Interfacial Behavior of Naphthenic Acids and Multivalent Cations in Systems with Oil and Water. I. A Pendant Drop Study of Interactions Between<i>n</i>‐Dodecyl Benzoic Acid and Divalent Cations

Brandal, Øystein; Sjöblom, Johan; Øye, Gisle

doi:10.1081/dis-120037687

Cited by 55 publications

(56 citation statements)

References 21 publications

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“…The rest of the studied brine solutions (higher CaCl 2 salinities and Na 2 SO 4 ) not only did not alter the wettability of the sample to water-wet but some of them turned the limestone sample to more oil wet. Several studies conducted on the forces between carboxylic acid coated surfaces in divalent electrolyte solutions (Brandal et al, 2004;Brandal and Sjoblom, 2005a;Brandal et al, 2005b;Ederth and Claesson, 2000) proved that multivalent cations in solution, especially Ca +2 , have high affinity towards the carboxylic groups. All of the measurements were conducted at the ambient temperature and therefore, the effect of higher temperatures on wettability was not considered in this study.…”

Section: Results For Indiana Limestone Samplesmentioning

confidence: 99%

Wettability Alteration of Carbonates by Optimizing the Brine and Surfactant Composition

et al. 2012

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It is well known that the majority of carbonate reservoirs are neutral to oil-wet. This leads to much lower oil recovery during waterflooding since there is no spontaneous imbibition of water in heterogeneous reservoir displacement. It has been verified by a number of researchers that Adjustment of ion concentration in brine solutions, or adding surfactant solutions can enhance the oil recovery by altering the wettability. In the published literature, contact angle studies usually refer to measurement on calcite crystals and there are no results for the contact angle of carbonate porous media representative of reservoir rocks. Moreover, there are few studies on the effect of non-ionic surfactants, compared to those for ionic surfactants. Understanding the effect of various ions and their concentration in the injection brine on the wettability of the Limestone outcrop core samples is the first step for tailoring of the optimum injection brine. This will be followed by a study of the effect of surfactant on the wettability of calcite crystal samples. The evaluation of the results may provide guidelines for the design of injection brines for efficient enhanced oil recovery from carbonate reservoirs. In this work, a procedure is established for the measurement of the contact angle on limestone outcrop core samples. Results showed that, at atmospheric conditions, low salinity CaCl 2 solution induced the most significant improvement on the wettability of the outcrop sample. Moreover, among all the non-ionic surfactants studied, only the presence of the two first members of the 15S analogous series might lead to a slight decrease of the contact angle.

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Section: Results For Indiana Limestone Samplesmentioning

confidence: 99%

Wettability Alteration of Carbonates by Optimizing the Brine and Surfactant Composition

et al. 2012

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“…[27] Thus, from the observations and explanations above, the effects of pH, counterions, and acid structure on the film stability may be summarized in the following way: . As described in the theory part, the binding strength between the compounds is also fixed by the degree of hydration of the cations; the more water of hydration that surrounds the cation the less preferable it is to be located at a water-oil interface.…”

Section: Resultsmentioning

confidence: 99%

Interfacial Behavior of Naphthenic Acids and Multivalent Cations in Systems with Oil and Water. II: Formation and Stability of Metal Naphthenate Films at Oil‐Water Interfaces

Brandal

Sjöblom

2005

Journal of Dispersion Science and Technology

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The stability of interfacial naphthenate films of three synthetic naphthenic acids and four different divalent cations is measured by means of the Langmuir technique with a trough for liquid-liquid systems. The chloride salts of Ca 21 , Mg 21 , Sr 21 , and Ba 21 were dissolved in water at two different pH levels: ultrapure water (pH 5.6) and buffered ultrapure water at pH 8.0. The water phase was covered by the oil phase consisting of n-decane and dissolved naphthenic acid. The systems were then equilibrated for 45 minutes before the compression of the interfacial films was initiated.The results, plotted as interfacial pressure (IP) versus compression area, showed clear distinctions depending on acid structure, type of metal salt, and pH of the aqueous phase. The differences in film stability by introducing various salts are assumed to be a result of different degrees of hydration of metal cations, which according to the theory increases with decreasing cationic size. Raising the pH from 5.6 to 8.0 generally caused decreasing film stability due a higher ionization of the interfacial layer and a higher water solubility. Furthermore, introducing naphthenic acids with bulky structures increases the molecular distance, which in turn may hinder the monomers to be bound in 2 : 1 ratio with the divalent cations.

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“…IFT studies using a model naphthenic acid showed that the process of metal naphthenate formation is initiated by diffusion of the amphiphilic acid to the oil-water interface where it dissociates to the more interface-active anion (Brandal et al 2004). If the water phase contains cationic species, the extent to which IFT changes will depend on the nature and concentration of the cation in the water and naphthenic acid in oil.…”

Section: Identification Quantification and Characterization Of Naphtmentioning

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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Interfacial Behavior of Naphthenic Acids and Multivalent Cations in Systems with Oil and Water. I. A Pendant Drop Study of Interactions Betweenn‐Dodecyl Benzoic Acid and Divalent Cations

Cited by 55 publications

References 21 publications

Wettability Alteration of Carbonates by Optimizing the Brine and Surfactant Composition

Wettability Alteration of Carbonates by Optimizing the Brine and Surfactant Composition

Interfacial Behavior of Naphthenic Acids and Multivalent Cations in Systems with Oil and Water. II: Formation and Stability of Metal Naphthenate Films at Oil‐Water Interfaces

Oilfield metal naphthenate formation and mitigation measures: a review

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