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A Novel Internal Corrosion Risk Management Methodology for Relief Lines

Product Number: 51323-19468-SG

Author: Ayman A. Alabdullatif, Faisal M. Al-Abbas, Rakan A. Al-Shebil, Lay Seong Teh

Publication Date: 2023

$20.00

RLs are susceptible to internal corrosion that is influenced mainly by fluid corrosiveness including factors such as temperature, pH, carbon dioxide (CO2) and hydrogen sulfide (H2S) content, water chemistry, flow stagnation, wettability, and presence of deposits.

Generally, for corrosion to occur there must be liquid water with sufficient quantity to wet the pipe surface. Once water wet, the line will corrode at a rate determined by the chemistry of the water, acidity and quantity of deposits.

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A Novel Method for the Enhanced Kill of Sulfate Reducing Microorganisms

Product Number: 51320-14412-SG

Author: Gary E. Jenneman

Publication Date: 2020

$20.00

Hydrogen sulfide gas produced by sulfate reducing microorganisms (SRM) creates significant challenges in the petroleum industry including corrosion concerns, product devaluation, and significant health risks. Biocides and inhibitors are often employed to control these detrimental activities. Recently, co-injection of a synergistic blend of biocides and the SRM inhibitor, nitrite, was proposed as an effective means to control biogenic sulfide production, however, the method only addressed inhibition of SRM activity and not kill. Inhibition can have the undesirable consequence of allowing SRM to resume full activity once the inhibitor is depleted, thus requiring the continuous input of expensive chemicals to maintain control. On the other hand, biocides are designed to reduce SRM concentrations thus reducing the need to add additional chemical until the SRM population re-establishes. Lab results, using an SRM field enrichment, demonstrated that the sequential injection of nitrite inhibitor followed by glutaraldehyde led to an 8-log reduction in SRM while only a 2-log reduction when co-injecting these chemicals at equivalent concentrations. It is proposed that pretreatment with the inhibitor, nitrite, or other respiratory inhibitor, results in a reduction in cellular ATP of the SRM creating a sublethal stress response allowing for their enhanced kill upon subsequent biocide addition.

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A Novel Methodology For Addressing Corrosion Under Insulation (CUI) Utilizing Corrosion Inhibitor Impregnated Self-Amalgamating Silicone Based Tape

Product Number: 51322-17931-SG

Author: Phillip Low

Publication Date: 2022

$20.00

Integrity management of corrosion under insulation (CUI) has historically and continues to be one of the biggest corrosion related challenges within the oil & gas, maritime, chemical and petrochemical industries.² Corrosion of piping, associated flanges, pressure vessels and structural components from CUI is a commonly found phenomenon and if left undetected or not stringently managed can result in catastrophic leaks or explosions, equipment failure and periods of prolonged downtime due to repair or replacement. It is estimated around 40% to 60% of an operator’s pipeline maintenance budget is a result of CUI.³

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A Novel Quick Turn-Around Repair Coating For Offshore Windmills

Product Number: 51323-19481-SG

Author: Hindrik Harm Broesder, Dinko Cudic

Publication Date: 2023

$20.00

Offshore wind towers are commonly foreseen with factory-applied anti-corrosion coatings that consist of
multi-layer 2-component protective paint systems like epoxies or polyurethanes. These coating systems have various requirements in place for application and curing conditions like a high degree of surface cleanliness of steel, roughness profile for achieving proper adhesion, low levels of salt contamination on the surface, and appropriate control of temperature and humidity during curing. During transport and installation of the coated towers, the factory-applied coating often gets damaged.

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A Paradigm Shift Of Corrosion Management Using IOW Program

Product Number: 51322-17712-SG

Author: Ahmed Al-Yahyaai, Abdullah Al-Maqbali, Naif Al-Abri, Yahya Al-Bulushi

Publication Date: 2022

$20.00

The purpose of this paper is to emphasize the current advancements of monitoring the integrity level of the processing facilities using means of Integrity Operating Window (IOW) program. In our company, integrity and material & corrosion departments across the upstream and downstream businesses successfully implemented a well oriented and constructive IOW programs to manage the corrosion risks and monitor the integrity level of the capital assets and proactively assess the situation to prevent loss of primary containment. The technology that sets behind this success is the digitalized approach that gathers information from process, operations, lab services and inspection programs and converts them all into a high-level real-time tracking system that asses the current status of corrosion threats and integrity level.

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A Parametric Evaluation of Well Construction Corrosion-Resistant Alloys for Geological Carbon Sequestration

Product Number: 51324-20582-SG

Author: Manuel Marya

Publication Date: 2024

$40.00

A parametric test program involving completion alloys in supercritical CO2 was conducted using both isothermal and non-isothermal cycles in the presence of contaminants (i.e., H2O, NO2, SO2, H2S, H2) above typical impurity limits for carbon capture and sequestration (CCS). The isothermal testing consisted of 4500 psi (310 bar) autoclave tests at 175°F (79°C) with the test materials in supercritical CO2, and optionally, in a NaCl-rich brine in equilibrium; the non-isothermal testing was similar, but included three consecutive cycles with 250°F (121°C) and 70°F (21°C) exposures. Up to ten corrosion-resistant alloys [i.e., 9Cr (UNS K90941), 13Cr (UNS S42000), S13Cr (ISO13680 (1) Type 13-5-2), 15Cr (proprietary), 17Cr (proprietary, 22Cr (UNS S32205), 25Cr (UNS S32750), G3 (UNS N06985), 925 (UNS N09925), 718 (UNS N07718), and 716 (UNS N07716)] were tested for weight loss, pitting, and crevice corrosion. The alloys, known to be more susceptible to environmentally-assisted cracking (EAC), were also evaluated for cracking with ppm-levels impurities (25-to-150 ppmv each), including hydrogen sulfide (H2S). Alloys 22Cr, 25Cr, and API (2) Spec. 6A and Std. 5CRA nickel-based alloys are generally found to be fit-for-service for subsurface CCS. In contrast, the alloys with 9-to-17 wt.% chromium tend to suffer from pitting, which when extensive, has been associated with a case of EAC. For the pitting-resistant alloys under test, neither EAC nor crevice corrosion created major new risks. The introduction of non-isothermal cycles to qualify alloys for CCS has successfully emphasized the dominant effects of condensates, otherwise under-represented, and is suggested for future material testing and qualification programs.

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A Prediction and Inspection Technology for Detecting the Corrosion Under Insulation

Product Number: MPWT19-15162

Author: Ayman Amer, Ali Al Shehri, Vincent Cunningham, Ihsan Taie

Publication Date: 2019

$0.00

Corrosion under insulation (CUI) is a critical challenge that affects the integrity of assets for which the oil and gas industry is not immune. Over the last few decades, both downstream and upstream industry segments have recognized the magnitude of CUI and challenges faced by the industry in its ability to handle CUI risk-based assessment, predictive detection and inspection of CUI. It is a concern that is hidden, invisible to inspectors and prompted mainly by moisture ingress between the insulation and the metallic pipe surface. The industry faces significant issues in the inspection of insulated assets, not only of pipes, but also tanks and vessels in terms of detection accuracy and precision. Currently, there is no reliable NDT detection tool that can predict the CUI spots in a safe and fast manner. In this study, a cyber physical-based approach is being presented to identify susceptible locations of CUI through a collection of infrared data overtime. The experimental results and data analysis demonstrates the feasibility of utilizing machine-learning techniques coupled with thermography to predict areas of concern. This is through a simplified clustering and classification model utilizing the Convolutional Neural Networks (CNN). This is a unique and innovative inspection technique in tackling complex challenges within the oil and gas industry, utilizing trending technologies such as big data analytics and artificial intelligence.

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A Prediction of Corrosion-related Leakage on Distribution Pipelines via Machine Learning Method

Product Number: 51323-18972-SG

Author: Zhuoran Zhang, Guanlan Liu

Publication Date: 2023

$20.00

In the United States, there are fuel pipelines spanning more than 2.6 million miles. A major portion of the pipelines is gas distribution lines, where the product is delivered from the pressure regulating station to the customer’s home or facility. The Pipeline and Hazardous Materials and Safety Administration (PHMSA) finalized rules for Distribution Integrity Management Program (DIMP) plans in 2009, enforcing the distribution pipeline operators to assess, report, and manage the risk associated with the pipeline operation. Corrosion threat is one major threat to the pipeline operation and integrity based on CFR 192, CFR 195 and ASME B31.82. A comprehensive understanding and assessment of corrosion risk are indispensable for a safer pipeline operation. This demands a more precise understanding, prediction, and management of the pipeline corrosion

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A real-time matrix based corrosion monitoring system

Product Number: 51322-18130-SG

Author: Hanne Martinussen, Fredrik Sandquist

Publication Date: 2022

$20.00

Pipeline integrity management and practices have been systemized through standards(1), and one important aspect in integrity management is corrosion monitoring. Corrosion monitoring by using permanently installed equipment has increased in the past years⁽²⁾. By using permanently installed ultrasound transducer (UT) sensors and automating signal processing and communication, a more costefficient corrosion management program can be obtained. Ultrasound techniques have been developed to complement traditional inspection with monitoring to improve cost efficiency of pipeline integrity management.

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A Recent Case Of Intermetallic Precipitations In Super Duplex

Product Number: 51322-17627-SG

Author: Henrik Bang, Jakob Mølholm, Kirsten Grønning Sørensen

Publication Date: 2022

$20.00

Production of oil and gas is well known to cause potential corrosion issues due to the CO2 content in the well stream. Carbon steel is widely used for production facilities as e.g. flowlines and manifolds, however, aging of the reservoir increases the number of corrosive agents, such as e.g. CO2, which are known to cause high corrosion rates in carbon steel. Therefore, carbon steel piping is often being replaced with super duplex stainless steel due to its high strength, excellent toughness and good corrosion resistance. Replacing carbon steel with super duplex has been conducted on several mature offshore oilfields in the European North Sea region.

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A Recent Failure Case Studies on Duplex Stainless Steels in Refinery

Product Number: 51324-20707-SG

Author: D.S Lee; Y. Ro; S.Y Pae

Publication Date: 2024

$40.00

Duplex stainless steel (DSS) is widely used in the refinery because of its economical combination of strength, corrosion resistance and cost. Various forms of damage may occur to the DSS depending on the concentration of chloride, H2S, water, and temperature. This report presents the analysis results of failure cases occurring in various environments of the SK energy refinery. Operation condition and corrosion environment of each exchanger are described. Analysis results of the cause of damage, inspection method and the results are also explained. This report introduces some failure analysis cases occurred in various environments of the refinery, for example, chloride induced SCC (Cl-SCC) in CDU and SRP process, SSC (Sulfide Stress Crack) in the weldment of air cooler header box, and pitting corrosion in high temperature chloride environments. This study will clearly show the importance of a tube production quality of DSS and the limitation of DSS tube in terms of the surrounding environments such as temperature, Cl and/or H2S contents, and salt formation. Furthermore, the potential problem of a repair welding during manufacturing DSS header box will be presented. We think that the present case studies will help DSS end-users and manufactures improving the understanding of a safe application for DSS.

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A Remote Monitoring System Featuring GPS Synchronized Instant-Off Potential And Line-Current Measurements

Product Number: 51322-17635-SG

Author: Andreas Junker Olesen, Lars Vendelbo Nielsen

Publication Date: 2022

$20.00

There are several ways to validate the performance of a cathodic protection (CP) system for buried pipelines. Over the years, pipeline networks and their corrosion challenges have become increasingly complicated, not least due to the many sources of both AC and DC interference that affects CP operation. Also, the various measurement techniques that can be applied to test CP effectiveness has increased over the years. Finally, the sheer number of buried pipeline miles has been constantly increasing.

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Association for Materials Protection and Performance