AMPP Store - Products tagged with 'naphthenic acid corrosion'

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05568 Study of Corrosiveness of Acidic Crude Oil and its Fractions

Product Number: 51300-05568-SG

ISBN: 05568 2005 CP

Author: Alec Groysman, Naphtali Brodsky, Joseph Pener, Alon Goldis and Natali Savchenko, Oil Refineries Ltd.

Publication Date: 2005

$20.00

The main goal of this work is to investigate the corrosiveness of different petroleum fractions distilled from acidic crude oil “A” at 150 to 370oC (302 to 698oF) and to find effective measures for diminishing the corrosiveness of aggressive fractions.

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51316-7302-Mechanism of High Temperature Corrosion by Model Naphthenic Acids

Product Number: 51316-7302-SG

ISBN: 7302 2016 CP

Author: Peng Jin

Publication Date: 2016

$20.00

This work demonstrates that the pretreatment of carbon steel and 9Cr alloy with model acids yields iron oxide scales with different morphology and chemical composition as determined by Scanning Electron Microscopy (SEM) and Transmission Electron Microscopy (TEM).

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51317--9694-Multipoint Flux Monitoring by the Hydrogen Collection Method Using a New Wide Temperature Range Flux Measurement Probe

Product Number: 51317--9694-SG

ISBN: 9694 2017 CP

Author: Frank Dean

Publication Date: 2017

$20.00

The hydrogen collection method is used widely. In this paper we present preliminary measurements from a newly developed device based on the hydrogen collection method of flux measurement, which enables readings to be taken from up to four external probes sequentially, within a short time.

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Effect of Time on High Temperature Naphthenic Acid and Sulfur Corrosion of Carbon Steel under Continuous Oil Flow Conditions

Product Number: 51321-16413-SG

Author: Prince Kumar Baranwal/Winston Robbins/Gheorghe Bota

Publication Date: 2021

$20.00

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Naphthenic Acid Corrosion And Sulfidic Corrosion In Crude Oil Fractions

Product Number: 51322-17533-SG

Author: Yuhchae Yoon, Hui Li, Kwei Meng Yap

Publication Date: 2022

$20.00

In the petroleum industry, much greater attention has been focused on more highly sour and acidic oil resources due to the gradual depletion of conventional sweet oil resources. In addition, reducing crude oil costs have forced to look for opportunity (alternate) crudes, usually low-quality corrosive crude oils with high concentrations of naphthenic acids and sulfur compounds.1 The main constituents in the crude that cause corrosion are sulfur compounds, organic and inorganic chlorides, salt water, organic and inorganic acids. Processing of these highly acidic and sulfur-containing crudes at high temperatures in refineries has promoted significant corrosion problem in hot oil distillation units and associated piping systems.

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Naphthenic Acid Corrosion in a High TAN Condensing Overhead System

Product Number: 51317--9095-SG

ISBN: 9095 2017 CP

Author: Kwadwo Sarpong

Publication Date: 2017

$20.00

A case history where an ethoxylated thio-phosphate ester was successfully used to mitigate low temperature naphthenic acid corrosion in a high total acid number condensing overhead system in which a traditional imidazoline corrosion inhibitor failed.

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Physicochemical Description of Refinery High Temperature Naphthenic Acid Corrosion

Product Number: 51324-20988-SG

Author: Ishan Patel; David Young; Gheorghe Bota

Publication Date: 2024

$40.00

Refinery high temperature naphthenic acid corrosion is known to generate oil soluble iron naphthenates and solid iron oxide as corrosion products. Associated chemical reactions have been written for a long time but are barely sufficient to resolve the comprehensive mechanism necessary to model their kinetics. A mechanism for naphthenic acid corrosion is proposed to be proceeding via formation of active intermediate by adopting the Lindemann-Hinshelwood approach. The rate law for the calculation of pure naphthenic acid corrosion rate was derived using a pseudo steady state hypothesis which could simulate laboratory corrosion data reported in the literature. The rate equation was also validated by experimental corrosion tests conducted in a high temperature flow-through reactors for carbon steel using a model oil solution of petroleum derived acids by manipulating solution concentration and temperature. Also, the formation of the solid iron oxide is proposed to be a result of the decay of active intermediate as an alternative mechanism in contrast with the currently accepted thermal decomposition pathway.

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Quantifying Effect of Hydrogen and Sulfur in Mitigating Free Fatty Acid Corrosion in Renewable Diesel Applications

Product Number: 51324-20864-SG

Author: Sridhar Srinivasan; Winston Robbins; Gerrit Buchheim

Publication Date: 2024

$40.00

Production of Renewable Diesel (RD) and Sustainable Aviation Fuels (SAF) from bio / natural oils has seen significant investment in recent years, stemming from worldwide government mandated need to reduce fossil fuel CO2 emissions. New investments have occurred in retrofitting / adapting existing refinery hydroprocessing infrastructure to process natural oils or coprocess natural oils blended with crudes to produce RD and SAF. This stems from the fact that natural oils have the hydrocarbon (HC) structures to fit within the mid-distillate fuel product such as diesel and aviation fuel as well as that these processes are optimized for removal of unwanted Sulfur and Oxygen removal. In Corrosion/2023, the authors introduced a molecular mechanistic model to quantify FFA corrosion as a function of temperature and FFA concentration. This model exploited the similarity of FFA to carboxylic acids, akin to naphthenic acids found in conventional refinery crude unit process streams, especially in case of unsaturated FFA. A key aspect of modeling corrosion for FFA is the inhibitive role of hydrogen in the presence of Iron sulfide species. While natural oils do not contain sulfur compounds, presence of reactive sulfur species such as thiols and sulfides in coprocessing applications provides an easy pathway to provide for the formation of a potentially protective nano barrier layer of FeS. Further, the presence of FeS acts as a catalyst towards dissociation of molecular H2 to atomic H and subsequent reduction of FFA through atomic hydrogen. A threshold H2 partial pressure is required to ensure hydrogen reduction of FFA is kinetically dominant when compared to acid corrosion of Fe. Residence time of acid is another key parameter that will impact propensity for corrosion and / or H2 inhibition and is considered in the development of the prediction model. A framework incorporating the effects of H2 partial pressure, residence time and reactive S concentration is proposed for assessing FFA corrosion for various commonly utilized natural oils in renewable applications.

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Quantifying High Temperature Corrosion in Renewable Diesel and Sustainable Aviation Fuel Production

Product Number: 51323-19457-SG

Author: Sridhar Srinivasan, Winston Robbins, Gerrit Buchheim

Publication Date: 2023

$20.00

In Corrosion/2021, the authors introduced a molecular mechanistic model that quantifies and predicts simultaneous naphthenic acid and sulfidation (SNAPS) corrosion rates. During Corrosion/2022, we presented the mechanistic corrosion prediction framework describing the molecular basis of the model’s reactions, kinetics, and mass transport of reactive organic sulfur compounds (ROSC) to vessel walls. In this molecular model, sulfidation corrosion is calculated for direct heterolytic reaction of ROSC with solid surfaces.

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Structure And Related Effectiveness Of Naphthenic Acid Corrosion Inhibitors

Product Number: 51322-18157-SG

Author: Oussama Zenasni, Maria D Marquez, Philip Thornthwaite, John N. Scholz

Publication Date: 2022

$20.00

Opportunity crudes are generally defined as petroleum crudes bearing a high level of sulfur, metals, or total acid number (TAN). These crudes are typically offered at a discounted value. Thus, refining such crudes carries with it a lucrative incentive. However, due to the above-mentioned characteristics, processing such crudes presents numerous operational challenges as well, such as naphthenic acid corrosion, which is commonly associated with the high TAN content in these crudes. In refinery units such as the crude distillation tower, these carboxylic acids react with the iron atoms of the metal surfaces to produce oil soluble iron carboxylates.^1,2 The continued formation of such complexes would then erode the metal surface. Equipment failure due to such corrosion results in shutting down a large segment or the entire refinery. Therefore, establishing a means for mitigating this type of corrosion is paramount for processing crude oils with an elevated TAN due to naphthenic acids.

Products tagged with 'naphthenic acid corrosion'

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