AMPP Store - Products tagged with 'autoclave'

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51316-7312-Changes in Test Methodology to Reflect the Changes Within the Oil and Gas Linings Market

Product Number: 51316-7312-SG

ISBN: 7312 2016 CP

Author: Michael Harrison

Publication Date: 2016

$20.00

Traditional internal lining schemes for the storage/transport of crude oil & refined fuels may no longer be appropriate. The aggressive nature of crude oil (high temp. & more sour), high purity refined products & increased use of biofuels demand better linings & more certain test results. The focus of this paper is to review the trends in test methodology from the early 1990’s to present.

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51318-10903-Evaluation of corrosion inhibitor with high speed rotating cage

Product Number: 51318-10903-SG

Author: Susumu HIRANO, Toshiyuki SUNABA and Takashi ITO

Publication Date: 2018

$20.00

Three brands of oil-soluble water-dispersible inhibitors were evaluated with the rotating cage autoclave (RCA). Some inhibitors showed enough efficiency at high rotating speed but the others require more dosage to maintain the same result.

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Advanced Chemical Resistant Epoxy Systems To Endure High Pressure and High Temperature in Pipes and Tanks

Product Number: 51323-18766-SG

Author: Yong Zhang

Publication Date: 2023

$20.00

Most cured epoxy resins provide excellent mechanical strength and toughness as well as outstanding chemical, moisture, and corrosion resistance. They also have good thermal, adhesive, and electrical properties, no volatiles emissions, low shrinkage upon cure and dimensional stability1. This unique combination of properties coupled with outstanding formulating versatility and reasonable costs, have gained epoxy resins wide acceptance as materials of choice for a multitude of protective coatings applications.

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Development of Corrosion Inhibitor for High Temperature Sweet Gas Wells

Product Number: 51324-20757-SG

Author: Ime Bassey Obot; Tao Chen; Ahmad A. Sorour; Qiwei Wang

Publication Date: 2024

$40.00

The corrosion of carbon steel downhole completion tubing at high temperature is one of the serious corrosion issues facing the oil and gas industry. Few corrosion inhibitor chemistries can protect downhole production tubing against corrosion, especially at high-temperature and high-pressure (HTHP) in high total dissolved solids (TDS) brine. The objective of this study was to develop a HTHP corrosion inhibitor abbreviated (NAM 9) for the protection of carbon steel at a temperature of up to 120 oC for possible application in sweet gas wells. The new corrosion inhibitor formulation (NAM 9) was evaluated using the linear polarization resistance (LPR) technique, batch corrosion testing (drop and drip) and autoclave corrosion test. The LPR result shows that 10 ppm of NAM 9 drastically reduces the corrosion rate of C1018 steel from 214.4 mpy (5.44 mm/y) to 3.28 mpy (0.08 mm/y) giving an inhibition efficiency of 98.47 % at 70 oC. The corrosion rate of the blank using autoclave corrosion testing at 120 oC was 250.6 mpy (6.36 mm/y) and 30.3 mpy (0.77 mm/y) in the presence of 500 ppm of NAM 9, respectively. The results indicate that NAM 9 is a promising high-temperature corrosion inhibitor for downhole production tubing used in gas wells.

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Development of Linings for High Temperature, High Pressure Applications for Petrochemical Applications

Product Number: 41214-838-SG

Author: Ted Moore, Mark M. Morrison

Publication Date: 2014

$20.00

Development of linings for high temperature, high-pressure applications present a number of special challenges. Challenges include chemical resistance, abrasion resistance, adhesion under cycling temperature and pressure conditions, flexibility, application properties, as well as resistance to pressure and temperature.

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Development of New Coating Systems for High Erosion Environments

Product Number: 51323-19184-SG

Author: John M. Bronk, Robert Polance, Benjamin Chaloner-Gill, Peter Hillman, Frank Zychowski, Mason Kinter

Publication Date: 2023

$20.00

Components utilized in oil field operations are often exposed to harsh environments. Corrosion and wear of components and piping can be considered one of the main causes of failure. These components are exposed to high flow rates, high pressures, and other environmental conditions.

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Handling Extreme Environments With Supoxy Platform Technology

Product Number: 51322-17643-SG

Author: Justin Manuel, Chad Remy

Publication Date: 2022

$20.00

One can find some of the most aggressive and corrosive environments for coatings in the process work and equipment functions for Oil and Gas Upstream facilities. These conditions have typically been handled using traditional coating options such as vinyl esters, epoxies, or baked phenolic linings. While these products are often tailored to environments with elevated temperatures and pressures found within upstream and “downhole” oil and gas production, the inception of new drilling techniques and the discovery of new shale basins has morphed the landscape of corrosive environments in this market.

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High Temperature and High Chemical Resistant Ambient Cure Tank Liner

Product Number: 51317--9016-SG

ISBN: 9016 2017 CP

Author: Yong Zhang

Publication Date: 2017

$20.00

Olin Epoxy has designed a unique low VOC and high solids epoxy system which offers superior performance in tank liner application. The formulation of these novel materials in high temperature and high chemical resistant ambient cure tank liner will be described.

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Mitigation of Elemental Sulfur and Iron Sulfide Under-Deposit Corrosion

Product Number: 51323-19423-SG

Author: Sherman Kung, Nolan Miller, Feras EI Yaakobi, Jeremy Moloney

Publication Date: 2023

$20.00

Production of highly sour oil and gas fields has increased recently, which introduces new challenges for
corrosion control. In recent years, some unexpected and unexplained pipeline failures have occurred,
resulting in complex investigations and laboratory corrosion performance testing studies to assess the
inhibitors that are applied in these environments. While some of these failures are due to cracking in
sour environments which are prevented by alternative material selection or different operation pipeline
maintenance, we were specifically looking at cases where chemical inhibitors could be used to mitigate
corrosion.

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NACE TM0185-2024, Evaluation of Internal Plastic Coatings for Corrosion Control of Tubular Goods by Autoclave Testing

Product Number: NACE TM0185-2024

Publication Date: 2024

$109.00

This test method has been prepared to provide manufacturers, applicators, and users of internal pipe coatings with a method of comparing the performance of these coatings. The method used in this standard is not intended to correlate with any particular field performance but is intended solely to compare samples of internally coated tubular goods under uniform laboratory test conditions.

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Novel Internal Coating System for High Concentration H2S Environments

Product Number: MECC23-19951-SG

Author: Robert S. Lauer

Publication Date: 2023

$20.00

During the 72-year history of using high performance coating systems for pipe internal corrosion control, there has been a slow introduction of different resin chemistries that serve as the backbone of these coating systems. While phenolic resins systems were the primary starting point, it transitioned to include epoxies, novolacs, nylons, urethanes and others. As needs outside corrosion control like deposit mitigation and wear resistance arose, coatings based on other specialty resin chemistries, like from the fluoropolymer family, were developed.

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Proposed Test Protocol for Evaluating Internal Coating Systems for Railcar Sour Oil Applications

Product Number: 51324-20646-SG

Author: Amal Al-Borno; Moavin Islam; Henry Pedraza

Publication Date: 2024

$40.00

Crude oil is usually transported by pipelines from the production areas to refineries. However, in North America, particularly Canada, a significant amount of crude oil is transported via specially designed railcars. The internals of the railcars are typically coated with a high-quality coating system to prevent corrosion. Still, coating failures do occur due to the unique cyclic operating service conditions of the railcars. Thus, elevated temperatures are used to reduce fluid viscosity with a resultant increase in the vapor pressure while the loading of the oil in the railcars. Once loaded, the crude is transported under ambient temperature and pressure until the railcars reach their destination. During off-loading, elevated temperatures are again used for reducing the viscosity of the oil. After emptying the contents, the railcars are allowed to return to ambient conditions and sent back to the production area to repeat the loading, transportation, unloading cycle. Currently, there is no established test protocol to evaluate candidate coating systems for railcar internals under simulated operating conditions. Testing is usually done under a single set of operating conditions of loading or unloading and does not include the synergistic effect of the different temperature variations. This paper presents a detailed test protocol for evaluating candidate coating systems for railcar internals. The proposed test protocol was designed to simulate the expected service conditions of railcars using a modified NACE TM0185-2006 test procedure, “Evaluation of Internal Plastic Coatings for Corrosion Control of Tubular Goods by Autoclave Testing”. The modification includes the cyclic service condition of railcars – fuel loading, loaded transportation, off-loading, dry heat and empty transportation.

Products tagged with 'autoclave'

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