 2.49 0.31 0.0 1.5 0.0 0.98 1.4 30 months 18" = 8.5 SCFH Purge Supply Butterfly/Motor Butterfly/Motor --- Must test every 30 months per Reg Guide 1.163 ---

Ventilation System 2-VS-MOV-202***

Butterfly/Motor Containment 92 2" None 2-CV-TV-250C 2.48 0.26 0.66 0.21 0.26 0.4 0.35 0.25 60 months 2" = 1.0 SCFH Vacuum 'A' Globe/Air Pilot Pump Suction 2-CV-TV-250D 0.1 0.0 1.63 0.18 0.0 0.3 0.2 0.09 60 months Globe/Air Pilot Containment Vacuum 'B' 93 2" None 2-CV-TV-250A 0.81 1.44 11.94 - 2.07 1.23 0.2 0.0 0.13 0.0 60 months 2" = 1.0 SCFH Globe/Air Pilot Pump Suction 2-CV-TV-250B 0.07 0.0 3.0 0.0 0.33 0.0 0.0 0.0 0.0 60 months Globe/Air Pilot Containment 94 8" 2-CV-HCV-200** 2-CV-2** 3.71 6.86 0.11 - 5.7 1.92 0.8 2.2 60 months 8" = 3.5 SCFH Vacuum & Globe/Air Pilot Gate/Manual 0.6 0.64 0.0 0.0 2.0 1.8 0.8 60 months Leakage Monitoring UNIT 2 MISCELLANEOUS CONTAINMENT PENETRATIONS (MANUAL VALVES) - Inside Valve data - first row / Outside Valve data - second row.

RSHX SW Drai ns 51 2" 2-SW-206 2-SW-208 0.1 0.38 0.0 60 months 2" = 1.0 SCFH Gate/Manual Gate/Manual 0.0 0.38 0.0 60 months Primary Vent 54 2" 2-VA-9 2-VA-1 0.0 0.0 0.0 60 months 2" = 1.0 SCFH Pot Vent Gate/Manual Gate/Manual 0.0 0.0 0.0 60 months

'A' SG Recirc 96 3" 2-RT-2 2-RT-6 0.0 0.0 0.0 60 months 3" = 1.0SCFH

& Transfer Ball/Manual Ball/Manual 0.0 0.0 0.0 60 months

'B' SG Recirc 22 3" 2-RT-21 2-RT-25 0.0 0.0 0.0 0.0 60 months 3" = 1.0 SCFH

& Transfer Ball/Manual Ball/Manual 0.0 0.18 0.0 0.0 60 months C' SG Recirc 114 3" 2-RT-40 2-RT-44 0.0 0.0 0.0 60 months 3" = 1.0 SCFH

& Transfer Ball/Manual Ball/Manual 0.0 0.3 0.0 60 months Reactor Cavity 103 3" 2-RL-5 2-RL-3 0.0 0.0 0.0 60 months 3" = 1.0 SCFH Purification Inlet Diaphragm/Manual Diaphragm/Manual Reactor Cavity 104 3" 2-RL-13 2-RL-15 0.23 0.0 0.0 0.0 0.0 60 months 3" = 1.0 SCFH Purification Outlet Diaphragm/Manual Diaphragm/Manual 0.0 0.0 290.0 0.0 0.0 60 months

Serial No. 08-0176 nacket No 50-281 Attachment 3 Page 6 of 7 Containment Mechanical Penetration Test History and Current Test Frequency - Surry Unit 2 System Name Pen Nominal Valve Numberffype/Operator LLRT As- Found Test Results (SCFH) Current Test Maximum Allowable No. Valve Size Inside Outside 1995 1996 1997 1998 1999 2000 2002 2003 2005 2006 Frequency LeakaqeNalve UNIT 2 MISCELLANEOUS CONTAINMENT PENETRATIONS (MANUAL VALVES) CONTINUED Fire Protection 101 4" None 2-FP-151 0.0 0.0 0.0 60 months 4" = 1.0 SCFH Ball/Manual 2-FP-152 0.0 0.0 0.0 60 months Ball/Manual RHR to RWST 24 6" None 2-RH-108 0.48 0.0 0.0 0.0 0.0 60 months 6" = 1.0 SCFH Gate/Manual UNIT 2 MISCELLANEOUS CONTAINMENT PENETRATIONS (CHECK AND/OR TRIP VALVES) - Inside Valve data - first row / Outside Valve data - second row.

PG Water to PRT 45 3" 2-RC-160 2-RC-TV-2519A 1.33 0.0 0.0 0.0 290.0 0.0 0.0 0.0 60 months 3" = 1.0 SCFH Check Diaphragm/Air Pilot 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 60 months Condenser Air 89 6" 2-VP-12 2-SV-TV-202A 0.14 8.3 0.32 9.3 1.78 0.88 0.05 0.0 0.41 60 months 6" = 2.5 SCFH Ejector Discharge Check Gate/Air Pilot 0.0 0.0 0.21 0.0 0.0 0.25 01 0.12 0.0 60 months UNIT 2 COMPONENT COOLING CONTAINMENT PENETRATIONS (TRIP VALVES) - ** Inside Valve data - first row / Outside Valve data - second row.

CCWfrom 'B' 1 18" None 2-CC-TV-2098 5.8 7.38 0.0 0.0 10.56 5.1 0.65 60 months 18" = 8.5 SCFH RHR HX Butterfly/Air Pilot CCWfrom 'A' 5 18" None 2-CC-TV -209A 0.34 - 0.23 0.0 0.0 60 months 18" = 8.5 SCFH RHR HX Butterfly/Air Pilot CCW from 'B' Air 12 6" None 2-CC-TV-210B 0.0 0.0 0.0 0.0 0.48 60 months 6" = 2.5 SCFH Recirc. Fan Plug/Air Pilot CCW from 'C' Air 13 6" None 2-CC-TV-210C 0.0 0.0 0.55 0.0 60 months 6" = 2.5 SCFH Recirc. Fan Plug/Air Pilot CCW from 'A' Air 14 6" None 2-CC-TV-210A 2.31 0.44 4.37 1.5 1.5 1.42 60 months 6" = 2.5 SCFH Recirc Fan Plug/Air Pilot CCWfrom 'A' 25 4" None 2-CC-TV -205A 0.0 0.0 1.9 0.0 0.0 60 months 4" = 1.5" SCFH RCP Plug/Air Pilot CCWfrom 'C' 26 4" None 2-CC-TV -205C 0.0 0.0 0.21 0.0 60 months 4" = 1.5" SCFH RCP Plug/Air Pilot CCWfrom 'B' 27 4" None 2-CC-TV -205B 0.34 - 0.0 0.0 0.0 60 months 4" = 1.5" SCFH RCP Plug/Air Pilot CCWfrom RCP 110 2-1/2" 2-CC- TV-240A*' 2-CC-TV-240B** 236 290 135 0.21 0.32 27.6 290.0 0.17 0.0 60 months 2" = 1" SCFH Thermal Barrier Gate/Air Pilot Gate/Air Pilot 0.0 0.0 0.35 0.8 0.32 0.0 0.0 0.0 0.0 60 months

Serial No. 08-0176 nncket No 50-281 Attachment 3 Page 7 of 7 Containment Mechanical Penetration Test History and Current Test Frequency - Surry Unit 2 System Name Pen Nominal Valve Numberrrype/Operator LLRT As- Found Test Results (SCFH) Current Test Maximum Allowable No. Valve Size Inside Outside 1995 1996 1997 1998 1999 2000 2002 2003 2005 2006 Freauencv LeakaaeNalve UNIT 2 COMPONENT COOLING CONTAINMENT PENETRATIONS (CHECK VALVES) ccw to 'A' 2 18" 2-CC-177 None 0.0 0.0 0.0 60 months 18" = 8.5 SCFH RHR HX Check ccw ie 'B' 4 18" 2-CC-176 None 0.0 0.0 0.0 60 months 18" = 8.5 SCFH RHR HX Check CCW to 'C' Air 9 6" 2-CC-224 None 0.0 0.65 0.0 60 months 6" = 2.5 SCFH Recirc. Fan Check CCW to 'A' Air 10 6" 2-CC-242 None 0.77 0.0 0.0 60 months 6" = 2.5 SCFH Recirc. Fan Check CCW to 'B' Air 11 6" 2-CC-233 None 0.0 0.0 0.0 60 months 6" = 2.5 SCFH Recirc. Fan Check CCW to 'c RCP 16 6" 2-CC-59 None 0.34 0.88 1.5 60 months 6" = 2.5 SCFH Check CCW to 'B' RCP 17 6" 2-CC-58 None 0.0 0.57 0.0 60 months 6" = 2.5 SCFH Check CCW to 'A' RCP 18 6" 2-CC-1 None 0.0 0.94 0.54 60 months 6" = 2.5 SCFH Check