PRACTICAL INTERNAL CORROSION CONTROL AND MONITORING IN OIL & GAS OPERATIONS

April 5-8, 2011 at Bali

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

• Piping and Pipeline Leakage due to Pitting Corrosion and Microbiological Induced Corrosion
• Severe Pipe Wall Thickness Reduction and Short Remaining Service Life caused by Sour Corrosion
• Pipe Wall, Rotating Parts and Equipment Cracking due to Chloride and Sulfide in the Fluids
• Internal Corrosion of Pipeline and Equipment due to Water in Oil and Oil in Water Emulsions
• Internal Corrosion due to Multi Phase Flow in the Pipeline
• Severe Corrosion Rate caused by CO2 and Hydrate in the Gas Lines, CO2/H2S Removal Unit and Glycol Dehydration Unit
• Internal Corrosion in the Water Lines due to Dissolved Oxygen, Mud and Sludge
• 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

• Anodic-Cathodic Reactions, Electrical Properties and Characteristics of Corrosion Cells
• Physical & Metallurgical Conditions of Metals and Chemical Composition that Promote Corrosion
• Destructive and Catastrophic Effects of Corrosive Agents and Microorganism in the Gas, Oil and Produced Water Fluids
• The Role and Mechanism of O2, CO2, H2S, Dissolved Salts and Microorganism in Internal Corrosion
• The Role of Oilfield Bacteria and the Mechanism of MIC
• Characteristics and Detection of Internal Corrosion in the Pipeline and Surface Equipment
• Removal of Dissolved Corrosive Agents and Non-Hydrocarbon Gases in the Gas, Oil and Produced Water Fluids
• Internal Corrosion Control with On-line Chemical Inhibitors Injection, Surface Barriers and Scavengers

Internal Corrosion Detection and Monitoring Techniques, Devices and Analysis

• Visual Inspection and Early Detection Techniques & Devices for Monitoring Fluid Corrosiveness and Tests for Identifying Corrosion products
• The Important of Internal Corrosion Rate Monitoring Before and After Chemical Injection and Treatment
• NACE Standard Method for Preparation, Installation, Laboratory Analysis and Interpretation of Results of Internal Corrosion Monitoring
• Access Fittings, Retrievers, Corrosion Coupons, Scale Coupons, Corrosion Probes, Holders, Injection & Sampling Devices and Instrument for On-line Internal Corrosion Monitoring
• The Use of Nipple or Spool, Hydrogen Probe and Galvanic Probe
• NACE Standard Method for Testing and Analysis of Bacterial Activity and Microbiological Induced Corrosion
• Iron Content Analysis of Produced Water and the COPRA Correlation
• Down-hole Tubing or Casing Calipers, Ultrasonic Wall Thickness Testers and Radiography

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

• Nature & Classification of Inhibitors and Effect of Ionic Character on
• Inhibiting Ability
• Formulations of Oilfield Inhibitors and the use of Water Soluble Inhibitors, Volatile Inhibitors and Acid Inhibitors
• Typical Corrosion Inhibitors, Scavengers & Biocides for Oil & Gas Field
• Guidelines of Inhibitor and Biocide Applications and the Chemical Injection Equipment for Pipeline and Surface Facility
• Inhibitor and Biocide Batch Treatment Using Pigs, Chemical Dosage and the Pigging Operations
• Surfactant and Cleaners for Solving Fouling Problem in the Equipment and Systems
• Cationic & Mixed Charge Organic Inhibitors for Hydrocarbon and Oxygen Corrosion Inhibitors for Produced Water
• Testing and Evaluation of Inhibitor and Biocide Effectiveness
• Safety Precaution in Working with Inhibitors and Biocides

Internal Corrosion Control as a Key Factor to Pipeline Integrity Management

• Hazard Assessment and Risk Based Inspection for the Pipeline and Equipment Maintenance Program
• Pipeline Internal Damage Record and Wall Thickness Monitoring
• Pigging for Water and Deposit Removal from the Pipeline System
• Controlling of Flow Stability and Corrosion Rate to a Safe Level
• Estimating Present Pipeline Remaining Service Life
• Evaluation of Present Condition and Comparison with Initial Pipeline Design Baseline
• Evaluation and Controlling of Chemical Inhibitor and Biocide Injection by using Corrosion Rate Monitoring Data.
• Evaluation of Pipeline and Equipment Damage in accordance with Root Cause Failure Analysis
• 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
Facilities

• Quality training material (hardcopy and softcopy)
• Quality training kits included calculator, T-shirt or jacket, cap, ect.
• Convenient training facilities with four star quality
• Morning and afternoon coffee breaks and lunch for along the training
• Certificate of Completion
• 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.