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Erosion Behavioral Study for High Nickel Alloys

Product Number: 51324-20638-SG

Author: Mansour Alhammad; Nayef Alanazi; Abdullatif Alabdulhadi; Salako Olaoluwa; Anaam Shaikh Ali

Publication Date: 2024

$40.00

Oil and gas industry have employed Corrosion Resistant Alloys (CRA) in highly corrosive environments for a sustained production capacity and longer service life. These materials are regarded to have high resistance to corrosion, however, a prominent issue that can occur in O&G production is the potential of erosion along material surface. In this study, ASTM G76 standard was used as basis to generate high nickel alloy erosion database. The materials used in this study include N06255, N08535 and N07718 with respective nickel content of 48.5, 31.4 and 48 %wt. An Air-Jet Erosion Tester was utilized with Alumina Oxide as erodent for this study, in which the feedrate varied between 1 – 6 g/min with a 1g/min step, impingement velocity ranging between 30 - 110 m/s and a varying impingement angle (15° - 90°) with 15° step bringing the total number of runs in excess of 100. The erosional behavior of materials N06255, N08535 and N07718 were studied and the resulting steady state erosion rate (SSER) for each was determined. The tested materials were ranked based on SSER from lowest to highest metal loss per time as follows N06255, N8535 and N07718 which could be attributed to difference in molybdenum and nickel content.

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Erosion Corrosion Phenomena In Oil And Gas Facilities: Evaluation And Monitoring

Product Number: 51322-17665-SG

Author: Raquel Araujo, Mioara Stroe, Kuate-Teku Rheingold, Igor Pipas, Francisco Mateus-Garcia, Laurent Dehays

Publication Date: 2022

$20.00

High flow velocity can have negative impact on the integrity of the oil and gas production equipment. This negative impact can manifest by the reduction of Corrosion Inhibitor (CI) efficiency: the higher the flow velocity, the lower the CI efficiency. The negative impact can also manifest by the occurrence of liquid erosion corrosion phenomena.

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Erosion/Corrosion of Duplex Stainless Steel in Sweet Production with Sand Versus CaCO3

Product Number: 51323-19394-SG

Author: Anass S. Nassef, Michael W. Keller, Siamack A. Shirazi

Publication Date: 2023

$20.00

In the Oil and Gas industry, carbon steel tubing, piping and process equipment may be susceptible to erosion-corrosion damage due to the erosive and corrosive nature of the flow. To minimize the harsh effects and costly losses of erosion-corrosion, corrosion resistance alloys (CRAs) and corrosion inhibitors are commonly used. CRAs such as stainless steels, nickel and titanium alloys have excellent CO2 corrosion resistance.

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ESG and PHMSA’s Mega Rule Have Necessitated Advancements in Hydrotesting and Abandonment of Offshore and Onshore Pipelines

Product Number: 51323-18982-SG

Author: A.R. Trueman

Publication Date: 2023

$20.00

The work here is the culmination of many years of prior effort in the development of an atmospheric corrosion model and accompanying sensors. Atmospheric corrosion is a complicated process where many factors interact to determine if it occurs and its severity. These factors can be separated into three general categories: environmental, surface salts, and materials.

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Establishing Internal Corrosion Prediction Model and Inline Inspection (ILI) Correlation

Product Number: 51324-20703-SG

Author: Sankara Papavinasam

Publication Date: 2024

$40.00

There are several technical advantages and economic benefits of integrating inline inspection (ILI) findings and internal corrosion prediction models. ILI provides “what has happened” and model provides “why it has happened” and “how it will evolve in the future.” This approach has been demonstrated in oil transmission pipelines, condensate pipelines, dry gas pipelines, wet gas pipelines and multiphase pipelines. This paper (1) explains the benefits of integrating internal corrosion model and ILI; (2) reviews the historical development of internal corrosion models; (3) elaborates the status of correlation between inline inspection (ILI) data and internal corrosion model prediction; and (4) explains future challenges and opportunities.

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Estimating Corrosion Rate Risk Distributions using Machine Learning and Geospatial Analytics

Product Number: 51320-14640-SG

Author: Joseph Mazzella, Thomas Hayden, Haralampos Tsaprailis, Len Krissa

Publication Date: 2020

$20.00

Estimating corrosion growth rates for underground pipelines is a challenging problem. There are confounding variables with complex interaction effects that may result in unexpected outcomes. For instance, the relationship between soil conditions and AC interference is highly non-linear and challenging to model. This work expands upon prior work using a suite of machine learning tools to estimate corrosion rates. However, instead of estimating a single corrosion growth rate for a single girth weld address (GWA), this work estimates a distribution of potential corrosion growth rates. Modeling distributions provide a more effective risk-measurement framework, especially concerning high volatility or areas of severe tail risk.

This work relies heavily on machine learning and geospatial tools - particularly artificial neural networks and gradient boosted trees to estimate the corrosion rates and non-linear processes. Building upon prior work using data from a North American Operator, the models in this paper use additional variables from recent research in AC interference and microbiologically influenced corrosion to construct a higher accuracy and distribution-based model of pipeline corrosion risk.

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Estimating the Financial Risk Reductions Associated with Cathodic Protection Programs

Product Number: 51320-14546-SG

Author: Parth Iyer, Yoko Nakazato, Han Wu, Millan Sen, Len Krissa

Publication Date: 2020

$20.00

On an increasingly frequent basis, pipeline operators are using risk-based decision making to prioritize cross-company expenditures. Due to the long-term mitigation benefits of Cathodic Protection (CP), when planning external corrosion mitigation activities, pipeline operators typically prioritize mitigation of deeper anomalies for integrity expenditures due to their higher Probability of Failure (PoF). However, anomalies that are not receiving adequate CP or those experiencing electrical interference may remain unaddressed using this rationale. This paper presents both a qualitative and semi-quantitative approach to support the quantification of the risk reduction benefits gained from external corrosion prevention on pipelines. This can help in the efficient prioritization of both pro-active and re-active integrity repair activities. Supporting examples are also discussed to help explain the intended use of the methodology and the interpretation of the results.

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Evaluating AC Corrosion in Shared Corridors with Multiple Circuits

Product Number: 51324-20764-SG

Author: David Lewis; Majid Siahrang

Publication Date: 2024

$40.00

Growth in electrical generation sources and greater electrical power demands in North America, drive need for new electric transmission lines with multiple circuits. Many understand a transmission line loading can vary seasonally and increase over time. Typical approaches to address the variation in analyzing AC corrosion is simply using the maximum transmission line loading. In corridors with multiple circuits, the maximum transmission line loading may significantly underestimate the maximum induced voltage on inductively coupled pipelines. Multiple circuits significantly add to the complexity of AC corrosion as variable loading and even power flow direction affect the vectoral summation of magnetic fields. This paper highlights the challenges that engineers will overcome in addressing shared corridors with multiple circuits. This includes the need to understand the phase configuration, power system rotation, power flow, and the importance that engineering tools consider varying induction on shield wires.

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Evaluating Irradiation Damage In CANDU Components By Characterizing Surrogate Material Harvested From The Decommissioned NRU Reactor At Chalk River Laboratories- Application To The CANDU Calandria Tubesheet Degradation

Product Number: ED22-17290-SG

Author: Mitchell Mattuchi, Qiang Wang, Brian Langelier, Nicolas Huin, Brian Connolly, Grace Burke

Publication Date: 2022

$20.00

The CANDU® reactor is a pressurized heavy water moderated (D2O) reactor, fueled with natural uranium. Nuclear fission of natural uranium occurs in the fuel channels and the heat generated from the fission is transported from the fuel channel to the steam generator, via the primary heat transport system. The nuclear reaction is moderated by heavy water that surrounds the fuel channels contained within the Calandria Vessel.

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Evaluating the Effect of Chloride Content on the Performance of Corrosion Inhibitors during Hydrostatic Testing

Product Number: 51321-16464-SG

Author: John Wulterkens; Casey Heurung

Publication Date: 2021

$20.00

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Evaluating the Effect of Surface Finishing on Microbial Induced Corrosion of Pipeline Steels

Product Number: MECC23-20073-SG

Author: Eman Adel Almutawa; Ihsan UlHaq Toor; Wasif Farooq

Publication Date: 2023

$20.00

Microbial influenced corrosion is a type of corrosion caused by microorganisms attached to the metal surface or by their activity. The first one who noted the MIC was Gaines in 1910 [1], followed by research about the graphitization of cast irons in anaerobic soils in 1934 [2]. Nowadays, attention to MIC problems increased significantly.

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Evaluating The Effects of Powder Processing Conditions with Accelerated Corrosion Testing

Product Number: 51323-19190-SG

Author: Connie Przeslawski

Publication Date: 2023

$20.00

Fluoroethylene vinyl ether (FEVE) resins were developed to overcome some of the challenges of traditional fluoropolymer resins exhibited in paint coatings. FEVE resins are synthesized from two monomers, fluoroethylene, and vinyl ether. When these monomers undergo radical polymerization, they produce amorphous A-B-type polymers shown below (Figure 1).

Online Conference Paper

Association for Materials Protection and Performance