DownStream Oil & Gas Session
18 August, Thursday - Kedah Room - 1:30pm - 3:15pm

Chair : Mohd Hafiz Zakaria, Sarawak Shell Berhad​

Corrosion-Free Pipeline: A Reality or Far-fetched?

18 August, Thursday - Kedah Room - 1:35pm - 2:05pm

Bio of Speaker


Full Name :  Mohd Nazmi bin Mohd Ali Napiah
Title / Position :  Custodian (Pipeline Integrity)/ Group Technical Authority
Company name :  Petronas GTS

Custodian/Group Technical Authority with 20 years’ experience, delivering optimal engineering solutions for key pipeline projects and initiatives.  Hands-on and diverse operations and project management experiences in the oil and gas industry. Focused efforts on pipeline design and integrity management systems and key business performance improvements. He’s also Editorial Board Member of Journal of Pipeline Engineering incorporating Journal of Pipeline Integrity, Vice-Chairman of Malaysia’s ISO Standard Technical Committee 67 – Pipeline Transportation, and Leader of Study Group 3 of International Gas Union’s (IGU) Transmission Committee. He’s been active delivering technical papers on various topics concerning pipeline integrity, operation and maintenance worldwide.
Corrosion is the one of the primary factors that threatening offshore and onshore pipelines worldwide as well as in Malaysia. In Malaysia, PETRONAS owns approximately more than 10,000 kilometres of high pressure liquid and gas pipelines. The average age of the pipelines is between 15-20 years and there are pipelines that more than 30 years in operation and require repair and/or rehabilitation for continued operation. Carbon steel and steel-related material has always been the ‘primary’ choice of material for pipelines due to its long term acceptably-safe service histories in the oil and gas industry. Nevertheless, as pipelines age, corrosion attacks are imminent that pushes the cost of inspection, monitoring, repairs to be at least 70% of the total operation and maintenance cost of pipelines. The industry, as of today, has developed various non-metallic materials for pipeline construction, repair and rehabilitation e.g. reinforced thermoplastic, thermo-composite, composite etc. But the question remains on utilising non-metallic pipe as ‘PRIMARY’ material selection in green field development rather than just for pipeline rehabilitation and repairs. If the non-metallic materials are to be used in green field development project, corrosion related costs can be reduced to nearly zero throughout the pipeline life cycle. In view of the matter that could be of multi-millions dollar value creation to PETRONAS in current as well as future oil and gas economic scenarios, PETRONAS has devised a novel concept and methodology combining front end engineering, ‘current and future’ risk-based approach for the whole life cycle of pipeline and life cycle cost analysis in assessing non-metallic materials for greenfield development. This paper will provide brief run through of the novel concept, a simulation case study and how it will benefit PETRONAS and industry technically and economically.

Crude furnace creep assessment and high temperature degradation

18 August, Thursday - Kedah Room - 2:10pm - 2:40pm

Bio of Speaker


Name:  Gary Yaw Hoong Lee
Title / Position:  Fitness for Service Engineer
Company:  Shell Global Solutions (Malaysia) Sdn Bhd

I am an engineer in the Fitness for Service Assessment team within the Mechanical, Materials and Integrity department of Shell Projects and Technology Engineering Services. My current role involves regional focal point duties on fitness for service work in the arena of adopting API 579 practices including vibration induced fatigue troubleshooting and assessments for pipework. These involve frequent work with operating sites with visits for reviews, workshops, audits, failure investigations and root cause analyses.
I currently am the global custodian of the web based pipework vibration software screening methodology and am also driving R+D innovation to continually improve the assessment procedures. I am also the regional focal points for high temperature degradation and low temperature embrittlement of materials.
Creep calculations indicate a crude furnace radiant section carbon steel tubes exceeding their life fraction due to flame impingement reaching up to 700C for a year. The ambiguity of the temperature and material data means the life fraction of creep calculations were based on limited inspection data and infra-red scanning giving a conservative indication of end of life. Due to unavailable tubes in stock, a planned pit stop cannot be arranged due to economic and safety reasons as the furnace cannot be started back up safely. 

Material performance and Corrosion Monitoring in Ammonia Plant

18 August, Thursday - Kedah Room - 2:45pm - 3:15pm

Bio of Speaker


Name: Mohd Farid Mohamed
Title / Position:  Corrosion Engineer
Company:  Petronas Group Technical Solutions

​​Mohamed, M.F, earned his a Master of Science degree from Ohio University and first degree from the Science University of Malaysia. He is currently working with Petronas Group Technical Solutions and as technical consultant. He works in corrosion field since 2003 which cover the corrosion issues from design stage, fabrication until operation of downstream and upstream industries.  Farid authored/co-authored over 5 presented and published paper. His work interests include material selection, prediction model, and coating and corrosion inhibition. He has also experience in research on CI, blending, testing, CI application and field monitoring.
The abundance of natural gas from offshore Malaysia provides the much required feed to Ammonia plant in producing liquefied ammonia. Malaysia is the main ammonia producer in Asia with 950,000 metric tons production in 2009 [1]. This paper aims to share failures experienced in the ammonia plant due to corrosion. The operational corrosion risks highly depend on the materials of construction, the operating conditions and the presence of corrosive agents. The influence of the changing of conditions on the process parameter as well as forthcoming effect to corrosion will also be discussed. One of the mitigation includes the establishment of an IOW program that is designed to provide the notification of an increased integrity risk enabling proactive actions to be taken by the plant operators in a timely manner. The IOW program can greatly increase its effectiveness, provide preventions and early recognition of equipment failure and loss of primary containment.