Isolation and Characterization of Naphthenic Acids from a Metal Naphthenate Deposit: Molecular Properties at Oil‐Water and Air‐Water Interfaces

Brandal, Øystein; Hanneseth, Ann‐Mari Dahl; Hemmingsen, Pål V.; Sjöblom, Johan; Kim, Sung-hwan; Rodgers, Ryan P.; Marshall, Alan G.

doi:10.1080/01932690500357909

Cited by 75 publications

(84 citation statements)

References 51 publications

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“…The most abundant ARN contains six cyclic rings [3][4][5][6][7]. Based on their special molecular structure (Table 1), these tetrameric acids (TA) show higher interfacial activity than monoacids [8], and they have the ability to form cross-linked gel networks at oil-water interface when reacting with divalent ions such as Ca 2? , Ba 2?…”

Section: Introductionmentioning

confidence: 99%

Aggregation of tetrameric acid in xylene and its interaction with asphaltenes by isothermal titration calorimetry

Wei

Orlandi

Barriet

et al. 2015

J Therm Anal Calorim

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This paper describes the self-association of tetrameric acids (TA) and their interactions with asphaltenes using isothermal titration calorimetry. In order to visualize the importance of molecular structures of TA and asphaltenes, stearic acid (SA) and asphaltene model compounds are used for comparison. Both SA and TA form dimers in xylene solutions. However, the dimerization enthalpy for SA (DH) in absolute value is higher than the corresponding value for TA, indicating that the aggregation is less efficient for TA likely due to steric reasons. The interplay between asphaltenes and TA or SA is similar except at low concentrations. Interactions between TA and asphaltene model compounds are strongly dependent on the presence of acid group in model compounds, indicating hydrogen bonds as a central but not only element in the interactions.

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Section: Introductionmentioning

confidence: 99%

Aggregation of tetrameric acid in xylene and its interaction with asphaltenes by isothermal titration calorimetry

Wei

Orlandi

Barriet

et al. 2015

J Therm Anal Calorim

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“…Once in contact with an aqueous phase, water-soluble hydrocarbons in the crude oil will partition into the water phase [22][23][24] , adsorb at the gas-water interfaces and influence the oil removal efficiency by gas flotation [25][26] . The characteristics of the produced water also depends on the properties, like pH [27][28] , ionic strength 29 and the presence of divalent ions 30 .…”

Section: Introductionmentioning

confidence: 99%

Influence of the Crude Oil and Water Compositions on the Quality of Synthetic Produced Water

2017

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Produced water originates from the crude oil production. It is a mixture of organic and inorganic compounds and its composition is highly oilfield-dependent. The present study was carried out to increase the understanding of the relations between the crude oil properties and the composition of the aqueous phase on the produced water quality. Brines with different compositions and pH levels were mixed with five crude oils. Initially, the physicochemical properties and composition of the crude oils were determined, while the quality of the synthetic produced water samples were described by parameters such as the total oil concentration and organic carbon, pH, the drop size distribution and the Sauter mean diameter. The characterization part revealed that crude oils fell into two categories: light and heavier oils. 2 Most parameters like density, viscosity, total acid number (TAN) or composition reflected this division. A similar pattern was sustained for the water quality analyses. Water produced with heavier crude oils generally contained higher concentration of emulsified oil with the biggest and most polydispersed droplets. Light oils had a tendency to create water-in-oil emulsion between the oil and water phase, which impeded the phase separation, resulting in less free water. The Sauter mean drop diameters increased with pH of the water phase. However, the presence of calcium at the highest pH decreased the droplet size and the amount of free water, compared to the brine without divalent ions, which is in agreement with the interfacial role of the naphthenic acids in the crude oil emulsions. The results showed the significance of both the water and oil composition on the quality of the produced water. This can lead to improved fundamental perception of the produced water treatment process.

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“…10 Chemical structures of some monomeric, copolymeric and terpolymeric naphthenate inhibitors necessary not only to ascertain the efficiency of the product but to estimate the dosage for field tests and evaluate its compatibility with other production chemicals such as corrosion inhibitors and scale inhibitors. Bottle test remains a popular method for screening of naphthenate inhibitors, but there are several other methods including interfacial shear/ dilational rheometry, pendant drop tensiometry, gravimetry, Langmuir balance technique, light-scattering near-infrared spectroscopy and dynamic flow tests (Subramanian et al 2017;Debord and Srivastava 2009;Hanneseth et al 2006;Havre 2004;Brandal et al 2004Brandal et al , 2006Rosseau et al 2001).…”

Section: Inhibitor Screening and Management Of Compatibility Issuesmentioning

confidence: 99%

“…Surface pressure-area isotherm of tetraacid at different pHs(Brandal et al 2006) Interfacial film stability (at constant surface pressure) of tetraacid at different pHs(Brandal et al 2006). [A/A 0 ] is the loss in interfacial area Effect of pH on interfacial tension of biphasic system containing tetraacid(Brandal et al 2006) Surface pressure-area isotherm of a synthetic naphthenic acid at different Ca 2+ concentrations (pH 5.6)(Havre et al 2002)Fig. 7…”

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confidence: 99%

Oilfield metal naphthenate formation and mitigation measures: a review

Eke

Victor-Oji

Akaranta

2019

J Petrol Explor Prod Technol

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Process facilities for the separation of hydrocarbons from produced water in the oilfield are critical to flow assurance, product quality and environmental compliance. The formation of metal naphthenates, which are emulsion stabilizers and equipment foulers, is deleterious to performance and integrity of these processes and facilities. Manual removal of deposits of these organic salts formed at the oil-water interface during separation processes is difficult and expensive; hence, the best operational option is inhibition. The conventional method for the inhibition of metal naphthenates, which relies on suppressing the deprotonation of naphthenic acids by common ion effect, is no longer tenable because it exacerbates internal corrosion problems in topside facilities. Current industry focus is on the development of effective surface active agents for inhibition of naphthenates. There are a plethora of chemical compounds with naphthenate inhibition potential such as sulphonates, phosphate esters, aminated phosphonates and sulphosuccinates, but compatibility issues make the choice of inhibitor a complicated process. In this paper, the drivers and mechanism of oilfield metal naphthenate formation are reviewed. Surfactants for oilfield metal naphthenate inhibition and the mechanisms of inhibition are highlighted with a view to process optimization.

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Isolation and Characterization of Naphthenic Acids from a Metal Naphthenate Deposit: Molecular Properties at Oil‐Water and Air‐Water Interfaces

Cited by 75 publications

References 51 publications

Aggregation of tetrameric acid in xylene and its interaction with asphaltenes by isothermal titration calorimetry

Aggregation of tetrameric acid in xylene and its interaction with asphaltenes by isothermal titration calorimetry

Influence of the Crude Oil and Water Compositions on the Quality of Synthetic Produced Water

Oilfield metal naphthenate formation and mitigation measures: a review

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