Extra-heavy Crude Oil Research Articles

Combustion behavior and effluent liquid properties in extra-heavy crude oil reservoirs developed by steam huff and puff

In recent years, interest in in-situ combustion (ISC) as an alternative technique for extra-heavy crude oil reservoirs subjected to steam huff and puff has grown significantly; however, the ISC behavior and effluent liquid properties in such oil reservoirs remain under-explored. In this work, the combustion tube (CT) was used to investigate the combustion behavior of extra-heavy crude oil. Also, the effluent liquid properties during ISC were analyzed comprehensively. The results revealed that when the secondary water bodies (SWB) were present at the injection end of CT, a stable combustion front advanced, causing a gradual temperature rise and a CO2 concentration above 12 % in the effluent gas. This suggested that steam injection wells in these reservoirs were suitable candidates for subsequent air injection after steam huff and puff. Conversely, when the SWB was located at the production end of CT, the peak temperature of combustion decreased, indicating a transition to medium-temperature combustion and unstable combustion front advancement, making steam injection wells unsuitable for ISC as production ones. Three key criteria for evaluating ISC effectiveness in extra-heavy crude oil were: (1) the intensity of –CH2 and –CH3 peaks, (2) the C-O absorption peak between 1100 and 1000 cm−1, and (3) the distribution of characteristic peaks around 750 cm−1. A significant decrease in these peaks indicated high-temperature combustion and substantial oil upgrading. Also, the presence of alkynes suggested extensive thermal cracking and a stable combustion front. The anion concentration of effluent water increased compared to crude water, but the relationship between water ion concentration and combustion state was weak, without a discernible pattern.

Transforming Petrochemical Processes: Cutting-Edge Advances in Kaolin Catalyst Fabrication

The depletion of conventional light petroleum reserves has intensified the search for alternative sources, notably, low-quality heavy oils and byproducts from heavy crude processing, to meet the global demand for fuels, energy, and petrochemicals. Heavy crude oil (HO) and extra heavy crude oil (EHO) represent nearly 70% of the world’s reserves but require extensive upgrading to satisfy refining and petrochemical specifications. Their high asphaltene content results in elevated viscosity and reduced API gravity, posing significant challenges in extraction, transportation, and refining. Advanced catalytic approaches are crucial for efficient asphaltene removal and the conversion of heavy feedstocks into valuable light fractions. Kaolin, an aluminosilicate mineral, has emerged as a key precursor for zeolite synthesis and a promising catalyst in upgrading processes. This article provides a comprehensive exploration of kaolin’s geological origins, chemical properties, and structural characteristics, as well as the various modification techniques designed to improve its catalytic performance. Special focus is given to its application in the transformation of heavy crudes, particularly in facilitating asphaltene breakdown and enhancing light distillate yields. Finally, future research avenues and potential developments in kaolin-based catalysis are discussed, emphasizing its vital role in addressing the technological challenges linked to the growing reliance on heavier crude resources.

Pilot-scale study of methane-assisted catalytic bitumen partial upgrading

The direct utilization of heavy and extra-heavy crude oils presents a formidable challenge due to their inherent physical and chemical properties such as high C/H ratio, extremely high viscosity and density, low APIo, super low mobility, high asphaltene and impurity (Fe, Ni, Co, S, N, etc.) contents. To tackle these problems cost-effectively, we have proposed and established a novel technique, distinct from conventional hydrotreating, for catalytic partial upgrading of extra heavy crudes with co-fed methane and a multi-functional catalyst. This technique has been further optimized using lab-scale batch reactors (100 mL, 300 mL), bench-scale and pilot-scale fixed bed reactors with their processing capacity of 250 mL/day and 20 L/day, respectively. The feasibility, stability, and profitability of this technique have been successfully verified using all these facilities and a wide variety of feedstock. Yet, further scale-up is necessary to advance this technique towards commercialization in industry. In this study, a pilot-scale prototype unit (processing capacity of 1 barrel/day) was designed and manufactured based upon the previous achievements, and a bitumen sample recovered from the Steam Assisted Gravity Drainage (SAGD) process was chosen as a typical extra heavy crude for the upgrading. A 30-day upgrading has been conducted smoothly without clogging and a liquid yield of 96.7 % was observed with remarkable enhancements in product quality. The notable decreases in density, viscosity, TAN, asphaltene content, and sulfur content were confirmed and consistent with previous results. A low olefin content implies excellent stability and compatibility of the liquid product. Additionally, a preliminary TEA (Techno-Economic Assessment) and LCA (Life-Cycle Analysis) have been conducted and the beneficial features of this novel technique have been confirmed with higher profitability, lower cost, and lower carbon footprint. This study further consolidates the advantages of this promising technique as a cost-effective and environmentally friendly alternative to hydrotreating for processing extra heavy crudes.

Sulfured FeMo carbides and nitrides catalysts upgrade extra heavy crude oil quality

In the context of the energy transition scenario, effective sulfur management is crucial. Enhancing the quality of extra heavy crude oil (EHCO) through catalytic processes, specifically hydrotreatment, is essential for reducing pollutant emissions like SOx into the atmosphere. Traditional hydrotreatment, utilizing MoS2-based catalysts typically on Al2O3 support, faces challenges with EHCO due to its elevated S and N content, which hampers catalyst efficiency. Metal carbides and nitrides exhibit promising electronic structures that confer resistance to deactivation in the presence of heteroatoms. This study compares the catalytic performances of Fe-promoted Mo sulfides, carbides, and nitrides (FeMoS(C,N)) in the thiophene hydrodesulfurization (HDS) reaction, serving as a model molecule for sulfur removal. Subsequently, we investigate the upgrading of a Venezuelan EHCO in terms of pollutant reduction, API gravity, and feedstock aromaticity. Catalysts were prepared from oxide precursors, varying the (Fe/(Fe+Mo)) atomic ratios (x = 0.00, 0.10, 0.33, 0.50, and 1.00), employing a temperature-programmed reaction protocol. Catalytic upgrading of EHCO was conducted in a stirred batch reactor, and the results were compared with a commercial CoMo-based catalyst. FeMoC(N) outperformed the commercial catalyst in sulfur removal. The elemental composition and nitrogen content of the feed remained constant; however, the sulfur content of asphaltenes decreased. Furthermore, the API gravity of crude oil increased when employing FeMoS and FeMoN catalysts, except with FeMoC, possibly linked to dealkylation reactions and the enrichment of lighter fractions with alkanes. FeMoN increased asphaltene aromaticity, while FeMoC decreased it. These results highlight the promise of FeMoC(N) as catalysts for HDS and upgrading heavy feedstocks.

Processing and Recovery of Heavy Crude Oil Using an HPA-Ni Catalyst and Natural Gas.

To maintain economic profitability and stabilize fuel prices, refineries actively explore alternatives for efficiently processing (extra) heavy crude oils. These oils are challenging to process due to their complex composition, which includes significant quantities of asphaltenes, resins, and sulfur and nitrogen heteroatoms. A critical initial step in upgrading these oils is the hydrogenation of polyaromatic compounds, requiring substantial hydrogen sources. Methane from natural gas streams is known to act as an effective hydrogen donor. This study investigates the use of a heteropolyacid (HPA) catalyst modified with nickel and methane to enhance the quality of heavy crude oil with an initial 8.0°API (at 15.5 °C) and 2200 cSt viscosity (at 37.5 °C). After treatment in a batch reactor at 380 °C and 4.4 MPa for 2 h, the oil properties markedly improved: API gravity increased from 8.0 to 16.0 (at 15.5 °C), and kinematic viscosity reduced from 2200 to 125 cSt (at 37.5 °C). Additionally, there was a significant decrease in asphaltenes (from 38.7 to 16.4% by weight), sulfur (from 5.9 to 4.0% by weight), and nitrogen (from 971 to 695 ppm). This was accompanied by an increase in the volume of light distillates from 1.3 to 4.9%, and middle distillates from 8.8 to 21.0%. These results suggest that nickel-modified HPA catalysts, combined with methane as a hydrogen donor, are a promising option for upgrading heavy crude oils.

Insights into water-lubricated transport of heavy and extra-heavy oils: Application of CFD, RSM, and metaheuristic optimized machine learning models

With diminishing light crude oil reserves, the focus shifts to heavy and extra-heavy crude oil, posing challenges with high viscosity impeding flow. Water-lubricated technology addresses this issue in oil transmission lines. This study introduces a novel method integrating response surface methodology (RSM), computational fluid dynamics (CFD), and optimized machine learning (ML) models to analyze pipeline pressure gradients (PG) in oil–water two-phase flows downstream of T-junctions. The present study uses the D-optimal technique for simulation design to optimize CFD computational demands efficiently. This study breaks new ground by proposing a framework that leverages support vector machines (SVMs). The proposed framework incorporates metaheuristic optimization algorithms (genetic algorithm (GA) and particle swarm optimization (PSO)) to achieve superior PG prediction accuracy. The optimized ML models outperformed RSM models for predicting PG. Results indicated that oil-to-water viscosity ratio and oil inlet velocity significantly affect PG, followed by water inlet velocity and surface tension between phases. In contrast, the oil-to-water density ratio, oil entry angle at the T-junction, and wall contact angle have minimal impact. Furthermore, statistical metrics and visual comparison tools identified the PSO-optimized SVM model based on linear kernel function as the most effective (MAPE = 13.2 % and R = 0.9949). The hybrid methodology presented in this research holds significant promise for optimizing heavy oil transfer efficiency in applications involving water-lubricated technologies.

Viability of the steam-based extraction of extra-heavy crude oil using nanoparticles: Exergy and life-cycle assessment

The growing energy demand has prompted the research community to seek more efficient and sustainable resource extraction methods, particularly in the case of crude oil. Investigating the potential of nanotechnology to enhance crude-oil recovery from extra-heavy and heavy crude-oil reserves is crucial for optimizing resource utilization, improving economic viability, minimizing environmental impacts, driving technological advancement, ensuring energy security, and meeting market demands. In this study, we investigated the implementation of exergy analysis (ExA) on nanotechnology in oil-recovery processes, which has not previously been explored. This involved a life-cycle assessment (LCA) to evaluate the environmental impacts and to complement the ExA in order to optimize operations. To environmentally and thermodynamically analyze the extraction process of extra-heavy crude oil, four scenarios were evaluated: i) steam injection at 0.5 quality; ii) steam injection at 1.0 quality; iii) steam injection at 0.5 quality with 500 mg L−1 of nanoparticles; and iv) steam injection at 1.0 quality with 500 mg L−1 of nanoparticles. The nanofluids used (AlNi1 and AlNi1Pd1) consisted of 500 mg L−1 of alumina (Al2O3) doped with a 1.0 % mass fraction of nickel (Ni) (i.e., AlNi1), and the same amount of alumina doped with a 1.0 % mass fraction of Ni and palladium (Pd) (i.e., AlNi1Pd1). Both nanofluids were supplemented with 1000 mg L−1 of Tween 80. The experiments were conducted in a laboratory and numerical simulation was used to upscale the different scenarios. Considering the equilibrium K-values model, a multiphase/multicomponent flow model coupled with an energy transport equation was utilized. Nanocatalyst transport, as per the experimental data, involved non-equilibrium transference between the liquid phases and the rock surface. The laboratory data were used to calibrate the model, which was then scaled up to reservoir conditions to estimate the oil recovery obtained from deploying in-situ upgrading processes at the field scale. Exergy calculations were performed on the involved flows and porous media in order to assess the crude-oil quality throughout the process. An LCA was implemented to evaluate the reduction in environmental impact achieved by using steam injection at X = 1.0 quality, with and without nanoparticles. The results of the ExA showed that using nanoparticles allowed crude oil with a higher energy quality to be obtained. Furthermore, the ExA showed that the increase in steam quality had a more significant effect on the exergy destroyed in the process than the use of nanomaterials, demonstrating the good performance of the proposed technology. Environmental analyses showed that marine ecotoxicity, urban land occupation, particulate matter formation, and global warming potential were the most-impacted categories, significantly contributing to total environmental impacts, after the fossil depletion impact category for all scenarios. In conclusion, using bimetallic nanoparticles in crude-oil extraction produces a better product with better energy and environmental performance.

Pt–Mo/MWCNT catalysts for desulfurization of extra-heavy crude oil at low temperature

AbstractPt–Mo nanoparticles supported by MWCNT were synthesized by wet impregnation and applied to desulfurize extra-heavy crude oil. Structural, morphological, and chemical characterizations confirmed uniform dispersion of Pt and Mo on MWCNT surfaces. The Pt–Mo nanoparticles had crystallite sizes ranging from 1.7 to 28 nm. The catalysts were used in the aquathermolysis of UTSIL crude oil, showing good stability and activity. Sulfur was reduced by 50% at 50°C and 80% at 100°C. FT-IR spectroscopy revealed the formation of hydrogenated aromatic rings and a decrease in sulfonic groups during desulfurization. Graphical abstract

New Trends for Hydrogen Sulfide Scavenging Using Natural Compounds as Biogenic Amines.

Hydrogen sulfide (H2S) mitigation through the use of additives in a laboratory-scale evaluation of steam injection in batch reactors was studied using extra heavy crude oil. For this purpose, additives based on biogenic amines from a fishing effluent were used with methanol and ethanol as solvents in a previous extraction of industrial fishmeal waste. The study of the extracts using high-performance liquid chromatography (HPLC) permitted the determination that the methanol-based extract with 48 h of decomposition had the highest biogenic amine content, totaling 1472 ppm. In addition, methanol extractions were more efficient, with an average biogenic amine content of 592 ppm. Subsequent evaluations were carried out for sand/oil/water/scavenging additive systems, where solutions of commercial organic compounds, analytical-grade histamine, and biogenic amine extracts were used. These evaluations were performed at a constant temperature of 247 °C and under an initial pressurization of methane gas of 215 psig, with a reaction time of 24 h. Characterization of gaseous effluents for each system allowed us to determine that the methods in which biogenic amine extracts were used with methanol were more effective in H2S scavenging because they had the lowest gas concentration at the end of the reaction time. Within this group, the most effective was the C1 extract, with a H2S reduction from 1700 to 150 ppm, representing 91% removal. The biogenic amine family produced by decomposition in conjunction with histamine has a synergistic effect in tests under vapor injection conditions when comparing the results with analytical-grade histamine solution-based additives and commercial additives. This study shows that using steam injection technology to use biogenic amines in H2S mitigation is feasible.

Sandpack flooding of microwave absorbent nanofluids under electromagnetic radiation: an experimental study

AbstractElectromagnetic (EM) radiation has long been recognized as an effective method for enhancing the quality and recovery of heavy and extra-heavy crude oil. The incorporation of EM absorbers, particularly nanoparticles, has demonstrated significant potential to boost efficiency and expand the stimulated reservoir volume. However, the application of simultaneous EM radiation and nanofluid injection in a natural porous medium, which is critical for the successful implementation of this approach in field-scale operations, remains an underexplored frontier. In this context, this research represents a pioneering endeavor, aiming to bridge this knowledge gap through a comprehensive statistical and optimization study. The primary objective was to unravel the intricate interplay between five distinct types of magnetic nanoparticles and their concentrations within the base fluid to improve oil production. Notably, it focused on iron oxide (Fe3O4) magnetic nanoparticles and their innovative hybridization with multi-walled carbon nanotubes (MWCNT) and nickel oxide (NiO) nanomaterial. A newly designed glass sandpack was employed as the porous medium, thus mirroring real reservoir conditions more accurately. Then, a rigorous full factorial design scrutinized the multifaceted effects of nanoparticle type and concentration when introduced into deionized water during this process. The results showed that microwave radiation, applied at 400 W, dramatically improved oil recovery, catapulting it from a baseline of 19% to an impressive 39.5% during water injection. The addition of magnetic nanoparticles to the base fluid enhances efficiency. However, the specific type of nanoparticle exerts varying effects on oil recovery rates. Notably, the synthesis of Fe3O4–MWCNT nanoparticles had a substantial impact on the ultimate oil recovery factor, achieving approximately 69%. Furthermore, the hybridization of Fe3O4 nanoparticles with MWCNT and NiO nanoparticles leads to reduced consumption (using low weight percentages) while achieving the highest oil recovery rates during the injection process. Finally, the optimization analysis demonstrated that employing 0.34 wt.% of Fe3O4–MWCNT nanoparticles under 400 W of microwave radiation represents the optimal condition for achieving the highest oil production in a sandpack porous medium. Under these conditions, the oil recovery factor can increase to 78%.

Water-Soluble Catalysts Based on Nickel and Iron for In Situ Catalytic Upgrading of Boca de Jaruco High-Sulfur Extra-Heavy Crude Oil

Water-Soluble Catalysts Based on Nickel and Iron for In Situ Catalytic Upgrading of Boca de Jaruco High-Sulfur Extra-Heavy Crude Oil

Development of a highly tolerant bacterial consortium for asphaltene biodegradation in soils

Asphaltenes are the most polar and heavy fraction of petroleum, and their complex structure and toxicity make them resistant to biodegradation. The ability to tolerate high asphaltene concentrations is crucial to reducing the toxicity-related inhibition of microbial growth and improving their capacity for adaptation, survival, and biodegradation in soils highly contaminated with asphaltenes. This study developed a highly tolerant consortium for efficient asphaltene biodegradation in soils from 22 bacterial isolates obtained from heavy-crude oil-contaminated soils. Isolates corresponded to the Rhodococcus, Bacillus, Stutzerimonas, Cellulosimicrobium, Pseudomonas, and Paenibacillus genera, among others, and used pure asphaltenes and heavy crude oil as the only carbon sources. Surface plate assays were used to evaluate the tolerance of individual isolates to asphaltenes, and the results showed variations in the extension and inhibition rates with maximum tolerance levels at 60,000 mg asphaltenes l−1. Inhibition assays were used to select non-antagonistic bacterial isolates among those showing the highest tolerance levels to asphaltenes. A consortium made up of the five most tolerant and non-antagonistic bacterial isolates was able to degrade up to 83 wt.% out of 10,000 mg asphaltenes kg−1 in the soil after 52 days. Due to its biological compatibility, high asphaltene tolerance, and ability to utilise it as a source of energy, the degrading consortium developed in this work has shown a high potential for soil bioremediation and is a promising candidate for the treatment of aged soil areas contaminated with heavy and extra-heavy crude oil. This would be the first research to assess and consider extreme bacterial tolerance and microbial antagonism between individual degrading microbes, leading to the development of an improved consortium capable of efficiently degrading high amounts of asphaltenes in soil.

Investigations into extra-heavy crude oil pyrolysis under non-isothermal conditions: thermal characteristics, kinetics, and thermodynamic parameters

This study comprehensively investigated the pyrolysis characteristics, kinetics, and thermodynamic parameters of extra-heavy oil through thermogravimetry (TG) experiments. The TG results revealed a two-stage pyrolysis process, consisting of light-temperature pyrolysis (LTP) and high-temperature pyrolysis (HTP), in which the HTP was the primary mass loss interval, contributing roughly 53.5% of mass loss from 370 to 500 °C. The pyrolysis kinetics were obtained using Ozawa-Flynn-Wall (OFW) and Friedman methods. The results revealed that the main pyrolysis reaction mechanism shifted from volatilization to thermal cracking while the conversion degree exceeded 0.35. The thermodynamic parameters, including enthalpy (ΔH), Gibbs free energy (ΔG), and entropy (ΔS), were also calculated. The thermodynamic features showed that the pyrolysis process absorbed large amounts of energy to change the main reaction mechanism in the range of α = 0.4–0.6, and altered from an organized to a disordered state due to the disruption of intramolecular structure induced by the formation of coke while the conversion degree exceeded 0.6. These findings have the potential to offer a thorough comprehension of the pyrolysis mechanism of extra-heavy oil.

Viscosity Bioreducer Temperature and Concentration Effect on Pressure Drop in Extra Heavy Crude Oil

Viscosity Bioreducer Temperature and Concentration Effect on Pressure Drop in Extra Heavy Crude Oil

Prospective electric heavy oil upgrading at ambient pressure by high energy electron beam

To alleviate increasing problems of greenhouse gas emissions, two approaches should be deployed: the development of sustainable energy technologies such as wind and solar to reduce the share of fossil fuels, and greener refining and upgrading technologies of fossil/bio-fuels. Here, we introduce an electric method that uses high energy electron beam to achieve heavy oil upgrading in a methane environment at ambient pressure with nearly zero GHG emissions. Two extra-heavy crude oil samples were treated by the electron beam at different conditions. Conversion and yields to gasoline and diesel range fuels were quantified. Detailed economic analysis shown that using low specific energy input (SEI or dose), 500 kJ/kg, <$1.5/barrel, this upgrading process converts heavy fractions (>C40, ∼20 $/barrel) to stable intermediate products (C10–C24, ∼75 $/barrel) in diesel range. No coke was found in treated oil. Product yields (C10–C24) were ∼9 molecules/100 eV, comparable with thermal methods. Sufficient product separation is crucial to the success of this method. This method is electrically driven, easily adaptable to renewable intermittent electricity. It has potentially zero GHG emissions, and is attractive for on-site upgrading of heavy/bio fuels and integration with distributed renewable energy.

Catalytic In-Situ Upgrading of Heavy and Extra-Heavy Crude Oils

Catalytic In-Situ Upgrading of Heavy and Extra-Heavy Crude Oils

A new correlation to calculate the viscosity of binary mixtures of heavy or extra-heavy crude oil and light hydrocarbons using the Arrhenius-Lederer equation

Heavy crude oils are commonly mixed with lighter crude oils to reduce heavy oil viscosity and to ensure the flow through the pipeline system. Viscosity, as is well known, is a crucial property for designing and sizing offshore and onshore facilities for producing and transporting crude oil. When not available experimentally, the viscosity of mixed crudes can be obtained from theoretical approaches such as the Arrhenius-Lederer equation depending only on bulk properties (density and viscosity) of mixture components, and an adjustable parameter (α), which allows calculations to match experimental data. This work presents a new correlation for calculating the rescaled parameter proposed by Lederer for the Arrhenius equation to determine the viscosity mixtures of heavy and light hydrocarbons. The proposed correlation was developed considering experimental data of binary mixtures of paraffinic hydrocarbons, diesel, and heavy oil over a wide range of temperature conditions (from 293 to 343 K), fluid density ratios (from 1.014 to 1.40), and viscosity ratios (1.3 to 311,000). For viscous fluids, which exhibited non-Newtonian behavior, viscosity on the first Newtonian region is considered. The correlation was tested to predict the viscosity of biodiesel-diesel, heavy crude oil-diesel, bitumen-heptane, and eicosane-decane binary mixtures from 308 to 448 K and pressures up to 10 MPa. Finally, for assessing the predictive capabilities of the new correlation, the viscosity of several mixtures was estimated. The first consisted of mixtures formed by three oils at different compositions, whereas the last consisted of a recombined live oil and supercritical CO2. Predicted viscosities are in better agreement with experimental data than those estimated from Shu’s correlation. The total mean absolute percentage error was 6.66 and 19.32 for the proposed and the Shu correlation, respectively.

Extra heavy crude oil viscosity and surface tension behavior using a flow enhancer and water at different temperatures conditions

Research reports reveal the importance of applying various substances to enhance extra-heavy crude oil pipeline transportation. During the crude oil conduction process, shearing occurs in the equipment and pipe accessories, producing a water-in-crude emulsion associated with forming a rigid film by adsorbing natural surfactant molecules in the droplets water, leading to increased Viscosity. This study presents the effect of a flow enhancer (FE) on the behavior of the Viscosity of an extra heavy crude oil (EHCO) and in emulsions formed with 5% and 10% water (W). The results revealed the effectiveness of the 1%, 3%, and 5% flow enhancer in lowering the Viscosity and presenting a Newtonian flow behavior which will help reduce the cost of heat treatment during the transportation of crude oil through the pipeline.

Study of Bulk Properties Relation to SARA Composition Data of Various Vacuum Residues Employing Intercriteria Analysis

Twenty-two straight run vacuum residues extracted from extra light, light, medium, heavy, and extra heavy crude oils and nine different hydrocracked vacuum residues were characterized for their bulk properties and SARA composition using four and eight fractions (SAR-ADTM) methods. Intercriteria analysis was employed to determine the statistically meaningful relations between the SARA composition data and the bulk properties. The determined strong relations were modeled using the computer algebra system Maple and NLPSolve with the Modified Newton Iterative Method. It was found that the SAR-ADTM saturates, and the sum of the contents of saturates and ARO-1 can be predicted from vacuum residue density, while the SAR-ADTM asphaltene fraction content, and the sum of asphaltenes, and resins contents correlate with the softening point of the straight run vacuum residues. The softening point of hydrocracked vacuum residues was found to strongly negatively correlates with SAR-ADTM Aro-1 fraction, and strongly positively correlates with SAR-ADTM Aro-3 fraction. While in the straight run vacuum residues, the softening point is controlled by the content of SAR-ADTM asphaltene fraction in the H-Oil hydrocracked vacuum residues, the softening point is controlled by the content of SAR-ADTM Aro-3 fraction content. During high severity H-Oil operation, resulting in higher conversion, hydrocracked vacuum residue with higher SAR-ADTM Aro-3 fraction content is obtained, which makes it harder and more brittle.

Measurements of the Density and Viscosity of Heavy Oil and Water-in-Oil Emulsions Over a Wide Temperature Range

Density and dynamic viscosity of extra viscous heavy crude oil and water-in-oil (W/O) suspensions based on Ashalchinskaya (Tatarstan, Russian Federation) oil have been measured as a function of temperature and concentration of water at atmospheric pressure. The measurements were made at temperatures from (293 to 463) for density and from (293 to 367) K for viscosity with various concentrations of water (from 0 % to 30 % volume fraction). Measurements were made using modified hydrostatic weighing for density and falling body techniques for viscosity. The combined expanded uncertainty of the density, viscosity, pressure, and temperature measurements at 0.95 confidence level with a coverage factor of k = 2 is estimated to be $$U\left( \rho \right)$$ = 0.16 % and $$U\left( \eta \right)$$ = 1.0 %, $$U\left( P \right)$$ = 1.0 %, and $$U\left( T \right)$$ = 0.02 K, respectively. The reliability and accuracy of the new experimental method and correct operation of the modified experimental apparatus was confirmed with measurements using different methods (pycnometric, capillary flow, commercial standard instruments, Brookfield rotational viscometer). The effect of temperature and concentration of water on the measured values of density and viscosity of W/O suspensions were studied. Using crude dry oil, the effective viscosities of several synthetic W/O emulsions are measured at atmospheric pressure using a commercial standard instrument, Brookfield rotational viscometer and falling body technique for different shear rates, temperatures and volume fractions of the dispersed phase. The various correlation equations for describing viscosity as a function of temperature and dispersed phase volume fraction is developed. A number of factors such as water content, shear rate, shear stress, and temperature and their effects on the density and dynamic viscosity of dry crude oil and W/O emulsions were assessed.