POWER NO PROC - NRC: Home PageDIABLO CANYON POWER PLANT NO OPERATING PROC F r, TITLE: CHEMICAL CONTROL LIMITS ~ 4 SCOPE This procedure specifies the chemical control operating 1imits

PACIFIC GAS AND ELECTRIC COMPANYNUCLEAR GENERATION DEPARTMENT

DIABLO CANYON POWER PLANT NO

OPERATING PROC F r,

TITLE: CHEMICAL CONTROL LIMITS~ 4

SCOPE

This procedure specifies the chemical control operating 1imits and where appli-cable, absolute limits for all the plant water systems. Procedures for makingchemical adjustments to the various systems are not covered here.

PRERE UISITES

None

PROCEDURE

Chemical control 1'imits for normal"operation of the various plant water systems'reshown in the tables'hich follow. Process monitor instrumentation and periodic

sample analyses serve as the basis for checking the water quality. When the waterquality is observed to be outside- the prescribed normal operating limits, promptaction should be taken to adjust the water quality to within the normal operatinglimits.

The tables included in this procedure are as follows:

'ABL'E'ND.

1

23

56

'789

10ll12131415161718A

18B19

TITLE

AccumulatorsAuxiliary Boiler WaterBoric Acid Storage Tank and Boron Injection TankCirculating Water Pump Motor Cooling SystemComponent Cooling WaterCondensate After Condensate PumpsCondensate Storage TankDiesel Engine Jacket Cooling WaterFeedwaterPrimary Water Storage TankReactor Coolant SystemRefueling Mater Storage TankResidual Heat Removal SystemService Cooling WaterSpent Fuel Pool MaterSpray Additive TankStator Cooling MaterSteam Generator Steam Side and Feedwater ChemistrySpecifications for AVTSteam Generato~ Blowdown Limiting AVT SpecificationsSteam Purity

PAGE 1 OF 13

APPRO'IAL

REYISION DATE 2/1/80

PLANT SUPERINTENDENT DATE

6 0041 60~

II

",; DIABLO. CANYON POWER ANT UNIT NOS. 1 AND 2'PERATING PROCEDURE NO'. F-5': -'ITITLE: CHEMICAL'ONTROL LIMITS

L~

'~

a

a

C

k ~

Par'ameter

., TABLE

1'CCUMULATORS

S ecificationBoric acid, ppm as boron 1900 to 2100

Parameter

TABLE 2

'AUXILIARYBOILER WATER

erat>onS ecification

~et Layeu>

pH, at 25'CDissolved 'oxygen, ppmHardness, ppm as CaC03Chloride, ppm'Conductivity, at 25 C

Hydrazine, ppmAmmonia, ppmIron and Copperz, ppm

8.0 to 9.5Less than 0.10Less than 0.10Less than 10 .

Less than 60 ymhos/cmLess than 1

Less than 1.0Less than 1.0

'=:.i'10.0 to 10.5Less'han 0.10

75 to 1'501

>Ammonia is to be added in sufficient quantity to adjust the pH toits specified range. This should normally require approximately5 to 50 ppm aranonia.

2This is not intended as a control value; rather, it serves as anindicator of a system abnormality resulting from a crud burst,excessive corrosion rates, etc.

3The water level must be above the tubes and'he vapor space must beinerted with nitrogen during layup.

TABLE 3

BORIC ACID STORAGE TANK AND'ORON INJECTION TANK

Parameter

Boric acid, ppm as boronChloride~ ppmFluoride~, ppmSilica, ppmAluminum, ppmCalcium, ppmMagnesium, ppmMakeup Water

uif'0,000 to 22,500

Less than 0.15Less than 0.25Less than

2.1'ess

than 0.66Less than 0.66Less than 0.66Shall meet the specifications of Table10, with the. exception for dissolved oxygen

Limit based on maximum limit of 0.00004$ Cl and 0.0002K F in boricacid crystals per W PDS 52205 AP, Rev. F.

PAGE 2 OF 13 REVISION ~ .GATE ~2''1'0

$1

~ DIABLO CANYON POWER PLAh NIT NOS. 1 AND 2OPERATING PROCEDURE NO. F-5

TITLE: CHEMICAL CONTROL LIMITS

TABLE 4

CIRCULATING WATER PUMP MOTOR COOLING SYSTEM

Parameter

Chromatei, ppm as CrO<pH, at 25'Cz

S ecification

250 to 3609.0 to 9.7

iPotassium dichromate (KzCrq07) or potassium chromate (KqCrOq) mustbe used for makeup.

~The pH is controlled by the addition of potassium hydroxide (KOH)where the pH is less than 9.0, or by the addition of KzCrqOy whenthe pH is greater than 9.7.

TABLE 5

COMPONENT COOLING WATER

Parameter

Chromate>, ppm as CrO>pHzChloride, ppmFluoride, ppm

S ecification

175 to 2258.0 to 9.0Less than 0.15Less than 0.15

>Potassium dichromate (KqCrqOq) or potassium chromate"(KqCrO<)must be used for makeup.

zThe pH is controlled by the addition of potassium hydroxide (KOH)when the pH is less than 9.0, or by the addition of KqCrq07 whenthe pH is greater than 9.7.

Parameter

TABLE 6

CONDENSATE AFTER CONDENSATE PUMPS

S ecification Wet La u

Dissolved oxygen, ppbHydrazine>; ppmAmmonia, ppm

Less than 10I.O,] + 0.005Less than 1.0

Less than 10075-150Less than 1.0

i[0q7 means the concentration of dissolved oxygen, in the same unitsas hydrazine.

PAGE 3 OF 13 REVrsrON DATE 2/1/80

PAULO .CANYON POIPLANT UNIT NOS. I ANO 2,OPERATING PROCEDURE NO. F-5


Parameter

TABLE 7

CONDENSATE STORAGE TANK

Normal Limit's Absolute Limits

Cation Conductivity, at 25'CPH, at 25'CTotal suspended solids~, ppmDissolved oxygen'', ppmFree Hydroxide, ppm as OH

Sodium, ppmSilica, ppm

Less than 1.0 ymho/cm6.0 to;8.0Less than O.lLess than O.lNot detectableLess than 0.01Less than 0.2,.

Less than 2.0 ymhos/cm5;-S.to 9;2 "

Less than 1.0Less than 1.0 „Less than 0.2Less than 0.1Less than 2.0

~Suspended solids are those which are retained on a 0.45 micron poresize filter.

zIn a practical sense, it may not be possible to maintain the oxygenat this level for all conditions of operation. However, it is impera-tive that maximum effort be made to maintain a low oxygen level atall times during wet layup and hydrostatic testing of the steam gen-.erators.

TABLE 8

DIESEL ENGINE JACKET COOLING WATER

Parameter

Chromate~, ppm as CrOqpH, at 25 Cz

S ecification

790 to 15758.5 to 10.0

>Potassium dichromate (KqCrz07) or potassium chr'ornate (KqCrOI,) mustbe used for makeup.

zThe pH is controlled by'the addition of potassium hydroxide (KOH) when

the pH is less than 8.5, or by the addition of KqCrq07 when the pH isgreater than 10.0.

Parameter

Hydrazine, ppmDissolved oxygen. ppbAmmonia, ppm

'TABLE'

FEEDWATER

[0>) + 0.005Less than 5

~Met l.a u

75-'150'Less

than100'ess

than 1.0

Dur ng power operat on (refer to Table 18 for limits during othermodes of operation.

PAGE. 4 OF '13 NNYISION DATE 2/1/80'

) ~

DIABLO CANYON POMER PLANT IT.NOS. 1 AND 2OPERATING PROCEDURE NO. F"


Parameter

TABLE 10

'PRIMARY MATER STORAGE TANK

Cation conductivitypHDissolved Oxygen~, ppmChloride and Fluoride(Total) ppmTotal s'olidsz, ppmSuspended solids , ppmSilica, ppmPotassium, ppmSodium, ppmAluminum, total, ppmCalcium, ppmMagnesium, ppm

Less than 1.0 gnho/cm at 25'C6.0 to 8.0 at 25'CLess than 0.10

Less than 0.10Less than 1.0Less than O.lLess than O.lLess than 0.01Less than 0.01Less than 0.02Less than 0.02Less than 0.02

>Oxygen concentration in the makeup water to the Reactor. CoolantSystem must not exceed 0.1 ppm when the coolant temperature isgreater than 180'F.

zExcluding boric acid in the Reactor Coolant System makeup.

sSolids are defined as particles retained on a 0.45 micron poresize filter.

PAGE 5 OF 13 REVISION 1 DATE 2/1/80

DIABLO CANYON POWE NT UNIT NOS. 1 AND 2OPERATING PROCEDURE NO. 'F-5

CHEMICAL .CONTROL. LIMITS

Parameter

Conductivity, pnhos/cmat 25'C

pH

. TABLE llREACTOR COOLANT SYSTEM

S ecificationstea tate on >talons

Varies with boric acid andalkali. Exp'ected range isfrom 1 to 40.

Varies with boric acid andalkali, Expected range isfrom 4.2 to 10.5 at 25'C

9.8-10. 2

Dissolved oxygen ~; ,3,ppm

Chloride ',4, ppm

Fluoride ~,", ppm

Hydrogen', cc(STP,)/kgpower >1MWtnormal target band

Total suspendedsolids6, ppm

Lithium -77, ppm as Li

<0.10

<0.15

25-5030-40

0.7-2.2

<1. 0

<1.5

<0.15

<0.15

0.7-2.2

Boric acid, ppm's B

Silica8, ppm

Al.Uminuma, ppm

Calciums,. Ppm ,

Magnesiums, ppm

Variable from 0-4000

<0.2

<0.05-

<0;05

<0.05

e'!

Wst t 1s c emsstry parameter in excess"'of its steady'state limit, but withinits t'ransient limit, restore'the'pa'rameter; to within its steady'tate limitwithin 24 hours or be in't least HOT STANDBY within the next 6 hours,'and inCOLD SHUTDOWN within, the follow'ing 30 hours. If a.transient limit is 'exceeded,be in at least HOT STANDBY within 6'hoiirs and in COL'D'HUTDOWN within thefollowing 30 hours.

2Limits apply prior to heatup beyond-180'F. During power'peration with thespecified hydrogen concentration maintained in the coolant, the'esidual oxygenconcentration must not ex'ceed 0.005 ppm.

PAGE .6 OF 13 REVISION .'. -1' 'ATE '/1/80'---

tl l~

DIABLO CANYON POWER PLAN IT NOS. 1 AND 2

OPERATING PROCEDURE NO. F-5

TITLE: CHEMICAL CONTROL LIHITS

TABLE ll - (Continued)

sOuring startup, hydrazine may be used in concentrations up to 10 ppm when thecoolant temperature is between 150'F and 180'F 'and the Oq exceeds O.l ppm.

"Halogen concentration must be maintained below the specified limits regardlessof system temperature.

'Owing to changes in pressure in volume control tank during coolant letdown andcharging to the RCS, the hydrogen concentration may exceed the normal operatingrange of 30 to 40 cc(STP)/kg.HqO. At power levels-above 1 NWt the hydrogenconcentration in the coolant must be within the specified range of 25 to50 cc(STP)/kg. Twenty-four hours prior to a scheduled shutdown, when the RCS

is intended to be cooled down, the hydrogen concentration may be reduced to15 cc(STP)/kg Hz0. The earlier reduction in hydrogen concentration facilitateshydrogen degasification following shutdown. This specification is not intendedto include decay heat generated during subcritical operation.

Suspended solids are those which do not pass through a filter having 0.45 micronpore size.

~The lithium -7 limits apply prior to heatup beyond 150'F.

aThese limits are included as recommended standards for monitoring coolantpurity. Establishing coolant purity within the limits shown for these speciesis judged desirable with the current data base to minimize fuel clad crud deposi-tion which affects the corrosion resistance and heat transfer of the clad.

PAGE 7 OF 13 REVISION DATE 2/1/80

DIABLO CANYON POM PLANT UNIT NOS. 1 AND 2

.OPERATING PROCEDURE:NO. F-5


Parameter

TABLE 12

REFUELING MATER STORAGE TANK

S ecification

Boric acid. ppm as boronpH, at 25'CChloride, ppmFluoride, ppmSuspended Solids', ppmSilicaz,

ppm'luminumz, ppmCalciumz ppmMagnesiumz,'pmMakeup water

2000 to 22004.0 to 4.7Less than 0.15Less than „0.15Less than 2.0 .

Less than 0.30Less than 0.08Less than 0.08Less -than 0.08Shall meet the specifications ofTable 10,,with the exception fordissol.ved oxygen

V'Solidsare those which do not pass through a fil,ter having 0.45 micronpore size.

zThese limits are included in the table of refueling water storage tankspecifications as recommended standards for monitoring the refuelingwater purity. Since the refueling water becomes common with thereactor coolant during refueling, it is judged desirable with thecurrent data base to establish refueling water limits shown, for thesespecies to minimize fuel clad deposition which affects the corrosionresistance and heat transfer of the clad.

'PAGE 8 OF 13 REVISIDII 1 DATE.,2/1/80

) 4

g3

DIABLO CANYON POWER PLA UNIT NOS. 1 AND 2

OPERATING PROCEDURE NO. F-5CHEMICAL CONTROL LIMITS

Parameter

TABLE 15

SPENT FUEL POOL WATER

S ecification

Boric acid, ppm as boron~pH, at 25'CChloride, ppmFluoride, ppmCalcium, ppmMagnesium, ppmMakeup Water

2000 to 25004.0 to 8.0Less than 0.15Less than 0.15Less than 1.0Less than 1.0Shall meet the specifications of Table10, with the exception for dissolvedoxygen.

~The boron specification applies during periods when fuel transferoperations via the transfer canal are in progress. During initialfuel loading, the boron concentration limit does not apply.

Parameter

TABLE 16

SPRAY ADDITIVE TANK

~Bi i ti

Sodium hydroxide, as NaOHSodium carbonate, as NaqCOq

30 to 325 by weightLess than 1.0% by weight

Parameter

TABLE 17

STATOR COOLING WATER

S ecification

Conductivity, pmhos/cm at 25'CChloride, ppmSuspended solids

Less than 1.5Less than 0.15Less than 1 FTU

PAGE 10 OF 13 >EVISION DATE 2/1/80

DIABLO CANYON POWE, E'LANT UNIT NOS. 1 AND 2

OPERATING PROCEDURE NO. F-5TITLE:, CHEMICAL CONTROL LIMITS

TABLE 15

SPENT FUEL POOL WATER

Parameter

Boric acid, ppm asboron'M,

at 25'CChloride, ppmFluoride, ppmCalcium, ppmMagnesium, ppmMakeup Water

S ecification

2000 to 25004.0 to 8.0Less than 0.15Less than 0.15Less than 1.0Less than 1.0Shall meet. the specifications of Table10, with the exception for dissolvedoxygen.

iThe boron specification applies during periods when fuel transferoperations via the transfer canal are in progress. During initialfuel loading, the boron concentration limit does not apply.

Parameter

TABLE 16

SPRAY ADDITIVE TANK

S ecification

Sodium hydroxide," as NaOHSodium carbonate, as Na~C03

30 to 325 by weightless than 1.0Ã by weight

Parameter

TABLE 17

STATOR COOLING WATER

S ecification

Conductivity, qmhos/cm at 25'CChloride, ppmSuspended solids

Less than 1.5Less than 0.15Less than 1 FTU

PAGE 10 'F 13 REVISION DATE 2/1/80

TABLE 18A

STEAM GENERATOR STEAM SIOE AHD FEED'ifATER CHEMISTRY SPECIFICATIONS FOR AVT

Par~meter Cold Hydro,Hct Layup>

Hot Functional, HotShutdown, Hot Standby Startup from Hot Standby Normal Power Operations

Slowdown Blowdown Feedwater Blowdown Fccdwa ter Blowdown

pH at 25'C

Free OH. ppm

Cation Conductivity,uml:os/cm at 25'C

Specific Conductivity,>moos/cm at 25'C

Sodium, ppm

Chloride,, ppm

Arsconia, ppm

Hydrazine, ppm

Dissolved Oxygen, ppb

Si0., ppn .

Iron, ppm

Coppcri PPn

Suspended Solids, ppm

Blcwdown Rate, gpm/SG

10.0-10,5

Not detectableNA

N

HA

<0.5

As pH requires75-150z

<100 ~ .

HA

HA

HA

HA

N

Control

8.8-9.2<0.05

<2.0

-HA

NA

NA

HA

HA

HA

NA

HA

HA

HA

Expected

8.8-9.2<0.05

<2.0

<0.1

<0.15.'«0. 5

HA

c5

<1.0

HA

HA

«14

As required

Control

N.NHA

N~ HA

HA

[Oz]+0.005s

c100

ttA

tlA

HA

HA

HA

8.8-10.0s

N'A'lA

8.5-10.0s<0.05

<77

HA

HA.

HA

HA

[Oz]<0.005sc 100

HA

'<0.1.c 0.05

NA

HA

HA

tlA

HA

NA

HA'

HA

NA

.HA

HA

Maximum

Expected Control Expected

8.5-10.0s«0.05

<7z

NA

. 'c0.5c0.5

<10.0N

. c5c5

HA

NHA

Maximum

HA

NA

tlA

8.8-9.2HA

.HA

HA c4

HA

HA

NA

[Oz]~0.005<5

tlA,

llA

HA

HA

HA

HA

HA

<0.5'Oz]%.005

c5

HA

<0.01c 0.005

HA

NA ~

Control Expected Control

8.5-9.0<0.05

<2.0

NA

HA

tlA

NA

NA

NA

HA.

HA

~ HA

As required

Expected

8.5-9.0<0.05

«2.0

hA

'0.«0.15

<0.25 . ~

HA

c5

<1,0NA

HA

<1;0HA ~

C7)m

N r: ans not applicable.

>Ccndensate quality makeup water shall be used exclusively in achieving these conditions.Curing. Cold Hydro, scmc decomposition of hydrazine is expected; sufficie'nt hydrazine should be added with the nakeup to reestablish the Cold itetLayup conditions at completion of .the test.

Fcedwater (Auxiliary Fcedwatcr) shall be of condensate makeup quality to which ammonium hydroxide and hydrazine are added at the inlet into thesteam generator for pH and oxygen control. The hydrazine shall be added at h rate to achieve a hydrazine concentration equivalent to three to .five times the oxygen concentration." Curing hot functional testing, higher than normal suspended solids are expected. Blowdown should be maximized to reduce thc stean generatorsolids content to the concentration specified.

rOcParture from the normal 8.8-9.2 PH range allows for increased HHs resulting from decomPosition of hydrazine used for feedwater system layuP.

sHydrazinc level should exceed oxygen level by 5 ppb.

70uring startups. up to 48 hours from the initiation of plant loading, additional latitude from normal operating specifications is providedbecause increased levels of contaminants arc expected.

"Operation outside the control par'amctcrs spccificd for. norcml power operation is governed by the limiting conditions specifications (see Table 18B).I

I Om

~ «

O

O Og ~

Vl«

DIABLO CANYON POWE ANT UNIT NOS. 1 AND 2OPERATING PROCEDURE NO. F-5


- ~

TABLE 188

STEAM:GENERATOR 'LOWDOWN 'IMITINGAVT 'SPECIFICATIONS

Parameter

pH at 25'C

Cation Conductivi ty,pmhos/cm at 25'C

Two Weeks~

8.0-8.5 or 9.0-9.2

>2.0 but <120

24Hours'A

Immediate~

<8.0 or >9.4

>120

Free Hydroxide, ppm

Blowdown Rate, gpm/SG

NA2 >0.05 but <0.35 >0.35

- - - - Maximum available capacity - - --

~Corrective action including shutdown, if necessary, is recommended within thetime periods indicated.

No relief for Free Hydroxide above the normal operating control limit of0.05 ppm is provided in excess of 24 hours.

Parameter

Cation conductivity,pmhos/cm

Dissolved oxygen, ppm

Sodium,, ppm

Chloride, ppm

Silica, ppm

Copper,. ppm

Iron, ppm

Sulfites and sulfates

Notes

TABLE 19

STEAM'URITY

Norma0 erations

<0. 3

<0.01'0.'005

<0.005

<0!010<0'.002

<0:020

Not'etectable

S ecificationsL matin Con >talons

2 Weeks

0. 3-'0'. 5

24. Hours

0.5-1.0

0.01-0.030.'03-0.10'.005-0.'010

0.010-0.0200.'005-0.010 0.010-0.0200.010-0.020 0.020-'0.050

>Yalue to be used as a cont'rol parameter. Either continuous direct analysis ofcondensed inlet steam, or as calculated from steam generator water and mechanicaland vaporous carryover.

2Not a control parameter. The values represent typical levels which should beachieved under steady state conditions.

PAGE 12 OF 13, NNVrSrON DATE'/1/80'

g ~

E

DIABLO CANYON POWER PLANT UNIT NOS. 1 AND'2

OPERATING PROCEDURE NO. F-5


REFERENCES

l. Diablo Canyon Power Plant FSAR, Table 10.4-2

2. "ChI.mistry Criteria and Specifications," Westinghouse Electric CorporationDocument No. 5-1 (Previously WCAP-7452), Revision 2, March 1977, NuclearEnergy Systems, Water Reactor Divisions,'WR Systems Division.

3. .General Operating Orders, 5.301, 5.315, 8.201, 8.302

4. Standard Technical Specifications

5. "Steam -Side Water Chemistry Control Specifications," Westinghouse ElectricCorporation Document No. 5-4 (Previously WCAP-8113), Revision 1, January1975, Nuclear Energy Systems, Water Reactor Divisions, PWR Systems Division.

ATTACHMENTS

1. Appendix 1, Steam Cycle Process Sampling Points

2. Appendix 2

PAGE 13 OF 13 REVISION DATE 2~/1 80

0l'

DIABLO CANYON POWER PLA UNIT NOS. 1 AND 2OPERATING PROCEDURE NO. F-5


APPENDIX 1

STEAM CYCLE PROCESS SAMPLING'POINTS

The steam cycle process sampling system is provided for continuous, instru-mented chemical analyses for certain important parameters. The steam cycleanalyzer network ncompasses monitoring the following 'subsystems.

1. Main CondenserI

The condensate in the main condenser is monitored for saltwater intrusion.Monitoring consists of measuring cation conductivity for the condenser tubesheet leak detection system, and specific conductivity for the condensertray sample system. In addition, the east condenser half and the westcondenser half are each sampled and ahalyzed for sodium ion. Thisparticular sampling is accomplished through a header network from thesamples on the tube sheet leak detection system and the condenser traysample system. I

2. Condensate Pumps Discharge Header

Condensate downstream of the condensate pumps and the point where chemicaladdition takes place is sampled and analyzed for dissolved oxygen, specificand cation conductivity.

3. Feedwater

The feedwater is sampled downstream of feedwater heaters lA, B, and C ona common header. This water is analyzed for dissolved oxygen, hydrazine,pH, specific conductivity and cation conductivity.

4. Steam Generator Blowdown

Each steam generator's blowdown water is monitored for cation conductivity,pH, and sodium ion. In addition, the four steam generator samples headertogether, and the mixed sample is monitored for radioactivity (RE-19).

5. Steam Generator Steam

Each steam generator's steam is monitored for specific and cation conductivity.

This network of analyzers is'intended to provide the operator with a data basewhich serves as guidance for operation of the plant. The measurement value fora monitored parameter is to be compared to the limits specified in the appropriatetables in the main body of this procedure'. When a monitored parameter indicatesa value which is outside the normal control value, corrective action must betaken without delay. THE INSTRUMENT READING IS TO BE CONSIDERED ACCURATE.The only exception to this admonition is when it is known for a fact that theinstrument reading is actually in error.

I

The identification of the individual analysis instruments are shown in thefollowing tables and figures.

PAGE 1 OF 5

REVELS

NN DATE 2/1/80

I

DIABLO CANYON POW LANT UNIT NOS. 1 AND 2OPERATING PROCEDURE NO. F-5


APPENDIX 1 (Cont'd)TABLE Al-1'AIN CONDENSER'SALTWATER INLEAKAGE INSTRUMENTATION

Sys tern SampleLocation Un 1 t

aneni t

ane

Sam le Cell and Panel Nos.

Condenser Trays,Specific ConductivityMeasurement

Tube Sheet LeakDetection, CationConductivityMeasurement

NW

SE

NW

InnerOuter

InnerOuter

InnerOuter

InnerOuterInletOutletInletOutletInletOutletInletOutlet

31None

2625

2930

2728

9394

9192

9798

9596

2A

6161

61. 61

6161

6161

2930

2728

31None

2625

9798

9596

9394

9192

2A

6161

6161

61

.61

6161

Condenser InleakageSodium Ion Measure-ment

West HalfEast Half

99

100

63 99

63 100

63

63

Notes for Table Al-1:1. Panel 2 is located in turbine building, East side of condenser.2. Panel 2A is located in turbine building, West side of condenser.3. Panel 4 is located in turbine building, East side of condenser.4. Panel 5 is located in turbine building, West side of condenser.5. Panel 61 is located in turbine building, Northeast of the condenser for

Unit'.1, and Southeast of condenser for Unit 2.6. Panel 63 is located in turbine building, Northeast of the condenser for

Unit 1; and Southeast of condenser for Unit 2.7. The sample supplied to cell 99 (sodium analysis) is a composite sample from

samples supplying cell Nos. 25, 26, 27, 28, 91, 92, 95, and 96. The samplesupplied to cell 100 (sodium analysis) is a composite from samples supplyingcell Nos. 29, 30, 31, 93, 94, 97 and 98.

8. Refer to Figure A-1 for sample source location.9. The signal from the condenser tray samples is recorded on the turbine board

(VB3) in the control room; the signal from the condenser tube sheet samplesis annunciated on high conductivity.

PAGE 2 OF 5 RtVtSrON DATE 2/1/80

OUTLET

SE

98

. 96

30

2997

INLET

UNIT 1

93

91

26

NM

OUTLET

-l a0W PlPl 5

O Qmmw +O OW PlI

O XlO %

XO+ ~

lI Iw Ql

V)

C7

CÃ7IC)

UNIT 2

9330

29

OUTLET INLET OUTLET

91

SE

FIGURE Al-1'CELL NUMBERS FOR'BENIN CONDENSER SEAtlATER INLEAKAGE INSTRUMENTATION

DIABLO CANYON POW LANT UNIT NOS. 1 AND 2OPERATING PROCEDURE NO. F-5

TITLE: CHEMICAL .CONTROl LIMITS

APPENDIX 1 (Cont'd)

TABLE AJ-2

CONDENSATE WATER qUALITY INSTRUMENTATION

PARAMETER

Dissolved 0 en

S ecific Conductivi,tCation Conductivit

CELL,NUMBER

90

,88

89

PANEL,NUMBER

Notes for Table Al-21. Panels 1 and 3 are located in the auxiliary building sample

room on the 85'levation.

2. The signals from these.moni,tors are, recorded, on the, turbineboard (VB3).

TABLE Al-3.FEEDWATER UALITY INSTRUMENTATION

PARAMETER

Dissolved Ox en

H drazineS ecific ConductivitCation Conductivit

CELL NUMBER

81

35

59

60

47

PANEL, NUMBER

3

Notes for Table Al-3:1. Panels 1 and 3,are located in the auxiliary, building sample

room on the 85'levation.

2. The, signals from, the DOq, hydrazine, specific and cation conduc-tivity are recorded on the turbine board (VB3).

3. The FW pH is recorded on panel 1, and annunciates in the controlroom on high or low pH.

;PAGE .4 OF 5 ,DATE ,2/1/80

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0 I.

. DIABLO CANYON POWER PL UNIT NOS. 1 AND 2

OPERATING PROCEOURE NO. F-5


APPENDIX 2

This appendix discusses the rationale for controlling'various chemical para-meters for the major water systems. As part of this discussion, advisorycomments are also provided for plant operation and shutdown associated withthe power cycle chemical control parameters. It should be appreciated thatsome degree of corrosion or degradation of system materials will be takingplace at all times. As such, the chemical control limits established in thisprocedure do not provide for a condition where "zero" corrosion rates exist;rather, the objective is to maintain the water quality to keep the corrosionrates tolerab')y low, and thereby extend the service life of system components.

1. REACTOR COOLANT SYSTEM'.

Electrical Conductivity and pH

These values will vary during fuel cycle lifetime and will be affectedby the concentration of boric acid and alkali present. Observedvariations in the electrical conductivity and pH, not associated withplanned changes in system chemistry, may indicate deterioration ofreactor coolant quality.

V

b. Oxygen

Oxygen concentration of the reactor coolant is to be maintained below0.1 ppm for plant operation above 180'F. The limit of 0.1 ppm isintended primarily as a guide to continuation of plant heatup from180'F.to normal operating temperature. Plant operation with the speci-fied hydrogen concentration will result in oxygen concentration belowthe detectable limit, that is less than 0.005 ppm.

It has been observed that oxygen added to the system, for example, inmakeup water will be consumed in the system. However, the consumptionresults in part from undesirable oxidation of metal surfaces withincreased corrosion and corrosion product formation.

Chloride

Chloride is well known to be detrimental to austenitic stainless steelsin its role in stress corrosion cracking. The specified limit, accept-able for use. in these system materials, can readily be achieved withconventional water, treatment systems.

d. Fluoride

Fluoride concentration must be limited to the specified value to pre-clude the possibility of attack of the Zircaloy fuel cladding as wellas the austenitic stainless steels.

e. Suspended'olids

The concentration of suspended solids must be limited to minimize the

PAGE ~ OF 14 REVISION 1 DATE 2//120

0%4<"~' "'l

DIABLO CANYON POWE ANT UNIT NOS. 1 AND 2OPERATING PROCEDURE NO. F-5


'

APPENDIX 2 (Cont'd)

presence of solid materials which could add,to fuel clad fouling 'andto an increase in the r'adioactivity level of the coolant as activatedcorrosion products.

f. pH Control Agent

The solution pH will vary with the concentration of. boric acid aridalkali present. The expected range measured at 25'0 is between'.2and 10.5. Litliium hydroxide is added to the'oolant to'rov'ide'analkaline envirohment at operating temperatures. As the reactor, coolanttemperature increases, dissociation of boric acid decreases

allowing'he

alkaline additive to control the coolaht pH,

g»

h.

Hydrogen

Owing to chang'es in pressure in the chemical and volume control kanPk

during coolant letdown and charging to the, RCS', the hydrogen concen'-„tration may exceed the normal operating range'f 30 to 40 cc (STP)'/kqH20. At power'evels abov'e 1 NMt the'ydrogen concentration-iri

the'oolantmust- be within -the specified range of 25'o'0 cc (STP)'/kg.Twenty-four'ours prior to a scheduled shutdown, whe'n the reactorcoolant systeii is'nterided to be cooled down, th'e hy'drogen concentr'a'-'tion may be''educed'o 15 cc (STP)/kg H20. The earlier

reduction'n

hydrogen concent'ration facilitates hydrogen dega'sification follow'ingshutdown. This specification is not intended to include: decay'eatgenerated during subcr'itical operation'.

The hydrogen excess in the'CS provides a mechanism for coPnvertingoxygen (pro'duced from water rad'iolysis') back'to water (i.e.,"2Hz+02~2H20).'eolite

Forming, Elements

The thermal and'ydiraulic conditions in some Westinghouse cores'areconducive to a'imited:degree of subcooled nucleate boiling heattransfer; nucleate boiling, is, in turn, conducive: to'increased cruddeposition. Conversely', cores with singgle phase heat transfer may'esubject to excessive'crud deposition due to high levels of impuritiesin the coolant',. or for'ther'r'e'asons; this may'ause initia'tion ofboiling'eat transfer". In either"case, incorporation of ma'gnesium andcalcium.hardne'ss"and aluminum and silica into th'is crud will cause

(1) a signficant barrier to the'heat transfer, and, (2) densificationof the crud; with the potential for*increased con'centration of lithiumhydroxide at'he clad surface. Experience. with boiling heat tra'nsfersurfaces, generally, and with nuclear'uel, in particular, indicatesboth can lead to destructive corrosion and hydriding of the fuelelements.. Thus, appropriate c'ontrol of the'oolant purity, as indicated

'ntable'l. is required to provide a high degree of core integrity.Furthermore, impro'ved control of c'rud buildup in the-core will help"limit the transport'of activation products-throughout the primary- system.

* 6 ' m 4 ' ' gal'0'lit 0 " ''ll'(IO.t'I

0'AG222 OF," 14',i 82P18108a 1 O'AT2-,2/1/80,,

. DIABLO CANYON POWER PLANI'NIT NOS. 1 AND 2


APPENDIX 2 (Cont'd)

2. TURBINE STEAM PURITY

The presence of unwanted corrosive impurities in steam can cause damagetn turbine components by corrosion, stress corrosion and corrosion fatigue.Deposition of impurities can also cause distress by lowering the efficiencyof blades, upsetting pressure distributions and clogging seals and clear-ance in valves. If the extensive damage, lengthy outages and costly repairscaused by these occurrences are to be avoided, the purity of the steamthroughout the turbine must be rigorously controlled. In addition, positivesteps must be taken to assure that impurities from chemical cleaning proce-dures for plant piping and equipment do not get into the turbine.

From the point of view of steam turbine operation, ammonia, cyclohexylamineand morpholine may be used for pH adjustment. Water injections shouldutilize condensate quality water.

Reconmended limits for impurities commonly found in turbine steam are givenin Table 19. The normal values represent Westinghouse recommendations forreliable turbine operation. These values represent limits where the impurityconcentration in steam is below its expected solubility limit everywhere inthe dry regions of the turbine. The limiting conditions represent undesirableconditions which should be corrected to normal within the time periods indi-cated. In plants where better steam purity can be maintained, every effortshould be made to do so.

3. STEAM SIDE WATER CHEMISTRY

Condenser leakage, makeup water flash evaporator carryover or demineralizerbreakthrough and condensate feedwater systems corrosion products are thesources of chemical agents that have the potential for accumulating as sludgeon the steam generator tube sheet, producing deposits on steam generator heattransfer surfaces and for being deleterious to the steam generator materialsof construction. The feedwater is the means by which these chemical agentsare transported to the steam generator. Recognition must be given to thefact that an All Volatile Treatment (AVT) chemistry provides no buffer againstthe effects of condenser leakage, that it is incapable of preventing theformation of scale should the chemical agents that, have the propensityfor scale formation be present and that the ammonium hydroxide or the aminesadded to the system for feedwater pH control have minimum effectiveness assteam generator pH control agents at the operating temperature in the steamgenerator. Therefore, to accomplish the goal of maintaining a steam generatorsteam side all volatile chemistry environment which is innocuous to the steamgenerator materials, it is necessary through a rigorously controlled chemistryprogram to minimize the introduction of contaminants to the system and tominimize corrosion of the materials of construction of the condensate andfeedwater systems. In addition to providing the proper environment for thesteam generator, a well maintained AVT chemistry program will accomplishthe following:

. Maintain a high integrity of all systems components.

PAGE 3 OF REVISION DATE 2/1/80

DIABLO CANYON 'POWER ~ANT UNIT NOS. 1 ANO 2

OPERATING PROCEDURE NO. F-5TITLE: CHEMICAL CONTROL LIMITS

APPENDIX 2 (Cont'd)

- Avoid or minimize turbine deposits due to carryover andvolatility from the steam generator.

. Minimize sludge at its point of concentration, the steamgenerator.

~ Minimize scale deposits on the steam generator heat trans-fer surfaces.

- Minimize feedwater oxygen content prior to entry into SG.

-'Minimize corrosion of the condensate/feedwater systemsmaterials..

These objectives can be achieved by proper selection of systems materialsand by exercising careful chemistry control over the systems, includingcomprehensive sampling and analysis (in-line and laboratory), chemicalinjection at selected points, continuous system blowdown from the steamgenerator and effective protection of 'the steam generator and feedwatertrain internals during periods of inactivity. The details of

these'rocedures.are discussed in the following sections.

a. General Treatment Requirements

The steam system All Volatile Treatment chemistry specifications areaddressed to the concerns of:

~ .Minimizing metal, corrosion~ Limiting the accumulation of sludge in the steam generator~ Minimizing scale formation (Ca-Mg) on the heat transfer

surfaces~ Minimizing the potential for the -formation of free caustic

or acid~ 'Maintaining "zero" dissolved oxygen level (particularly at

points of contact with carbon steel and the steam generatorheat transfer surfaces, viz., the Inconel 600 tubing.)

The above concerns will be minimized by meeting the three steam generatorcontrol parameter s identified in Table 18A, specifically the blowdown pH,cation conductivity and the Free Hydroxide

Protection of the steam generators during inactive periods due to main-tenance, refueling, etc. will require placing the steam generators ina layup condition. To ensure the long term performance of the steamsystem, it is essential that .the same degree of chemical control beexercised during these idle periods as that'xercised during normalplant operation.

PAGE 4 OF 14:- REVISION DAT,E ~2'Qgg

,DIABLO CANYON POWER PLAN NIT NOS. 1 AND 2


APPENDIX 2 (Cont'd)

Periods of hot shutdown and hot standby operati'on require that steambe released from the steam generators to provide heat release from theReactor Coolant System due to heat input from core decay and reactorcoolant pump heat. Chemistry control must be ap'plied during suchoperations similar 'to that exercised during normal operating conditions.Feedwater addition to the steam generators during this period may befrom the condenser hotwell (if the condenser is being used as the heatsink and the condenser is being maintained under adequate vacuum), orthe feedwater supply must be taken from a deaereated source (i.e. anappropriately designed condensate storage tank, etc.) in order toexclude oxygen from the system. Testing procedures should be insti-tuted to check the steam generator water chemistry during hot shutdownand hot standby operating periods to maintain a proper chemical environ-ment. Increased blowdown should be used as required to keep the steamgenerator water chemistry within specifications per Table 18A. It isimperative that the feedwater supply to the steam generators at alltimes have a low dissolved oxygen content. The only acceptable deviationfrom this rule is the water supplied to the steam generators during anemergency condition after the assured supply of deaerated condensatein the condensate storage tank has been exhausted and the alternateemergency sources of water are being utilized. The normal method ofproviding low dissolved oxygen content water to the steam generator isthrough the condensate and feedwater systems. The auxiliary feedwatersystem should also be capable of providing deaerated water to the steamgenerator for extended startup and hot standby operation. Therefore,the condensate storage tank must contain de-oxygenated water at all timesin order to provide the desired quality water to the auxiliary feedwaterpumps. The procedure to be followed in providing the protectionmentioned above is discossed in greater detail in the following sections.

1) Steam Generator and Feedwater Chemistry "Control" Specifications

These specifications reflect a means for proper chemistry control inall of the steam cycle components. The possible occurrence of systemcontamination through condenser leakage, makeup water system mal-function or primary-to-secondary leakage is acknowledged. UNDER NO

CIRCUMSTANCES SHOULD SODIUM PHOSPHATE OR OTHER CHEMICALS BE FED TOTHE STEAM GENERATORS TO COMPENSATE FOR THE INTRODUCTION OF CONTAMIN-ANTS FROM THESE SOURCES. The bases for these specifications aremore fully described below. Fundamental to the AVT approach tochemical control is the use of ammonium hydroxide or morpholine forfor feedwater and steam pH control. Ammonium hydroxide is generallypreferred; however, morpholine is acceptable provided it does notinterfere with the sensitivity of the free hydroxide determination.Also, oxygen scavenging in the feedwater train is accomplished withnon-catalyzed hydrazine. Under normal conditions, continuous blow-down'nd continuous chemical addition is maintained.

PAGE 5 OF 14 REVISION ~ DATE

DIABLO CANYON POWER NT UNIT.NOS. 1 AND 2OPERATING PROCEDURE NO. F-5


'PPENDIX 2 (Cont'd)

a) Feedwater Chemistry Control Parameters

Both the feedwater and steam systems are once-through systemsrequiring that any chemical treatment of these systeIIIs be basedon the AVT concept regardless of the chemistry used in the steamgenerator. This concept has been adhered to by Westinghousein its previous and present specifications relating to feedwaterchemistry control.

(1) Dissolved Oxygen

For corrosion prevention, oxygen must be eliminated as faras possible from the feedwater entering the steam generator.There must be no detectable oxygen (<0.005 ppm) present inthe blowdown under any operating or test condition. Oxygenis controlled by the addition of hydrazine at the dischargeof the condensate pumps. THE USE OF SULFITE FOR THIS PURPOSEIS PROHIBITED.

For hot functional testing and hot standby, the concentra-'ion of oxygen in the feedwater can be O.l ppm or lessprovided the concentration of hydrazine injected into thesteam generator is 3 to 5 times the oxygen concentration inthe feedwater source.

The principal source of oxygen intrusion into the secondarysystem is air inleakage into the main condenser and in theportions of the condensate and feedwater train which are atsub-atmospheric pressure. It should be recognized that the,points where sub-atmospheric pressures occur varies withpower level. The steam jet air ejector discharge flow .rateshould be closely monitored for indications of abnormallyhigh.air-inleakage flow rates.

(2) Hydrazine

Hydrazine is added to the feedwater to control oxygen asmentioned above. The concentration of hydrazine in the steamdrum during hydro and,wet layup must be in the range 75 - 150ppm. For hot functional testing and hot standby th'ydrazineconcentration in the .feedwater should be maintained at 3 to5 times the oxygen concentration in the feedwater source. Forpower operation, it is recommended that a hydrazine residualof >0.005 ppm in excess of the feedwater oxygen be maintaineddownstream of the highest pressure feedwater heater.

b) Steam Generator Chemistry Control Parameters

(1) pH

When controlling steam generator chemistry on,AVT chemistry

'AGE ~ OF 14 REIII GIGA I GATE EF IgGP

rr rrt

DIABLO CANYON POWER PLANT NIT NOS. 1 AND 2OPERATING PROCEDURE NO. F-5

CHEMICAL CONTROL LIMITS

APPENDIX 2 (Cont'd)

it must be recognized that 1) AVT provides no bufferingcapacity for contaminants entering the steam generatorand 2) the steam generator bulk water pH is at or slightlyin excess of the neut'ral pH for water at the operatingtemperature of the steam generator. The ahsence of alkalin-ity in the steam generator at its operating temperature isdue to the low ionization of the feedwater pH control aminesat these temperatures. Therefore,.contaminants enteringthe steam generator .that are more strongly ionized than .thefeedwater pH control amines have the potential for producingmajol perturbations to the bulk water either in the form ofacidity (sea water circulating cooling water).

Clearly then, the objectives of the steam generator pHcontrol parameters stated in Tables 18A and 18B are toprovide a means for controlling free acidity in the steamgenerator bulk water to minimize corrosion of the steamgenerator materials and turbine cycle and to provide a meanswhereby perturbations to the steam generator chemistry fromsources such as condenser leakage can be recognized..

In the case of a sea water intrusion into a steam generatoron AVT chemistry control a blowdown pH depression is expected.The magnitude of the pH depression at temperature was calcula-ted from data developed by D.J. Turner. It was determinedthat for chloride concentration implied by the cationconductivity control parameter (10 ppm) for sea water plants(Table 188) the operation temperature (300'C) pH in the steamgenerator would be depressed approximately 0.5 pH units whilethe room temperature pH would be essentially unaffected. Thedata revealed that blowdown chloride concentrations in excessof approximately 40 ppm would be required to depress the roomtemperature pH. It is concluded, therefore, that in the caseof sea water intrusions into the steam generator, pH alone isnot an adequate monitor of water purity.

Figure A2-1 depicts the expected effect of steam generatorprimary-to-secondary leakage (boric acid plus lithium hydroxide)on the ammonium hydroxide.pH at 25'C of the steam generatorblowdown. These data were derived empirically in the labora-tory and reveal that the presence of boric acid 'will cause a

significant depression in the blowdown pH at 25'C. A lithiumto boron weight ratio of 1/500 was selected for this studybecause it represents the primary coolant chemistry at mid-corelife. It is significant to note that at the operating tempera--ture of the steam generator, there is essentially no depressionof the bulk water pH because of the low ionization of boricacid at these temperatures. The concentration of the lithiumhydroxide, in the steam generator bulk water would not be ofsufficient magnitude to affect the pH.

PAGE 7 OF 14 REYISION DATE 2/1/80

DIABLO CANYON POWER LANT UNIT NOS. 1 AND 2

OPERATING PROCEDURE NO. F-5TITLE'HEMICALCONTROL LIMITS

APPENDIX 2 (Cont'd)

(2)'ation Conductivity

In the recirculating steam generator, the only bulk waterlosses from the steam generator ar the blowdown and themoisture that is entrained in the steam. Therefore, anycontaminant entering'he steam generator will tend toconcentrate until corrective action is taken. For thisreason blowdown cation conductivity is one of the moresensitive methods available for monitoring contaminantinput to the steam generator.

In analyzing a circulating water chemistry for purposes ofcalculating the steam generator blowdown cation conductivityas a function of condenser leakage, it is necessary to makethe assumption that anything in the circulating water thathas the potential for depositing on heat transfer surfaceswill deposit or conversely, only the salts of sodium andpotassium will remain soluble and are therefore the primecontributors to the blowdown cation conductivity; This isa'ery important point because the weight ratio of solublesal'ts to tho'se that have a propensity for depositing on heattransfer surfaces is a significant variable in circulatingwater chemistries. An example of this variation is apparentwh'en comparing the chemistry of sea water, which has a ratioof approximately 7, to the chemistry of Lake Michigan, whichhas a ratio of approximately 0.05. From this analysis, itbecomes apparent that the sea water has a significantly lowerscaling potential than Lake Michigan and therefore, for agiven blowdown cation conductivity attributable to condenser1'eakage less deposition is occurring on the heat transfersurfaces of a plarit sited on the sea coast.

There is no question that cation conductivity is a valuablet'ool in the control of steam generator chemistry; however,recognition must be given to its total significance forproper'pplication.

(3} Free Hydroxide

It h'as been'established iri the laboratory and operatingunits that Inconel 600 steam generator tubing is susceptibleto caustic stress assisted corrosion cracking and, becauseof this fact, every effort must be made to exclude FreeHydroxide from the steam generator environment.

There are several potential, sources of free hydroxide.They'nclude condenser leakage from fresh water cooled plants(sea water inleakage tends to produce an acid condition inthe steam g'ener'ator), makeup water systems and condensatepolishing systems.

PAGE 8 OF .14.. 'EVISION 'DATE 2/1/80

'

I)C, ()

. DIABLO CANYON POWER PLANT UNIT.NOS. 1 AND 2

OPERATING PROCEDURE NO. F-5TITLE CNEMICAL CONTROL LIMITS

l0.0APPENDIX 2 (Cont'd)

LI/O = I/ Joo MEI GHT

NH3 PPH

0 o.2o.5

G I.O

0 2.o

9.0

CD

8.0CD

CDlCCLcs

LUCQ

7.0

6.00 l0 20 30 QO 50

BORON (PPM)Figure A2-1 Boric Acid —Lithium Hydroxide Effect on

Ammonio p H

PAGE 9 OF 14 RSViSrOR DATE

DIABLO CANYON POWER LANT UNIT NOS. 1 AND '2


APPENDIX 2 (Cont'd)

In cases where ion exchange is used to produce makeupwater or condensate polishing, there is a potential forthe accidental introduction of sodium hydroxideregenerant chemical into the system, and also the phen-omenon known as "sodium throw." The latter,may occurwhen the sodium inventory on the resin. bed is slowlyreplaced with another cation, such as ammonium ion whichis normally present in the steam cycle.

2) Steam Generator and Feedwater Chemistry "Expected" Parameters

The following parameters are identified in Table 18A a's ExpectedParameters. These parameters are identified for the'urpose ofproviding the operator a means for evaluating system chemistryperturbations.

a) Feedwater .

(1) Feedwater pH Control

The feedwater pH control ranges identified in Table lSAare based on guidelines established by the fossil boilerindustry for minimizing corr'osion to the materials ofconstruction normally utilized in these systems.

The'bjectivesof the feedwater specifications are to meet orexceed the designed system component requirements and tominimize the amount of feedwater system corrosion productsentering the steam generator.

The .pH of the feedwater system fluid is controlled'ycontinuous addition of ammonium hydroxide or an amine,added at the condensate pump discharge. Hydrazine addedfor oxygen suppression, may also contribute to the pH.The volatility of the amine enables it to be carried over:into the main steam system thus maintaining an alkalinepH in this system.

(2) Iron and'opper

These are reasonable allowances for contamination input tothe'team generator during'ormal operation. They arenot intended's control values, but are intended to indi-cate a point above which some system abnormality mayexist (i.e. excessive corrosion resulting from improperchemical cohdi tions in the condensate and feedwater system).

b) Steam Generator Blowdown

(1) Sodium

Sod'ium is specified'or purposes of providing'a means of

PAGE~> OF 1'a REVISION'. DATE

Ag

DIABLO CANYON POWER PLANT UNIT NOS. 1, AND 2

OPERATING PROCEDURE NO. F-5CHEMICAL CONTROL L IHITS

APPENDIX 2 (Cont'd)

(2)

crosschecking the free hydroxide measurement and confirm-ing the source of a contaminant. The sources of sodiumand their significance have been discussed previously.

A

Chloride

Although Inconel 600 possesses good resistance to chloridestress corrosion cracking, steam generator chloride levelsare restricted by the overall need of high water qualityfor AVT control. The presence of chloride in the blowdownis normally indicative of a condenser leak. The magnitudeof the condenser leak can be calculated from the knownchloride concentrations in the circulating water and blow-down and the total plant blowdown rate.

Chloride ion has been identified as the most active chemicalspecies in an extremely complicated chemical process .thatproduces denting of the steam generator tubes in thevicinity of the carbon steel tube support plate.

At the recent Steam Generator Symposium, data was presentedrelative to the level of chloride ingress necessary toinduce the tube support plate corrosion process that resultedin denting in plants with secondary systems containing copperalloys. Of particular note was the low level of chlorideingress required to produce denting at plants with circu-lating water chemistries capable of producing acid chlorideenvironments in the steam generator, e.g., sea or brackishwaters. The lant data stron 1 su ests that for sea watercooled lants havin co er-a loys in the secon ar s stem,continue o eration with nown ch ori e in ress- is notrecommen ed, even t ou ow own ermits o servance of thenorma s ecification. The cause of the contamination should

e correcte immediately upon detection. At the same time,steam generator blowdown should be increased to the maximumrate, and action .should be taken to either temporarilyarrest the leak source, or if it is in the condenser, isolatethe affected condenser half for repairs of locatable leaks.

Dissolved Oxygen

The presence of oxygen in water has two effects:'t cor rodesmetals by means of oxidation and in. many instances thecorrosivity of'nown deleterious materials is in'creased dueto the presence of oxygen. Therefore, in order to provideoptimum protection to the steam generator materials of construc-tion there must be no detectable oxygen ((0.005 ppm) presentin the steam generator'blowdown under any operating or testcondition.

PAGE ~ OF ~ REYISION 1 . DATE

DIABLO CANYON POW LANT UNIT NOS. 1 AND 2


(,4)'i1,i ca

APPENDIX 2'Cont'd)

Sil.ica is volatile and'ill'e present in the steam to anextent determined'y the boiler water pH, silica content andsteam pressure. The objective in limiting Che silicacontent of the steam generator blowdown water is to minimizeits concentration in the steam and avoid silica deposits onturbine blades and valves.

The present 1'imit of 1 ppm in the nuclear steam generator.,reflecting the overall emphasis on good water quality, isconservative- relative to the "industrial standard" forcurrent operation pressures and is believed, therefore, toavoid silica'eposition altogether.

(5) Ammonium Hydroxide

The ammonium hydroxide entering the steam generator withthe feedwater will undergo steam stripping to the extentthat the ammonia concentration in the steam generator blow-down will be approximately one half of that in the feed-water .- This stripping action and a maximum feedwater pHof 9.2 are the bases for the expected blowdown ammoniaconcentrations identified in. Table 18A.

(6) Suspended Solids

Steam generator suspended solids should be minimized toprevent accumulation of excess sludge on the secondary sideof the steam generator tube sheet. The operating limitof 1'pm is given to provide guidance as to acceptableand'achievable suspended solids input to the steam generator.

("7,) Blowdown Rate

To achieve optimum, effectiveness from the steam generatorwater chemistry control, the minimum continuous blowdownrate required to maintain the chemistry control parametersis required'during normal power operation. Such operationprovides a dynamic system which is constantly removing anyimpurities from the steam generator. In addition, experiencehas shown conclusively that more stable steam generatorchemistry control can be obtained with continuous blowdownthan is obtained with an intermittent mode of operation.During periods of maintenance of the blowdown system or make-up. water treatment'ystem, blowdown may be reduced so longas the chemical specifications are not exceeded. To facili-tat'e maximum cleanup of the steam generator following a coldor hot shutdown, it is recommended that the maximum blowdownrate be instituted and maintained until full power operationis achieved. It is emphasized'that the blowdown rate should

PAGE 12 PF14''

REVISION . DATE 2/1/80

DIABLO CANYON POWER PLANT UNIT NOS. 1 AND 2


APPENDIX 2 (Cont'd)

be, increased, as required, to compensate for chemistryimbalances in the steam generator caused by factors suchas condenser leakage, etc. during power operation. However,the causes of such imbalances should be corrected as soon aspossible in order to keep the impurity input to the steamgenerator to a minimum.

During hot standby and hot functional testing, blowdown isemployed as needed to maintain the steam generator waterchemistry indicated in Table 18A.

3) Chemical Addition

The All Volatile Treatment method for steam side water chemistry controlrequires maximum attention to the prevention of contaminant input tothe steam generators. This follows from the fundamental aspect ofAVT control that it provides no chemical treatment for the steamgenerator itself, relying entirely on the exclusion of oxygen andcontaminants resulting from condenser leakage, makeup water systemmalfunctions and chemicals used during such activities as pre-operation feedwater system cleaning, etc. The only chemicals injectedinto the steam side of the plant during operation are hydrazine, foroxygen suppression and an amine as required for feedwater and steamsystem pH control

Since no steam generator chemical treatment is provided, the intro-duction of impurities may result in the accumulation of high concen-trations of contaminants in local areas and the formation of hardnessscale on the heat transfer surfaces, i.e. the steam generator tubes.To minimize these possibilities, blowdown is increased as necessaryto reduce the contaminant levels in the steam generator; failure tocontain contaminant levels within the limits specified calls forimmediate corrective measures.

Corrective Actions

Remedial actions available to correct an abnormal chemical conditionin the steam generator are as follows:

a) Increase the steam generator blowdown rate.b) Overboard the affected hotwell, if condenser leakage is detected.c) Overboard the water from the tube sheet leak detection system,if this appears to be the contaminant source.d) Isolate the leaking condenser half and repair.e) Correct makeup water contamination, if indicated.

If these corrective measures prove unsuccessful in controlling thesteam generator chemistry, the unit must be shut down and repairsmade to eliminate the source of the contaminant. The LimitingControl Specifications given in Table 18B have been established for

PAGE 13 OF 14 "- ' ISIQN DATE 2/1/80

DIABLO CANYON ER PLANT UNIT NOS. 1 AND 2

OPERATION PROCEDURE NO. F-5TITLE: CHEHISTRY CONTROL LIHITS

APPENDIX 2 (Cont'd)

the purpose of allowing the operator a time frame during whicha load reduction or shutdown can be scheduled for the purposeof making the repairs necessary to eliminate the source ofcontamination.

PAGE 14 OF 14 REVISIQN 1 ATE 2/1/80

0DIABLO CANYON POWER PLANT UNIT NOS. 1 AND 2

OPERATING PROCEDURE NO. f-5TITLE: CHEMICAL CONTROL LIMITS

APPENDIX 3

SECONDARY CYCLE CHEMISTRY CORRECTIVE ACTION GUIDANCE

This appendix provides corrective action guidance in summary fashion forsituations when one or more secondary cycle chemical parameters are out ofspecification. Table A3-1 summarizes expected symptoms of certain operatingupsets, such as condenser saltwater inleakage, excessive condenser airinleakage, incorrect chemical feed rates, etc. Table A3-2 suranarizes possiblecauses and corrective actions for off-control point chemical parameters.

PAGE 1 OF 9 arvisroH DATE 2/1/80

m

C)

UPSET CONDITION

Leaking condenser .tube, defect not near tube sheet.

LIKELY SYMPTOMS1

1. High specific conductivity ona. Condenser tray(s)b. Condensatec. Feedwaterd. Steam generator blowdowne. Steam generator steam (large leaks)

2. High sodium concentration ona. Condenser leak detection systemb. Feedwaterc. Steam generator blowdown

3. Low cation conductivity on tube sheet leakdetection.

APPENDIX 3 (Continued)

TABLE A3-1CHEMICAL SYMPTOMS OF OPERATING UPSET CONDITIONS DURING POWER OPERATION

O~r cax) +m ~r~ +o

~oo~ ~mmZ OOtH p)+

OA m~r a>o mmR Rr7O ~~0r

NgCh

C)C/l

4. High cation conductivity ona. Condensateb. Feedwaterc. Steam generator blowdownd. Steam generator steam (large leak)

5. Low pH on steam generator blowdown, feedwater pHmay trend downwards.

Condenser'tube sheet leak.

6. High chlorides* in steam aenerator blowdown.

1. High cation conductivity ona. Tube sheet leak detectionb. Condensatec. Feedwater

l. Asterisked (*) items are indicated by grab sampling; all others are instrumented process monitors.

0,

UPSET CONDITION

Condenser tube sheet leak (continued) d. Steam generator blowdowne. Steam generator steam (large leak)

2. High sodium concentration ona. Condenser leak detection systemb. Feedwaterc. Steam generator blowdown

3. High specific conductivity ona. Condensateb. Feedwaterc. Steam generator blowdownd. Steam generator steam (large leak)

4. Low specific conductivity on condenser trays

5. Low pH on steam generator blowdown, feedwatermay trend downwards

6. High clorides* on steam generator blowdown


TABLE A3-1CHEMICAL SYMPTOMS OF OPERATING UPSET CONDITIONS DURING PONER OPERATION

LIKELY SYNPTONS1

QD

Ctl ~ I

om Mm

OZ ODl ~DO

I C

o m~R7

O~CDI

UlQC/7

O

D

Excessive condenser air inleakage. l. High dissolved oxygen (D02) ina. Condensateb. Feedwater

Incorrect armonia (morpholine) feed rate.

2. Higher than normal air ejector flow rate

3. High copper* and iron* in feedwater

1. Low pH (underfeed) or high pH (overfeed) ina. Feedwaterb. Steam generator blowdownc. Steam generator steam

l. Asterisked (*) items are indicated .by grab sampling; all others are instrumented process monitors.

0

RlO1

O

UPSET CONDITION


TABLE A3-1CHEMICAL SYMPTOMS OF OPERATING UPSET CONDITIONS DURING POMER OPERATION

LIKELY SYMPTOMS1

Incorrect hydrazine feed rate 1. High 002 (underfeed) in feedwater

2. High copper* and iron* (underfeed) in feedwater

3. High pH (overfeed) ina. Steam generator blowdownb. Steam generator steam

Incorrect ammonia (morpholine) feed rate (continued) 2. High copper* (overfeed) ina. Feedwaterb. Steam generator blowdown

3. High copper* and iron* (underfeed) ina. Feedwaterb. Steam generator blowdown

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Primary-to-secondary leakage 1. High radi oacti vity ona. Steam generator blowdown monitor (RE-19)b. Air ejection discharge monitor (RE-15)c. Plant vent monitor(RE-14A 5 B, noble gases)d. Steam generator blowdown tank effluen't

monitors (RE-23, liquid; RE-27, tank vent),during periods of SG blowdown when theblowdown cleanup demineralizer systemis cut out

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l. Asterisked (*) items are indicated by grab sampling; all others are instrumented process monitors.

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SAMPLE POINT

1. MAIN CONDENSER

PARAMETER OUT OFSPECIFICATION POSSIBLE CAUSES CORRECTIVE ACTION

a. Tray samples High specificconductivity

Sal twa terinleakage

Locate and plug leakingondenser tube(s)ic

High specificconductivity withlow cationconductivity incondensate andfeedwater

Excessive feedrate of pH controlagent, ammonia(morpholine), orexcessive feed rate~of hydrazine

Decrease feed rate ofammonia (morpholine);overboard drains from steamjet air ejector; verifycorrect hydrazine feed rate


TABLE A3-2CORRECTIVE ACTIONS FOR OFF-CONTROL POINT CHEMICAL CONDITIONS IN THE SECONDARY CYCLE

REFERENCEOPERATINGPROCEDURE

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2. CONDENSATEPUMPS DISCHARGEHEADER

High cationconductivity

High sodiumconcentration

High dissol vedoxygen

Saltwaterinleakage

Saltwaterinleakage

Excessive air .

leakage

Locate and plug leakingcondenser tube(s)

For WEST condenser hal fsample header, cut outcirculating water pump 1-1or (2-1)For EAST condenser halfsample header, cut outcirculating .water pump 1-2(or 2-2)

Increasehydrazine feed rate;locate and secure inleakagepathway

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SAMPLE POINT

2. CONDENSATEPUMPS DISCHARGEHEADER

(Continued)

PARAMETER OUT.OFSPECIFICATION

High specificconductivity with

low�

.cationconductivity

POSSIBLE CAUSES CORRECTIVE ACTION

Excessive pH con- Decrease arrmonia (morpholine)trol agent, ammonia feed rate; verify correct(or morpholine) feed rate of hydrazine


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3. FEEDMATER


pH (low)

pH (high)

High 002

High/Low Hydrazine

High specificconductivity withlow cationconductivity .

Saltwaterinleakage

Underfeed ofammonia (or mor-pholine)

Overfeed ofatmonia(morpholine) oroverfeed of.hydrazine

Excessive condenseair inleakage;underfeed ofhydrazine

Hydrazine feedrate not inbalance withD02 levels

Excessive ammonia(or'orpholine) oroverfeed of hydra-zine


Increase ammonia (morpholine)feed rate; terminate dis-charge of steam jet airejector after-condenserdrains; verify correcthydrazine feed rate

Decrease ammonia (morpholine)feed rate; increase overboardof steam jet air ejector after-condenser drains; verifycorrect feed rate of hydrazine

Increase hydrazine feed rate;locate and secure condenserair inleakage pathway

Adjust hydrazine feed ratefor target residual concen-tration

Decrease ammonia (morphol ine)feed rate; veri fy correcthydrazine feed rate

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SAMPLE POINT

3. FEEDWATER

(Continued)

PARAMETER OUT OFSPECIFICATION


POSSIBLE CAUSES CORRECTIVE ACTION

SaltwaterL'nleakage


High copper andiron

Excessive corrosionrate due to highD02 or excessiveammonia levels

Check condenser air inleakage,pH, D02 levels, hydrazine feedrate

4. STEAM GENERATOR

BLOWDOWN


Saltwaterinleakage; in-sufficient SG

blowdown; blow-down cleanupdemineralizerexhaustion

Increase SG blowdown; checkfeedwater chemistry; checkperformance of blowdown clean-up demineralizers; check forcondenser saltwater inleakage




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High pH Excessive ammonia(morpholine) feedrate, excessive

~ hydrazine feedrate, insufficientdischarge rate ofair ejector after-condenser drains

I Increase SG blowdown; checkproper feed rates of amnonia(morpholine) and hydrazine;increase discharge of air

I ejector after-condenser drains,check feedwater chemistry;

'heck S/G Free Hydroxide

C-60-2

Low pH Condenser saltwaterinleakage, insuf-ficient ammonia(morpholine) feedrate, excessivedischarge of airejector aftercondenser drains.

Increase SG blowdown andincrease aomonia (morpholine)feed rate; terminate dischargeof air ejector after. condenserdrains; check for condensersaltwater inleakage; checkcondensate and feedwaterchemistry; verify correcthydrazine feed rate

C-6D-2E-4

SAMPLE POINTPARAMETER OUT OFSPECI FICATION POSSIBLE CAUSES CORRECTIVE ACTION

4. STEAM GENERATORBLO|IlDOMN

(Continued)

High sodium

High radioactivity

Saltwaterinleakage; insuf-ficient SG blow-down; blowdowncleanup deminera-lizer exhaustion

Primary-to-secondary leakage

Increase SG blowdown; checkfeedwater chemistry; checkperformance of blowdowncleanup demineralizers; checkfor condenser saltwater

'nleakage.

Terminate discharge of SG

blowdown; cut in blowdowncleanup demineralizers; checkactivity and leakrate for TechSpec compliance/action




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5. STEAM GENERATOR

STEAM

All other param-eters,- determinedby laboratoryanalysis of grab.samples

High specificconductivity withlow cation con-ductivity


Excessive ammonia(or morpholine)

Excessive carry'-over of non-volatile impur-ities in steamgenerator

Increase SG blowdown; checkfeedwater chemistry; checkfor correct feed rate ofammonia (morpholine) andhydrazine; check for condensersaltwater inleakage

Check for correct pH controlagent feed rate in condensate;check for excessive hydrazinefeed rate; check pH of steamgenerator. blowdown

Increase SG blowdown; SG blow-down cation conductivity shouldbe too high (refer to actionsoutlined above)

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SAMPLE POINT

6. CONDENSATESTORAGE TANK(CST)

PARAMETER OUT OFSPECIFICATION

All controlparameters, exceptdissolved oxygen

High dissolvedoxygen

POSSIBLE CAUSES

Makeup water outof specification;hotwell reject toCST out of speci-fication

Deaerator notfunctioningproperly; poorvacuum on seawater flash evap-orator

CORRECTIVE ACTION

Check makeup water supply toCST; if hotwell is out ofspecification (possibly due tocondenser saltwater inleakage),terminate hotwell rejection toCST, i.e., overboard excesswater

Check makeup water deaeratorperformance; check vacuumor sea water evaporator

APPENDIX 3 (Continued)TABLE A3-2

CORRECTIVE ACTIONS FOR OFF-CONTROL POINT CHEMICAL CONDITIONS IN THE SECONDARY CYCLE


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Documents

POWER NO PROC - NRC: Home PageDIABLO CANYON POWER PLANT NO OPERATING PROC F r, TITLE: CHEMICAL CONTROL LIMITS ~ 4 SCOPE This procedure specifies the chemical control operating 1imits