Text

Rev 4 to Chemistry Operating Procedure COP 11, Secondary Sys Chemistry
	ML18051B497
Person / Time
Site:	Palisades
Issue date:	07/31/1985
From:	Hillman C; CONSUMERS ENERGY CO. (FORMERLY CONSUMERS POWER CO.)
To:	;
Shared Package
ML18051B496	List: ML18051B495; ML18051B497;
References
	COP-11, NUDOCS 8508070347
	Download: ML18051B497 (30)
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ATTACHMENT 3 Consumers Power Company Palisades Plant Docket 50-255 PALISADES PLANT CHEMISTRY OPERATING PROCEDURE COP-11, "SECONDARY SYSTEM CHEMISTRY July 31, 1985 8508070347 850731

j

.~DR *. ADOCK 0500025_5 i....

f>DR. __..,.. ~--"'

29 Pages MI0785-0252-NL04

1.

Prepared

--~"T'~~

Originator PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE Revision and Approval Summary TITLE:

SECONDARY SYSTEM CHEMISTRY

2.

QA Concurrence

3.

Recommend Approval/Q-List No

4.

PRC Reviewed

~Head

5.

Approved

6.

ATMS Incorporated 1./"J-1/f(;"

'Date Biennial Review Date 1181-0070kl54-89 Proc No COP 11 Revision 4 Date 6/28/85 1.k/PS Date It-t.8-BST'-8 Date I

PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE:

SECONDARY SYSTEM CHEMISTRY Table of Contents 1.0 PURPOSE

2.0 REFERENCES

SAMPLING AND ANALYSIS 3.0 4.0 LIMITS AND SPECIFICATIONS 4.1 ACTION LEVELS 4.1.1 Action Level 1 4.1.2 Action Level 2 4.1.3 Action Level 3 4.2 LIMITS 5.0 NORMAL CONTROL AND CORRECTIVE ACTION 5.1 pH..

5.1.l Normal Control 5.1.2 Corrective Action 5.2 CATION CONDUCTIVITY 5.2.1 Normal Control.

5.2.2 Corrective Action 5.3 CONDUCTIVITY.

5.3.1 Normal Control 5.3.2 Corrective Action 5.4 DISSOLVED OXYGEN 5.4.1 Normal Control.

5.4.2 Corrective Action ch1181-0070jl54-89 Proc No COP 11 Revision 4 Page i 1

1 1

2 2

2 3

3 3

3 4

4 4

4

PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE:

SECONDARY SYSTEM CHEMISTRY Table of Contents 5.5 HYDRAZINE 5.5.1 Normal Control 5.5.2 Corrective Action 5.6 SODIUM.

5.6.1 Normal Control 5.6.2 Corrective Action 5.7 CHLORIDE..

5.7.1 Normal Control 5.7.2 Corrective Action 5.8 SILICA.

5.8.1 Normal Control 5.8.2 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 5.10.1 Normal Control 5.10.2 Corrective Action 5.11 CONDENSATE STORAGE TANK CONTAMINATION LIMITS 5.11.1 Normal Control 5.11.2 Corrective Action 5.12 STEAM GENERATOR NITROGEN PURGE

5. 12. 1 Normal Control chl181-0070j154-89 Proc No COP 11 Revision 4 -

Page ii 4

4 5

5 5

5 6

6 6

PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE Proc No COP 11 Revision 4 Page iii TITLE:

SECONDARY SYSTEM CHEMISTRY Table of Contents Page 5.12.2 Corrective Action 7

5.13 SULFATE 7

5.13.1 Normal Control 7

5.13.2 Corrective Action 7

5.14 ORGANICS.

7 5.14.1 Normal Control 7

5.14.2 Corrective Action 7

6.0 RECORDS AND ATTACHMENTS 8

6.1 RECORDS 8

6.2 ATTACHMENTS 8

ATTACHMENTS, Table 3.1 "Secondary System Sample and Analysis Sched4le:

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

Cold Shutdown", Table 3.2 "Secondary System Sample and Analysis Schedule:

Hot Standby and Hot Shutdown", Table 4.2 "Secondary System Chemistry Levels:

Hot Standby and Hot Shutdown", Table 3.3 "Secondary System Sample and Analysis Schedule:

Power Operation", Table 4.3 "Secondary System Chemistry Levels:

Power Operation", "Secondary System Sampling", "Secondary System Chemical Additions" chll81-0070jl54-89

1.0 PURPOSE PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE:

SECONDARY SYSTEM CHEMISTRY Proc No COP 11 Revision 4 Page 1 of 8 This procedure establishes the guidelines for maintaining proper chem-istry conditions in the Secondary System.

This procedure shall con-trol in the event of conflicts between it and other Plant documents, except for incorporated Technical Specification requirements.

In order to deviate from this procedure, the Plant Manager's approval is required.

2.0 REFERENCES

2.1 P-CE-3909, April 16, 1974 2.2 CENPD-28 2.3 EPRI Steam Generator Owners' Group - PWR Secondary Water Chemistry Guidelines, September 1981 2.4 Technical Specification 3,18, 3.1.5.c, Table 4.2.1 2.5 Technical Specification Table 4.2.1 2.6 Chemistry Procedure CH 1.5, "Chemistry Operating Logs, Records, Graphs, Data_ Management" 2.7 E-PAL-81-095A; D-PAL-81-095; RHK83*137 3.0 SAMPLING AND ANALYSIS Sampling and analysis frequencies for Secondary System are specified 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.

4.0 LIMITS AND SPECIFICATIONS The chemistry values stated in Attachments 2, 4 and 6 shall be adhered to in order to assure long-term Secondary System equipment reliabil-ity.

These values reflect current understanding of the role of chem-ical transport, impurity concentrations, material selection, corrosion behavior and industry practice for the operation, maintenance and in-tegrity of steam generator systems.

Failure to maintain these limits may reduce long-term Secondary System equipment reliability.

4.1 ACTION LEVELS Three action levels for power operation are established and shall be used to initiate remedial action when monitored parameters are con-firmed (ie, verified by an additional sample and analysis) to be outside the normal operating value.

They are as follows:

chl181-0070al54-89

4.1.1 4.1.2 4.1.3 Action Level 1

a.

Objective e

PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE:

SECONDARY SYSTEM CHEMISTRY Proc No COP 11 Revision 4 Page 2 of 8.

Promptly identify and correct the cause of an off-normal value without power 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 value range within 1 week following confirmation of excursion, be at approximately 30%

power within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by initiating a controlled power reduction.

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 approximately 30%

within eight hours of confirmation of Action Level 2.

2.

Return parameters to within normal value range within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in hot standby within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by initiating a controlled power reduction.

Action Level 3

a.

Objective Prevent rapid steam generator corrosion during continued oper-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 primary coolant temperatures ~an be expected.

chll81-0070al54~89

9 e

PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE:

SECONDARY SYSTEM CHEMISTRY Proc No COP 11 Revision 4 Page 3 of 8 4.2 LIMITS s.o 5.1 5.1.1 5.1.2 NOTE:

5.2 5.2.1 5.2.2 Limits on the steam generator chemistry parameters are specified in Plant Technical Specifications.

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

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 hydrazine.

The steam jet air ejector after condenser drain is normally routed to waste.

Corrective Action High secondary 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 and lower pH.

This.only applies when the heating system is on extraction 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 malfunction).

Chemical feed of morpholine should be increased to maintain pH limits.

Prompt action must be taken to terminate any impurity ingress.

CATION CONDUCTIVITY Normal Control Normal control is exercised by maintaining low levels of condenser air/water leakage, maintaining proper makeup water quality and continuous steam generator blowdown.

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

To determine the source 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 chll81-0070al54-89

5.3 5.3.1 PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE:

SECONDARY SYSTEM CHEMISTRY

d.

North and South Condenser Hotwell Samples

e.

T104 Effluent (Steam Generator Blowdown Demineralizer)

Proc No COP 11 Revision 4 Page 4 of 8

f.

Local Condensate Pump Discharge (To Check CPD Sample Cooler Leakage)

g.

Heating Boiler Condensate Receiver Tanks (If Routed To Condenser Hotwell)

h.

Feed Pump Condensate Receiver Tanks

i.

Blowdown Heat Exchanger Outlet

j. Heater Drain Pump Discharge (HDP 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 air ejector drains (**E-8 After Condenser Drain) and steam generator

- ** - * * * * * - * * *

blowdown.

5.3.2 5.4 5.4.1 Corrective Action High steam increasing impurity.

controlled generator (impurity caused) conductivity may be reduced by steam generator blowdown and isolating the source of High conductivity due to excessive additives may be by reducing additive feed rate.

DISSOLVED OXYGEN Normal Control Oxygen ingress into the Secondary System is controlled by maintaining low levels of condenser air inleakage.

5.4.2 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.

5.5 HYDRAZINE 5.5.1 Normal Control Normal control of system hydrazine levels is by changing hydrazine feed rates.

chll81-0070a154-89

5.5.2 5.6 5.6.1 5.6.2 PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE:

SECONDARY SYSTEM CHEMISTRY Corrective Action Proc No COP 11 Revision 4 Page 5 of 8 Hydrazine concentrations are adjusted by varying the hydrazine addition rate.

SODIUM Normal Control Normal control of steam generator sodium is exercised by controlling makeup quality, controlling condenser inleakage and steam generator blowdown.

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.

5. 7 CHLORIDE 5.7.1 Normal Control Normal control of steam generator chloride is exercised by controlling makeup quality, controlling condenser inleakage and steam generator blowdown.

Steam generator blowdown may be increased to reduce chloride level.

5.7.2-Corrective Action 5.8 5.8.1

. 5.8.2 5.9 5.9.1

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

SILICA Normal Control Normal control of silica is by steam generator blowdown and control of makeup water quality.

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

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

Air ejector off-gas ch1181-0070a154-89

5.9.2 e

PALISADES NUCLEAR PLANT

. CHEMISTRY OPERATING PROCEDURE TITLE:

SECONDARY SYSTEM CHEMISTRY Proc No COP 11 Revision 4 Page 6 of 8 flow rate should normally be 5-10 cfm or less.

Readings greater than 10 cfm are abnormally high and should result in corrective action.

Corrective Action Use of the freon leak detector system is recommended for leak location.

Helium leak detection may also be used for leak location.

Helium leak detection is more sensitive and will permit location of smaller leakage sources.

5.10 CHEMICAL HIDEOUT AND RETURN

5. 10. 1 Normal Control 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 tank contamination is by control of hot well and makeup quality.

5.11.2 Corrective Action Corrective action for condensate storage tank contamination is to isolate the impurity source and also partial tank drain and fill steps.

5.12 STEAM GENERATOR*NITROGEN PURGE 5.12.1 Normal Control NOTE:

During long-term cold shutdown (greater than three days) a nitrogen purge of the gas space should be established in the steam generators, in order to minimize the corrosive effects of oxygen.

The bottom blowdown lines should normally be used for nitrogen feed to the Steam Generator not on recirculation.

Nitrogen purge is normally secured to the Steam Generator on recirculation.

Nitrogen purge with no detect-able oxygen present must be established before lowering the Steam Generator water level such that Steam Generator tubes are uncovered.

Nitrogen purge could be interrupted by maintenance, inspection, etc, of the secondary side of the steam generators, main steam lines and ch1181-0070a154-89

PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE:

SECONDARY SYSTEM CHEMISTRY Proc No COP 11 Revision 4 Page 7 of 8 other components which are normally nitrogen purged during cold shut-down.

Sampling of the gas space may be suspended during this time.

5.12.2 Corrective Action Reestablish 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).

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.

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 generators.

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.

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.

Organics intrusion sources are such things as resins (blowdown demin), lubricating oils (feedwater pumps) or non-ionic organics introduced through the makeup system.

5.14.2 Corrective Action Confirmed increases in Steam Generator organics contamination may be reduced by increasing Steam Generator blowdown and isolating the source of impurity.

chl181-0070a154-89

e PALISADES NUCLEAR PLANT CHEMISTRY OPERATING PROCEDURE TITLE:

SECONDARY SYSTEM CHEMISTRY Proc No COP 11 Revision 4 Page 8 of 8 6.0 RECORDS AND ATl'ACHMENTS 6.1 RECORDS 6.2 6.2.1 6.2.2 6.2.3 6.2.4 6.2.5 6.2.6 6.2.7 6.2.8 Records of chemical analysis of the Secondary System should be re-corded in the Cold Lab Logbook in accordance with Reference 2.6.

Ganuna spectrums shall normally be stored on the magnetic tape acces-sory to the multichannel analyzer.

The paper printout may be substi-tuted when the magnetic tape is not available.

Selected analyses from the Secondary System shall be recorded on the Secondary Chemistry Data Sheet.

Chemical additions to the Secondary System should be recorded in the Cold Lab Logbook in accordance with Reference 2.6.

ATl'ACHMENTS, Table 3.1 "Secondary System Sample and Analysis Schedule:

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

Cold Shutdown", Table 3.2 "Secondary System Sample and Analysis Schedule:

Hot Standby and Hot Shutdown", Table 4.2 "Secondary System Chemistry Levels:

Hot Standby and Hot Shutdown", Table 3.3 "Secondary System Sample and Analysis Schedule:

Power Operation", Table 4.3 "Secondary System Chemistry Levels: Power Operation", "Secondary System Sampling", "Secondary System Chemical Additions" chll81-0070a154-89

TABLE 3.1 Secondary System Sample and Analysis Schedule:

Cold Shutdown4 Feedwater Heaters 1 Dry Lay-Up Wet Lay-Up Auxiliar~ Feedwater Parameter (Pref /Req)

(Pref/Req)

(Pref/Req) pH NR W/NR 2/NR Conductivity NR W/NR 2/NR Hydrazine NR W/NR 2/NR Sodium NR NR/NR 2/NR Dissolved Oxygen NR W/NR 2/NR Phosphate NR NR/NR NR/NR Sulfate NR NR/NR NR/NR Chloride NR W/NR 2/NR NOTES:

TABLE 3.1 Steam Proc No COP 11 Revi.sion 4 Page 1 of 2 Generators5 (Both)

(Pref/Req) 4 3/NR 3/NR 3/NR 3/NR 3/NR W/NR W/NR 3/NR

1.

Dry lay-up of the feedwater 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).

2.

Auxiliary feedwater should be sampled daily when being used to supply water to the steam generators.

3.

Technical Specifications required sample/analysis frequencies are controlled by the Technical Specifications Surveillance Test Program.

4.

Cold shutdown conditions exist when PCS temperature is < 210°F.

5.

Assumes recirculation is achievable.

6.

Nitrogen purge may be interrupted during cold shutdown because of maintenance, inspections, etc.

Sampling may be suspended during this time.

Key:

W = Once Per Week; 3 = Three Times Per Week; NR = Not Required chll81-0070bl54-89 I"".(.

e

Parameter Gross Gamma Humidity Oxygen (Gas Space)

Nitrogen (Gas Space)

NOTES:

TABLE 3.1 TABLE *3.1 Secondary System Sample and Analysis Schedule:

Cold Shutdown4 Feedwater Heaters 1 Dry Lay-Up Wet Lay-Up Auxiliary Feedwater (Pref /Req)

(Pref /Req)

NR NR/NR NR/NR W/NR NR/NR NR/NR NR NR/NR NR/NR NR NR/NR NR/NR Steam Proc No COP 11 Revision 4 Page 2 of 2 Generators 5 (Both)

(Pref/Req) 4 W/3 NR/NR 3/6 3/6

1.

Dry lay-up of the feedwater beaters (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).

2.

Auxiliary feedwater should be sampled daily when being used to supply water to the steam generators.

3.

Technical Specifications 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 conditions exist when PCS temperature is < 210°F.

5.

Assumes recirculation is achievable.

6.

Nitrogen purge may be interrupted during cold shutdown because of maintenance, inspections, etc.

Sampling may be suspended during this time.

Key:

W = Once Per Week; 3 = Three Times Per Week; NR = Not Required ch1181-0 1154-89

Proc No COP I}:..

i Revision 4 Page I of I TABLE 4.1 Secondary System Chemistry Limits:

Cold Shutdown (Administrative Limits)

Steam Generators 2 (Both)

Parameter Feedwater (Wet Lay-Up)

Normal Value Auxiliary Feedwater Normal Value Normal Value Initiate Action Prior to Heatup pH 9.3-10.0 9.6-10.2

<9.6, >10.2 9.5-10.0 Conductivity (µmho/cm)

<20.0

µmho/cm Hydrazine (ppm) 50-100 75-200

<75, >200 20-50 1 Sodium (ppb)

<1000

>1000

<1000 Dissolved Oxygen (ppb)

<30

>30

<30.0 Oxygen (Gas Space)

>1%

Sulfate (ppb)4

<100

>1000

<100 NOTES:

TABLE 4.1 I.

The limits listed 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 generator recirculation and the above chemistries should be implemented for cold shutdowns of three days, or longer, planned length.

2.

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 do not apply if recirculation and T-104 demineralizer are not available.

The normal limits should be achieved before recirculation is secured.

3.

At all times, the steam generator water level will cover the entire steam generator tube bundle except when drained per HSS0-2 or HSS0-3.

4.

Sulfate values of less than 1000 ppb apply only if an instrument is readily available for measurement in this range.

chll81-0070cl54-89

TABLE 3.2 Secondary System Sample and Analysis S.chedule:

Hot Standby 1 ' 5 Auxiliary Condensate4 Feedwater2 Feedwater2 Parameter Procedure (Pref/Req)

(Pref/Req)

(Pref /Req) pH CH 4.1 S/NR S/NR S/NR Conductivity CH 4.2 S/NR S/NR S/NR Cation Conductivity CH 4.2 D/NR D/NR NR/NR Hydrazine CH 4'. 7 D/NR S/NR S/NR Dissolved.Oxygen CH 4.5A-D S/NR S/NR S/NR Sodium CH 4.33 D/NR NR/NR D/NR Chloride CH 4.48 NR/NR NR/NR NR/NR CH 4.56 Phosphate CH 4.56 NR/NR NR/NR NR/NR Sulfate CH 4.9 NR/NR NR/NR NR/NR CH 4.56 NOTES:

TABLE 3.2

1.

This table is applicable when PCS temperature is >210°F and reactor power is <2%.

Proc No Cuc 11*

Revision 4 Page 1 of 2 Steam Generators (Pref/Req)

S/3 S/3 S/NR S/NR S/NR D/3 D/NR D/NR D/NR

2.

Feedwater sample/analysis frequency is applicable only when the steam generators are being supplied via the Main Feed Pumps P-IA 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 Program, 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 Week chll81-0070d154-89

Proc No COP 11 Revision 4 Page 2 of 2 TABLE 3.2 Secondary System Sample and Analysis Schedule:

Hot Standby 1 tS Auxiliary Condensate4 Feedwater2 Feedwater2 Steam Genera.tors Parameter Procedure (Pref/Req)

(Pref /Req)

(Pref/Req)

Gross Gaouna CH 5.4 NR/NR NR/NR NR/NR 3/3 Silica CH 4.12 NR/NR NR/NR NR/NR 3/NR Iron CH 4.33 D/NR D/NR D/NR 3/NR Copper CH 4.33 D/NR D/NR NR/NR 3/NR Dose Equivalent DWC-4 NR/NR NR/NR NR/NR W/3 Iodine Calcium CH 4.33 W/NR NR/NR NR/NR D/NR Magnesium CH 4.33 W/NR NR/NR NR/NR D/NR NOTES:

TABLE 3. 2

1.

This table is applicable when PCS temperature is >210°F and reactor power is <2i.

2.

Feedwater sample/analysis frequency is applicable only when the steam generators are being supplied via the Hain ~eed Pumps P-IA or P-lB.

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 frequ~ncies are controlled by the Technical Specifications Surveillance Test Program, 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 Week; W = Once per Week chll8 70d154-89 e

TABLE 4.2 Proc no COP 11 Re.vision 4 Page 1 of 1 Secondary System Chemistry Limits:

Hot Standby (Administrative Limits) 2 Parameter pH Conductivity (µmho/cm)

Cation Conductivity

(µmho/cm)

Dissolved Oxygen (ppb)

Hydrazine (ppb)

Sodium {ppb)

Chloride (ppb)

Sulfate (ppb)s Iron (ppb)

Copper {ppb)

NOTES:

TABLE 4.2 Condensate Normal Value 8.5-9.2

<20 1.Sx 02

<SO

<100

<100 Feedwater Auxiliary Normal Normal Value Value 8.5-9.2

<20

<20 1.Sx 02 Feedwater Steam Generators (Both)

Initiate Normal Initiate Value Prior to Action Value 4 Action Power E*calation3 8.5-9.3

<8.8, >9.3 8.8-9.2

<2

>2

<2.0

>20

<10.0

>10.0 I

<l.Sx 02 (10.-50.

<IO., >SO. ]@>soo°F

[>500

<500, >4000]@<500°F

<100.0

>100.0

<100.0

>100.0

<100.0

<500

>1000

<100

1.

This table is applicable when PCS temperature is >200°F and reactor power is ~2%.

2.

The limits in this table are administrative limits.

Technical Specifications limits are controlled by the Technical Specifications Surveillance Test Program, Procedure DWC-4.

3.

These limits are to be achieved prior to escalating Plant power above 2%.

4.

Normal limits should be met within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 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.

S.

Sulfate values of less than 1000 ppb apply only if an instrument is readily available for measurement in this range.

chl181-0070el54-89 e

Change No I} *f'S-()73 TEMPORARY CHANGE TO A PROCEDURE Proc No 10.41 Revision 4 Page 1 of 2 Change Date ~7~--l_.2~*~i_5~- Expiration Date /() -J,2-f.:J-Procedure Type Q,0?

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Proc No COP 11 Revision 4 Page 1 of 3 TABLE 3.3 Secondary System Sample and Analysis Schedule:

Power Operation 1 Condensate Feedwater2 Steam Generators Parameter Procedure (Pref/Req)

CST (Pref/Req)

(Pref/Req) pH CH 4.1 S/NR W/NR S/NR s;s Conductivity CH 4.2 S/NR W/NR S/NR S/3 Cation Conductivity CH 4.2 D/NR NR/NR D/NR D/NR Ammonia CH 4.-8A,B 3/NR 3/NR 3/NR 3/NR Morpholine CH 4.10 3/NR 3/NR 3/NR 3/NR Hydrazine CH 4.7 S/NR D/NR S/NR S/NR Dissolved Oxygen CH 4.58,C S/NR W/NR S/NR NR/NR Sodium CH 4.33 D/NR D/NR NR/NR S/3 NOTES:

TABLE 3. 3

1.

This table is applicable when reactor power is >2%.

2.

The feedwater sample is obtained for "A" or "B" 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 DWC-4.

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 GaDBDa Spectral Analysis.

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

Proc No COP 11 Revision 4 Page 2 of 3 TABLE 3.3 Secondary System Sample and Analysis Schedule:

Power Operation 1 Condensate Feedwater2 Steam Generators Parameter Procedure (Pref /Req)

CST (Pref/Req)

(Pref /Req)

Chloride CH 4.4B NR/NR W/NR W/NR D/NR CH 4.56 Iron CH 4.33 W/NR W/NR W/NR W/NR Copper CH 4.33 W/NR W/NR W/NR W/NR Silica CH 4.12 NR/NR NR/NR NR/NR 3/NR Gross Gaouna CH 5.4 NR/NR W/NR5 NR/NR 3/3 CH 4.39 Dose Equivalent DWC-4 NR/NR NR/NR NR/NR W/3 Iodine Magnesium CH 4.33 S/NR W/NR D/NR D/NR NOTES:

TABLE 3.3

1.

This table is applicable when reactor power is >2%.

2.

The feedwater sample is obtained for "A" or "B" 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 DWC-4.

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.

Key:

S = Once Per Shift; D = Once Per Day; W = Once Per ~eek; 3 = Three Times Per Week; NR = Not Required; M = Once Per Month ch

-0070f154-89 e

TABLE 3.3 Secondary System Sample and Analysis Schedule:

Power 0peration 1 Condensate Feedwater2 Parameter Procedure (Pref/Reg)

CST (Pref /Reg)

Sulfate CH 4.9 NR/NR D/NR NR/NR CH 4.56 Calcium CH 4.33 W/NR.

W/NR NR/NR Phosphate CH 4.56 NR/NR NR/NR NR/NR Organics 4

M/NR M/NR M/NR NOTES:

TABLE 3.3

1.

This table is applicable when reactor power is >2%.

Proc No COP 11 Revision 4 Page 3 of _3 Steam Generators (Pref/Reg)

D/NR W/NR W/NR M/NR

2.

The feedwater sample is obtained for "A" or "B" 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 DWC-4.

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.

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 ch1181-0070f154-89

Parameter pH TABLE 4.3

... I,,

~.

. Pro" no COP l l

Attachment 6 *~

Revision 4*

Page 1 of 3 Secondary System Chemistry Limits:

Power Operation (Administrative Limits) 2 Normal Value Condensate Action Level 1

2 3

Feedwater Normal Action Level Value 1

2 3

8.8-9.3

<8.8

>9.3 Steam Generators (Both)

Normal Action Level Value 1

2 3

8.8-9.3

<8. 8" <8.5

>9.3 >9.5 Cation Conductivity4

(µmho/cm)

<0.8

>0.8

>2.0

>7.0 Sodium (ppb) 4

<20

>20.0

>100.0 Chloride. (ppb) 4

<20

>20.0

>100.0 Sili!=a (ppb)

<300

>300.0 I

Oxygen (ppb)

<10.0

>10.0

>30.0 >100.

<5.0

>5.0 Hydrazine (ppb) 1.5 x 02 10.-20.

<10.0 10.-20.

<10.0 Organics (ppm)

<5

<5 NOTES:

TABLE 4.3

1.

This table is applicable when reactor power is above 2%.

2.

The limits in this table are administrative limits.

Technical Specifications limits are controlled by the Technical Specifications Surveillance Test Program, Procedure DWC-4.

3.

The above limits are based upon a continuous steam generator blowdown of 10,000 pph (minimum) each.

>500.0 I I

4.

After start-up, maintain Plant power at <35% until Action Level 2 parameter limits are established.

1 Normal value limits should be met within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months of start-up (T G Synchronizing).

The controlling parameters for Action Level 2 shall be sodium, chloride and sulfate.

The Action L~vel 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 condenser water leaks is ~ot desirable.

When an identified condenser_

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

dfll81-0070g-93-89

I Parameter TABLE 4.3 Proc No COP 11 Revision 4 Page 2 of 3 Secondary System Chemistry Limits:

Power Operation (Administrative Limits) 2 Normal Value Condensate Action Level 1

2 3

Normal Value Feedwater Action Level~

1 2

3 Steam Generators (Both)

Normal Action Level Value 1

3 Sulfate (ppb) 4 Magnesium (ppb)s

<20

>20 2

>100 e

<0.05

>0.05

>0.1

>2.0 NOTES:

TABLE 4. 3

1.

This table is applicable when reactor power is above 2%.

2.

The limits in this table are administrative limits.

Technical Specifications limits are controlled by the Technical Specifications Surveillance Test Program, Procedure DWC-4.

3.

The above limits are based upon a continuous steam generator blowdown of 10,000 pph (minimum) each.

4.

After start-up, maintain Plant power at <35% until Action Level 2 parameter limits are established.

Normal value limits should be met within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months of start-up (T G Synchronizing).

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 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.

chl181*

'.>gl54-89

I;.

I Proc No COP :U Attachment* 6 Revision 4.

Page 3 of 3 TABLE 4.3 Secondary System Chemistry Limits:

Power Operation (Administrative Limits)2 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)

<2

>30.

>75.0

>1940.

SJAE Off-Gas (cfm)

<8.0 10.0 Sulfate ppm

<0.5

>0.5

>I.O

>5.0 NOTES:

TABLE 4.3

1.

This table is applicable when reactor power is above 2%.

2.

The limits in this table are administrative limits.

Technical Specifications limits are controlled by the Technical Specifications Surveillance Test Program, Procedure DWC-4.

3.

The above limits are based upon a continuous steam generator blowdown of 10,000 pph (minimum) each.

4.

After start-up, maintain Plant power at <3S% until Action Level 2 parameter limits are established.

Normal value limits should be met within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months of start-up (T G Synchronizing).

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.

S.

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.

dfll81-0070g-93-89

t I

'r SECONDARY SYSTEM SAMPLING 1.0 PURPOSE Proc No COP 11 Revision 4 Page 1 of 2 This attachment describes the methods and precautions used in sampling -

the Steam Generators, Condensate Pump Discharge (CPD) and the Feedwater Pump Suction.

2.0 REFERENCES

2.1 P&ID M-219, M-207, M-226 3.0 PRECAUTIONS 3.1 The high temperatures 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 as radioactive.

4.0 SAMPLE POINT LOCATIONS 4.1 STEAM GENERATOR SAMPLES 4.1.1 The sample points for the "A" and "B Steam Generator bottom blowdown sample and the surface blowdown samples are located at the **EC-42 panel.

Sample valve identification for "A" Steam Generator is

~-ksX-0771 and ;"*SX-0739 for bottom and surface blowdown samples, respectively.

Sample valve identification for "B" 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 **EC-42 panel) is approximately 31 minutes.

4.2 FEEDWATER PUMP SUCTION SAMPLES 4.2.1 The sample for feedwater is taken from the bypass line of Feedwater Heaters **W06A/~'"*E-6B. This sample is routed to the ~'"*EC-42 panel.

- SX-0710 is the sample valve for Feedwater Heater ~'"*E-6B.

1ri;SX-0711 is the sample valve for Feedwater Heater ~"*E-6A.

4.2.2 Flush time for the sample line (from Feedwater Heater **E-6A to

- EC-42) is approximately 30 minutes.

Flush time for th.e sample line (from Feedwater Heater **E-6B to **E-6B to **EC-42) is approximately 38 minutes.

chll81-0070h154-89

SECONDARY SYSTEM SAMPLING 4.3 CONDENSATE PUMP DISCHARGE (CPD)

Proc No COP !11 '

Revision 4 Page 2 of 2 4.3.1 The sample for the CPD is taken from the discharge side of the after Condenser Cooler (**E-8).

The sample is routed to the **EC-42 panel.

- SX-0785 is the sample valve for the 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 heater drains is taken at the discharge of the Heater Drain Pumps **P-lOA/**P-lOB.

The sample is routed to the

- EC-42 panel.

- SX-0788 is the sample point for HOP **P-lOB.

- SX-0787 is the sample point for HOP **P-lOA.

4.4.2 Flush time for the HOP sample lines (from HOP discharge to **EC-42) is approximately 24 minutes.

5.0 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 changes while filling the sample bottle.

chl181-0070h154-89

c SECONDARY SYSTEM CHEMICAL ADDITION 1.0 PURPOSE Proc No COP 11 Revision 4 Page 1 of 2 This attachment describes the valving arrangements to accomplish chemical addition of morpholine and hydrazine to Hain Feedwater, Turbine Hood Spray and Condensate Pump Discharge (CPD).

2.0 REFERENCES

2. 1 P&ID H-220 3.0 PRECAUTIONS

3. 1 HYDRAZINE Direct skin or eye contact produces burns.

Vapors are irritating to eyes, nose and throat.

3.2 HORPHOLINE Direct skin or eye contact causes severe burns.

Vapors may be irritating to eyes, nose and throat.

3.3 Adequate protective clothing (eg, goggles, impervious gloves, boots and apron) shall be worn when handling the above chemicals.

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 Addition System.

Specific valve lineups will be dependent on the desired concentrations of chemicals and equipment availability.

Therefore no valve lineups will be given in this section.

6.0 RECORDS AND ATTACHMENTS 6.1 RECORDS Record all chemical additions in the appropriate log book in accordance with Reference 2.6.

6:2 ATTACHMENTS None chl181-0070il54-89

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2.0 REFERENCES

2.0 REFERENCES

2.0 REFERENCES

2.0 REFERENCES

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