ML20112G317

Forwards Bechtel Evaluation of Corrosion on Buried Piping, Tanks & Associated Structures at Facility.Corrosion Protection Acceptable

ML20112G317
Person / Time
Site:	Palo Verde
Issue date:	12/21/1984
From:	Van Brunt E ARIZONA PUBLIC SERVICE CO. (FORMERLY ARIZONA NUCLEAR
To:	Martin J NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION V)
References
ANPP-31552-MFH, NUDOCS 8501160298
Download: ML20112G317 (115)

Text

{{#Wiki_filter:I .c j e o-diCS . YI'C 1 Arizona Nuclear Power Project y ] ,,, g p o BOX 52034 e PHOENIX. ARIZONA 85072-2034 i December 21, 1984 l I ANPP 31552 MFH/MAM,, vem... Mr. John B. Martin, Administrator U.S. Nuclear Regulatory Commission Region V 1450 Maria Lane - Suite 210 Walnut Creek, California 94595 - 5368

Subject:

drrosion Protection and Concerns File: 84-056-026; G.1.01.10

Reference:

(1) B/ANPP-E-123480, dated 10/22/84 (2) B/ANPP-E-120712, dated 9/10/84 (3) B/ANPP-E-118454, dated 8/7/84 (4) B/ANPP-E-115422, dated 5/24/84 (5) B/ANPP-E-114045, dated 4/24/84 (6) B/ANPP-E-101069, dated 4/16/84 (7) B/ANPP-E-111408, dated 2/3/84

Dear Mr. Martin:

As you are aware, the PVNGS design incorporates the use of buried piping, tanks and associated structures. Since the completion of construction of these items we had gained knowledge, through our maintenance and testing programs, of corrosion developing on these systems. As a result of this knowledge we required our architect / engineer, Bechtel, to review, evaluate and resolve these corrosion concerns. The attached Bechtel responses (References 1-7) provide the most significant information on this matter. APS 'has reviewed the referenced information to determine if there is-any impact. to buried. safety related or important to safety systems that would adversely affect the ' health ~ and safety of the public. A discussion of this review is as follows: Safety Related Buried Piping: r Carbon steel piping. is -the only buried, safety-related-piping currently used at PVNGS..The piping has been inspected on a sample basis and no problems have been identified. A r it '/

e . o* .gd page 2. Iuportant.to Safety Buried Piping: Fire protection piping' is the only important to safety buried pipe currently used at PVNGS. Corrosion of fire protection piping is being investigated through Investigative Reports IR-024 and IR-024, Rev. 1. The final results of these investigations are not in at tt.As -time since this is a long term review of all power block (operable) Post Indicator Valves (PIVs). However, we have a sufficient data base to determine that the corrosion on the fire protection piping, hydrants and PIVs is mainly - the corrosion of flange bolts. This corrosion is not detrimental to the operation of the fire protection -(FP) system,.and the main problem is the long tera deterioration of the flange bolts. The inspection of the FP valves also has revealed that continuity across the flanges was not always acceptable and Electro-bond straps were needed to be. installed.- As an ongoing effort we plan to inspect and replace the: power block (operable) PIVs ~ _ flange bolts 'as necessary with a goal to complete this activity by the end of. the first scheduled refueling outage for Unit 1.

Conclusion:

s As a result of the APS review of the overall corrosion protection at PVNGS and the referenced letters, we believe this corrosion has been properly addressed, - is acceptable, and. has no safety impact for PVNGS. Corrosion protection, monitoring and maintenance will be an , ongoing effort and is expected to keep this concern well under control. Very truly yours, E. E. ' Van Brunt, Jr. ~ APS Vice President Nuclear Production ANPP Project Director EEVBJr/MAM/rw Attachments- -cc: ' A. C..Gehr-w/a 4 R. P. Zimmerman A. C. Rogers D. B. Karner-W. H. Wilson .W. F Quinn T. J. Bloom ~ w/a v. A e. yw y.,....,ewy y -9 eem-g -,,,,a ve-,- ..-pw m 9

, (..<.. Bechtel Power Corporatiori-Engineers - Constructors 12400 East Imperial Highway HPn.,..n vuwrtalk. Cahfornia 90650 MAIL AOCRESS P o Box 60660. TERMetAL ANNEX, LOS ANGELES CALFORNIA 90000

• g g ]* p yt, NE. (213) $Q7 2000 B/ANPP-E-123480 MOC 347046 ACR j /., c October 22, 1984 WLH JTB JWR (Mtn)

MDH 8 WFO Mr. J. R. Bynum 's DBF Manager of Nuclear Operations Palo Verde Nuclear Generating Statie, 3 -JRR c GCA e APS Operations - Engineering Departunt fg ELL Post Office Box 49 c oc Palo Verde, Arizona 85343 kd 66 " c-EEVH l re. -Attention: Mr. L. G. Papworth FILE # Engineering Manager g

Subject:

Arizona Nuclear Power Project ene. Bechtel Job 10407 Transmittal of Investigation Requests _ File: D.48

Dear Mr. Papworth:

The following Investigation Request (IR) is. transmitted for your implementation: _IR No. Revision Subject A0-IR-024 1 Inspection of Additional PIV's and Hydrants and Fire Protection Hydrants After implementing the IR please return a copy of the IR form, with Block 12 completed, to W. G. Bingham. Very truly yours, BECHTE' WER CORPORATION. s 3 f$# W. G. Bingham Project Engineering Manager Western Power Division WGB:DRG:pm

Enclosure:

See abov'e listing (1 copy) ec: E. E.. Van Brunt, Jr. w/ enclosure J. D. Houchen w/o enclosure ./ L --.

w ,3,- - f ? l p. INTERIM REPORT

SUMMARY

A0-IR-024 REVISION'O

Reference:

PVNGS-LGP-L84-15 Tables 1 and 2 summarize quantitative results of field inspection of several . hydrants and PIV's. Corrosion of PIV and hydrant valve bodies was found to be insignificant and no pitting was evident. Also bolt threads and cross-i -sect onal areas of bolts were foued to be in accordance with the IR-024 acceptance criteria. However, at least two or more bolts and nuts were replaced on all hydrants and PIV's inspected, due to excessive corrosion of bolt heads and/or nuts. . There appears to be some correlation between degree of corrosion and length of ~ . time buried in the ground, although a Unit 3 hydrant had more bolt / nut replace- - ments than two hydrant locations in the Unit 1 and 2 areas. Some additional valve inspections are recommended to provide a larger sample . size, in lieu of excavating and inspecting all of the. remaining valves and hydrants as suggested in the referenced letter. Additional valve locations have been selected, which are generally remote from the existing energized. anode. beds; and.which are, therefore, considered to be representative of unprotected areas to date. lRue additional valve locations.are also selected to . check corrosivity data already obtained.and to compare the degree of corro-sivity with Unit 1 data attached herein. With the completion of this additional inspection', IR-024 record data will have been.obtained for approximate 85 of the PIV's and 295'of_ the hydrants, excluding the WRF area. ~

Attachment:

' (A).. Table I - Interim Report Summary A0-IR-024, Revision 0 (B) Table II --Interim Report Summary A0-IR-024,' Revision 0~ i p i I t b L l m W 't % 2 ., -, - ~.., ,,,.m g w..

. fs INTERIM REPORT

SUMMARY

- TABLE 1 A0-IR-024. Revision 0 Field Inspection of PIV's and Hydrants Bolt / Nut Quantities External Valve Body (1)

Valve Location No. Replaced Percent UT - Body Wall Visual No. Due to Corrosion Replacement Thickness (in) Inspection Area 1/ Area 2 PIV'S No. 6 Unit 1-N. 12 285 0.700/0.650 Insignificant No. 43 Unit 3-N. 3 7% 0.650/0.650 Surface No. 55 Unit 3-S. 10 33% 0.625/0.625 corrosion - No. 103 N. of - ~13 30% 0.700/0.700 No Pitting (376) Unit 1 Hydrants No. 2 Water 11 69% 0.590/0.640 Treatment Arez No. 5 Unit 1-N. 2 12% NA/NA No. 8 Unit 1-3. 9 56% 0.510/0.500 ~ No. 10 Unit 1-S. 8 50% 0.460/0.580-No. 13 Unit 2-N. 2 12% 0.460/0.420 No. 21 Unit 3-N. 5 31% 0.520/0.460 No. 24 Unit 3-S. 3 19% 0.440/0.520 No. 30 Switchyard 7 44% 0.760/0.720 Area No.138 Unit 2 - 9 56% 0.520/0.560 V Cooling Tower Ares _ i A Note 1 ' Manufacturer's specified nominal /n:inimum wall thickness is 0.750/0.595 for-12" PIV and 0.470/0.380 for 6" hydrant. 4 h

1 INTERIM REPORT

SUMMARY

- TABLE 2 A0-IR-024. Revision 0 Number of Bolts / Nuts Replaced Due to Corrosion Valve at.

at at at Total Percent No. Pipe Flge Bonnet Bonnet Elbow No. Total Connections Connections Stuffing Flange Replaced Replaced (1) Boxes Connec. PIV No. 6 8 4 0 NA 12 28% PIV-No. 43 2 1 0 NA 3 7% PIV No. 55 1 7 2 NA 10 23% PIV No.103 6 6 1 NA 13 30% (Valve No. 376) Hydrants: No. 2 3 NA NA 8 11 69% No. 5 1 1 2 12% No. 8 4 5 9 56% No. 10 8 0 8 50% No. 13 1 1 2 .12% No. 21 5 0 5 31% No. 24 3 0 3 19% No. 30-4 3 7 44% No '38-8 Y 1 9 56% I Note 1:- PIV has 12 bolts on each pipe flange connection, 16 bolts on bonnet connection, and 3 bolts on bonnet stuffing box. Total of 43 bolts. Hydrant has 8 bolts on pipe flange connection 'and 8 bolts on elbow flange connection. ' Total of 16 bolts. E, w

j' vYW T2/M/ PALC VERDE NUCLEAR GENER ATING STATION '^* UNITS 1. 2, & 3 INVESTIGATION REQUEST A0-IR-024 7-20-84 la. in NO. UNIT 2

28. COMPLETION REO*D JOB NO.10407 3.PAGE

4. QCLASS

5. SYSTEM D ESIG.

IC. IR NO. UNIT 3 2c. COMPLETION REO*D 1 OF 2 l S See Attch. II

6. IDENTIFICATION SUPPLIER'S NAME CM-053 Kennedv Valve Mfe. Co. (for Hydrnnes nna nTvd A D D R ESS Elmira. New York SUPPLIER CONTACT Mr. T. Rahiewicz PHONE NO. (607) 714-2711

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9. SERVICE sULLETIN OR OTHER REFERENCE DOCUMENT ATTACHED I Block "10" Attachment II Fire Protection System Ceneral Arrangement Dwg. 13-C-zVA-011 TTI See Attech ent "T" /Conferenco "nene No.

C" r-1910

10. EQUlPM ENT NO.

D E.1C RIPTION [y g5'O R V AFFEcTED DOCUMENTS Ol See A t en ch-en e "T T" nn A "TTA" .b See Attachment "II" PR. 2

11. PURPOSE AND INTENT OF INVESTIG ATION:

1) Excavate and inspect buried stainless steel piping for corrosion and l violation of minimum wall thichness. (see Attachment II for acceptance criteria.) If no violation of minimum wall thickness detected, clean, coat and wrap per Spec.13-FM-205 (Attach. IV), prior to back filling per Spec. 13-CM-300 (Attach. V). Replace excavated pipe sections if minimum uall thickness exceeded, and coat ar.d wrap new pipe. Refer to Attach. III for inspection procedure. 2) Excavate and inspect buried portions of fire hydrants, block valves and indicators (PIVs) for excessive corrosion and acceptability post Refer to Attach. II for acceptance criteria, (for location see Attach. VI). If not previously coated, clean and coat per Spec. 13-CM-335, Sec. 8.8, SCN. 3419 (Attach. VII). If valve body wall thickness below minimum, replace valve or hydrant. Refer to Attach. III for insnection nrecedure. g' Inspection of Additional PIV's and Hydrants Q* lA.20 N gb. _ Qj a Tr~svect4nn of f4rn nrnenr~tinn M-A r nee mA s f i ((1\\ MLLk valves, stainless steel ninine and crnund orid l r a c a-4 REv. DATg laterals. DESCRIPTION ORIGIN ATOR PC I2. ACTIONEE*S RESULTS OF INVESTIG ATION: INTERIM REPORT SR! MARY (enclosed) -N AU TreORf 2 E D SIGN A TUM E

. f., . Continuntion ,- ((} LA.IR No. Unit A or 1 2A. Completion Req'd' Palo Verde Nuclear Generating Station n-024 7 90-R4 lb.IR No. Unit 2 2B. Completion Req'd. INV STIGA ON REQ EST 3.Page

4. Q Class

. 5. System Desig. 1C.IR No. Unit 3 2C. Completion Req'd. 2 of 2 S Ron Arrrh. rv 3) Clean and inspect all nuts and bolts for hydrant and valve connecting flanges and bonnet flanges in Item 2 above. Replace all nuts and bolts where corrosion has started. Refer to Attachment III for inspection procedures, and Attachment IM for acceptance criteria. Coat all nuts and bolts and flanges per Attachment VII for final installed materials. 4) Excavate trenches to expose approximately b f t. of ground cable at seven places as shown per Attachment "VIII". This work is to be performed to expose the ground cable for physical inspection and to verify whether the ground cable is corroded or not. Recommended procedures for selection of trench location and excavation is as follows: a) Select location for trench excavations of station lateral runs of #4/0 bare copper cables (of grounding mat) at approx-imate locations indicated on Attachment "VIII". All locations must be accessible for men and equipment. b) Each trench shall be deep enough to allow a minimum of b in. clear space between conductor and bottom of the trench. c) Trench may be excavated by mechanical means to approximately 6 in. above buried conductor. Further excavation must be continued by hand tools to expose conductor with care to prevent damage to the conductors-d) Refer to Attachment IIIA for insjection procedures and acceptance criteria. 5) Inspection team: APS Bechtel Dan Sachs Ext. 0537 (PVNGS) W. J. Mitchell (valves & piping) Bob Grinstead 828-6057 (D.V.ENG.) M. Laskowski (ground laterals) Jim douton Ext. b)99 (PVdGS) Resident Engr. (all inspections) (to be selected) m

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m, , c -,,.,.-. a A ' o't. p 's Arizona Nuclear Power Project O. 'h Eechtel Job 10407 9g* Date: April 20,1984 g6 3 h/ g' File: D.20.01, D 28, E.16'.04 7 E.16.05, H.11.01 hg4 ANPP CONFERENCE NOTES NO. CN-E-1535 DATE OF MEETING: April 12, 1984 LOCATION: APS Engineering Offices ATTENDEES: APE Bechtel E. Van Brunt, Jr. W. G. Bingha= W. Ide R. R. Sciens C. Rodgers R. W. Gillison D. Fasnacht O. Zeringue J. Barrow J. Bouton

SUBJECT:

Corrosion Protection for Euried Piping and Structures PURPOSE: Review overall corrosion proble=s experienced to date, corrective actions taken, and program to ce=plete corrosion protection for all buried piping and structures. Also review Eechtel's " draft report" in response to NRC questions regarding corrosion proble=s onsite. A. Kev Decisions ' APS stated the Bechtel program to _ protect buried piping' systems and - ,,tructures shall demonstrate that satisfactory protection is currently being provided, pending the completion of installation and full energi-astion of the Cathodic Protection (CP) system. Completion of the CP ~ system installation is tentatively scheduled for June,1985. To ~ accomplish this objective, Bechtel will initiate a sampling program to inspect buried piping and ground cable installations in those areas most laffected by cctrosive soil conditions.

R.

Discussion 'Bechtel handed over " Draft" copies of a ' Sun: mary Status Report, Corrosion i Protection for Euried Piping Systems, Ground Cable and Structures, dated April,1984, for APS review and comment. ~ An " overview" summary of this draft status report was presented by Eechtel as'the discussion basis for ~ the meeting. All ' action ite=s as a result of this meeting are Bechtel action items., e o (. .L'

- ammum 7 F b w-e ANPP Conference Notes No. CN-E-1535. p Date: April 20, 1984 ~; Page 2 E = G r Significant items discussed and action items are summari=ed b'eleV: r p ?- i 1. The drilling specification, for drilling of ve11s for anode beds for the balance of the CP system, shall include any record data [ required to meet environmental and/or permit concerns. These q p concerns include requirements, in the event of overdrilling, for g the 200-foot deep wells, and any precautions to be taken in Category I drilling areas, y 2. In the su==ary report, the following shall be included: "{ Emphasize that all safety-related buried piping has special h. a. coating and wrapping with verification by a field authorized -7 inspector that the installation is satisfactory prior to backfill. = b. Provide a histogram showing the operation of the CP syste= L after initial energization. The histogram shall show, for example, when the CP system was deenergized due to construc-tion and startup outages, when rectifier output levels were reduced to allow for velding in various plant areas, and k current energization status. c. Emphasize that fire protection piping is "important to safety" i. and that cathodic protection is being added to insure the overall integrity of this system for the plant life. i [ .- d. Provide a sampling plan to establish that the conditiot. of g the stainless steel piping installed in the ground is accept-able. Also demonstrate that the anticipated corrosion cate li i for the stainless steel piping vill not exceed corrosion ii allevance for this piping through the period of June, 1985, [_ when the three unit CP system is expected.to be fully energized. .r f e. Provide a similar sampling plan for the buried fire protec-h tion system hydrants and valves. This plan shall include inspection and/or replacement, or coating, of all nuts and bolts for hydrant and valve connecting flanges and bonnet flanges as required. [ f. Emphasize that all buried care metallic structuies~are - f. included in the design crir.eria for the CP system. (There are b miscellaneous metals in the dump area and temporary buried 5 piping in various areas.) = 3. Some discussion was held regarding possible correlation of type of backfill used and degree of soil corrosivity. (Subsequent to 3 the meeting, Bechtel Construction has verified that all stock-Siled material came from general excavations in the power block Excavation material was not specifically segregated into [ area. different stockpiles, except for coarser material which was stoch piled and located in a separate borrow pit area. Piping instal-I lation records (CIP's) do not identify the stockpile source for 7 E o .a' AFrd D" Der 5, er= @S N +9(M

• D44.+-

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~ . J.. 1 l s. 1 ANPP Conference Notes No. CN-E-1535 Date: April 20, 1984 Page 3 i the backfill. Also stockpiled and bcrrow pit area soils were sometimes blended to meet Category I requirements. Data 'on the source of backfill, if available, would therefore not necessarily assist in identifying any special characteristics of the soil that might relate to pipe corrosion problems.) 4 The _recent leak in the southeast corner of the power block was i:n I a domestic water copper line. The leak apparently occurred due to a faulty solder joint connection in a 2-1/2 inch reducing flange. 5. Bechtel will inspect the field lateral runs in the 4/0 bare copper ground conductor. The investigation will be made at the most_ corrosive site areas, as applicable. i 6. Bechtel will make a general inspection of the "WRF" CP systea, which has already been completed, energized, and turned over.to APS, to verify the system is operating satisfactorily. 7. Bechtel will give APS a cost comparision suc=ary of alternative designs investigated for the buried stainless steel piping. These alternatives included substitution of a fiberglass rein-1 forced polyester (FRP) piping for the existing stainless steel, or excavation, cleaning, coating, wrapping, and backfill of the ~ existing stainless steel piping. 8. Bechtel will verify the accessibility of all CP connections provided for testing and monitoring. Grade level tanks with concrete perimeter ring wall and sand base' are provided with monitoring stations. Grade level tanks with solid concrete foundations for the entire tank base do not have cathodic protection and, therefore, do not require monitoring stations. -(Electrodes may have been installed by error beneath solid concrete foundations for tanks. The leads for these electrodes may have been permanently buried.) 9. APS has reported that some of the anode beds and/or rectifiers are not operating properly in the Unit 1 area. Bechtel will send .CP personnel to the site to assist in solving any problem areas.

10. APS requested that Bechtel obtain the service of a corrosion -

protectioniconsultant to verify and add credibilitt to the. l Bechtel CP design.' . 11. Bechtel vill report the results of the pipe surface inspection of l_ the Unit 1. refueling water tank 20" nozzle extensions. (These I extensions were subsequently enclosed in a concrete tunnel and . protected:from direct contact with the soil per DCP CH-154.) 12.. :Bechtel vill clarify the NFPA code requirements for coating of -buried portions of fire hydrants, post indicator valves, and block valves.

13. Bechtel will advise the reasons for the increase in CP system design capacity (as

1. 2ected in DCP QH-006) over the original CP system design, which was based on design quantities known or anticipated in 1976.

+ Di .L -h ed - 4.JM &r

ANPP Conference Notes No. CN-E-1535 Date: April 20, 1984 Page 4 _ ACTION ITEM SUWARY All items herein are Bechtel action items. Items 7, 11, 12 and 13 scheduled for completion by 5/15/84; Items 2, 5, 6, 8 and 9 complete by 6/1/84, and Item 10 complete by 9/1/84 Recorded by: R. W. Gillison Reviewed by: 9 -O GA W. C. Bingham WCB:RWG:eg i o e i I l 1 i 't i-I l l-a y l4*, ia me.4 4 a 49 - lf4 asf'b

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A;+A3 r nur sera cress. rec 7 A/7CA SecD cos./DITipH '- 0 Acceptance criteria for bolt / nut assemblies: 1.- Cross-sectional area of bolt = 50% of original bolt size. 2. The number of acceptable bolt threads in contact with nut, on flange bearing side, 3 c 50% of the number of original bolt threads in contact uith nut, or the length of the nut with acceptable threads = 50% of the original nut' length. Acceptable threads may have discoloration but no corrosion. 3._ The net cross-sectional area of the nut adjacent to flange sides D 50% of the original -ndt area; the same requirement applies to the bolt head. 4. _ Acceptable proof test loading: 3/4" bolt-2.12 KSI 950 lbs 7/8" bolt 4.2 KSI 2550 lbs ) ' * ' Criteria allows for possible additional corrosion for. the next year of operation, -ccsuming the cathodic protection system will not be in complete operation until then.. e, d & mW& ' W w

,J. .I~ ATTACHMENT III . hb. LA.IR No. Unit A or 1 2A. Completion Req'd. Palo Verde Nuclear Generating Station . A0-IR-024 7-20-84 Units 1, 2, & 3 18.IR No. Unit 2

28. Completion Req'd.

INVESTIGATION REQUEST 3.Page

4. Q Class

. 5. System Desig. 1C.IR No. Unit 3 2C. Completion Reg'd. 1 S Inspection Procedures I. Stainless Steel Pipe 1. Expose approximately 10 feet of pipe all around. 2. Clean the pipe surface to bare metal with a wire brush made with stainless steel bristie. 3. Make visual inspection of the pipe for general surface corrosion and pitting. Measure pit depths with a pit depth measuring gauge. 4. Subtract pit depth from nominal pipe wall thickness and coupare with minimum wall thickness requirement. (Refer to acceptance criteria in Attachment II.) II. Valve Bodies and Flange Hardware 1. Expose valve body all around including all flange hardware. 2. Clean the valve body, flanges, and bolt and nut surfaces to bare metal with a wire brush. 3. Measure pit depths on the valve body using a pit depen gauge. 4. Measure the wall thickness using ultrasonic (UT) test procedures. 5. Subtract pit depth from measured valve body wall thickness and compare with minimum wall requirement. (Refer to Attachment II.) 6. Visually inspect the flange and valve bonnet nuts and bolts for evidence of corrosion. Replace all nuts and bolts.where corrosion has started. Retain old bolt and nut assemblies. 7. Inspect all old bolt and nut assemblies f rom item 6 above and proceed as follows for each assembly (refer to Attachment 11A). a. Detensine the number of bolt thrqads adjacent to the connecting flange bearing surface tnat are not corroded. (Heasure 0.0. and root diameter of thread on bolt and compare to new bolt thread if corros' ion is suspected but not evident.) b. Measure length of each nut and compare with a new nut. Inspect each nut thread for satisfactory condition. c. For determination of net bolt and nut bearing area: +

1) deasure bolt thread 0.D., 0.D. of nut adjacent to flange surface, and 0.D. of original size nut.

Determine nut bearing area of nut and compare to orig?nal nut bearing area.

2) Determine the net bearing area of the bolt head similar to the above.

d. Take thtee (3) worst corroded bolts for botn the 3/4" and 7/o" size and run tension tests to f ailure for each bolt. Record failure load. i III. 4/0 Copper Cable Ground Laterals 1. Carefully clean the soil froa around the cable and note the color S of the cable surface. 2. If enere is an accumulation of corrosion product, remove these products and save for analysis if needed. 3. Wire brush portion of the cable (approx. 2 ft.) clean, and check for pitting and other signs of corrosion. 4. Refer to Attachment IIIA for acceptance criteria. u-ees e

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1 0 ATTACIIMENT III A .,55. i 1A.IR No. Unit A or 1 2A. Completion Reg'd. Palo Verde Nuclear Generating Station ^ AO:IR-024 7-20-84 Units 1, 2, & 3 13,7R No. Unit 2 2B. Completion Reg'd* INVESTICATION REQUEST 3.Page

4. Q Class

. 5. System Desig. lc.IR No. Unit 3 2C. Completion Req'd. I g Acceptance Criteria 4/O Ground Cable Laterals 1. Cable is satisfactory and can be backfilled when the following is observed: a. Discoloration of cable with no evidence of corrosion attack. b. General corrosion, with or without cable discoloration, when the cabie roughness is 30 nils or less at the points of the maximum depth. 2. The portion of the cable or length of corroded cable shall be replaced when the following is observed: a. Surf ace attack where there is pitting of all surfaces strands greater than 30 mils, without actual parting or severance of strands. b. One or more strands are parted. q h i i I l i L

r_ 13-PM-205 AIIM i ATTACHMENT Y RECOMMENDED PROCEDURES FOR COATING AND WRAPPING OF pURIED STAINLESS STEEL PIPE l'. 0, MATERIALS Material Manufacturer Primer: Chloride-Free TC Cold Prime Tapecoat Company Tape: Tapecoat CT 10/40W Tapecoat Company Equipmenti ' Hand Wrapster #3 Tapecoat Company 2.0 SURFACE PREPARATION 2.1 Remove weld slag, weld spatter, dirt, or other foreign material by wire brushing and/or grinding. Remove sharp edges by grinding. Round and contour all welds to a smooth radius, not to extend more than 1/8 inch above the base metal. 2.2 Remove oil or grease with a volatile solvent such as xylene in accor-dance with SSPC SP-1. 14 3.0 APPLICATION 3.1 Apply one coat of primer to the clean, dry surface of the pipe in accordance with the manufacturer's latest published instructions. Apply only a thin film that is adequate to wet the surface. Allow the primer to become " tacky" (approximately 5 to 15 minutes, depending on environ-mental conditions) before the tape application. Apply tape only to primer that is tacky; 'if the primer dries out, it must be reprimed with another thin coat. Prime only that amount of pipe that can be wrapped during the same workday; the primer is expected to remain tacky for this period. 3.2 Apply tape to the primed surface in accordance with the manufacturer's latest published' instructions. Select the proper width tape for the size of pipe. Apply a single spiral wrap with edges overlappeo 1 inch minimum. Use enough tension to obtain a tight and conformable wrapping free of wrinkles or voids. Do not overstretch the tape to the point that its thickness is reduced. Overlap the end lap of each new roll at least six inches on the preceding roll. On the last encirclement, or at the end of the tape strip, relax the tension and prime the end of the tape to ensure firm adhesion to the pipe. This procedure will reduce the tendency of the tape to pull back or creep. NOTE: Do not leave rolls of tape exposed to stron, sunlight. Keep tape in cartons or under cover until ready for use. Y-1 y 'E-W-J

.~ 13-FM-205 ATTACHMENT T (co. 4.0. INSPECTION 4.1 Following the field application, visually inspect the coated and wrapped pipe for voids or other defects. Inspect for pinholes or holidays with a Tinker and Rasor Model AP holiday detector or accepted equal, at a minimum of 12,000 V. Use the holiday detector at a tr'avel rate not to exceed one foot per second. Do not allow the holiday detector to remain stationary while the power is on. 4.2 Indicate defects clearly with chalk immediately upon discovery. 5.0 REPAIR 5.1 Remove all loose or defective tape in the area of repair and approxi-mately 2 inches in the surrounding area. Reapply primer to the exposed area and overlap onto the cleaned existing tape. Reapply tape to the repair area, overlapping onto the existing tape at least 6 inches. 5.2 " Window patching" may be used to repair pinholes, provided there are fewer than 3 pinholes per linear foot of pipe. Apply,cne layer of tape over the pinhole as a window patch (at least 4 square inches), and follow 14 by a second layer of tape applied completely around the pipe. 5.3 Inspect all repairs in accordance with paragraph 4.0. 6.0 HANDLING OF COATED PIPE 6.1 After testing and repair, handle tape-coated pipe in a manner to protect the tape coating from damage. 6.2 Lift, lower, or suspend tape-coated pipe by the use of rubber or canvas belting with a removable pin and clevis on one end to permit removal of the belt without injury to the tape coating. The belt width is to be equal to or greater than the pipe diameter. The use of ropes, books, chains, or cables is not permitted. 6.3 In the lowering-in operation, take care to prevent swinging impact - or scuffing on the sides of the ditch. 6.4 The ditch shall be free of rocks, hard clods, stumps, skids, roots, and other solid debris. The excavated backfill soil shall be free of heavy rocks, clods, protrusions, or other foreign objects. A buffer board may be used to protect the pipe from damage during backfilling. 6.5 Backfill immediately af ter lowering-in. Perform backfilling with s care to prevent coating damage. k'. Y-2 y s

13-CM-300 j77AC#MENI 1 9.2.2 Placement 9.2.2.1 Filter Material Filter material shall be placed immediately following completion of the embankment. The subgrade upon which the filter material is to be placed shall not vary from the planned slope by more than 1 foot measured at right angles to the slope. The placing methods shall be such as to prevent segregation of the material. 9.2.2.2 Riprap 9.2.2.2.1 A footing trench shall be excavated along the toe of the slope. Rocks shall be so placed as to provide a minimum of voids and the larger rocks shall be placed in the toe course and on the outside surface of the slope protection. The rock may.be placed by dumping and may be spread in layers by bulldozers or othe~r suitable equipment. Local surface irregularities of the slope protection shall not vary from the planned slope by more than a tolerance of plus 0.50 foot except that the extreme of such tolerance shall not be continuous over an area greater than 200 square feet. 9.2.2.2.2 At the completion of the work, the footing trench shall be filled with excavated material and compaction will not be required. 10.0 BACKFILL 10.1 General 10.1.1 This section includes the material, moisture control, placement, compaction and testing requirements for the various classes of backfill. 10.1.2 Depending on the functional and engineering requirements, the backfill will be classified as follows: a. Structural Backfill, Class 1 (also called Category 1 7 Structural Backfill) This backfill is that fill placed under and around Category 1 i structures including Category 1 pipelines and as otherwise shown l on the drawings. This material is further defined in'10.2.2. b. Structural Backfill, Class 2 This backfill is that fill placed under and around non-Category 1 structures and as otherwise shown on the drawings. This material is further defined in 10.2.3. t c. Emb'ankment Fill This backfill is any fill required to raise the existing grade to the required finished grade elevation outside the limits of the power block structures. Further definition is given in 10.2.4. 8 o W E

a 13-CM-300 d. Backfill for Underground Utilities This backfill is any fill placed under or around buried utilities other than Category 1 pipelines. This definition includes con' rete c encased electrical ductbanks in utility corridors. Further 'defi-nition is given in 10.2.5. e. Category 1 Ductbank Material This material shall consist of sand as required to encase the electrical ducts. Further definition is given in 10.2.6. ) 10.2 Material Requirements 10.2.1 General 10.2.1.1 Backfill materials may be obtained from power block excavations or from other appcoved borrow areas. Designation and approval of a borrow area does not mean that all materials within that area are suitable for backfill. Only suitable material from approved borrow sources shall be placed in the backfill. Material containing brush, roots. peat, sod or other organic, perishable or deleterious matter, snow, ice or frozen soil, shall not be placed in the backfill. If unsuitable material is placed in any part of the backfill, all such material shall be removed and replaced with suitable material. 10.2.1.2 Materials suitable for structural backfill may be separately 7 stockpiled for later use. If stockpiling is done prior to backfilling, gradation testing in accordance with the requirements of 10.4.7 should be performed on the material prior to placing in the stockpile in order to determine its suitability for structural backfill. All materials from stockpiles which have not been prequalified by gradation testing and from other potential borrow sources shall be tested to establish their suit-ability for backfill in accordance with the requirements of 10.4.7. Only those materials meeting the specified quality requirements shall be used as backfill. 10.2.1.3 Materials shall be moisture conditioned as far as practicable in the stockpile areas by sprinkling, aerating, harrowing, discing, drain-ing or other approved means in order to obtain uniform moisture distribu-tion such that the specified density may be obtained. Sprinkling shall be by sprinkler trucks equipped with pressure spray bars and valves to give a uniform and even application of water to the dry areas and a positive control of the rate of water application at all times. 10.2.1.4 Any section of backfiil containing material which is too wet or too dry shall not be compacted until the moisture content meets the limits necessary to achieve the specified density or the material shall be removed 3 and replaced with material having a moisture content within acceptable limits. 9 'h'# r.=eM e i ~_ _

13-CM-300 .e-l' 10.2.1.5 Should, in the opinion of the Field Engineer, any portion of the surface of the backfill become so dry or glazed during construction that bond with the succeeding layer to be placed thereon cannot be obtained or should ruts and roadways develop on the backfill, such surfaces shall be scarified to a minimum depth of 6 inches, releveled, moisture condi-tioned, and recompacted to the specified density just prior to placing of the succeeding layers. 10.2.1.6 Extreme care should be exercised in placing and compacting back-fill in the proximity of all structures. Heavy construction equipment shall not pass over any permanent plant structure or pipe until such struc-tures and/or pipes are covered by the applicable minimum depth of fill shown on the drawings or as specified. 10.2.1.7 During backfill compaction neavy construction equipment shall not be used within a distance of 2 feet (plus or minus) from any concrete structures or walls (except electrical ductbank). The compaction of backfill adjacent to concrete structures or walls (except electrical ductbank) within a distance of 2 feet (plus or minus) and in other restricted areas shall be done using hand-operated vibratory compactors and/or power tampers. 7 10.2.1.8 All classes of backfill shall conform to the material and com-paction requirements specified below for the respective class of backfill. The backfill shall be placed and compacted to the elevations and limits shown on'the drawings. 10.2.2 Structural Backfill, Class 1 In addition to the general material requirements, this class of backfill shall be well graded and dense, and shall consist of sound, durable material from a designated borrow area or required excavation and shall conform to the following gradation limits: U.S. Sieve Number Percent Passing or Opening Size by Weight 1-1/2 inch 80 to 100 No. 4 60 to 100 No. 10 50 to 100 No. 40 20 to 90 No. 100 0 to 60 No. 200 0 to 30 1 10 'e s w sMs

13-CM-300 .. o. ' The maximum size of the material shall be 4 inches in confined areas where hand tamping is required and no greater than 2/3 the uncompacted lift thickness in other areas. The material shall not contain soil lumps which will not break down and compact satisfactorily when rolled. The backfill gradation shall be such that each zone is free of pockets and layers or streaks of poorly graded material. Clay layers encountered in the exca-vation shall not be used in structural backfill. 10.2.3 Structural Backfill, Class 2 This class of backfill shall meet the requirements of Structural Backfill, Class 1, except that the maximum limit of fines passing No. 200 U.S. sieve is 40 percent. 10.2.4 Embankment Fill All onsite soils, provided they conform to the general material require-ments specified, will be suitable for use as embankment fill. In addition the embankment materials shall conform to the following: No rock over 2/3 the loose lift thickness will be permitted in the top lift of the embankment. No rock greater than the loose lift thickness will be per-mitted in other portions of the embankment. 7 10.2.5 Backfill for Underground Utilities All onsite soils will be suitable for the backfill for underground utili-ties provided they conform to the general material requirements specified. Backfill within 6 inches of the underground utilities shall be free from rocks, hard lumps, and clods greater than 3 inches in maximum dimension. 10.2.6 Category 1 Ductbank Material Electrical duct sand encasement shall conform to the following gradation limits: Opening Size or Percent Passing U.S. Sieve Number by Weight 3/4 inch 100 1: 3/8 inch 95 No. 200 0 to 10 7 Larger material shall be evenly distributed throughout the fill. 1; As-an alternative, lean concrete (2000 psi) may be used in lieu of sand. Kt-10.2.7 Cementitious Aggregate t'onerete 9 ~ Cementitious aggregste concrete back. fill may be used in lieu of embankment fill. This may also be used in lieu of structural backfill Class 2 in non-load bearing applications or backfill for non-Category 1 pipes and ducts for underground utilities with t,he approval of the Engineer. This shall be used 11

13-CM-300 l. 10.3.2.1 Backfill in Restricted Areas Backfill in restricted areas, for the purposes of this specification, is defined as backfill below elevation 51'-6" around the Auxiliary Building, backfill in the Containment Building between the reactor pit walls and tendon gallery walls, and backfill in areas, as determined by the Field Engineer, too restricted to allow operation of heavy compaction equipment. In areas too restricted to allow operation of the specified roller types, the backfill shall be compacted in lifts with uncompacted thickness no greater than 6 inches using hand-operated or light power compaction equipment. 10.3.2.2 Backfill in Unrestricted Areas For the purpose of this specification, backfill in unrestricted areas is defined as all backfill not covered in 10.3.2.1. Backfill in these areas shall be compacted using heavy compaction equipment and as covered in 10.3.2. 10.3.3 Placement of Structural Backfill, Class 2 The placement criteria for Structural Backfill, Class 1, as described in 10.3.2 shall be used as guidance for this class of backfill to achieve the specified compaction. 7 10.3.4 Placement of Embankment Fill Embankment material shall be placed in successive horizontal layers and shall be compacted to not less than 90 percent of maximum dry density as determined by ASTM D 1557, unless otherwise shown on the engineering drawings. 10.3.5 Placement of Backfill for Underground Utilities 10.3.5.1 Bedding requirements are given in 13-CM-335, " Underground Utilities." Backfilling of pipe trenches shall not be completed until the entire length of pipe being backfilled has been inspected, tested if required, and approved by the Field Engineer. Backfill shall be placed in layers of uniform thickness, and compacted by rolling or tamping. ihe l l lift thickness of loose backfill material placed shall not exceed 12 inches, and shall be as required by the Field Engineer considering the type of ( backfill material, compaction equipment and type of pipe. This method of filling and compacting shall be continued until the backfill is 12 inches over the top of the pipe. At no time during backfilling operations shall the differential elevation of the top of backfill on opposite sides of a pipe exceed 1 foot. 10-3.5.2 Each layer of backfill up to a level 1 foot above the top of tho l pipe shall be compacted to a density not less than 90 percent of the maxi-3 mum dry density as determined by ASTM D 1557. l ? i 14 9 + t 4 = N " 94

13-CM-300 P.' ]

• 10.3.5.3 Backfill shall be placed to a minimum depth of 3 feet above the top of pipes or structures before power operated heavy hauling or rollini; equipment is operated over the pipe or structure, except that equipment not exceeding a total seight of 5,000 pounds is permitted after backfill'has been placed and compacted to a minimum depth of 1 fout above the top of pipe.

l '10.3.5.4 All backfill more than one foot above the top of the pipe, shall be placed in 8 inch loose lifts along the trench, and compacted to not less than 85 percent of maximum dry density as determined by ASTM D 1557. The backfill material shall be brought up above the adjacent rough grace in the form of a mound of sufficient height, to allow for settlement of the trench material. 7 10.3.5.5 Compaction of trench backfill by pending and jetting will not be permitted. 10.3.5.6 Pipe trenches shall be backfilled as soon as possible after the i pipe has been installed; provided, however, that no backfilling shall be performed until trenching, pipe bedding and installation, and testing, if required, have been approved by the Field Engineer. 10.3.5.7 Backfilling of trenches for temporary construction services in areas other than power block structures or Category I structures, areas not under roads or other permanent plant items, are exempt from the compaction density requirements of this section. These areas may be backfilled as directed by the Field Engineer. 10.3.6 Placement of Category 1 Ductbank Material Sand shall be placed around the ducts by dumping and shall be wetted and rodded as necessary to prevent bridging. The sand shall he compacted by vibrating in place, to a density not less than 95 percent of the maximum dry density as determined by ASTM D 1557. Sand shall be added as required 9 during compaction to fill depression caused by vibration or as required by the Field Engineer. Final ductbank configuration shall conform to the ductbank details shown on the electrical drawings. Backfill to grade above ductbank shall conforn ( to applicable material requirements of the area where the ductbank is located, (i. e., structural backfill Class 1 in Category 1 areas or backfill for underground utilities in yard tress). If lean concrete is used in lieu of sand, final ductbank configuration IC shall conform to the ductbank details shown on the appropriate electrical drawings. ~ 10.4 Testing i This section includes the testing requirements for Structural Backfill, 7 Class 1 and 2, Embankment Fill, and Backfill for Underground Utilities. The frequency of tests is outlined in 10.4.6. 10.4.1 A qualified soils testing laboratory shall perform all tests on compacted materials to assure compliance with these specifications. The 15 r-4

13-CM-300 soils testing laboratory will conduct field density and other tests and-the related laboratory compaction testing to determine the relative degree of compaction and other properties. At the direction of the Field Engineer and concurrent with construction, the soils testing laboratory will take representative samples of the material from the borrow areas, stockpiles or areas of backfill. These samples will be tested as required t'o deter-mine the acceptability of backfill quality and degree of compaction includ-irg any control or record tests which may be required. y 10.4.2 Representative samples of the backfill shall be tested in the laboratory in accordance with ASTM D 1557 in order to determine the maximum dry density and optimum moisture content applicable to the backfill mate-rial being used. 10.4.3 Moisture content determination shall be made in accordance with ASTM D 2216. 10.4.4 During backfilling, the field compaction shall be monitored by performing field density testing in accordance with ASTM D 1556. Compactica equipment must be stopped during the time the sand is being poured into the hole during these field density tests so as to prevent its densification by vibration. All field sandcone density tests should be made ic=ediately 11 below the depth of surface disturbance caused by compaction equipment. The relative degree of backfill compaction shall be determined by dividing the field dry density by the maximum dry density determined by laboratory testing for the backfill material being tested and the result shall be expressed as a percentage. 10.4.5 The backfill quality shall be determined by performing gradation test in accordance with ASTM D 422 using the wet sieving procedure. 10.4.6 The minimum frequency of testing required to-monitor the backfill compaction and quality for the various classes of backfill is given in table 1. 7 10.4.7 Unless Structural Backfill, Class 1 or 2 is obtained from pre-qualified stockpiles, gradation testing specified below will be in addition to any other gradation tests that are performed in conjunction with labora-tory or field testing. If material is obtained directly from excavations in potential borrow areas or from stockpiles which have not been prequalified, periodic gradation testing on representative soil samples in accordance with ASTM D 422 using wet sieving procedure is required to ensure that only materials conforming to the specified gradation limits for the structural backfills are used. T5is testing should be performed prior to hauling the materials to the backfilling area. A minimum of one gradation test in accord nce with 3 ASTM D 422 ueing the wet sieving procedure for every 1000 yd of potential fill material is required to monitor the quality of backfill cisterial. 16 q,pr,94

13-CM-300 - ~ .If nonuniform soil conditions exist in the borrow areas or unquelified stockpiles, more gradation tests will be required to establish the material suitability. The extent of additional testing shall be determined by the Field Engineer who is monitoring the quality of backfill materials and responsible for the excavation work. 7 \\ 10.4.8 All test report results, for both density and gradation, shall be .in whole numbers. This is not meant to reduce the accuracy of calculations, which may be carried to any necessary degree of accuracy. It is necessary .that any reported value, to be compared with values stated in this specifi-cation, be on the same basis.- l 4 I 'M

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LO VERDE NUCLE AR GENER ATING KT AT8cN SPECIFICATION CHANGE NOTICE [h- (k-335 hhff (SCN) e 6 Gu ALITY CLas$ / I h., 104o7 SHEET G --G-8' 3.,. 6. @sem ( Joe NO l [; Cleaning shall be done by power tool or hand tool, followed by'" solvent cleaning using a solvent recommended by the coating manufacturer. g {Q,3 Costing Application Costing shall be: 1 - Koppers "Bitumastic 300" or 2 - Ameron "78 EB" Coating shall be applied by brush to a dry film thickness of 12 to 25 mils in one coat, ensuring that all surfaces I are thercughly coated sud taking special care to ensure that anting surf aces between bolt heads and flanges receive additional coating to ensure continuity of coverage. f.8, y Curing Coated surfaces shall be allowed to cure undisturbed for a sinimu= l f of 72 hours. At the end of this period, back fill may proceed. Care must be taken to prevent damage to the coating. (Note: Any indication that film is soft prior to back fill would indicate that additional curing time at ambient conditions is required; optimum curing time at ambient before back filling is tan days.) l l l N My -/L h//, af sco/A : Ily ra.hr d l 9.9 l_ ~ e %'_t

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7,,,... Bechte! Power Corporation Engineers - Constructors 12400 East Impenal Highway Norwalk, California 90650 uAucoRess P o 80x 60660. TERMINAL ANNEX. LOS ANGELES. CALFORNIA 90080 TELEPHONE Q13)664-601I G B/ANPP-E-101069 MOC 249275 Responsible Action By April 13, 1983 Eng. (Date) @/t/-$3 Arizona Nuclear Power Project '] Comment **E ] Info P. O. Box 21666 - Mail Station 3003 Phoenix, Arizona 85036 Attention: Mr. Edwin E. Van Brunt, Jr. APS Vice President, ANPP Project Director

Subject:

Arizona Nuclear Power Project Bechtel Job 10407 Cathodic Protection for Underground Piping and Valves, Units 1, 2, & 3 File: E.16.05

Reference:

(A) Telex ANPT-2986-EEVBJR/ACR, March 30, 1983 (B) Letter B/ANPP-E-97418, December 17, 1982

Dear Mr. Van Brunt:

As requested in your telex [ Reference (A)], the current status of the field testing and review of the installed cathodic protection system is summarized as follows: 1. Field tests were completed during the period January 10 to February 4, 1983, to determine voltage potential levels of the buried stainless steel piping, with the existing rectifier settings. Also, data was recorded to calculate the incremental current needed to raise tne potential level of this piping to acceptable levels at various locations. The data shows that a significant number of-areas containing buried stainless steel piping require supplemental cathodic protection. The number and location of test coupons to be installed for evaluation of additional anode bed requirements, as noted in our letter (Reference (B)], was determined from this L Potential survey data. A tabulation of the recorded test data is i enclosed as Bechtel interoffice memorandum dated February 8, 1983 (Enclosure (2)]. p NO e. NY

Bechtel Power Corporation

• 'r-

.Mr..E. E. Van. Brunt, Jr.

Page.2-E/ANPP-E-101069 HOC 249275

. April 13, 1983 w i 2. Design Change Package DCP-lSE-QH-005 was approved March 31, 1983, A -to proceed with the installation of these test coupons and reference electrodes for the buried stainless steel piping, and some ductile iron piping. Test data gathered from these test plates will be used to assess the overall performance of the present cathodic protection system and determine the location for additional anode capacity, as previously noted in Item 1 above. 3.: Field requisition of the above test coupons and hardware accessorier. is now in process. Bids have been received and award will be made this week. Material delivery is anticipated about the first we'ek in June, 1983. 4. A revision to DCP ISE-QH-005 is also now in preparation to purchase and install the additional recti.fiers and anodes required for the buried stainless steel piping, as lead time for this material is twelve ~(12) weeks. The rectifiers will be the same as those originally purchased on Purchase Order 13-EM-109 and will be added to this-purchase order. The anodes (16 per rectifier) will be 7 f t. long'for installation in 15-25 ft. deep shallow anode beds. 5. Field' testing'for. continuity and grounding of the buried fire-C protection piping system has been completed. This tes't work was outlined.as Items 1 and 2 in_our letter (Reference (B)}. Five pipe, . loops around Units 2 and 3 were found to'have excessive resistance and unsatisfactory-continuity due to broken'or poorly connected ~ copper bonding straps.. A sixth piping loop:in Unit 3.was found to have incomplete piping and will be retested for continuity upon. . completion. -The-location of each of the above problem areas.has been excavated and new bonding straps, consisting of_ insulated copper wire cadwelded to. tne pipe joints or bolted to pipe fittings,'as l applicable, 'are being installed.- A record of this corr'ective work is reported on Nonconformance Report NCR-CT-4063. Documentation r L .of method of testing for piping continuity and grounding, and test L results for 105 continuity check points (Enclosure (3)}, is enclosed L as Bechtel-interoffice memorandum dated March 18, 1983. L -It_should be noted that balancing-and adjustment of the overall cathodic h protection' system,:as currently installed, and as planned in our letter [ Reference -(B), Schedule' Item 1} was not possible, as eight rectifiers of 1 the Unit 3 Cathodic Protection System were temporarily shut'down to avoid [ excessive erfrent surges during welding of the Unit 3 condensate storage tank.._(This welding'~does not affect the Units 1 and 2 energized cathodic p Protection system.) Also, a power outage occurred on the' Unit 1 ' cathodic ~ L protection system during the; scheduled field' testing period. 3 I. + ~ mo e a

,J. Bechtel Power Corporation .Mr..E. E. Vcn Brunt, Jr. Page 3 B/ANPP-E-101069 MOC 249275 . April 13, 1983 AdditionalheavyweldingwillcontinueintheUnit3areaforthedemineralizeb water storage tank, refueling water tank and reactor make-up tank. Tap settings are now being adjusted to reduce Unit 3 rectifier output in these areas, as required, to maintain best possible level of cathodic protection until com-pletion of this welding. Rectifier adjustments which will be performed during the overall three-unit balancing period will be performed during off-hour periods when this welding is not in progress. The updated schedule for the balance of the cathodic protection installation and test work is enclosed [ Enclosure (1)]. The schedule shows purchase and installation dates for additional cathodic protection equipment, field test periods for evaluation and adjustment of buried stainless steel piping protection levels, and the overall program to complete the cathodic protection system, including the final report. A project engineer has been assigned to coordinate the design modifications and to expedite coapletion of this very important system. Very truly yours, BECHTEL POWER CORPORATION (J 9tJ h t-W. H. Wilson [ Project Manager Los Angeles Power Division RWG:pb l

Enclosures:

(1) Schedule for Completion of Cathodic Protection System (1 page, 4 copies) (2) Bechtel IOM, T. Hartman from R. C. Robinson, 2/8/83 (15 pcges, 4 copies) (3) Bechtel IOM, T. Hartman from M. Castro, 3/18/83 (15 pages, 4 copies) cc: G. C. Andognini w/ enclosures D. B. Fasnacht w/ enclosures J. R. Bynum w/o enclosures J. M. Allen w/ enclosures - l e w gY'&$^$ JL-4

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~ .3. .) CATMODIC PROTECTION FItLD TEST FROCRAM (AS OF 4/6/83) ~ 2/25 3/tt 3/25 4/8 4/22 5/6 5/206/3'6/I77/1 7/15 7/29 8 !! 8/26 9/9 9/23 10/7 10/21 !!/4 11/18 12/2 12/16 12/30 FIRE PR91 KTION FIFINC After . Coatisoity verificaties - a Evaluatiae & Receansedaties Sepair 31ecentisettles s . CATE001C PROTECTION SYSTEM U Potentist Survey (Preliminary)' Ceept.'2/8/83 ~ ~ ar s "','! ""'d . j; - addtties.t T..t Comm '. ~. ' Restere Dett'3 Feuer & Survey ""'I Peteettale eith Test Coupese ' Additiemal Amedes & tectifiere P0 P0 Mg*t_ gee *g - Becttsiese Amedes Instatt - Att asedee & Rectifiere Energised , soak ~~ Adjust & Betance C[S. W Plant Potentist Survey. Final sepert, ~ ~ g o p e p, + ..= s e. o m J

-l % *... - t BechtelPowerCorporation ~ Interoffice Memorendum To om Hartman, w/ encl. File No. J1.1 - ANFP Subien Arizona Nuclear Power Project Date February 8, 1983 (ANPP) Units 1, 2& 3, Cathodic Protection System, Electrical From M. Castro Potential and Continuity Testing - Interim Report at Engineering Cope to R. N. Carscn, w/o encl. At LAPD Ext. 3993 R. R. Avila, w/o encl. R. C. Robinson, w/o encl. R. B. Lal, w/o encl. M. McNeill, Field, w/ encl.

Enclosures:

1. ANPP, Cathodic Protection System, Pipe Potentials at Excavations, Test Stations and Stub-Ups for 6" DW Service Stainless Steel Lines, dated February 8, 1983. 2. Sketch SK-10407-002-CP-101-0, Pcter.tial Profile for Buried 6" DW Service Stainless Steel Lines, dated February 9, 1983. 3. ANPP, Cathodic Protect'icn. System, Pipe Span Resistance and Current Flcw for 6" DW Service Stainless Steel Lines, dated. February 7, 1983. Reference is made to the January.10 - February 4, 1983 trip to the ANPP'jobsite by the Corrosion Cor. trol Group to perform the work necessary to determine the poter.tial levels of the buried bare stair.less steel pipes ar.d the'cor.tinuity of the buried fire water pipes, ar.d to conduct a ger.eral r pcter.tial survey of the buried structures ir. the staticn - area. ' Based on the-results of the measurements perfctmed in the staticr. area ar.d in the Water Reclamation area, ar.d of the-T ir.specticr. work at the excavaticr. points, we have prepared the fclicwing comments and reccmmendatior.s: Comm er.t s 1 The potential measuremer.t work cr. the buried stainless steel-pipes was the first field task performed. However, prict to the actual measurement work, the test lo c a t icr.s, that is, the poir.ts cr. the pipes seletted for te s t i r.g, had to be four.d ar.d i d e r.t i f ied. W y -r\\ r 'J, "-4 96 YA

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• . a Tcm Hartman Page 2 We. proceeded to locate pipes, stub-ups, valve boxes and other points accessible and useable for testing purposes.

Excava-ti'on of the stainless steel pipes was carried out only at -locations where there was no access to the pipes and testing was required. The field test work was started at the North side of the Chemical Production Building using two stub-ups for the DW stainless steel pipes and a stub-up for the domestic water service (DS) copper pipes for the potential measurements; the test work was then continued at the North side of the Water Treatment Building when the DW stainless steel pipe connections to the Rinse Water Tank along with a DS copper pipe located on the South side of the building were used for the measurements. The potential measurement work was then continued along the route of the stainless steel header pipe, where the potentials were measured on the pipe prcper or at holes excavated for the purpose and at existing potential stations. The potentials were also measured cn the pipe where it brarches around Units 1, 2 and 3, using excavated locations and other loca-tions where the pipe is exposed, such as stub-ups and valve boxes. Potential measurements at all test locations for the buried-6" DW service stainless steel lines are shown in Table 1 and' Sketch SK-10407-002-CP-101-0 (Enclosures 1 and 2). In the course of our measurement work in the Units 2 and 3 areas, we found that the electric arc. welding process being used.to erect the Unit 3 Condensate Storage Tank,'causes unusually high oscillations in the output of the surrounding cathodic protection rectifiers, up to 20 ampere spikes, there-by affecting the companion anode beds and the prctective ~ ~ levels; however, our primary concern at this time is that these high current spikes may damage the anode elements in the beds. - Because of this interference from the welding prccess the potential measurement work in the Units 2 & 3 areas had to be performed after regular working hours. Also, as part of the measurement work, we performed currer.t span tests, where possible, on the stainless steel pipes in order to better define the incremental current needed to raise the potential of these pipes. This test work turned cut well, generally, except for the work on the stainless steel pipes in front of Unit 1, where we were not able'to " buck outa the line current successfully, cor.tributed to by several ir.teracting rectifier s. Inis work also had to be . performed after regular workir.g hours in the-Units 2 & 3 areas,_because of the interference from the welding work e v'M4 " 5

r: ~* ' Tom Hartmcn Page 3 e underway. Results of the current span tests are summarized in Table 2 (Enclosure 3). u. Re' gar' ding the tests for verification of continuity for the pl-an t fire protection system pipes, the work was started with a walking inspection to confirm location and accessibility of selected test points; the test work using an audio generator was started in the vicinity of PIV No. 44 and proceeded along the Western boundary of the station. We have completed about 40% cf testing for the buried ductile iron pipe loops and have found them to be continuous to this point. We plan to complete this phase of our work during the week of February 21, 1983, and issue a separate report covering the results. Regarding the performance of the station-wide potential sur-vey, we were not able to conduct this work because of elec-trical interference from welding in the Unit 3 area and the fact that the Unit 1 rectifiers had been off for an extended period of time due to loss of power; this work will have to be re-scheduled to a time after the welding has been completed and the entire protective system has been operating without interruption for an extended period of time. As to the results of our test work, the review cf the potential values measured on-the buried stainless steel pipe, induced through the cycling of rectifiers local to the pipes, shows the impact of individual rectifiers on the potential of the pipes,-and, logically, the rectifiers that have to be adjusted to raise these potentials in the areas under test. If the rectifiers and their ccmpanicn anode beds can not or should not be adjusted upwards, supplemental ancdes will have to be installed in the area. The review of the current and voltage values obtained through the current span tests, and the calculations derived therefrcm, show the incremental current valves needed to raise the potential of the stainless steel pipe and other pipes in the locality, to a more cathodic level. In general, our tests indicate that all of the areas require - supplemental ampere capacity; this supplemental capacity can be supplied through increased rectifier cutputs cr installa-tion of new anode beds. However, before final adjustment of rectifiers or addition of ancde beds takes place, a number of test coupon assemblies should be installed throughout the site .tc aid in setting the rectifier cutputs and to be used to i monitor the potential level of~the stainless steel pipe.- After the test coupon assemblies have been installed and tested, - the~cutput of the_ rectifiers can be adjusted upwards, to the extent possible; af';er a "scaking" ~ period, a potential survey using the test coupon assemblies will show the areas where the supplemental anodes are required; the informatict cn hand e +~+ -.,n.

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Tom Hartman Page 4 will allow us to design the anode scheme fcr the supplemental anode capacity requirements. Because some of the ductile iron pipes for the fire system in the same bundle with the DW stainless steel pipes, and are consequently are in the same electric field and draw current, we suggest that provisions be made to monitor their behavior around the buildings. This would only require the addition of a ductile iron coupon with lead to each test couper. assembly, which now consists each of a 304 stainless steel coupon and a copper / copper sulfate reference electrode with leads. We are ser. ding you ccpies of the data obtained in the. field, cur derived calculations and a plan for test locations, all this as shown on Enclosures 1, 2 and 3. Recommendations 1. Based on the results of our work in the field, we reccmmer.d that a series of test coupon (304 stainless steel) Reference Electrode (Cu/Cu SO4) assemblies be installed and tested at selected locations along the DW pipe runs to measure the elec-tric gradient and to help monitor the energized potential of the stainless steel pipes. Ncte: Please be aware that we are in the prccess of developing a plan for the installation of the test assemblies and will send you this information as scen as possible. 2. Based on the results of the potential measurements and current span tests conducted, we recommend that the cathodic protecticr. system be both adjusted to a higher operating ~ level, where possible, and supplemented using shallcw impressed curre r.t anodes where necessary, in order to bringithe stainless steel pipes and pipe bundle in the locality into the protected range. Note: Please be aware that we are in the process of designir.g the ancde scheme and related informaticr. for-the supplemer.tal capacity needs for the cathodic protection systen. i 3. Based on the conditicns cbserved in the field, we recomme'c n that rectifiers Nos. 9, 10, 11, 43, 44, 45, 46 and 47 De turr.ed off until welding of tar.ks in the Unit 3 area has been_ccmpleted a..d tne rectifiers can be turned cr. safely. .4. ' Based cr. the conditicr.s found in the field, we recommer.d tnat the station-wide pcter.tial survey be postpcr.ed ur.til ~ sucn time that the welding of tar.ks in the Ur.it 3 area has beer, completed and the er. tire protective system has Deer.. cperated, ur.ir.terrupted, for accut a mor.th or so. a. (- ~

e Tom Hartman Page 5 Raga'rding our recommendations: Implemer.tation of Item 1 should take place as soon as you receive the pertinent information; -' implementation of Item 2 can take place after Item 1 has been implemented,-with the rectifier adjustment work takir.g place before any anodes are installed; Item 3 has been implemented. Please review our report and let us know if you have ar.y comments or would like to discuss the informaticr.. ?? -4 M. Castro MC:ljb - Enclosures ff 6 1. k f 4-m ~

• • 5

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y l AoLt 1 ENCLOSURE 1 [*J. ARIZONA NUCLEAR POWER PROJECT .los No.10407-002 - CATHODIC PROTECTION SYSTEM DATE 2-7-83 PIPE POTENTIALS AT EXCAVATIONS, STATIONS AND STUB.UPS TEST ENGR'S: R. R. Avila FOR M. Castro DW SEhVICE STAINLESS STEEL LINES . R. C. Robinson ON!0F F POTENTI ALS TEST COORDINATES MV TO CSE' 'LOCATIO N (STATE PL ANE) P!FE DEPTH AT GRADE REMARKS WATER RECLAM ATION ', N 873.077.00 46Gi-RECTIFIERS 6.11 & 12 ON ~ HOLE SCH-2 6" DW E 212.430.00 WATER RECLAM ATION N 873.077.00 473/434 RECTIFIERS 6.11 & 12 CYCLED HOLE SCH-3 6" DW E 212.260.00 SIMULTANEOUSLY WATER RECLAM ATION N 872.875.00 524/- 475/413 RECTIFIERS 6.11 & 12 CYCLED HDLE SCH-4 6" DW E 212.246.00 SIMULTANECUSLY UNIT 1 LAYD OWN N 872.600.00 644l570 RECTIFIER 30 CYCLE 0 A RE A P/S 716" DW E 212.242.20 UNIT 1 LAYDCWN N 872.600.00 622/538 CSE 15' E AST AREA P/S 716" DW E 212.242.20 573/510 CSE 15' WEST UNIT 1 LAYDOWN N 872.C99.78 692l666 RECTIFIER 1 CYCLED' ARE A P/S 70 6" 0W E 212.243.59 UNIT 1 LAYDOWN N 872.039.78 646/618 CSE 15' E AST ' AREA P/S 70 6" DW E 212.243.59 579 554 CSE 15' WEST UNIT 1 LAYDOWN N 870.083.00 651/591 RECTIFIER I CYCLED AREAHOLESCH 5A E 212.246.00 UNIT 1 PIPE C0ATIN G N 871.555.53 637/582 635!577 RECTIFIE R I CYCLED YARD HOLES SCH-5 & 6 E 212.245.5S UNIT 1 PIPE CO ATING N 871520.00 654i618 677/618 RECTIFIE R 1 CYCLED YARD PlS 69 6" DW E 212.180.00 UNIT 1 PIPE C0ATING N 871.520 00 635/587 - CSE 15* E AST YARD P!S E9 6" DW E 212.160.00 SE7/590 CSE 15' WEST UNIT 1 PIPE COATING N 871.350.05 702/653 697/654 RECTIFIER 1 CYCLED YARD HOLE SCH-7 E 211.892.20 ~ UNIT 1 PIPE C0ATING N 871.350.05 75$/714 CSE 15' E AST YARD HDLE SCH-7 E 211.892.20 677/649 CSE 15' WEST UNIT 1 NORTH 0F N 871.160.00 594/574 RECTiclER 2 CYCLED TU R8INE P!S 63 6"DW E 211.540 DC UNIT I NORTH O F N 871,160.00 620!595 CSE 15' E AST TUR8INE P!S 63 6" DW E 211.540.00 542/530 CSE 15' WEST UNIT I NORTH O F N 871.C25.36 52S/519 501/479 RECTIFIE R 3 CYCLEC TUR8INE SCH 8 6"DW E 211.342.82 UNIT 1 NO RTH OF N 871.025.36 481/460 CSE 15' E AST TUR8INE SCH-8 6" DW E 211.342 82 495/461 CSE 15' WEST UNIT I NORTH OF CONTAIN. 640!632 574l543 RECTIFIE R 3 CYCLED MENT VALVE PIT 6" DW UNIT 1 NORTH 0 F CONTAIN-575l569 CSE 15' EAST MENT VALVE PIT 6"DW 585'572 CSE 15' WEST UNIT I SPR AY POND N 870.C80.37 $35/528 RECTIFIER 5 CYCLED P.4 516" DW E 210348.48

• UNLESC SHOWN OTHERWISE. POTENTIALS ARE NEGATIVE TO COPPER SULFATE ELECTRODE (CSE SHEET 10F 9 7
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~ TABLE 1 ENCLOSURE 1 ARIZONA NUCLEAR POWER PROJECT JOB NO.10407-002 CATHODIC PROTECTION SYSTEM DATE 2-7-83 i PIPE POTENilALS AT EXCAVATIONS, STATIONS AND STUB.UPS TEST ENGR *S: 'R. R. Avila FOR M. Castro DW SERVICE STAINLESS STEEL LINES R. C. Robinson D.'i/0 FF POTENTI ALS TEST ^ 3 COOR DIN ATES MV TO CSE* LOCATION (STATE PLAfiEl PIPE DEFTH AT CRADE REMARKS UNIT 1 NO RTH 0 F CONTAIN-N 870 S43.74 574/553 545/526 RECTIFIER 3 CYCLED MENT P/S 55 6" DW E 211,165.98 UNIT 1 NORTH 0 F CONTAl.*l-N 870.943.74 582/553 CSE 15' E AST MENT P/S 55 6" DW E 211,165.95 554/536 CSE 15' WEST UNIT 1 NEaR RECTIFIER 4 N 870,776.79 495/476 461/454 RECTIFIER 4 CYCLED HOLE SCH-9 6" DW E 211.C53.88 UNIT 1 NEAR RECTIFIER 4 N 870776.79 492/476 CSE 15' E AST HOLE SCH-9 6" DW E 211.053.88 $42/489 CSE 15' WEST UNIT 2 NEAR RECTIFIER 5 N 870,350.00 551/536 520!506 RECTIFIER 5 CYCLED P/S 45 6"DW E 210.660.00 UNIT 2 NEAR RECTIFIER 6 633l601 630l600 RECTit >.R 6 CYCLED HDLE SCH-116" DW UNIT 2 NEAR RECTIFIER 6 595/555 5E1/524 RECTIFIER 6 CYCLED HOLE SCH-11 A 6" DW UNIT 2 NEAR RECTIFIER 6 579/536 CSE 15' E AST HOLE SCH 11A 6"DW 582/548 CSE 15' WEST UNIT 2 NEAR RECTIFIER 7 N 870.056.90 576'554 57!!571 RECTIFIER 7 CYCLED P!S 34 6" DW E 210.437.96 UNIT 2 NEAR RECTIFIER 7 765.'718 717/682 RECTlFIE R 7 CYCLED H OLE SCH-12 A 6" DW UNIT 2 NE AR RECTIFIER 7 765/718 717/682 RECTIFliR 7 CYCLED H OLE SCH-12 6" DW UNIT 2 NEAR RECTIFIER 8 N 669.544.93 684/614 639 633 RECTIFIE R S CYCLED P/S 316" DW E 210.178.43 UNIT 2 NEAR RECTIFIER 8 N 859,376.C8 584i541 532/50G RECTIFIER 8 CYCLED HOLE SCH-13 6" DW E 213.127.63 UNIT 2 NEAR RECTIFIER 8 N 869.231.42 593/586 587/580 RECTIFIER 8 CYCLED PiS 25 6" DW E 210.053.20 UNIT 2 NEAR RECTIFIER 8 N 869217.76 651/633 670/548 RECTIFIER 9 CYCLED - H OLE SCH-14 6" DW E 210.061.98 UNIT 3 NEAR RECTIFIER 9 N 868.962.84 721/676 716/669 RECTIFIER 9 CYCLED H0LE SCH 15 6"DW E 209.984.47 UNIT 3 NEAR RECTIFIER 9 N 668,982.84 529/539 $89/580 RECTIFIER 9 CYCLED P/S 15 6" DW E 209,984.47 1 UNIT 3 NEAR RECTIFIER 10 814/674 731/639 RECTIFIER 10 CYCLED HOLE SCH 16 6"DW 'UNLESS SHOWN OTHERWISE, POTENTIALS ARE f.'EGATIVE TO COPPER SULFATE ELECTRODE (CSE). SHEET 2 0F 9 p .en b.o 9-

F TABLE 1 ENCLOSURE 1 ARIZONA WUCLEAR POWER PROJECT JOB NO.10407-002 CATHODIC PROTECTION SYSTEM DATE 2-7-83 PlPE POTENTIALS AT EXCAVATIONS, STATIONS AND STUB UPS TEST ENGR'S: R. R. Avila ~ Y FOR M. Castro DW SERVICE STAINLESS STEEL Ll;JES R. C. Robinson Ch/DFF POTENTIALS TEST COORDINATES MV TO CSE' e LOCATION - (STATE PLANE) PIPE DEPTH AT GRADE REMARKS UNIT 1 W. 0F COND, TAN K 640/632 574/545 SEE UNIT 1 VALVE PIT SCI-16" DW O65 SHEET 1 UNIT 1 NEAR CONTAIN. HEAVY TRAFFIC AREA B LO G. SCl-2 UNABLE TO EXCAVATE UNIT 1 S.W.0F CONTAIN-HEAVY TRAFFIC AREA MENT SC1 1 UN ABLE T0 EXCAVATE UNIT 1 E.0F NITROGEN HEAVY TRAFFIC AP.EA STORAGE SC1-4 UN ABLE TO EXCAVATE UNIT 1 NEAR AIR HAND-ASPHALTED AREA LING SCl-5 UNABLE TO EXCAVATE UNIT 1 NEAR HEAT ASPHALTED AREA EXCHANG ERS SCI-6 UNABLE TO EXCAVATE UNIT 1 NEAR TURBINE ASPHALTED AREA BLOG SC1-7 4" CM 094 UNABLE TO EXCAVATE UNIT 1 NEAR LUBE OIL ASPHA.TED AREA TANK $C14 UNABLE 70 EXCAVATE UNIT I NEAR TURBINE ASFHALTED AREA BLDG SC1-9 UNAELE TO EXCAVATE UNIT 1 NEAR COND. TAfiK 453.448 RECTIFIER 4 CYCLED TP1-110" CD 001 UNIT 1 NEAR CONO. TANK 403101 RECTIFIER 4 CYCLED TP1-18" CP 165 UNIT 1 NEAR COND. TANK 400'333 RECTIFIER 4 CYCLED TPI-16" SCN 230 UNIT 1 NEAR CCND. TANK $15!513 RECTIFIER 4 CYCLED TPI-1 A 6" CW 067 UNIT 1 NEAR COND. TANK 525/523 RECTIFIER 4 CYCLED TPI-1 A 4" DW 045 UNIT I NEAR COND. TANK 447/444 RECTIFIER 4 CYCLED TP1 1 A 4" DW 035 UNIT 1 NEAR COND. TANK 463/467 RECTIFIER 4 CYCLED TPI-18 3" LR 133 UNIT 1 FUEL BLOG. 333/335 RECTIFIER 4 CYCLED TPI-2 3" CT 031 UNIT 1 FUEL BLDG. 400/396 RECTIFIER 4 CYCLED TPI 2 3"DW049 UNIT 1 FUEL BLDG. 397/394 RECTIFIER 4 CYCLE 0 TPl.2 3" DS 233 'UNLESS SHOWN OTHERWISE.PO!ENTIALS ARE NEGATIVE TO COPPER SULF ATE ELECTRODE (CSEl. SHEET 3 0F 5 o . < en-e. e ae + es m.., L g

TABLE 1 ENCLOSURE 1 ~ ARIZONA NUCLEAR POWER PROJECT JOB NO.10407-002 CATHODIC PROTECTION SYSTEM DATE 2-7-83 PIPE POTENTIALS AT EXCAVATIONS, STATIONS AND STUB UPS TEST ENGR'S: R. R. Avila FOR M. Castro DW SERVICE STAINLESS STEEL LINES R. C. Robiru: r. s ON/0FF POTENTI ALS 5 TEST COORDINATES MV TO CSE' LOCATION (STATE PLANE) PIPE DEPTH AT GRADE REMARKS UNIT 1 REACTO R M AKEUP TANK 415/410 RECTIFIER 37 CYCLED TPI-310" CH 385 UNIT 1 REACTOR M AKEUP TANK 460/455 RECTIFIER 37 CYCLED TP1-3 3" LR 194 UNIT 1 REACTO R M AKEUP TANK 461/453 RECTIFIER 37 CYCLED TF1-3 3" DW 049 UNIT 1 REACTO R MAKEUP TANK 524/501 RECTIFIER 37 CYCLED TPI-4 3"CH 333 UNIT 1 REACTOR M AKEUP TANK 521/505 RECTIFIER 37 CYCLED TP1-41 1/2" CH 415 UNIT 1 REACTOR M AKEUP TANK 5211505 RECTIFIER 37 CYCLEO TP1-4 3"CH 383 UNIT 1 HOLD UP TANK 524/501 RECTIFIER 37 CYCLED TPI-5 3" CH 333 UNIT 1 HOLD UP TANK 521/506 RECTIFIER 37 CYCLED - TPI-5 3" CH 383 UNIT 1 HO LD.UP TANK I 521l505 RECTIFIER 37 CYCLED TP1-5 2"CH 415 l UNIT 1 HOLD UP TANK 460!455 . RECTIFIER 37 CYCLED TPI 5 3"LR 194 UNIT 1 DEMIN. WTR. TANK $17/513 RECTIFIER 4 CYCLED TPI-6 4" OW 044 UNIT I DEMIN.WTR. TANK 553l545 RECTIFIER 4 CYCLED TPI-6 4" CW 045 UNIT 1 WASTE NEUTR AL TANK INACCESSIBLE TP1-7 UNIT 1 WASTE NEUTRAL TANK 404.'402 RECTIFIER 35 CYCLED TP1-810" CD 001 UNIT 1 WASTE NEUTRAL TANK 421/420 RECTIFIER 34 CYCLED TPI-9 8" CD 165 UNIT 1 WASTE NEUTR AL TANK 323!321 RECTIFIER 34 CYCLED TPI-10 6"SCN 233 i 'UNLESS SHOWN OTHERWISE. POTENTIALS ARE NE0ATIVE TO C0FPER SULFATE ELECTRODE (CSE). SHEET 4 0F 9 ~ m ~ _,m

TABLE 1 ENCLOSURE 1 ARIZONA NUCLEAR POWER PROJECT JOB WO 10407-o:3 CATHOOIC PROTECTIOM SYSTEM DATE 2-7-83 PIPE POTENTIALS AT EXCAVATIONS, STATIONS ANO STUB UPS TEST ENGR S: R. R. Avila FOR M. Cutro DW SERVICE STAINLESS STEEL LINES R. C. Robinson CN/0FF POTENTIALS

• TEST COO RDIN ATES MV TO CSE' LOCATION (STATE PLANE)

FIPE DEP1H AT GRADL REMARKS UNIT 2 W.0F CONDENSATE N 869.697.80 626l600 631/601 RECTIFIER 7 CYCLED TAN K SC2-1 6" DW 066 E 210.475.90 HEAVY TRAFFIC AREA, UNIT 2 NEAR CONTAINMENT N 863,747.03 BLOG.SC2-2 E 210,533.00 UNABLE TO EXCAVATE UNIT 2 S.W.0F CONTAINMENT N 8ES,679.34 598/578 551/535 RECTIFIER 7 CYCLED SC2-310" CH 385 E 210,497.29 UNIT 2 S.W. 0F CONTAINMEN1 N 869,679.34 537/577 550!536 RECTIFIER 7 CYCLED SC2-3 3" DW C49 E 210.437.29 UNIT 2 5.W. OF CONTAINMENT N 809,679.34 595!572 552!537 RECTIFIER 7 CYCLED SC2-3 3" CT 031 E 210.497.29 UNIT 2 E. OF NITROGEN N E69.579.34 629/634 597/572 RECTIFIER 42 CYCLED STOR AGE SC2-410" CH 385 E 210.451.10 UNIT 2 E. OF NITROGEN N 263,579.34 629/604 $97/572 RECTIFIER 42 CYCLED STORAGE SC2-4 3" DW 049 E 210.451.10 UNIT 2 NE AR HEAT EXCHAN-N 869,975.46 M0!520 522/503 RECTIFIER 6 CYCLED GER SC2-5 6" CTN 009 E 210,542.39 UNIT 2 NEAR HEAT EXCH AN-h 869.975.46 537/517 529/50C RECTIFIER 6 CYCLED GER SC2-5 8" CD 165 E 210.542.39 UNIT 2 NE AR HE AT EXCHAN-N 863.575.46 539/516 523:505 RECTIFIER 6 CYCLED GER SC2-510" CD 001 E 210.50.39 UNIT 2 NEAR HEAT EXCHAN-N 869,975.46 533 512 528!$05 RECTIFIER 6 CYCLED GER SC2 5 3" DW 165 E 210.M2.39 UNIT 2 NEAR HCAT EXCHAN-N 870.023.44 543/516 5481525 RECTIFIE R 6 CYCLED GER SC2-6 8" CD 165 E 210,595.79 UNIT 2 f. :AR HEAT EXCHAN-N 870,023.44 545!$20 548!525 RECT!FIE R 6 CYCLED GER SC2-6 6" SCN 230 E 210.595.79 UNIT 2 NEAR TURBINE BLOG N 859.933.33 472l457 443/436 RECTIFIER 39 C)CLED SC2 7 4" CM 094 E 210.701.86 ~ UNIT 2 N.lF LUBE OIL TANK N 870,119.32 525'515 54f!S33 RECTIFIER 33 CYCLED SC2-8 8" CD 165 E 210.E59.22 UNIT 2 N.lF LUBE OIL TANK N 870,119.32 524!513 547/531 RECTIFIER 38 CYCLED SC2-8 6" SCN 230 C 210.659.22 UNIT 2 NEAR TURS6NE BLOG N 870,150.24 532/490 524/494 RECTIFIER 38 CYCLEO SC2-9 4" TC 310 E 210 825.34 UNIT 2 NE AM TURBINE BLOG H 870.150.24 534/492 524/495 RECTIFIER 38 CYCLED SC2-9 6" SCN 230 E 210.825.34 UNIT 2 NE AR TURBINE BLOG N 870,160.24 535i454 525/495 RECTIFIER 38 CYCLED SC2-9 8" CD 165 E 210.825.34 UNIT 2 N E AR M AINT. 8 LOG, N 8CS.062.91 563'509 534/458 RECTIFIER 38 CYCLED SC210 4" CM 034 E 210162.3G 'UNLESS SHOWN OTHERWISE POTENTIALS ARE NEG ATIVE TO COPPFR SULFATE ELECTRO SHEET 5 0F 9

o l TABLE 1 ENCLOSURE 1 ARIZONA NUCLEAR POWER PROJECT .30B NO.10407-002 CATHODIC PROTECTION SYSTEM D ATE 2-7-83 PIPE POTENTIALS AT EXCAVATIONS, STATIONS AND STUB UPS TEST ENGR'S: R. R. Avila FOR M. castro DW SERVICE STAINLESS STEEL LINES R. C. Robinson ON/DFF POTENTI ALS e - TEST COO RDIN ATES MV TO CSE' ~ (ST ATE FLANE) PIPE DEPTH ATGRADE REMARKS LOCATION UNIT 2 NEAR CONDENSATE E18/510 RECTIFIER 40 CYCLED TANK TP2-110"CD 001 UNIT 2 NEAR CONDENSATE 505/501 RECTIFIER 40 CYCLED TANK TP2-18" CD 165 UNIT 2 NEAR CONDENSATE 449/447 RECTIFIER 40 CYCLED TANK TP2-16"SCN 230 ' UNIT 2 N EAR COND ENSATE 580/573 RECTIFIER 40 CYCLED TANK TP2-1 A 6" DW OE7 UNIT 2 NEAR COND ENSATE 521/512 RECTIFIER 40 CYCLED TANK TP2-1 A 4" DW 047 UNIT 2 NEAR CONDENSATE 534!519 RECTIFIER 43 CYCLED TANK TP2-1 A 4" CW 035 UNIT 2 NEAR COND ENSATE 534i525 RECTIFIER 40 CYCLED TANK TP2-1B 3" LR 193 UNIT 2 FUEL BLOG. 4381434 RECTIFIER 40 CYCLED TP2-2 3" CT 031 UNIT 2 FUEL BLOG. 435 432 RECTIFIER 40 CYCLED TP2-2 2" OW 043 UNIT 2 FUEL BLOG. 439 434 RECTIFIER 40 CYCLED TP2-2 2" D5 230 UNIT 2 REACTOR M AKEUP 523!509 RECTIFIER 42 CYCLED TANK TP2-310" CH 385 UNIT 2 REACTOR M AKEUP 511/503 RECTIFIER 42 CYCLED TANK TP2-3 2" LR 194 UNIT 2 REACTOR M AKEUP 506/496 RECTIFIER 42 CYCLED TANK TP2-3 2" 0W 049 UNIT 2 REACTOR M AKEUP 516/494 RECTIFIER 42 CYCLED TANK TP2-4 3" CH 393 UNIT 2 REACTOR M AKEUP 521/100 RECTIFIER 42 CYCLED TANK TP2-411/2"CH 415 UNIT 2 REA' OR M AKEUP TANK TP2-4 3"CH 383 522/497 RECTIFIER 42 CYCLED UNIT 2 HOLD UP TANK 411/403 RECTIFIER 42 CYCLED TP2 51"OW 128 i 'UNLESS SHOWN OTHERWISE. POTENTIALS ARE NEG ATIVE TO COPPE R SULFATE ELECTRODE (CSE) SHEET 6 0F 9 e h >_9**& 8

TABLE 1 ENCLOSURE 1 ARIZONA NUCLEAR POWER PROJECT JOB NO.1(M07-002 ~ CATHODIC PROTECTION SYSTEM DATE 2-7-83 PIPE POTENTIALS AT EXCAVATIONS, STATIONS AND STUB UPS TEST ENGR'Si R. R. Avila FOR M. Castro DW SERVICE STAINLESS STEEL LINES R. C. Robinson ON/0FF POTEhTIALS 'A TEST COORDINATES MV TO CSE' LOCATION, (STATE PLANEl PIPE DEPTH AT GRADE REMARKS UNIT 2 DEMIN.%7R'. TANK 634/C15 RECT 6FIER 40 CYCLED TP2-6 4" DW 044 N UNIT 2 DEMIN.WTR. TANK $49/542 RECTIFIER 40 CYCLED TP2-6 4" DW 044 S UNIT 2 WASTE NEUT RAL INACCESSIBLE TANKTP2 7 UNIT 2 NEAR BLOWDOWN 472/467 RECTIFIER 38 CYCLED D EM. TP2-810" CD 001 UNIT 2 NEAR HEAT EXCHAN-504/500 RECTIFIER 6 CYCLED GER TP2-9 8" CD 165 UNIT 2 N. 0F HEAT EXCHAN. 447/446 RECTIFIER 6 CYCLED GER TP2-10 6"SCN 230 'UNLESS SHOWN OTHERWISE, POTENTIALS ARE NEG ATivE TO CorPER SULFATE ELECTRODE (CSEl. 1: SHEET 7 0F 9 O

TABLE 1 ENCLOSURE 1 ARIZONA NUCLEAR POWER PROJECT JOB NO.10407-002 CATHODIC PROTECTION SYSTEM O ATE 2-7-83 PlPE POTENTIALS AT EXCAVATIONS, STATIONS AND STUB UPS TEST ENGR'S: R. R. Avila FOR M. castro DW SERVICE STAINLESS STEEL LINES R. C. Robmson ON/0FF PDTENTI ALS TEST CO O RDIN ATES MV TO CSE' LOCATION, (STATE PL ANE) PIPE DEPTH AT GRAuE ~ REMARKS UNIT 3 W. 0F CON!I. TANK PIPE NOT INSTALLED Sc3-16" OW OSS UNIT 3 NEAR CONTAIN. PIPE NOT INSTALLED B LOG. SC3-2 UNIT 3 S.W. OF CONTAIN-PIPE NOT INSTALLE0 MENT SC3-3 UNIT 3 E. 0F NITROGEN PIPE N OT INSTALLED ST AG SC3 4 UNIT 3 NEAR HEAT 723/678 7561680 RECTIFIER 10 CYCLED EXCHANGER SC3-5 8" CD 165 UNIT 3 NEAR HEAT EXCHAN-7191675 755/E96 RECTIFIER 10 CYCLE 0 GER SC3-5 6" SCN 230 UNIT 3 NEAR HEAT EXCHAN-720iG71 748/677 RECTIFIER 10 CYCLE 0 GE R SC3-510" CD 001 UNIT 3 NEAR HEAT EXCHAN-96!l778 1007/777 RECTIFIER 10 CYCLED G E R SC3-5 3' OW 165 UNIT 3 NEAR HEAT EXCHAfe. 496,479 832/769 RECTIFIER 9 CYCLED GER SC3-6 8" CD 165 UNIT 3 NEAR HEAT EXCHAfi-485!473 834s778 RECTIFlER S CYCLED GE R SC3-6 C" SCN 233 UNIT 3 NE AR TURB'tsE BLOG 644/527 642!$16 RECTIFIER 44 CYCLE 0 SC3 7 4"CM C94 UNIT 3 N.0F LUEE O!L TANK 1051/1068 1027/1029 RECTIFIER 45 CYCLED SC3-8 3" LW 165 UNIT 3 N.0F LUBE OIL TANK 695/E67 655/661 RECTIFIER 45 CYCLED SC3-810" CD 001 UNIT 3 N.0F LUBE OIL TANK 678/678 708/684 RECTIFIER 45 CYCLE 0 SC3-8 8" CD 165 UNIT 3 N.0F LUEE DIL TANK 686/688 721/694 RECTIFIER 45 CYCLE 0 SC3-4 6"SCN 230 - UNIT 3 NEAR TURBINE BLOG 1045/888 1082/918 RECTIFIER 43 CYCLE 0 SC3-9 8" CD 165 UNIT 3 NEAR TURBINE BLOG 1045!896 10881922 RECTIFIER 43 CYCLED SC3 9 6"SCN 233 UNIT 3 NEAR TURBINE BLOG 1012/887 1088/922 RECTIFIER 43 CYCLE 0 SC3-9 4" CM 094 UNIT 3 NEAR M AINT. 8 LOG 1066/883 1072/8E8 RECTIFIER 43 CYCLE 0 SC3-10 4" CM 034 'UNLES3 SHOWN OTHERWISE. POTENTIALS ARE NEGATIVE TO COPPER SULFATE ELECTRODE (CSEl. SHEET 80F9 er L

TABLE 1 ENCLOSURE 1 ARIZONA NUCLEAR POWER PROJECT JOB NO. IC407-002 CATHODIC PROTECTION SYSTEM DATE 2-7 83 PIPE POTENTIALS AT EXCAVATIONS, STATIONS AND STUB.UPS TEST E 4GR'S: R. R. Avila FOR M. cutro DW SERVICE STAINLESS STEEL LINES R. C. Robinson ON/0FF POTENTIALS TEST COORDINATES MV TO CSE* e LOCATION (STATE PL ANE) PIPE DEPTH AT GRACE REMARKS UNIT 3 NEAR COND, TANK PIPE NOT INSTALLE? TP3-1 UNIT 3 FUEL BLOG. PIPE NOT INSTALLED TB3-2 UNIT 3 REACTOR MAKEUP PIPE f.0T INSTALLED TANK TB3-3 UNIT 3 REACTOR MAKEUP PIPE NOT ifoSTALLED TANK TB3-4 UNIT 3 HOLOUP TANK PIPE NOT INSTAL LE0 TB3-5 UNIT 3 OEMIN. WATER PIPE NOT INSTALLED TANK TE3-6 UNIT 3 WASTE NEUTRAL PIPE NOT INSTALLED TAN K TE3-7 UNIT 3 NEAR BLOWOOWN 870/603 RECTIFIER 44 CYCLED DEM. TP3-810" CD 031 UNIT 3 NEAR HEAT EXCHAN. 537/516 RECTIFIER 44 CYCLED GER TP3 9 8" CD 165 UNIT 3 NEAR HEAT ExCHAN. l 832/750 RECTIFIER 44 CYCLE 0 GER TP3 9 4" CT 310 UNIT 3 N.0F HEAT EXCHAN. 732l642 RECTIFIER 44 CYCLED GER 5" SCN 233 t 'UNLESS SHOWN OTHERWISE, POTENTIALS ARE NEGATIVE TO COPPER SULFATE ELECTRODE (CSEl. SHEET 9 0F 9 p (

ENCt.OSURE 3 TABLE 2 JOB NO.10407-002 ARIZONA NUCLEAR POWER PROJECT DATE 2-7-83 CATHODIC PROTECTION SYSTEM PIPE SPAN RESISTANCE AND LINE CURRENT FLOW TEST ENGR'S: R. R. Avila FOR M. Castro 6" DW SERVICE STAINLESS STEEL LINES R.C. Rolnnson MEASURED VALUES CALCULATED VALUES l SPAN SPAN APPLIE D CURRENT REGUlRED TEST LENGTN SPAN CURRENT SPAN VetTAGE

• PIPE RESISTANCE LINE CURRENT FOR 100 FT SPAN LOCATION (L) FEET ll! AMPS (El MILLIVOLTS (R) MICR0 OHMS /FT AMPS /100 FT SPAN AMPS /lte MV SHIFT WATER RECLAMATION 0

-5.9 7, 54.65 0.374 0.959 HOLES SCH-2 TO SCH-3 0 $35 0 WATER RECLAMATION O 4.9 HOLES SCH-3 TO SCH4 0.411 0 UNIT I NEAR RECTIFIER 3 0 31.E HOLES SCH-5 TO SCH-7 0.500 42.5 UNIT I NEAR RECTIFIER 3 1.000 -5.1 HOLES SCH-3 TO VAULT l.630 0 UNIT I NEAR RECTIFIER 1 0 25.7 8' HOLES SCH-5 TO P/S 79 1.002 55 0 UNIT 2 NEAR RECTIFIER S 0 4.3 HOLES SCH-il TO SCH-il A O449 0 UNIT 3 NEAR RECTIFIER 9 0 -2.6 H0LES SCH-14 TO SCH-15 0999 12.1 AVERAGE CALCULATED VALUES 56.59 0.414 0 971

• PIPE RESISTANCE (R) DETERMINED FROM CHANGES IN MEASURED SPAN VOLTAGE (AEl AND APPLIED SPAN CURRENTS (AI).

I .. - gl 7 I; e a e ,9

Bechtel Power Corporation interoffice Memorandum To Tom' Hartman w/ enc 1. Fde No. J1.1-ANPP saieci Arizona Nuclear Power Project om March 18, 1983 (ANPP) Units 1, 2&3, Fire Protection Waterline From R. C. Robinson Electrical Continuity Survey - Final Report a Engineering coe.es to R. N. Carson w/o enc 1. At LAPD E.i. 2991 M. Castro w/ encl. R. R. Avila w/o encl. R. B. Lal w/o enc 1. M. McNeill (Field) w/ enc 1.

Enclosures:

1. Sketch SK-10407-002-CP-104-0, plan of Fire Protection Pipe Continuity Tests and Excavations, dated March 15, 1983. 2. . Table 1, Fire Protection Pipe Continuity, Induced Audio Signal Method, dated January 27,'1983. 3. Table 2, Fire Protection Pipe Continuity, Applied Span Current Method, dated March 16, 1983. 4. Figures 1&2, Photographs of Current Span Continuity Test and. Excavation, dated March 16,'1983. Reference is made to M. Castro's February 8, 1983. Interim Report and to our February 28 - March 11, 1983 survey by R..Avila and R. Robinson to complete the field testing for electrical continuity of the buried fire protection water-lines that are interconnected with Units 1, 2 and 3 cathodic protection systems. Our interim report describes the initiation of the work and selected ~ test points used to confirm continuity on about 40 percent of the buried ductile-iron pipe loops. It also describes the need for supplemental cathodic protection capacity and additional test coupon assemblies for monitoring the buried pipes. This final report covers the results of all continuity measure-monts performed in the station area, and at excavated points reqaired for locating pipe joint and fitting discontinuities. Based on this work, we have prepared the following connents regarding survey methods, test results, conclusions and recom-mendations, for repairing pipe discontinuities. e g A sF 'k {

E. .g p Tom Hartman page " Survey Methods The contiduity survey for the fire protection pipes included two methods of test. The first, known as the " Induced Audio Signal' Method" covered a broad range of piping laterals. The second, called.the " Applied Span Current Method" encom- ' passed a specific pipe lateral span and was used where discon-tinuities were suspect as noted by the first method. For the " Induced Audio Signal Method" a Tinker and Rasor Model PD Pearsor. Detector was used to apply an audio-frequency (750 hertz) a.c. signal between two test points in the pipe lateral up to several thousand feet apart. The signal was traced by traversing the pipe lateral using a receiver equipped with a-search coil. If a strong a.c. signal is received pipe continuity is confirmed. If the signal attenuates too rapidly continuity is suspect. For the " Applied Span Current Method" a 12-volt battery, rheostat, shunt ~and multimeter were used to apply a known anount of current (I) between two test points fron a few to several hundred feet Voltage drop (E) along the pipe span and pipe potential apart. to a copper. sulfate electrode (CSE) were also noted. pipe con-tinuity and span resistances (R) were determined from changes in measured span voltage (21E) and applied current (211). There -high' span resistances occurred, mid-span fittings and joints were exposed for further-incremental testing. Test Results and Discussion Results of the induced audio signal tests for 105 pipe locations throughout the station area are given in Table 1. They indicate that the majority of the' fire protection lines tested appeared continuous and conducted satisfactory a.c. signals. Sixteen lines were suspect and required further testing. At these loca-tions the signal could not be readily-traced. It attenuated rapidly via ground grid connections, pipe supports, building foundations or other parallel paths such as pipe discontinuities. The 10 suspect areas were retested using the applied span current method.. Their locations are noted on Sketch SK-10407-002-Cp-104-0, plan of Fire protection Continuity Tests and Excavations. Results 1 of these tests are summarized in Table 2. They show live pipe loops (items 2C, SC, 8D, 118, and ?SB) around Units 2 and 3 have excessive resistance and unsatisfactory continuity. A sixth pipe loop (item 10A) in Unit 3 has incomplete piping and needs to be 'i retested for continuity upon completion. e f 4A-

. r.. Tom Hartman Page, The five pipe loops with excessive resistance were excavated at . pipe joi'nt's and fittings for further incremental testing as shown in Figure 1. At these locations, the copper bond straps cadwelded across the joints were defective, damaged or broken as shown in Figure 2. The bonds can be repaired by rebonding with insulated

1. 4/0 copper cable.

As indicated in Table 2 item 2C, pipe joints and excavated tees F north of PIV #28 contain defective bonds. This condition was 'also noted for items llB and 15B. A broken tee bond was identi-

fied as the cause of the discontinuity between PIV #82 and PIV #83 (item SC).

In item 8D, the discontinuity was traced to the joints at PIV #58. In item llB, the exact location (s) of discontinuities between FH #3G and the excavated tee was not determined since most of the line is~ under a concrete slab used for storing pipe fittings. In this area, the fire hydrant, fittings and first pipe joint can be excavated, bonded and the hydrant connected to the ground grid i with insulated #4/0 copper cable. Continuity of the line can be verified during repairs. .During the survey it was noted'that 2G of 47 cathodic protection rectifiers were shut off; 18 in Unit 1 due to power outage and 8 in Unit 3 to prevent:danage from tank welding as discussed in the Interim Report. On March 8, 1983 the ApS Engineer was noti-fied and the power restored to Unit I rectifiers. Because of the above, a station wide potential survey should be-postponed until the power is uninterrupted, pipe continuity repairs are implemented and the Unit 3 welding is completed which is estimated to.be within the next few months. Conclusions and' Recommendations l. Fire protection pipes with properly cadwelded and coated copper bond straps across each joint and fitting provide -adequate conductivity for cathodic protection current;- bonds that are defective, danaged or broken can produce high' joint or fitting resistances resulting in inadequate protection current distribution.

2. -

Five pipe loops around Units 2 and 3, as shown in Sketch SK-10407-002-CP-104-0, were found to'have excessive pipe span resistance and their excavated pipe joints and fittings were inadequately bonded; a sixth pipe loop in Unit 3 had incomplete ' piping and - should be rechecked for continuity upon completion. 3. -Based on conditions found in the field, we reconnend that- 'high resistance pipe joints, fittings, post indicator valves _and fire _ hydrants identified in Table 2 be repaired by rebonding with insulated #4/0 copper cable cadwelded across each-joint'and/or fitting. m._, -A

s + ; ' Tom Hartman Page. - 4. Because of the inaccessible conditions for fire protection piping to hydrant FH #3G, it is recommended that the hydrant fittings and first pipe joint be excavated, bonded and the hydrant connected to the ground grid with a separate in-sula ad #4/0 copper cable. 5. . It is Iecommended that the station-wide potential survey be postponed a few months until the piping continuity repairs . and tank welding in Unit 3 are completed, additional test coupons installed and all cathodic protection rectifiers

are operational for a month or so.

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ENCLOSURE 2 TABLE 1 JOB NUMBER: 10407-002 ARIZONA 14UCLEAR POWER PROJECT DATE: JANUARY 27,1983 FIRE PROTECTION PIPE CONTINUITY TEST ENGRS: R. R. Avila INDUCED AUDIO SIGNAL METHOD R. C. Robinson SIG N AL TEST. SERVICE TEST CIRCUIT E ASILY TR ACED NUMBER. LINE NUMBER CONNECTION YES NO REMARKS t 1 256 PlV 47 to FH 45 'X Line appears contmucus ~ (West of Unit 3) 2 209 P!V 47 to P/S 7 X Line appears continuous (West of Unit 31 3 209 P/S 7 to PlV 86 X Line appears continuous (West of Unit 31 4 Temp. Line P/S 7 to Welding X Line appears continuous BuiMing (W/ Unit 3) 5 209 Piv 86 to PlV 83 X Line appears continuous l (West of Unit 31 6 258 PlV 83 to FH 44 X Line appears contmucus (West of Unit 3) 7 209 PlV 83 to PlV 82 X Poor signal,line suspect (West of Unit 3) Current span test required (5) 8 209 Piv 82 to PlV 81 X Line appears continuous (West of Unit 3) 9 209 PlV 81 to PiV 39 X Line appears continuous (West of Unit 31 10 Temp. Line PlV 81 to Maint. X Line appears continuous Shop (W/ Unit 3) 11 Temp. Line Piv 39 to FH 47 X . Line appears continuous (West sf Unit 3) 12 Temp. Line FH 47 to Saw Shop X Line appears continuous - (West of Unit 3) 13 Temp. Line FH 48 to FH 43 X Line appears continuous (West of Unit 3) 14 210 FH 1 to P/S 71 X Line appears continuous (Wtr Treatment) 15 210 P/S 71 to P/S 70 X Line appears continuoc (East of Unit 1) 16 210 P/S 70 to P/S 69 X. Line appears continuo.as (East of Unit 1) 17 -210,312, P/S 69 to FH 3 X ' Line appears continuous 264.263 (East of Unit 1) PlV - Post indicator Valves ( ) Number in parenthesis indicates span test location FH - Fire Hydrant shown in Table 2. ,. ~ f -O - SHEET 10F 7 ' ,..... u.

c. wm

F ENCLOSURE 2 TABLE 1 JOB NUMBER:,10407-002 ARIZONA NUCLEAR POWER PROJECT DATE: JANUARY 27,1983 FIRE PROTECTION PlPE CONTINUITY TEST ENGRS: R. R. Avila INDUCED AUDIO SIGNAL METHOD R. C. Robinson ~ SIGNAL TEST SERVICE TEST Cl!! Cult EASILY TR ACED NUMBER LINE NUMBER CONNECTION VES NO REMARKS 18 ' 314,312,310 FH 4 to PlV 4 X Line appears continuous (Unit 1) 19 310,312,309 PlV 4 to PlV 23 X Poor signalline suspect (Unit 1) Current span test required (13) 20 310 Piv 4 to FH 5 X Line appears continuous (Unit 1) 21 310 PlV 6 to FH 5 X Line appears continuous (Unit 1) 22 312.209 FH 3 to PlV 103 X Line appears continuous (East of Unit 1) 23 209 PlV 103 to P/S 72 X Line appears continuous (East of Unit 1) 24 209 P/S 72 to Flange X Line appears continuous at Fire Pump Hse 25 229 Unit 1 Fire Purnp X Line appears continuous Sta.to PlV 94 26 233,234,236 FH 35 to PlV 68 X Poor signal line suspect (West of Unit 1) Current span test required (1) 27 234 PlV 68 to FH 34 X Line appears continuous (North of Unit 1) 28 234 FH 34 to PlV 67 X Line appears continuous (North of Unit 1) 29 212 PlV 67 to PlV 106 X Poor signalline suspect (Unit 2 NW Area) Current span test required (11) 30 212 PlV 106 to TH 36 X Poor signalline suspect (Unit 2 h3 Areal Current span test required (11) 31 212 FH 36 to PlV 71 X Line appears continuous (N of Unit 2 Cool-ing Twr) 32 - 212 PlV 71 to FH 39 X Line appears continuous (E of Unit 3 Cool-ing Twr) 33 210,231,313 Unit 1 - FH 6 to X Line appears continuous - '(1 PlV10 34 210,313 Unit 1 - FH 6 to X Line appears continuous to PlV 7 PlV - Post Indicator Valves ( ) Nurnber in parenthesis indicates span test location FH - Fire Hydrant snown in Table 2. SHEET 2 0F 7 Rev.2/25/83 L

ENCLOSURE 2 TABLE 1 JOB NUMBER; 10407-002 _ ARIZONA NUCLEAR POWER PROJECT DATE: JANUARY 27,1983 FIRE PROTECTION PIPE CONTINUITY TEST ENGRS: R. R. Avila INDUCED AUDIO SIGNAL METHOD R. C. Robinson SIG N AL TEST SERVICE TEST CIRCulT EASILY TR ACED NUM8ER LINE NUM8ER CONNECTION YES NO REMARKS 35'

• 210,313,309 Unit 1 - FH 6 to X

Line appears continuots PlV 5 36 210,313,309 Unit 1 - FH 6 to X Line appears continuous Riser to Turbine Bldg. 37 210,313,289 Unit 1 - FH 6 to X Poor signalline suspect FH 7 Current span test required (3) 38 210,283,289 Unit 1 - FH 7 to X Line appears continuous FH 8 39 283,232 Unit 1 - FH 8 to X Line appears continuous Tool Rm 40 283,237 Unit 1 - FH 8 to X Line appears continuous Fuel Bldg. 41 283,286 Unit 1 - FH 8 to X Line appears continuous Piv15 l 42 283,286 Unit 1 - FH 9 to X Line appears continuous PlV 15 g 43 283,284 Unit 1 - FH 9 to X Line appears continuous PlV 17 44 283,209 Unit 1 - FH 9 to l X Line appears continuous PlV 19 l 45 282,283 Unit 1 - FH 10 to k - Line appears continuous PlV 18 46 280,209,282 Unit 1 - FH 10 to X Line appears continuous Piv 22 47 280,209,282 Unit 1 - FH 10 to X Line appears continuous -e' ' FH 11 48 280,209 Unit 1 - FH 11 to X Line appears continuous Piv 23 49 226 . Unit ! - PlV 20 te X Line appears continuous PlV 21 50 209 Unit 1 - PlV 21 to X Line appears continuous PlV 19 t 51 209,426 Unit 1 - PlV 19 to X Line appears continuous PlV 98 PlV - Post Indicator Valves ( ) Number in parenthesis indicates span test location FH - Fire Hydrant shown in Table 2. SHEET 3 0F 7 Rev.3/25/83 -s 4 b UwY# S ' ,,,e

I 3 s 1. ENCLOSURE 2 TABLE 1 JOB NUMBER: 10407-002 ARIZONA NUCLEAR POWER PROJECT DATE: JANUARY 27,1983 FIRE PROTECTION PIPE CONTINUITY TEST ENGRS: R. R. Avila INDUCED AUDIO SIGNAL METHOD R. C. Robinson SIGNAL TEST SERVICE TEST CIRCUIT EASILY TRACED NUMBER' LINE NUMBER CONNECTION YES NO REMARKS 69 314 Unit 2 - FH 12 to X Line appears continuous FH 13 70 314,210 Unit 2 - FH 13 to X Line appear. continuous FH 14 71 209 Unit 3 - PlV 37 to X Poor signalline suspect PlV58 Current span test reovired (8) 72 210,314 Unit 3 - PlV 30 to Line appears continuous FH 21 73 313,210 Unit 3 - FH 22 to X Poor signalline suspect PlV 44 Current span test reouired (15) 74 313,210 Unit 3 - FH 22 to X Line appears continuous Piv46 75 210,314 Unit 3 - PlV 44 to X Line appears continuous FH 21 76 210,314,309 Unit 3 - PiV 44 to X Line appears continuous Turb. Bldg. 77 239,210,313 Unit 3 - FH 23 to X Poor signalline suspect FH 22 Current span test reovired (15) 78 289,210, Unit 3 - FH 23 to X Line appears continuous 283,288 FH 24 79 283,287 Unit 3 - FH 24 to -X ' ho signalline suspect Fuel Bldg. Current span test required (16) 80 283,286 Unit 3 - FH 24 to X No signalline suspect Rad Waste Current span test required (16) 81-283,284 Unit 3 - FH 24 to X No signalline suspect '~ LRS Tnh Current span test required (16) 82 283,209,2.e2 Unit 3 - FH 25 to X-Line appears continuous FH 26 83 282,209 Unit 3 - FH 26 to X Line appears continuous '280,281 FH 27 84 311,314,310 Unit 3 - FH 20 to ,X Line appears continuous Turb. Bldg. ~- -t 85 311,314,303 Unit 3 - FH 20 to X Line appears continuous Maint. didg. ~ PlV - Post Indicator Valves ( ) Number in parenthesis indicates span test location ' FH - Fire Hydrant shown in Table 2. SHEET 5 0F 7 wh p=

.~ ENCLOSURE 2, TABLE 1 JOB NUMBER: 10407-002 ARIZONA NUCLEAR POWER PROJECT DATE: JANUARY 27,1983 FIRE PROTECTION PlPE CONTINUITY TEST ENGRS: R. R. Avila INDUCED AUDIO SIGNAL METHOD R. C. Robinson SIGNAL TEST' SERVICE TEST CIRCUIT EASIL Y TRACED NUMBER. LINE NUMBER CONNECTION YES NO REMARKS 86 312,314,;i11 Unit 3 - FH 20 to X Line appears continuous FH 21 87 209,222 Serv. Bid g. X Line appears continuous PlV 37 to FH 32 88 222,221 Serv. Bld g. X Poor signal line suspect FH 32 to PlV 63 Current span test repuired (141 89 222,211,220 Serv. Bidg. X Line appears continuous FH 32 to FH 31 90 220,211,389 Serv. Bldg. X Line appears continuous FH 31 to FH 46 91 218,211 Admin. B!dg. X Line appears cor.tnuous FH 46 to PlV 97 92 218,211,217 Admin. Bldg. ~ X Line appears continuous FH 46 to FH 28 93 217,211 Switchyard - X Line appears continuous FH 28 to FH 29 94 211,213,216 Swittri, ard - X Poor signal hne suspect FH 29 to FM 30 Current span test reouitec (9) 95 216,213,214 Switchyard X Line appears continuous FH 30 to PlV 92 96 216,213,215 Switchyard - X Line appears continuous FH 30 to PlV 91 97 252,210 FH 42 to Piv 30 X Line appears continuous j N of U-2 Spray Pond 98 255,210 Unit 3 Pump Hse X Line appears continuous to PlV 46 99 255,210,289 Unit 3 - Fire Pump X Line appears continuous Hse to FH 23 100 212 Setween U-2 & 3 X Poor signal hne suspect CW Twr, FH 39 to Current span test required (4) PlV 72 t-101 212 PlV 72 to FH 40 X Line appears continuous t PlV - Post Indicator Valves ( ) Number in parenthesis indicates span test location i FH - Fire Hydrant shown in Table 2. i I SHEET 6 0F 7 Rev.3/2543 M

\\ .~ ,t ENCLOSURE 2 ~ TABLE 1 JOB NUMBER: 10407-002 ARIZONA NUCLEAR POWER PROJECT DATE: JANUARY 27,1983 FIRE PROTECTION PIPE CONTINUITY TEST ENGRS: R. R. Avila INDUCED AUDIO SIGNAL METHOD R. C. Robinson . SIGNAL TEST SERVICE TEST CIRCUlf EASILY TRACED - e. NUMBER LINE NUMBER CONNECTION YES NO REMARKS 102' 212 FH 40 to FH 41 X Line appears continuous 103 -212 FH 41 to PlV 80 X Poor signalline suspect Current span test required (12) 104 209 Unit 3 - PlV 54 to X Line tppears continuous FH 43 105 210 Unit 3 - PlV 48 to X Line appears continuous PlV 83 t l I e i l i.. I t t. t PlV - Post Indicator Valves ( ) Nurnber in parenthesis indicates span test location FH - Fire Hydrant shown in Table 2. SHEET 7 0F 7 p ( Pe a# 'hOM b'_ J

F TABLE 2 ENCLOSURE 3 ~ ARIZONA NUCLEAR POWER PROJECT ' JOB NO.10407-002 FIRE PROTECTION PIPE CONTINUITY DATE 3-16-83 .c APPLIED SPAN CURRENT METilOD TEST ENGINEE RS: R. Avila R. Robinson SPAN SPAN ME ASURED VALUES CALCUL ATED VALUES TEST. SERVICE LENGTH SPAN CURRENT SPAN VOLT AGE PIPE POTENTIAL " PIPE RESISTANCE PIPE POT ENTI AL CONCLUSIONS & LO CAT 10N' LINE NO. (FEET) (D AMPS (E) MILLlVOLIS MV 10 CSE (_ R) MILL 10HMS/FT. MV SHIFT RECOMMENDATIONS (1)

• UNIT 1 S W. AREA 6" F P 2350 1.020 348 328 0.989 12 PIPE CONTINUITY OKAY FH.35 TO PlVeCa 233 & 236 2.020 694 316 12)

UNIT 2 NEr.R R6 12" FP Of180 0 992 642__ 456 3.390 10 P'PE RESISTANCE T00 HIGH PlV.27 TO PlV m28 210 1.971 1252 446 CO NTINUITY UNSATISFACTORY (2A) UNIT 2 NEAR R6 10" FP' 12 1.000 3.8 512 0.308 0 PIPE CONTINUITY OK AY PlV e27 TO EXCAV.T 308 2.000 7.5 SI F (28) UNIT 2 NE AR R6 6" FP 50 ' 2.000 17.0 5I8 1 000 9.0 517 0.160 1 PIPE CONTINUITY OKAY FH e14 TO EXCAV.T 313 (2C) UNIT 2 NEAR R6 12" FP

1. 150 1 000 751 426 5.070 74 PIPE RESISTANCE TOO HIGH PlV e28 TO EXCAV.T -

210 2.000 1512 alF REPAIR DEFECTIVE BONOS 13) UNIT 1 NEAR R3 12" FP 210 2350 1.024 191 353 0.591 38 PIPE CONTINUITY OKAY PlV e8 TO FH e7 6" FP 289 2.010 395 3i5 (4) . UNIT 2 TOWER C 12" FP d-250 1.050 20 461 0.064 2 PIPE CONTINUITY OKAY FH 39 TO PlV e72 212 2.050 36 45 F '(5) UNIT 3 S.W. ARE A 12" FP '57 1 01 2GI 326 3.460 19 PIPE RESISTANCE TOO HIGH PlV.82 TO PlV.83 210 & 209 2.01 458 301 CONTINUITY UNSATISFACTORY (SA) UNIT 3 S.W. AREA 12" FP 2 450 1.000 531 373 0.742 33 PIPE CONTINUITY OKAY PlV 82 TO PlV e81 209 2.000 865 340 (5B) UNIT 3 S W. AREA 12" FP 18 1.000 20 403 0.117 0 PIPE CONTINUITY 0KAY PlV eB2 TO EXCAV.T 209 2.000 4.1 403 (SC) UNIT 3 S.W. AR E A 12" FP - 39 1000 342 401 4.490 0 PIPE RESISTANCE TOO HIGH PlV eB3 TO EXCAV.T 209 2.000 167 401 REPA!H BROKEN TEE BOND (6) UNIT I S.E. AREA 12" FP 2 550 1 000 153 478 0.393 32 PIPE CONTINUITY O KAY Piv e40 TO PlV e19 209 2.000 369 510 (7) UNIT 2 N.E. AREA 12" FP 2 500 1.010 125 475 0.272 31 PlPE CONTINUITY OKAY PlV e40 TO FH #12 314 2.010 261 506 (8) UNIT 3 N.E. AREA 12" FP Of-500 1.000 1309 210 1.244 113 PIPE RESISTANCE TOO HIGH FH 20 TO PlV 58 314 2 000 1931 97 CONTINUITY UNSATISFACTORY (8A). UNIT 3 N E. AREA 12" FP 2425 1 000 130 790 0.292 5 PIPE CONTINUITY AND FH.20 TO EXCAV. T 314 2.000 254 795 FH.20 OK AY (88) UNIT 3 N E. AREA 12" FP 80 1.000 818 371 4.560 5 PIPE RESISTANCE TOO HIGH Piv e58 TO EXCAV.T 209-2.000 1180 376 C0idTINUITY UNS ATISFACTORY 'SEE SKETCH SK-10407-002-CP-104 0 FOR TEST LOCATIONS AND EXCAVATIONS. " PIPE RESISTANCE (R) OETERMINEO FROM CHANGES IN MEASURED SPAN VOLTAGE (AE) AND APPLIE0 SPAPTCURRENT(AI). 0 t c i-SHEET 10F 2 t

TABLE 2 ENCLOSURE 3 ARIZONA NUCLEAR POWER PROJECT JOB NO.10407-002 FIRE PROTECTION PIPE CONTINUITY DATE 3-16-83 APPLIED SPAN CURRETJT METilOD TEST ENGINEERS: R. Avila H. Robinson SPAN SPAN ME ASURED VALUES CALCUL ATED val.UES 3 TEST SERVICE LENGTH SPAN CURRENI SPAN VOLT AGE PIPE POTENTI AL "FIPE RESIST ANCE tlPE POTENTIAL CONCLUSIONS & LOCATION' LINE NO. (FEET) (D AMPS (E) MIL LIVOLTS MV TO CSE (R) MIL L10HMS/FT. MV SHIFT RECOWiiAENDATIONS (8C) ' UNIT 3 N E. AREA 12" FP 18 1 000 1.1 493 0.061 0 PIPE CONTINUITY OKAY EX C AV. C 10 E XCAV. D 209 2 000 22 493 (801 UNIT 3 N.E. AREA 12" FP 20 1 000 149 459 13.70 4 PlV e58 RESISTANCE TOO HIGH EXCAV. D TO PlV e58 209 2.000 423 4B F REPAIR DEFECTIVE BONDS 19) UNIT 2 E. AREA 8" FP - 600 1.000 167 492 0.340 4 PIPE CONTINUITY OKAY ^# PlV e62 TO FH 30 - 213 2.000 311 496 (10) UNIT 2 W. AREA 6" FP 178 1 000 75 597 0.0899 6 PlPE CONTINUITY OKAY PlV =34 TO R AD. BLDG. 286 2 000 41 591 (11) UNIT 2 N.W. ARE A 12" FP d 500 1 000 477 366 0 878 167 PlPE RESISTANCE TOO HIGH FH 36 TO PlV e106 212 2.000 916

19. I CONTINUITY UNSATISFACTORY (11 A) UNIT 2 N W. AREA 12" FP 425 1 000 138 413 0.296 9

PIPE CONTINUITY AND PlV.106 TO EXCAV.T 212 2.000 264 404 PlV 106 OKAY (118) UNIT 2 N W. AREA 6" FP 75 1 000 318 414 5.190 10 PIPE RESISTANCE TOO HIGH EXCAV.T TO FH 36 237 2.000 707 404 -'- REPAlR DEFECTIVE BONOS (12) UNIT 2 SW. AREA 6" FP d 425 1 000 97 508 0.122 8 PIPE CONTINUITY OKAY PlV e75 TO Piv s80 251 2.000 149 500 113) UNIT 1 N.E. AREA 6" FP 2 500 1 000 421 429 0.434 15 PIPE CONTINUITY O KAY PlV e4 TO PlV 23 312 2.000 638 4I4 (14) UNIT 2 SERVIGE 6" FP 150 1 000 67 452 0.413 18 PIPE CONTINUITY OKAY BLOG. TO FH e32 222 2.000 129 434 (15) UNIT 3 N.W. AREA 12" FP 2 180 1 000 279 372 1.556 94 PIPE RESISTANCE TOO HIGH PlV e44 TO PlV e45 210 2 000 559 278 CONTINUITY UNSATISFACTORY (15 A) UNIT 3 N W. ARE A 10" FP 20 1.000 18 405 0.750 3 PIPE CONTINUITY AND PlV e44 TO EXCAV. T 308 2.000 33 408 P!V e44 OKAY (ISB) UNIT 3 N.W. AREA 12" FP 1120 1 000 2G0 716 3.21 295 PIPE RESISTANCE TOO HIGH EXCAV.T TO EXCAV.T 210 2.000 645 421 REPAlR DEFECTIVE BONDS (16) UNIT 3 S.W. ARE A 6" FP 2 350 1 000 743 406 2.09 160 PIPING REPORTED INCOMPLETE PlV e53 TO PlV e49 285 2.000 1415 246 CONTINUITY UNKNOWN (16A) UNIT T S W. ARE A 6" FP E 330 1 000 741 400 2.22 170 COMPLETE PIPING AND FH 25 TO PlV e49 285 2.000 1975 230 CHECK CONTINUITY 'SEE SKETCH SK-10407-002-CP-104-0 FOR TEST LOCATIONS AND EXCAVATIONS. PIPE RESISTANCE (R) DETERMINED FROM CHANGES IN MEASURED SPAN VOLTAGE (A E) AND APPLIED SPAN CURRENT (AD. f = ~ SHEET 2 0F 2 i Rev.3/25/83 <

~ ' ' '" ENCLOSURE 4 JOB NO. IM07-002 DATE March 16,1983 FIGURE 1. Setting up current span test apparatus for continuity check on 12-inch fire protection line in Unit 2 at pipe excavatiori m I near PlV #28. k(k!Ndh 2 Wj, -g'. -- J 9 '..'5: "j N? '_. 'L ; )Y ' N. g~.$ $ 1 g M..' p.n;-. S l- {- ($ .s. s FIGURE 2. Defective copper bond strap in tee run at pipe excavation. Bond resistance a,7 O ** = - was too high for satisfactory electrical p $p. ^b co7tinuity. j f ~$ ~ a ~ l 1 '3-DEFECTIVE i BOND STR AP dup-

e ~ Q Bechtel Power Corporation Engineers - Constructors . i 7% i ~. L,~- e 12400 East Imperial Highway Norwalk. California 90650 g MAIL ADDRESS . 7 n -- .7t P o BOX 60660 7EAwNAL ANNEX LOS ANGELES CAU50AN'a 900E0 TELEPHONE (213:807 2000 B/ANPP-E-114045 pril 1984 Arizona Nuclear Power Project gg (Date) / -P.O. Box 21666 - Mail Station 3003 '/-AT-gy Phoenix, Arizona 85036 Review & Comment I"f0 Attention: Mr. Edwin E. Van Brunt, Jr. APS Vic.s President, ANPP Project Director Follow y Procoas

Subject:

Arizona Nuclear Power Project Bechtel Job 10407 ANPP Conference Notes No. CN-E-1535 D.20.01, D.28, File: E.16.04, E.16.05. M.11.01

Dear Mr. Van Brunt:

Enclosed are five (5) copies of ANPP Conference Notes for the meeting held in Phoenix, Arizona, at the APS Engineering Offices. Very truly yours, BECHTEL POWER CORPORATION )W w <> 5o . H. Wilson Project Manager [ Los Angeles Power Division RWG:eg Enclosure : ANPP Conference Notes No. CN-E-1535 (4 pages, 5 copies) cc: C. C. Andognini w/ enclosure J. D. Houchen w/ enclosure J. R. Bynum w/ enclosure D. B. Fasnacht w/ enclosure ~ '

0. J. Zeringue w/ enclosure Attendees w/ enclosure

.= e .,,,sg,, f,4q+e_ E % *s k L.

u i Arizona Nuclear Power Project' Bechtel Job 10407 Date: April 20, 1984 File: D.20.01, D.28, E.16.04 E.16.05, M.11.01 ANPP CONFERENCE NOTES NO. CN-E-1535 DATE OF MEETING: April 12, 1984 LOCATION: APS Engineering Offices ATTENDEES: APS Bechtel E. Van Brunt, Jr. W. G. Bingham W. Ide R. R. Stiens C. Rodgers R. W. Gillison D. Fasnacht O. Zeringue J. Barrow . J. Bouton

SUBJECT:

Corrosion Protection for Buried Piping and Structures PURPOSE: Review overall corrosion probleme experienced to date, correctivt actions taken, and program to complete corrosion proteccion for all buried piping and structures. Also review Bechtel's " draft report" in response to NRC questions regarding corrosion problems - onsite. A. Key Decisions APS stated the Bechtel program to protect buried piping systems and l structures shall demonstrate that satisfactory protection is currently. being provided, pending the completion' of installation and full energi-( . zation of the Cathodic Protection (CP) system. Completion ~of the CP l -- system installation is tentatively scheduled for June, 1985. To accomplish this objective, Bechtel will initiate a sampling program to inspect buried piping and ground cable installations in those aress most affected by corrosive soil conditions. LB. Discussion-1, t l l Bechtel handed over "Draf t" copien of a Summary Status Report, Corrosion Protection for Buried Piping. Systems,-Ground Cable and Structures, dated April, 1984, for APS review and. comment. An " overview" summary of this draft status report was presented by Bechtel as the discussion basis for the meeting. ' All action items as a result of this meeting are Bechtel l action items. .e [,) e ;

e. 0,

4P eM~ ,sN', e I. b-

ANPP Conference Notes No. CN-E-1535 Date: April 20, 1984 Page 2 Significant items discussed and action items are summarized below: 1. The drilling specification, for drilling of wells for anode beds for the balauce of the CP system, shall include any record data required to meet environmental and/or permit concerns. These concerns include requirements. in the event of overdrilling, for the 200-foot deep wells, and any precautions to be taken in Category I drilling areas. 2. In the summary report, the following shall be included: Emphasize that all safety-related buried piping has special a. coating and wrapping with verification by a field authorized inspector that the installation is satisfactory prior to

backfill, b.

Provide a histogra-showing the operation of the CP system after initial energization. The histogram shall show, for example, when the CP system was deenergized due to construc-tion and startup outages, when rectifier output levels were 1 reduced to allow for velding in various plant areas, and current energization status. Emphasize that fire protection piping is "important to safety" c. and that cathodic protection is being added to insure the overall integrity of this system for the plant life. d. Provide a sampling plan to establish that the condition of the stainless steel piping installed in the ground is accept-able. Also demonstrate that the anticipated corrosion rate for the stainless steel piping will not exceed corrosion allowance for this piping through the period of June, 1985, when the three unit CP system is expected to be fully energized. Provide a similar sampling plan for.the buried fire protec-e.- l-tion system hydrants and valves. This plan shall include Einspection and/or replacement,'or coating, of all nuts and bolts for hydrant and valve connecting flanges and bonnet' flanges as required. f. Emphasize that all buried bare metallic structures are included in the design criteria for the CP system. (There are [. miscellaneous metals in the dump' area and temporary buried piping in various areas.)

3. ~ Some discussion was held regarding possible correlation of type of backfill used and degree of soil corrosivity.

(Subsequent to .the meeting, Bechtel Construction has verified that all stock-- . piled material came from general excavations in the power block-Excavation material was not specifically segregated into area. different stockpiles, except for coarser material which was stock piled and located in a separate borrow pit area. Piping instal-p lation. records (CIP's) do not identify.the stockpile source for .O 9 g n sgl R&p. N'r*- hh '

r .o ~~ -t ANPP Conference Notes No. CN-E-1535 Date: April 20, 1984 Page 3 the backfill. Also stockpiled and borrow pit area soils were sometimes blended to meet Category I requirements. Data on the source of backfill, if available, would therefore not necessarily assist in identifying any special characteristics of the soil that might relate to pipe corrosion problems.) 4. The recent leak in the southeast corner of the power block was in a domestic water copper line. The leak apparently occurred due to a faulty solder joint connection in a 2-1/2 inch reducing flange.

5. - Bechtel will inspect the field lateral runs in the 4/0 bare copper ground conductor. The investigation will be made at the most corrosive site areas, as applicable.

6. Bechtel will make a general inspection of the "WRF" CP system, which has already been completed, energized, and turned over to APS, to verify the system is operating satisfactorily.

7. ~ Bechtel will give APS a cost comparision summary of alternative designs' investigated for the buried stainless steel piping.

These alternatives included substitution of a fiberglass rein-forced polyester (FRP) piping for the existing stainless steel, or excavation, cleaning, coating, wrapping, and backfill of the existing stainless steel piping. -8. Bechtel will verify the accessibility of all CP connections provided for testing and monitoring. Grade level tanks with concrete perimeter ring wall and sand base sre provided with monitoring stations. Grade level tanks with solid concrete foundations for the entire tank base do not have cathodic -protection and, therefore, do not require monitoring stations. (Electrodes may:have been installed by error beneath solid concrete foundations for tanks. The leads for these electrodes may have been permanently buried.) L .9. APS has reported-that some of.the anode beds and/or rectifiers 'are not operating properly in the Unit I area. Bechtel will send ,y CP personnel to the' site to assist in solving any problem areas. 10.-- APS requested that Bechtel obtain the service of a corrosion ,prctection' consultant to verify and add credibilityfto the Bechtel CP design. 11. Bechtel will report the results of the pipe surface inspection of o 'the Unit.1 refueling water tank 20" nozzle extensions. ~ (These extensions were subsequently enclosed in a concrete tunnel and protected from direct contact with 'the soil, per DCP CH-154.) = 12.. Bechtel will clarify the.NFPA' code requirements for coating of i L buried portions of fire hydrants, post indicator valves, and I block valves, 13. Bechtel will advise the reasons for the increase in CP systen design capacity (as reflected in DCP QR-006) over.the originni CP = system _ design, which was based on design quantities known or -anticipated in 1976. ..y. a ~ .~ ; x. &% Q:

~ = o. s. ANPP Conference Notes No. CN-E-15'35 Date: April 20, 1984 Page 4 ACTION ITEM

SUMMARY

All items herein are Bechtel action items. Items 7, 11, 12 and 13 . scheduled for completion by 5/15/84; Items 2, 5, 6, 8 and 9 complete by 6/1/84, and Item 10 complete by 9/1/84. Recorded by: R. W. Gillison Reviewed by: O b W. G. Bingham WGB:RWG:eg= f i m

• l

I I L (. I' i-e e_ a .s.~. 4

Bechtel Power Corporation Engineers - Constructors gpan--g --i 22 00 East imperia sionway Norwalk. California 90650 MA8L ACORESS '84 ALU -d A9 60 $$ *AY$$75 ^""'" *** "" B/ANPP-E-118454 MOC 329446 August 7, 1984 Responsible Antion By Eng. Arizona Nuclear Power Project (Datt) P. O. Box 21666 - Mail Station 3003 N I~ I 'N Phoenix, Arizona 85036 P.sview & Attention: Mr. Edwin E. Van Brunt, Jr. Comment Ido APS Vice President, ANPP Project Director

Subject:

Arizona Nuclear Power Project Bechtel Job 10407 Independent Consultant's Report on Cathodic Protection System _ File: E.16.05

Reference:

(A) Letter ANPP-30036-JTB/RJG, July 24, 1984 (B) Letter B/ANPP-E-117083, July 6, 1984 Dear Mr. Van Brunt? Enclosed are four (4) copies of Dr. Gordon Scott's report regarding his review of the overall design of the proposed cathodic protection system. This finalized report includes a soil resistivity probability curve with calculation data and a list of reference documents used in preparing the report. These two items were not included in the preliminary report forwarded to you earlier (Reference (B]). We understand your letter (Reference (A3) concurs with the recommendations and conclusions of Dr. Scott's report. This report is for your record file. Very truly yours, BECHT POWER CORPORATION f 5 t W. H. W lson Project Manager Los Angeles Power Division RWG:pm

Enclosure:

Dr. Gordon N. Scott's Report entitled "ANPP Cathodic Protection Design Review (4 copies) cc: J. D. Houchen w/ enclosure J. R. Bynum w/o enclosure -D. B. Fasnacht w/ enclosure O. J. Zeringue w/ enclosure Vg

Gorcion N. Scott Professson:'En;mcc Pos: Office Bas 21S Bne !y Hiiis,Ca'ifornia 90:13 L.S.A. August 2, 1984 Mr. Manuel Castro Supervising Engineer, Corrosion Control Group Post Office Box 60860 . Terminal Annex 'Los Angeles, CA 90060 File: CR 8491.(Job 10407-044) Authorization: Bechtel Power Corporation: Agreement for Consulting Services; 21 May 1984

Subject:

ANFP Cathodic Protection Design Review

Reference:

(a) List.of Bechtel documents in temporal sequence as provided for ANPP Cathodic Protection Design Review (attached) (B) An Assessment of the Present Criteria for Cathodic Protection of Buried Steel Pipelines; Paper No. 46, by Barlo and Berry, presented. at the NACE Convention. April 1984, New Orleans, LA.

Enclosure:

1. Soil Resistivity Probability Curve

== Introduction:== The sharp increase in cathodic protection from an original-47 power. units to an-additional 76 has focused on the adequacy _and/or ~>- conservatism of the Palo Verde design. To assist in resolving the dilemma, i the writer was retained to make an independent assessment by a review of the present design, documents and to offer such changes in design as may be appropriate under the circumstances. 2 To satisfy these objectives, all available information'on: '(a) the properties of the soil at the' Palo Verde site, '(b)-.the types of metals which are exposed to the soil, i . (c) their immediate' environments (protective coatings), (. d) their unique responses to the cathodic protection current, (e) their geometric relation _to grade and, (f) the inter-relation-of the numerous pipeline arrays, - were examined and studied. a -e+ g -G EMWADN

r' ~ n Soils: The resistivity of the soil was measured at the site by the Wenner Method at 48 locations with pin spacings to reach below grade depths.of 2 1/2 to 300 feet. While all of the resulting probability curves are in general agreement, one of the better curves, taken at the 7 1/2 foot pin spacing, is shown in Enclosure 1 as an example. The soils at the Palo Verde Plant site are extremely corrosive. This corrosiveness results from two major factors and a secondary aspect, attributable to the corrosion process itself. Firstly, the chloride content (a corrosive element and of the electrolyte content) is exceedingly high, being of the order of 3,000 parts per million. This high chloride ion content is given in the soil analyses in Items 5 and 19 of: Reference (a). Secondly, the interconnection at short intervals of the various pipe metals has undoubtedly set up galvanic cells with the carbon steel and stainless steel as anodic or corroding components. In addition, the high sodium content present migrates by diffusion in the soil, and under the influence of the galvanic potentials, to the car.hode, where the sodium ions gather and, unlike calcium and magnesium ions which are prone to precipitate and form a protective layer of slightly soluble salts at the cathode, remain in solution to increase the electrolytic conductivity and favor galvanic current flow to the detriment of the baser metal. Metals: A variety of metals has.been buried at the plant site to serve many necessary purposes. 1hese metals include carbon steels, stainless steel, ductile iron, cast iron, copper and copper-clad steel. The smaller carbon steel pipes are -shop coated with~ bituminous and other organic coatings to various degrees of' thickness. Buried carbon steel tanks are coated and grade level metallic-tank bottoms in contact with the soil are essentially bare. The huge cooling water lines are coated with portland cement mortar. The rebars, obviously, are embedded in concrete. The stainless steel demineralized water line was laid bare. The fire lines are mill coated ductile or cast iron. Some of the middle range and smaller pipes are copper. The basic electric ground loop in the corridor and surrounding the three power generating units are both copper and copper-clad steel conductors. i . Anticipating cathodic protection, this intricate maze of pipes and other metallic structural components are interconnected to the grounding system, at'close intervals, so that the whole comprises a single continuous metallic mat. .A 9' 'sbt si 'i

.o , c' 3 Geometrv: The geometry of the corroding structure has a profound effect upon the distribution of cathodic protection current flowing about the cathode. Consider the simple but unlikely case of a buried pipeline tangent at grade. It will have a maximum current density at six o' clock and zero current density at the top or twelve o' clock, the point of tangency. The distribution of current around any size of pipe buried at any_ depth of cover can be calculated from mathematical analysis. The resulting curve computed at all radii has been confirmed by field measurements. Further, such a curve has been obtained by plotting the leak frequency of a pipeline which has failed over a substantial period of time. However, the distribution of current density cannot be easily determined for an array of, say, seven or more pipelines ranging in diameter from three to thirty inches and at depth of from four to se'.en feet'below grade. What can be said is that for all pipes the current density will be greater by far below the springline then above. The purpose of the above analysis is to record the impossibility of a strictly engineered design for cathodic protection of a complex system such as that confronted at Palo Verde. The design will inevitably be dependent upon judgement and experience. Criteria of Protection: Interest here centers on a criterion whereby it may be said that cathodic protection has been achieved or is lacking as the case may be. The National Associatioa of Corrosion Engineers has formalized five measurements of potential and potential differences as acceptable criteria with which to gage the adequacy of cathodic protection. All of these criteria are empirical. While not so stated they were originally intended for use on a linear coated pipeline. No reference is specifi-cally made to metallic networks such as exist at Palo Verde where -carbon steel and stainless steel, ductile and cast iron,.and copper pipe and cable co-exist with environmental variants such as bitumen, cold mill-applied, dipped and wrapped coatings and concrete. These criteria have been studied for steel in the laboratory by Barlo and Berry: Their study does not define a fixed criterion but rather admits of variation and inconsistancy in them, with soil, water content and temperature as key parameters. The list of criteria for cathodic protection is far from complete. The selections by NACE may have originated from expediency rather than objectivity since all, with perhaps one exception, may be readily checked in the field at any point. This writer's selection of a potential which marks " incipient hydrogen evolution" is a novel criterion. Unlike the criteria above, which apply to iron or steel, " incipient , hydrogen. evolution" is independent of the metal under test. Other chemical options are also open to test. It is-concluded from the above that the criterion of "300 mv shift" ~ applied to Palo Verde is conservative and certainly acceptable.as a criterion of the sufficiency of cathodic protection at Palo Verde. m i

w..sn.L i e

N. . - - ~ -A

, s' 4 s Design Factors: To estimate the total current required for cathodic protection at Palo Verde Bechtel has used the following values for current-density for the several types of pipe installed: Current Density Metal (ma/sq. ft.) Carbon steel, wrapped 0.3 Ductile iron and cast iron uncoated 3 Stainless steel 50 Copper, buried pipes and cable 50 Concrete pipes and rebars 0.5 The values are generally acceptable for computing current requirements. The. high current demand for stainless steel probably would not persist once passivation is lost, as by the exclusion of oxygen, and the metal corrodes: it then behaves like carbon steel. Because concrete coated structures are very susceptible to cathodic protection current and can show wide changen in potential resulting from low current densities, it is urged that extreme caution be used in their protection. Conclusion and Recommendations: There has probably been some "over-protection" resulting from the additional anodes and rectifiers. However, certain advantages were gained. These include less attenuation of current per unit, a much more uniform potential throughout and a decidedly longer life. -Therefore, the recommendation is made that the protective system'be installed as proposed. It is suggested that in balancing the cathodic protection at Palo Verde that the protection of the concrete structures be.first fixed and that cathodic protection of the remaining combination of metallic materials be adjusted in accordance.with reduction of current on the concreted structures if necessary. It should be noted, too, that the occasional flushing of the anodes is highly desirable in that oxidation of the anode elements by chlorine gas is. minimized. Yoses truly,

4.,, "i s

' *I l jf , \\- Gordon N. Scott, Th.D i .GNS/jp e

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t .s ..RIZONA NUCLEAR' POWER PROJECT SOIL RESISTIVITY SURVEY 1/2 FT PIN SPACING i Rank. Probab. Ohm-m Key Notes Rank Probab. Ohm-m Key n x y n x y 1 2.13 3.30 26 55.27 12.90 2 4.26 3.53 27 57.40 13.50 3-6.37 3.60 28 59.53 13.73 991.78 4 8.52 4.95 29 61.66 13.95 5 10.65 5.25 31.93 RCL.1 30 63.79 16.50 989.65 6 12.78 5.85 31 65.92 16.50 7 '14.91 6.45 32 68.05 16.50

8 17.04 7.05 33 70.18 18.00 9

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23 48.99

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l g. t ANPP CATHODIC PROTECTION DESIGN REVIEk' LIST OF ITEMS PROVIDED TO DR G. N. SCOTT, CONSULTANT ITEM DATE NO. DESCRIPTION PROVIDED 1. List of Corrosion Control Group phone nos. and addresses 5-23-84 ~2. 12 Bechtel drawings covering ANPP cathodic prot. system, 5-23-84 ground grid and fire protection piping 3. List of 12 drawing titles and BPC Nos. and descriptions, 5-23-84 2 pages 4. DCP package for ISE QH006, 2SE QH006, 3CE QH006, 5-23-84 200 pages 5. ANPP soil chemical analysis, Smith Emery Co. report, 5-23-84 dated July 19, 1977 6. ANPP soil resistivity data for plant area, 14 pages, 5-23-84 dated Dec. 5,1975 7. Aerial photograph of ANPP site taken in July 1983 5-24-84 -8. Cathodic protection system operating comments, 5-24-84 historical account, 3 pages 9. Cathodic protection system - summary of protected 5-24-84 structures, 3 pages, dated May 9, 1984 10. ANPP,-ground grid electrical continuity. data, 5-25-84 enclosures 1 to 5, dated May 18, 1984 11. ANPP~ cathodic protection _ rectifier, de output summary, 5-24-84 -dated Nov. 1982:and Aug. 1983 12. ANPP soil resistivity data, switchyard and plant, dated 5-25-84 Nov. 1975 13. ANPP cathodic protection design review, Siegfried,' dated 5-25-84 May 11,.1984 14. ANPP general overview,-corrosion protection report, 5-25-84 dated April 1984, 20 pages ^t - 15,. .ANPP cathodic protection system,-design current loading, 5-25-84 IOM, dated April 16, 1984, 2 pages 16. ANPP cathodic protection system, summary of additional 5-25-84 protection, dated May:11, 1984 17. ANPP ground grid electrical continuity survey,- 5-25-84 Enclosures 1-to 5 data, dated May 18, 1984, 33 pages Sheet 1 of 2 h A3' 'NJ 't8 b

.s'. i-ANPP CATHODIC PROTECTION DESIGN REVIEW (CONTINUED) LIST OF ITEMS PROVIDED TO DR G. N. SCOTT, CONSULTANT . ITEM DATE NO. DESCRIPTION PROVIDED 18. ANPP history of cathodic protection system at PVNGS, 5-29-84 dated May 25, 1984 .19. ANPP soil chemical analysis for 5 samples 5-29-84 20. ANPP Unit I stainless stell pipe inspection report, 5-30-84 dated Oct. 19, 1983, 3 pages 21. Marked-up copy of station grounding plan Dwg 13-E-ZVG-001, 5-30-84 showing soil sample locations 22. ANPP pipe corrosion leak locations and pipe ages, 5-31-84 Table 1, May 31, 1954, 2 pages 23. Marked-up copy of Dwg 13-E-ZYG-039 showing soil sample 5-31-64 and pipe leaks ' 24. 77 drawings (see attached in index) area drawings and ~ 6-1-84 cathodic protection details 25. Pipe system designation list (2 pages) 6-1-84 26. Plant cooling water system; concrete pipes (5 sheets) 7-5-64 r.- t

/]

Sheet 2 of 2 g ,6'mi,4 h M km k-.

' e. m 9 Bechtel Power Corporation Engineers - Constructors 12400 East impenal Highway Norwalk. Cahfornia 90650 MAIL ADOAESS Lli' ~.',, j y 's ** I P o 80x 60860 TEAwNAL ANNEX LOS ANGELES CAL *oRN'A 10060 $5 ' ' ' TELEPMONC i213n J07-2000 r -- jj KnD '.'s B/ANPP-E-120712 MOC 337824 September 10, 1984 Arizona Nuclear Power Project P. O. Box 21666 - Mail Station 3003 Phoenix, Arizona 85036 Attention: Mr. Edwin E. Van Brunt, Jr. APS Vice President, ANPP Project Director

Subject:

Arizona Nuclear Power Project Bechtel Job 10407 Protection of Undergr g d Piping Systems File E.16.05,611.01,Q.16 m

Reference:

APS QA Documentation No. 84-CQA-103, August 17, 1984

Dear Mr. Van Brunt:

This letter responds to Action Items 1 and 2 from the NRC meeting of August 13, 1984, regarding the Bechtel report on " Protection of Underground Piping Systems, Tanks and Structures." Action Item 1: Define what the nonsafety-related systems are and what affect their failure would have an safety-related items. In the report, six nonsafety-related piping systems with undergrcund piping (huried and in tunnels) were identified as also having underground piping with safety-related components. The six systems are spray ponds (SP), condensate transter (CT), chemical and volume control (CH), nuclear cooling (NC), fuel pool cooling (PC) and auxiliary feedwater (AF). The underground portions of. the piping classified as nonsafety related in these systems is connected directly to nonsafety-related parts of the systems, or is isolated from the safety-related system piping by means of either combination stop and check valves, or by normally closed block valves. Enclosure (1) is a tabulation of underground portions of these piping systems which are classified as nonsafety related, and comments regarding safety implication. In all case:s, failure of the nonsafety-related piping would have no affect on safety-related systems. , One marked-up copy [ Enclosure (2)] of P&I diagrams of these systens from the FSAR is also attached to show interfaces of the underground nonsafety-related piping with the safety-related piping system, as applicable. f h

~ S Be.ltel Power Corporation f c Mr. Edwin E. Van Brunt, Jr. Page 2 B/ANPP-E-120712 MOC 337824 September 10, 1984 Action Item 2: Compare nnaber of linear feet of safety-related carbon steel buried piping that will be inspected, compared to the number of linear feet of carbon steel safety-relaced buried piping. Inspection of all safety-related carbon steel buried pipi y; prior to backfill is recorded on Bechtel "Ccastruction Inspection Planning for Placement of Backfill" forms (CIP's). The initial installation of a portion of the Unit 3 safety-related piping (24" piping in the spray pond system) has just been ccmpleted and it is not intended that this piping be reexcavated for a second inspection. The balance or che safety-relateo previcusly buried piping will be reinspected during the excavations to add test stations for the cathodic protection system. The excavations will be approximately 10 ft long for each test station location, and will uncever parallel lines whcce grouped together for the 10" diameter piping. The estimated footage to be reiaspected, and the related percent of total footage per unit is summarized below. Item Unit 1 Unit 2 Unit 3 1. Buried diesel fuel oil piping total length (2" and 2-1/2") 643 _: 643 ft 643 ft 2. Estimated footage and percent Item 1 to be reinspected. 60 ft/9% 60 ft/9% 60 ft/9% 3. Buried spray pond pipitg total length.(24") 1,116 ft 1,116 ft 1,116 ft 4. Estimated footare and percent Item 3 to be reinspected (24") 100ft/9%

• 100 ft/9%

( /0% 5. Buried spray pond piping total length (10") 2,77L ft 2,772 ft 2,772 ft 6. Estimated footage and percent Item 5 to be reinspected (10") 360 ft/13%

• • 360 ft/13% 360 ft/13%

Reinspection already completed per DCP CE-QH-005, Revision 1; piping in satisfactory condition.

• • 320 ft already completed per DCP CE-QH-005, Revision 1; piping la satisfactory condition.

Y 9 8 tel Power Corporation Mr. Edwin E. Van Brunt, Jr. .Page 3 -j - / ~ /ANPP-E-120712 B MOC 337824 September 10, 1984 Please advise if additional information or clarification of the above is required. Very truly yours, BECHTEL POWER CORPORATION o W. H. Wilson 4-Project Manager Western Power Division RWG:eg-

Enclosure:

(1) Nonsafety-Related Underground Piping (4 pages, 4 copies) (2) Marked-up P&I Diagrams: Figure 9.2-1 (1 page, 1 copy) Figure 9.3-13 (2 pages, 1 copy) Figure 9.1-9 (2 pages, 1 copy) Figure 9.2-4 (1 page, 1 copy) Figure 9.2-7 (1 page, 1 copy) cc: J. D. Houchen J. E..Kirby J., R. Bynum D. B..Fasnacht O. J. Zeringue All w/ enclosure (1) All w/o enclosure (2) 4 S e o e o>

'}. + T' i,PRh. ..CL,,-l BechtiesT F5wer Corporation y u Engineers - Constructors

b. FEB o. A9 :02 1240d East Imperial Highway Ncrwafk. Califomia 90650 MAL ADDRESS P o Box 60ee0. TESMNAL ANNEX. LoS ANGELES. CALIFOfwA 90080 TELEPHONE Qt3)e6440tt B/ANPP-E-111408 MOC 300181 February 3,1984 Responsible Action By Eng h

Arizona Nuclear Power Project (Dato) P. O. Box 21666 - Mail Station 3003 Phoenix, Arizona 85036 c7 8'/ Review & Attention: Mr. Edwin E. Van Brunt, Jr. 00""'At Info APS Vice President, ANPP Project Director

Subject:

Arizona Nuclear Power Project Bechtel Job 10407 Corrosion Protection for Buried Piping File: E.16.04. E.10.05. M.II.0F

Reference:

(A) Letter B/ANPP-E-110430, January 3, 1984 (B) Letter B/ANPP-E-109836, December 12, 1983 (C) Letter B/ANPP-E-107642. October 3, 1983 (D) Letter B/ANPP-E-107169, September 19, 1983 (E) Letter NRC to E. E. Van Brunt, Jr., September 1, 1983 (F) Letter AFPP-27607-WEI/ JAR, August 22, 1983 (G) Letter B/ANPP-E-101059, ~ April 13,1983

Dear Mr. Van Brunt:

In response to your letter (Reference (F)) and subsequent ANPP/Bechtel meetings (References (B) and (D)], we have summafized herein the current status of cathodic protection for underground piping systems and the correc-tive actions being taken to prevent recurrence of underground piping corrosion problems. A list of previous piping corrosion problema, and suggested re- .sponses to NRC concerns regarding corrosion of buried piping are also swcmarized per your rsquest. DCP ISE-QH-005, Revision 2, has been issued to Construction for installation of an additional 14 anode beds and six rectifiers in the water treatment area, the piping corridor north of Unit 1, and the main underground piping header - r6ns adjacent to Unit 1. evaluation of test data obtained from the recentThis increase in system capacity monitoring stations for stainless steel and ductile iron piping, and willinstallation provide the required level of cathodic protectisa where these pipes are installed. .s .\\, -.x ~ ,,. _ ~

u l-Bechtel Power Corporation t .p-r .~. Mr. Edwin E. Van Brunt, Jr. Page 2 B/ANPP-E-111408 M0c 300181. } February 3, 1984 1 DCP 2CE-QH-005, Revision 1, for Unit 2, (over 50% complete in construction) adds permanent test stations to monitor the cathodic protection potential levels for safety-related buried carbon steel piping in the essential spray ponds and diesel fuel oil supply systems. Data obtained from these permanent test stations will be used to verify that cathodic protection potential levels-are adjusted and maintained in accord with NACE standards. Similar test stations will be added for Units 1 and 3 essential spray ponds and diesel fuel Ei1 supply' (DCP 10E-QH-007 and 3CE-QH-007), with the determination of the .y number and location of test stations to be influenced by the cathodic protec-tion data received from Unit 2. The design for this latter DCP has been released by Engineering for walkdown review. All safety-related, below-grade stainless steel piping for three units has been installed in concrete tunnels and is accessible for inspection, except j for two short sections of 20-inch buried stainless steel piping connected to (- each of the refueling water storage tanks. DCP 10P-CH-154, 2SP-CH-154 and 3CP-CH-154 has been reinased to Construction to provide concrete enclosures around these two piping sections so that there will then be no underground stainless steel safety-related piping in direct contact with the soil, Final system upgrade to complete cathodic protection requirements for the t L ' balance of the nonsafety-related buried stainless steel piping and other buried safety and nonsafety piping in Units 1, 2 and 3 power block areas will .be completed and issue ( for field walkdown and APS approval in March, 1984, (DCP 10E-QH-006, 2SE-QH-006 and 3CE-QH-006). Enclosure (3) summarizes these additional requireisents. 'In Enclosure (1) a tabulation is given of the corrective actions taken to date to eliminate specific. buried piping corrosion problems which occurred prior to and after initial energization of the cathodic prote'etion sy~ tem. s Initial energization. occurred during the period of October 4 to November 23, L 1982, with subsequent scheduled and forced periods of downtime because of system equipment problems, changeover to permanent power supplies, require-ments-for static potential readings and effect of local welding on rectifier- ' operation. A tabulation of the specific piping corrosion problems which have been correcte.1 (Table 1) and a tabulation.of the external protective coating i system for buried piping ~and tanks (Table 2) are also enclosed as part of i-Enclosure (1) for your information. I Our action plan to complete the overall corrosion protection system includes the following: 1. Verification, using en audio-signalling method', that all metallic buried piping with flanged or mechanical joint conne:tions '(nonwelded- .and/or not threaded) is electrically continuous, as required for the p t l ( A f ,e g;

~ l, Bechtel Power Corporation Mr. Edwin E. Van Brunt, Jr. Page 3 B/ANPP-E-111408 ~ MOC 300131 February 3, 1984 ,,catbodic protection impressed current system. This test work will be

• * completed in May,1984, when underground yard piping for all three units is essentially complete. Monitoring stations, measuring potential response during system balancing operations, will provide the final check that system continuity and grounding is sacisfactory.,

1 2. Verification that flanged connections for the buried safety-related carbon steel piping (i.e., spray pond 24" and 10" piping) are satis-factorily coated and protected from corrosion. Inspection will be hade at~those. locations where cathodic protection monitoring test stations are to be sdded at excavated flanged connections.

3. _ Excavation, at selected locations, of nonoafety-related carbon steel, stainless steel, cast iron, and ductile iron piping, as well as safety-

" ' " ". "Yelated' carbon steel piping, to verify piping conditions prior to the [ energization of.the cathodic protection system, and to correct problem areas, as required, if not in accordance with project design criteria. The selected locations will be those where prior pipe leakage had occurred or soil corrosivity was significantly high, such as at the ~ fire pumphouse area, main pipe corridor locations in Units 1 and 2 [ and northeast corner of Unit 1 Turbine Generator' Building. In l-addition, sections of the Unit 2 diesel generator -fuel oil piping will i be_ inspected during the installation of monitoring stati<,ns. ~4. Verification that all t'emporary isolating flange joints used to insure isolation'for initial local sacrificial protection have been'jumpered l 'to provide continuity and grounding for the interconnected impressed l current cathodic protection system. r 5. Addition of procedtiv'e* covering (primer and wrapping) on all stain-less steel piping not yet buried in Unit 3 and on any buried f. stainless steel piping which has been or might be excavated for . inspection in the future.

6. - Addition of copper ' jumper ' straps across flanged connections for all piping yet to be buried'in Unit 3,~or on all flanged piping _ con-nections which have been or will be excavated for inspection in the future.

' Although corrosion and/or-pitting already has occurred.in some buried metallic - piping, we believe that completion'of the cathodic protection system' vill minimize'or prevent further corrosion damage. High concentrations of ! chlorides have been found in the soil and are a contributor to she stainless steel pipe corrosion problems. Also, we now have reason to believe that the-l ~ t'b N 4 h 4%

.= 7 Bechtel Power Corporation "Mr. Edwin E. Van Brunt, Jr.

Page 4 t

p B/ANPP-E-111408 Q<! HOC 300181 h'gC February 3, 1984 E local soils may contain bac6rialrganisms that could cause or induce ~ corrosion of bare metallic piping. This latter type corrosion has been referred to as microbiological-induced corrosion (MIC). Although the best method for control of MIC bas not been identified in the industry, it has been demonstrated that cathodic protection will prevent MIC. In essence, the cathodic protection system imposes a,dc voltage, opposite in polarity to that-of the corrosion reaction, thereby stifling corrosion reaction in progress and polarizing the metallic pipe surface. This action prevents the initiation of I' new corrosion sites. 'The cathodic protection phenomena, an' electrochemical one in nature, is a reaction restricted to the surface of the pipe and its immediate surroundings, where the latter is made more negative than the corrosion reaction. (Our letter [ Reference (C)] also demonstrates that any existing pitting as deep as 3/32" in any of the nonsafety-related buried stainless steel piping would not affect original design criteria. requirements and/orjause, pipe; failures,becauseexcesspipewallthicknessisprovided.) A detailed response to'NRC concerns reg'ar' ding onsite findings relative to ~ piping corrosion and related design questions is sumsarized in Enclosure (2). This draft document responds specifically to the NRC's letter [ Reference (E)] 3 and the attachment to your letter (Reference (F)]. Enclosure (2) covers correction of minor inconsistencies in the wording of some of our detail. specifications and drawing notes which the NRC has identified. We have also defined ' action taken to improve protection of the underground safety-related stainless steel piping in response to the NRC onsite findings, and we believe the completion of the permanent monitoring. stations'and cathodic procection system will provide satisfactory ansvers to their questions regarding other-buried piping systems. In addition, we have addressed NRC concerns regarding reportability relative to' safety-related and nonsafety-related buried piping-systems. l7 In summary, our design approach for protection of buried safety-related piping nystems in direct conta:t with the soil has been to provide two lines of l _ defense against corrosion. The first line of defense is coating and wrapping i of the piping, with holiday detection check and sign off by an authorized inspector. ' The second line of defense is the energized cathodic protection system which will insure that full protection -is being maintained. Also, all safety-related underground 'tainless steel piping vill be installed in tunnels s L 'or _ enclosures to eliminate any possibility of external corrosion as this E piping vill not be in ' direct contact with the soil. All other nonsafety-L1celated buried piping, except stainless steel and cast iron, is coated and/or F - wrapped.and cathodically protected. The nonsafety-related buried' stainless l: , steel and csst iron piping,' although uncoated, -hes extra pipe watil thickness 'in addition to cathodic protection. Also, all stainless steel piping which is - excavated for any reason is now required to be wrapped. 6 g n. L '~ a

Bechtel Power Corporation + l Mr. Edwin E. Van Brunt, Jr. Page 5 B/ANPP-E-111408 HOC 300181 February 3, 1984 The above summarizes the status of our ongoing program for protection of the huried piping systems and provides information for your response to the NRC arcs: of concern. A'detarled work-plan-for -completion of the cathodic protection system will be forwarded February 21, 1984. Very truly yours, BECHTEL POWER CORPORATION e.,....,, hhY ~ ~ rre er-- rc2r - W. H. Wilson r' '.. Project Manager a....~ ~ Los Angeles Power Division RWG:eg' L.=

--..... n.; a.u..

Enclosure:

(1) Summary of Pipe Corrosion Problems to Date and Corrective Actions Taken (5 pages, 4 copies) ~~' (2) NRC Concerns Regarding Corrosion of Buried Piping (5 pages, 4 copies) (3) Design Additions to Complete Cathodic Protection System (1 page, 4 copies) cc: G. C. Andognini w/ enclosures - J. D. Houchen w/ enclosures J. R. Bynum w/o enclosures , D. B. Fasnacht w/ enclosures

0. J. Zeringue w/ enclosures m

.M..e .m 9 -.L. L.. ..r i 1 4 O h ',g '- Y -y. y,y --iwg, e------ e- -r F-

ENCLOSURE 1 January, 1984

SUMMARY

OF PIPE CORROSION PROBLEMS TO DATE AND CORRECTIVE ACTIONS TAKEN I Pine Corrosion Problems to Date b 1. A chronology listing of documented correspondence regarding .. corrosion of. buried-piping is-attached as-Table 1. 2. Initial corrosion of buried piping systems has occurred primarily on the Fire Protection System post indicator valves (PIV's) and hydrants, including bonnet and flange connections. This equipment 4 had no special exterior coating and has been installed for the longest period of time prior to the energization of the Cathodic Protection System. Only the manufacturer's standard of one or two mils coating for protection during shipment was applied. In comparison, the major portion of the fire protection piping has 16 mils special shop coating, plus the same coating on the field connections-3. The problem of corrosion of stainless steel piping is exhibited as pitting corrosion due to the relatively high chlorides in the soil (1650-4512 uppm chlorides as determined in three of seven samples). The chlorides will attack the veld bead and the heat-affected weld zones as well as other stainless pipe surfaces exposed to the soil. = We believe microbiological-induced corrosion (MIC) may also be a contributor in promoting corrosion failures in the~ stainless steel buried piping.. i L .4. Discontinuities-in the Cathodic Protection System grounding to the I . plant ground grid were found in some fire protection lines due to broken electro-bond straps connecting the mechanical piping-joints. 1 - Because of these~ discontinuities, any current reaching the pipes L will return to the rectifier at the discontinuities, leaving corrosion damage behind at the points of discharge on the pipe surface. In addition, discontinuities, which occurred where fire protection piping connects to a PIV, reflect the fact that the PIV was not grounded. i 5. Prior to.energization of the cathodic protection system, exces-sively corroded nuts and bolts at some PIV and fire hydrant flange connections were caused by corrosive soil conditions in these areas and lack of coating. 6. Some corrosion of. carbon steel piping occurred due to undetected physical: damage to the externa 1' coating and wrapping either;during a initial installation or subsequent adjacent excavation work.. L j. 1 # %. + Y.. A

{ II -Corrective Actions Taken 1. Corroded bolts and nuts on bonnet and flange connections were replaced on PIV's and hydrants for the Fire Protection System. Any valves or hydrants that are excavated now or in the future will be ..__ cleaned and coated per r~evised Specification 13-CM-335. A summary of the types of coatings and/or protective coverings originally specified for all buried piping, as well as fire protection valves and buried tanks, is attached as Table 2. 2. Corroded pipe. sections of buried carbon steel and stainless steel were replaced with new pipe. 3. Electrical continuity of the fire protection piping has been checked. Electro-bond straps at "Tyton" joints have been repaired, as required; pipe is electrically continuous. 4. The Cathodic Protection System was partially energized October 8, 1982, to provide initial low 1cvel protection. Additional areas were energized during the next few months, and cathodic protection adjustments were made in November,1982, and January, February and March, 1983. 5. Test stations are now being added to monitor protection of the buried stainless steel piping and ductile iron piping, and to evaluate requirements to improve the cathodic protection capacity levels for'the stainless steel pipes. -(DCP-ISE-QH-005, -2CE-QH-005 and -3CE-QH-005, Rev. 0). 6. DCP ISE-QH-005, Revision 2, has been released to construction to install additional anode beds required to raise the cathodic _ protection capacity for the buried stainless steel piping in the water. treatment. area,.the piping corridor north.of Unit I and the main header runs in Unit 1. Additional releases will be made for the remainder of the main header runs in Units 2 and 3, and for the related branch header.i iping in the power block' area in Units 1, 2, p and 3. DCP 10E-QH-006, will cover this work for Unit 1, and DCP 2SE-and 3CF-QH-006 'for Units 2 and 3 respectively. Also all other anode beds to be installed for the balance 1of cathodic protection for three units will be included in this DCP.. 7. DCP 10P-CH-154 for Units 1, 2, and 3, has been released-to construc-tion to eliminate direct soil contact with any safety-related stainless steel piping. All safety-related stainless. steel piping will either be'above ground or.in concrete vaults or tunnels, and .' visible for inspection purposes. L. Action' has been taken on DCP. 2CE-QH-005, Revision 1, to install test 8. stations to monitor.the cathodic protection levels on Unit 2 safety-related. buried carbon steel piping. . Using this data.as a guide, addition'a1. anode bed capacity will be provided, as required. Similarly, test stations for permanent monitoring will also be added

for Units :1 and 3 'earbon steel saf ety-related piping.

DCP 10E-QH-007 and 3CE-QH-007 vill be prepared to cover these instal-lations.. t u

• W

} }-

January, 1984 ENCLOSURE 1 TABLE 1 DOCUMENTED CORRESPONDENCE REGARDING CORROSION OF BURIED Description Line Corrective of Corrosion Mat'l System Size Date Action Taken Ref. Drain to oily-CS Not 6" 1/80 Pipe stub cut Letter water separater defined off and replaced. ANPP-sump - Unit-2 Pipe coated and

15916, wrapped.

- 15-80 Exterior pipe CS SP 6" 11/80 Pipe replaced, NCR surfaces corrod-coated and PY-1846 ed due to improper e.~ wrapped per coating and wrap-ing (SP-053) Spec. Demineralized SS DW 6" 2/82 Pipe section re-Letter water supply line - Unit 2 placed.- ANPP-(DWNL-009) -r--

21164, u-6/10/82

' Fire protection CS FP 2/82 -Replaced valve Letter PIV-26 nuts and bolts on flanges (internal leak-ANPP-and bonnets age problem).

21164, 6/10/82

- Unit 1 lube oil CS ... u:. OS 3", 6/82 Pipe sections Do storage piping Welded 4" replaced. (OSNL-005, -008 and -011) . c.. - nrn. -Fire protection CS FP-10/82 Replaced nuts.. Letter P.1/-22 nuts on - c and bolts. ANPP - flanges corroded away

22239, 11/9/82 Exterior pipe CS (Mi 6/82 Recoated.

Letter surfaces (OWNL-174) rewrapped and ANPP-Holiday tested 21164 i 6/10/82 Exterior pipe-CS DS 6" 6/82

Recoated, surfaces (DSNL-046) rewrapped and Holiday tested PIV-30 CS FP 6"

3/82 Bolts replaced.- QAF-82-26 bolt corrosion- . f v.

• r#

A 4

January, 1984 ENCLOSURE 1 4 r TABLE 2 EXTERNAL COATING SYSTEMS AND/OR PROTECTIVE COVERINCS ON BURIED PIPES AND TANKS (All"S'y'sieis"to Y p~r~o Uc~tei by ' cathodic proeeetion) ~ Item / System Class Protective Covering Reference 1. Pire Hydrants-S Manufacturer's Standard - P.O. 10407-C-053 (1-2 mils asphaltic Spec. 13-CM-335. covering) -2. Post Indicator S Same as Item 1 above P.O. 10407-C-053 Valves Spec. 13-CM-335 ' 3.. Ductile Iron' Piping S 16 mils Koppers Bitu-P.O. 10407-C-057 "and Fittings (Fire plastic No. 33 or Spec. 13-CM-335 ' Protection)

• standard coating

4. -' Nuts and Bolts for S

AWWA Spec. 151-71 P.O. 10407-C-057 i' Ductile Iron P1ges (1 mil asphaltic at Valves coating std)

5. - Carbon Steel Piping Q,R,S Primer -> *TC Cold Prime Per Pipe Spec PM-205, or Polyken No. 927 or PM-204 w/ Holiday No. 929; Tape - CT Tape-detection coat or Polyken 930 6.

C. S.-Planged' Q,R,S Two - 30 mil wet coatings Per Pipe - Spec PH-205, Connections of TC mastic. .PM-204 w/ visual. inspection 7. Copper / Brass Piping S Any of the;following Per Pipe Spec ^ -a) Polyken 929 primer " Piping material w/35 alls Polyken tape -classification, b) TC Cold Prime /Tapecoat Sheet-P2-1" CT (35 mils) c) Protecto wrap 1170/ Protecto' tape No. 310 i, (35 mils) 8.: LS.tainless Steel R,S None Refer Construction Piping' -(Cathodic Protection drawings and CPS 1. System) 't notes

9. ; Buried Puel 011 Q

30 mils Koppers Bitu-P.O. No. 10407-MM-105-Tanks plastic No. 33 ~

10.- CastJIron' Piping-

.S None ( Refer Construction . Misc. Drain Systems). (Cathodic Protection Drawings and~ CPS ~ System) Notes L.

• Standard coating conforms to 'AWWA C151-71, See Item 4 -

e af (2 YO E Y S

F ENCLOSURE NO. 2 ~ RESPONSE.TO NRC CONCERNS RECARDING CORROSION OF BURIED PIPING (

References:

ANPP-2767-WEI/ JAR, August 22, 1983; Letter NRC to E. E. Van Brunt, Jr., September 1, 1983) t i f, I' Safety Related Pioine and Buried Tanks 1 1. All safety-related yard stainless steel piping will either'Ee routed above ground or in concrete vaultsaor tunnels, and protected from direct ccatset with the soil. The two 20-inch stainless steel piping nozzles at the refueling water tanks for each unit will be protected by an enclosure around the piping per Bechtel Design Change-Packages DCP-10P-CH-154, 2SP-CH-154, and 3CP-CH-154. -There F " ~- will be no safety-related underground stainless steel piping in -Je direct contact with the soil. 4 ~ ' ' ' "shown on Table 1 (attached).A line-by-line tabulation of safety-related ca 2. The protection plan for this piping 'is also summarized on Table 1. 3...The carbon steel essential spray pond piping is coated and wrapped iper-Specification 13-PM-204 and effectiveness of surface protection ~ is. checked by a holiday detector. The field "CIP" reports record the Authorized Inspector (AI) approval and sign-off. 4 The flanged connections, including flanges, bolts and nuts, for the carbon' steel ~ essential spray pond piping will be coated with 60 mils .of Tapecost "TC Mastic." Test stations to monitor level of cathodic protection are currently being installed on the Unit 2 piping, with -- test. leads being attached directly to the' lined pipe at selected flange locations. After evaluation of cathodic protection potential levels, additional anode beds will be added at each unft, as ~ required, to meet cathodic protection requirements per the project design criteria and NACE standards. The coating on eight' flanged connections, recently u'ncovered on Unit.2 to add monitoring stations, S~ were found:to be satisfactory. DCP 2SE-QH-005, Revision 1, and DCP 10E-QH-007, and DCP 3CE-QH-007, Revision 4, will add. these monitoring i stations. The buried diesel fuel oil tanks provided for each unit were

(

shop-coated with 30 ' ails of Koppers Bituplastic No. 33 prior to Jinstallation. Temporary sacrificial anodes l vere ' attached to the tank -exteriors and insulating flanges were provided st pipe connections.to (isolate the' tanks from ground grid prior to the-energization of the ' Cathodic" Protection System in-1982. The changeover lto the-impressed. ' current operating mode'is being made and these tanks will be receiving' cathodic system protection. J + E m - _g_. .:/ '3 ( I. [ W' L' b A

I' 6. The buried diesel fuel oil piping from the buried tanks to the diesel generator day tanks is coated and wrapped per Specification 13-PM-204 Monitoring stations are being added to check cathodic protection levels as part of the add-on work in Itew 4 sbove. Additional _ anode beds will be added, as required, to insure protection for this system. The piping vill be inspected when -excavated to install these :sonitoring stations. II Non-Safety Related Piping 1. Some corrosion and pitting has occurred in the buried stainless steel piping due to the relatively high chloride level in the soil. The chloride ion causes pitting corrosion at both the welded con-n,ections an.d.the pipe surfaces. We also have reason to believe there is indication of microbiological-induced corrosion (MIC) which also causes pitting. The degree of pitting corrosion will depend upon the length of time the pipe ha s been buried and grounded to the station ground grid prior to energizacion of the Cathodic Protection System, and -the establishment of an effective cathodic protection potential level. Although pitting has occurred to various degrees, a review of the wall thickness requirements for all buried stainless steel shows that pitted areas as deep as about 3/32 inch (a maximum of 0.118 inches) could be permitted without exceeding ANSI code requirements for the specified service conditions. Some of the buried stainless steel has an excess wall thickness of over 0.10 inches. It is planned that adequate cathodic protection levels will be maintained for.all_ buried stainless steel piping to neutra'ize the effect of the chloride attack and/or MIC. Anode beds and test stations will he added, as requir.ed,_to provide this protection, and'for monitoring purposes. S'ome-corrosion has occurred on Fire Protection System cast-iron fire .2. hydrants, post indicator valves (PIV's) and the flanged bonnet and end connections of this equipment prior to energization of the Cathodic Protection System. This equipment did not receive the ~ 16 mils special shop coating, which was provided for the majority of the fire protection piping and pipe joints. Specification 13-CM-335 has been revised to require coating of' these valves and flanged connections, when excavated for inspection or other reasons. - 3. Isolated cases of carbon steel buried pipe corrosion have also been reported. Although this piping is coated and wrapped, corrosion - had occurred due to. improper coating or accidental physical damage to the protective covering. A nonconformance report (NCR) will -be written when coatings / wrappings not per specification are found during inspection prior to burying. (An example is NCRTPY-1846).- It is latended that the Cathodic Protection' System provide additional insurance that any piping with coating imperfecitions not detected during initial installation be protected from corrosion. y e, 4 +4

- III Document and Specification Inconsistencies

1.. The wording of.the System Description for the Cathodic Protection System (QR) will be revis~ed to include buried stainless steel iR Ping, as well as. ductile iron, copper and cast iron piping. Also, the wording of the System Description will be revised to include the refueling water storage tank. This will be accomplished by March 1, 1984. "

" " '~' ~~ ~~ ~ ~

2. " A11 corrective actions required in Quality Assurance Finding (QAF)

SF 82-26 dated March 18, 1982,- are in progress or have been com-plated. Replacements of bolts and nuts on Fire Protection System ~ valve flange and bonnet connections were made without issuance of NCR's during initial system checkouts as all work had been installed per specificat' ions._, It was intended that a soon-to-be energized [, Cathodic Protection System would provide the necessary corrosion protection..Also this piping is not categorized as safety related. However, nonconformance reports will be prepared in the future to identify any new corrosion problems. ~ ~ QAF SF 82-26 will only be completed when the cathodic protection -system is satisfactorily maintaining desired potential levels for the fire protection systems for all three units. Unit 3 yard piping is scheduled for completion about April,1984. The current cathodic protection schedule and monitoring program is being revised to include additional anode bed and monitoring requirements. 3. Specification notes and inconsistencies have been corrected to agree with the construction drawings. Separate Cathodic Protection System. grounds are not provided for_ buried piping when the piping emerges above the soil at either end. All piping will utilize available equipment and/or structure grounds which are in turn connected to' the ground grid. Piping emerging above-the soil and not connected to grounded structures (such as yard shower head piping) will-be. grounded'in accordance with safety grounding requirements. y '4. Electrical Drawing 13-E-ZvG-007 has been clarified to state that all buried piping inside the property fence line is connected to'the plant ground grid. 5. Piping Specification Notes for 13-PM-205 (and I?-PM-204 for safety 'related piping) have been clarified to define the temporary use of insulating flange kits prior to the energization of the Cathodic ~ Protection System.: These insulating ~ flanges will be'jumpered now that.the Cathodic-Protect'>n System is energized. 7 '6.. Piping Specification 13-PM-205 (and 13-PM-204) Par. 7.1.4 wording will'be corrected to-include the coating of. external surfaces of nuts and bolt heads, as was provided during' the acetral installation. 9 _. m. x

• =

IV Reportability 1. The corrosion of the buried stainless steel piping is a generic problem. However, when this problem surfaced, the initial precheck of all buried safety-related and nonsafety-related piping in November,.1982, overlooked the fact that two 20-inch pipe nozzle-lengths at the refueling water' tank (total of about 10 ft. for two connections per unit) were buried, although it was generally known that the original design plan was to minimize buried piping for all safety-related yard piping where physically feasible. Each tank is mounted on a concrete foundation, and a pipe tunnel ic located immediately adjacent to the tank. The buried piping was between the~ tank and the tunnel. Reports of other stainless steel corrosion problems were not related to Q Class piping. Therefore, no .e-reportability was deemed necessary. 2. Possible-corrosion of safety-related carbon steel piping was not a concern as (a) no. leaks had been detected during system hydros, -(b) the piping is coated and wrapped and checked for voids with a holiday detector and (c) a CIP report is made for each pipe section . inspected and sign-off is by the AI. The energization of the Cathodic Protection System would also provide back-up insurance to prevent possible corrosion. +9m o e 4 p g e k k 4 T s

=

V l d_ 3 1 .r a. ENCLOSURE 2. i -TABLE 1 SdFETY-RELATED BURIED PIPING J i.

• System Protection l

Line No. Service Footage Mat'l Conn. Plan l ^ SP-B-080-HGCA-10" fj From Diesel. Gen Clg Wtr Ht Exch 629 C.S. Fig'd DCP 2-CE-QH-005, Rev. 1 for Unit 2 and DCP SP-A-080-HGCA-10"';ToDiese1~GenClgWtrHtExch 638 and Fig'd 10E-QH-007 and 3CE-QH-007 Wrapped for Units 1 and 3 adds SP-B-080-HGCA-10" 3 From Diesel Gen Clg Wtr Ht Exch 747 per F1g'd Monitoring Stations to 13-PM-204 vr.rify cathodic protection SP-A-080-HGCA-10".To Diesel Gen.C1g Wtr Ht Exch 758 App. 4X Fig'd level is satisfactory. !) 2772 Anode beds and rectifier g stations will be added, h 3 as required, to meet SP-A-080-HGCA-24" 'd From ECW Ht Exch 431 C.S. Fig'd project design criteria, Coated as part of DCP-10E-QH-006, SP-A-080-HCCA-24" ljTo ECW Bt Exch EWA-E01;; 262 and Fig'd -2 SE and CE-QH-006. .1. t Wrapped Inspect flanged connections SP-B-080-HGCd-24" s To ECW Rt Exch-EWB-E013, p i 209 per Fig'd already buried at new 0 13-FM-204 monitoring station loca-SP-B-080-HCCA-24" " From ECW Nt Exch EWB-E01 214_ App. 4X Fig'd tions, apply additional 1116 protective coating, if 1 required. Complete CP i energization and system DF-024-HBCB-2-2" Train B - F.O. to day Tank-207 C.S. Welded balancing. t Coated. DF-036-HBCB-2-1/2" Train B - Overd' low from Tank 209 and Welded

i

'd Wrapped .h. .DF-005-HBCB-2-2 Train A -.F.O. to day Tank 107 per Welded 13-PM-204 DF-006-HBCB-2-1/2" Train A - Overflow to Tank 105 App. 4X Welded DF-037-HBCB-2-2" Crosstie between Tr. A & B 15 Welded .e - 643 i 0 Per unit quantities. WI 4 ( m

3 , e ' a. ENCLOSURE 3 DESIGN ADDITIONS TO COMPLETE CATHODIC PROTECTION SYSTEM (DCP 10E-QH-006..-2SE-QH-006, -3CE-QH-006) NO. OF , ITEM / SYSTEM. RECTIFIER ANODE BEDS STATIONS NO. DEPTH-(FT) A. U/C Buried Piping Systems 1. Stainless Steel Piping

• 18 19 9 100 (various nonsafety-related systems) 38 6 50 11 8 25 2.

Carbon Steel Piping a) Safety-related piping - for 18 1 e 200 essential cooling water heat 3 9 130 exchangers, diesel generator 2 8 100 heat exchangers and fuel oil 12 6 50 supply to diesel generator 18 8 35 day tanks 34 9 20 b) Various nonsafety-related 9 6 6 50 systems adjacent to spray 9 8 35 ponds 17 9 20 3. Fire Protection System 8 5 0 200 2 0 130 1 8 100 s 4.~ Total for u/g Piping - 3 Units ~~53 178 anode beds B. System cround Grid

• • 11 10 8 200 1

9 130 .n

• Excludes 6 rectifier stations and 14 anode beds to be installed in DCP-ISE-QH-005, Revision 2.
  • Recommended for protection of new ground grid installation (DCP ASE-QG-005,

. Revision 0) per APS Letter ANPP-27804-JTB/SLK, September 15, 1983. 1 7 e L

t. o-Bechtel Power Corporation i Engineers - Constructors NPRPi-OUC-i r 124m east imperiai sionway 'To Assisne Norwalk, California 90650 d!Ud MAIL ADDRESS w 84 m & P1 : 1 eo soxeaseo resumt Amex wSmcctes Bospue 2 ACG n u.., m.o "ooo ugr./ _CCA B/ANPP-E-ll5422 Supy MOC 317601 F SCJ May 24, 1984 0 ~DJK Arizona Nuclear Power Project d -D2f P. O. Box 21666 - Mail Station 3003 ~Ac.i vey_ Phoenix,' Arizona 85036

.J N

3e w Attention: Mr. Edwin E. Van Brunt, Jr. APS Vice President, ANPP Project Director

f. 3 l,JLL.[~~

'ri r-. rtw w 5 d (%-,, !f N lM$,_,.]

Subject:

Arizona Nuclear Power Project Bechtel Job 10407

n. E i*' UTC.Jr. v/ene.

-d Transmittal of Investigation Requests EE M I_.~f [.5 ~~ File: D.5.01 "A F-U Filo 9,5.0/

Dear Mr. Van Brunt:

enc. .One copy of the Investigation Requests listed below is transmitted for your review. IR Nos. Revision j -AO-IR-024 0 Please return one copy of this letter with the status noted, along with any comments. We would appreciate a reply from you within three weeks from the above date. Very truly yours. BECHTEL POWER CORPORATION W. H. Wilson Project Manager-Los Angeles Power Division By: /fd. ( i Return Status: Date: Approved for Implementation ANPP Approved Subject to Comments Attached Signature for APS E. E. Van Brunt, Jr., APS Vice President Rejected,'Do Not Issue Nuclear Projects, ANPP Project Director EEVBJr/

~ ; -{' f. ( ( ' *p Bechtel Power Corporation . ~ Engineers - Constructors ( NPRl'i-00C-i / $24m eas: imperiai sionway

• To Assign,

Norwalk. Cahfornia 90650 6(/ O, MAIL ADDRESS g w IE N 4 l 7 0 8 ~B/ANPP-E-115422 S"E# "CA MOC 317601 F ~5Of tay 24, 1984 0, 'BJK Arizona Nuclear Power Project D U21 P. 0. Box 21666 - Mail Station 3003 ~ Phoenix, Arizona 85036 ~t..I h.n , i..J i~ c L -~ - Attention: Mr. Edwin E. Van Brunt, Jr. Qn i EI,L ~~ APS Vice President, ANPP Pro.'ect Director I 3 ' T:n n j (. _--.!C35.Q.._ t .1. f,

Subject:

Arizona Nuclear Power Project Bechtel Job 10407 g j JJC.Jr. v'en.o_g_ Transmittal of Investigation Requests n- ._f > ? - - File: D.S.01

• " ' F-U File F. 5. C /

Dear Mr. Van Brunt:

enc. One copy of the Investigation Requests listed below is transmitted for your review. IR Nos. Revision A0_IR-024 0 Please return one copy of this letter with the status noted, along with any comments. ( We would appreciate a reply from you within three weeks from the above date. Very truly yours, BECHTEL POWER CORPORATION W. H. Wilson Project Manager Los Angeles Power Division By: //J. ( i Return Status: Date: June ll, 1984 Approvcd for-Implent-atte:t ANPP 29717-ACR/JTB R Approved Subject to Comments I-YOc n D.Qk .e Attached Signature fo'r APS " I. ~ E. E. Van Drunt, Jr., APS Vice President Rejected, Do~Not Issue Nuclear Projects, ANPP Project Director EEVBJr/JTB/sp ,b E#It," M Li -w

t.;. W,,* ;.

S Attachment to ANPP-29717 - ACR/ JIB June'11, 1984 These are our comments on A0-IR-024:

1. For corrosion that is found on S.S. pipe, acceptance criteria and the procedure to be used, is not identified. Once the " pit" depth is measured, do you subtract this from a wall thickness on - attachment III and, if so, which one? L2. No acceptance criteria are listed for flange fasteners. Has. any prior commitments been made to replace the fasteners when pipe is excavated? 3. What is the acceptance criteria on value bodies. '4. The following people are named as APS inspectors for. pipe, valves, and grounding radials. extension 6557 (PVNGS) Dan Sachs extension 828-6057 (D.V. Engineering) Bob Grinstead extension 6599 (PVNGS) Jim Bouton General: The acceptance criteria,. reflected by comments 1) through 3), must be. included in the IR prior to work initiation. .cc: - D. B.-Karner A. C. Rogers - D. Sachs (6077) F. Reynolds (6230) D. lB. Fasnacht J. R. Bynum.

j. +

m h e B i vi e i g 3 i L? j

~ t-1 Polo Varde Nuclear Canarcting Station 1A.IR No. Unit A or 1 2A. Completion Req'd. Units 1, 2, & 3 Ao -IR - 024 C) 84 INVESTICATION REQUEST IB.IR No. Unit 2 2B. Completion Req'd. L { 3.Page

4. Q Class

5. System Desig. IC.IR No. Unit 3 2C. Completion Reo'd.

I of 2. .S SEE ATTCH. II'

6. Identification: CM 053 Supplier's Name: CRAME SUPPLY CcMPAMN (FOR HYDRAMTS ( 9'IV'S Address: P.O. Boy, 3793 PlloE MtY A1. BS6"Ao

~ Supplier

Contact:

MIL Ttp Nona Phone No.f fco?) 7.5B-bE3\\ 7.Backchargeable: O Yes E No D*

9. Service Bulletin or other reference document attached:

I, St.ncE *lO' ATTACH MENT I FtRE, pro 11K.Tl0N S'(STEM GemERAL ARRAN(.E MEMT W (m. 13 -C-7V A-O1 \\

m. Sua AncuMuur "I" (copensue.a uo rES No. CM-E-19d

10. Equipment No.

Description Affected Documents $;)"'N San Amt.MM ENT'W l

11. Purpose of investigation and corrective action requiremen:s:

l

1) EvcwATE i, \\MSPECT BURIED STAtwt.ESS STEEL 9t PIM(= FoR coRRostou AMD VibtATlou 0F MtMIMuM WALL TatCEMESS WEE ATrkc I

\\F Wo Vlot.ATIOM OF MtNIMOM WM.L. 'TRICXMEf6 WRAP PER SPEC.. 13-PM Zog ( ATTAc H. ISQ, PR \\cR To BAcKDETEC.TE D, c.s l SPEC. 13-c.M-Sco (, ATTACH.Y). PREPARE pit,,ugg pgg A REPORT of FINutM45, Fi%ES Aub DEVI ATIOM FRoM DE%ic=N CRITER I A. D INSPECT REPhlR OR REPLAC.E FIRE 3 MYDRAkR5, BLbCW VAINES AMD Pc6T j INDic.AToRs (PIV' ) FoR coREostok.1 RATE Auca ( s McEFnStuTY (rom Lot.AT10w sna ATmcn MEMT 'EI.'.). lP NOT PREVtoubbY COATED ct. NAM Aub (.o PER SP EC.. \\"5-C.M-335, SEC. 8.6, SC.kl. 34)*) ( niTTC.H. %, 3 A' Ao mwasxm o p.ma rs.Tsc.riew eWonw n, vmw u wp 517.-84 a swum szust m pem n N.AFAMAMtg Rev. Date l Descriotion Orieinator PE

12. Actionees completion of investigation:

a. List NCR's which implement corrective action:

b. Station documentation updated as req'd. - List af fected document (s) which hav been updated:

e l

c. Spare parts lists and inventory control updated as req'd:

d. Remarks:

O Yes O No i Authorized Signature Date O

,I & CCN'TINUATICAJ Palo Verde Nuclear Generating Station 1A.IR No. Unit A or 1 2A. Completion Req'd. g.7g.og q.g_ g Units 1, 2, & 3 18.IR No. Unit 2 2B. Completion Reg'd. INVESTIGATION REQUEST ge3.Ig.og, eg. i.6 l, 3.Page

4. Q Class

5. System Desig 1C.IR No. Unit 3 2C. Completion Reg'd.

p, of < co ses mattu. E 3C -TR-o?4 CH -.:. ...ITE. M 2) ccNT. A REPORT....._... _...,..;..; ;.. c -- -. 2 PREPAEE oP FIMDIN(=5 AM D P nvES.

3) IMSPECT, REPAtR AND ot REPLME, CoATtM4 oF ~Au. MuTs AhD' 'sht.h

~ foe HYDRAMT VALyE couuscTIN4 maw 4E5 Auo BouMET PLAhx=ES AS REQutRED. REPl. ACE PLAM4E TASTEMERS If MECEs51 HEM.

4) PER ATrACHMEMT% E%cAVATE. TR.ENCHE5 (3 FEET VJibE % f. FEET Low 4 x 5 FIEET DEEP APPE8YD, M*

SENEM PUM.ES AS SHOM M PER ATTpc%MEtd THIS WORE, is To BE PERFoRME.D To Es. POSE-TMP-a,touwo casts. FoK PnY.itC.AL. INSPEC. Tion AH b TD V E.RIFY WHETHER T H E.Gdt40MO cASLE 15 ccRRoDEO o n w o r. Rsconnsuos o PsoCuouRES Fon SELECTION OF TRENCH Loc.ATioM AMD e.xcAuATsoM is As F ou.cr*JS'. a.) SELECT LOCATION foe TEEMC.H EycA n T) OHS op STA* Runs op

• 4/o BARE cePPER CABLES op 4RouNDIN G.MhT AT Af9 RAM MNTP.,

Locations \\WDiCATED 'ATTKH MENT ' M". Att OM LotATibMS MUST BE Acc ESS\\BL E FOR MEM AND EaOPMENT. b) CEMTER LINES o s- 'TRENC.HES SH E BE Locate.D DIRecTLY OM CEuTER LlWE5 OF CABLE /a TD SE )MSPEr.TE.D. c) EEH TRENc.H SHALL Bs PEEP ENoutsR To Altow A i MtusMoM op (o nNC.Has

c. LEAR "oFAc.E BETwuEM CDMoutToR AuD BOTTOM O F T H E.

TR E NC.H. I d) ' st 2.s. o F TRENCH SMALL BE SOFFIC. tam Tb PRcVIDE EAS (CESS FOR

• T W O M E.N INSPECT lWCs ccM DUC TOR ~

i e) TREMcM MAY BE. EtcAVATED BY MECl4AMICAL MEANS AFFRoriMRTELY (. INCHE5 ABohE. BURt E D CON DOC.TDR.. MM38: 1* To I FURTMR. E%CAVATtcN MUST - BE. CONT 1MOE D BY j CohlDUC. tor, WlTH CaREAT CARE. TO Tb EXPoSFi PREVENT AuY cou Tk4.7 I l W fm OR - DAM BLS E. TO THE. CoMDOCfDR.5, f) Awy PHYS tc.AL. REW OR5. To SE ~ . BY PutTttipANTS. OsTERMINED AT 'T*lHE OF tuSPECTtou NOTE '. APS Aub BPC. EM(etMEERt HC3 To BE PRESEhlT WHEM i Ac.Tiou 15 bel 44 W.8 0-a .6.

1 ATTAC H/4ciu T _T Arizona Nuclear Power Project-Bechtel Job 10407 Date: April 20, 1984 File: D.20.01, D.28, E.16.04 ~" E.16.05, M.11.01 ANPP CONFERENCE NOTES NO. CN-E-1535 DATI 0F MEETING: April 12, 1984 LOCATION: APS Engineering Offices ATTENDEES: APS Bechtel E. Van Brunt, Jr. W. G. Bingham W. Ide R. R. Sciens C. Rodgers R. W. Gillison D. Fasnacht O. Zeringue J. Estrow J. Bouton SUBJECT. Corrosion Protection for Buried Piping and Structures PURPOSE: Review overall corrosion problems experienced to date, corrective actions taken, and program to complete corrosion protection for all buried piping and structures. Also review Bechtel's " draft ' report" in response to NRC questions regarding corrosion problems onsite. A. Kev Decisions APS stated the Bechtel program to protect buried piping systems and structures shall demonstrate that satisfactory protection is currently being provided, pending the completion of installation and full energi-sation of 6he Cathodic Protection (CP) system. Completion of the CP systes installation is tentatively scheduled for June, 1985. To . accomplish this objective, Bechtel vill initiate a sampling program to inspect buried piping and ground cable installations in those areas most affected by corrosive soil conditions. 'B. Discussion Bechtel handed over "Draf t" copies of a Suemary Status Report, Corrosion Protection for Buried Piping Systems, Ground Cable and Structures, dated April,1984, for APS review and comment. An " overview" summary of this draft status report was presented by Bechtet as the discussion basis for the meeting. All action items as a result of this meeting are Bechtel action items. P S L

c.*- j.,., ANPP Confer *nce Notes No. CN-E-15 5 Date: April 20, 1984 Page 2 gignificant items discussed and action items are summarized below: 1. The drilling specification, for drilling of wells for anode beds for the balance of the CP system, shall include any record data required.to meet environmental and/or permit concerns. These concerns include requirements, in the event of overdrilling, for the 200-foot deep wells, and any precautions to be taken in category 1 drilling areas. 2. In the susunary report, the following shall be included: Emphasize that all safety-related buried piping has special a. coating and wrapping with verification by a field authorized inspector that the installation is satisfactory prior to backfill. b. Provide a histogram showing the operation of the CP system after initial energiration. The histogram shall show, for example, when the CP system was deenergized due to construc-tion and startup outages, when rectifier output levels were reduced to allow for welding in various plant areas, and current energization status. c.~ Emphasize that fire protection piping is "important to safety" land that cathodic protection is being added to insure the overall integrity of this system'for the plant life. -- d. Provide a sampling plan to establish that the condition of .the stainless steel piping installed in the grcund is accept-able. Also demonstrate that the anticipated corrosion rate for the stainless steel piping'will not exceed corrosion allowance for this piping through the period of June, 1985, when the three. unit CP system is expected to be; fully ' energized. Provide's similar sampling plan for the buried fire protec-e. tion system' hydrants and valves. This plan shall include inspection and/or replacement, or coating, of all nuts and bolts for* hydrant and valve connecting flanges'and bonnet flanges as required. .f. Emphasize that all buried bare metallic structures are included in the design criteria for the CP system. (There are miscellaneous metals in the dump area and temporary buried LJ piping in various areas.) - 3. Some discussion was held-regarding possible correlation of type of backfill used and degree of soil corrosivity. (subsequent to the meeting, Bechtel Construction has verified 'that all stock-i piled material came from general excavations in the power block i i Excavation material was not specifically segregated into area. different stockpiles, except for coarser material which was stock piled and located in a separate borrow pit area. Piping instal-1ation records (CIP's) do not identify the stockpile source for e

• 9 en u

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ANPP Conference Netes No. CN-E-1535. - 1 l Date: April 20, 1984 Page 3 the backfill. Also stockpiled and borrow pit area soils were sometimes blended to meet Category I requirements. Data on the source of backfill, if available, would therefore not necessarily assist in identifying any special characteristics of the soil that might relate to pipe corrosion problems.) 4 De recent leak in the southeast corner of the power block was in a domestic water copper line. ne leak apparently occurred due to a faulty solder joint connection in a 2-1/2 inch reducing flange. g

5. - Bechtel will inspect the field lateral runs in the 4/0 bare copper ground conductor. D e investigation will be made at the most. corrosive site areas, as applicable.

6. Bechtel will make a general inspection of the "WRF" CP system, which.has already been completed, energized, and turned over to APS, to verify the system is operating satisfactorily. 7. Bechtel will'give APS a cost comparision summary of alternative designs investigated for the buried stainless steel piping. nese alternatives included substitution of a fiberglass rein-forced polyester (FRP) piping for the existing stainless steel, or excavation, cleaning, coating, wrapping, and backfill of the existing stainless steel piping. 8. Bechtel vill verify the accessibility of all CP connections provided for testing and monitoring. Grade level tanks with concrete perimeter ring wall and sand base are provided with monitoring stations. Grade level tanks with solid concrete foundations for the entire tank base do not have cathodic . protection.and, therefore, do not require monitoring stations. (Electrodes may have been installed by error beneath solid concrete foundations for tanks. ne. leads for these electrodes may have been permanently buried.) 9. APS has reported that some of the anode beds and/or rectifiers are'.not operating properly in the Unit I area. Bechtel vill send CP personnel.to the site to assist in solving any problem areas.

10. APS requested that Bechtel obtain the service of a corrosion protection consultant to verify and add credibility. to the Bechtel CP design.

11. Bechtel will report the results of. the pipe surface inspection of the Unit I refueling water 'ank-20" nozzle extensioos.

(nese t extensions were subsequently ecciosed'in a cooerete tunnel and protected from direct contact with the soil, per DCP CH-154.) .12.' Bechtel wi11' clarify the NFPA cod.: requirements for coating of buried portions.of fire hydrants, post indicator valves, and .y-sblock valves. ~ .s. 13.. Bechtel will advise the reasons for the increase in CP systes design capacity (as reflected in DCP QH-006) over the original CP system design, which was based on design quantities known or anticipated in 1976.

1. e e-

.e' Q e, f K-M, ~h L-.

F l 'ANPP Conference Notes No CN-E-1535 Date: April 20, 1984 Page 4 ACTION ITIM

SUMMARY

All items herein are Bechtel. action items. Items 7,11,12 and 13 6/1/84, and Item 10 complete by 9/1/84 scheduled for completion by 5 / Recorded by: R. W. Gillison Reviewed by: -O A5 W. G. Bingha= WCE:RWG:eg + 4 , /*

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PW e-ter-i . Description i Affected Documents UNIT 1 $ h Y Y,' CM-ou - 4"ss cipE tw-oco 01-c- ZvC-305 ( B-2) (,'ss. pios c i - c-zvC -L38 (E-51 Dw -009 6" SS. PI PE f D+ 00*> // ss. 9t 95 01 - C-TVC-Add (D~Y o t - C-2.vc-44 8 (c,-to) SC-2.30 fo" S.S. PI PE 01-C-zvc-Sc6 (5 -5) i, j UN IT 2 CD-114 8 " 5 5.. PI P E- } CC-1 bC 8" s L oic= 02-C-IVC-320 ( A-2) l o *2.-C ~LvC-32 3 f E -5) CM-0% 4." 6.5. Pl PE 01-C-ZVC *M.C (A. D i Dw-oce 6" 5% cso= O 2 -C-1.\\/ c-50 % I c-O SC 'i.2.o L' E.S.9tPE. o'2.-C-Z VC-320 ( A-2i RC 250 // 6 c. Ct c c_. 02-c-IVC-32.1 ( E-d J j. UNTT', CD IL,5 S'5.S.949E o t-C-2.VC-325 (S-B i _ CD-t kE 9" 5 5. Pipe i CM-o% M-C-ivc-11S '_E-5) /." S S. Pi F E .i c 5 C-7VC.: SEF 3C3 DW- 009 I (/ SS. PtPE 03-C-2.VC-SES ff-5 b/- orn r/g s pi c=_ _GC-210 n 3. c-1 f c. sg3 r c s) 6" 6A Pipe o s C-INc-ME ' 5 T. SC-2'20 /i' s.S. PIPE og-C-tvC-33 6 ( 9 5) 1 {. _ HYDR ANT No. E o i - C-Ivc- / t-6~(e. 3 i 5 { 8 0 t c-2.vC-4 SE I D-s ) o i-C-I.vt.- 3 \\ \\ ( A-2) 10 ot-C-7_VC-t-M I D-5) 13 O2 C-2.VC 'IOo ( E-O 1 2I 03 C.-2.vc-550 ( E M 03-C 2.VC -5 53 ( 62) oe o 1 - C-2.vc-4t I (E 5) 36 02-C-IVC-506 ( G-(A i PT V vat.ve No. 4 to o n-r zv< - a ss ( o 2.3 e f f{ $ k $ $ $ S E% AO O ~8* I ,, _ - _.. - - - - - - - - - ~ ' - ~ ~ ~ ' ' ' ~ ~ ~ ~ ~ " ~

i

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10. Equipment No.

Description Affected Documents Rev. geq o 4 (Yes) (No) 43 o3-C-2MC-sso (F-2) 55 03-C-2NC-5st (s-a n 6 Nor A pw 01-C-ZNC A A A (e.g a J l d-i l i l i 1 \\ i ) I i i e 'S e + n e' <, % .-53.. l ,.n ..n,, .-:,..,---,..,..---.,,.~.,,,,-.--,-.,-,,--,,-----n._

A 77~/;G.4Ma n' : APPENDIX 2 WALL THICKNESS OF BURIED STAINLESS STEEL PIPING Req'd , Actual Line Nominal Nominal

• Extra Pipe' Size Pipe Wall Thick-Wall Thick-Wall Thick-Spec (inches)

Schedule ness (Inches) ness (Inches) ness (Inches) HCBA 20 20 0.132 0.375-0.243 HCDA 1 40 0.015 0.133 0.118** 2 40 0.027 0.154 0.127 2-1/2 40 0.032 0.203 0.171 3 40 0.039 0.216 0.177 4 40 0.050 0.237 0.187 6 40 0.074 0.280 0.206 8 20 0.096 0.250 0.154 HCDB 10 20 0.085 0.250 0.165 Can be considered as corrosion tolerance before cathodic protection system energization. Sms11est tolerance;. equivalent to approximately 3/32" greater than required nominal wall thickness. k S 15 OO% b

,477CNME//f ~ u 13-PM-205 ATTACHMINT Y (cont) 4.0 INSPECTION 4.1 Following the field application, visually inspect the coated and wrapped pipe for voids or other defects. Inspect for pinholes or holidays with a Tinker and Rasor Model AP holiday detector or accepted equal, at a minimum of 12,000 V. Use the holiday detector at a travel rate not to exceed one foot per second. Do not allow the holiday detector to remain stationary while the power is on. 4.2 Indicate defects clearly with chalk immediately upon discovery. i 5.0 REPAIR 5.1 Remove all loose or defective tape in the area of repair and approxi-mately 2 inches in the surrounding area. Reapply primer to the exposed area and overlap onto the cleaned existing tape. Reapply tape to the repair area, overlapping onto the existing tape at least 6 inches. 5.2 " Window patching" may be used to repair pinholes, provided there are fewer than 3 pinholes per linear foot of pipe. Apply one layer of tape over the pinhole as a window patch (at least 4 square inches), and follow 14 by a see nd layer f tape applied completely around the pipe. 5.3 Inspect all repairs in accordance with paragraph 4.0. 6.0 EANDLING OF COATED PIPE 6.1 Af ter testing and repair, handle tape-coated pipe in a manner to protect the tape coating from damage. 6.2 Lift, lower, or suspend tape-coated pipe by the use of rubber or canvas belting with a removable pin and clevis on one end to permit removal of the belt without injury to the tape coating. The belt width is to be equal to or greater than the pipe diameter. The use of ropes, hooks, chains, or cables is not permitted. In the' lowering-in operation, take care to prevent swinging impact 6.3 or scuffing on the sides of the ditch. 6.4 The ditch shall be free of rocks, hard clods, stumps, skids, roots, and other solid debris. The excavated backfill soil shall be free of heavy rocks, clods, protrusions, or other foreign objects. A buffer board may be used to protect the pipe from damage during backfilling. i 6.5 Backfill immediately after lowering-in. Perform backfilling with care to prevent coating damage. l i Y-2 t (..

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SP.CIFIC ATIO 0. R E V. SC ~ 0. PALO VERDE NUCLEAR GENER ATING STATION /3-G N-335 -G $W9 SPECIFICATI N HANGE NOTICE i (sCN) Qu ALITY CLASS 10407 SNEET C JOB NO. A .A, . G-6-Tr3 ,,, G. G ea Ef ENolNEE.,No C- ..E.ut.TEo.v. CmENT ,,EL. ,u,,m E.,c o N,,, A CTo,, AdA c<> d L sw. Ae fue /hd<d ,, E,..N r., e-. E, / / i / A Vdves afut~ iMat/a. / i DESCRIPTION OF CH ANGr Add 1de fsoJiy see%s - speue nyua kw9 p%< FinMya~dr

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e. 8. 2 1 suc,4n ppm %.

Surfaces to be Coated shall be dry and free of oil, grease, dirt and other contaminants. Surface rust is permit,ted if it is tightly adhering and cannot be readily removed with wire brush.

• usE ADDITION AL SNEET IF NECESSA4Y OR ATTACH COPY OF MEVISED SPECIFICATION PAGES. [ -/ //. Q M ATEnl AL enocunEMENT RESPONSislWTY
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W SCM M SPECIFICATION CHANGE NOTICE (sCN) /3 - CM-Dg 8'W9 QU ALITY CLASS JOB NO 10407 SHEET O c -c-e a.,. a con ~ o,,. solvent cleaning using a solvent recommended by manufacturer. % f,7,3 Coating Application Coating shall be: 1 - Koppers "Bitumastic 300" 2 - Ameron ~78 EB" or Coating shall be applied by brush to a dry film thickness of 12 to 25 mils in one coat, ensuring that all surfaces are thoroughly coated and taking special care to ensure that mating surfaces between bolt heads and flanges i receive additional coating to ensure continuity of coverage. 7,8, g Curing Coated surfaces shall be allowed to cure undisturbed for a min of 72 hours. At Care must be taken to prevent damage to the coating.the end of (Note: Any indication that film is soft prior to back fill would indicate that required; o additional curing time at ambient conditions is ten days.) ptimum curing time at ambient before back filling is M o M y & h // ~ Ly seJ4 : s.gI nyh,4 S 1

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ENCLOSURE 2 TABLE 1 JOB NUMBER: 10407-002 ARIZONA NUCLEAR POWER PROJECT DATE: JANUARY 27,1983 FIRE PROTECTION PIPE CONTINUITY TEST ENGRS: R. R. Avila INDUCED AUDIO SIGNAL METHOD R. C. Robinson SIGNAL TEST SERVICE TEST CIRCU1T EASILY TRACED NUM8ER LINE NUMBER CONNECTION YES NO REMARKS 52 210 Unit 1 - PlV 12 to X Line appears continuous PlV 91 (North of Spray Pond U1) 53 212 Unit 1 - PlV J1 to X Line appears continuous PlV 66 54 313,210 Unit 2 - FH 14 to X Poor signalline suspect PlV 27 Current span test reouired (2) 55 308 Unit 2 - PlV 27 to X Line appears continuous Turbine Bldg. 56 210 Unit 2 - PlV 28 to X Line appears continuous PiV29 57 210,289 Unit 2 - PlV 28 to X Line appears continuous FH 15 58 210,283 Unit 2 - FH 15 to X Line appears contrnuous FH 16 59 283,287 Unit 2 - FH 16 to X Line appears continuous Fuel Bidg. 60 283 Unit 2 - FH 17 to X Poor signal line suspect to PiV 31 Current span test trouired (10) 61 283,286 Urit 2 - FH 17 to X Poor signalline suspect Rad Waste Current span test reovired (10) 62 283 Unit 2 - FH 17 to X Poor signal line suspect PlV32 Current span test required (10) 63 280,209,283 Unit 2 - FH 18 to X Line appears continuous PlV35 64 280,209,281 Unit 2 - FH 18 to X Line appears continuous FH 19 65 281,209,314 Unit 2 - FH 19 to X Line appears continuous Turb. Bldg. 66 281,209 Unit 2 - FH 19 to X Poor signalline suspect FH 40 Current span test required (61 67 281,209,314 Unit 2 - FH 19 to X Poor signaf kne suspect FH 12 Current span test required (7) 68 314 - Unit 2 - FH 12 to X Line appears continuous Turbine Bldg. PlV - Post indicator Valves ( ) Number in parenthesis indicates span test location FH - Fire Hydrani shown in Table 2. SHEET 4 0F 7 h

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