b31.3 process piping course - 03 materials-libre

8/10/2019 B31.3 Process Piping Course - 03 Materials-libre

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ASME B31.3 Process Piping Course 3. Materials

BECHTENGINEERING COMPANY, INC. Materials - 1

ASME B31.3 Process Piping

Charles Becht IV, PhD, PE

Don Frikken, PE

Instructors


1. Establish applicable system standard(s)2. Establish design conditions3. Make overall piping material decisions

Pressure Class

Reliability

Materials of construction

4. Fine tune piping material decisions Materials

Determine wall thicknesses

Valves

5. Establish preliminary piping system layout & support

configuration6. Perform flexibility analysis7. Finalize layout and bill of materials8. Fabricate and install9. Examine and test

Piping Development Process


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3. Materials

Strength of Materials

Bases for Design Stresses

B31.3 Material Requirements

Listed and Unlisted Materials

Temperature Limits

Toughness Requirements

Fluid Service Requirements

Deterioration in Service


The Material in This Section isAddressed by B31.3 in:

Chapter II - Design

Chapter III - Materials

Appendix A - Allowable Stresses & QualityFactors Metals

Appendix F - Precautionary Considerations


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StressStrain

Stress-Strain Diagram Elastic Modulus

Yield Strength

Ultimate Strength

Creep

Fatigue

Brittle versus Ductile Behavior


Strength of MaterialsStress (S): force (F) divided by area (A)

over which force acts, pounds force/inch2

(psi), Pascals (Newtons/meter2)

Strain (): change in length (L) divided

by the original length (L)

F

L L


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Strain

Stress

E = Elastic Modulus = Stress/Strain

SY = Yield Strength

ST = Tensile Strength

Typical Carbon Steel



ST = Tensile Strength

Typical Stainless Steel Strain

Stress

SY = Yield Strength

0.2% offset

Proportional Limit


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Creep: progressive permanentdeformation of material subjected toconstant stress, AKA time dependentbehavior. Creep is of concern for

Carbon steels above ~700F (~370C)

Stainless steels above ~950F (~510C)

Aluminum alloys above ~300F (~150C)



Time

Strain

Primary Secondary Tertiary

Rupture

Creep Rate (strain/unit time)

Typical Creep Curve


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Minimum Stress to Rupture, 316 SS

Fig I-14.6B, ASME B&PV Code, Section III, Division 1 - NH



Stress

Number of Cycles

Fatigue failure: a failure which results from arepetitive load lower than that required to causefailure on a single application


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Brittle failure:

Ductile deformation:


Strength of MaterialsBrittle failure:

Ductile failure:

Strain

Stress

Toughness

Strain

Stress

Toughness


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Measuring Toughnessusing a Charpy impacttest H1

Charpy Impact Test

Cv = W(H1 - H2)

= Energy Absorbed

H2

H1 -H2W

Pendulum

Specimens tested at 40, 100 and 212F(4, 38 and 100C)



Ductile to Brittle Transition for a Carbon Steel


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Most Materials

Bolting

Gray Iron

Malleable Iron


Bases for Design StressesMost Materials (materials other than grayiron, malleable iron and bolting) below thecreep range, the lowest of (302.3.2)

1/3 of specified minimum tensile strength (ST)

1/3 of tensile strength at temperature

2/3 of specified minimum yield strength (SY)

2/3 of yield strength at temperature; exceptfor austenitic stainless steels and nickelalloys with similar behavior, 90% of yieldstrength at temperature


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Most Materials additional bases in thecreep range, the lowest of (302.3.2)

100% of the average stress for a creep rateof 0.01% per 1000 hours

67% of the average stress for rupture at theend of 100,000 hours

80% of the minimum stress for rupture at theend of 100,000 hours


Bases for Design StressesASTM A106 Grade B Carbon Steel (US Customary Units)

0.00

5.00

10.00

15.00

20.00

25.00

0 200 400 600 800 1000

Temperature, F

Stress,

ksi

2/3 of Yield

1/3 of Tensile

Allowable


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ASTM A106 Grade B Carbon Steel (Metric Units)

0.0

20.0

40.0

60.0

80.0

100.0

120.0

140.0

160.0

180.0

0 100 200 300 400 500

Temperature, C

Stress,

MPa

2/3 Yield

1/3 Tensile

Allowable


Bases for Design StressesASTM A312 Gr TP316 Stainless Steel (US Customary Units)

0.00

5.00

10.00

15.00

20.00

25.00

30.00

0 200 400 600 800 1000

Temperature, F

Stress,

ksi 2/3 Yield

90% Yield

1/3 Tensile

Allowable


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ASTM A312 Gr TP316 Stainless Steel (Metric Units)

0.0

20.0

40.0

60.0

80.0

100.0

120.0

140.0

160.0

180.0

200.0

0 100 200 300 400 500

Temperature, C

Stress,

MPa

2/3 Yield

90% Yield

1/3 Ultimate

Allowable


Bases for Design StressesAdditional Notes

For structural grade materials, design

stresses are 0.92 times the value determinedfor most materials (302.3.2)

Stress values above 2/3 SY are notrecommended for flanged joints and othercomponents in which slight deformation can

cause leakage or malfunction (302.3.2)

Design stresses for temperatures below the

minimum are the same as at the minimum


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Bolting below the creep range, the lowestof (302.3.2)

1/4 of specified minimum tensile strength(ST); if properties are enhanced by heattreatment or strain hardening, 1/5 ST


2/3 of specified minimum yield strength (SY);if properties are enhanced by heat treatment

or strain hardening, 1/4 SY 2/3 of yield strength at temperature


Bases for Design StressesBolting additional bases in the creeprange, the lowest of (302.3.2)

100% of the average stress for a creep rateof 0.01% per 1000 hours

67% of the average stress for rupture at theend of 100,000 hours

80% of the minimum stress for rupture at the

end of 100,000 hours


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Gray Iron the lowest of (302.3.2)

1/10 of specified minimum tensile strength(ST)



Bases for Design StressesMalleable Iron the lowest of (302.3.2)

1/5 of specified minimum tensile strength (ST)



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B31.3 Material Requirements


Temperature Limits

Impact Test Methods & Acceptance

Toughness Requirements

Fluid Service Requirements


Listed and Unlisted Materials Listed Material: a material that conforms

to a specification in Appendix A or to astandard in Table 326.1 may be used(323.1.1)

Unlisted Material: a material that is notso listed may be used under certainconditions (323.1.2)

Unknown Material: may not be used(323.1.3)


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An unlisted material may be used if(323.1.2)

It conforms to a published specificationcovering chemistry, mechanical properties,method of manufacture, heat treatment, andquality control

Otherwise meets the requirements of theCode

Allowable stresses are determined in

accordance with Code bases, and

Qualified for serviceall temperatures (323.2.3)


Temperature LimitsListed materials may be used above themaximum described in the Code if (323.2.1)

There is no prohibition in the Code

The designer verifies serviceability of thematerial, considering the quality of mechanicalproperty data used to determine allowablestresses and resistance of the material to

deleterious effects in the planned fluid service(323.2.4)


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Temperature Limits

Listed materials may be used within thetemperature range described in the Code if(323.2.2)

The base metal, weld deposits and heataffected zone (HAZ) are qualified inaccordance with Column A of Table 323.2.2.


Table 323.2.2Requirements for Low Temperature Toughness Tests

Seepag

e21ofthesu

pplemen

t.


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Temperature Limits

Listed materials may be used below theminimum described in the Code if (323.2.2)

There is no prohibition in the Code

The base metal, weld deposits and heataffected zone (HAZ) are qualified inaccordance with Column B of Table 323.2.2.


Carbon Steel Lower Temperature Limits Most carbon steels have a letter

designation in the column for minimumtemperature in Appendix A

See page 26 of the supplement

Note Min. Temp. column

Read Appendix A note 7

Read Appendix A note 4 & see page 27 For those that do, the minimum

temperature is defined by Figure 323.2.2A


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Figure 323.2.2AMinimum Temperatures without Impact Testing for Carbon Steel

Seepag

e23oft

hesupp

lement.


Carbon Steel Lower Temperature Limits Impact testing is not required down to

-55F (-48C) if stress ratio does notexceed the value defined by Figure323.2.2B

Impact testing is not required down to-155F (-104C) if stress ratio does not

exceed 0.3


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Fig.323.2.2BReduction in Minimum Design Temperature w/o Impact Testing

See page 24 of the supplement.


Carbon Steel Lower Temperature LimitsFig.323.2.2B provides a further basis for useof carbon steel without impact testing. Ifused: Hydrotesting is required

Safeguarding is required for components withwall thicknesses greater than in. (13 mm)

Stress Ratiois the largest of

Nominal pressure stress / S Pressure / pressure rating

Combined longitudinal stress / S


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Carbon Steel Lower Temperature Limits

Design Pressure: 650 psig(45 bar)

Design Temperature:735F (390C).

Pipe material is ASTM A53Gr B seamless.

What options are availableto deal with expected

ambient temperaturesdown to -30F (-34C)? 0.971.000

(25.40)

30

(750)

0.860.500

(12.70)

12

(300)

0.740.237

(6.02)

4

(100)

0.710.178(4.52)

1

(25)

StressRatio

NominalWTin (mm)

NPS

(DN)


Impact Test Methods and Acceptance Impact testing is done in accordance with

ASTM A370

Each set of impact test specimensconsists of 3 bars

Impact test temperature:

For full size (10 mm square) Charpy V-notch

specimens, the design minimum temperature For subsize specimens smaller than 8 mm,

below the design minimum temperature[323.3]


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Impact Test Methods and Acceptance

Acceptance criteria Most steels, based on energy absorbed per

Table 323.3.5

For high strength steels, including bolting,based on minimum lateral expansion of0.015 in. (0.38 mm) opposite the notch

Retest of a second set of three specimensis permitted under certain conditions.

[323.3]


Fluid Service Requirements (323.4.2)

Ductile Iron

generally limited to temperature range of

-20F to 650F (-29C to 343C) and B16.42ratings

welding is not permitted


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Other Cast Irons may not be used under severe cyclic

conditions

may be used for other services ifsafeguarded for heat, thermal andmechanical shock, and abuse

may not be used in above ground flammableservice above 300F (149C) or above 400

psi (2760 kPa)


Fluid Service Requirements (323.4.2) Gray Iron

may not be used in flammable service above150 psi (1035 kPa)

may not be used in other services above 400psi (2760 kPa)

Malleable Iron may not be used outside -20F to 650F

(-29C to 343C) High Silicon Iron

may not be used in flammable service


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Aluminum Castings the designer is responsible for establishing

design stresses and ratings if thermal cutting isused

Lead, Tin & their Alloys

may not be used with flammable fluids

Clad Materials

cladding may be considered to be part of thethickness of components under certainconditions


Deterioration in Service Selection of material to resist deterioration

in service is not within the scope of theCode. (323.5)

Recommendations for material selectionare presented in Appendix F.

General considerations

Specific material considerations


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Deterioration in Service

Types of Damage Mechanisms Loss of metal

Stress Corrosion Cracking

Metallurgical and Environmental Degradation


Loss of MetalLoss of metal can be

General

Localized

depending on thephysical conditions andthe specific mechanism.

A Rainbow of Rust Colors


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Loss of Metal

Mechanisms include Galvanic corrosion

Atmospheric corrosion

Corrosion under insulation

Crevice


Galvanic CorrosionElectrochemical process

The anode is the site atwhich the metal iscorroded

The electrolyte is thecorrosive medium

The cathode forms theother electrode in the celland is not consumed inthe corrosion process


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Galvanic corrosion

GALVANIC SERIES INSEA WATER

CORRODED END (Anodic)MagnesiumZinc

AluminumCadmiumMild SteelCast IronStainless Steels 18/8 (Active)LeadTinNickel (Active)BrassCopperAluminum BronzeCupro nickelSilver SoldersNickel (Passive)Stainless Steel 18/8 (Passive)

Silver

TitaniumGraphiteGoldPlatinumPROTECTED END (Cathodic)

Carbon Steel Nipple Threaded into a

Stainless Steel Water Tank


Galvanic corrosionMaterials Affected

All metals, with the exception of most noble metals, are affected.

Critical Factors

For galvanic corrosion, three conditions must be met:

Presence of an electrolyte

Two different metals or alloys in contact with the electrolyte

An electrical connection between the anode and the cathode

The relative exposed surface areas between anodic material andthe cathodic material has a significant affect


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Galvanic corrosion

Prevention The best method for prevention/mitigation is through good design.

The more noble material may need to be coated. If the activematerial were coated, a large cathode to anode area can accelerate

corrosion of the anode at any breaks in the coating.

Improvements in Materials of Construction

Galvanic corrosion is the principle used in galvanized steel, wherethe zinc corrodes preferentially to protect the underlying carbonsteel.

If there is a break in the galvanized coating, a large anode to smallcathode area prevents accelerated corrosion of the steel.

This anode-to-cathode relationship reverses at water temperaturesover about 150F (65C).


Atmospheric CorrosionAtmospheric

corrosion is a formof galvaniccorrosion.

Different parts ofthe surface of themetal act asanodes and

cathodes.Variations in the

electrolyte alsocontribute.


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Atmospheric Corrosion

Materials Affected Carbon and low alloy steels are most affected.

Critical Factors Marine environments can be very corrosive (20 mpy) as are

industrial environments that contain acids or sulfur compounds thatcan form acids (5-10 mpy).

Inland locations exposed to a moderate amount of precipitation orhumidity are considered moderately corrosive environments (1-3mpy).

Dry rural environments usually have very low corrosion rates (


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Corrosion Under Insulation

CUI is a form ofgalvanic corrosion.

Different parts of thesurface of the metalact as anodes andcathodes.

CUI is caused bythe presence of an

electrolyte, usuallyrain water.


Corrosion Under InsulationMaterials Affected Carbon and low alloy steels are affected by thinning

Austenitic stainless steels are affected by SCC and biological attack

Critical Factors Poor installations that allow water to become trapped.

Corrosion rates increase with increasing metal temperature up tothe point where the water evaporates quickly.

Corrosion becomes more severe at metal temperatures betweenthe boiling point 212F (100C) and 250F (120C), where water isless likely to vaporize and insulation stays wet longer.

In areas where significant amounts of moisture are present, the

upper temperature range where CUI may occur can be extendedsignificantly above 250F (120C).

Insulating materials that hold moisture (wick) are more of aproblem.

Cyclic thermal operation can increase corrosion.


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Prevention Maintaining the insulation

sealing/vapor barriers toprevent moisture ingress

Using appropriate coatings

Selection of insulatingmaterials that will hold lesswater against the pipe wall

Using low chloride insulationwith austenitic stainless steels

Not insulating where heatconservation is not asimportant

Improvements in Materials

of Construction Generally not an economical

approach.



Near miss 230 psig (16 bar) propane line Remaining wall as little as 1 mm thick


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Crevice Corrosion

Localized form of corrosionStagnant solution in crevices such as

Under gaskets Under fasteners Threaded joints Socket welded joints

initiated by changes in local chemistry within thecrevice Depletion of inhibitor in the crevice Depletion of oxygen in the crevice

A shift to acid conditions in the crevice Build-up of aggressive ion species (e.g. chloride) in

the crevice


Crevice Corrosion

Initially, the level of

soluble oxygen and isthe same everywhere.

Oxygen consumed by

normal uniformcorrosion is very soon

depleted in thecrevice.

Corrosion products

create acidicenvironment and further

seal the creviceenvironment.

Depletion of Oxygen in the Crevice

http://www.corrosion-doctors.org/


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Crevice Corrosion

Materials Affected Carbon and low alloy steels are affected by loss of metal

Austenitic stainless steels are affected by SCC and biological attack

Critical Factors

Aggressive ions like chlorides may be present in the electrolyte.

Corrosion rates increase with increasing metal temperature.

Prevention

Avoiding crevices whenever possible; e.g. using butt weldinginstead of socket welding and threaded joints.

Improvements in Materials of Construction

Generally not an economical approach.


Stress Corrosion CrackingRequires Stress

o Residual from Weldingo Design

Right Material Right Environment

o Chemical, pH

o Concentrationo Temperature


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Stress Corrosion CrackingMechanisms include

Chloride stress corrosion cracking (ClSCC)

Hydrogen-induced cracking (HIC)


Chloride Stress Corrosion Cracking

Requires thepresence of:

Chlorides insufficientconcentration

High enough stress


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Chloride Stress Corrosion Cracking

Materials Affected All 300 Series SS are highly susceptible.

Duplex stainless steels are more resistant.

Critical Factors Increasing temperatures increase the susceptibility to cracking.

Cracking usually occurs at metal temperatures above about 140F(60C), although exceptions can be found at lower temperatures.

Increasing levels of chloride increase the likelihood of cracking. Nopractical lower limit for chlorides exists because there is always apotential for chlorides to concentrate.

SCC usually occurs at pH values above 2. At lower pH values,uniform corrosion generally predominates. SCC tendencydecreases toward the alkaline pH region.

Stress may be applied or residual. Highly stressed or cold worked

components, such as expansion bellows, are highly susceptible tocracking.


Chloride Stress Corrosion CrackingPrevention When hydrotesting, use low chloride content water and dry out

thoroughly and quickly.

Properly applied coatings under insulation.

Avoid designs that allow stagnant regions where chlorides canconcentrate or deposit.

Improvements in Materials of Construction Nickel content of the alloy has a major affect on resistance. The

greatest susceptibility is at a nickel content of 8% to 12%. Alloyswith nickel contents above 35% are highly resistant and alloysabove 45% are nearly immune.

Low-nickel stainless steels, such as the duplex (ferrite-austenite)stainless steels, have improved resistance over the 300 Series SSbut are not immune.

Carbon steels, low alloy steels and 400 Series SS are notsusceptible to CISCC .


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Hydrogen-Induced Cracking (HIC)

Hydrogen Blisters Hydrogen blisters are surfacebulges on the surface of a pipe.

The blister results from hydrogenatoms that diffuse into the steel,and collect at a discontinuity.

The hydrogen atoms combine toform hydrogen molecules that aretoo large to diffuse.

The gas pressure builds to thepoint where local deformationoccurs

A primary source for the H atomsis from the sulfide corrosionprocess.


Hydrogen-Induced Cracking (HIC) Neighboring or adjacent blisters that are at slightly

different depths (planes) can develop cracks that linkthem together.

This is hydrogen-induced cracking. Interconnecting cracks often have a stair step

appearance, and so HIC is sometimes referred to as"stepwise cracking.


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Hydrogen-Induced Cracking (HIC) When HIC is assisted by high stresses in the piping, it

is called Stress Oriented Hydrogen Induced Cracking(SOHIC).

The SOHIC cracks usually appear in the base metaladjacent to the weld heat affected zones where theyinitiate from HIC damage.

SOHlC is potentially more dangerous because it resultsin a through-thickness crack that is perpendicular to thesurface.


Hydrogen-Induced Cracking (HIC)Critical Factors All of these damage mechanisms are related to the absorption and

permeation of hydrogen in steels.

Hydrogen permeation or diffusion rates have been found to beminimal at pH 7 and increase at both higher and lower pH's. Thepresence of hydrogen cyanide (HCN) in the water phasesignificantly increases permeation in alkaline (high pH) sour water.

Hydrogen permeation increases with increasing H2S partialpressure due to a concurrent increase in the H2S concentration inthe water phase.

Blistering, HIC, and SOHlC damage have been found to occur

between ambient and 300F (150C) or higher. HIC is often found in so-called "dirty" steels with high levels of

inclusions or other internal discontinuities from the steel-makingprocess.


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Hydrogen-Induced Cracking (HIC)

Materials Affected Carbon and low alloy steels are affected.

High alloy steels are not affected.

Critical Factors (cont.) HIC damage can occur throughout the refinery wherever there is a

wet H2S environment present.

Increasing concentration of ammonium bisulfide above 2%increases the potential for HIC.

Cyanides significantly increase the probability and severity of HICdamage.

Prevention Coatings that protect the surface of the steel from the

wet H2S environment can prevent damage.

Process changes that affect the pH of the water phaseor cyanide concentration can help to reduce damage.


Metallurgical and Environmental DamageCauses degradation and loss of material

properties

Involve some form of mechanical and/orphysical property deterioration of thematerial due to exposure to a processenvironment

Causes of metallurgical and environmentaldegradation failures are varied


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Mechanisms include Graphitization

Decarburization

High Temperature Hydrogen Attack(HTHA)

Metallurgical and Environmental Damage


GraphitizationGraphitization is the decomposition of

carbide phases in steels after long-termoperation in the 800F to 1100F (430C to590C) range into graphite nodules.

The decomposition causes a loss instrength, ductility, and creep resistance.


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Graphitization

Materials Affected Carbon and 0.5Mo steels are susceptible to graphitization.

Critical Factors Graphitization is not commonly observed.

What causes some steels to graphitize while others are resistant isnot well understood.

Severe heat affected zone graphitization can develop in as little as5 years at service temperatures above 1000F (540C).

Very slight graphitization would be expected to be found after 30 to40 years at 850F (450C).

Prevention Graphitization can be prevented by using chromium containing low

alloy steels for long-term operation above 800F (427C).


DecarburizationA condition where steel looses

strength due the removal ofcarbon and carbides leaving onlyan iron matrix.

Decarburization occurs duringexposure to high temperaturessuch as

during heat treatment

from exposure to fires

from high temperature service in agas environment.


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Decarburization

Materials Affected Carbon and low alloy steels are affected.

Critical Factors The material must be exposed to a gas phase that has a low carbon

activity so that carbon in the steel will diffuse to the surface to reactwith gas phase constituents.

The extent and depth of decarburization is a function of thetemperature and exposure time.

Typically, decarburization is shallow, but loss in room temperaturetensile strength and creep strength may occur.

Prevention Decarburization can be controlled by controlling the chemistry of the

gas phase and alloy selection. Alloy steels with chromium and molybdenum form more stable

carbides and are more resistant to decarburization.


High Temperature Hydrogen Attack High temperature hydrogen attack results from exposure

to hydrogen at elevated temperatures and pressures.

The hydrogen reacts with carbides in steel to formmethane (CH4), which cannot diffuse through the steel.

Methane pressurebuilds up, formingbubbles or cavities,micro fissures andfissures that may

combine to formcracks.


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High Temperature Hydrogen Attack

Materials Affected In order of increasing resistance: carbon steel, C-0.5Mo, Mn-0.5Mo,

1Cr-0.5Mo, 1.25Cr-0.5Mo, 2.25Cr-1Mo, 2.25Cr-1Mo-V, 3Cr-1Mo,5Cr-0.5Mo.

Critical Factors The loss of carbide causes an overall loss in strength.

Failure can occur when the cracks reduce the load carrying abilityof the pressure containing part.

For a specific material, HTHA is dependent on temperature,hydrogen partial pressure, time and stress. Service exposure timeis cumulative.

HTHA is preceded by a period of time when no noticeable changeis detectable by normal inspection techniques.

API RP 941 provides material resistance curves.


High Temperature Hydrogen AttackAPI RP 941 provides material resistance curves.


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High Temperature Hydrogen Attack

Prevention Use alloy steels with

chromium and molybdenumto increase carbide stability

thereby minimizing methaneformation. Other carbide

stabilizing elements includetungsten and vanadium.

300 Series SS, as well as

5Cr, 9Cr and 12Cr alloys, arenot susceptible to HTHA at

conditions normally seen in

refinery units.HTHA to a Boiler Tube


High Temperature Hydrogen Attack One employee sustained a minor injury.

NPS 8 carbon steel elbow ruptured after operating for only 3 months. The escaping hydrogen gas from the ruptured elbow quickly ignited.

HTHA to a Boiler Tube

A maintenancecontractor

accidentallyswitched a

carbon steelelbow with an

alloy steelelbow during ascheduled heat

exchangeroverhaul.


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API 571

Graphitization

Softening (Spheroidization)

Temper Embrittlement

Strain Aging

885F Embrittlement

Sigma Phase Embrittlement

Brittle Fracture

Creep / Stress Rupture

Thermal Fatigue

Short Term Overheating -Stress Rupture

Steam Blanketing

Dissimilar Metal Weld (DMW)Cracking

Thermal Shock

Erosion / Erosion-Corrosion

Cavitation

Mechanical Fatigue

Vibration-Induced Fatigue

Refractory Degradation

Reheat Cracking

Galvanic Corrosion

Atmospheric Corrosion

Much of the information presented on deterioration of metals is taken

from API 571 Damage Mechanisms Affecting Fixed Equipment in theRefining Industry API 571 addresses all of the following mechanisms:


API 571 Corrosion Under Insulation

(CUI)

Cooling Water Corrosion

Boiler Water CondensateCorrosion

CO2 Corrosion

Flue Gas Dew Point Corrosion

Microbiologically InducedCorrosion (MIC)

Soil Corrosion

Caustic Corrosion

Dealloying

Graphitic Corrosion

Oxidation

Sulfidation

Carburization

Decarburization

Metal Dusting

Fuel Ash Corrosion

Nitriding

Chloride Stress CorrosionCracking (CI-SCC)

Corrosion Fatigue

Caustic Stress CorrosionCracking (CausticEmbrittlement)

Ammonia Stress CorrosionCracking

Liquid Metal Embrittlement(LME)


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API 571

Hydrogen Embrittlement (HE) Amine Corrosion

Ammonium Bisulfide Corrosion(Alkaline Sour Water)

Ammonium Chloride Corrosion

Hydrochloric Acid (HCI)Corrosion

High Temp H2/H2S Corrosion

Hydrofluoric (HF) AcidCorrosion

Naphthenic Acid Corrosion(NAC)

Phenol (Carbonic Acid)Corrosion

Phosphoric Acid Corrosion Sour Water Corrosion (Acidic)

Sulfuric Acid Corrosion Polythionic Acid Stress

Corrosion Cracking (PASCC)

Amine Stress CorrosionCracking

Wet H2S Damage

Hydrogen Stress Cracking HF

Carbonate Stress CorrosionCracking

High Temperature HydrogenAttack

Titanium Hydriding

b31.3 process piping course - 03 materials-libre

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