AMPP Store - AMPP Conference Papers

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15.5-Year Inspection Reveals the Effectiveness of a Single-Coat Epoxy

Product Number: 51322-17996-SG

Author: Guy Zanti

Publication Date: 2022

$20.00

In the mid-1990s, the US Navy’s technical community, led by Naval Sea Systems Command (NAVSEA), recognized existing coatings used to protect the inside of ships’ tanks were failing on average 5-8 years after application. The high cost to blast and recoat over 11,000 tanks every 5-8 years, not counting submarines and aircraft carriers, was prohibitive. To address this issue, the Navy conducted a study to analyze the problem and decided to replace these legacy coatings with high solid epoxy coatings.¹

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2022 Conference Proceedings

Product Number: FLASHDRIVE22-CONF_MAR22

Publication Date: 2022

$149.00

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2-Layer Polyethylene Plant Applied Mainline Coating for Use in Water and Wastewater Pipeline Applications

Product Number: 51324-20761-SG

Author: Samuel Thomas

Publication Date: 2024

$40.00

This paper will review what a 2-layer polyethylene coating consists of, the application and use as an external mainline coating for both ductile iron and carbon steel pipe. Laboratory data will be reviewed regarding UV aging and thermal and hydrolytic aging and mechanical properties. Examples of field installations will also be discussed. Case histories regarding long term in-ground performance of 2-layer polyethylene plant applied external corrosion coatings will be discussed.

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3D Printing Of Cemented Carbide: A Review And Perspectives In Oil Sands

Product Number: 51322-17506-SG

Author: Young Li, Duane Serate, Stefano Chiovelli, Simon Yuen, Darius Remesat, Brian Doucette, Billy Rideout, Dave Waldbillig, Marcus Ive

Publication Date: 2022

$20.00

Canada's oil sands are the third largest deposit of crude oil in the world, and consist of a mixture of sand, water, and bitumen. Due to an aggressive operating environment that includes abrasive sands and corrosive chemicals, oil sands equipment and process piping often experience severe wear and erosion-corrosion, which can lead to the risk of equipment failures, plant downtime or, even worse, environmental leaks [1]. For more than half a century, oil sands producers have collaborated with materials suppliers, equipment fabricators, and technology providers to develop wear technologies to reduce downtime and improve operational reliability.

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40-Year Maintenance Free Coating Solution for Offshore Structures

Product Number: 51324-20591-SG

Author: Darren Ward; Mike O'Donoghue; Vijay Datta

Publication Date: 2024

$40.00

Offshore assets such as those found on wind farms are being designed to have extended lifetimes of more than 40 years to offer a sustainable form of energy generation. With offshore maintenance considered a hazardous and expensive process, owners are looking for low or maintenance free solutions to protect their assets. The challenge to the coating manufacturer is twofold, firstly to design a coating system that offers a maintenance free solution in a highly corrosive environment and secondly demonstrating long term performance. This paper will describe a 40-year case history of a coating system applied to the hull of a offshore TLP with submerged, splash/tidal, and atmospheric zone. We will describe both the technology approach using high loadings of lamellar glass flake to enhance both abrasion and mechanical properties and secondly demonstrate the in-service properties of the coating system after 40 years exposure including visual appearance, adhesion, cross sectional optical microscopy and electrical impedance spectroscopy (EIS). The coating integrity has been well maintained by a multiple coating application. We will discuss the key product attributes that are relevant to providing a high durability coating solution for extreme environments. We will also introduce a new international standard related to the offshore wind industry with particular focus on extending asset lifetime through appropriate coating specification and selection.

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50 mV As a Screening Criteria for Shorted Casings – Case Study

Product Number: 51323-18899-SG

Author: Keith Parker, Len Krissa, Kris Hoisington

Publication Date: 2023

$20.00

While performing cathodic protection surveys, carrier pipe and casing potential readings are typically recorded at the same test station location near the end of a casing. Comparing these potentials should reveal a difference between the cathodically protected pipe versus an unprotected and electrically isolated casing. The difference in potentials is one of available tests to determine whether a casing may be electrically shorted to the carrier pipe. The pipe-to-electrolyte and casing-to-electrolyte potential comparison is usually the initial “screening” method.

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51324-ALL-Conference Proceedings 2024 ALL PAPERS

Product Number: 51324-ALL-SG

$400.00

Compilation of conference papers presented at the AMPP Annual Conference + Expo 2024 in New Orleans, LA, USA.

Papers will be available for download on March 3, 2024.

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A Case Study On Microbiologically Influenced Corrosion In Oil Producing Well Flowlines

Product Number: 51322-17924-SG

Author: Amer Jarragh, Sandip Kuthe, Sharad Londhe, Akhil Jaithlya, Abeer Rashed, Nadine El-Kaouri

Publication Date: 2022

$20.00

Oil field operating company’s ⁽¹⁾ flowline network in North and West Kuwait (NWK) has over 3000 wells connected through 6” carbon steel pipelines flowing from wellhead to the nearest Gathering Center (GC). Untreated wet crude is transported through the flowlines to GC’s directly or passing through the Remote Headers and Manifold (RHM) to GCs. In RHM, mixing of the wet crude takes place before it is sent to GC’s via transfer lines for further separation. The flowlines are laid aboveground except at road crossings where they are buried.

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A Case Study on the Cause of Pipelines Leaks by Phone Line Damage

Product Number: 51324-20946-SG

Author: Richard Flowers

Publication Date: 2024

$40.00

An increase in unrepaired, broken phone lines potentially contribute to low cathodic protection (CP) potentials or leaks along steel natural gas pipelines. This paper presents data of multiple interference locations between the phone line and natural gas distribution piping. Data includes output voltage from phone lines, before and after CP potentials, and Close Interval Surveys (CIS) of two (2) Interference locations. This paper will present ways to identify potential phone line interference through case studies and then conclude with discussion on how to remediate the interference.

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A Case Study on the Failure of Fiber Reinforced Epoxy (FRE) Lining on Condensate Storage Tank

Product Number: 51323-19193-SG

Author: Ahmad Raza Khan Rana, George Jarjoura, Syed Umair Niaz Bukhari

Publication Date: 2023

$20.00

A remarkable amount of financial loss is incurred every year because of premature failures of paints and coatings. The budget to repair such failures extremely outweighs the initial cost of coatings, since excessive engineering may be looked-for to access the deteriorating areas of a coating system. Additional accountability may also be anticipated if a facility stops operation for the essential repairs to be made.

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A Case Study: Piecewise vs. Holistic Pipeline AC Mitigation Design

Product Number: 51323-19307-SG

Author: Perry Ross

Publication Date: 2023

$20.00

AC interference analyses are an important part of designing an adequate cathodic protection system on a pipeline when collocations with high voltage powerline(s) occur. Modeling software has been developed to create accurate simulations of what is occurring in the real world to create the best mitigation designs for operators. Many of these studies are proposed due to pipeline replacements that update pipelines from coatings with coal tar to fusion bonded epoxy (FBE).

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A Case Study-Caustic Gouging Of Boiler Tubes

Product Number: 51322-17780-SG

Author: Suresh Divi, Sri Krishna Chimbli

Publication Date: 2022

$20.00

Caustic corrosion is sometimes referred to as “caustic attack or “caustic gouging.” Corrosion of this type may result from internally fouled heat transfer surfaces and the presence of sodium hydroxide in the boiler water; and concentrated solutions of alkali where the normal washing of the tube metal ID is restricted after Departure from Nucleate Boiling (DNB), i.e., when the steam bubble release exceeds the rinsing rate.

AMPP Conference Papers

Association for Materials Protection and Performance