Electromagnetic Viscometer Research Articles

THE QUALITY OF CRUDE OIL FROM THE MUANDA FIELD AND ITS CONSEQUENCES ON THE INSTALLATIONS

"The study on the quality of the crude oil of the Muanda field and its consequences on the installations, was carried out within the framework of our scientific research of study of Advanced Diploma (DEA). The objective of this study was to determine upstream the physical properties and composition of the Muanda field crude oil, in order to determine the conditions of asphaltene deposits in the tubing and other installations. To achieve this, the samples collected in the field were analysed in our laboratories and at the PVT Laboratory of Sonangol in Luanda to constitute the results of this manuscript. The results of these analyses show that the crude oil of the Muanda field is a Medium Crude Oil (29.7°API) on the API density scale with the hypothesis of two sources: one of Light Oil, the other of Medium Oil). These two sources of crude oil, induce the establishment of two oils of different viscosities and pour points of which one more viscous (Mu 23) and the other less viscous (Mu 16 and Mu 2) having the average pour point at 15° C (60°F). The Standing correlation gave acceptable results and close to those of the Electromagnetic Viscometer (EMV). The chemical composition showed that the crude oil is composed of 18.63% of gas and 81.37 % of Paraffins and Asphaltenes, and that this oil is of low sulfur content type (Low Sulfur Content (LSC) <0.6% weight). A solid sample collected from the oil field was characterized through melting, further heating and solidification point (28 oC). "

Predicting the Viscosity of Petroleum Emulsions Using Gene Expression Programming (GEP) and Response Surface Methodology (RSM)

This paper summarizes an investigation of certain operating parameters on the viscosity of petroleum emulsions. The production of crude oil is accompanied by emulsified water production, which comes along with various challenges like corroding the transport systems and catalysts poisoning during petroleum refining in the downstream. Several process variables are believed to affect the ease with which emulsified water can be separated from emulsions. Some of the issues have not been extensively examined in the literature. The simplicity with which water is separated from petroleum changes with age (after formation) of the emulsion; notwithstanding, this subject has not been investigated broadly in literature. This study tries to assess the correlation between aging time, water cut, crude oil viscosity, water viscosity and amount of solids and viscosity of petroleum emulsions. To achieve that, a response surface methodology (RSM) based on Box-Behnken design (BBD) was used to design the experiment. Synthetic emulsions were prepared from an Offshore Malaysian Crude oil based on the DoE design and were aged for 7 days. The emulsions viscosities were measured at 60-degree Celsius using an electromagnetic viscometer (EV100). The broad pressure and temperature range of the HPHT viscometer permit the imitation of acute conditions under which such emulsions may form. The data obtained from the RSM analysis was used to develop a prediction model using gene expression programming (GEP). It was discovered that the viscosity of water has no effect on the viscosities of the studied emulsions, as does the water cut and amount of solids. The most significant factor that affects emulsion viscosity is the aging time, with the emulsion becoming more viscous over time. This is believed to be imminent because of variations in the interfacial film structure. This is followed by the amount of solids, also believed to be as a result of increasing coverage at the interface of the water droplets, limiting the movements of the dispersed droplets (reduced coalescence), thereby increasing the viscosity of the emulsions.

Heavy Oil Viscosity Measurements: Best Practices and Guidelines

Viscosity is an important parameter in reservoir development, especially in heavy oil production, processing, and transportation. Accurate measurement (±5%) of heavy oil viscosities can be affected by sample handling, storage, and cleaning procedures. In addition, the type of viscometers and the corresponding experimental procedures can impact the accuracy of viscosity measurements. The objectives of this paper are to present the results of a systematic evaluation and comparison of different viscometers typically used in heavy oil viscosity measurements, provide references on the subject of viscometer selection, recommend developed measurement procedures for each viscometer, and generate a reliable viscosity database of dead and live heavy oils. The systematic study was performed using three viscometers typically used in heavy oil systems: a capillary viscometer (CV), an electromagnetic viscometer (EMV), and a rheometer (Rh). Viscosity measurements were performed over a range of temperature and pressure c...

Measurements and correlation of Mexican heavy dead crude oil viscosities

This work presents reliable measurements for dynamic viscosity of representative heavy oil samples from Mexican reservoirs. Most of the experimental data of dynamic viscosity were measured using a constant force electromagnetic viscometer. The viscometer was calibrated using several viscosity standards based on a maximum standard deviation of 0.5% in all measurements for the three pistons used. Dynamic viscosities of heavy dead crude oils were obtained at a temperature range from 397.1 to 300.8 K, viscosities in the range of 10.9–7476.7 cP, oil API gravity from 11.5 to 19.4, and at a constant pressure of 0.1 MPa. The estimated uncertainty on viscosity was less than ±1.0% over the temperature range of measurements. A new correlation approach was developed to estimate dynamic viscosities of Mexican heavy crude oils based on oil API gravity, and temperature.

High-Pressure Viscosity Measurements for the Binary System Cyclohexane +n-Hexadecane in the Temperature Range of (318.15 to 413.15) K†

The viscosities of binary mixtures of cyclohexane and n-hexadecane at high pressures were measured for six different compositions with an electromagnetic viscometer in the range of (6.90 to 62.05) MPa at temperatures varying from (318.15 to 413.15) K, extending the data of Tanaka et al. with a vibrating crystal viscometer and that of Wakeham and co-workers utilizing a vibrating wire viscometer, for higher temperatures. The data were correlated with the molar additive mixing rule using temperature-dependent Gaussian functions in pressure for pure component viscosities. At higher temperatures, the curvature of the viscosity−pressure function changes significantly with composition for this asymmetric mixture.