Posted by: timtraining | April 28, 2011


Internal Corrosion Problems in Gas, Oil and Produced Water Pipeline and Equipment

n  Piping and Pipeline Leakage due to Pitting Corrosion and Microbiological Induced Corrosion

n  Severe Pipe Wall Thickness Reduction and Short Remaining Service Life caused by Sour Corrosion

n  Pipe Wall, Rotating Parts and Equipment Cracking due to Chloride and Sulfide in the Fluids

n  Internal Corrosion of Pipeline and Equipment due to Water in Oil and Oil in Water Emulsions

n  Internal Corrosion due to Multi Phase Flow in the Pipeline

n  Severe Corrosion Rate caused by CO2 and Hydrate in the Gas Lines, CO2/H2S Removal Unit and Glycol Dehydration Unit

n  Internal Corrosion in the Water Lines due to Dissolved Oxygen, Mud and Sludge

n  Malfunction of Pump, Compressor, Valves and Equipment due to Under-Deposit Corrosion, Under-Film Corrosion and Fouling

The Nature, Mechanism and Characteristics of Internal Corrosion and the Control Methods

n  Anodic-Cathodic Reactions, Electrical Properties and Characteristics of Corrosion Cells

n  Physical & Metallurgical Conditions of Metals and Chemical Composition that Promote Corrosion

n  Destructive and Catastrophic Effects of Corrosive Agents and Microorganism in the Gas, Oil and Produced Water Fluids

n  The Role and Mechanism of O2, CO2, H2S, Dissolved Salts and Microorganism in Internal Corrosion

n  The Role of Oilfield Bacteria and the Mechanism of MIC

n  Characteristics and Detection of Internal Corrosion in the Pipeline and Surface Equipment

n  Removal of Dissolved Corrosive Agents and Non-Hydrocarbon Gases in the Gas, Oil and Produced Water Fluids

n  Internal Corrosion Control with On-line Chemical Inhibitors Injection, Surface Barriers and Scavengers


Internal Corrosion Detection and Monitoring  Techniques, Devices and Analysis

n  Visual Inspection and Early Detection Techniques & Devices for Monitoring Fluid Corrosiveness and Tests for Identifying Corrosion products

n  The Important of Internal Corrosion Rate Monitoring Before and After Chemical Injection and Treatment

n  NACE Standard Method for Preparation, Installation, Laboratory Analysis and Interpretation of Results of Internal Corrosion Monitoring

n  Access Fittings, Retrievers, Corrosion Coupons, Scale Coupons, Corrosion Probes,  Holders, Injection & Sampling Devices and Instrument for On-line Internal Corrosion Monitoring

n  The Use of Nipple or Spool, Hydrogen Probe and Galvanic Probe

n  NACE Standard Method for Testing and Analysis of Bacterial Activity and Microbiological Induced Corrosion

n  Iron Content Analysis of Produced Water and the COPRA Correlation

n  Down-hole Tubing or Casing Calipers, Ultrasonic Wall Thickness Testers and Radiography

Internal Corrosion Control with Chemical Inhibitor Injection, Passive Film Formation and Biocides

n  Nature & Classification of Inhibitors and Effect of Ionic Character on

Inhibiting Ability

n  Formulations of Oilfield Inhibitors and the use of Water Soluble Inhibitors, Volatile Inhibitors and Acid Inhibitors

n  Typical Corrosion Inhibitors, Scavengers & Biocides for Oil & Gas Field

n  Guidelines of Inhibitor and Biocide Applications and the Chemical Injection Equipment for Pipeline and Surface Facility

n  Inhibitor and Biocide Batch Treatment Using Pigs, Chemical Dosage and the Pigging Operations

n  Surfactant and Cleaners for Solving Fouling Problem in the Equipment and Systems

n  Cationic & Mixed Charge Organic Inhibitors for Hydrocarbon and Oxygen Corrosion Inhibitors for Produced Water

n  Testing and Evaluation of Inhibitor and Biocide Effectiveness

n  Safety Precaution in Working with Inhibitors and Biocides

Internal Corrosion Control as a Key Factor to Pipeline Integrity Management

n  Hazard Assessment and Risk Based Inspection for the Pipeline and Equipment Maintenance Program

n  Pipeline Internal Damage Record and Wall Thickness Monitoring

n  Pigging for Water and Deposit Removal from the Pipeline System

n  Controlling of Flow Stability and Corrosion Rate to a Safe Level

n  Estimating Present Pipeline Remaining Service Life

n  Evaluation of Present Condition and Comparison with Initial Pipeline Design Baseline

n  Evaluation and Controlling of Chemical Inhibitor and Biocide Injection by using Corrosion Rate Monitoring Data.

n  Evaluation of Pipeline and Equipment Damage in accordance with Root Cause Failure Analysis

n  Development of Specific Pipeline Integrity Management System by using Internal Corrosion Rate Monitoring Data

Course Leader: Hilman Ahmad

This specially designed course will be conducted by Hilman Ahmad & Associates, an Independent Consultant in industrial oil and gas, member of the Society of Indonesian Petroleum Engineers, who manage the Professional Industrial Oil & Gas Education Center, and has been practicing production operation & safety and corrosion control engineering in Indonesia for more than twenty-five years. He post-graduated from Tokyo Institute of Technology (sponsored by UNESCO) in 1977. He joined in-field-practice program at Nippon Kokan Steel Company & Research Center Kawasaki, Japan for production facility design & construction and corrosion prevention & control in 1983, and collaborated with Cormon Industrial Research Center Brighton UK for on-line corrosion monitoring development in 2000. He has been delivering training course in production operation, maintenance & safety and corrosion control for personnel from Oil & Gas Company and Petrochemical Industry since 1979.

General Information


ü  Quality training material (hardcopy and softcopy)

ü  Quality training kits included calculator, T-shirt or jacket, cap, ect.

ü  Convenient training facilities with four star quality

ü  Morning and afternoon coffee breaks and lunch for along the training

ü  Certificate of Completion

ü  Exclusive flash disk.

Tuition Fee & Registration Deadline

IDR 8.750.000,-/ Person, (excluded tax 10% and accommodation)

Registration and payment deadline a weeks before training held.

For further information and registration please contact:

Mohammad Ramli     +62 852 17900 824

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