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11118 Material Selection Assessment for Topside Process Equipment for Production Fluids with High CO2 Content

Picture for 11118 Material Selection Assessment for Topside Process Equipment for Production Fluids w/ High CO2
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Product Number: 51300-11118-SG
ISBN: 11118 2011 CP
Author: Felipe A. Ramirez, Richard T. Hill, Brian Monty and Gunasekaran Palanivel
Publication Date: 2011
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During recent years, in the exploration for new oil and gas sources, the tendency towards developing offshore fields in more stringent environments has increased. Operators are now developing deep water, high pressure, high temperature, and high CO2 fields. This tendency has created numerous challenges to the project initial cost (CAPEX) and subsequent operational cost (OPEX). The material selection is critical for such fields showing high CO2 content. Although the initial capital cost for using carbon steel may be much lower than that of a corrosion resistant alloy (CRA), the total cost of the carbon steel option could be much higher due to the required corrosion inhibition programs as well as the potential for equipment failures representing losses from not only the cost of repairs, but also the loss of production.

This paper addresses the material selection assessment for topside process equipment for production fluids with high CO2 content. A project specific case study is analyzed in terms of: 1) fluid/CO2 partitioning through the topsides production systems, 2) corrosion analysis involving multiphase (oil, gas, and produced water) and single phase streams, and 3) the material selection for associated piping and equipment.
During recent years, in the exploration for new oil and gas sources, the tendency towards developing offshore fields in more stringent environments has increased. Operators are now developing deep water, high pressure, high temperature, and high CO2 fields. This tendency has created numerous challenges to the project initial cost (CAPEX) and subsequent operational cost (OPEX). The material selection is critical for such fields showing high CO2 content. Although the initial capital cost for using carbon steel may be much lower than that of a corrosion resistant alloy (CRA), the total cost of the carbon steel option could be much higher due to the required corrosion inhibition programs as well as the potential for equipment failures representing losses from not only the cost of repairs, but also the loss of production.

This paper addresses the material selection assessment for topside process equipment for production fluids with high CO2 content. A project specific case study is analyzed in terms of: 1) fluid/CO2 partitioning through the topsides production systems, 2) corrosion analysis involving multiphase (oil, gas, and produced water) and single phase streams, and 3) the material selection for associated piping and equipment.
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51318-11477-Corrosion evaluation of tubing steels and material selection in the CO2/H2S coexistent environment

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To evaluate the applicability of the tubing steels, the corrosion behavior and stress corrosion cracking of tubing steels (P110S, P110-13Cr and duplex stainless steel 2205) were investigated under different H2S partial pressures and temperature.
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