Asphaltene, Naphthenic Acid, and Naphthenate Components of Some Crude Oil Samples and Their Impact on Production and Export

CHIKWE, TEMPLE N; Duru, Remy Ukachukwu

doi:10.22050/ijogst.2022.277619.1615

Asphaltene, Naphthenic Acid, and Naphthenate Components of Some Crude Oil Samples and Their Impact on Production and Export

Document Type : Research Paper

Authors

TEMPLE N CHIKWE ¹

Remy Ukachukwu Duru ²

¹ Assistant Professor, University of Port Harcourt, Nigeria

² Assistant Professor, Department of Pure and Industrial Chemistry, University of Port Harcourt, Nigeria

https://doi.org/10.22050/ijogst.2022.277619.1615

Abstract

The asphaltene and metal naphthenate components of crude oil samples from 10 wells within an oil reservoir were determined using different analytical techniques. The asphaltene content of the crude was determined by gravimetric analyses using American Standard for Testing and Material (ASTMD) 6560 to obtain its weight concentration. In contrast, the metal naphthenate components were determined by obtaining the metal ion concentration of the produced water and the naphthenic acid concentration of the crude using atomic absorption spectrometer (AAS) and potentiometric titration respectively. The results show that the asphaltene content of the crude samples ranges from 2.0000 to 8.000 wt %, while the naphthenic acid concentration indicated by the total acid number (TAN) ranges from 0.3000 to 1.4600 mg/KOH/g. All the crude samples possess asphaltene components and the propensity to form calcium and sodium naphthenate scale deposits with a Ca₂⁺ concentration between 32.5000 and 94.5000 mg/L and an Na⁺ concentration between 27.7 and 105.1 mg/L respectively. However, the formation of naphthenate scale deposits highly depends on the pH of the produced water of the crude, which makes well FT01 less likely to form naphthenate scales since it has a pH of less than 6; in other words, the produced water pH and availability of cations play an essential role in the formation of naphthenate scales. Calcium naphthenate scale formation is more favored at a brine pH higher than 6, while sodium scale formation is favored at a pH of approximately 8.5. An increase in produced water pH during crude oil production is usually caused by depressurization and CO₂ release. Both asphaltene and naphthenate deposits are directly proportional to the specific gravity of the crude and inversely proportional to the API gravity, implying that both components reduce the quality of the crude. Asphaltene and metal naphthenate solid deposits in the crude can cause many flow assurance difficulties, such as blocking expedition lines, pore plugging, wettability, crude oil parameter alteration, and reduction in oil recovery.

Highlights

The Asphaltene and metal naphthenate components of crude oil samples from ten different wells within an oil reservoir were determined using different analytical techniques.
The asphaltene content was determined by gravimetric analyses while the metal naphthenate components were determined by obtaining the metal ion concentration of the produced water and the naphthenic acid concentration of the crude using atomic absorption spectrometer (AAS) and potentiometric titration respectively
All the crude samples possess asphaltene components as well as the propensity to form calcium and sodium naphthenate scale deposits
The formation of naphthenate scale deposits is highly dependent on the pH of the produced water of the crude
Both asphaltene and naphthenate deposits are directly proportional to the specific gravity of the crude and inversely proportional to the API gravity implying that both components reduce the quality of the crude.

Keywords

Expedition line

Flocculation

Flow assurance

Precipitation

Reservoir

Scale deposits

Subjects

Hydrocarbon Reservoirs Management

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