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Heavy Oils Conversion Processes

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A special issue of Processes (ISSN 2227-9717). This special issue belongs to the section "Chemical Processes and Systems".

Deadline for manuscript submissions: closed (10 January 2021) | Viewed by 43357

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Dr. Galina P. Kayukova

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Arbuzov Institute of Organic and Physical Chemistry, FRC Kazan Scientific Center, Russian Academy of Sciences, 8 Akademika Arbuzova, 420088 Kazan, Russia
Interests: chemistry and geochemistry of heavy oil; oil production and oil refining; ecology; investigation of asphaltene composition, structure, and transformation after thermal influences; developing catalytic systems and hydrogen donors for heavy oil recovery applications
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Dr. Alexey V. Vakhin

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Institute of Geology and Petroleum Technologies, Kazan Federal University, 18 Kremlyovskaya St., P.O. Box 420008, Kazan, Russia
Interests: EOR; heavy oil; aquathermolysis; catalysts; thermal analysis; EM heating; nanotechnology
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Dear Colleagues,

Thermal enhanced oil recovery methods are attracting wide interest for exploitation in heavy oil deposits. It is common knowledge that the exploitation of such oils is associated with various physical and chemical processes depending mainly on the chemical conversion of resins and asphaltenes. However, resins and asphaltene destruction generally results in reduced oil viscosity and its increased mobility through the porous medium of reservoir rock. The correlation between the reactions occurring within the reservoir and mineral composition and properties of the reservoir rock is noteworthy because of the influence generated from the latter factors on the process mechanisms. Moreover, some rock components may catalyze the processes that result in asphaltene and resin destruction. For this reason, many studies have been performed on the impact of different catalysts and reagents on intensifying resin and asphaltene destruction on oil composition, and showed an increase in the content of light saturated and aromatic hydrocarbons. In addition, the role of hydrogen donors in ensuring conversion is important, though more work is needed to address the effect of plate salts and pH on the conversion of asphaltenes and the functioning of catalysts embedded in the formation.

Dr. Galina P. Kayukova
Dr. Alexey V. Vakhin
Guest Editor

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Keywords

heavy oil
hydroconversion
catalyst
supported catalysts
dispersed catalytic systems
hydrogen donors
transition metals
asphaltenes
in situ upgrading

Published Papers (13 papers)

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Editorial

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4 pages, 198 KiB

Open AccessEditorial

Special Issue “Heavy Oils Conversion Processes”

by Galina P. Kayukova, Mohammed Amine Khelkhal and Alexey V. Vakhin

Processes 2023, 11(1), 116; https://0-doi-org.brum.beds.ac.uk/10.3390/pr11010116 - 31 Dec 2022

Viewed by 738

Abstract

It is common knowledge that the world’s economic growth is mainly based on hydrocarbon exploitation and processing, regardless of the political efforts towards developing renewable energy [...] Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

Research

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19 pages, 19347 KiB

Open AccessFeature PaperArticle

Influence of Metal Oxides and Their Precursors on the Composition of Final Products of Aquathermolysis of Raw Ashalchin Oil

by Sergey M. Petrov, Aliya G. Safiulina, Natalya Yu. Bashkirtseva, Alfiya I. Lakhova and Galiya G. Islamova

Processes 2021, 9(2), 256; https://0-doi-org.brum.beds.ac.uk/10.3390/pr9020256 - 29 Jan 2021

Cited by 16 | Viewed by 2081

Abstract

Experiments were conducted simulating hydrothermal conversion of heavy oil in the presence of carbonate, kaolin, Al₂O₃, Ni²⁺ and Cu²⁺, NiO mixed with poly-α-olefins, C₆H₈O₇, C₂H₄O₂ at 290–375 °C and 10–135 bar. Al₂O₃, carbonate at 375 °C and 135 bar, accelerated the resin degradation. Experiments with carbonate at 350 °C and 10 bar showed no significant composition changes. NiSO₄, CuSO₄, kaolin mineral, at 350 °C and 78 bar, accelerated decomposition of resins (from 35.6% to 32.5%). Al₂O₃ and carbonate at 290 °C and 14 bar led to the destruction of asphaltenes (from 6.5% to 4.7% by weight), which were adsorbed on the surface of carbonate. Al₂O₃, NiO, poly-α-olefins at 350 °C and 78 bar accelerated C–C bond cracking of high-boiling asphaltenes. C₆H₈O₇, rock-forming carbonate, at 360 °C and 14 bar, contributed to the polymerization and polycondensation of hydrocarbons with the formation of additional resins. C₂H₄O₂ and kaolin at 360 °C and 12 bar affected the reduction in the resin content from 35.6% to 31.9% wt. C₂H₄O₂ interacted with the active metals with the formation of acetate salts exhibiting catalytic activity. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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11 pages, 541 KiB

Open AccessArticle

Preparation of Polymer Bitumen Binder in the Presence of a Stabilizer

by Yerzhan Imanbayev, Anar Akkenzheyeva, Akkenzhe Bussurmanova, Akmaral Serikbayeva and Assiya Boranbayeva

Processes 2021, 9(1), 182; https://0-doi-org.brum.beds.ac.uk/10.3390/pr9010182 - 19 Jan 2021

Cited by 13 | Viewed by 3128

Abstract

The article presents the results of research on the production of polymer-bitumen binder (PBB) based on mixtures of non-oxidized and oxidized petroleum products, namely high-viscosity tar, darkened vacuum distillate, and oxidized petroleum bitumen 70/100, obtained at technological installations of Limited Liability Partnership (LLP) “JV Caspi Bitum’’ and styrene-butadiene-styrene (SBS) block copolymer brand L 30-01A modifier in the presence of a stabilizer. The results obtained show that the introduction of the SBS modifier in the presence of a sulfur stabilizer improves the performance characteristics of PBB, such as elasticity, ductility, softening temperature, penetration, and brittleness temperature. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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17 pages, 2141 KiB

Open AccessArticle

Mechanistic Approach to Thermal Production of New Materials from Asphaltenes of Castilla Crude Oil

by Natalia Afanasjeva, Andrea González-Córdoba and Manuel Palencia

Processes 2020, 8(12), 1644; https://0-doi-org.brum.beds.ac.uk/10.3390/pr8121644 - 12 Dec 2020

Cited by 5 | Viewed by 2854

Abstract

Asphaltenes are compounds present in crude oils that influence their rheology, raising problems related to the extraction, transport, and refining. This work centered on the chemical and structural changes of the asphaltenes from the heavy Colombian Castilla crude oil during pyrolysis between 330 and 450 °C. Also, the development of new strategies to apply these macromolecules, and the possible use of the cracking products as a source of new materials were analyzed. The obtained products (coke, liquid, and gas) were collected and evaluated through the techniques of proton and carbon-13 nuclear magnetic resonance (¹H and ¹³C NMR), elemental composition, Fourier-transform infrared spectroscopy (FTIR), X-ray powder diffraction (XRD), saturates, aromatics, resins, and asphaltenes (SARA) analysis, and gas chromatography–mass spectrometry (GC-MS). A comparison of the applied methods showed that the asphaltene molecules increased the average size of their aromatic sheets, lost their aliphatic chains, condensed their aromatic groups, and increased their degree of unsaturation during pyrolysis. In the liquid products were identified alkylbenzenes, n-alkanes C₉–C₃₀, and n-alkenes. Moreover, the gaseous products included methane, ethane, propane, and pentane. An approach of the structural chain reaction was used to define the possible asphaltenes chemical structures before and after pyrolysis. In conclusion, this type of thermal process can be used as an easy route to attain new materials associated with specific structural units from the asphaltenes. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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20 pages, 4348 KiB

Open AccessFeature PaperArticle

Chemical Characterization Using Different Analytical Techniques to Understand Processes: The Case of the Paraffinic Base Oil Production Line

by Rémi Moulian, Johann Le Maître, Hélène Leroy, Ryan Rodgers, Brice Bouyssiere, Carlos Afonso, Pierre Giusti and Caroline Barrère-Mangote

Processes 2020, 8(11), 1472; https://0-doi-org.brum.beds.ac.uk/10.3390/pr8111472 - 18 Nov 2020

Cited by 4 | Viewed by 3299

Abstract

Mineral base oils are used to produce commercial lubricants and are obtained from refining vacuum residue. Lubricants are used to reduce friction in industry devices, so their viscosity is a key characteristic that needs to be optimized throughout the process. The purpose of this study is to show how global chemical characterization of samples from the base oil production chain can facilitate a better understanding of the molecular impacts of processing and their effect on macroscopic properties like viscosity. Eight different samples were characterized by different analytical techniques, including liquid chromatography and mass spectrometry techniques, to understand their chemical evolution through the different process units at the molecular level. Furthermore, a statistical treatment allowed for the identification of parameters that influence viscosity, mainly sulfur and polyaromatics content. This study demonstrates the importance and effectiveness of cross-checking results from different complementary analytical techniques to acquire valuable data on lubricating oil base samples. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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13 pages, 2116 KiB

Open AccessFeature PaperArticle

Qualitative and Quantitative Analysis of Heavy Crude Oil Samples and Their SARA Fractions with ¹³C Nuclear Magnetic Resonance

by Ilfat Rakhmatullin, Sergey Efimov, Vladimir Tyurin, Marat Gafurov, Ameen Al-Muntaser, Mikhail Varfolomeev and Vladimir Klochkov

Processes 2020, 8(8), 995; https://0-doi-org.brum.beds.ac.uk/10.3390/pr8080995 - 16 Aug 2020

Cited by 20 | Viewed by 4283

Abstract

Nuclear magnetic resonance (NMR) approaches have unique advantages in the analysis of crude oil because they are non-destructive and provide information on chemical functional groups. Nevertheless, the correctness and effectiveness of NMR techniques for determining saturates, aromatics, resins, and asphaltenes (SARA analysis) without oil fractioning are still not clear. In this work we compared the measurements and analysis of high-resolution ¹³C NMR spectra in B₀ ≈ 16.5 T (NMR frequency of 175 MHz) with the results of SARA fractioning for four various heavy oil samples with viscosities ranging from 100 to 50,000 mPa·s. The presence of all major hydrocarbon components both in crude oil and in each of its fractions was established quantitatively using NMR spectroscopy. Contribution of SARA fractions in the aliphatic (10–60 ppm) and aromatic (110–160 ppm) areas of the ¹³C NMR spectra were identified. Quantitative fractions of aromatic molecules and oil functional groups were determined. Aromaticity factor and the mean length of the hydrocarbon chain were estimated. The obtained results show the feasibility of ¹³C NMR spectroscopy for the express analysis of oil from physical properties to the composition of functional groups to follow oil treatment processes. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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13 pages, 3797 KiB

Open AccessArticle

As-Synthesized Oleic Amido Propyl Betaine Surfactant Mixture and the Effect on the Crude Oil–Seawater Interfacial Tension

by Norhidayah Ahmad Wazir, Anita Ramli, Nurida M. Yusof, Wasan Saphanuchart and Emily S. Majanun

Processes 2020, 8(8), 965; https://0-doi-org.brum.beds.ac.uk/10.3390/pr8080965 - 11 Aug 2020

Cited by 6 | Viewed by 2736

Abstract

As-synthesized oleic amido propyl betaine surfactant mixture was developed through a slight modification of a conventional two-step betaine synthesis process of amidation and quaternization reactions. This method is a “direct formulating through synthesis” to achieve a targeted interfacial property (interfacial tension or IFT) of the as-synthesized surfactant. Oil–water IFT was measured in the crude oil–seawater system at 96 °C. The result showed that the as-synthesized surfactant was able to reduce crude oil–seawater IFT to the ultra-low level (<0.01 mN/m). As the finding emerged, the investigation was conducted to identify the elements that would bring the characteristic of ultra-low IFT. The characterization of the surfactant using FTIR, TG-IR, and HPLC suggested that unreacted materials associated with the surfactant remained, such as the carryover of a fatty amide from the intermediate process, residues of N, N trimethylene dimethylamine and sodium chloride as a by-product, and the important newly formed sodium oleate compound that was inadvertently generated via the reaction. The performance of the as-synthesized in seawater condition has been verified and the surface tension plot shows the lowest surface tension point at 0.05 wt.% concentration before developing a plateau region at higher surfactant concentration, indicating that the formation of surfactant micelles has been interrupted by the presence of other components in the solution. The dynamic IFT test performed on the as-synthesized product revealed that it was still able to reduce the crude oil–seawater IFT to an ultra-low level, despite the multiple undesirable components in the surfactant. IFT as low as 3.4 × 10⁻⁴ mN/m for the specific seawater and crude oil composition was obtained at a temperature of 96 °C. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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17 pages, 3033 KiB

Open AccessFeature PaperArticle

Heavy Oil Hydrocarbons and Kerogen Destruction of Carbonate–Siliceous Domanic Shale Rock in Sub- and Supercritical Water

by Zukhra R. Nasyrova, Galina P. Kayukova, Alexey V. Vakhin, Richard Djimasbe and Artem E. Chemodanov

Processes 2020, 8(7), 800; https://0-doi-org.brum.beds.ac.uk/10.3390/pr8070800 - 08 Jul 2020

Cited by 16 | Viewed by 2841

Abstract

This paper discusses the results of the influences of subcritical (T = 320 °C; P = 17 MPa) and supercritical water (T = 374 °C; P = 24.6 MPa) on the yield and composition of oil hydrocarbons generated from carbonaceous–siliceous Domanic shale rocks with total organic content (C_org) of 7.07%. It was revealed that the treatment of the given shale rock in sub- and supercritical water environments resulted in the decrease of oil content due to the intensive gas formation. The content of light hydrocarbon fractions (saturated and aromatic hydrocarbons) increased at 320 °C from 33.98 to 39.63%, while at 374 °C to 48.24%. Moreover, the content of resins decreased by almost twice. Insoluble coke-like compounds such as carbene–carboids were formed due to decomposition of kerogen after supercritical water treatment. Analysis of oil hydrocarbons with FTIR method revealed a significant number of oxygen-containing compounds, which are the hydrogenolysis products of structural fragments formed after destruction of kerogen and high-molecular components of oil. The gas chromatography–mass spectroscopy (GC–MS) method was applied to present the changes in the composition of mono- and dibenzothiophenes, which indicate conversion of heavy components into lighter aromatic hydrocarbons. The specific features of transforming trace elements in rock samples, asphaltenes, and carbene–carboids were observed by using the isotopic mass-spectrometry method. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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16 pages, 2577 KiB

Open AccessArticle

Microemulsion Rheological Analysis of Alkaline, Surfactant, and Polymer in Oil-Water Interface

by Mohd Sofi Numin, Khairulazhar Jumbri, Anita Ramli and Noorazlenawati Borhan

Processes 2020, 8(7), 762; https://0-doi-org.brum.beds.ac.uk/10.3390/pr8070762 - 29 Jun 2020

Cited by 19 | Viewed by 3371

Abstract

Injection of alkaline (A), polymer (P), and surfactant (S) chemicals in enhanced oil recovery (cEOR) processes increases output by changing the properties of the injected fluid. In this work, micellar fluid interactions were studied via microemulsion rheological analysis. Crude oil and stimulated brine with ASP or SP was used for bottle testing. The results revealed that no microemulsion was produced when ASP (Alkaline, Surfactant, and Polymer) or SP (Surfactant and Polymer) was left out during the bottle testing phase. The addition of ASP and SP led to the formation of microemulsions—up to 29% for 50% water cut (WC) ASP, and 36% for 40% WC SP. This shows that the addition of ASP and SP can be applied to flooding applications. The results of the rheological analysis show that the microemulsions behaved as a shear-thinning micellar fluid by decreasing viscosity with increase in shear rate. As per the power-law equation, the ASP micellar fluid viscoelastic behavior shows better shear-thinning compared to SP, suggesting more efficiency in fluid mobility and sweep efficiency. Most of the microemulsions exhibited viscoelastic fluid behavior (G’ = G”) at angular frequency of 10 to 60 rad s⁻¹, and stable elastic fluid behavior (G’ > G’’) below 10 rad s⁻¹ angular frequency. The viscosity of microemulsion fluids decreases as temperature increases; this indicates that the crude oil (i.e., alkanes) was solubilized in core micelles, leading to radial growth in the cylindrical part of the wormlike micelles, and resulting in a drop in end-cap energy and micelle length. No significant difference was found in the analysis of viscoelasticity evaluation and viscosity analysis for both ASP and SP microemulsions. The microemulsion tendency test and rheology test show that the addition of ASP and SP in the oil-water interface yields excellent viscoelastic properties. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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9 pages, 1370 KiB

Open AccessFeature PaperEditor’s ChoiceArticle

Catalytic Aquathermolysis of Boca de Jaruco Heavy Oil with Nickel-Based Oil-Soluble Catalyst

by Alexey V. Vakhin, Firdavs A. Aliev, Irek I. Mukhamatdinov, Sergey A. Sitnov, Andrey V. Sharifullin, Sergey I. Kudryashov, Igor S. Afanasiev, Oleg V. Petrashov and Danis K. Nurgaliev

Processes 2020, 8(5), 532; https://0-doi-org.brum.beds.ac.uk/10.3390/pr8050532 - 01 May 2020

Cited by 40 | Viewed by 4067

Abstract

This paper investigates aquathermolysis of heavy oil in carbonate reservoir rocks from Boca de Jaruco, which is developed by the cyclic steam stimulation method. The nickel-based catalyst precursor was introduced in order to intensify the conversion processes of heavy oil components. The active form of such catalysts—nickel sulfides—are achieved after steam treatment of crude oil at reservoir conditions. The experiments were carried out on a rock sample extracted from the depth of 1900 m. Changes in composition and structure of heavy oil after the conversion were identified using SARA-analysis, Gas Chromatography-Mass Spectroscopy of saturated fractions, FTIR spectroscopy of saturated fractions, and MALDI of resins. It is revealed that catalyst particles provide a reduction in the content of resins and asphaltenes due to the destruction of carbon-heteroatom bonds. Moreover, the destruction of C=C_arom. bonds and interactions with aromatic rings are heightened. In contrast, the results of experiments in the absence of catalysts exposed polymerization and condensation of aromatic rings. The most remarkable result to emerge from the thermo-catalytic influence is the irreversible viscosity reduction of produced crude oil enhancing the oil recovery factor. Moreover, the introduction of catalysts increases the gas factor due to additional gas generation as a result of aquathermolysis reactions. The yield of methane gas is significantly high in the experimental runs with oil-saturated rocks rather than crude oil experiments. The gas factor reaches 45 m³/ton. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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Review

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20 pages, 2728 KiB

Open AccessFeature PaperReview

The Role of Nanodispersed Catalysts in Microwave Application during the Development of Unconventional Hydrocarbon Reserves: A Review of Potential Applications

by Alexey V. Vakhin, Mohammed Amine Khelkhal, Arash Tajik, Marat R. Gafurov, Oleg G. Morozov, Aydar R. Nasybullin, Sergey A. Karandashov, Andrey A. Ponomarev, Tatiana O. Krapivnitskaia, Mikhail Yu. Glyavin, Olga V. Slavkina and Konstantin A. Shchekoldin

Processes 2021, 9(3), 420; https://0-doi-org.brum.beds.ac.uk/10.3390/pr9030420 - 26 Feb 2021

Cited by 26 | Viewed by 2551

Abstract

Electromagnetic impact on oil reservoir manifests itself in various physical and chemical phenomena and attracts a significant scientific and technological interest. Microwave (MW) radiation heating can be more efficient for the oil recovery than heat transfer by convection or by thermal conduction. MW influence can also lead to significant changes in the physicochemical and rheological properties of oil caused by chemical processes of transformation of the oil high-molecular components such as resins and asphaltenes. The efficiency of transition-metal catalysts applied for the in-situ conversion of hydrocarbons directly in the reservoir might be significantly increased by exposing the oil formation to MW radiation. Actually, transition metals nanoparticles and their oxides are considered as active absorbers of MW radiation and; therefore, they can be used to intensify MW impact on the reservoir. Catalyst particles dispersed in the formation provide enhanced MW sweep. Taken together, the functioning of the catalysts and the effect of microwave radiation provide deep conversion of resins and asphaltenes, a decrease in the viscosity of the produced oil and an increase in oil recovery factor, along with a decrease in water cut of the well production. The present review analyzes the latest works on the combined application of microwave exposure and dispersed catalysts. In addition, this review discusses the prospects and perspectives of practical application of electromagnetic heating to enhance heavy oil recovery in the presence of nanoparticles. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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22 pages, 21321 KiB

Open AccessFeature PaperReview

In-Situ Heavy Oil Aquathermolysis in the Presence of Nanodispersed Catalysts Based on Transition Metals

by Firdavs A. Aliev, Irek I. Mukhamatdinov, Sergey A. Sitnov, Mayya R. Ziganshina, Yaroslav V. Onishchenko, Andrey V. Sharifullin and Alexey V. Vakhin

Processes 2021, 9(1), 127; https://0-doi-org.brum.beds.ac.uk/10.3390/pr9010127 - 08 Jan 2021

Cited by 46 | Viewed by 4360

Abstract

The aquathermolysis process is widely considered to be one of the most promising approaches of in-situ upgrading of heavy oil. It is well known that introduction of metal ions speeds up the aquathermolysis reactions. There are several types of catalysts such as dispersed (heterogeneous), water-soluble and oil soluble catalysts, among which oil-soluble catalysts are attracting considerable interest in terms of efficiency and industrial scale implementation. However, the rock minerals of reservoir rocks behave like catalysts; their influence is small in contrast to the introduced metal ions. It is believed that catalytic aquathermolysis process initiates with the destruction of C-S bonds, which are very heat-sensitive and behave like a trigger for the following reactions such as ring opening, hydrogenation, reforming, water–gas shift and desulfurization reactions. Hence, the asphaltenes are hydrocracked and the viscosity of heavy oil is reduced significantly. Application of different hydrogen donors in combination with catalysts (catalytic complexes) provides a synergetic effect on viscosity reduction. The use of catalytic complexes in pilot and field tests showed the heavy oil viscosity reduction, increase in the content of light hydrocarbons and decrease in heavy fractions, as well as sulfur content. Hence, the catalytic aquathermolysis process as a distinct process can be applied as a successful method to enhance oil recovery. The objective of this study is to review all previously published lab scale and pilot experimental data, various reaction schemes and field observations on the in-situ catalytic aquathermolysis process. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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31 pages, 22328 KiB

Open AccessFeature PaperReview

Fractionation and Characterization of Petroleum Asphaltene: Focus on Metalopetroleomics

by Fang Zheng, Quan Shi, Germain Salvato Vallverdu, Pierre Giusti and Brice Bouyssiere

Processes 2020, 8(11), 1504; https://0-doi-org.brum.beds.ac.uk/10.3390/pr8111504 - 20 Nov 2020

Cited by 40 | Viewed by 5852

Abstract

Asphaltenes, as the heaviest and most polar fraction of petroleum, have been characterized by various analytical techniques. A variety of fractionation methods have been carried out to separate asphaltenes into multiple subfractions for further investigation, and some of them have important reference significance. The goal of the current review article is to offer insight into the multitudinous analytical techniques and fractionation methods of asphaltene analysis, following an introduction with regard to the morphologies of metals and heteroatoms in asphaltenes, as well their functions on asphaltene aggregation. Learned lessons and suggestions on possible future work conclude the present review article. Full article

(This article belongs to the Special Issue Heavy Oils Conversion Processes)

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