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THE EFFECT OF CORROSION DEFECTS ON BURST PRESSURE OF PIPELINES
KHAIRUL ANWAR BIN IBRAHIM
Report submitted in fulfillment of the requirements for the award of the degree of
Bachelor of Mechanical Engineering
Faculty of Mechanical Engineering
UNIVERSITI MALAYSIA PAHANG
JUNE 2012
vii
ABSTRACT
The predictions of pipeline burst pressure in the early stage are very importance in order
to provide assessment for future inspection, repair and replacement activities. The
failure of oil and gas pipelines contribute to economic implications and also constitute a
serious hazards to the environment due to leakage. This thesis deals with the study on
the effect of corrosion defect on the burst pressure of pipelines for API 5L X42 steel.
The objectives for this project are to determine the burst pressure of corroded pipelines
using Finite Element Analysis (FEA) and to compare the results with the available
pipelines design code. This project implicates analysis of the API X42 steel by using
MSC Patran 2008 r1 software as pre-processor and MSC Marc 2008 r1 software as a
solver. A quarter of pipe was simulated by fully applying the symmetrical condition.
The pipe is modeled in 3-D with outer diameter of 60 mm, wall thickness of 6 mm and
different defect parameters. In this analysis, stress modified critical strain used as failure
criterion to predict the failure of defective pipe. Result shows that the burst pressure
decreases when both defect depth and length increases. The defect depth appear as a
most influence parameter that affect the burst pressure. The circumferential extent has a
less influence on the burst pressure. The results have been compared to available design
codes for corroded pipelines such as ASME B31G, Modified ASME B31G and DNV
RP F101. Comparison with available design codes have shown that FEA burst pressure
gives higher values compare to codes. From the results, ASME B31G gives the lowest
values than other codes.
viii
ABSTRAK
Ramalan-ramalan tekanan letus saluran paip di peringkat awal adalah sangat penting
untuk menyediakan penilaian bagi pemeriksaan pada masa akan datang, aktiviti
pembaikan dan penggantian. Kegagalan saluran paip minyak dan gas menyumbang
kepada implikasi ekonomi dan juga merupakan suatu bahaya yang serius kepada alam
sekitar yang berpunca daripada kebocoran. Tesis ini berkaitan dengan kajian pada kesan
kecacatan kakisan pada tekanan pecah saluran paip untuk API 5L keluli X42. Objektif
bagi projek ini adalah untuk menentukan tekanan pecah paip berkarat yang
menggunakan Analisis Unsur Terhingga (FEA) dan membandingkan keputusan dengan
kod saluran paip reka bentuk yang ada. Projek ini aib analisis keluli API X42 dengan
menggunakan MSC Patran 2008 r1 perisian sebagai pra-pemproses dan MSC Marc
2008 perisian r1 sebagai penyelesai. Satu perempat daripada paip adalah simulasi
dengan menggunakan sepenuhnya keadaan simetri. Paip model 3-D dengan diameter
luar 60 mm, ketebalan dinding 6 mm dan parameter kecacatan yang berbeza. Dalam
analisis ini, menekankan tarikan kritikal yang diubahsuai digunakan sebagai kriteria
kegagalan untuk meramalkan kegagalan paip rosak. Keputusan menunjukkan bahawa
tekanan yang pecah berkurangan apabila kedua-dua kedalaman kecacatan dan panjang
bertambah. Kedalaman kecacatan muncul sebagai satu parameter pengaruh yang paling
yang memberi kesan kepada tekanan pecah. Sejauh lilitan mempunyai pengaruh yang
kurang pada tekanan pecah. Keputusan telah berbanding kod reka bentuk tersedia untuk
saluran paip berkarat seperti ASME B31G, Modified ASME B31G dan DNV RP F101.
Perbandingan dengan kod reka bentuk yang ada telah menunjukkan bahawa tekanan
letus FEA memberikan nilai yang lebih tinggi berbanding dengan kod. Daripada
keputusan, ASME B31G memberikan nilai yang terendah daripada kod lain.
ix
TABLE OF CONTENTS
Page
EXAMINER’S DECLARATION ii
SUPERVISOR’S DECLARATION iii
STUDENT’S DECLARATION iv
DEDICATIONS v
ACKNOWLEDGEMENTS vi
ABSTRACT vii
ABSTRAK viii
TABLE OF CONTENTS ix
LIST OF TABLES xii
LIST OF FIGURES xiii
LIST OF ABBREVIATIONS xviii
CHAPTER 1 INTRODUCTION
1.1 Introduction 1
1.3 Project Background 2
1.3 Problem Statement 3
1.4 Objectives 4
1.5 Scope Of Study 4
CHAPTER 2 LITERATURE REVIEW
2.1 Introduction 5
2.2 Oil Exploration Review in Malaysia 5
2.3 Theory of Corroded Pipeline 8
2.4 Types of Corrosion 9
2.4.1 Uniform Corrosion 9
2.4.2 Pitting Corrosion 10
2.4.3 Dealloying Corrosion 11
2.4.4 Intergranular Corrosion 12
2.4.5 Erosion-Corrosion/Impingement 13
2.4.6 Transgranular Corrosion 14
x
2.5 Submarine Pipeline Corrosion 15
2.5.1 External Corrosion 16
2.5.2 Internal Corrosion 16
2.6 Pipeline Failures 18
2.6.1 Pipeline Failure Causes 19
2.7 Corrosion Prevention Methods 22
2.8 Finite Element Analysis 23
2.8.1 Meshing 23
2.8.2 Application of the Finite Element Method 24
2.8.3 Advantages of Finite Element Method 24
2.8.4 Analytical Method 25
CHAPTER 3 METHODOLOGY
3.1 Introduction 26
3.2 Flow Chart of the Project 26
3.3 Methodology 28
3.3.1 Structural Modelling 29
3.3.2 Mesh Model 34
3.3.3 Loads / Boundary Conditions 36
3.3.4 Input Data 38
3.3.5 Materials Application 40
3.3.6 Element Properties Application 42
3.3.7 Analysis Performing For Model 43
3.4 Predicting Burst Pressure 44
CHAPTER 4 RESULTS AND DISCUSSIONS
4.1 Introduction 45
4.2 Result 46
4.2.1 Comparison of burst pressure of different defect depth
between Modified ASME B31G and Finite Element result.
46
4.2.2 Comparison of burst pressure of different defect length
between Modified ASME B31G and Finite Element result.
48
4.2.3 Comparison of burst pressure of different defect width
between Modified ASME B31G and Finite Element result.
51
4.2.4 Comparison of burst pressure of different defect depth
between ASME B31G and Finite Element results.
53
xi
4.2.5 Comparison of burst pressure of different defect length
between ASME B31G and Finite Element results.
55
4.2.6 Comparison of burst pressure of different defect width
between ASME B31G and Finite Element results.
57
4.2.7 Comparison of burst pressure of different defect depth
between DNV RP F101 and Finite Element results.
59
4.2.8 Comparison of burst pressure of different defect length
between DNV RP F101 and Finite Element results.
61
4.2.9 Comparison of burst pressure of different defect width
between DNV RP F101 and Finite Element results.
63
4.2.10 Summary of burst pressure with different defect depth,
defect length and defect width for ASME B31G, Modified
ASME B31G, DNV RP F101 And FEA
65
4.2.11 Radial displacement for different defect depth 68
4.2.12 Radial displacement for different defect length 71
4.2.13 Radial displacement for different defect width 73
4.2.14 Summary of radial displacement with different defect
depth, defect length and defect width
75
4.2.15 Comparison between deformed pipe and undeformed pipe. 77
4.2.16 Finite element analysis (FEA) defect deformation with
different length at same pressure 30 MPa.
78
4.2.17 Finite element analysis (FEA) pipe deformation with
different depth at burst pressure.
79
4.2.18 Finite element analysis (FEA) pipe deformation with
different length at burst pressure.
80
4.2.19 Finite element analysis (FEA) pipe deformation with
different width at burst pressure
81
CHAPTER 5 CONCLUSION AND RECOMMENDATIONS
5.1 Introduction 82
5.2 Conclusion 82
5.3 Recommendations for Future Research 83
REFERENCES 84
APPENDICES 86
xii
LIST OF TABLES
Table No. Title Page
2.1 Hazardous liquid pipeline accident summary 20
2.2 Natural gas transmission pipeline incident summary 21
2.3 Natural gas distribution pipeline incident summary 21
3.1 The parameter of the defects 31
3.2 Material data for API 5L - X42 steel 41
4.1 Burst pressure for different defect depth Modified ASME B31G
and FEA
46
4.2 Burst pressure for different defect length Modified ASME B31G
and FEA
49
4.3 Burst pressure for different defect width Modified ASME B31G
and FEA 51
4.4 Burst pressure for different defect depth ASME B31G and FEA 54
4.5 Burst pressure for different defect length ASME B31G and FEA 56
4.6 Burst pressure for different defect width ASME B31G and FEA 58
4.7 Burst pressure for different defect depth DNV RP F101 and FEA 60
4.8 Burst pressure for different defect length DNV RP F101 and FEA 62
4.9 Burst pressure for different defect width DNV RP F101 and FEA 64
xiii
LIST OF FIGURES
Figure No. Title Page
2.1 Malaysia oil production and consumption 7
2.2 Uniform corrosion 10
2.3 Pitting corrosion 11
2.4 Dealloying corrosion 12
2.5 Intergranular corrosion 13
2.6 Erosion-corrosion 14
2.7 Stress-corrosion cracking (SCC) 15
3.1 Overall flowchart 27
3.2 Methodology flowchart 28
3.3 A quarter model of the pipe 29
3.4 Defect dimensions 30
3.5 Corroded defect 30
3.6 Geometry bar 32
3.7 Geometry properties 32
3.8 Pipe sketch 33
3.9 Pipe surface 33
3.10 Element bar 34
3.11 Mesh seed properties bar 34
3.12 Mesh properties bar 35
xiv
3.13 Equivalence properties bar 35
3.14 Loads / Boundary conditions bar 36
3.15 Loads / Boundary conditions properties bar 37
3.16 Geometrical modelling with load, x-axis, and z-axis vector 37
3.17 Engineering stress strain curve of API 5L X42 steel 39
3.18 True stress strain curve of API 5L X42 steel 39
3. 19 Input data table 40
3. 20 Material input menu 41
3. 21 Element properties input menu 42
3.22 Creating job step analysis 43
3.23 Critical location 44
4.1 Graph burst pressure versus defect depth for Modified ASME
B31G
47
4.2 Graph burst pressure versus defect depth for FEA 47
4.3 Comparison graph burst pressure versus defect depth for
Modified ASME B31G and FEA
48
4.4 Graph burst pressure versus defect length for Modified
ASME B31G
49
4.5 Graph burst pressure versus defect length for FEA 50
4.6 Comparison graph burst pressure versus defect length for
Modified ASME B31G and FEA
50
4.7 Graph burst pressure versus defect width for Modified ASME
B31G 52
4.8 Graph burst pressure versus defect width for FEA 52
xv
4.9 Comparison graph burst pressure versus defect width for
Modified ASME B31G and FEA
53
4.10 Graph burst pressure versus defect depth for ASME B31G 54
4.11 Graph burst pressure versus defect depth for FEA 54
4.12 Comparison graph burst pressure versus defect depth for
ASME B31G and FEA
55
4.13 Graph burst pressure versus defect length for ASME B31G 56
4.14 Graph burst pressure versus defect length for FEA 56
4.15 Comparison graph burst pressure versus defect length for
ASME B31G and FEA
57
4.16 Graph burst pressure versus defect width for ASME B31G 58
4.17 Graph burst pressure versus defect width for FEA 58
4.18 Comparison graph burst pressure versus defect width for
ASME B31G and FEA
59
4.19 Graph burst pressure versus defect depth for DNV RP F101 60
4.20 Graph burst pressure versus defect depth for FEA 60
4.21 Comparison graph burst pressure versus defect depth for
DNV RP F101 and FEA
61
4.22 Graph burst pressure versus defect length for DNV RP F101 62
4.23 Graph burst pressure versus defect length for FEA 62
4.24 Comparison graph burst pressure versus defect length for
DNV RP F101 and FEA
63
4.25 Graph burst pressure versus defect width for DNV RP F101 64
4.26 Graph burst pressure versus defect width for FEA 64
xvi
4.27 Comparison graph burst pressure versus defect width for
DNV RP F101 and FEA
65
4.28 Comparison graph for burst pressure with different defect
depth
66
4.29 Comparison graph for burst pressure with different defect
length
66
4.30 Comparison graph for burst pressure with different defect
width
67
4.31 Graph internal pressure versus radial displacement for
3 mm defect depth
69
4.32 Graph internal pressure versus radial displacement for
3.5 mm defect depth
69
4.33 Graph internal pressure versus radial displacement for
4 mm defect depth
70
4.34 Graph internal pressure versus radial displacement for
4.5 mm defect depth
70
4.35 Graph internal pressure versus radial displacement for
30 mm defect length
71
4.36 Graph internal pressure versus radial displacement for
40 mm defect length
71
4.37 Graph internal pressure versus radial displacement for
50 mm defect length
72
4.38 Graph internal pressure versus radial displacement for
60 mm defect length
72
4.39 Graph internal pressure versus radial displacement for
4 mm defect width
73
4.40 Graph internal pressure versus radial displacement for
6 mm defect width
73
xvii
4.41 Graph internal pressure versus radial displacement for
10 mm defect width.
74
4.42 Graph internal pressure versus radial displacement for
14 mm defect width.
74
4.43 Comparison graph for radial displacement with different
defect depth.
75
4.44 Comparison graph for radial displacement with different
defect length.
76
4.45 Comparison graph for radial displacement with different
defect width.
76
4.46 Undeformed pipe. 77
4.47 Deformed pipe. 78
4.48 Defect deformation with different length at 30 MPa. 79
4.49 Pipe deformation with different depth at burst pressure. 80
4.50 Pipe deformation with different length at burst pressure. 80
4.51 Pipe deformation with different width at burst pressure. 81
xviii
LIST OF ABBREVIATIONS
2-D Two Dimension
3-D Three Dimension
ASTM American Society for Testing and Materials
ASME American Society of Mechanical Engineers
API American Petroleum Institute
ANSI American National Standards Institute
DNV Det Norske Veritas
FEA Finite Element Analysis
FEM Finite Element Method
HIC Hydrogen Induced Cracking
RP Recommended Practice
SCC Stress Corrosion Cracking
SOHIC Stress-Oriented Hydrogen Induced Cracking
SSC Sulfide Stress Cracking
MSS Maximum Shear Stress
CHAPTER 1
INTRODUCTION
1.1 INTRODUCTION
A pipeline is all parts of the physical facility where liquids or gases such as
crude oil and natural gas are transported usually over long distances between a
producing region and a local distribution system. Offshore pipeline systems are vital to
transport the raw oil products and gas from the oil platform to the onshore terminal.
Such pipelines are necessary because the locations of oil/gas production sites tend to be
far away from the refineries, processing plants and end user (Khan and Islam, 2007).
Offshore pipeline transport enormous quantities of oil and gas vital to the
economic of virtually all nations. Therefore the exploration and production of oil and
gases form adverse or hostile environments and from marginal field is becoming
increasing important to ensure a continuous and independent energy supply. Production
of oil and gas from sea bottoms,performed from stationary platform has gained wide
development. Most of the sub sea oil and gas fields that been developed,or are under
development, are marginal with a production life time between 5 and 15years
(Martinussen, E. 1995).
As a pipeline ages, it can be affected by a range of corrosion mechanisms, which
may lead to a reduction in its structural integrity and eventual failure. The economic
consequences of a reduced operating pressure, loss of production due to downtime,
repairs, or replacement can be severe and, in some cases, not affordable.
2
There are lots of methods (codes) in the engineering practice to determine the
burst pressure of corroded pipes depending on the loadings and the scopes of the
pipelines. These semi-empirical methods based on measurement data (ASME B31G,
Modified ASME B31G, DNV RP F101,) consider only the length and depth dimensions
of the simple, 3D geometrical shapes which are used to approximate the real corrosion
failures. They are based on limit analysis of defective pipelines, however, one part of
them over- or underestimate the burst pressures considering their geometrical models or
semi-empirical factors. The transmission steel pipelines are usually made from ductile
steel, but the majority of codes consider only elastic and perfectly plastic material
behaviour. A fairly severe disadvantage of them is that they consider internal loads
only. Because of these enumerated properties they can be called conservative.
1.2 PROJECT BACKGROUND
Predicting the failure of damaged oil and gas pipeline has become an essential art
for the determination of design tolerance. A pipeline may experience significant internal
and external corrosion defects by chemical and environmental effects that reduce its
strength and resistance to fatigue, local buckling, leakage and bursting. Finite Element
Modeling has become a reliable method for a prediction technique. The technique
developed recently has enabled the reliable and accurate location and sizing of pipeline
wall corrosion. The burst pressures of pipes with corrosion defects on their outer
surfaces were determined with the help of FEA, where the calculated burst pressure
values were called as ultimate pressures.
The main goal of the simulations was to determine how the depth, width, and length
of the corrosion defects influence the burst pressures. The material use for this analysis
is API 5L X42 steel. In order to determine stress triaxiality and equivalent strain, model
with different parameter defects will be simulated in finite element software. For this
purpose, MSC Patran/Marc 2008 r1 were applied. The main reasons for using MSC
Patran/Marc for failure prediction is to reduce cost by replacing physical testing with
less expensive digital simulation. True stress-strain data for API 5L X42 steel was used
as input data in the finite element analysis.
3
Throughout this project, ASME B31G, Modified ASME B31G, and DNV-RP-F101
are the standards followed in order to standardize the results obtained. The limitations
of this study are subjected to previously mentioned codes and standard. The data from
the analysis will be compared with the available design code for pipelines.
1.3 PROBLEM STATEMENT
Nowadays, the investigation of the crude oil- and natural gas transmission steel
pipelines applied in the pipeline industry has generally revealed that the primary reason
for their failure is corrosion. Wall thinning caused by corrosion failure on the inner or
outer surfaces of the pipelines will generate stress concentration on the pipe wall. The
highest stress and strain value will occur at the deepest point of the corrosion defect,
therefore the failure of the pipelines are usually expected at this location. Including
dimensions (length, width, depth) of the corrosion defects influence the stress
concentration to a different extent. (Length of the defect refers to the longitudinal, the
width of the defect refers to the circumferential directions of the pipelines.)
Integrity assessment of corroded pipeline is very vital in oil and gas industry. Better
understanding is required to reduce the conservatism involved in the current assessment
method. Previous research has found out that finite element analysis has become a
reliable engineering approach towards achieving actual results. Many Consultant
Company realize that it is difficult to have a finite element modeling of the offshore
corroded pipeline as the modeling need further understanding and detail research on
each data. In this research, finite element analysis will be implemented comparing with
the available codes as it is a higher demand in the oil and gas industry. This research
will be a start and guidance in helping industries towards achieving accurate prediction
of failure on corroded pipelines.
4
1.4 OBJECTIVES
For this project, two main objectives are listed:
i. To determine the burst pressure of corroded pipelines using Finite Element
Analysis (FEA)
ii. To compare the FE burst pressure results with available design code for
corroded pipelines.
1.5 SCOPE OF STUDY
The scope of study of this project is failure predictions which include the study
of remaining strength of corroded offshore pipeline by using finite element analysis
software. The scope of the research are :
a) API 5L X42 steel is used in this analysis.
b) MSC Patran is used as pre-processor and MSC Marc is used as solver.
c) Finite element analysis (FEA) condition:
3-D model.
Homogeneous material model.
Elastic-plastic.
Reduced integration.
Non-linear.
d) True stress-strain data for API 5L X42 steel was used as input data in the
finite element analysis.
e) Stress modified critical strain model is the failure criterion used to
predict the burst pressure.
f) Finally, finite element results will be compared with the available design
code that are ASME B31G, Modified ASME B31G, and DNV-RP-F101.
CHAPTER 2
LITERATURE REVIEW
2.1 INTRODUCTION
This chapter will briefly explain about the properties, material , design, failure
and cause of failure in pipeline. The sources are taking from journals, articles, and
books. Besides, the information about the software that will be used also included in
this chapter. Literature review is done to provide information about previous research
and that can help to smoothly run this project. All this information is important before
furthering to the analysis and study later.
2.2 OIL EXPLORATION REVIEW IN MALAYSIA
The first oil well discovered in Malaysia was by Shell Company, in 1910 in
Miri, Sarawak. Thereafter, the same company constructed Malaysia's first refinery in
1914, which undertakes the whole manufacturing of petroleum products. At present,
Malaysia's oil company, PETRONAS undertakes the exploration and production of the
oil and gas in Malaysia whilst Shell and other oil companies operate as a contractor to
PETRONAS under Production Sharing Contracts.
6
Malaysia's oil and gas fields can be found mainly offshore of Peninsula Malaysia
as well as the east coast. At present, Malaysia has 37 producing oil fields and 11
producing gas fields whilst several others are under development. The main five oil
fields that produce high quality blends of crude can be found in the east of Peninsula
Malaysia mainly, Tapis, Labuan, Miri, Bintulu and Dulang. It has been estimated that
Malaysia has been producing 630,000 barrels of oils and five billion cubic feet of gas
per day. Such an amount produced has made Malaysia one of the niche players in the oil
and gas industry.
Malaysia has uncovered an estimated 214 gas field and most of these fields are
under some development. As at 1 January, 2000, Malaysia has about 3.4 billion barrels
of crude oil reserves and about 84.2 trillion standard cubic feet of gas reserves. This
reserve has successfully placed the country at 27th and 12th places respectively in terms
of world ranking. PETRONAS has the licensing authority for all upstream activities:
exploration, production and transportation of oil in Malaysia. Most of the country's oil
fields contain 10 low sulphur, high quality crude, with gravities in the 35-50 API range.
Over half of the country's oil production comes from the Tapis field, which contains 44
API oil with low sulphur content (EIA, 2000; PETRONAS, 1999). Esso Production
Malaysia Inc. (EPMI) is the largest crude oil producer in Peninsular Malaysia,
accounting for nearly half of Malaysia's crude oil production. EPMI operates seven
fields near the peninsular, and one-third of its production comes from the Seligi field.
(EIA, 2000).
Currently, Terengganu produce more than half of Malaysia's total oil output with
daily production totalling 380,000 barrels (EIA, 2000). Proven reserves off Terengganu
total 2.4 billion barrels from 18 oil fields. Besides PETRONAS Carigali (PCSB), five
other companies are also involved in the oil and gas exploration off Terengganu coast in
PSC agreement. They are International Petroleum Ltd, USA; Esso Production Malaysia;
Western Mining Corporation, Australia; Texaco and Penyu International Inc. The others
major oil companies operating in Sabah and Sarawak are Shell, Sarawak Shell Berhad,
Sarawak Shell/PETRONAS Carigali, and Amoco (PETRONAS, 2001). Figure 2.1
shows Malaysia`s oil production and consumption in 1990 until 2009.
7
Figure 2.1: Malaysia`s oil production and consumption
Source: Petronas (2001)
PETRONAS is concern in the area of safety regulations and enforcement.
Among the tools for ensuring pipeline integrity, one of the most successful is risk
management and RBI (Reid, 1998). PETRONAS has been successful in implementing
RBI for platform structures and for mechanical piping. Number of planned
comprehensive inspection for platform structures have been reduced from 117 to only
59 after the implementation of RBI procedure (Goh, 2000). Now, PETRONAS is
moving ahead in implementing the same procedure for offshore pipelines.
8
2.3 THEORY OF CORRODED PIPELINE
Corroded pipeline are referring to the pipeline that undergo the chemical reaction
between a metal or alloy and its environment. A pipeline may experience significant
internal and external corrosion defects that will reduce its strength and resistance to
fatigue, local buckling, leakage and bursting. Corrosion mechanisms include
electrochemical corrosion, chemical corrosion, and stress-promoted corrosion.
The strength of old pipelines declines because of a number of reasons, with
corrosion being the major one. This is especially true when the pipeline is not well
corrosion–protected. The study of increasing corrosion resistance is essential to reduce
the maintaining cost. The factors that most influence the behaviour of the stainless steel,
in rough order of importance to corrosion, are as follow:
1. Presence of oxidizing species which aids reformation of the oxide film
2. Chloride ion concentration because chloride hinders oxide film repair
3. Conductivity of the electrolyte, which affects the cathode/anode ration
4. Crevices that can initiate corrosion
5. Sediments that prevent reformation of the oxide film
6. Scales and deposits that prevent reformation of the oxide film
7. Chlorinating practice that alters the chlorine content of the environment
8. Surface condition of the stainless steel
9. pH(if below 5) that increase the cathodic reactions
10. Temperature that alters the relative rates of oxide film breakdown, corrosion
processes and oxide film reformation rate.
The reaction that occurs when steel is immersed in sea water or corrosive liquid
environment can be written as followed (Craig, 1993):
Oxidation: Fe Fe2+ + 2e- (2.1)
Reduction: O2 + 2H2O + 4e- 4OH- (2.2)
9
The overall reaction will be written as (Khan and Islam, 2007):
2Fe + 2H2O + O2 2Fe2+ + 4OH- (2.3)
Or
2Fe + 2H2O + O2 2Fe(OH)2 (2.4)
However, ferrous hydroxide (corrosion products) reacts with salt to form ferrous
chloride:
Fe(OH)2 + 2NaCl FeCl2 + 2NaOH (2.5)
In the later stage of corrosion, ferrous chloride reacts with water to form hydrochloric
acid:
FeCl2 + 2H2O Fe(OH)2 + 2HCl (2.6)
2.4 TYPES OF CORROSION
Corrosion can be categorized in various ways which are (Craig, 1993):
2.4.1 Uniform corrosion
Uniform corrosion represents the ideal case in which the metal is uniformly
corroded away at some constant rate. Figure 2.2 shows uniform corrosion of pipe. This
type of corrosion attack is the basis for most design. Corrosion often very localized and
failure occurs long before failure by general thinning of metal. This form of corrosion is
observed on metal structures exposed to the atmosphere such as offshore platforms.
10
Figure 2.2: Uniform corrosion
Source : Craig (1993)
2.4.2 Pitting corrosion
Pitting attack is one of the most frequent forms of corrosion encountered. It
shows a very localized attack in a few weeks or months while the remaining area of
metal is relatively uncorroded. The shape of pits depends on the particular pitting
environment. Once pitting is initiated, the remaining unpitted surface area becomes
cathodic to the pits. As pits progress, pH of solution in the bottom of pit is reduced often
to a pH of 1. With the reduction in pH together with anodic character of the pit, it drives
the corrosion process until the metal is perforated. During perforation of metal, some
pits will initiate and then stop growing while others propagate to various depths and
stop or continue to grow until failure. While pitting can be catastrophic and difficult to
predict, it is necessary to understand the environments which induce pitting. Figure 2.3
shows pitting corrosion of pipe.
11
Figure 2.3: Pitting corrosion
Source : Craig (1993)
2.4.3 Dealloying corrosion
Dealloying or selective leaching is the selective corrosion of one element in an
alloy. Figure 2.4 shows dealloying corrosion of pipe. Dezincification is an example of
dealloying whereby zinc is selectively attacked and removed from brass alloys, leaving
only copper behind. Another form of cast irons attack is called graphitization is
whereby the iron matrix of gray cast iron is being corroded leaving behind a layer of
graphite. For instance, gray cast-iron butterfly valves and water pumps used in
petroleum industry are most susceptible to this type of corrosion.