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AECL-5849
ATOMIC ENERGY W S & L'ÉNERGIE ATOMIQUEOF CANADA UMITED f & J T DU CANADA LIMITÉE
EFFECT OF CONDENSER WATER IN-LEAKAGE ON
STEAM GENERATOR WATER CHEMISTRY
Paper no. IWC-77-12
by
P.V. BALAKRISHNAN
38th Annual AAeeting of the International Water Conference
Pittsburgh, Pennsylvania, November 1-3, 1977
Chalk River Nuclear Laboratories
Chalk River, Ontario
January 1978
EFFECT OF CONDENSER WATER IN-LEAKAGEON STEAM GENERATOR WATER CHEMISTRY
Paper IWC-77-12 Presented at 38th Annual Meeting |International Water Conference *
Pittsburgh, Pennsylvania1-3 November 1977
Atomic Energy of Canada LimitedChalk River Nuclear LaboratoriesChalk River, Ontario KOJ 1JO
January 1978
AECL-5849
Effet des infiltrations d'eau du condenseur sur lachimie de l'eau des générateurs de vapeur "̂
par
P.V. Balakrishnan
Résumé
Des environnements corrosifs peuvent être engendrés dansdes générateurs de vapeur à partir d'infiltrations d'eau derefroidissement dans le condenseur. Une évaluation théoriqueainsi qu'expérimentale de l'agressivité de tels environnementsest effectuée pour les eaux de refroidissement du condenseurutilisées dans les centrales nucléaires CANDU-PHW*. Les calculsont montré que des solutions de chlorure fortement concentrées -acides dans le cas d'infiltrations d'eau de mer et alcalinesdans les autres cas considérés - seraient produites à l'intérieurdu générateur de vapeur. Des expériences effectuées dans unmodèle de chaudière ont montré que des infiltrations d'eau demer provoquent une corrosion rapide des composants en acier aucarbone seulement lorsque l'on utilise AVT** pour le contrôlede la chimie de l'eau. L'emploi d'un réactif non volatil,^comme dans le traitement au phosphate conforme a permis d'éviterla corrosion rapide de l'acier au carbone.
Selon nos études, le traitement au phosphate conformedurant les infiltrations d'eau de mer semble souhaitable.
Document IWC-77-12 présenté à la 38 e m e Assemblée annuellede l'International Water Conference, Pittsburgh, Pennsylvanie,1 - 3 novembre 1977.
CANada Deuterium Uranium - eau lourde pressurisée
* *AVT - Ail Volatile Treatment
L'Energie Atomique du Canada, LimitéeLaboratoires Nucléaires de Chalk River
Chalk River, Ontario KO j 1J0T • -imo AECL-5849Janvier 1978
EFFECT OF CONDENSER WATER IN-LEAKAGEON STEAM GENERATOR WATER CHEMISTRYt
\
by
P.V. Balakrishnan
ABSTRACT
Corrosive environments may be generated within steamgenerators from condenser cooling water in-leakage. Theoreticalas well as experimental evaluation of the aggressiveness ofsuch environments is being carried out for the condenser-coolingwaters used at CANDU-PHW* nuclear power stations. Calculationshave shown that highly concentrated chloride solutions - acidicin the case of sea-water, m-leakage, and alkaline in the restof the cases considered .- would be produced within the steamgenerator. Experiments in a model boiler showed that sea-waterm-leakage caused rapid corrosion of carbon steel componentswhen only AVT** was used for water chemistry control. Use of anon-volatile reagent, as in the congruent phosphate treatment,avoided the rapid corrosion of carbon steel.
On the basis of our studies, congruent phosphatetreatment during sea water in-leakage appears desirable.
+ Paper IWC-77-12 presented at 38th Annual Meeting,International Water Conference, Pittsburgh, Pennsylvania,1-3 November 1977.
* CANada Deuterium Uranium - Pressurized Heavy Water
** AVT - All Volatile Treatment
Atomic Energy of Canada LimitedChalk River Nuclear LaboratoriesChalk River, Ontario KOJ 1J0
January, 1978
AECL-5849
EFFECT OF CONDENSER WATER IN-LEAKAGE
ON STEAM GENERATOR WATER CHEMISTRY
by
P.V. Balakrishnan
Corrosion from the secondary side has contributed to
many boiler tube leaks in nuclear steam generators. The world
experience in steam generator tube failures has been documented
by Stevens-Guille and Hare in a series of reports. There
has been no corrosion-induced tube failure in any steam
generator of a CANDU-nuclear power station.
Corrosion in steam generators is caused by the accumu-
lation there of chemicals which are by themselves corrosive or
which, on concentration, generate a corrosive environment. Such
chemicals may be introduced into the steam generator with the
feed water via a leaking condenser which allows the raw
condenser cooling water to mix with the condensate. Undesir-
able chemicals may enter the steam generator also with the
make-up water because of improper operation of the make-up
water treatment plant. The phosphates used for water treatment
in some PWR* steam generators have also contributed to tube
failures.
Printed by permission of Conference Organizers
* Pressurized Water Reactor
CONCENTRATION OF NON-VOLATILE SOLUTES IN THE STEAM GENERATOR
Steam generators, by nature, are concentrators of non-
volatile solutes. Thus, a continuous injection of non-volatile
matter with the feed water into the steam generators causes the
solute to accumulate. If some of the water is continuously
blown down from the steam generator, the concentration which
the solute can attain in the bulk of the water is limited. The
steady state concentration factor will be the ratio of the feed
rate to the blowdown rate.
In addition to the above bulk concentration process,
there may be a further concentration within low flow areas in
the steam generators. The crevices within the tube-to-
tubesheet joints and those between the tube support plates and
tubes, sludge accumulated on the tube sheet, and porous
deposits on the tubes, are examples of such areas. Solute
concentration within porous deposits has been studied in :i(23) •}
detail. Models ' have been suggested for the
concentration process within deposits, all based on wick
boiling.(4)
Concentration of solutes in the water should lead to
changes in the composition of the solution, as the equilibria
(hydrolytic, ionization and solubility) in solution cause the
formation of different ionic species and precipitates. The
change in the composition of the solution may very well
generate an aggressive environment and cause corrosion problems
in the steam generator.
In the following, the effect of ingress of condenser
cooling water on the chemistry in CANDU-PHWR* steam generators
is discussed.
PHWR - Pressurized Heavy Water Reactor
REACTIONS IN STEAM GENERATOR WATER BETWEEN SOLUTE SPECIES
The analyses for major species in the cooling waters
now being used or soon to be used for the condensers in
CANDU-PHWR steam supply systems are given in Table 1.
The increase in concentration of the ionic species due
to evaporation in the steam generator results in the
precipitation of compounds whose solubility products have been
exceeded. This alteis the relative composition of solutes in
the water and the water may become acidic or alkaline, depend-
ing on the nature of the compounds that have precipitated. The
compounds that may precipitate at somewhat low concentrations
are :
calcium and magnesium carbonates
calcium and magnesium hydroxides
calcium sulphate and magnesium hydroxysulphate
Within crevices, very high concentrations are possible and
salts of higher solubility (e.g. sodium chloride, sodium
sulphate, etc.) may precipitate.
The following reactions are considered in this work:
HCO 3 -> OH + CO 2t . . . (1)
H 20 = H + + 0H~; K W = [H+][OH~] ... (2)
HSO~ = H + + S0~2; K H S Q = [H+][SO~2]/[HSO~] ... (3)
CaSO4(s) = C a+ 2 + SO~ 2; K C a S Q = [Ca + 2][SO~ 2] ... (4)
Ca(OH)2(s) = C a+ 2 + 20H"; K C a ( O H ) = [Ca + 2][OH~] 2 ... (5)
Mg(OH)+ = Mg + 2 + 0H~; K M g Q H = [Mg+2][OH~]/[Mg(OH)+] ... (6)
Mg(OH)2(s) = Mg+ 2 + 2OH~; K M g ( Q H ) = [Mg+2][OH~]2 ... (7)
MgSO4(s) = Mg+ 2 +"'so~2; K M g S Q = [Mg+2][so~2] ... (8)
Na2SO4(s) = 2 Na+ + SO~2; K^ S Q = [Na+]2[SO~2] ... (9)
2 4
NaCl(s) = Na+ + Cl"; K N a C 1 = [Na+][Cl~] ... (10)
CaCl2(s) = Ca+ 2 + 2 Cl"; K C a C 1 = [Ca+2][Cl"]2 ... (11)
MgCl2(s) - Mg+ 2 + 2 Cl"f K M g C 1 = [Mg+2][cl"]2 ... (12)
The above scheme of reactions is, perhaps, too simple. It
needs to be verified, since we do not really know that the
precipitates that would be formed in a steam generator have all
been included. No double or basic salts are considered in this
scheme because of a lack of thermodynamic data. The bicarbonate
ion is assumed to dissociate completely, the resulting carbon
dioxide being carried away from the system by steam. Because of
these simplifications, the results from this work may be taken
as only approximately defining the chemistry conditions in the
steam generator. Moreover, this scheme considers leakage of
salts iiito steam generator water that is untreated. The
results, however, should apply to water treated with a volatile
amine (e.g. ammonia, cyclohexylamine or morpholine) according to
the All Volatile Treatment (AVT) because the reagent usually
distributes preferentially to steam and because it is a weak
base and almost completely un-ionized at the operating
temperature of steam generators.
The equilibrium constants for the reactions at the
temperatures considered here are listed in Table 2. The terms
within the square brackets on the right-hand side of the
equations for equilibrium constants are the activities of the
corresponding ions. The activities are obtained by multiplying
the concentration in mol/kg by the activity coefficient. Use
of concentrations instead of activities in the expression for
equilibrium constants yields the concentration quotients, Q,
which are related to the thermodynamic equilibrium constants,
K, by the equation
K = Q.r ... (13)
The activity coefficient quotients, V, are described in terms
of the individual mean ionic activity coefficients, y, by
expressions analogous to those describing the equilibrium
constants (e.g. rNa;;SOi< = Y Na+#YSO'2) a n d a r e o b t a i n e d
from the modified Debye-Huckel expression of the form
S is a constant, for a given temperature; (Az ), the difference
in the sum of squares of the ionic charges betv;een the right-
hand side and the left-hand side of the equation representing
the chemical reaction; A, a constant at a given temperature for
a given equilibrium; and y the ionic strength of the medium.
The ionic strength, \i , is related to the molal ionic
concentration, m., and ionic charges, Z., by the relation
2u = h 2 m±z± ... (15)
i
The parameters for evaluation of activity coefficient quotients
are also shown in Table 2.
CALCULATIONS
The calculations consist of two parts. In the first
part the impurities entering the steam generator at a certain
rate from condenser in-leakage are considered to concentrate
there because water is removed as steam. The change in
concentration of a non-volatile solute is derived from the mass
balance equation
d CBv = F.C - B.C ... (16)dt F B
v = volume of the steam generator
C = concentration in the steam generatorB
C = concentration in the feed water, as a result of
condenser in-leakage
F = rate at which feed water enters the steam generator
B = rate at which the steam generator water is blown down
Equation (16), on integration, gives
CB = [1 - exp( - | . t ) ] . . . (17)
for the concentration at time, t. At steady state, when the
rate of input of impurities into the steam generator is equal
to the r a t e of removal by blowdown,
CB = F.CF/B . . . (18)
Calculations are done for the period from the start of the
condenser leak to steady state.
In the second part, the bulk water in the steam
generator is considered to concentrate within crevices, by
arbitrary factors until either equilibrium with respect to all
solute species is attained or the elevation of boiling point of
the solution because of increasing solute concentration
prevents the solution from boiling at the pressure in the
secondary system at the highest temperature attainable in the
steam, generator - the primary coolant temperature. The
elevation of boiling point, AT, is calculated using the
equation
AT = - £L_ in(l - x ) ... (19)AHv
where R = gas constant
T - temperature
AH = latent heat of vaporization of water at the
given pressure
total mol
solution
X = total mole fraction of all solutes in the
In either part the compounds whose solubility product:;
are exceeded are allowed to precipitate. The overall
concentration of the solute species in the water is obtained by
multiplying the feed concentrations by the appropriate
concentration factor. The net concentrations used in equations
(3) to (12) are obtained from the overall concentrations by
allowing for reduction in concentration due to precipitation of
the appropriate compounds whose solubility products are
exceeded. The values for the reduction in concentration due to
the formation of the various precipitates are at this stage
unknown and are solutions to the non-linear equations
represented by equilibria (2) to (12). An equation imposing
electroneutrality condition is added to these equations and
this set of equations is solved in the computer. Starting from
an approximate value for ionic strength, the calculations
refine the ionic strength value by iteration until convergence
is achieved. Calculations for the bulk concentration neglect-
any effect of precipitation within crevices.
CONCENTRATION OF SOLUTES IN STEAM GENERATOR WATER
Bulk Water
Three cases are considered.
1) Bruce Nuclear Generating Station, Ontario
Bruce NGS consists of four CANDU-PHW reactors, each of
nominal 750 MW(e )* capacity. Each reactor has eight steam
generators. Lake Huron water is used for condenser cooling. A
condenser leak rate per steam generator of 2,500 kg/h resulting
in 12.8 ;.g Na/kg in the feed wattr is considered.
2) Gentilly-2 Nuclear Generating Station, Quebec
Gentilly-2 NGS has a 600 MW(e) CANDU-PHW reactor with
four steam generators. St. Lawrence River water will be used
for condenser cooling. A condenser leak rate per steam
generator of 1,000 kg/h, which leads to 11.6 ug Na/kg in the
feed water, is treated.
3) Point Lepreau Nuclear Generating Station, New Brunswick
Point Lepreau NGS is similar to Gentilly-2, except
that it will use sea water for condenser cooling. A condenser
leak rate per steam generator of 5 kg/h giving rise to 63 yg
Na/kg in the feed water is considered.
The above leak rates are based on what is easily
detected by a sodium ion specific electrode and is possible to
locate.
The results of the calculations are shewn in Figures 1
to 4. Figures 1 to 3 show the buildup of Ca, Mg and Na
respectively, in the steam generator. The points at which a
compound starts precipitating is marked in the figures by a
vertical line with the appropriate label. Figure 4 shows the
change in pH for the three stations. The fresh waters
(Lake Huron and St. Lawrence River) are seen to be alkali-
forming and the sea water, acid-forming.
Table 3 gives the concentrations at steady state.
* electrical
Cirevices
Here the five cooling waters (Table 1) are considered
concentrated from their natural solute concentrations, rather
than from steady state concentrations in a steam generator.
Figures 5 to 8 show the buildup of the concentration of the
various ions as a function of concentration factor at a primary
temperature of 300°C. The appearance of a specific precipitate
is indicated at the corresponding concentration factor.
The concentration of each ion at the maximum
attainable concentration factor approaches the same value for
the fresh waters (except for Ottawa River water for which the
calculation could not be done up to the maximum concentration
factor because of some computational problems). Sea water
attains saturation with respect to each of the solute species
at 300°C.
Figure 9 shows the change in pH o as a 'function of
concentration factor in crevices. The sea water turns acid and
the fresh waters alkaline. Among the fresh waters, Lake Huron,
St. Lawrence River and Lake Ontario waters behave similarly
with respect to change in pH, with alkalinity decreasing in
that order. The Ottawa River water shows much higher
alkalinity than the other fresh waters at the same
concentration factor and the pHo^o shows an increasing trend
up to the highest concentration factor (10 ) considered.
Alkalinity results from the decomposition of the bicarbonate
ion (reaction 1)
HCO- •* CO2+ + OH~ ... (1)
Acidity results from the hydrolytic reactions (5a) to (7a).
Ca+2 + 2H2O + Ca(OH)2 + 2H+ ... (5a)
Mq+2 + H2O -> Mg(OH)+ + H+ ... (6a)
Mg + 2 + 2H2O - Mg(OH)2 + 2H+ ... (7a)
10
The calciu..i and magnesium concentrations in Ottawa River water
are much lower than those in the remaining fresh waters (Table
1). The Ottawa River water should, therefore, be much less
acidic, i.e. more alkaline than the other fresh waters.
Table 4 gives the maximum attainable concentrations
within crevices at a temperature of 300°C and Table 5 those at
275°C. The fresh waters all lead to alkaline solutions of high
chloride concentration, sodium and calcium chlorides being the
principal solutes. Sea water leads to an acid solution of high
chloride concentration, with sodium and magnesium chlorides as
the principal solutes. The concentrations at 275°C are lower
than those at 300°C.
POSSIBLE EFFECTS OF THE CONCENTRATION OF SOLUTES IN
STEAM GENERATORS
If the ionic species from the condenser cooling water
can concentrate to the maximum possible concentration within
crevices in the steam generator, corrosion may occur at an
accelerated rate at these sites. The types of corrosive attack
which have occurred in steam generators are caustic-induced
stress corrosion cracking of the tubes (Inconel-600 or
Incoloy-800), pitting and general metal wastage, also of the
tubes, usually caused by acid conditions, and corrosion of
other parts, e.g. the carbon steel tube support plates in the
steam generator.
The fresh waters all lead to alkaline solutions when
concentrated, but no cracking of Fe-Ni-Cr alloy tubes has been
observed in laboratory tests at the low concentrations of
alkali that are calculated to result from condenser leakage.
Thus, based on the current information on caustic cracking,
condenser in-leakage does not pose a threat, except perhaps
with Ottawa River water.
The acid chloride solution produced from sea water
could corrode carbon steel components, particularly the tube
11
support plates which form crevices around the tubes. Potter
and Mann have shown that carbon steel corrodes at a fast
and linear rate in 0.1 mol/kg FeCl solution at 300°C. A
similar situation is possible with concentrated sea water. The
phenomenon of tube denting* seen in some PWR steam generators
has been attributed to the rapid corrosion of the tube support
plates within crevices. Denting has been seen mostly with sea-
water cooled PWR's and it has been more severe in the hot leg
than in the cold leg. The calculations reported here do show
that the concentration of solutes at the lower temperature of
275°C is less than that at 300°C, which suggests a lower
corrosion rate in the cold leg than in the hot leg, as
indicated by the relative severity of denting at these
locations.
MODEL BOILER EXPERIMENTS
Experiments to study the effect of sea-water
in-leakage on corrosion were carried out in a model boiler.
The boiler had a single U-tube of Incoloy-800, the preferred
alloy for CANDU steam generators. A concentrating device (a
carbon steel umbrella), shown in Figure 10, was appended to one
leg of the tube to provide a crevice around the tube where
steam blanketing and concentration of chemicals could occur.
The heat required for the operation of the boiler was derived
from a high-temperature high-pressure loop. The water from the
loop flowed through the tube and boiled the secondary water in
the shell. The steam produced was condensed in a condenser
tubed with copper. The flow in the secondary system was
* Denting is the reduction in the diameter of the steamgenerator tubes within tube support plates.
12
maintained by natural convection (density differences). The
loop and the model boiler are shown schematically in Figure 11.
The operating conditions of the system are given in Table 6.
The sea water was injected into the boiler with the
make-up water. When phosphate treatment was used for the
boiler water the phosphates were pumped into the boiler. A
steady rate of blowdown was maintained. Analyses of samples of
the blowdown liquid, the make-up water and the feed water were
done periodically for pH, conductivity, chloride, phosphate,
sodium, calcium and magnesium.
Congruent Phosphate Treatment (CPT) and Sea-Water Injection !
During one phase of the experiments, the boiler water £
was treated according to the congruent phosphate treatment !\i
method, while injecting sea water into the boiler to simulate ;',
condenser leakage. The chemistry conditions were as follows: ?
pH =9.8
phosphate = 18 mg PO./kg water (average)
chloride (from sea water) = 17 to 55 mg Cl/kg (32 mg/kg average)
oxygen = 10 pg/kg
morpholine ~ 6 mg/kg
The observed pH of 9.8 at the morpholine concentration of
~6 mg/kg corresponds to a sodium-to-phosphate molar concen-
tration ratio of «2.4:1. (The desired range for this ratio is
2.2 to 2.6:1.) After 47 days, the tube was covered with a
thick black deposit composed of corrosion products (mainly
magnetite) and the products from sea-water salts (calcium
phosphate, magnesium hydroxide). No localized corrosion was
observed on the tube, even under crevices. The carbon steel
13
umbrella used as the concentrating device did not show any
localized or general corrosion.
All Volatile Treatment and Sea-Water Injection
During this phase the water was treated with
morpholine (a volatile amine), while sea-water injection was
maintained. This phase was started with a clean tube, i.e. no
prior deposit. The boiler chemistry conditions were:
pH = 9.5 to 9.6 (with morpholine)
chloride = 8 to 60 mg Cl/kg water (average 30 mg/kg)+ 2
Mg = 1.5 to 2.3 mg/kg as Mg+ 2
Ca = 1.4 to 4.3 mg/kg as Ca
oxygen = 5 to 10
The pH tended to drift towards lower values and it required
more morpholine than normally required to maintain the pH in )
the same range in the absence of sea water. About 12 mg/kg was
normally sufficient in the absence of sea water, but up to 25
mg/kg was required with sea-water injection. This behaviour
illustrates the acid-forming nature of sea water.
After 47 days the deposit formed in this phase was
thinner than that formed with CPT, but its chemical composition
was similar.
There was no evidence of localized attack on the tube,
but the carbon steel umbrella was severely corroded (Figure 1 2 ) .
The original wall thickness of 0.57 mm at the neck of the
umbrella was completely penetrated in 47 days. This allows an
estimate for the corrosion rate of greater than 900 mg/(dm'.day)
This high corrosion rate must have been due to the very high
chloride concentration and the acid pH that would have existed
in the crevice within the umbrella. This contrasts with the
lack of significant corrosion when congruent phosphate
14
treatment was used to counter the effects of sea water. The
non-volatile phosphate buffer system prevented the pH from
going to the acid side. The volatile amine, morpholine, which
is also only a weak base and hence mostly un-ionized at the
boiler temperature, was inadequate for this purpose.
Interpretation
The experiments described demonstrated that sea-water
in-leakage into boiler water treated with volatile amines would
result in accelerated corrosion of carbon steel components. If
the pH was maintained alkaline with a non-volatile buffering
reagent during the sea-water in-leakage, the rapid corrosion of
carbon steel and the related problems would be suppressed. The
buffering reagent may be sodium phosphates as in the congruent
phosphate treatment, borate or another suitable system.
SUMMARY AND CONCLUSIONS
Calculations show that concentration of the fresh
waters that are being used now or soon to be used for cooling
condensers at CANDU-PHWR stations lead to alkaline solutions of
high chloride concentration. Sea water, on concentration,
leads to highly concentrated chloride solutions of acid pH.
Model boiler experiments have shown that sea-water
in-leakage countered only by volatile treatment of the boiler
water would lead to rapid corrosion of carbon steel.
Accelerated corrosion of carbon steel has been the cause of
denting of tubes in some steam generators. A non-volatile
buffering reagent, such as the sodium phosphates, controls the
chemistry so that the corrosion of carbon steel is suppressed.(14 1
The current recommendation ' for secondary water
treatment for CANDU-steam generators at sea-water cooled
stations is to use AVT during normal conditions, but to switch
to a low concentration (2 to 10 mg PO /kg water) congruent
15
phosphate treatment with the sodium to phosphate molar concen-
tration ratio in the range (2.2:1) to (2.6:1) on detecting a
condenser leak. The phosphate treatment is to be maintained
until the leak is located and corrected, when the treatment is
to be returned to AVT. The findings from the work reported in
this paper, i . e . the inadequacy of AVT during sea-water
in-leakage for the protection of carbon steel components in the
steam generator and the desirabil i ty of using a non-volatile
buffering system for this purpose, support this water treatment
approach.
ACKNOWLEDGEMENT
The contribution of D.P. Martin in developing the
computer program used in this work has been very valuable.
16
REFERENCES
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World Survey of Water-Cooled Nuclear Power Reactors to
the End of 1971", AECL-4449, Atomic Energy of Canada
Limited (1973).
b) Stevens-Guille, P.D., "Steam Generator Tube Failures:
World Experience in Water-Cooled Nuclear Power Reactors
During 1972", AECL-4753, Atomic Energy of Canada Limited
(1974).
c) Stevens-Guille, P.D. and Hare, M.G., "Steam Generator
Tube Failures: World Experience in Water-Cooled Nuclear
Power Reactors in 1973", AKCL-5013, Atomic Energy of
Canada Limited (1975).
d) Hare, M.G. , "Steam Generator Tube Failures: World
Experience in Water-Cooled Nuclear Power Reactors in
1974", AECL-5242, Atomic Energy of Canada Limited (1975).
e) Hare, M.G., "Steam Generator Tube Failures: World
Experience in Water-Cooled Nuclear Power Reactors in
1975", AECL-5625, Atomic Energy of Canada Limited (1976).
2. Collier, J.G. and Kennedy, T.D.A., "Solute Concentration
in Highly Rated High Pressure Steam Generators.
I. A Model for the Concentration of Solute Within the
Pores of a Magnetite Deposit", AERE-R 7203, United
Kingdom Atomic Energy Authority, Harwell, UK (1972).
3. Cohen, P., "Heat and Mass Transfer in Porous Deposits
with Boiling", WARD-5836, Westinghouse Electric Corpor-
ation, Madison, Pa., USA (1972).
17
4. Macbeth, R.V., "Boiling on Surfaces Overlayed with a
Porous Deposit: Heat Transfer Rates Obtainable by
Capillary Action", AEEW-R 711, United Kingdom Atomic
Energy Authority, Winfrith, UK (1971).
5. Fisher, J.R. and Barnes, H.L., "The Ion-Product Constant
of Water to 350°C", J. Phys. Chem. 76, 90 (1972).
6. Marshall, W.L. and Jones, E.V., "Second Dissociation
Constant of Sulfuric Acid from 25° to 350° Evaluated
from Solubilities of Calcium Sulfate in Sulfuric Acid
Solutions", J. Phys. Chem. JO, 4028 (1966).
7. Helgeson, U.C., "Thermodynamics of Hydrothermal Systems
at Elevated Temperatures and Pressures", Amer. J. Science
267, 729 (1969) .
8. Marshall, W.L., "Thermodynamic Functions at Saturation of
Several Metal Sulfates in Aqueous Sulfuric and Deutero-
sulfuric Acids at Temperatures up to 350°C", J. Inorg.
Nucl. Chem. 37' 2 1 5 5 (1975).
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Temperatures XVIII. Activity Coefficient Behaviour of
Calcium Hydroxide in Aqueous Sodium Nitrate to the
Critical Temperature of Water", J. Phys. Chem. T^, 2641
(1967).
10. Mellor, J.W., "A Comprehensive Treatise of Inorganic and
Theoretical Chemistry", Vol. Ill, Longman, Green & Co.,
New York, p 702 (1946).
\
18
11. Cohen, P., "The Chemistry of Water and Solutions at High
Temperatures for Application to Corrosion in Power
Systems", WARD-5788, Westinghouse Electric Corporation,
Advanced Reactors Division, Madison, Pa., USA, p 38
19 72) .
12. Liu, C-T and Lindsay, W.T., Jr., "Thermodynamics of
Sodium Chloride Solutions at High Temperatures", J.
Solution Chem. 1, 45 (1972).
13. Potter, E.C. and Mann, G.M.W., "The Fast Linear Growth
of Magnetite on Mild Steel in High-Temperature Aqueous
Conditions", British Corrosion Journal, 1, 26 (1965).
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Tubing Material - Service Experience and Allied Develop-
ment", AECL-5384, Atomic Energy of Canada Limited (1976).
19
TABLE 1
RAW WATER QUALITY DATA
Calcium
Magnesium
Sodium
Potassium
Sulphate
Chloride
Bicarbonate
OttawaRiver '
6.5
2.5
4
3.2
7
2.4
ConcentrationLakeHuron2
25-28
7-9
3-4
0.8-1.3
12-15
5-8
95-110
LakeOntario3
38-41
7.5-8
10-14
1-1.5
28
28-30
120
(mg/kg)St. Lawrence
River **
27
8
10
2
26
21
80
AtlanticOcean 5
400
1,272
10,556
380
2,649
18,980
140
1 Used at Nuclear Power Demonstration (NPD) Generating Station
2 Used at Bruce Generating Station and Douglas Point Generating Station
3 Used at Pickering Generating Station
11 To be used at Gentilly-2 Generating Station
5 To be used at Point Lepreau Generating Station
TABLE 2
EQUILIBRIUM CONSTANTS AND SOLUBILITY PRODUCTS
Reaction
H 20 = H + 0H~
HSO4 = H + S0 4
Mg(OH) = Mg +
CaSO4(s) = Ca *
Ca(OH)2(s) = Ca
CaCl2(s) = Ca
CH
Mg(OH)2(s) = Mg
+ 2MgSO (s) = Mg
4MgCl (s) = Mg + 2
+ 2
2 OH
2 OH
2 Cl"
(s) 2 Na + SO" 2
NaCl(s) = N a + + Cl"
(Ref.
(Ref.
(Ref.
(Ref.
(Ref.
(Ref.
(Ref.
(Ref.
(Ref.
(Ref.
(Ref.
5)
6)
7)
8)
9)
10)
11)
8)
10)
8)
12)
8
1
1
9
4
1
250(S = 0.K
.912xlO~
.05xl0~5
.OOxlo"
.311xlO~9
-9.270x10
.07x10
°C9848)
A
1
1
2
1
2
2
.45
.77
.14
.60
.14
.14
9.
4.
4.
2.
1.
275°(S = 1.
K
772xlO~
5SxlO~6
-650x10
290xl0~9
352x10
127:
3.
3.
.40x10
,462x10
11.72
9.
4,
.521xlO"6
.425
C112
1.
1.
2.
1.
2.
2.
2.
1,
2.
0,
1
A
33
77
15
60
15
15
,15
,60
.15
.62
.33
9.
1.
2.
5.
4.
300(S = 1K
120xlO~
94xl0~6
00xl0~
-10636x10
130xl0~i0
45'
1.
4.
4
4
2
.04X10"1
-8.634x10
.2"
.550xl0~6
.248
°C.287
1.
1.
2.
1.
2.
2.
2.
1.
2.
0,
1
A
20
73
16
60
1 6
o16
,16
,60
.16
.72
.20
1 Estimated from the solubility of calcium chloride at 260°C, given in Reference 10.
2 Estimated from the solubility of magnesium chloride at 181°C, given in Reference 10.
TABLE 3
STEADY STATE CONCENTRATIONS IN STEAM GENERATOR BULK WATER
Blowdown Rate = 0.1% of Steaming RateTemperature = 250°C
Condenser C o n c e n t r a t i o n (mmol/kg) EquivalentWater pH o
(leakage rate) Ca Mg Na K S O . C l 5 c
Sea water 0.059 0.311 2.73 0.058 0.164 3.184 5.42(5 kg/h)
St . Lawrence 0.510 0.014 0.507 C.060 0.040 0.691 10.92River(1000 kg/h)
Lake Huron 1.419 0.048 0.644 0.087 0.021 0.896 11.42(2 500 kg/h)
22
TABLE 4
MAXIMUM POSSIBLE CONCENTRATION IN CREVICE
Temperature - Primary: 300°C- Secondary: 250°C
Calcium
Magnesium
Sodium
Sulphate
Chloride
P H25°C
Fresh Water*(mol/kg)
14.36
1.72xlO"3
5.42
3,17xlO"5
34.15
10.41
Sea Water(mol/kg)
0.134
11.10
6.17
3.90xl0~3
28.56
3. 52
* Lakes Huron and Ontario, St. Lawrence River
23
TABLE 5
MAXIMUM POSSIBLE CONCENTRATION IN CREVICE
Temperature - Primary: 275°C- Secondary: 250°C
Fresh Water(mol/kg)
Sea Water(mol/kg)
Calcium
Magnesium
Lake Huron Lake Ontario
1.45
3.47x10-4
1.96
4.21x10-4
9.35x10
1.44
-3
Sodium
Sulphate
9.04
8.84x10,-5
8.28
6.86x10-5
9.06
1.45x10"
Chloride 11.95 12.20 11.91
pH 10.86 10.80 4.42
24
TABLE 6
OPERATING CONDITIONS OF THE MODEL BOILER SYSTEM
Primary Circuit
Temperature - boiler inlet: 3Q0°C
Pressure:
Flow rate:
PH:
Oxygen:
Purification flow:
Make-up water:
9.0 MPa
1.1 to 1.5 kg/s
10 to 10.5 {with LiOH)
<5 ug/kg {controlled bycatalyzed hydrazine)
«10% of the loop flow
distilled, deionized,deoxygenated water
Secondary Circuit
Temperature - steam:
- condensate:
- feed water:
Steaming rate:
Boiler pressure:
Blow down:
251°C
95°C
170°C
0.063 kg/s
4.1 MPa
=1% steaming rate
25
I - 2
•et
o
BUILDUP OF CALCIUM IN WATERTEMPERATURE: 250°CBLOWDOWN: O.I* OF STEAMING RATE
BRUCE - LAKE HURON ( 2500 ,kg/h )
G-2 - ST. LAWRENCE RIVER (1000 kg/h)
PT. LEPREAU - SEA (5 kg/h)
SOLID PRESENT - A: CaS04
B: Ca(0H)2
2 0 3 0T I M E ( H O U R S )
F I G 1 B U I L D U P O F C A L C I U M C O N C E N T R A T I O N I N S T E A MG E N E R A T O R W A T E R(CONDENSER LEAK RATES W I T H I N PARENTHESES)
26
- 3
où
oE
ai
oC_3
BUILDUP OF MAGNESIUM IN WATERTEMPERATURE: 250°CBLOWDOWN: 0. \% OF STEAMING RATE
PT. LEPREAU - SEA (5 kg/h)
G2 - ST. LAWRENCE RIVER ( 1000 kg/h)
10 - 6
BRUCE - LAKE HURON (2500 kg/h)
D - SOLID Mg(OH)2 PRESENT
_J I I I
0 0 502 0 3 0 4 0T I M E ( H O U R S )
F I G . . 2 B U I L D U P O F M A G N E S I U M C O N C E N T R A T I O N I N S T E A MG E N E R A T O R W A T E R(CONDENSER LEAK RATES W I T H I N PARENTHESES)
27
- 2
oc
UJ
oo
FIG.
BUILDUP OF SODIUM IN WATERTEMPERATURE: 250°CBLOWDOWN: 0. \% OF STEAMING RATE
I40 502 0 3 0
T I M E ( H O U R S )
3 B U I L D U P O F S O D I U M C O N C E N T R A T I O N I N S T E A MG E N E R A T O R W A T E R(CONDENSER LEAK RATES WITHIN PARENTHESES)
28
1 2. 0
0. 0
8 . 0 -
6 . 0 -
4. 0
2. 0
j/\^ BRUCE - LAKE
\. G2 - ST. LAWRENCE
PT. LEPREAU - i
TEMPERATURE: 250°BL0WD0WN: 0. \ai
1 i
.
HURON
RI
SEA
C; OF
VER
(5
( 2500
( !000
kg/h)
STEAMING
i
kg/h)
kg/h)
RATE
i
0 0 2 0 3 0 4 0 5 0
T I M E ( H O U R S )
F I G . . 4 C H A N G E I N p H ^ I N S T E A M G E N E R A T O R W A T E R
(CONDENSER LEAK RATES W I T H I N PARENTHESES)
29
ozo
- 1
-3
BUILDUP OF CALCIUM CONCENTRATIONTEMPERATURE - PRIMARY: 300'
- SECONDARY:
SOLID PRESENT
A: CaS04
B: Ca(OH),
-5
-6
ION
ST. LAWRENCE RIVER
LAKE HURON
OTTAWA RIVER
I I I0 1 2 3 4 5 6
log (CONCENTRATION FACTOR)
FIG.. 5 BUILDUP OF CALCIUM CONCENTRATION WITHIN CREVICES
3 0
2
0aa
JE
\
Ê -1
ION
t—
"* - 2(—
ICE
N
s -3
o
- 4<
I-5
-6
-
y
"IT
BUILDUP OF MAGNESIUM CONCENTRATION
SATURATION
y ^ - SECONDARY: 250°C
y SOLID PRISENT:
^ / D: Mg(0H)2
/ E: MgSO4
F: HgCI2
LAKE ONTARIO
ST. LAWRENCE s ' / r <
^ ^ ^ < ^ ^ a ' ^ k \ L A K E HURON
^^^KOTTAWA RIVER
>Q 01 1 1 1 1 1
0 1 2 3 4 5 6 7
log (CONCENTRATION FACTOR)
FIG.. 6 BUILDUP OF MAGNESIUM CONCENTRATION WITHIN CREVICES
31
ozo
-5
-60
I1
SATURATION(SEA)
LAKE O N T A R I O
ST. L A W R E N C E RIVER
LAKE HURON
OTTAWA RIVER
BUILDUP OF SODIUM CONCENTRATION
TEMPERATURE - PRIMARY: 300°C- SECONDARY: 25O°C
SOLID PRESENT
G: NaCl
I I I 12 3 4 5 6
log (CONCENTRATION FACTOR)
FIG.. 7 BUILDUP OF-SODIUM CONCENTRATION WITHIN CREVICES
32
e t
UJooo
-5 -
-6
SEA
. LAWRENCE RIVER
SATURATION
(SEA)
R I V E R
BUILDUP OF CHLORIDE CONCENTRATIONTEMPERATURE - PRIMARY: 3OO°C
- SECONDARY: 250°CSOLIDS PRESENT:
G: NaCII
F: M g C I
I 2 3 1 5 6l o g ( C O N C E N T R A T I O N FACTOR)
F I G . 8 BUILDUP OF CHLORIDE CONCENTRATION WITHIN CREVICES
vr> Q
OTTAWA RIVER
LAKE HURON
ST. LAWRENCE R IVER
TEMPERATURE - PRIMARY: 300°C- SECONDARY: 250°C
SEA
I I II 2 3 4 5 6
lo g ( C O N C E N T R A T I O N F A C T O R )
F I G . 9 C H A N G E IN p H 2 5 e c W I T H I N C R E V I C E S
34
HOSE CLAMP
UMBRELLA
BOILER TUBE
FIGURE 10 THE CONCENTRATING DEVICE (UMBRELLA)ON BOILER TUBE
MAKEUPTANK
CHEMICAL MAKE-UPDISTILLED WATER
TEST SECTION 9HEATER
CHEMICAL MAKE-UPDISTILLED WATER
CONDENSER
MODEL BOILER
6 KW HEATER
BLOWDOWN
PRIMARY
= SECONDARYAUXILIARY
MAKE-UP PUMP
SEA_WATER
""-S
MAKEUP
TANK
MAKE-UP PUMP
PHOS-PHATETANK
F I G U R E 1 1 S C H E M A T I C D I A G R A M O F M O D E L B O I L E R I N S T A L L A T I O N
36
FIGURE 12 THE CARBON STEEL UMBRELLA AFTER EXPOSURETO SEA WATER AND AVT FOR 47 DAYS.
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