Acidity in Crude Oils

Ramirez-Corredores, Maria Magdalena

doi:10.1016/b978-0-12-801225-3.00004-8

Cited by 11 publications

(7 citation statements)

References 174 publications

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“…The ICrA evaluation (Tables S13 and S14) revealed that both crude oils BTV and BSP (Figure 8) contributed to the higher crude blend acidity, with BSP being the dominant factor (Figure 7). A rule of thumb is that crude oils which have a total acid number (TAN) higher than 0.5 mg KOH/g are considered acidic and probably problematic from a corrosion point of view [71,72]. Qu et al [73] announced that the higher-TAN crudes are more corrosive.…”

Section: Discussionmentioning

confidence: 99%

“…This observation is in line with the conclusion of Barrow et al [75], that TAN is not a reliable tool for assessing the acid content of petroleum, because it also measures species which have "mobile protons" like esters, phenols, resins, etc. [72]. The acid structures identified in petroleum crudes were found to contain functional groups of oxygen, nitrogen, aromatics, and sulphur, such as alkyl sulphonic acids [76].…”

Section: Discussionmentioning

confidence: 99%

“…The acid structures identified in petroleum crudes were found to contain functional groups of oxygen, nitrogen, aromatics, and sulphur, such as alkyl sulphonic acids [76]. That is why the corrosivity of crude oil does not always correlate to the TAN [77] and is dependent on the size and structure of acid species [71,72,78,79]. The higher molecular weight acids were announced to have lower corrosion activity, while the low molecular weight acids manifest a very high corrosivity [80].…”

Section: Discussionmentioning

confidence: 99%

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Experience in Processing Alternative Crude Oils to Replace Design Oil in the Refinery

Stratiev,

Shiskova,

Toteva

et al. 2024

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A comprehensive investigation of a highly complex petroleum refinery (Nelson complexity index of 10.7) during the processing of 11 crude oils and an imported atmospheric residue replacing the design Urals crude oil was performed. Various laboratory oil tests were carried out to characterize both crude oils, and their fractions. The results of oil laboratory assays along with intercriteria and regression analyses were employed to find quantitative relations between crude oil mixture quality and refining unit performance. It was found that the acidity of petroleum cannot be judged by its total acid number, and acid crudes with lower than 0.5 mg KOH/g and low sulphur content required repeated caustic treatment enhancement and provoked increased corrosion rate and sodium contamination of the hydrocracking catalyst. Increased fouling in the H-Oil hydrocracker was observed during the transfer of design Urals crude oil to other petroleum crudes. The vacuum residues with higher sulphur, lower nitrogen contents, and a lower colloidal instability index provide a higher conversion rate and lower fouling rate in the H-Oil unit. The regression equations developed in this work allow quantitative assessment of the performance of crucial refining units like the H-Oil, fluid catalytic cracker, naphtha reformer, and gas oil hydrotreatment based on laboratory oil test results.

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Section: Discussionmentioning

confidence: 99%

Section: Discussionmentioning

confidence: 99%

Section: Discussionmentioning

confidence: 99%

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Experience in Processing Alternative Crude Oils to Replace Design Oil in the Refinery

Stratiev,

Shiskova,

Toteva

et al. 2024

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“…There may be different reasons for emulsion formation and the retention of salts by crude oils. Naphthenic acids (carboxylic acids of cycloalkanes) and their corresponding naphthenate salts (metal cycloalkanoates) can be contributing both to emulsion stabilization and the retention of metals in the oil . This can be extended to acidic organic compounds in general.…”

Section: Introductionmentioning

confidence: 99%

Desalting Behavior of Bitumen

2021

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The salt content of crude oil that enters a petroleum refinery should be kept to a minimum to limit corrosion and fouling issues associated with salts. Desalting is usually performed as the first step in refining. Desalting of strong emulsion-forming crude oils, such as oil sand-derived bitumen, is more challenging. This work investigated the desalting behavior of oil sands bitumen to determine whether salts were present mainly in emulsified connate water, or whether salts were also present outside of emulsified water. A four step desalting procedure was performed and the removal of ionic species in the aqueous phase was monitored, with emphasis placed on anion quantification. With consecutive washing steps, the anion and cation concentrations did not always decrease monotonically and these observations were supported by conductivity measurements. The ratio of anions, notably carbonate/sulfate and chloride/sulfate, did not remain constant either. With repeated water washing, the pH of the aqueous phase became more acidic. The pH from the first washing step was 7.3 and with subsequent washing steps, the pH decreased, reaching as low as 4.7 in one of the experiments. The desalting behavior was therefore not consistent with a description of bitumen that retained salts only in emulsified connate water. At least some salts had to be present as solids in the bitumen to explain variability in anion ratios. It was also speculated that some salts could be present in ionic or coordination interactions with bitumen.

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“…Several potential sources of NAs have been identified 1,2 : acid components originated from organic matter (plants/animals), acids formed during biodegradation (change in nonacidic/acidic compounds ratio), acids developed after death due to bacteria degradation and acids produced via chemical oxidation. The formation of naphthenic acids increases the polarity and the concentration of oxygen-containing species.…”

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confidence: 99%

Interfacial behavior and partitioning of partially neutralized naphthenic acids: experiments versus HLD-NAC predictions.

Pérez

Bhattacharya

Acosta

2023

Preprint

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Recent studies have shown that naphthenic acids (NAs) and sodium naphthenates dominate the interfacial activity of bitumen and the formation of bitumen emulsions. NAs are naturally occurring mixtures of carboxylic acids in bitumen, where their concentration can reach 4 wt%. Unlike other fatty acid-containing oils, alkaline neutralization of NAs in bitumen does not lead to ultralow interfacial tensions (IFT<0.1 mN/m). Ultralow IFTs are beneficial towards separating emulsions and could be beneficial in the separation of bitumen emulsions. Two possible reasons for the lack of ultralow IFTs with neutralized NAs were explored. One involved insufficient adsorption and neutralization of NA, and the other was the partition of naphthenic species in different phases. Dynamic IFT and pH studies suggest that adsorption and neutralization of NA proceed as predicted by the stoichiometry of the reaction. On the other hand, it was determined that a large fraction of the sodium naphthenates (NaNs) formed at the interface partitioned back into the oil. By forcing the participation of NaNs at the interface via their introduction through the aqueous phase, it is possible to create transient ultralow IFTs. The conditions (NA and NaN concentration and the salinity of the system) that led to ultralow IFTs were predicted by an HLD-NAC model previously validated for the neutralization of oleic acid.

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Acidity in Crude Oils

Cited by 11 publications

References 174 publications

Experience in Processing Alternative Crude Oils to Replace Design Oil in the Refinery

Experience in Processing Alternative Crude Oils to Replace Design Oil in the Refinery

Desalting Behavior of Bitumen

Interfacial behavior and partitioning of partially neutralized naphthenic acids: experiments versus HLD-NAC predictions.

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