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| Section | Weight | Objectives |
|---|---|---|
| Topic 1: Uniform or Localized Loss of Thickness | 25% | - Oxidation and Scaling - Ammonium Bisulfide Corrosion - Sulfidation - Corrosion Under Insulation (CUI) - Hydrochloric Acid Corrosion |
| Topic 2: Other Damage Mechanisms | 15% | - Erosion and Erosion-Corrosion - Liquid Metal Embrittlement - Cavitation Damage - Microbiologically Influenced Corrosion |
| Topic 3: Mechanical and Metallurgical Failure Mechanisms | 15% | - Creep and Stress Rupture - Brittle Fracture - Mechanical Fatigue - Thermal Fatigue |
| Topic 4: High-Temperature Corrosion and Degradation | 15% | - Metal Dusting - Decarburization - Carburization - Graphitization |
| Topic 5: Terms, Definitions, and Acronyms | 5% | |
| Topic 6: Environmentally Assisted Cracking | 25% | - Hydrogen Embrittlement - Caustic Stress Corrosion Cracking - Chloride Stress Corrosion Cracking - Sulfide Stress Cracking |
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NEW QUESTION # 47
(Which of the following is the appropriate method for monitoring hydrochloric acid corrosion susceptibility in an atmospheric crude unit?)
Answer: D
Explanation:
Comprehensive and Detailed Explanation From Exact Extract:
Hydrochloric acid (HCl) corrosion in atmospheric crude units is primarily associated with the overhead system, where chloride salts hydrolyze to form HCl in the presence of condensed water. This damage mechanism is well documented in API RP 571 under "Chloride Stress Corrosion Cracking and Hydrochloric Acid Corrosion".
The primary indicator of HCl corrosion risk is the acidity of the condensed water in the overhead system.
The overhead accumulator boot water collects condensed water where dissolved HCl will be present.
Monitoring the pH of this water provides a direct, real-time indication of acid formation and corrosion severity.
* Low pH values (typically below 5.5) indicate active HCl corrosion conditions.
* API RP 571 states that pH monitoring is a key operational control and surveillance tool for managing overhead corrosion.
Why the other options are incorrect:
* Option A (UT at water injection points) does not address overhead acid formation and is not a susceptibility monitoring method.
* Option C (Corrosion probes or coupons) provide general corrosion rate data, but they do not directly measure HCl formation or acid severity and often respond too slowly for operational control.
* Option D (UT scanning or radiography) is a damage detection method, not a susceptibility or early- warning monitoring technique.
API RP 571 emphasizes that effective monitoring of HCl corrosion requires controlling and monitoring water chemistry, especially pH in the overhead accumulator boot, to prevent severe localized corrosion and ammonium chloride salt deposition.
Referenced Documents (Study Basis):
* API RP 571 - Section on Hydrochloric Acid Corrosion in Crude Unit Overhead Systems
* API Corrosion and Materials Study Guides - Atmospheric Crude Unit Overhead Corrosion
NEW QUESTION # 48
Stainless steels have higher coefficients of thermal expansion than carbon steel or low alloy steel or nickel based alloys and are more likely to see _________.
Answer: C
NEW QUESTION # 49
Which of the materials listed are not susceptible to Chloride Stress Corrosion Cracking?
Answer: D
Explanation:
Chloride Stress Corrosion Cracking (Cl-SCC) is a serious form of corrosion primarily affecting austenitic stainless steels and some duplex stainless steels, particularly when exposed to chloride-containing environments at elevated temperatures.
According to API RP 571 Section 5.1.2.3 (Chloride Stress Corrosion Cracking - Cl-SCC):
"Austenitic stainless steels (e.g., 300 series such as Types 304 and 316) are the most susceptible to Cl-SCC...
Duplex stainless steels have greater resistance but are not immune, especially at temperatures >150°F (65° C)... Ferritic stainless steels (400 series) are generally not susceptible." Thus, Option A (400 Series Stainless Steel) is not susceptible to chloride SCC, making it the correct answer.
NEW QUESTION # 50
The remaining life of a component susceptible to creep damage can be cut in half by a/an:
Answer: A
Explanation:
According to API RP 571 Section 5.3.2.1 (Creep):
"Creep damage is exponentially dependent on temperature. A small increase in temperature (e.g., 25°F or 15° C) can reduce remaining life by more than half. This is because the creep rate increases rapidly with temperature, especially above design limits." Stress is a contributing factor, but the dominant and most sensitive variable is temperature.
Thus, Option C (increase in temperature of 25°F/15°C) is the correct answer.
NEW QUESTION # 51
Lean amine is generally not corrosive because they have either low conductivity and/or high pH. Corrosion rates increase with increasing temperatures, particularly in rich amine service. Temperatures above _________ can result in acid gas flashing and severe localized corrosion.
Answer: C
NEW QUESTION # 52
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