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Understanding Materials Testing as it Relates to Product Evaluation and Selection in the Polymeric Flooring and Coatings Industry
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Understanding Materials Testing as it Relates to Product Evaluation and Selection in the Polymeric Flooring and Coatings Industry

Product Number: 41214-856-SG
Author: Steven Schroeder
Publication Date: 2014
$20.00

Then design professionals, or prospective users of polymeric flooring and coating systems review product data sheets, they rely largely on reported test values to make decision as to the appropriateness of a particular product. They review physical strength characteristics such compressive and tensile strength to make a determination if a particular product possesses the required properties to provide the intended service on a project.
Picture for Understanding of Corrosion Inhibitor Behavior through Interaction between Stearic Acid and Alkane
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Understanding of Corrosion Inhibitor Behavior through Interaction between Stearic Acid and Alkane

Product Number: 51324-20900-SG
Author: Susumu Hirano; Tatsuya Sei; Midori Kawasaki; Atsushi Kobayashi
Publication Date: 2024
$40.00
A principle of corrosion inhibitor behavior in an oil pipeline was studied with stearic acid and alkane. The role of corrosion inhibitor is explained by the function of surfactant, i.e., partition from oil to water, dispersion in water and adsorption on metal surface. Stearic acid alkane solution was treated as a single component model inhibitor. The performance of the model inhibitor was evaluated by measuring corrosion rates of carbon steel in a metal-oil-water system. Interfacial tension and total organic carbon were measured to investigate the dispersion of the model inhibitor. The corrosion rate was influenced by the carbon chain length of alkane, flow speed and pH of the test solution. The carbon chain length and flow rate seemed to affect the dispersion of the model inhibitor in the aqueous phase in association with the interfacial tension between alkane and water. Alkane dissociation at pH 5.5 seemed to accelerate the adsorption of the model inhibitor.
Picture for Understanding of the Co-deposition of Calcium Sulfate and Calcium Carbonate Deposition in ESP
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Understanding of the Co-deposition of Calcium Sulfate and Calcium Carbonate Deposition in ESP

Product Number: 51321-16296-SG
Author: Tao Chen/Mohammed Bataweel/Qiwei Wang/Salem Balharth
Publication Date: 2021
$20.00
Picture for Understanding of the Differences on CaCO3 and CaSO4 Control by Diethylenetriamine Penta (Methylphosphonic acid) before and after Thermal Aging
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Understanding of the Differences on CaCO3 and CaSO4 Control by Diethylenetriamine Penta (Methylphosphonic acid) before and after Thermal Aging

Product Number: 51323-18789-SG
Author: Jian Hou, Tao Chen
Publication Date: 2023
$20.00

Scale is an adherent deposit of inorganic compounds precipitated from water onto surfaces. Most oilfield waters contain certain amounts of dissolved calcium, barium or strontium salts. The mineral scale can be formed by chemical reactions in the formation water itself, by mixing of formation water with injected seawater, or by mixing of the well streams of two incompatible oilfield waters. In carbonate reservoirs, when calcium is deposited as calcium sulfate or calcium carbonate scale, a loss of production and increased maintenance expenses can result. Therefore, effective mitigation of scaling potential is of importance to the oil producers.
Picture for Understanding Pitting Corrosion Behaviour of X-65 (UNS K03014) Carbon Steel in CO2 Saturated Environ
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Understanding Pitting Corrosion Behaviour of X-65 (UNS K03014) Carbon Steel in CO2 Saturated Environments: The Temperature Effect

Product Number: 51314-4214-SG
ISBN: 4214 2014 CP
Author: Frederick Pessu
Publication Date: 2014
$20.00
Picture for Understanding Sour Service Performance of Coiled Tubing
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Understanding Sour Service Performance of Coiled Tubing

Product Number: MPWT19-14407
Author: Bruce Reichert, Claudio Morales, Martin Valdez
Publication Date: 2019
$0.00

Coiled tubing is a long (sometimes more than 25000 feet) electrical resistance welded pipes that is uncoiled for the deployment of oil and gas wells to perform a variety of jobs that involve subjecting the pipe to high pressure, axial loads, and contact with acidification, and production environments among others. Since the pipe is coiled and deployed multiple times for different jobs during its lifespan, it is typically plastically deformed and fatigued.
This paper discusses the challenges of improving the performance of this welded pipe base material, as well as its multiple welds, when facing an inhibition failure that could cause exposure to corrosive and/or embrittlement environments.
The product development process resulted in the complete modification of steel chemistry, its welding procedures and heat treatment process. The testing program includes, among other tests, the exposure of the pipe to different environments, followed by fatigue testing to determine the remaining material resistance after such exposure.
Understanding the Breathing-Air System in Abrasive Blasting
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Understanding the Breathing-Air System in Abrasive Blasting

Product Number: 41215-891-SG
Author: Thomas E. Enger
Publication Date: 2015
$20.00

The Occupational Safety and Health Administration (OSHA) defines abrasive blasting as “using compressed air or water to direct a high-velocity stream of an abrasive material to clean an object or surface, remove burrs, apply a texture or prepare a surface for the application of paint or other type of coating.” OSHA regulations governing General Industry, Construction, and Shipyards mandate the use of abrasive-blast respirators approved by the National Institute for Occupational Safety and Health (NIOSH). Blast respirators are Type-CE supplied-air respirators, commonly known as “blast helmets.” This article will review and explain the components and the requirements pertaining to the use of these respirators.
Picture for Understanding the Corrosion Performance and Mechanism of Stainless and Carbon Steels in Different Storage and Transportation of Pyrolysis Oil Environments
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Understanding the Corrosion Performance and Mechanism of Stainless and Carbon Steels in Different Storage and Transportation of Pyrolysis Oil Environments

Product Number: 51324-21226-SG
Author: Minkang Liu; Xue Han; Yimin Zeng
Publication Date: 2024
$40.00
This study assessed the suitability of two candidate materials for use in fast pyrolysis reactors and their core components. An immersion test conducted at temperatures of 60 °C and 80 °C over a 7- day period revealed significant corrosion in carbon steel A516-70, with corrosion rates reaching up to 6.24 mm/year. In contrast, UNS S32205 displayed impressive resistance to corrosion, even at 80 °C. Fe2O3 have been identified as the major corrosion products on A516-70, chromium oxides and spinel oxides were found on UNS S32205. The primary corrosive agents were identified as organic acids present in the pyrolysis oil, owing to the oil's high total acidic number and low pH value. Ongoing microscopic characterizations aim to provide a more comprehensive understanding of the underlying corrosion mechanisms.
Picture for Understanding the Discrepancies in Wet Bottom and Dry Bottom MASTMAASIS Testing Results of AA2060
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Understanding the Discrepancies in Wet Bottom and Dry Bottom MASTMAASIS Testing Results of AA2060

Product Number: 51317--9171-SG
ISBN: 9171 2017 CP
Author: Mary Parker
Publication Date: 2017
$20.00

In the current study, in-situ measurements were used to deconstruct the testing environment of dry-bottom (DB) ASTM G85-A2 to provide an understanding of what makes this test successful when others are not.
Picture for Understanding the Effect of Pigging and Corrosion Inhibitor Injection on Microbiologically Influenced Corrosion of Carbon Steel Pipelines
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Understanding the Effect of Pigging and Corrosion Inhibitor Injection on Microbiologically Influenced Corrosion of Carbon Steel Pipelines

Product Number: 51319-13103-SG
Author: Jaspreet Mand
Publication Date: 2019
$20.00

Microbiologically influenced corrosion (MIC) is a persistent problem for many oil and gas production operations. Carbon steel pipelines are particularly susceptible to biofilm formation by microorganisms which consequently threatens the integrity of these lines. Although MIC within pipelines is challenging to mitigate it is generally accepted that pigging a mechanical cleaning process that removes water oil scales and solids from the pipeline surface is an effective method to control biofilm formation. However not all pipelines can be effectively pigged to counter biofilm development. In many cases partially removed or unremoved biofilms are exposed to continuously injected film-forming corrosion inhibitors (CI) which are used to mitigate acid gas corrosion in pipelines.To date the individual and combined effects of pigging and CI injection on biofilm formation and subsequent corrosion has not been well-studied.To this end corrosive consortia consisting of sulfate-reducing bacteria and methanogenic archaea were grown as biofilms on carbon steel coupons under defined laboratory conditions. Biofilms were grown for a period of 3 weeks in order to establish base (unmitigated) MIC rates. Once biofilms were established the coupons were exposed to one of the following corrosion mitigation treatments: (1) simulated pigging using a wire brush (2) exposure to a CI-containing medium or (3) a combination of both. Biofilms were incubated for an additional 6 weeks following these treatments to allow for biofilm regrowth. The impact of these treatments on the resulting MIC rates was evaluated by comparing the weight loss corrosion rates and localized pitting corrosion of the carbon steel coupons. Additionally qPCR and 16S rRNA gene sequencing were used to enumerate and identify the different corrosive microbial communities that developed on the coupons following the different treatments. Fundamentally different effects of corrosion inhibitors on MIC were observed depending on whether these chemicals were applied to a pre-formed biofilm or to mechanically cleaned steel surfaces.
Picture for Understanding the Effect of Water Chemistry and Surface Grinding on the Stress Corrosion Cracking Initiation of Filler Metal 82

Understanding the Effect of Water Chemistry and Surface Grinding on the Stress Corrosion Cracking Initiation of Filler Metal 82

Product Number: ED22-17143-SG
Author: N.SUPORNPAIBUL, M.G. BURKE, J. DUFF, F. SCENINI, Y.WANG
Publication Date: 2022
$20.00

SCC of Ni-base filler metal (FM) 82 has been reported in the nozzles and other components in Light Water Reactors (LWRs). The typical characteristics of stress corrosion cracking (SCC) of Ni-base alloys are a long incubation time followed by slow propagation, which can suddenly transition to fast propagation. Whilst there has been considerable effort expended to develop an SCC mechanism that can explain and predict SCC in Alloy 600, fewer studies have investigated SCC of FM 82. The Preferential Intergranular Oxidation (PIO) SCC mechanism of Alloy 600 proposed by Bertali et al.  which is an evolution of the Selective Internal Oxidation SCC mechanism proposed by Scott and Le Calvar is considered one of the most representative primary water SCC mechanisms for Alloy 600.
Understanding the Effects of NaCl Concentration on Zinc Phosphate Pigment Morphology and Composition by Advection Through Phenoxy Thermoplastic Free Films
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Understanding the Effects of NaCl Concentration on Zinc Phosphate Pigment Morphology and Composition by Advection Through Phenoxy Thermoplastic Free Films

Product Number: 41215-879-SG
Author: Robert C. Bennett, Greg Curtzwiler, Christina Konecki, Dilhan Fernando, James W. Rawlins
Publication Date: 2015
$20.00

Corrosion is a major concern for all materials during their service lives. In particular, salts such as sodium chloride (NaCl) are known to promote corrosion and detrimentally affect coating performance. Understanding how NaCl affects water uptake into a film and its interactions with corrosion-inhibiting pigments is important for developing the next generation of anticorrosive coatings. 
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