Behavior Of Asphaltenes Research Articles

Adsorption behavior and interfacial dilational properties of asphaltenes at the interface between n-decane/α-methylnaphthalene and brine water

As the complex component in crude oil, asphaltenes adsorb at the interface and exhibit unique interfacial properties, ruling the emulsifying properties and emulsion stability of produced fluid. Hence, this study deals with the adsorption behavior and interfacial dilational properties of asphaltenes. To investigate the adsorption behavior of asphaltenes, the dynamic interfacial tension is obtained with the pendant drop shape method at various concentrations and temperatures. Based on the adsorption kinetic equation, the adsorption behavior is found to be controlled by different mechanisms at different stages. The initial stage is dominated by the diffusion mechanism. Then, the adsorption process is gradually affected by diffusion and random sequential adsorption simultaneously. Finally, the controlling factor changes to the random sequential adsorption of adsorbed asphaltenes. A higher concentration of asphaltenes can accelerate the diffusion coefficient by increasing the concentration gradient, while the effect of temperature is weaker than concentration. Based on the experimental results, a new method is developed to quantify the influences of different mechanisms. After that, the droplet dilation experiment is carried out to probe the structural properties of the formed interfacial layer. By fitting the experimental data with the Langmuir equation of state, the average interfacial area occupied per asphaltene molecule is calculated. Finally, the emulsion stability experiments are carried out to support the conclusions in the interfacial experiments. This study enriches the adsorption kinetics theory of asphaltenes. It also contributes to the safe and economical transportation of produced fluid and rises the efficiency of demulsification.

Asphaltene aggregation studied by molecular dynamics simulations: role of the molecular architecture and solvents on the supramolecular or colloidal behavior

Asphaltene aggregation is a subject under vivid discussion: There are several parameters one needs to determine before its behavior can be mastered and better target solutions can be tailored. The nature of asphaltene aggregation (colloidal or supramolecular) and the role of solvents and their mixtures are among the least understood parameters in asphaltene science. This paper addresses molecular dynamic simulations to correlate the aggregation properties of asphaltenes, their molecular structure and the concentration of these solvents. We show that the formation of the nanoaggregate depends, primarily, on the size of the conjugated core and on the eventual presence of polar groups capable of forming H-bonds. Heteroatoms on the conjugated core do not change their shape or type of aggregation but may induce stronger uppi - uppi interactions. The macroaggregation formation depends upon the length of the lateral chains of asphaltenes and also on the presence of polar groups at its end. Moreover, n-heptane and water may interact selectively with asphaltenes in function of their molecular architecture. Given this fact and the aggregation behavior observed, we advocate toward the assumption that a colloidal behavior of asphaltenes might be a particular case of a more general model, based on a supramolecular description.

Microfluidic Study of the Deposition Dynamics of Asphaltene Subfractions Enriched with Island and Archipelago Motifs

Asphaltene-related flow assurance problems are prevalent in oil production processes and are at the heart of issues such as the plugging of pipelines, the damage of rock formations, and the stabilization of viscous water-in-oil emulsions. A comprehensive understanding of the interfacial behavior of asphaltenes, from a physical–chemical perspective, is required for an accurate design of solutions to these challenges. In this work, we elucidate the deposition dynamics of various asphaltene subfractions in a porous media microfluidic model. Extrography fractions from the interlaboratory sample known as PetroPhase 2017 asphaltenes, reported to be a mixture of abundant island and archipelago motifs, and Wyoming deposit C7 asphaltenes, known for being island type dominated, are investigated. The deposition rate increases when the compositional ratio archipelago/island motif increases for PetroPhase 2017 derived fractions, whereas Wyoming deposit asphaltenes appear to exhibit stronger aggregation for fractions w...

Magnetic treatment of petroleum and its relation with asphaltene aggregation onset (an atomistic investigation)

Magnetic treatment is often used in certain oil industries for alterations in petroleum rheological properties. In this report, we introduce the scientific basis for the role of magnetic treatment on the onset of asphaltenes aggregation from petroleum fluids. Molecular dynamics simulations are used to study the effect of magnetic fields that are applied to three different model asphaltenes (A1-A3) in paraffinic and aromatic oil media. Radial distribution functions, hydrogen bond interactions, and the simulation trajectories are produced and analyzed. Our simulation results show that the onset of asphaltene aggregation in petroleum fluids is affected by the magnetic field and it is a function of its strength. In a paraffinic medium, magnetic field reduced aggregation of the model asphaltenes studied in the range of 20–35%. Where magnetic field of 1.5T caused a high disruption of A1 aggregation and changed the dominated stacking. However, the highest disruption of A2 and A3 asphaltenes was at 1.0T. In an aromatic medium, magnetic field reduced association of the model asphaltenes studied in the range of 25–70%. Where 0.5T diminished the association of A2 and A3 asphaltenes while 1.0T was able to do that for A1 asphaltene. The stacking modes and distances between asphaltene molecules were also affected by magnetic field. For example, in paraffinic medium, 0.5T enhanced the aggregation of A1 and A2 asphaltenes with multiple-layer stacking where some of the peaks appeared farther than the reported cutoff of asphaltene stacking. Hydrogen bond results showed that magnetic fields did changes on the average number of hydrogen bonds. These changes were due to changes in the orientation and the distances between asphaltene molecules. The difference in asphaltene response to the magnetic treatment was due to the differences in their structures. Overall, the effect of magnetic field on the onset of asphaltene aggregation is dependent on the magnetic field strength, asphaltene architecture, and the medium. Results of this simulation are applicable to asphaltene behavior in real crude oil.

Systematic Investigation of Asphaltene Deposition in the Wellbore and Near-Wellbore Region of a Deepwater Oil Reservoir Under Gas Injection. Part 1: Thermodynamic Modeling of the Phase Behavior of Polydisperse Asphaltenes

Thermodynamic modeling is conducted for a high-asphaltene, high-resin crude oil produced from a deepwater reservoir using the perturbed-chain statistical associating fluid theory (PC-SAFT). The asp...

Determining the flocculation point of asphaltenes combining ultrasound and electrochemical impedance spectroscopy

The characterization of asphaltenes in heavy crude oil remains relevant as continuous extraction of conventional oil pushes industries to seek oil from new, unconventional sources. Unconventional crude oil contains a high concentration of asphaltenes, resulting in a very dense (22.3-10 °API) and viscous substance, which makes the handling and processing of this type of petroleum more challenging. The flocculation of asphaltenes is still a challenge to address during crude oil production, transportation, blending, and processing. Therefore, understanding the phase behavior of asphaltenes as well as their stability and physicochemical properties demands new and more practical characterization techniques capable of providing new insights into the asphaltene flocculation process. Current characterization techniques used to determine the flocculation point of asphaltenes in crude oil are primarily based on optical techniques and ex-situ methodologies. In this work, we propose, investigate, and provide preliminary results on a new approach aimed to determine the flocculation point of asphaltenes using electrochemical impedance spectroscopy (EIS) assisted by ultrasound (US). Our results show that the asphaltene flocculation process is significantly influenced by using US pulses, which promote the disaggregation of asphaltenes, thus allowing the determination of the flocculation point of asphaltenes via EIS.

Systematic Investigation of Asphaltene Deposition in the Wellbore and Near-Wellbore Region of a Deepwater Oil Reservoir under Gas Injection. Part 2: Computational Fluid Dynamics Modeling of Asphaltene Deposition

Asphaltene deposition during oil production is a major flow assurance problem. The asphaltene deposit layer reduces the pipe cross-section, leading to a significant reduction in the flow rate and eventually plugging the pipeline. This flow assurance problem caused during oil production has motivated the development of several experimental and modeling techniques to investigate the asphaltene behavior. This study proposes an integrated approach to simultaneously model asphaltene precipitation, aggregation, and deposition on a single platform. It focuses on the development of a deposition simulator that performs thermodynamic modeling using the perturbed chain version of the statistical associating fluid theory equation of state (PC-SAFT EOS) and depicts the deposition profile by means of a computational fluid dynamics (CFD) model based on the finite element method. In this work, the asphaltene deposition risk was assessed in the near-wellbore region and the production tubing as a result of gas breakthrough. To achieve this goal, a sample of crude C2 was analyzed to determine its properties and also the tendency of the asphaltenes contained in this sample to precipitate and deposit under various conditions. Laboratory-scale experiments were performed to analyze the rates of asphaltene precipitation, aggregation, and deposition. With the results obtained from the various experiments, advanced modeling methods based on PC-SAFT EOS and CFD models were calibrated and used to predict asphaltene precipitation and deposition under field conditions. Simulation methods for oil flow and asphaltene precipitation in the near-wellbore region of the reservoir and inside the production tubing were coupled to provide the most rigorous modeling approach ever developed to understand and predict this complex flow assurance problem. The results show a low to moderate asphaltene deposition rate produced by crude C2 as the gas breaks through. Nevertheless, further investigation is recommended to analyze the effect of other fluids that may be co-produced to enhance our ability to understand and predict asphaltene deposition under different conditions.

Molecular Dynamics Study on Aggregating Behavior of Asphaltene and Resin in Emulsified Heavy Oil Droplets with Sodium Dodecyl Sulfate

The aggregates of asphaltene and resin molecules play an important role in stabilizing heavy crude oil. Although many experiments are applied to investigate the complex aggregating structure of asphaltene and resin molecules in heavy crude oil, those microstructure and properties are still not clear at the molecular level. As another auxiliary tool, molecular dynamics (MD) simulation can be used to simulate the behavior of asphaltene and resin in the heavy oil droplet or emulsified oil droplet. The simulation results showed the following: (i) Asphaltene and resin molecules can form a netlike structure in heavy oil through face-to-face or edge-to-face stacking interaction, and the aggregating structure is considered to be the main reason that heavy crude oil has high viscosity. (ii) When surfactant molecules were added to the heavy oil phase, the asphaltene molecules moved to the center of emulsified oil droplet from the oil/water interface. The adsorption of surfactant molecules at the interface resulted ...

Microfluidic investigations of crude oil-brine interface elasticity modifications via brine chemistry to enhance oil recovery

Waterflooding has been widely adopted as an improved oil recovery technique since water is, in general, inexpensive and readily available. More recently, low salinity waterflooding (LSW) has been applied to oil production. LSW has successfully demonstrated higher recovery efficiencies than conventional water flooding, yet the underlying mechanism is still quite unclear. Extensive research has focused upon rock-fluid interactions under low salinity conditions, however very little work has considered interactions between oil and brine and how fluid-fluid interfacial properties are influenced by brine salinity and composition. To fill this gap, we have developed a microfluidic device for multiphase interfacial testing with length scales comparable to the pore scale of oil reservoir rocks. Unlike conventional core flooding tests, fluid-fluid phenomena can be easily visualized within microfluidic devices via optical microscopy. Oil snap-off, a phenomenon that represents a major dispersion mechanism, occurs when crude oil flows through porous media in the reservoir and induces trapping hysteresis, can be investigated within a well-controlled microfluidic flow-focusing geometry. The size of formed droplets is examined as a measure of the resistance to snap-off. It has been previously demonstrated that snap-off events are influenced by brine chemistry, oil composition, and the interaction time between crude oil and brine. Here, we show that asphaltenes in the oil phase contribute directly to the development of the elasticitic film. We also propose the reduction of interfacial elasticity by other polar components, such as naphthenic acids, which counteract asphaltene behavior over different time scales. The contribution of these effects on interfacial elasticity is shown to be mediated by both the composition and concentration of brine and oil.

Asphaltenes Dissolution Mechanism Study by in Situ Raman Characterization of a Packed-Bed Microreactor with HZSM-5 Aluminosilicates

Asphaltenes, which are the most aromatic component of heavy oil, are responsible for the fouling and impairment in flow lines, wellbores, and other production facilities in the petroleum industry. Aromatic solvents such as xylenes are commonly used for the asphaltenes’ cleaning process. Understanding the mechanism of asphaltenes’ dissolution in aromatic solvents is significant for the development of a remediation strategy. The reduction of a reactor’s characteristic length scale leads to the decrease in experimental period while providing high-throughput information. Microfluidic systems with in situ spectroscopy is an excellent platform for time-effective studies of the molecular behavior of asphaltenes in simulated sandstone reservoirs. Here, we injected the HZSM-5 zeolite nanoparticles (707 nm aggregate–1 in isopropanol solution) with varying Al2O3/SiO2 ratios (from 0 to 1/26) into the quartz porous media to represent reservoirs with different characteristic acidity. In-line ultraviolet–visible light (...

Surface and Interface Characterization of Asphaltenic Fractions Obtained with Different Alkanes: A Study by Atomic Force Microscopy and Pendant Drop Tensiometry

It is recognized that asphaltenes have a tendency toward aggregation and precipitation. Even at low concentrations, they can adsorb at interfaces/surfaces where each type of interaction plays an important role in different stages of oil production. In order to evaluate the behavior of asphaltenes, it is necessary to conduct studies that allow the understanding of their chemical and physical structure, as well as to assess how they behave interfacially and superficially. By using the Pendant Drop Tensiometry and Atomic Force Microscopy techniques, the present work aims to characterize the interfacial behavior and the surface structure of two asphaltenic fractions obtained through the precipitation using n-heptane and propane as flocculants. Asphaltenic fractions were characterized by Fourier transform infrared spectroscopy, elementary analysis, gel permeation chromatography, and differential scanning calorimetry, to obtain their physicochemical characteristics. Fractions were deposited in glass substrates at different concentrations, and the contact angle between water and the substrate was determined, identifying how the different asphaltenic fractions influence the wettability of the surface, even at low concentrations. When precipitation was conducted using propane, the asphaltenic fraction showed distinct structural characteristics that were obtained by precipitation with heptane. Atomic force microscopy suggested the formation of different surface arrangements between the fractions, caused by the higher presence of resins in the fractions precipitated by propane. The pendant drop tensiometry evidenced that the asphaltenic fraction insoluble in heptane showed greater affinity to migration to the interface, producing films more resistant to the deformation, than the asphaltene fraction insoluble in propane.

The influence of CO2 on the structure of confined asphaltenes in calcite nanopores

The effect of CO2 injection on the structure and transport properties of confined asphaltenes in 6 nm slit-shaped calcite nanopore was studied using molecular dynamics simulations. The difference between asphaltene behavior in confined and bulk fluids in the presence of CO2 were investigated. A higher number of CO2 molecules in confinement influenced the anisotropic distribution of the confined hydrocarbons by displacing the adsorbed hydrocarbons molecules away from the pore surface toward the center of the pore. The van der Waals and electrostatic affinity of toluene and asphaltene with calcite surface decreased with an increase in the CO2 mole fraction. Increase in the number of CO2 molecules in confinement enhanced the tendency of asphaltenes to form aggregates. Further, the diffusivities of hydrocarbons were influenced by the density of injected CO2 and were found to vary anisotropically in the calcite nanopores. The aggregation of asphaltenes in the absence of confinement is faster as opposed to being in confinement. The enhanced adsorption of CO2 to the pore surface reduces the concentration of CO2 in the center of the pore resulting in slower aggregation of asphaltenes in confinement. These results suggest that developing a fundamental understanding of asphaltene behavior in confinement is essential for developing more robust predictions of field-scale observations of asphaltene aggregation.

Behavior of asphaltene and asphaltene fractions films on a Langmuir–Blodgett trough and its relationship with proposed molecular structures

Asphaltenes were precipitated from a Venezuelan Ayacucho crude oil and separated into two fractions (A1 and A2) by the p-nitrophenol method. The asphaltenes and the fractions A1 and A2, as well as mixtures of the two fractions were tested in a Langmuir–Bodgett trough. It was found that the asphaltenes and the fraction A2 had similar behavior and higher compressibility than the fraction A1. This is because the molecules of A2 are more flexible than the molecules of A1 as they have aliphatic chains that bond aromatic structures while the A1 has an aromatic nucleus.

Asphaltene Mesoscale Aggregation Behavior in Organic Solvents-A Brownian Dynamics Study.

Significant advances have been achieved in understanding the main molecular mechanisms leading to asphaltene aggregation. However, the existing computational deficiency of molecular dynamics simulations did not allow full reproduction of the complex aggregation behavior of asphaltene in the past. In this work, we use the Brownian dynamics simulation to investigate asphaltene aggregation behavior on larger length and time scales that have not been previously accessed by molecular simulations. This enabled us to completely render the formation of clusters of asphaltene nanoaggregates and the resulting fractal or network of aggregates during the aggregation process. Asphaltene aggregation is studied at several volume fractions (ϕ = 1-7%) of asphaltene nanoaggregates in two solvents including heptane and heptol (i.e., a mixture of heptane and toluene). Our simulation results support the aggregation hierarchy proposed in the Yen-Mullins model (Mullins, Annu. Rev. Anal. Chem. 2011, 4, 393-418.) by demonstrating that asphaltene nanoaggregates form small clusters with an aggregation number of 7-8 and an average gyration radius of ∼4.0 nm capable of forming either fractal aggregates with a fractal dimension of 1.93-2.04 at low ϕ or percolating networks of aggregates at high ϕ. Percolating structures are observed at ϕ = 7% in both solvents. In heptol, the structures mainly percolate along two directions, whereas in heptane, they can percolate along three directions (i.e., x, y, and z). The self-diffusion coefficient ( D) significantly decreases as ϕ increases. Generally, D is larger in heptol than in heptane, but this difference diminishes as ϕ increases, approaching to almost the same value at ϕ = 7%.

Structure of Asphaltenes during Precipitation Investigated by Ultra-Small-Angle X-ray Scattering.

Time-resolved size and structure measurements of asphaltenes while in the process of precipitating were monitored for the first time using ultra-small-angle X-ray scattering. The results revealed that asphaltenes precipitating from a heptane-toluene mixture demonstrate a hierarchical structure of an asphaltene-rich phase (e.g., droplet) that further agglomerates into fractal flocs. The fractal flocs that form by the agglomeration of the asphaltene-rich phase are what is commonly detected by optical microscopy above the precipitation detection point. The surface of the asphaltene-rich phase is initially rough and transitions to a smooth interface, as would be expected for a highly viscous liquid. Simultaneous small-angle X-ray scattering measurements were also performed to investigate the structure of soluble asphaltenes, providing comprehensive structural characterization from the nanometer- to micrometer-length scales as a function of time. Further, the results demonstrate that the size and concentration of asphaltenes remaining in solution (e.g., soluble asphaltenes) do not change during precipitation, whereas the structure of insoluble asphaltenes varies. The ability to measure the properties of asphaltenes as they undergo precipitation opens new opportunities for understanding the fundamental mechanisms of asphaltene deposition and aggregation and the impact of chemical inhibitors to alter these processes. The universality of these conclusions and how specific properties vary as a function of asphaltene source and solution properties can provide valuable insight into asphaltene behavior.

Coarse-Grained Molecular Simulation and Nonlinear Manifold Learning of Archipelago Asphaltene Aggregation and Folding.

Asphaltenes constitute the heaviest aromatic component of crude oil. The myriad of asphaltene molecules falls largely into two conceptual classes: continental-possessing a single polyaromatic core-and archipelago-possessing multiple polyaromatic cores linked by alkyl chains. In this work, we study the influence of molecular architecture upon aggregation behavior and molecular folding of prototypical archipelago asphaltenes using coarse-grained molecular dynamics simulation and nonlinear manifold learning. The mechanistic details of aggregation depend sensitively on the molecular structure. Molecules possessing three polyaromatic cores show a higher aggregation propensity than those with two, and linear archipelago architectures more readily form a fractal network than ring topologies, although the resulting aggregates are more susceptible to disruption by chemical dispersants. The Yen-Mullins hierarchy of self-assembled aggregates is attenuated at high asphaltene mass fractions because of the dominance of promiscuous parallel stacking interactions within a percolating network rather than the formation of rodlike nanoaggregates and nanoaggregate clusters. The resulting spanning porous network possesses a fractal dimension of 1.0 on short length scales and 2.0 on long length scales regardless of the archipelago architecture. The incompatibility of the observed assembly behavior with the Yen-Mullins hierarchy lends support that high-molecular weight archipelago architectures do not occur at significant levels in natural crude oils. Low-dimensional free energy surfaces discovered by nonlinear dimensionality reduction reveal a rich diversity of metastable configurations and folding behavior reminiscent of protein folding and inform how intramolecular structures can be modulated by controlling asphaltene mass fraction and dispersant concentration.

Aggregation of modified hexabenzocoronenes as models for early stage asphaltene self-assembly

Molecular dynamics simulations were performed on solvated systems containing three molecules of hexabenzocoronene (HBC) derivatives to model the initial self-association of asphaltenes. Specifically, the hexane-modified HBC (HBC6) and those with substitutions containing a side chain with sulphur at three positions (α-H6SA, β-H6SB, and γ-HBCS) and a nitrogen substitution (H6N1) are included. These molecules were solvated with 20 mol% heptane and 80% toluene. Intermediate aggregation states, partial (two molecule clusters), as well as full aggregation of trimer clusters were observed. The conformation of the associated clusters was characterised by π–π stacking, giving the cluster a pre-rod-like shape. The aggregates displayed stability and did not dissociate throughout the course of the simulation (100–530 ns). In particular, the H6SB system showed statistically significant difference in means for both the separation distance and overall interaction energy. H6N1 and H6SA systems differed from the others in terms of electrostatic contributions. To gain a thorough understanding of initial aggregation behaviour and conditions of asphaltenes, additional simulations need to be conducted, in particular those incorporating oxygen substitutions as oxygen is a common heteroatom in crude.

Suppression of Phase Separation as a Hypothesis to Account for Nuclei or Nanoaggregate Formation by Asphaltenes in Toluene

Here, the concept of suppression of phase separation is proposed to account for the solubility behavior of asphaltenes at high dilution in toluene under ambient conditions. Nuclei formation at concentrations near 90 mg L–1 is the consequence of reaching A1 fraction solubility, and phase separation is suppressed by the intercalation of sufficient A2 in these nuclei or nanoaggregates. Presumably, such intercalation leads to media penetration of the nuclei periphery, hindering the growth and allowing for nuclei dispersion as a kinetic unit. Trapped compounds (TCs) or compounds trapped by asphaltene clusters were isolated, and their elemental analysis showed that they were neither resins nor asphaltenes. The information available regarding the A1 and A2 asphaltene subfractions is revised and complemented with new thermogravimetric analysis, simulation distillation (SimDis) curves, microcarbon Conradson, softening points, and nanoparticle results involving size-exclusion microchromatography. In general, physical results, such as solubility, SimDis, aggregation, and the softening point, differ substantially, whereas structural results, such as elemental analysis, DBE, and 13C nuclear magnetic resonance spectra, are similar. These results suggest that minor structural differences strongly affect the solubility, softening point, and other physical characteristics.

Molecular insights on the interfacial and transport properties of supercritical CO2/brine/crude oil ternary system

In this study, we conducted a series of molecular dynamics simulations to investigate the effect of supercritical carbon dioxide (sc-CO2) on the interfacial and transport properties of brine/crude oil at the reservoir conditions. We also studied the interfacial behavior of asphaltenes in presence of CO2. Crude oil was resembled by several hydrocarbons which are hexane, heptane, octane, nonane, cyclohexane, cycloheptane, benzene and toluene. The results showed that CO2, aromatics and asphaltenes accumulate at the interface at low CO2 mole fraction, however, as CO2 mole fraction increases, the relative density, the ratio of the density at the interface to the bulk density, decreases for both CO2 and aromatics. The decrease in CO2 relative density is due to the amount of CO2 dissolved in the oil bulk, which increases as CO2 mole fraction increase. It also found that CO2 displaces the oil molecules away from the interface, thus the relative density of aromatics decreases. Interestingly, it was found that as CO2 mole fraction increase, it enhances the face-to-face stacking between asphaltene molecules as noticed from the radial distribution function calculations. CO2 also force some asphaltene molecules to leave the interface and being dissolved and aggregated in the oil bulk. It also found that as CO2 mole fraction increased in the system, it dilutes the interface, penetrates to the water phase, forms hydrogen bonds with water and due to these effects, it reduces the interfacial tension of brine/crude oil system. The diffusivity of supercritical CO2/brine/crude oil system was also increased as a function of CO2 mole fraction. This study provides insights of the underlying interfacial properties from molecular level for a more realistic system of brine/crude oil.

Applying Grid partitioning based Fuzzy inference system as novel algorithm to predict Asphaltene precipitation

ABSTRACTAsphaltene precipitation is one of challenging problems in petroleum and chemical engineering so the importance of investigation of Asphaltene precipitation is clear. The asphaltene deposition effects on wellbore plugging, wettability alteration and facility damages. In order to solve these problems, a novel investigation based on Grid partitioning based Fuzzy inference system algorithm to predict precipitated asphaltene in terms of dilution ratio, temperature and carbon number of precipitant was developed. The predicting algorithm performance was evaluated statistically and graphically. The coefficients of determination (R2) for training and testing phases 0.9973 and 0.9900 respectively which confirm the great accuracy and high potential of predicting algorithm for estimation of precipitated asphaltene so this algorithm can be used as high accurate and simple software for prediction of asphaltene behavior in crude oil.