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Integrity Maintaining and Cost Saving Advanced CUI Detection Technique (PEC)

Product Number: MPWT19-14242

Author: Amro Hassanein, Ahmed Elsharkawi

Publication Date: 2019

$0.00

Corrosion under insulation (CUI) is a major problem for petroleum and petrochemical process industries that affects the plant mechanical integrity and attacks assets. CUI can result in sudden and hazardous leaks (safety concern), and plant shutdowns with high losses of production (economical concern).
Traditional detecting methods of CUI to cut a window in thermal insulation used to inspect visually, to measure the thickness, and then return thermal insulation back, giving high chance for water and moisture ingress, accelerating CUI, moreover big amount of scaffolding erection along with thermal insulation removal required.
SHARQ (Eastern Petrochemical Company, one of SABIC companies) is pioneer to study CUI, evaluating many Non–Destructive techniques has proven Pulsed Eddy Current (PEC) as the most effective technique in terms of integrity and cost optimization.
Considering all available techniques, all aspects studied, such as range of applications, features, and limitations, it is concluded and verified to meet our inspection plan strategy needs.
PEC does not require thermal insulation removal; optimize scaffolding erection, has a wide range of applications related to thickness, and temperature. PEC approved by international codes and standards (API) to meet RBI Meridium software requirements.
The validation study results show cost savings of more than 50% compared to traditional thickness measurement methodology, moreover it reduces EHSS (Environment, Health, Safety, and Security) negative impact reduces the probability of safety incidents due to reducing labor, man-hours, and eliminating many associated activities with potential hazard and risk.
PEC has high productivity, easily operated, and provides comprehensive and professional inspection report

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Integrity Operating Window Development for Refinery Units and Implementation Through a Digital Platform

Product Number: MPWT19-15288

Author: Giulia TREVISAN RINA, Flavia CAMPANELLI RINA, Claudio CAMPANELLI RINA, Fabio MONDELLO RINA

Publication Date: 2019

$0.00

Integrity operating windows can be developed to account for any changes occurring during plant
operation that affect expected damage rate or susceptibility to damage.
A five-step methodology based on API RP 584 advice was developed for consistent identification of
integrity operating windows and subsequently applied to several plant units in different refineries.
A digital dashboard was also developed for collecting and trending all the parameters affecting each
IOW and possibly for performing advanced data analysis (which may lead to the development of
predictive models). This represents a further step towards reliable implementation of integrity
operating windows and their positioning within an asset integrity management framework.

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Intellisyn™ - A New Class Of Multifunctional Smart Particles For Advanced Corrosion Protection

Product Number: 51322-17959-SG

Author: Benjamin Pearman, Xuejun Zhang, Dillon Campbell, Victoria Scarborough, Stephen Dickey

Publication Date: 2022

$20.00

Left unprotected, metals corrode quickly which over time contributes to the loss of structural integrity and the failure of buildings, bridges, oil & gas platforms, airplanes, cars and many other metal assets, all of which pose a risk to human safety and the surrounding environment. In 2016, the National Association for Corrosion Engineers (NACE) – now known as AMPP – published a landmark study, well-known to those attending this conference, that estimated the direct cost of corrosion to the world economy as $2.5T per year, equivalent to 3.4% of the Gross World Product (1). In the United States, the annual cost of corrosion is estimated at 3.1% of gross domestic product (2), equivalent to $635B (2018). When including indirect costs, such as asset downtime, ship dry-docking and the impact of bridge collapses, the cost of corrosion is estimated at twice that amount.

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Interference Study between a Solar Array Power Station and a Transmission Pipeline

Product Number: 51324-21051-SG

Author: Andres Peratta; Cristina Peratta; John Baynham; Nora Villamizar Piñeros; Didier Lozano Abril

Publication Date: 2024

$40.00

It is nowadays becoming increasingly common for new onshore structures and electrification systems to be installed in close vicinity to existing underground pipelines already equipped with their own CP and earthing systems. The problem with sharing common right of way between different structures is that their different earthing and CP systems are likely to interfere with each other. The coupling may reduce the performance of the individual designs or lead to major problems such as stray currents or shielding effects. Numerical modelling of these types of scenarios allows identifying such problems in advance, gaining understanding on the nature of the interference, and evaluating possible mitigation strategies. In this work the impact of constructing a solar power station across a set of transmission pipelines is investigated. The pipelines are protected by an ICCP system. The solar array includes galvanized piles and copper earthing system. The territory is mainly composed of clays or muds with flat and slightly undulating shapes with average resistivities in the order of 900 O-cm. Simulation results are presented showing the status of the pipelines before and after the solar array is constructed, as well as the solar array considering that the pipeline does not exist. The results show that the solar array piles and earthing system have measurable effects on the CP potentials on the pipeline.

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Intergranular Oxidation and Oxygen Transport in Ni-20Cr During Exposure to Model Dry and Wet Oxidation Environments

Product Number: ED22-17329-SG

Author: Martin Weiser, Daniel K. Schreiber, Karen Kruska, Mark H. Engelhard, Matthew J. Olszta

Publication Date: 2022

$20.00

The austenitic Ni-base Alloy 600 has been extensively used as structural material in primary water reactors (PWR). Despite good resistance against general corrosion in water-cooled nuclear power reactors, the material has been susceptible to stress corrosion cracking (SCC). These observations have led to ongoing discussions of the underlying embrittlement mechanism(s). Internal oxidation of the grain boundary (GB) at typical operating temperatures is one such mechanism, although debate continues on the exact mechanisms at play.

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Intergranular Oxidation Of Unstressed Alloy 600 SA And Alloy 600TT In PWR Primary Water

Product Number: ED22-17279-SG

Author: Daniel K. Schreiber, Karen Kruska, Matthew J. Olszta, Peter H. Chou

Publication Date: 2022

$20.00

Alloy 600 (Ni-16Cr-9Fe) is well known to exhibit intergranular corrosion and intergranular stress corrosion cracking (IGSCC) upon exposure to high temperature water environments, including those found in service environments of pressurized water reactors (PWR). While the higher Cr content alloy 690 exhibits superior IGSCC resistance in these environments, alloy 600 is still in use at many light water reactor plants. Part of the difficulty in assessing alloy 600 performance is the significant variability in behavior from heat to heat, both from the standpoint of initial alloy chemistry and the subsequent thermomechanical treatment of the material.

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Intergranular Stress Corrosion Cracking (IGSCC) of Carbon Steel Equipment

Product Number: 51323-19173-SG

Author: Duane Serate, Simon Yuen, Yashar Behnamian, Jeffrey Venezuela

Publication Date: 2023

$20.00

At the time of a recent maintenance shutdown, cracking was discovered in the repads and parent material in the vicinity of several nozzles along the bottom of two in-situ production treater vessels. Some of the cracks were reported to be through-wall. The vessels were commissioned in 2009 and had been in service for about 13 years before the cracks manifested as through-wall.

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Internal Corrosion in Natural Gas Pipelines

Product Number: 51323-19507-SG

Author: Christopher A. Walker

Publication Date: 2023

$20.00

Corrosion is defined as the degradation of a material or its properties due to a reaction with the environment and is one of the most common pipeline integrity threats for operators. External corrosion may be visually inspected during excavation; however, due to accessibility, additional non-destructive examination (NDE) methods must be utilized to identify the presence and severity of internal corrosion.

Understanding the chemistry and electrical properties of how corrosion occurs aids in mitigating the presence of corrosion, specifically internal corrosion.

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Internal Corrosion of Flare Header - A Case Study

Product Number: 51324-21201-SG

Author: Ayman A. Alabdullatif; Lay Seong Teh; Hatam Mehraz; Anaam H. Shaikh Ali

Publication Date: 2024

$40.00

In a major gas-oil separation plant (GOSP) in Saudi Arabia, a major flare header suffered from severe internal corrosion. Upon analyzing the scale and sludge that was found accumulated in the line, a significant proportion of elemental sulfur was identified. This indicated that in addition to hydrogen sulfide and water (which were expected to be present in the line), significant amount of oxygen was also present. An investigation was conducted to identify the source of this oxygen and to eliminate it. Other critical factors that impacted the internal corrosion were also identified. The line was not properly sloped to drain accumulated moisture. Knock-out boot levels were often high and not regularly drained. In addition, purge gas was not operated at rates adequate to sweep any accumulated liquids. All of these factors combined led to an accelerated deterioration of the header.

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Internal Corrosion of L80 Tubing in Permian Basin Oil and Gas Wells-Case Studies (Lab Study)

Product Number: 51323-18892-SG

Author: Suresh Divi, Michael Newman

Publication Date: 2023

$20.00

The Permian Basin is an oil-and-gas-producing area located in West Texas and the adjoining area of southeastern New Mexico. The Permian Basin covers an area approximately 250 miles wide and 300 miles long and is composed of more than 7,000 fields (best represented in Railroad Commission of Texas production figures as districts 7C, 08, and 8A) in West Texas.1 The greater Permian Basin accounts for nearly 40 percent of all oil production in the United States and nearly 15 percent of its natural gas production.

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Internal Corrosion Prevention During Hydrostatic Testing and Wet Layup of Pipelines: Approach and Case Study

Product Number: 51324-20594-SG

Author: Susmitha Purnima Kotu; Christopher Kagarise; Richard Bruce Eckert

Publication Date: 2024

$40.00

The introduction of water and the absence of flow during hydrostatic testing or layup of pipelines can lead to internal corrosion, making corrosion control a critical concern. Various corrosion mechanisms may be active, including microbiologically influenced corrosion (MIC), under deposit corrosion (UDC), and oxygen corrosion, depending on the service and operating conditions of the pipeline. Chemical treatment is typically used to control corrosion during hydrotesting or layup, but it must be targeted at the applicable corrosion mechanisms and remain effective over the duration of hydrostatic test or layup period. Additionally, the applied chemical treatment must reach metal surfaces susceptible to corrosion. This paper highlights the approach for selection of appropriate mitigation strategy for internal corrosion prevention as part of hydrostatic testing and wet layup. This paper also presents two case studies that illustrate the processes used to identify likely corrosion mechanisms and perform laboratory studies to examine the effects of various chemical mitigation solutions for hydrostatic testing and wet layup.

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Internal Corrosion Risk Assessment for Crude Pipeline-D - A Case Study

Product Number: MECC23-19965-SG

Author: Ayman A. Alabdullatif; Rakan A. Al-Shebil; Ahmad S. Al-Otaibi; Faisal M. Al-Abbas; Omar A. Al-Saif

Publication Date: 2023

$20.00

Pipeline-D was built in 1997 and was used to transport crude to Gas-Oil Separation Plant-1 (GOSP-1). The pipeline continued operating until it was subjected to intermittent shutdown in 2009 when GOSP-2 was built. As part of the project, 900 meters were added to connect Pipeline-D to GOSP-2.

Online Conference Paper

Association for Materials Protection and Performance