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| issue date = 01/17/1988
| issue date = 01/17/1988
| title = Rev 9 to Chemistry Operating Procedure COP 11, Secondary Sys Chemistry.
| title = Rev 9 to Chemistry Operating Procedure COP 11, Secondary Sys Chemistry.
| author name = HILLMAN C T
| author name = Hillman C
| author affiliation = CONSUMERS ENERGY CO. (FORMERLY CONSUMERS POWER CO.),
| author affiliation = CONSUMERS ENERGY CO. (FORMERLY CONSUMERS POWER CO.),
| addressee name =  
| addressee name =  

Revision as of 21:32, 17 June 2019

Rev 9 to Chemistry Operating Procedure COP 11, Secondary Sys Chemistry.
ML18052B458
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Site: Palisades Entergy icon.png
Issue date: 01/17/1988
From: Hillman C
CONSUMERS ENERGY CO. (FORMERLY CONSUMERS POWER CO.)
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COP-11, NUDOCS 8801250226
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Text

--Proc No COP 11 3. PALISADES NUCLEAR PWT CHEMISTRY OPERATING PROCEDUiE Revision and Approval Swnmary H.evision 9

  • Data. TITLE: SECONDARY SYSTEM CHEMISTRY 1/n/ae Date 2. . QA Concurrence

-

4 *. Date 5. Approved* c 6. Word Processing Incorporated

7. Periodic Review . ( BB01250226 880119 \ l \ PDR ADOCK 05000255 L' I I . P
  • PDR ' . r *. l-11£?** Date Date-Date Data Date *Date Date

,, ! e e ., *; PALISADES NUCLEAR PLANT Proc No COP 11 CHEMISTRY OPERATING PROCEDURE Revision 9 Page 1. T.ITLE: SECONDARY SYSTEM CHEMISTRY Table of Contents **. Page 1.0 PURPOSE . 1

2.0 REFERENCES

. 1 3.0 SAMPLING AND ANALYSIS . 1 4.0 LIMITS AND SPECIFICATIONS

  • ' . 2 4 .1 ACTION LEVELS. . 2 4.1.1 Action Level 1 . .. . 2 4.1.2 Action Level 2 . 2 4.1.3 Action Level 3 . . . . 3 4.2 LIMITS . .. 3 5.0 NORMAL CONTROL AND CORRECTIVE ACTION . 3 5.1 pH . . 3 5 .1.1 Normal Control .. . .. . 3 5.1.2'. Corrective Action 3 5.2 CATION CONDUCTIVITY . 4 5.2.1 Normal Control . .* 4 5.2.2 Corrective Action .* 4 5.3 .CONDUCTIVITY . ** 4 5.3.1 Normal Control .. 4 5.3.2 Corrective Action 5 DISSOLVED OXYGEN . . 5 5.4.1 Normal Control *. *. 5 5.4.2 Corrective Ac don 5 5.S HYDRAZINE . . s S.S.! Normal Control .. 5 5.5.2 5.6 5.6.2 5*. 1 5.7.-1 5.7.2 5.8 5.8.1 5.8.2 -. PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE: SECONDARY SYSTEM CHEMISTRY Table of Contents Corrective Action SODIUM * *. *. Normal Control Corrective Action CHLORIDE * . . Normal Control .. Corrective Action SILICA
  • Normal Control Corrective Action *.; 5.9 AIR EJECTOR . .OFF-GAS FLOW RATE 5.9.1 Normal Control . * .. .. 5. 9*. 2 Corrective Action .. 5 .10 CHEMICAL HIDEOUT. AND RETURN .. 5.10.l Normal Control 5.10.2 Corrective Action 5.n CONDENSATE STORAGE TANK CONTAMINATION LIMITS 5.11.1 No.rma 1 Cont ro 1 5.11.2 Corrective Aition *. .

.. s.12.1 Normal Control s.12.2 Corrective Action S.13 SULFATE .. 5.13.1 Normal Control chll81-0070kl54-89 . *' . .* ., . . . .. .. *, ... Proc No COP 11 Revision 9 Page ii Page 5 s 5 s 6 6 6 6 6 . . 6 6 6 6 7 7 7 7 7-7 7 7 8 8 PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE

.. . , TITLE:-SECONDARY SYSTEM CHEMISTRY Table of Contents 5.13.2 Action . . . . . . . . . . . . . 5.14 ORGANICS * . * *

  • 5.14.l Normal Control
  • 5.14.2 Corrective Action . . . . . . . . . . . 5 .15 -BORON 5.15.l Normal Control * . . . . . . . -. . 5.15.2 Corrective Action . . . . . -. . . . . . .

5.16 PRIMARY TO SECONDARY LEAK RATE . . . . . 6.0 RECORDS AND ATTACHMENTS

6. l_ RECORDS . . . . . . . . . . . . 6.2 ATTACHMENTS . . . . . . . . . . . . .. ATTACHMENTS . _ Attachment Table 3.1, "Secondary System Sample and Analysis Shutdown" Attachment 2, Table 4.1, "Secondary System Chemistry Levels: Attachment 3, Tabfe 3.2, "Secondary System Sample and Analysis Standby and Hot Shutdown" Attachment 4, Table 4.2, "Secondary System Chemistry Levels: Hot Shutdown" -Attachment 5, Table 3. 3, -"Secondary System Sample and Analysis Operation" -Attachment 6, _Table 4.3, "Secondary System Chemistry Levels: Attachment 7, Secondary System Sampling" Attachment 8, "Secondary System Chemical Additions" _ *Attachment 9, -"Boric Acid Conditicming of Ste.am Generators" chll81-0070kl54-89 Proc No COP-11 -Revision 9 Page_111 8 8 8 . . . . . . 8 . . . . . . 9 . . 9 . . 9 . . . . 9 * * -* , 9
  • 9 9 Sctledule:

Cold Cold Shutdown" Schedule:

Hot Hot St_andby and Schedule:

Power-Power-Operation'_'

  • .. PALISADES NUCLEAR PLANT *CHEMISTRY OPERATING PROCEDURE TITLE: SECONDARY SYSTEM CHEMISTRY Proc* No COP 11 Revision 9 Page 1 of.10 LO PURPOSE 2.0 2.1 2t.2 2 .* 3 2.4 2.5 2.6 2.7 2.8 2.9 2.10 2 .11 2.12 3.0 This procedure establishes the.guidelines for maintaining proper istry conditi6ns in the Secondary System. This shall
  • trol in the event of conflicts between it and other .Plant documents, except for Technical requirements.

The Palisades General Manager may allow variance from this procedure-upon his.approval.

REFERENCES P-CE-3909, April 16,.1974 CENPD-28 EPRI Steam Generator Owners' Group -PWR Secondary Water Chemistry September 1981 Technical Specification 3.1.5.c, Table 6.22 Technical Specification Table 4*.2 .1 Chemistry Procedure CH 1.5, "Chemistry Operad.ng Logs, Records, Graphs, Data Management" E-PAL-81-095A; D-PAL-81-095; RMK83*137 Operations Procedure "Dry Layup of "B" Steam Generator

(**E-508)

Operations Procedure MSS0-3, "Dry Layup of "A" Steam Generator

(**E-50A)

  • FWS0-1, Layup" CPCo Hazard Communication Program CTH85*014

.. SAMPLING AND ANALYSIS Sampling and analysis frequencies for -Secondary System are specifie_d in Attachments 1, 3 and 5. Additional sampling and analysis may be requested at the discretion of the Plant Laboratory Supervisor or Shift Supervisor.

Sampling should be performed in accordance with authorized Chemistry Procedures.

  • PALISADES NUCLEAR PLANT *CHEMISTRY OPERATING PROCEDURE TITLE: SECONDARY SYSTEM CHEMISTRY

... Proc No COP 11 Revision 9 Page 2 o( 10 4.0 .LIMITS AND SPECIFICATIONS The chemistry values stated in Attacrunents 2, 4 and 6 shall be adhered to in order to assure long-term Secondary System ity. These values reflect current understanding of the role of chem-* ical. transport, impurity material selection, corrosion behavior and industry practice for the operation, maintenance and tegrity of. steam generator systems. Failure to maintain these limits may reduce long-term Secondary System equipment reliability.

4.1 * -ACTION LEVELS 4.Ll 4.1.2 Three action levels for power operation are established and shall be used. to initiate remedial.

action when monitored parameters are firmed (ie, verified by an additiohal sample and to be outside the normal operating value. They are.as follows: Action Level 1 a. Objective identify and correct the cause of an off.:.normal value *without p()wer reduction.

b. Actions: 1. Return parameter to within normal_ value range within seven days following confirmation of excursion.
2. *If parameter is not within normal _vilue range within 1 week 'following.confirmation of excursion, be at approximately 35%

within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by initiating a controlled power r-eduction.

Action Level 2 a. Objective Minimize corrosion by operating at reduced power while investigations are made and corrective actions*are taken. b. Actions: -1. In a controlled manner, reduce* power to approxima:_tely 35% within eight hours of confirmation of Action Level 2. 2. Return to within normal value range within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in hot staridby within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by initiating a controlled power reduction.

    • 1.3 e-Action Level 3 a. Objective*

PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE: SECONDARY .SYSTEM CHEMISTRY Proc No COP 11 Revision 9 Pa_ge 3 of 10 Prevent rapid steam generator corrosion during continued ation. Plant -shutdown will minimize ingress and eliminate further concentration of harmful impurities.

-b. :Action: Be in a hot shutdown condition.within twelve hours by initiating a controlled power reduction.

Remain in.this operating mode or an operating mode resulting in a lower primary coolant temperature until the normal parameter levels for the existing operating mode can be maintained and normal parameter levels at higher coolant temperatures can be expected.

4.2_ LIMITS 5.0 5.1 5 .1.1 5 .1.2 Limits on the steam generator radiochemistry parameters are specified

  • in Plant Technical Specifications.

Corrective actions for these limits 'shall comply with the Technical Specification Requirement_s.

NORMAL CONTROL AND CORRECTIVE ACTION pH Normal Control Normal control of secondary cycle pH is maintained by addition_

of morpholine and the ammonia formed by thermal decomposition of The steam jet air ejector after condenser drain is 'normally routed to waste to reduce ammonia buildup. Corrective-Action_

High cycle pH can be reduced by reducing morpholine and/or hydrazine feed. Dumping the Plant heating boiler condensate receivers to -waste will also_ help remove volatiles from the system arid lower pH. NOTE:' This only*applie_s the heating system is on extracti-on and the. pH problem is' caused by ammonia. -Increasing steam generator blowdowns is another means of reducing _ system pH. Low pH is generally caused by insufficient chemical feed or large impurity ingress (condenser

  • air/water inleakage, makeup demineralizer Chemical feed of morpholine should be increased.

to maintain pH limits. Prompt action must taken to terminate any impurity ingress. chll81-0070al54-89 5 .2. 5.2.1 \

5.3 5.3.1 PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE: SECONDARY SYSTEM CHEMISTRY . CATION .CONDUCTIVITY Normal Control Proc No COP -.11 Revision 9 Page 4 of 10 Normal control is exercised by maintaining low levels of condenser air/water leakage, maintaining proper makeup water quality and continuous steam generator blowdoWri.

It has been determined that at the 5-10 ppm range boric acid increases cation conductivity values by 0. 03 µmho/ cm for each ppm boron that is present in solution*.

  • This
  • factor should be considered when evaluating steam generator cation conductivity.

Corrective Action High cation conductivity values can be by reducing impurity and increasing steam generator blowdown.

To determine the sou*rce of impurity, sample the following.

Analyze the liquid samples for pH, conductivity, sodium and magnesium.

a. Steam Jet Air Ejector Drain b. Condensate Pump Discharge
c. Condensate Storage Tank d. North and South Condenser Hotwell Samples e. **T-104 .Effluent (Steam Generator Slowdown Demineralizer)
f. Local Pump Discharge (To Check CPD Sample Cooler Leakage) g.

Boiler Condensate Receiver Tanks (If Routed To Condenser Hot well) h. Feed Condensate Receiver Tanks i. Slowdown Heat Exchanger Outlet J* *Heater* Drain.Pump*

Discharge (HOP Sample Cooled By-Service Water) CONDUCTIVITY . Normal Control Normal control of conductivity (ie, removal of dissolved carbon dioxide and excess ammonia) is by discharging to waste the steam jet iir ejector

(**E-8 After Condenser Drain) and steam generator blowdown.

.. 5.3.2 5.4 5.4.1 5.4.2 5.5 5.5.1 5.5.2 5.6 5.6.1 5.6.2 PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE: SECONDARY SYSTEM CHEMISTRY Corrective Proc No COP 0 11 Revision 9 Page 5 of 10 High steam generator (impurity c*used) may be reduced by increasing steam generator.blowdown and isolating the source of_ impurity *. High conductivity due to excessive additives may be controlled by reducing additive feed rate. DISSOLVED OXYGEN Normal Control Oxygen ingress into the secondary system is controlled by maintaining low levels of condenser inleakage.

Corrective Action Corrective action to reduce high dissolved oxygen is to locate and isolate air inleakage and increased hydrazine addition *. Care must be exercised with hydrazine addition to assure that hydrazine is not added to excess. HYDRAZINE Normal*Control Normal control of system hydrazine levels is by changing hydrazine feed rates. Corrective Action Hydrazine are adjusted by:varying the hydrazine addition.

rai:e.

Corrective Action Confirmed increases in steam generator blowdown sodium levels should lead to the impurity source location sampling listed in Section 5.2.2 of this procedure.

chll81-0070al54-89

5. 7 . 5.7.1 5.7.2 PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE
  • .TITLE: SECONDARY SYSTEM CHEMISTRY CHLORIDE Normal Control Proc No COP 11 Revision 9 Page 6 of 10 Normal control of steam generator is exercised by' contr6lling makeup quality, controlling condenser inleakage and steam generator blowdown.

Steam generator blowdown may be increased to reduce chloride *.level. Corrective Action Confirmed increases in steam generator blowdown chloride levels should .lead io the impurity source location sampling listed in Section 5.2.2 of this procedure.

5.8 SILICA 5.8.1. Normal Control . Normal contr.ol of silica is. by steam generator blowdown and control of makeup water qual_i ty *. . 5.8.2 .Corrective Action 5.9 5.9.1 5.9.2 Confirmed increases in steam generator blowdown silica levels should lead to the 'impurity location sampling listed in Section 5.2.2 of this procedure.

AIR EJECTOR FLOW RATE Normal Control Normal control of condenser air inleakage (Air Ejector Off-Gas Flow Rate) is by locating an4 isolating air inleakage.

Air ejector off-gas flow rate should normally be 5-8 cfm or less. Readings greater than or equal to 10 cfm are abnormally high and should result in corrective action. Corrective Action Use of the freon*leak detector system is recommended for ieak location * . *Helium *leak detection may also be used for t'eak location".

Helium leak detection is more sensitive and will permit ldcati6n of smaller leakage sources. chl1Sl-0070al54-89

,. PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE: SECONDARY SYSTEM CHEMISTRY 5.10 CHEMICAL HIDEOUT AND RETURN 5.10.1 Normal Control Pree No COP 11 Revision 9: Page 7 of 10.

  • Normal control of chemical hideout* and return is _by control of feedwater quality. 5.10.2 Corrective Action Chemical hideout is reduced by maintaining high quality feedwater and steam generator blowdown.

Chemical return is reduced by. partial steam generator drain and fill steps and by steam generator blowdown.

5.11 CONDENSATE STORAGE TANK CONTAMINATION LIMITS 5.11.1 Normal Control Normal control of condensate storage contamination is by control . of hot well and makeup.quality.*

5.11.2 Corrective Action acti6n for condensate storage tank contamination is to the impurity source. and also partial tank drain and fill steps. 5.12 STEAM GENERATOR NITROGEN PURGE 5.12.1* Normal Control *During long-term cold shutdown (greater _than three days) a nitrogen pur'ge of the gas space should be established in the steam generators, *ih ordei to* minimize the corrosive.effects oxygen. The bottom blowdown lines should normally be used for nitrogen feed to the Steam Generator not on Nitrogen purge is normally secured to the Steam Generator on recirculation.

Nitrogen purge with no able oxygen-present must be established before lowering the Steam water level (see references i.B and such that Steam Generator tubes are NOTE: *Nitrogen purge could be interrupted by maintenance,-

in.spectio-n, -eC-c, of the secoridary side of the.steam generators, main steam lines and other components which are normally nitrogen_purged during cold down. Sampling of the gas space may be **suspended during this time. 5.12.2 Corrective Action nitrogen flow to the Steam Generators as soon as possible.

Low nitrogen/high oxygen concentrations may be due to the following:

a. *Main steam line bladder leak (if.bladder installed).

chll81-0070al54-89

... PALISADES NUCLEAR PLANT .CHEMISTRY OPERATING PROCEDURE TITLE: SECONDARY SYSTEM CHEMISTRY Proc No COP 11 Revision 9 Page 8 of 10 b.

  • Main steam isolation valve or main steam relief valve work. c. Blocked sample line due to condensation in line. d. Low nitrogen feed flow. e. Improper valve lineup. f. Closed sample valve. g. Steam Generator manways not properly closed. . . h. Secondary side work (ie, sludge lancing, inspections, etc) has contributed oxygen in.the past due to air operated equipment used these operations.

5.13 SULFATE 5.13.1 Normal Control Normal control of Steam Generator sulfate is exercised by:controlling makeup water quality, controlling condenser leakage, and preventing resin from entering the feedwater and steam 5.13.2 Corrective Action Confirmed increases in sulfate levels. should lead to the °impurity source location sampling listed in Section 5.2.2 of this procedure.

High concentrations of sulfate may be more quickly reduced by performing a Steam Generator drain and ref ill in accordance with References 2.8 and 2.9. A complete drain and refill of the Steam Generators should be-considered when the plant enters a.cold shutdown condition.

5.14 ORGANICS 5.14.1 Normal Control Normal control for organics is accomplished using the Steam. Generator blowdowns by controlling makeup water quality and by maintaining integrity control over various interface systems. Organits intrusion sources are such things as resins (blowdown demin); lubr_icating oils (feedwater pumps) or non-ionic organics introduced through the makeup system. 5.14.2

  • Corrective Action Confirmed increases in Steam. Generator otganics contamination may be reduced by increasing Steam Gene_rator blowdown and isolating the source of impurity.*
  • PALISADES.

NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE: SECONDARY SYSTEM CHEMISTRY Proc No COP 11 Revision 9

  • Page 9 of l_O 5.15 BORON 5.15.1 Normal Control-Boric acid is added to the se.condary system to neutralize denting . . corrosion chemically in the steam generators during operation.

Normal control of system boron levels.is by changing.boric acid feed rates. 5.15.2 Corrective Action Boron concentrations are adjusted by varying the boric a*cid addition rate. Increasing steam generator blowdowns is a means of reducing*

steam generator boron levels; 5.16 PRIMARY TO SECONDARY LEAK RATE The equation for calculating a_primary to secondary ieak rate is *contained in Attachment 6 of Reference 2.6 6.0 *RECORDS AND ATTACHMENTS 6.1 RECORDS 6.2 6.2.1 6.2.2 6.2.3 Records of chemical of the Secondary System should be corded in the Cold Lab in accordance with 2.6. *Gamma spectrums shall normally be stored on the magnetic sory to the multichannel analyzer.

_The paper printout may be tuted when the magnetic tape is not available.

Chemical additions to the Secondary System should be recorded in the Cold Lab Logbook in accordance with Reference 2.6. ATTACHMENTS Attachment 1, Table 3.1 "Secondary System Sample and Analysis Schedule:

Cold Shutdown" Attachment 2, Table 4.1 "Secondary System Chemistry Levels: Shutdown"

  • Attachl!tent 3, Table 3.2 "Secondary System Sample and Analysis Schedule:

Hot Standby and Hot Shutdownn Cold 6.2.4 Attachment 4, Table 4.2 "Secondary System Chemistry

  • Levels:*

Hot* Standby and Hot Shutdown" 6.2.5 Attachment 5, Table 3.3 "Secondary System Sample and Analysis Schedule:

Power. Operation" 6.2.6 Attachment 6, Table 4.3 "Secondary Syst.em Chemistry Levels: Power Operation"

  • chll81-0070al54-89

/

6.2.7 6.2.8 6.2.9 PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE: SECONDARY .SYSTEM CHEMISTRY Attachment 7, "Secondary System Sampling" Attachment 8, Secondary

  • system Chemical Additions" Attachment 9, "Boric Acid Conditioning of Steam Generators" chll81-0070al54-89 Proc No COP 11 Revision 9 Page 10 of 10 Parameter Procedure llH CH 4.1 CH 4.2 lydrazine CH 4. 7 lodium CH 4.33 *issolved CH 4.5A-C hygen >hosphate CH 4.56 >ul fate CH 4 .* 9 CH 4.56 lhlorid.e CH 4.48 CH 4.56 lross Gamma CH 5.4 10TES: TABLE 3 .1 -TABLE.3.1 Secondary System Sample and Analysis Schedule:

Cold Feedwater Heaters 1 CST'or Dry Lay-Up Wet Lay-Up Auxiliary Feedwater Steam (Pref/Reg) (Pref /Reg) * (Pref/Reg)

NR

  • W/NR 2/NR NR
  • W/NR 2/NR NR W/NR 2 /NR. NR NR/NR
  • 2 /NR NR W/NR 2/NR *NR NR/NR 'NR/NR . NR NR/NR NR/NR NR W/NR 2 /NR NR NR/NR NR/NR Proc No COP 11 Attachment.

1, Revision 9 Page 1 of 2

  • Generators 5 (Both) (Pref/Reg)'i 3/NR 3/NR 3/NR 3/NR 3/NR W/NR 3/NR 3/NR M/NR Dry lay-up of the feedwater heaters (tube and shell side) is preferred to wet Weekly purging of the*shell side with dry air is recommended (shell side samples only). See Reference 2.10

Deleted Cold shutdown conditions exist when PCS temperature is< 210°F. Assumes recirculation is achievable-.

Nitrogen*

purge may be interrupted during cold* shutdown becaus.e of maintenance, inspections*, etc. Sampl i.ng may be suspended during this time. Jey: W* = Once Per Week; 2 = Two Times* Per Week; 3 = Three Times Per Week; NR = Not *Required; M = Onc.e Per Month

'<* .*

Parameter Procedure Humidity CH Oxygen CH 4.49 (Gas Space) Nitrogen CH 4.49 (Gas Space) Iron CH 4.33 Copper CH 4.33 Boron CH 4.3A NOTES: TABLE 3.1 TABLE 3.1 Secondary System Sample and Aflalysis Schedule:

Cold

W/NR NR/NR NR/NR NR . NR/NR NR/NR NR NR/NR *NR/NR NR W/NR 2/NR NR W/NR 2/NR NR/NR NR/NR 2/NR .Proc No COP 11 Attachment

  • l . . *Revision 9
  • Page -2 of 2 Generators 5 (Both) (Pref/Reg)lt NR/NR 3)6 3/6 NR/NR .NR/NR NR/NR 1. Dry of the heaters (tube and shell side) is preferred to wet lay-up. Weekly purging of the shell side with dry air is recommended (shell side samples only). See Reference 2.10 2. Auxiliary feedwater or the CST should be sampled daily when being used to supply water to the steam generators.
3. *Technical required sample/ analysis frequencies are controlled by the Technical Specifications Surveillance Test Program. See Reference 2.7 for clarification of this requirement.

,4. Cold shutdown exist when PCS temperature is < 210°F. 5. Assumes recirculation is achievable.

6. Nitrogen purge may be ittterrupted during cold shutdown because of maintenance, inspections, etc. Sampling may be suspended during this W = Once Per Week; 3 Three Times Per Week; NR = Not Required, M = Once Per Month tchll81-0070bl54-89 . I I I TABLE 4.1 Secondary System Chemistry Limits: Cold Shutdown (Administrative Limits) Feedwater CST or (Wet Lay-Up) Auxiliary Feedwater Steam (Both) Proc No COP 11
  • Attachment 2 Revision 9 Page 1 of 1 Parameter Normal Value Normal Value Normal Value Initiate Action Prior to Heatup f>H 9.3-10.0 9.6-10.2 <9.6, >10.2
onductivity

(µmho/'cm)

<20. 0 µmho/ cm }lydrazine (ppm) ])odium (ppb) )issolved Oxygen (ppb} ?xygen. (Gas Space) l>ulfate (ppb)'t (ppb) lron ( ppb) (ppb} (ppm) 5 50-100 <30 3x 0

  • 2. <100 *<100 <100 <100 <100 7.5-200 <75, '>200 20-50 1 <1000 >1000 <100 <30 >30 <30.0 <1% >1% <1000 >1000 <100 <1000 >1000 <100 <.5 >.5 <.5 TABLE 4.1 ll. The limits lis.ted above *apply to cold shutdown.

Short-term (less than three days}. cold. shutdowns require only that the components remain full 'with a 25-50 ppm hydrazine residual established in the steam generator (only). Steam gerierator recirculation and the abqve chemistries should be implemented for of three days, or longer, planned length. #,. These limits are to" be achieved prior to leaving cold shutdown conditions by steam generator recirculation and steam generator blowdown.

The Steam Generator limits for pH, Hydrazine, sulfate, sodium and chloride .do not apply if recirculation and T-104 demineralizer are riot available.

The normal limits should be achieved before recirculation is secured. ). At all times, the steam generator water level will cover the entire gerierator tube bundle except wben drained per Reference or 2.9. :?.. Sulfate values of less.than*

1000 ppb fipply only if an.instrument is readily available for .measurement in this range. p. Boron shall be blown down to <.5 ppm when going to told This is to m1n1m1ze the possibility of low pH and air ingress resulting in the.corrosion of carbon steel or Inconel 600. . I I Proc No COP TABLE 3.2 Attachment 3 Revision 9 Secondary System Sample and Analysis Schedule:

Hot Standby 1 '5 Page 1 of 2 *CST or Aux Condensat*e It. Feedwater 2 * *Feedwater 2 . . 5 Steam Generators Parameter Procedure (Pref /Reg)* (Pref /Reg)*. (Pref/Reg) (Pref /Reg) pH CH 4.1 S/NR S/NR D/NR S/NR Conduc ti vi ty CH 4.2A S/NR. S/NR D/NR NR/NR Cation Conductivity CH 4.2A D/NR D/NR NR/NR S/NR Hydrazine CH 4.7 S/NR S/NR D/NR S/NR Dissolved Oxygen CH 4.SA-C S6/NR S/NR D/NR *s/NR Sodium CH 4.33 S/NR NR/NR D(NR ** S/NR Chloride CH 4.48. S/NR NR/NR. D/NR S/NR CH 4.56 Phosphate CH 4.56 S/NR NR/NR

  • D/NR S(NR Sulfate CH 4.9 S/NR NR/NR D/NR S/NR CH 4.56* Boron CH 4.3A NR/NR NR/NR ' NR/NR .S/NR NOTES: TABLE 3.2* ---1. This table applicable when PCS temperature is and power is <2%. 2. Feedwater sample/analysis frequency is applicable only. when the steam generators are being via the Hain Feed Pumps P-lA or P-18. CST or Aux Feedwater sample/analysis frequency is applicable when the steam. generators are being supplied via the auxiliary feed pumps. 3.

Specifications required sample/analysis frequencies are by the Technical Specifications Surveillance Test Program, Procedure DWC-4.

  • 4.; Assumes recirculation is* available.*
5. : Assumes steam generator blowdow sample is avai'iable*.
6. Shiftly analysis of condensate for dissolved oxygen is not required until plant in on main feed. Prior to that time, daily sampling 'is required.

Keys: S = Once Per Shift 1;. D = Once Per Day; NR = Not Required; 3 = Three Times Per Week ch11a1-001od154-89

.*

Parameter Gross.Ganuna silica Iron *Copper Dose Equivalent Iodine Calcium. *Magnesium NOTES: TABLE 3.2 1. This table is applicable when PCS temperature is >210°F and reactor po'wer is <2%. 2. Feedwater sample/analysis frequency is applicable only when the .steam generators are being supplied via the. Main Feed Pumps P-lA or P-18. Auxiliary feedwater sample/analysis frequency is applicable when the steam generators are being supplied via the auxiliary feed pumps. . 3. Technical Specifications required sample/analysis frequencies are controlled by the Technical Specifications Surveillance Test Procedure DWC-4.

  • 4. Assumes recirculation is available.

5.. Assumes steam generator blowdown sample is* available.

Key: S :;;; Once Per Shift; D :;;; Once Per Day; NR :;;; Not Required; 3 :;;; Three Times Per Wee.k; W :;;; Once per Week ch1181-0070dl54-89 " .

.TABLE 4.2 Proc No COP 11 " Attachment 4 Revision 9 Secondary System Chemistry Limits: Hot Standby (Administrative Limits) Page 1 of 3 .CST or Auxiliary Steam Generators (Both) Condensate Norm81 Value Feedwater Normal Value Normal .Initiate Normal Value .. Initiate Value Prior to Parameter Value Action Action Power Escala.tion 3 pH 7 Cation Conductivity

(µmho/cm) 8.5.,...9.2 Dissolved Oxygen (ppb) * <20

.* 2 <20 8.5-9.3 <5.0 {10.-50. <8.8, >9.3 8.5-9.3 <2.0 8 >5.0 <10., >50. }@>500°F {>500 <500, >4000}@<500°F Hydrazine (ppb) l.5x 0 2 Sodium (ppb) .<50 <100.0 >100.0. Chloride (ppb) <100.0 Sulfate (pp_b)5 <100 >100 NOTES: TABLE 4.2 1. 2. This table is applicable when PCS temperature is >210°F and reactor power is <2% *. Deleted 3. These limits are to.be achieved prior to escalating Plant power above 2%. . . <100 .o <100.0 <100 4 *. Normal limits should be met within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> of start of.heatup.

If "initiate action" values are exceeded, a potentially damaging condition is indicated and cooldown may be needed to allow contaminant removal. ' 5*. 6. 7. Sulfate values of less than 1000 ppb apply only if an instrument is readily available for measurement in this range. Aux Feedwater control parameters deleted and controlled at CST until reliable sample points are obtained.

8. Boron values are applicable when coming from cold shutdown in preparing for boric acid soak (see Attachm*en_t 9). pH and Cation conductivity values during boric acid .soak ar*e listed in Attachment
9. Boric acid soak is to be initiated after long term shutdown.

It is not applicable when in short term shutdown.

See Attachmen:t

9. Boric contribution to Cation conductivity should be subtracted out before evaluating to limit.* See 5.2.1.

TABLE 4.2 Proc No CQP 11 Attachment 4 Revision 9 Secondary System Chemistry Limits: Hot Standby (Administrative Limits) Page 2* of*3 CST or Condensate Normal Value Feedwater Normal Value Auxiliary Feedwater 6

  • Steam (Both) Parameter iiron ( ppb) l;opper (ppb) (ppm)7 t'<>TES: TABLE 4.2 <100 <100 . Normal .Initiate*

Value Action Normal *value .. This table is applicable when PCS temperature is >210°F and reactor power is.<2%. Deleted ).

limits are to be achieved prior to escalating Plant power above 2%. Initiate Value Prior to Action Power Escalai:1on 3 *. 5-10. Y.. Normal limits should be met within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> .of start of heatup. If "initiate action values are exceeded, a potentially damaging condition is indicated and cooldown may be needed to allow contaminant removal. p. Sulfate values of less than 1000 ppb apply only if an instrument is readily available for measurement in this range. J). Aux _Feedwater control par.ameters deleted and control led at CST until reliable sample points are obtained. Boron values are applicable when coming* from cold shutdown in preparing for boric acid soak (see Attachment 9). pH.and Cation, conductivi'ty values during bor1c acid soak are listed in Attachment

9. Boric acid soak is to be initiated after long term shutdown.

It is not applicable when* in short term shutdown.

See Attachment

9. ). Boric aiid contribution to Cation conductivity shbuld be before evaluating compliance to limit. See 5.2.1. * *
  • Parameter pH Conduc ti vi ty (umho/cm)

Hydrazine (ppm) Dissolved Oxygen (ppm)-(ppm) Chloride (ppm) Phosphate (ppm) Sulfate (ppm) Iron (ppm) Copper '<ppm) Boron (ppm) NOTES: TABLE 4.2 TABLE 4.2 Secondary System Chemistry Limits: Hot Standby (Administrative Limits) Condensate Tank (T-2) Normal Initiate Value

  • 5.5-9.0 <3.0 <0.005 <0.1 <0 .100 <0.100 .. <O .100 <0.100 Action <5.5 6 >9.0 <75 <0.5 1. This table is when. PCS temperature is >20d°F and reactor <2%. 2. Deleted 3. These limits are .to be achieved prior to escalating Plant power above *2%. Proc No COP l'i Attachment 4, Revision 9 Page 3 of 3* 4. Normal limits should be met within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> of start of heatup. If "ini.tiate*

action" values are a potentially damaging condition is indicated and cooldown may be. needed to allow contaminant removal..

5. Sulfate values of less than 1000 ppb apply only if an instrument is readily available for measurement in this range. 6. Low pH in cold weather conditions inay be caused by an increase in C02 concentration.

Increases in pH may be caused by increased amononia, hydrazine or morpholine concentrations.

These parameters should be checked prior to_

action on the . ,. chll81-0070el54-89

...

TABLE 3.3 Secondary System Sample and Analysis Schedule:

Power Condensate Feedwater 2 Parameter Procedure 6 (Pref/Reg)

CST (Pref/Reg) pH CH 4.1 S/NR W/NR S/NR Conductivity CH 4.2A S/NR W/NR S/NR Cation Conductivity . CH 4.2A D/NR NR/NR D'/NR. Ammonia CH 4.8A 3/NR 3/NR 3/NR Morpholine CH 4 .10 *3/N!l 3/NR 3/NR Hydrazine CH 4.7 S/NR D/NR S/NR Dissolved Oxygen CH 4 .5A-C S/NR W/NR S/NR Sodium CH 4.33 D/NR D/NR NR/NR NOTES: TABLE 3.3 Pioc No COP 11 Attachment 5

S/NR S/NR

  • S/NR 3/NR 3/NR. siNR NR/NR S/NR 1. This table is applicable when reactor power is >2%. 2. The feedwater .sample is obtained for "A" or "B" feedwater This* sample point shoulij 'be recorded and rotated weekly. 3. Technical Specifications required sample/analysis frequencies are controlled by the Technical Specifications Surveillarice Test Program, Procedure DWC-4. 4. Sample is sent to Trail for analysis.

If sample 1s radioactively contaminated it is sent to Big Rock for analysis.

5. Perform a Gamma Spectral Analysis.

6 *. Process monitor readings may be used in lieu of laboratory analysis to fulfill the preferred frequency Key_: s:::: Once Per Shift; D:::: Once Per Day; W:::: Once Per Week;-3::::

Three Times Per Week;

  • I NR _:::: Not Requ1re9; M :::: Once Per Month I
i. . i' Proc No COP 11 Attachment 5 * *Revision 9 Page 2 of 3 TABLE 3.3 Secondary System Sample and Analysis Schedule:

Power Operation 1 Condensate Steam Generators Parameter (Pref/Reg)

Procedure 6 (Pref /Reg)* CST (Pref /Reg) Chloride Iron Copper Silica Gross Gamma Dose Equivalent Iodine* Magnesium NOTES: TABLE 3.3 CH 4.48 CH 4.56 CH 4.33 CH 4.33 CH 4.12 CH 5.4 CH 4.39 DWC 4 DW.C-4 CH 4.39 CH 4.33 NR/NR W/NR *w/NR NR/NR NR/NR NR/NR S/NR. 1. This table is applicable when reactor power is >2%. W/NR W/NR D/NR W/NR W/NR W/NR W/NR W/NR W/NR 3/NR NR/NR 3/NR

  • W/NR 5 NR/NR DI' NR/NR NR/NR W/NR D/NR. D/NR 2. The feedwater sample is obtained for "A'.' or "B" feedwater train. This sample .Point .. should be recorded and
  • 3. Technical Specifications required sample/analysis frequencies are controlled by the Technical*

Specifications Test Program, Procedure DWC-4. 4. Sample is sent to.Trail Street If sample is radioactively contaminated it is sent to Big Rock for analysis.

5. Perform a Gamma Spectral
6. Process monitor readings may be used in lieu of laboratory analysis to fulfill'the preferred frequency requirements.

Key: S = Once Per Sh,ift; D = Once Per Day; W = Once Per Week; 3 "' Three Times Per Week; NR "' Not Required; M "' Once Per Month TABLE Secondary System Sample and Analysis Condensate Parameter Procedure 6 SJAE (Pref/Reg) s*u1 fate CH 4.9 NR NR/NR *CH 4.56 Calcium CH 4.33 NR W/NR Pho.sphate CH 4.56 NR NR/NR Organics .. NR M/NR SJAE Off-Gas CH 3.31 D/NR NR/NR Boron CH4.3A D/NR NOTES: TABLE 3.3 1. This table is applicable when reactor power is >2%. 3.3 Schedule:

Power Operation 1 Feedwater 2 CST (Pref/Reg)

D/NR NR/NR W/NR NR/NR NR/NR NR/NR M/NR . M/NR NR/NR NR/NR. D/NR D/NR Proc No COP 11

  • (Pref /Reg)
  • D/NR W'/NR W/NR M/NR NR/NR S/NR 2. The feedwater sample is obtained for "A" or 11 8 11 feedwater train. This sample point should be. recorded and rotated weekly. 3. Technical Specifications required sample/analysis frequencies*are controlled by the Technical Specifications Surveillance Test Program, Procedure
  • . 4. Sample is sent to Trail Street for analysis.

If. sample is*.radioactively contaminated it is *sent to Big Rock for analysis .* 5. Perform a Gamma Spectral Analysis.

6. Process monitor readings may be used in lieu of laboratory analysis to fulfill *the preferred frequency requirements.

Key: S = Once Per .shift; D = Once Per Day; W = Once Per Week; 3 = Three Times Per Week; NR = Not Required; M = Once Per Month chll81-0070fl54-89

.*

Paramet.er . pH6 Cation Conductivity

't , (µmho/cm)

Sodium (ppb)'t Chloride (ppb)'t Silica (ppb) Oxygen (ppb) HOTES: TABLE 4.3 TABLE 4.3 Proc .No COP 11\" Attachment 6 Revision 9 Page 1 of ,3 Secondary System Chemistry Limits: Power Operation (Administrative Limits) 6 . Normal Value 7 , <10 .o Condensate Action Level 1 2 3 >10.0 >30.Q >100. Normal Value >8.5 Feed water Action Level 1 2 3 <8.5 >5.0 . Normal Value *> 7. 5 <0.8 <20 <20 <300 Generators (Both) Action Level 1 2 3 <7.5 >0.8 >2.0 >7.0 >20.0 >100 .. 0 > 5;00 .o >20.0 > 100. 0 . >300.0 e 1. This table applicable when reactor power is 2%. 2. Deleted 3. The above 1 imi t*s are based upon a continuous*

ste'am generator blowdown of 10 ,000 pph (minimum).

each. 4. Whenever the turbine/generator is synchronized all requirements of Table 4.3 including the Action Level Criteria shall apply. Prior to escalating power *above 35%, Normal chemistry values shall be achieved.

The controlling parameters for Action Level 2 shall be sodium, chloride and sulfate. The Action Level 2 value for cation conductivity need not be met if the values for sodium, chloride and sulfate are. below the Action Level 2 limits. 5. Plant operation with locatable c6ndenser water leaks is not desirable.

When an identified condenser.leak reaches approximately 0 .1 gallon per minute, :Plant power should be reduced for condenser leak location procedure.

6. Boron, pH and Cation conductivity value are when normal power operation.

Values for these parameters during boric acid power soak are listed ih Attachment

9. . . 7. Boric Acid contribution for Cation conductivity should be out before evaluating compliarice to limit. See 5.2.1. chll81-0070gl54-89 Proc No COP 11*" 0 Attachment 6 Revision 9 Page 2 of 3
  • TABLE 4.3 Secondary System Chemistry Limits: Power Operation (Administrative Limits) Parameter Hydrazine (ppb) :Organics (ppm) Sulfate (ppb) .. Magnesium (ppb)5 Boron (ppm)6 NOTES:* TABLE 4.3 Normal Value <5 <O .05
  • Condensate Action Level l 2 3 >0.05 >0.1 >2.0 -/ Normal Value 5.0-20. 1. This table is applicable when reactor power is above 2%. 2. Deleted Feedwater

<5 <20 ' 5-10* Action Level* 1 2 <5.0 >20 <5 >10 >100 3. The above limits are based upon a continuous steam generator blowdown of 10,000 pph (minimum) each. 4. Whenever the turbine/generator is *synchronized all requirements of Table 4.3 including the Action Level Criteria shall apply. Prior to escalating power above 35%, Normal chemistry values shall be achieved.

The controlling parameters for Action Level 2 shall be sodium, chloride and sulfate. The. Action Level 2* value for *cation. conductivity need not be met. if the values for sodium, chloride and sulfate are.below the Action Level 2 limits. 3 Plant operation with locatable condenser water leaks is not desirable.*

When an identified condenser leak reaches approximately 0 .J *gal ion per minute, Plant power should be reduced for condenser*

leak location procedure.

i6. Boron, pH and Cation 'conducti\1ity value are applicable when at normal power opera.tion.

Values.for these . parameters during boric acid power soak are listed in Attachment

9. 7. Boric Acid contribution for Cation conductivity should be subtracted out before evaluating compliance to See 5. 2 .1.

.. *{ Proc No COP 11 * .TABLE 4.3 Secondary System Chemistry Limits: Power Operation

'(Administrative Limits) Steam Jet Air Ejector (SJAE) Condensate Storage Tank Normal Action Level Normal Action Level Parameter Value 1 2 3 Value 1 .2 3 Sodium (ppb). <5 >30. > 75. 0 >1940. SJAE Off-Gas (cfm) <8.0 >10.0 Sulfate ppm <0 .100 >0.5 >1.0 >5 .o Attactunent' 6 Revision 9 Page 3 of 3 TABLE 4.3 1. ,3. a4. This table is applicable when reactor power is above 2%. Deleted The above limits are based upon continuous steam generator blowdown.of

  • 10,000 pph (minimum) each.* Whenever the turbine/generator is synchronized all requirements of Table 4.3 including the Action Level Criteria shall apply. Prior to escalating power *above 35%, Normal Chemistry

_values shall be achieved.

The controlling parameters for 'Action Level 2 shall sodium, chloride and sulfate. The Action 2 value for cautibn conductivity need not be met if the for sodium, and sulfate are below the Action Level 2 limits. Plant operation with locatable condenser water leaks is not desirable.

When an identified condenser leak reaches approximately 0.1 gallon per minute, Plant power should be reduced for condenser leak location procedure.

,, e

  • 9 SECONDARY SYSTEM SAMPLING
  • 1.0 PURPOSE Proc No COP 11 Attachment 7 *Revision.

9* Page l of 3 This attachment describes the methods and precautions used in sampling the Steam Generators, Condensate Pump Discharge (CPD} and the Feedwater Pump Suction. REFERENCES 2.1 P&ID M-219, M-207, M-226 3.0 PRECAUTIONS 3.1 The high teinperatures and pressures of steam generator samples are reduced before the sample point. Insure cooling water is cut in to the sample cooler and.exercise caution when first obtaining a sample. 3.2 If a primary to secondary leak is suspected, the steam generator water should be treated 4.0 SAMPLE POINT LOCATIONS 4.1 STEAM GENERATOR,SAMPLES 4.1.1 *The sample points for the "A"and 11 8 11 .. Steam Generator bottom blowdown sample and the surface blowdown samples are located at *the **C-42 panel. Sample valve identification for "A" _Steam Generator is **SX-0771 and **SX-07.39 for bottom and surface blowdown samples, respectively.

Sample valve identification for 11 8 11 Steam Generator is **SX-0770 and **SX-0738 for bottom and surface blowdown sample, respectively.

4.1.2 Flush times for the sample lines (from blowdown *tank to.**C-42 panel) is approximately 31 minutes. 4.2 FEEDWATER PUMP SUCTION SAMPLES 4.2.1 The sample for feedwater is taken from the line of Feedwater Heaters **E-6A/**E-68.

This sample is routed to the **C-42 panel. **SX-0710 is the sample valve for Feedwater Heater.**E-68.

    • SX-0711 is the sample valve for Feedwater Heater **E-6A. At **C-.42 the sample valve for **E-6A is **V-35 and for **E-68, 4.2.2 Flush time for the.sample line (from Feedwater Heater **E-6A to **C-42) is approximately 30 minutes. Flush time for the sample line (from Feedwater Heater **E-68 to **E-68 to **C-42) is approximately 38 minutes. chll81-0070hl54-89

. ...,. SECONDARY SYSTEM SAMPLING 4. 3 CONDENSATE .PUMP DISCHARGE (

Pree No COP 11

  • Attachment 7 Revision 9 Page 2 of 3 4.3.1 The sample for the CPD is taken from the discharge side of the Condensate pumps. The sampie is routed to the **C-4l panel. **SX-0785 is the sample valve for CPD.* 4.3.2 Flush. time for the CPD sample line (from CPD to **EC-42) is approximately 11 minutes. 4.4 HEATER DRAIN SAMPLES 4.4.1 The sample for the heatet.drains is taken at the discharge of the Heater Drain Pumps The sample is routed to the **EC-42 panel. **SX-0788 is the.sample point for HOP **P-108. **SX-0787 is the sample point for HDP **P-lOA. 4.4.2 Flush time for the HOP sample lines (from HOP discharge to **EC-42) is 24 minutes. 4.5. AUXILLARY FEEOWATER SAMPLE POINTS 4.5.1 The sample for Auxiliary .Feedwater Pumps P-8A and P-88 is taken from the vent line on the discharge of P-8A. The manual valve number is FW-710. . 4.6 aLOWDOWN DIMINERALIZER. (T-104) SAMPLING 4.6.1 The influent sample for. the *slowdown Demineralizer (T-104) is taken at the C-42 panel. The sample point number SX-6007. cThe effluent sample point for T-104 is also at C-42. The sample point is SX-6008 *. 4.6.2 Flush.times
  • for these sample lines (from T-104 to C-42) is 20 minutes. 4.7 HOTWELL SAMPLE 4.7.1 Sample points located at the north and south ends of *the main condenser are used to determine which side .of the main condenser is leaking once a condenser leaking once a condenser leak has been determined.* .The North hotwell sample loca.tion is in the heater drain pump pit. The sample point is located between the two waterboxes.

The sample

  • identification is SX-729A. *
  • . ..,. SECONDARY SYSTEM SAMPLING Proc No COP .11 Attachment 7 Revision 9 Page 3 of 3 The south hotwell location is in the pit for the circulating water supply valves at the south end of the main condenser.

The sample point is located between the two waterboxes.

The sample identification point. is SX-7298. S.O SAMPLING Sample line flush times are determined such that three line volumes are circulated.

Samples should be obtained only.after minimum flush time has elapsed *. Sample flow should not be changed while filling the sample bot.tle.

... . SECONDARY SYSTEM CHEMICAL ADDITION 1.0 PURPOSE Proc No COP 11 Attachment 8

  • Revision 9 Page 1 of 3 This attachment describes the valving arrangements to accomplish chemical addition of morpholine and hydrazine to Main Feedwater, Turbine Hood Spray and Condensate Pump Discharge (CPD).

2.0 REFERENCES

2.1 P&ID M-220 3.0 PRECAUTIONS 3

  • 1 HYDRAZINE WARNING HYDRAZINE HAS BEEN SHOWN TO PRODUCE CANCER IN LABORATORY ANIMALS. Direct skin or eye contact produces burns. Vapors are irritating to eyes, nose and throat. See the Material Safety Data Sheet (MSDS), Reference 2.11 for this product. 3.2 MORPHOLINE.

Direct skin or eye contact causes severe burns. Vapors may be irritating to eyes, nose and throat. 3.3 *Adequate clothing (eg, go*gles, impervious gloves, boots and apron) shall be worn when handling the above See the MSDS for the above chemicals by referring to Reference 4.0 LIMITS See main body of procedure.

5.0 NORMAL CONTROL AND CORRECTIVE ACTION 5.1 CHEMICAL ADDITION Included in this attachment is a simplified diagram of the Feedwater Chemical Additio.n System. Specific valve lineups will be dependent on the desired concentrations of che'micals and equipment availability.

Therefore no valve lineups will be given this section.

  • SECONDARY SYSTEM CHEMICAL ADDITION 6.0 RECORDS AND ATTACHMENTS 6.1 RECORDS Proc No COP 11 Attachment 8 Revision 9 Page 2 of 3* Record all chemical additions in the appropriate log book in accordance with Reference 2.6. 6.2 ATTACHMENTS . . None SECONDAR'{

SYSTEM .ADDITION ! f ., ' l _, ;; . c:hll81-0070il54-89.

Pree No COP 11 Attachment 8 Revision 9 *page 3 of 3 .. **-******----****

  • -Ii iQ ;t 5 *. Iii I i .. s
  • a; c ; v I I i I
  • Ii " . . . * *
  • I % ! l i t c *
  • cO I . i ' *
  • i r . I . J * . i i *-... -. .

BORIC ACID CONDITIONING OF STEAM GENERATORS 1.0 PURPOSE Proc No COP 11° . Attachment 9 Revision 9 Page 1 of 4 This attachment describes the method and precautions to be used in conditioning the.

Generators with Boric Acid during startup and subsequent Plant operation.

Boric acid soaks are to be used.when returning to power operation following a long term shutdown.

2.0 REFERENCES

2.1 EPRI Steam Generator Owners Group -PWR Secondary Water Chemistry Guidelines, Revision 1, June 1984 Appendix A 2.2 EPRI Steam Generator OwnE!rS Group -Implementation of Boric Acid in the Field -.Indian Point Unit 3 Plant, EPRI-NP-3066 Project Sll6-l Appendix A, Boric Acid Conditioning Procedure 2.3 EPRI Report NP-5558, "Boric Acid Application Guidelines for Intergranular Corrosion Inhibition" 3.0 PRECAUTIONS 3.1 Boron levels must be blown down to limits listed in main body Table 4.1 prior to going to cold shutdown.

This will minimize low pH corrosion attack of carbon steel or Inconel 600. 3.2 Boric Acid mix tank concentration

_must be maintained below 6% to prevent crystallization of the Boric Acid in the feed lines and tank. 3.3 It is essentiai to the success of the conditioning operation that the Borori concentration be to 50 ppm as quickly as possible.

3.4 All chemistry parameters must be closely monitored during each conditioning phase.* The s*econdary side chemistry

_is to be within the specified guidelines.

4.0 PREREQUISITES 4.1 Plant should be in cold shutdown prior to Boric Acid Soak. 5.0 PROCEDURE 5.1 PHASE I -DRAINING AND FILLING OF STEAM GENERATORS 5.1.1 Steam Generators should be drained and refilled per MSS0-2 and MSS0-3. Upon initiating the Steam Generator

_fill, the oxygen concentration of the fill water should be determined.

If greater than 100 ppb oxygen is detected, additional hydrazine should be added to provide a minimum residual in the initial fill of 75 ppm hydrazine

Proc. No COP l l Attachment 9 Revi_sion 9

  • Page 2 of 4 S.l.2 Boric Acid addition should be started upon initiation of the Steam Generator fill via the Slug Feed Chem Add System (T-3S), see Attachment
8. Boric Acid concentration should be increased-to SO ppm. S.2 PHASE II -_HEATUP (PRIOR.TO HOT.STANDBY)

S.2.1 Start heatup of reactor coolant system. Confirm boron concentration.

Adjust addition rate as _required to maintain approximately SO ppm in the Steam Generator blowdown.

S.2.2. Steam Generator blowdown should continue at the maximum permissible rate, as determined by Plant conditions.

S.2.3 Frequent analysis should be performed to identify the occurrence of any chemical release phenomena.

If chemical release is detected, heatup should be suspended*

until cleanup is effected.

See Table 4i2 for 1 i"mit s. . S.2.4 Oxygen concentration in the makeup water to the Steam Generators during this period should be identical to that used in the initial fill. See Section S.1.1 S.3 .PHASE III -HEATUP (HOT STANDBY) S.3.1 Heat up is to *continue until hot standby conditions are reached maintaining SO ppm boron in Steam Generator blowdown.

S.3.2 If necessary, blowdown at maximum rate until chlorides and other impurities are less than Table 4.2 non soak limits _and Table S.l if in Boric Acid Soak. S.3.3 Maintain hydrazine residual in Steam Generator blowdown per Attachment 4, Table 4.2. S.4 PHASE IV -POWER ESCALATION S.4.1 Establish 10-20 ppb hydrazine residual in feedwater using normal chem add sys t_em. NOTE: If pH requirements are not met, the addition of morpholine may be .necessary.

S.4.2 .

concentrations be maintained at SO ppm by using chem add system. Major Boric Acid addition can be made via the slug feeder if the boron concentration drops below 30 ppm.

5.5 5.5.l 5.5.2

  • Revision 9 Page 3 of 4 Power shall be held at 35 percent. Maintain power and Boron concentration for 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br />, monitoring the and operating.

parameters throughout.

Establish the Steam Generator boron* demand after 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> into s6ak as outlined in the following steps: a. Determine boron concentration in the Steam Generator blowdown then

b. After a minimum of 6 additional hours (54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> cumulative) determine boron concentration in the blowdown.
c. If boron at T = 6 > than 90%, demand is satisfied.

boron at T = 0 Where: T ::d 6 is the boron concentration 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after sec_uring boron addition and T = 0 is the boron concentration at the time of securing the

d. Resume addition to maintain 50+/-5 ppm. boron *. e. After 30 additional hours (84 cumulative hours in to soak), repeat Steps a through c. _If boron accountability is greater than 90%,* resume for 6 more hour_s to complete treatment.

However, if boron accountability is less than 90%

to Step f. f. Resume until demand is staisf ied (greater than 90%

repeating Steps a through c. 5.6 PHASE VI -BORIC ACID CONTINUOUS ADDITION DURING POWER OPERATION 5!6.1 At the of the low soak, terminate boric acid addition.

Allow. the blowdown boron concentration to decrease to 5-10 ppm before increasing power above 35%.

Once 5-10 ppm boron is in the Steam it can be maintained through the normal chem add system. Upon return to *power operation following a short term shutdown, boron concentratiqn should be maintained at 5-10 A 96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> Boric Acid Soak is only necessary when coming from cold shutdown after a long term shutdown.

chll81-0070jl54-89

<4 >4 Boron (ppm) . 30-50 <30, >50 NOTES: TABLE 5 .1. 1. All other limits are as Attachment 4, Table 4.2 chll81-0070jl54-89 Proc No COP 11 Attachment 9 Revision 9 Page 4 of 4 D

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