AMPP Store - Conference Papers

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Corrosion testing of CRA in simulated CO2 injection well environments

Product Number: 51323-18993-SG

Author: Gaute Svenningsen, Bjørn Helge Morland

Publication Date: 2023

$20.00

The number of CCS projects (planned and in operation) is increasing, and project developers need to provide firm evidence that the proposed material is suitable for these applications.
The petroleum industry has long experience with materials selection for wells, but the conditions for CO2 injection wells are somewhat different from “conventional” oil and gas wells. This is due to the high CO2 content and pressure (up to several hundred bar) which results in low pH condensed water (exact value depends on pressure and temperature, but approximately pH 3.0).

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Corrosion Testing Of Graphene-Oxide-Polymer Coatings For Geothermal Drilling Applications

Product Number: 51322-17732-SG

Author: Erlend Oddvin Straume, Gifty Oppong Boakye, Baldur Geir Gunnarsson, Arna María Ormsdóttir, Beatriz Alonso Rodriguez, Sigrun Nanna Karlsdottir

Publication Date: 2022

$20.00

The high temperature and chemical composition of the geothermal fluid results in corrosion damage of drilling equipment, well casing and other components made of steel and iron alloys used in geothermal power production. This corrosive nature of the geothermal environment decreases the service life and increases the need for maintenance of geothermal power plants and geothermal wells. The main reasons for the corrosion of components are hydrogen sulfide (H2S) and carbon dioxide (CO2) present in geothermal system.

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Corrosion under Hot Dilute Acidic Pre-Hydrolysis Biorefining Process

Product Number: 51320-15438-SG

Author: Minkang Liu, Yimin Zeng, Xue Han , Jing-Li Luo

Publication Date: 2020

$20.00

Hot dilute acidic pre-hydrolysis biorefining is a pre-treatment technology recently developed for converting raw biomass materials into sugar streams and other valuable intermediate chemicals at elevated temperatures. However, corrosion database of steels and alloys in hot dilute acidic solutions are very limited, resulting in the cost-effective selection of materials of construction difficult. Corrosion studies were thus performed to identify suitable alloys of construction and advance the understanding of how alloying elements (e.g., Cr and Mo) present in steels and alloys affect the formation and properties of surface oxides. In this paper, the corrosion performance of three alloys (UNS S31603, UNS S32101 and UNS N06625) in hot dilute sulfuric acids are introduced. The alloys exhibited active general corrosion and even pitting in the hot acidic solutions. Alloy 625 has better resistance to the hot dilute acid compared to SS 316L and duplex 2101. This may be attributed to the higher contents of Mo in the alloy. Long-term tests indicate that their corrosion rates are gradually increased with time. The introduction of 100 ppm Cl- from raw biomass feedstocks into the acid solution only has marginal effect on corrosion.

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Corrosion under Hydrothermal Liquefaction Biorefining Process

Product Number: 51320-15439-SG

Author: Minkang Liu, Yimin Zeng, Xue Han, Jing-Li Luo

Publication Date: 2020

$20.00

The corrosion modes and extents of three candidate alloys (UNS S31603, UNS S31000 and UNS N06625) was investigated under simulated hydrothermal liquefaction (HTL) conditions. The effect of alkaline catalysts (K2CO3), operating pressure and flow rate on corrosion was also examined. Results indicated that the three alloys underwent general oxidation in hot pressurized water, of which SS 316 exhibited worse corrosion resistance compared to SS 310 and Alloy 625. The addition of K2CO3 resulted in a significant increase in the corrosion rates of the alloys, likely due to the formation of soluble metal hydroxides in basic environment. Environmental loop tests showed that higher operating pressure led to a marginal increase in the corrosion rates of SS 310 and Alloy 625. Increasing flow rate from 9 to 15 had no noticeable effect on the corrosion rates of the alloys in hot pressurized water at 310 C and 10 MPa.

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Corrosion Under Insulation (CUI) Management – A Case History

Product Number: 51219-196-SG

Author: David A. Hunter

Publication Date: 2019

$20.00

Pond investigated pressure vessel tank failures which are causing recurring maintenance of $250,000 per year. This challenging project had limitations of space, operational time pressures/vessel availability requirements, cost and replacement variables. This presentation will chronical problems and discuss best practices of specifications, material selection, surface preparation, and application inspection that would have prevented the aforementioned outcome. This paper discusses the fundamentals of composite coatings, industry accepted design standards for their use, and examples of typical uses for these materials that solve problems in varied industries.

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Corrosion Under Insulation And Atmospheric Corrosion In The Refinery Industry. An Accurate Approach To Estimate Corrosion Growth Rates, A Texas Refinery Case Study

Product Number: 51322-17751-SG

Author: Bernardo Cuervo, Mark McQueen

Publication Date: 2022

$20.00

External corrosion in uninsulated pipelines is normally able to be prevented by cathodic protection (CP). Generally, external corrosion on buried pipelines cannot occur if CP current is getting onto the pipe. CP is an electrochemical means of corrosion control in which the oxidation reaction in a galvanic cell is concentrated at the anode and suppresses corrosion of the cathode (pipe) in the same cell. For instance, to make a pipeline a cathode, an anode is attached to it.

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Corrosion Under Insulation Behavior of Out-Of-Service Carbon Steel Pipes With And Without Non-Metallic Stand-Off Membranes

Product Number: 51323-19355-SG

Author: Ahmad Raza Khan Rana, George Jarjoura, Graham Brigham, Omar Chaar

Publication Date: 2023

$20.00

CUI (Corrosion under insulation) is among the key damage mechanisms affecting the integrity of equipment, piping, and pipelines in the hydrocarbon industry. CUI manifests (mostly) localized corrosion. CUI is a highly frequent degradation in the oil refining facilities where reportedly 40-60% of failures in the piping result from CUI.

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Corrosion Under Insulation Behavior Of Phenolic Epoxy Coatings Under Contacting And Contact-Free Insulations

Product Number: 51322-17535-SG

Author: Ahmad Raza Khan Rana, Graham Brigham, Omar Chaar, George Jarjoura

Publication Date: 2022

$20.00

CUI (Corrosion under insulation) refers to localized corrosion under thermal insulations, which pose integrity risks to the hydrocarbon facilities. 1 CUI is reportedly a driver behind 40-60% of failures in the facility piping. Smaller-sized piping (i.e., diameter < 4”) are even more prone to CUI, whereas reportedly 81% of failures in small-sized piping are due to CUI. 2 CUI-related failures and associated efforts comprise 10% of a facility’s maintenance budget. Management of CUI risks has always been challenging as it involves maneuvering numerous governing factors. The key driving factor behind CUI is the aerated moisture that comes from soaked thermal insulations.

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Corrosion Under Insulation on Industrial Piping – A Holistic Approach to Insulation System Design

Product Number: 51319-13042-SG

Author: Mark Swift

Publication Date: 2019

$20.00

Corrosion Under Insulation (CUI) on industrial piping is a major issue for oil and gas industry. The potential influence of applied thermal and acoustic insulation materials is normally assessed through a series of individual laboratory tests on the insulation materials themselves but very rarely on the applied system. Moreover the tested physical values do not necessarily and readily reflect the potential influence that a given insulation material or system has on the risk of CUI.A more sophisticated approach is proposed which takes into account not only the applied insulation system but also the CUI failure behaviour and water or water vapour ingress and retention processes. This approach allows the individual risk assessment of the applied insulation systems against different scenarios of water ingress to be performed. Other influencing factors for the risk assessment include the configuration of the insulation system (e.g. insulation materials aluminium barrier foil outside claddings) and specified construction or installation methods.It is hoped that the approach proposed in this paper will enable the reader to improve their knowledge of insulation materials and their influence on CUI risk and furthermore be able to better identify vulnerable areas on the facility where CUI is likely to occur thereby allowing appropriate CUI management strategies to be developed and implemented.

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Corrosion Under Insulation Performance Of Insulation Stand-Offs And Non-Metallic Membranes

Product Number: 51322-17618-SG

Author: Ahmad Raza Khan Rana, Graham Brigham, Omar Chaar,George Jarjoura

Publication Date: 2022

$20.00

Corrosion under thermal insulations namely CUI (Corrosion under insulation) is among the key damage mechanisms which poses integrity risk to the hydrocarbon facilities. CUI is reportedly known as the reason behind 40-60% of failures in the facility piping whereas small bore piping (i.e., NPS < 4”) are even more sensitive to CUI failures, where up to 81% of reported failures in small-sized piping are known to be from CUI. Monetary spending to inspect and fix CUI-related failures cost 10% of overall maintenance budget in a typical medium-sized oil refinery. CUI risk is influenced by numerous operational and environmental factors which impedes its management in a typical AIM (Asset integrity management) program.

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Corrosion under Insulation: Case Studies and Challenges in the Use of Corrosion Inhibitors

Product Number: 51324-20778-SG

Author: Takehiro Toyoda; Yoshiyasu Kushima; Koji Watanabe; Toshiyuki Sunaba

Publication Date: 2024

$40.00

Corrosion Under Insulation (CUI) is a significant concern in the oil and gas industry. This paper presents several case studies of CUI, including instances of External Chloride Stress Corrosion Cracking (ECSCC). In our facilities, applying insulation material sprayed with a specific corrosion inhibitor to the internal surface is considered a temporary solution for equipment where CUI is a concern due to damaged coatings. In our previous study, this non-combustible corrosion inhibitor containing phosphate and nitrite showed effective corrosion inhibition in carbon steel even when rusted. However, we considered that an Active Path Corrosion can be occurred under loaded stress portions. To replicate chloride-concentrated environments under insulation, a 70-day immersion test was conducted using U-bend type test specimens of carbon steel in a NaCl solution with the inhibitor. The tested specimens with the inhibitor maintained a metallic appearance without stress corrosion cracking. However, crevice corrosion was observed. These results suggest that the corrosion inhibitor may have limited effectiveness in chloride-concentrated environments. We concluded that it is beneficial to perform cleaning before applying the insulation with corrosion inhibitor and to implement other permanent measures before chloride concentration significantly increases.

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Corrosion Under Pipe Supports - Beyond Simply Inspection

Product Number: 51322-18155-SG

Author: Connor Tiegs

Publication Date: 2022

$20.00

Petrochemical facilities and refineries consist of many miles of above ground piping that transports product between processing and storage units. These pipes are either supported at ground level or in multi-story pipe racks on varying types and sizes of supporting structures. A common problem these structures create is corrosion and erosion at the junction between the pipe and the support, which reduces the remaining wall thickness of the pipe and compromises the integrity of the entire system.

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Individual Conference Papers

Corrosion testing of CRA in simulated CO2 injection well environments

Corrosion Testing Of Graphene-Oxide-Polymer Coatings For Geothermal Drilling Applications

Corrosion under Hot Dilute Acidic Pre-Hydrolysis Biorefining Process

Corrosion under Hydrothermal Liquefaction Biorefining Process

Corrosion Under Insulation (CUI) Management – A Case History

Corrosion Under Insulation And Atmospheric Corrosion In The Refinery Industry. An Accurate Approach To Estimate Corrosion Growth Rates, A Texas Refinery Case Study

Corrosion Under Insulation Behavior of Out-Of-Service Carbon Steel Pipes With And Without Non-Metallic Stand-Off Membranes

Corrosion Under Insulation Behavior Of Phenolic Epoxy Coatings Under Contacting And Contact-Free Insulations

Corrosion Under Insulation on Industrial Piping – A Holistic Approach to Insulation System Design

Corrosion Under Insulation Performance Of Insulation Stand-Offs And Non-Metallic Membranes

Corrosion under Insulation: Case Studies and Challenges in the Use of Corrosion Inhibitors

Corrosion Under Pipe Supports - Beyond Simply Inspection

Association for Materials Protection and Performance