Server maintenance is scheduled for Saturday, December 21st between 6am-10am CST.

During that time, parts of our website will be affected until maintenance is completed. Thank you for your patience.

Menu
Search
Filters
Close
Menu

Selection and Testing of Fusion Bond Epoxy Coating for High Pressure Pipelines with H2S and CO2 Acid Gases

Picture for Selection and Testing of Fusion Bond Epoxy Coating for High Pressure Pipelines with H2S and CO2 Acid Gases
Available for download

New gas field expansion will provide offshore facilities to process non-associated gas, where the new
gas gathering system takes non-associated gas from offshore gas wells and transports it through
pipeline to onshore processing plants. The gas is very corrosive due to high levels of H2S and CO2 acid
gases content. Further hydrate control is achieved by injecting mono ethylene glycol (MEG).

Product Number: 51323-19482-SG
Author: Sameer Ayyar
Publication Date: 2023
$0.00
$20.00
$20.00

Selection of materials for high pressure gas pipelines is driven by the reservoir conditions. Designers
calculate the expected corrosion rate per year based on the reservoir conditions including pressure,
temperature, water loading, H2S and CO2 acid gases content. The calculated corrosion rate is then
multiplied by the design life, and material selection is performed. When corrosion is expected to exceed
a certain level, corrosion resistant alloy (CRA) material or CRA weld overlay on carbon steel are
selected. In cases of lower corrosion rates, carbon steel with a higher wall thickness (corrosion
allowance) is selected.


For an offshore field with up to 8% H2S and 6.5% CO2, the choice of material based on calculated
corrosion rates had been CRA material. A design optimization was performed to utilize carbon steel
material with Fusion Bond Epoxy (FBE) coating instead of CRA material. The reservoir conditions were,
however, beyond the conventional limits of FBE coating with respect to partial pressures of acid gases
of H2S and CO2. A specialized testing and qualification program using 14 samples (8 samples for pipe
body and 6 samples for girth weld) was performed to qualify FBE coating for the high-pressure gas.


This paper summarizes FBE testing qualification program and coating test results for pipe body and
girth weld for the given challenging reservoir conditions.

Selection of materials for high pressure gas pipelines is driven by the reservoir conditions. Designers
calculate the expected corrosion rate per year based on the reservoir conditions including pressure,
temperature, water loading, H2S and CO2 acid gases content. The calculated corrosion rate is then
multiplied by the design life, and material selection is performed. When corrosion is expected to exceed
a certain level, corrosion resistant alloy (CRA) material or CRA weld overlay on carbon steel are
selected. In cases of lower corrosion rates, carbon steel with a higher wall thickness (corrosion
allowance) is selected.


For an offshore field with up to 8% H2S and 6.5% CO2, the choice of material based on calculated
corrosion rates had been CRA material. A design optimization was performed to utilize carbon steel
material with Fusion Bond Epoxy (FBE) coating instead of CRA material. The reservoir conditions were,
however, beyond the conventional limits of FBE coating with respect to partial pressures of acid gases
of H2S and CO2. A specialized testing and qualification program using 14 samples (8 samples for pipe
body and 6 samples for girth weld) was performed to qualify FBE coating for the high-pressure gas.


This paper summarizes FBE testing qualification program and coating test results for pipe body and
girth weld for the given challenging reservoir conditions.

Product tags
Also Purchased
Picture for 10189 Non-Technical Solutions for Technical Challenges
Available for download

10189 Non-Technical Solutions for Technical Challenges

Product Number: 51300-10189-SG
ISBN: 10189 2010 CP
Author: Martyn G. B. Cooper and John Fletcher
Publication Date: 2010
$20.00
Picture for 08027 Insights into Atlas Cell Testing for Selection of Linings for Oil and Gas Production Vessels
Available for download

08027 Insights into Atlas Cell Testing for Selection of Linings for Oil and Gas Production Vessels and Tanks

Product Number: 51300-08027-SG
ISBN: 08027 2008 CP
Author: L. Gray, N. Varennes, B. A. Bloor, M. O'Donoghue, R. Garrett, R. Graham, V. Datta, and B. Franke
Publication Date: 2008
$20.00
Picture for 08040 New Technology Helps Develop Coatings for High-Operating-Temperature Pipelines
Available for download

08040 New Technology Helps Develop Coatings for High-Operating-Temperature Pipelines

Product Number: 51300-08040-SG
ISBN: 08040 2008 CP
Author: J. Alan Kehr, Sam Attaguile, Dr. Mario A. Perez, and Mark Smith
Publication Date: 2008
$20.00
Categories
Industry
Recently viewed
Popular tags
View all

Association for Materials Protection and Performance

© AMPP All Rights Reserved.
Membership Terms of Content Use
Contact Customer Support