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1.

Chapter 1–Corrosions Theory, Types, and Mechanisms
What are the four conditions that must be met for corrosion to occur?

 a) Heat, Pressure, Oxygen, Water

 b) Oxygen, Water, Heat, Pressure

 c) Metal, Heat, Pressure, Electron

 d) Metal, Oxygen, Water, Electron

2.

What is the definition of corrosion?

 a) The improvement of a material due to reaction with its environment.

 b) The deterioration of a material due to reaction with its environment.

 c) The reaction of a material with water.

 d) The reaction of a material with oxygen.

3.

What is the focus of this course?

 a) The effects of external corrosion on carbon steel pipeline systems.

 b) The effects of internal corrosion on carbon steel pipeline systems.

 c) The effects of corrosion on plastic pipeline systems.

 d) The effects of corrosion on all materials.

4.

What can result if corrosion is not controlled?

 a) Decreased facility maintenance costs.

 b) Increased public safety.

 c) Unnecessary costs associated with facility maintenance, repair, or replacement.

 d) Decreased risk to public safety.

5.

What was the estimated direct corrosion cost for gas and liquid pipelines in the U.S. per year?

 a) $7M

 b) $70M

 c) $700M

 d) $7B

6.

What are the characteristics of anodic and cathodic reactions?

 a) Anodic reactions involve gain of electrons, while cathodic reactions involve loss of electrons.

 b) Anodic reactions involve loss of electrons, while cathodic reactions involve gain of electrons.

 c) Both anodic and cathodic reactions involve gain of electrons.

 d) Both anodic and cathodic reactions involve loss of electrons.

7.

How many different types of corrosion are there?

 a) Three

 b) Four

 c) Five

 d) Six

8.

What contributes to corrosion?

 a) Key environmental variables

 b) Only water and oxygen

 c) Only heat and pressure

 d) Only the type of material

9.

What is the main problem encountered by the owners and operators of underground metallic facilities?

 a) Heat

 b) Pressure

 c) Corrosion

 d) Material properties

10.

What is the main goal of corrosion personnel?

 a) To have a basic understanding of corrosion mechanisms.

 b) To control the heat and pressure in the facilities.

 c) To replace the corroded parts of the facilities.

 d) To ignore the corrosion in the facilities.

11.

What are the four conditions that must be met for metallic corrosion to occur?

 a) An anode, a metallic electrical connection, heat, and pressure

 b) An anode, a cathode, heat, and pressure

 c) A cathode, electrolyte, heat, and pressure

 d) An anode, a cathode, a metallic electrical connection, and electrolyte

12.

What is the term for the transfer of charge between the metal and the electrolyte in corrosion reactions in gas pipelines?

 a) Electrolytic

 b) Electrochemical

 c) Electromagnetic

 d) Electrostatic

13.

What happens at the cathode during corrosion?

 a) Oxygen reduction

 b) Oxidation

 c) Hydrogen evolution

 d) Reduction

14.

What happens at the anode during corrosion?

 a) Reduction

 b) Oxidation

 c) Hydrogen evolution

 d) Oxygen reduction

15.

What is the primary reason corrosion occurs?

 a) Pressure

 b) Heat

 c) Thermodynamics

 d) Electrolyte

16.

What is the natural state for iron?

 a) Ferric oxide (Fe2O3)

 b) Ferrous oxide (FeO)

 c) Iron (Fe)

 d) Iron ore (FeO2)

17.

What causes the potential difference between the anode and cathode during corrosion?

 a) The anode and cathode are at the same energy state

 b) The cathode is at a higher energy state than the anode

 c) The anode is at a higher energy state than the cathode

 d) The anode and cathode are at different temperatures

18.

What is an example of a situation where a potential difference between the anode and cathode can arise?

 a) When two different materials are electrically connected together

 b) When the anode and cathode are at different temperatures

 c) When the anode and cathode are made of the same material

 d) When the anode and cathode are at the same temperature

19.

What is the term for a cell where differences in the environment exist at different locations on the same structure?

 a) Galvanic cell

 b) Concentration cell

 c) Electrolytic cell

 d) Voltaic cell

20.

What measurements are used to describe corrosion processes?

 a) Potential and current

 b) Resistance and voltage

 c) Current and voltage

 d) Resistance and potential

21.

Chapter 2 Identification of Corrosion Mechanisms
What can the techniques described in this chapter be used for?

 a) Identifying corrosivity, estimating a corrosion rate, determining a corrosion mechanism, ensuring effectiveness of a corrosion control program, and optimizing chemical treatment costs

 b) Identifying corrosivity, estimating a corrosion rate, determining a corrosion mechanism, ensuring the ineffectiveness of a corrosion control program, and optimizing chemical treatment costs

 c) Identifying non-corrosivity, estimating a corrosion rate, determining a corrosion mechanism, ensuring effectiveness of a corrosion control program, and optimizing chemical treatment costs

 d) Identifying corrosivity, estimating a non-corrosion rate, determining a corrosion mechanism, ensuring effectiveness of a corrosion control program, and optimizing chemical treatment costs

22.

What should be considered when interpreting test results?

 a) The history of the system, accuracy of the tests, limitations of the techniques, and basic corrosion principles

 b) The future of the system, accuracy of the tests, limitations of the techniques, and basic corrosion principles

 
c) The history of the system, inaccuracy of the tests, limitations of the techniques, and basic corrosion principles

 d) The history of the system, accuracy of the tests, unlimited techniques, and basic corrosion principles

23.

What may be used for predicting corrosivity?

 a) Knowledge of the physical composition of the gas and liquids

 b) Ignorance of the chemical composition of the gas and liquids

 c) Knowledge of the chemical composition of the gas and liquids.

 d) Ignorance of the physical composition of the gas and liquids

24.

Where should gas and/or liquid samples be taken periodically at?

 a) Meter tubes, pig traps, filters, separation and dehydration vessels, pipeline and compressor station drips, and storage tanks

 b) Meter tubes, pig traps, filters, separation and dehydration vessels, pipeline and compressor station drips, and storage buildings

 c) Meter buildings, pig traps, filters, separation and dehydration vessels, pipeline and compressor station drips, and storage tanks

 d) Meter tubes, pig traps, filters, separation and dehydration buildings, pipeline and compressor station drips, and storage tanks

25.

What is required for corrosion to occur at any significant rate in a natural gas system?

 a) An electrolyte such as solid water

 b) An electrolyte such as liquid water

 c) An electrolyte such as gaseous water

 d) An electrolyte such as plasma water

26.

What environmental conditions tend to accelerate corrosion?

 a) Total pressures of nitrogen (N2), carbon dioxide (CO2), and hydrogen sulfide (H2S)

 b) Total pressures of oxygen (O2), carbon dioxide (CO2), and hydrogen sulfide (H2S)

 c) Partial pressures of nitrogen (N2), carbon dioxide (CO2), and hydrogen sulfide (H2S)

 d) Partial pressures of oxygen (O2), carbon dioxide (CO2), and hydrogen sulfide (H2S).

27.

What does not necessarily mean that the gas is corrosive?

 a) Exceeding the gas quality standards

 b) Meeting the gas quality standards

 c) Not meeting the gas quality standards

 d) Falling short of the gas quality standards

28.

What does NACE standard MR0175 indicate?

 a) Sulfide stress cracking is expected at H2S partial pressures less than 0.05 psia

 b) Sulfide stress cracking is not expected at H2S partial pressures less than 0.05 psia

 c) Sulfide stress cracking is expected at H2S total pressures less than 0.05 psia

 d) Sulfide stress cracking is not expected at H2S total pressures less than 0.05 psia

29.

What may be considered representative of the gas stream at any other location in the pipeline section?

 a) Gas composition values obtained from multiple sample points at one location

 b) Gas composition values obtained from a sample point at multiple locations

 c) Gas composition values obtained from a sample point at one location

 d) Gas composition values obtained from multiple sample points at multiple locations

30.

What is required for gas composition values obtained from a sample point at one location to be considered representative of the gas stream at any other location in the pipeline section?

 a) No additional gas sources are present

 b) Additional gas sources are present

 c) No additional liquid sources are present

 d) Additional liquid sources are present

31.

What measurements are commonly considered in a gas composition analysis for corrosion purposes?

 A. CO2, H2S

 B. CO2, H2S, Water, O2, Temperature, Pressure

 C. CO2, H2S, Water

 D. CO2, H2S, Water, O2

32.

How is CO2 content usually determined?

 A. By on-site (field) measurements

 B. By sending a gas sample to a remote chemistry laboratory

 C. By using a stain tube

 D. By using an electronic meter

33.

What is the significance of the water content of the gas?

 A. It determines the level of saturation

 B. It determines the level of corrosion

 C. It determines the level of pressure

 D. It determines the level of temperature

34.

What happens when the gas is fully saturated?

 A. It will increase the temperature of the pipeline

 B. It will evaporate water that can support corrosion

 C. It will condense water that can support corrosion

 D. It will decrease the pressure of the pipeline

35.

How is H2S content usually measured?

 A. Using a stain tube or electronic meter

 B. By sending a gas sample to a remote chemistry laboratory

 C. By on-site (field) measurements of temperature and pressure

 D. By using a pressure gauge

36.

What is the purpose of measuring pipeline gas pressure?

 A. To calculate the CO2 partial pressure

 B. To calculate the H2S partial pressure

 C. To determine the level of water saturation in the gas

 D. All of the above

37.

What could result in insupportable data during gas sampling?

 A. Proper gas sampling procedures

 B. Outside factors interfering

 C. Routine gas sampling and analysis

 D. Gas analysis alone

38.

What is typically recorded in a form or database for retrieval and comparison to future values?

 A. Gas sampling data

 B. Water content data

 C. Temperature and pressure data

 D. CO2 and H2S levels

39.

What is often indicated based on measurements of significant levels of CO2 and/or H2S, especially if the gas is wet?

 A. Further monitoring (e.g., coupons, probes, etc.)

 B. Gas sampling and analysis

 C. Gas chromatography

 D. Gas saturation

40.

What is used to calculate the CO2 partial pressure after the percentage of CO2 (CO2 mol. %) is determined by gas chromatography?

 A. Pipeline gas pressure

 B. Water content of the gas

 C. H2S content of the gas

 D. Temperature of the gas

41.

Chapter 3 Internal Corrosion Mitigation
What must the operator first determine before any mitigation program can be properly selected?

 A) The corrosion rate and the corrosion mechanism

 B) The corrosion rate and the corrosion location

 C) The corrosion mechanism and the corrosion location

 D) The corrosion rate, the corrosion mechanism, and the corrosion location

42.

What can cause the internal environment to become corrosive?

 A) Proper selection and application of mitigation measures

 B) Improper selection or misapplication of mitigation measures

 C) Proper selection or misapplication of mitigation measures

 D) Improper selection and application of mitigation measures

43.

What are the methods of internal corrosion mitigation?

 A) Chemical treatment, facilities maintenance, use of internal coatings, use of cathodic protection, and facility design considerations

 B) Chemical treatment, facilities maintenance, use of external coatings, use of anodic protection, and facility design considerations

 C) Physical treatment, facilities maintenance, use of internal coatings, use of cathodic protection, and facility design considerations

 D) Chemical treatment, facilities construction, use of internal coatings, use of cathodic protection, and facility design considerations

44.

How can corrosion be reduced or prevented in natural gas pipelines?

 A) Through maximizing entry of water and limiting the levels of potentially corrosive gases

 B) Through minimizing entry of water and maximizing the levels of potentially corrosive gases

 C) Through maximizing entry of water and maximizing the levels of potentially corrosive gases

 D) Through minimizing entry of water and limiting the levels of potentially corrosive gases

45.

What can cause corrosive conditions to exist for periods of time in pipeline gas?

 A) System upsets

 B) System downtimes

 C) System overtimes

 D) System undertimes

46.

How can internal corrosion control in carbon steel liquid petroleum pipelines be accomplished?

 A) By complete addition of water to the system, promoting operating conditions where water could settle out, or treating the water with corrosion control chemicals

 B) By complete removal of water from the system, promoting operating conditions where water could settle out, or treating the water with corrosion control chemicals.

 C) By complete addition of water to the system, avoiding operating conditions where water could settle out, or treating the water with corrosion control chemicals

 D) By complete removal of water from the system, avoiding operating conditions where water could settle out, or treating the water with corrosion control chemicals

47.

What is often required to get the chemical to the pipe surface and to remove solids?

 A) Jigging

 B) Digging

 C) Rigging

 D) Pigging

48.

How can a treatment chemical be applied to the liquid pipelines?

 A) Either by continuous application or by batch injection

 B) Either by batch application or by discontinuous injection

 C) Either by batch application or by continuous injection

 D) Either by continuous application or by continuous injection

49.

What conditions often determine the effectiveness of a batch treatment?

 A) Stagnant conditions

 B) Static conditions

 C) Dynamic conditions

 D) Flow conditions

50.

What is persistence in the context of an inhibitor?

 A) The ability of an inhibitor to resist detachment from the water surface it protects

 B) The ability of an inhibitor to attach to the water surface it protects

 C) The ability of an inhibitor to resist detachment from the metal surface it protects

 D) The ability of an inhibitor to attach to the metal surface it protects

51.

When a new chemical is being considered, what is recommended that the vendor supply?

 A) Material safety data sheet (MSDS), technical data sheet, and complete price matrix

 B) Performance testing, corrosion inhibitor partitioning, biocide kill test results, and complete price matrix

 C) Material safety data sheet (MSDS), technical data sheet, temperature stability, and compatibility information

 D) Material safety data sheet (MSDS), technical data sheet, temperature stability, compatibility information, performance testing, corrosion inhibitor partitioning, biocide kill test results, and complete price matrix.

52.

How may chemicals be applied?

 A) In batches or injected discontinuously

 B) In batches or injected continuously

 C) In slugs or injected discontinuously

 D) In slugs or injected continuously

53.

What does chemical treatment for corrosion control in most natural gas systems typically include?

 A) The use of biocides and hydrate prevention

 B) The use of biocides and emulsions

 C) The use of corrosion inhibitors and foam

 D) The use of biocides and corrosion inhibitors

54.

What is an example of slug (batch) treatment in a pipeline?

 A) When a measured amount of chemical is placed between two pigs for the purpose of removing a film from the circumference of the pipe wall

 B) When a measured amount of chemical is placed between two pigs for the purpose of examining a film on the circumference of the pipe wall

 C) When a measured amount of chemical is placed between two pigs for the purpose of changing a film on the circumference of the pipe wall

 D) When a measured amount of chemical is placed between two pigs for the purpose of laying a film down on the circumference of the pipe wall

55.

What is the choice of an application method a function of?

 A) The type of pipeline

 B) The type of corrosion

 C) The type of chemical

 D) The type of inhibitor

56.

What do metabolic inhibitors do?

 A) They damage enzymes and protein structures, inhibiting the transport of nutrients or other molecules, and affecting other metabolic processes

 B) They enhance enzymes and protein structures, promoting the transport of nutrients or other molecules, and enhancing other metabolic processes

 C) They damage cell membranes and walls or affect the cell’s ability to regulate its internal environment

 D) They enhance cell membranes and walls or promote the cell’s ability to regulate its internal environment

57.

What do surface-active agents do?

 A) They enhance cell membranes and walls or promote the cell’s ability to regulate its internal environment

 B) They alter or destroy cell membranes and walls or affect the cell’s ability to regulate its internal environment

 C) They enhance enzymes and protein structures, promoting the transport of nutrients or other molecules, and enhancing other metabolic processes

 D) They damage enzymes and protein structures, inhibiting the transport of nutrients or other molecules, and affecting other metabolic processes

58.

How are biocides broadly classified?

 A) Into oxidizers and non-oxidizers

 B) Into organic and inorganic compounds

 C) Into natural and synthetic compounds

 D) Into soluble and insoluble compounds

59.

What is the most reliable test apparatus to evaluate biocide performance?

 A) The artificial environment

 B) The laboratory environment

 C) The natural environment

 D) The operating environment

60.

What is ordinarily not a problem when two or more chemicals are present in conjunction?

 A) Compatibility of corrosion treatment chemicals with other products

 B) Incompatibility of corrosion treatment chemicals with other products

 C) Solubility of corrosion treatment chemicals with other products

 D) Insolubility of corrosion treatment chemicals with other products

61.

Chapter 4 Internal Corrosion Integrity Management
What does integrity imply in relation to pipelines?

 A) A pipeline system is unsound and incapable of unsafely performing the tasks for which it was designed

 B) A pipeline system is unsound and incapable of safely performing the tasks for which it was designed

 C) A pipeline system is sound and capable of unsafely performing the tasks for which it was designed

 D) A pipeline system is sound and capable of safely performing the tasks for which it was designed

62.

What were implemented in late 2002 for liquid pipelines in the U.S.?

 A) Old federal integrity management regulations

 B) New federal integrity promotion regulations

 C) Old federal integrity promotion regulations

 D) New federal integrity management regulations

63.

What does pipeline integrity management describe?

 A) A process that is used to ensure discontinued operation in an unsafe manner that meets all applicable regulations

 B) A process that is used to ensure discontinued operation in a safe manner that meets all applicable regulations

 C) A process that is used to ensure continued operation in an unsafe manner that meets all applicable regulations

 D) A process that is used to ensure continued operation in a safe manner that meets all applicable regulations

64.

What is a critical part of any pipeline integrity program?

 A) External corrosion promotion

 B) External corrosion control

 C) Internal corrosion promotion

 D) Internal corrosion control

65.

What are common methods for monitoring internal corrosion?

 A) Weight gain coupons; radiography; gas chemistry tests; in-line inspection tools; and electrical, galvanic, resistance, and hydrogen probes

 B) Weight loss coupons; radiography; gas chemistry tests; in-line inspection tools; and electrical, galvanic, resistance, and hydrogen probes

 C) Weight gain coupons; radiography; water chemistry tests; in-line inspection tools; and electrical, galvanic, resistance, and hydrogen probes

 D) Weight loss coupons; radiography; water chemistry tests; in-line inspection tools; and electrical, galvanic, resistance, and hydrogen probes

66.

What are liquid pipeline operators now required to develop?

 A) A promotion integrity program

 B) An integrity promotion program

 C) A promotion management program

 D) An integrity management program

67.

What are drips, dead legs, and sags in the context of pipeline location?

 A) Offline segments that are cleaned by pigging or other methods

 B) Offline segments that are not cleaned by pigging or other methods

 C) Online segments that are cleaned by pigging or other methods

 D) Online segments that are not cleaned by pigging or other methods

68.

What does the overall process of pipeline integrity management generally include?

 A) Developing a plan, assessing conditions, making repairs or promoting risk, and monitoring and approval

 B) Developing a plan, assessing conditions, making repairs or mitigating risk, and monitoring and approval

 C) Developing a plan, assessing conditions, making repairs or promoting risk, and monitoring and review

 D) Developing a plan, assessing conditions, making repairs or mitigating risk, and monitoring and review

69.

What do the integrity management rules apply to?

 A) Pipeline sections defined by code as high consequence areas (HCAs)

 B) Pipeline sections defined by code as low consequence areas (LCAs)

 C) Pipeline sections defined by code as no consequence areas (NCAs)

 D) Pipeline sections defined by code as medium consequence areas (MCAs)

70.

What cannot be completely eliminated, no matter how good a plan and inspection program?

 A) The chance of a pipeline design or initiation

 B) The chance of a pipeline construction or completion

 C) The chance of a pipeline repair or success

 D) The chance of a pipeline leak or failure

71.

What are some factors that present a greater risk to integrity or could result in more severe consequences in the event of a leak or failure?

 A) Results of future integrity assessments, pipe size, material, manufacturer, coating type and condition, seam type, leak future, repair future, Cathodic Protection future, and internal corrosion future

 B) Results of previous integrity assessments, pipe size, material, manufacturer, coating type and condition, seam type, leak history, repair history, Cathodic Protection history, and internal corrosion history

 C) Results of future integrity assessments, pipe size, material, manufacturer, coating type and condition, seam type, leak history, repair history, Cathodic Protection history, and internal corrosion history

 D) Results of previous integrity assessments, pipe size, material, manufacturer, coating type and condition, seam type, leak future, repair future, Cathodic Protection future, and internal corrosion future

72.

What is internal corrosion integrity management?

 A) A superset of the overall integrity management process

 B) A subset of the overall integrity promotion process

 C) A superset of the overall integrity promotion process

 D) A subset of the overall integrity management process

73.

What is the objective of what is presented in the section on internal corrosion integrity management?

 A) Increasing the risk associated with internal corrosion

 B) Reducing the risk associated with internal corrosion

 C) Increasing the risk associated with external corrosion

 D) Reducing the risk associated with external corrosion

74.

What are some factors that may impact the likelihood, or risk of, internal corrosion?

 A) Nature of product transported, flow rate/velocity, presence of H2S or CO2, water content and dew point, elevation/inclination of pipeline, internal coating, weld quality/joint type, water chemistry/microbiology, if line is piggable/routinely pigged, knowledge of previous internal corrosion

 B) Nature of product transported, flow rate/velocity, absence of H2S or CO2, water content and dew point, elevation/inclination of pipeline, external coating, weld quality/joint type, water chemistry/microbiology, if line is piggable/routinely pigged, knowledge of previous internal corrosion

 C) Nature of product transported, flow rate/velocity, presence of H2S or CO2, water content and dew point, elevation/inclination of pipeline, external coating, weld quality/joint type, water chemistry/microbiology, if line is piggable/routinely pigged, knowledge of previous internal corrosion

 D) Nature of product transported, flow rate/velocity, absence of H2S or CO2, water content and dew point, elevation/inclination of pipeline, internal coating, weld quality/joint type, water chemistry/microbiology, if line is piggable/routinely pigged, knowledge of previous internal corrosion

75.

Who is it up to assess and determine whether and how each factor is involved for every pipeline segment that falls under the integrity management program?

 A) The corrosion novice

 B) The corrosion expert

 C) The corrosion amateur

 D) The corrosion professional

76.

What is not a trivial task in most cases, as a significant amount of data must be collected and analyzed?

 A) Assessing and determining whether and how each factor is involved for all pipeline segments that fall under the integrity management program

 B) Assessing and determining whether and how each factor is involved for no pipeline segments that fall under the integrity management program

 C) Assessing and determining whether and how each factor is involved for some pipeline segments that fall under the integrity management program

 D) Assessing and determining whether and how each factor is involved for every pipeline segment that falls under the integrity management program

77.

What is a characteristic that implies a pipeline system is sound and capable of safely performing the tasks for which it was designed?

 A) Deceit

 B) Corruption

 C) Dishonesty

 D) Integrity

78.

What is an all-encompassing concept that goes well beyond merely meeting prescribed requirements?

 A) Deceit

 B) Corruption

 C) Dishonesty

 D) Integrity

79.

What are the potential consequences of a rupture in a high-pressure, 30 in. (76-cm)- diameter natural gas line certainly greater than?

 A) Those of a 30 in. (76-cm)-diameter high-pressure line

 B) Those of a 30 in. (76-cm)-diameter low-pressure line

 C) Those of a 4 in. (10-cm)-diameter high-pressure line

 D) Those of a 4 in. (10-cm)-diameter low-pressure line

80.

What did the U.S. Department of Transportation’s (DOT’s) Office of Pipeline Safety (OPS) issue in 2000?

 A) A bulletin to owners and operators of natural gas transmission pipeline systems advising them to review their external corrosion promotion programs

 B) A bulletin to owners and operators of natural gas transmission pipeline systems advising them to review their external corrosion control programs

 C) A bulletin to owners and operators of natural gas transmission pipeline systems advising them to review their internal corrosion promotion programs

 D) A bulletin to owners and operators of natural gas transmission pipeline systems advising them to review their internal corrosion control programs

81.

What is the first step in the process of internal corrosion management?

 A) Developing a plan

 B) Assessing conditions

 C) Mitigating risk

 D) Monitoring and review

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AMPP/NACE ICT Theory Exam Syllabus:

We are covering all the topics given below in this free AMP ICT Theory Exam practice test quiz course:

1. Corrosion Theory, Types, and Mechanisms
2. Identification of Corrosion Mechanisms
3. Internal Corrosion Mitigation
4. Integrity Management

AMPP/ NACE ICT Theory CBT Exam Pattern:

Test Name: NACE ICT –Internal Corrosion Technologist Theory
Test Code: NACE-ICT-001
Time: 2 ½ hours*
Number of Questions: 75
Format: Computer Based Testing (CBT)
NOTE: A pass/fail grade is provided at the end of the exam.

AMPP NACE ICT – Internal Corrosion Technologist Theory Exam Requirements:

To become an Internal Corrosion Technologist, candidates must fulfill the following unique criteria:

Work Experience Options:

• Accumulate 4 years of proven internal corrosion-related experience within a pipeline setting.
  OR
• Possess a Bachelor’s Degree in Biology, Microbiology, Chemistry, Chemical Engineering, or Metallurgical Engineering, coupled with 2 years of documented internal corrosion-related work experience in a pipeline environment.

Course Recommendation: Successful completion of the rigorous Internal Corrosion for Pipelines – Basic Course.

Core Exam Prerequisites:

• Completion of the Internal Corrosion Technologist Theory Exam.
• Successful undertaking of the Internal Corrosion Technologist Practical Exam.

Application Requirement: Submission and approval of the Internal Corrosion Technologist application.

These distinctive requirements ensure that candidates possess both academic knowledge and practical experience essential for effectively combating internal corrosion in pipeline systems.

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