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Environmental Modification And Atmospheric Corrosion: Clear Water Rinsing, Covering, And Seawater Spray

Product Number: 51322-17990-SG

Author: Christine Sanders, Raymond Santucci, Jr

Publication Date: 2022

$20.00

Aerospace assets are subjected to routine maintenance cycles to prevent, monitor, and repair corrosion damage. Currently, the maintenance cycles are determined according to its model and following its respective requirements document (eg: NA(1) 01-1A-509¹ or USAF(2) Technical Order 1-1-691).² A new paradigm of condition-based maintenance (CBM) is highly desired, as a given asset will require different prevention, monitoring, and repair maintenance cycles depending on where it is deployed. As corrosion is the degradation of a material in response to its environment, CBM takes into consideration the variability of the environment (the conditions to which an asset is exposed) when determining appropriate maintenance intervals and what should be done at each interval.

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Environmentally Assisted Cracking Of Nickel Based Alloy 955 In Saltwater With Cathodic Protection For HPHT Application

Product Number: 51322-17768-SG

Author: Arshad B Gavanluei, Vipul Shinde, Manuel Marya, Ramgopal Thodla, Alexis Simon, Stanley Gregory

Publication Date: 2022

$20.00

Precipitation hardened (PH) Ni-based alloys have been utilized in oil and gas industry for decades. Among them, UNS1 N07718 because of its performance in sour wellbore fluids and in hydrogen charging environments has received the most attention for multiple upstream applications such as tubing hangers, production stab, multi-phase flow meter bodies, valve stems, etc. It has been reported that the alloy performance is generally acceptable for many applications up to 175 °C (350 °F) – 204 °C (400 °F) in the exposed wellbore environments such as sour production fluid, completion brine, and depending on metallurgical processing and microstructure externally exposed to SWCP at the seabed temperature.

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Environmentally Assisted Cracking Susceptibility Of Nickel Based Alloy 955 In A Sour Wellbore Fluid For HPHT Application

Product Number: 51322-17766-SG

Author: Arshad B. Gavanluei, Ramgopal Thodla, Manuel Marya, Alexis Simon, Vipul Shinde, Stanley Gregory

Publication Date: 2022

$20.00

Precipitation-hardened nickel-based alloys have been used for decades in the oil and gas industry. Among these alloys, UNS1 N07718 has received the most attention for use in upstream applications such as tubing hangers, production stab plate, multiphase flowmeter bodies, and valve stems because of its performance in sour wellbore fluids (SWFs) and hydrogen-charging environments.

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Environmentally-Assisted Cracking (SSC And SCC) Of Martensitic Stainless Steel OCTG Material In Sour Environment In 5%Nacl And 20%Nacl Solution

Product Number: 51322-17563-SG

Author: Yuichi Kamo, Yusuke Mizuno, Yasuhide Ishiguro

Publication Date: 2022

$20.00

Martensitic stainless steels for OCTG materials are widely used in sweet and mild sour conditions. Environmentally-assisted cracking (EAC) is a major corrosion-related issue when using stainless steels as OCTG materials. The EAC in specific oil/gas well conditions with sour environments is defined as sulfide stress cracking (SSC) and stress corrosion cracking (SCC). The SSC is a type of cracking caused by hydrogen embrittlement, which is attributed to a cathodic reaction under acidic conditions, while SCC is associated with an anodic reaction. SSC testing for martensitic stainless steels for OCTG material is often carried out at or near ambient temperature under conditions simulating condensed water, and SCC tests are conducted at higher temperatures under conditions simulating formation water and/or the brine availability test.

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EPRI’S Approach To Longer Term Operations

Product Number: ED22-17191-SG

Author: Emma L. Wong, Andrew Mantey, Samuel Johnson, Jean Smith

Publication Date: 2022

$20.00

EPRI has been supporting the nuclear industry over the last several decades to provide the technical bases and research to support the operation of the current fleet of nuclear power plants beyond their initial licensing period (typically 30-40 years of operation). Hundreds of technical reports and guidance documents have been issued on topics ranging from developing and implementing aging management programs, identification, and evaluation of degradation mechanisms, and remaining useful life of key passive components (e.g., reactor vessel internals, cables, and concrete). A previous 2019 ANS Environmental Degradation Conference paper discussed the research goals and results of EPRI up to 2019 for concrete and cables. These research results provide a living technical basis as these results are supplemented regularly with industry operating experience, inspection results, and condition monitoring or non-destructive evaluations.

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Equivalent Circuit Model Fitting in Electrochemical Impedance Spectroscopy (EIS) for Protective Coating Evaluations

Product Number: 51321-16267-SG

Author: Bing Yuan; Martin Stephen; Muni Ramakrishnan

Publication Date: 2021

$20.00

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Erosion and Corrosion Assessment of Type 304L Stainless Steel Jumper Removed from Nuclear Waste Transfer Service

Product Number: 51324-20634-SG

Author: Sheewa X. Feng; Jason S. Page

Publication Date: 2024

$40.00

A pipe connection assembly (jumper), fabricated from Type 304L stainless steel, was used to transfer nuclear waste from one tank to other tanks on the Hanford Site. After serving as the routing connection for approximately 11 million liters of tank waste over approximately 11 months, the jumper was removed from service and examined to determine any erosion, pitting, cracking, or other forms of degradation to the jumper. Ultrasonic transducer measurements for wall thickness before and after service at the same selected locations show that there was no measurable wall loss, and no erosion patterns were observed. After the ultrasonic transducer measurement, the jumper section was cut open to expose the inner surface for detailed examination by optical microscopy and scanning electron microscopy. The straight pipe sections at both upstream and downstream locations looked pristine, while discoloring was observed at the two welds, in the heat-affected zone, and in nearby regions joining the elbow and straight pipes. There was no erosion, pitting corrosion, or flow-induced corrosion, nor were there other corrosion mechanisms in evidence except for a crack-like feature observed at the boundary of the base metal and weld. Material etching didn't show alignment of the crack with grain boundaries. Degree of sensitization measurement shows that the weld and heat-affected zone, including the neighboring base, was only slightly sensitized during the manufacturing process. The results suggest that there is very low likelihood that the crack-like feature observed from the weld cross section was the result of stress corrosion cracking. Overall, the jumper performed well during the waste transfer process.

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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.

Online Conference Paper

Association for Materials Protection and Performance