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Heavy Oils Conversion Processes (II)
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Heavy Oils Conversion Processes (II)

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

Deadline for manuscript submissions: closed (30 December 2022) | Viewed by 6621
Related Special Issue: Heavy Oils Conversion Processes (II)

Special Issue Editors

Dr. Galina P. Kayukova

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Guest Editor
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
Special Issues, Collections and Topics in MDPI journals
Dr. Alexey V. Vakhin

E-Mail Website
Guest Editor
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
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

The use of thermal enhanced oil recovery methods are attracting wide interest in exploiting heavy oil deposits. It is common knowledge that the exploitation of such oils is associated with various physical and chemical processes depending mainly on chemical conversion of resins and asphaltenes. However, resins and asphaltene destruction generally results in reducing oil viscosity and increasing its mobility through the porous medium of the reservoir rock. The correlation between the reactions occuring 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 process of asphaltenes and resins destruction. For this reason, many studies have been performed on the impact of different catalysts and reagents on intensifying resins and asphaltenes destruction and have shown an increase in the content of light saturated and aromatic hydrocarbons in oil composition. In addition, the role of hydrogen donors in ensuring conversion is important but study of the effect of plate salts and pH on the conversion of asphaltenes and the functioning of catalysts embedded in the formation still needs further improvement.

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

Manuscript Submission Information

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Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2400 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

Keywords

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

Published Papers (4 papers)

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Research

10 pages, 3270 KiB  
Article
Investigation into the Perforation Optimization in Conglomerate Reservoir Based on a Field Test
by Qinghu Fan, Yonggui Ma, Junping Wang, Liang Chen, Zhiquan Ye, Yajun Xu, Huan Li and Bo Wang
Processes 2023, 11(8), 2446; https://doi.org/10.3390/pr11082446 - 14 Aug 2023
Cited by 1 | Viewed by 668
Abstract
The Mahu conglomerate reservoir is characterized by strong heterogeneity and the uneven stimulation of the horizontal lateral during hydraulic fracturing. The optimization of the perforation number per cluster is of great value for horizontal well multi-stage fracturing (HWMF) because the suitable perforation number [...] Read more.
The Mahu conglomerate reservoir is characterized by strong heterogeneity and the uneven stimulation of the horizontal lateral during hydraulic fracturing. The optimization of the perforation number per cluster is of great value for horizontal well multi-stage fracturing (HWMF) because the suitable perforation number not only promotes the uniform propagation of multiple fractures but also prevents excessive perforation erosion. In this work, a typical well in the Mahu conglomerate reservoir was selected, and a field test of optimizing the perforation number was carried out. The perforation schemes of three, five, and eight perforations per cluster were designed in nine fracturing stages, respectively. The wellhead pressure under different perforation schemes was compared and analyzed with the step-down flow rate test, and the optimal perforation number per cluster in the Mahu conglomerate reservoir was selected as eight. The theoretical calculation results show that eight perforations per cluster can generate the perforation friction of 5 MPa, sufficient to overcome the mechanical property differences among multiple clusters within one stage. The downhole video technology shows that the perforation erosion area is the most uniform with the case of eight perforations per cluster. Moreover, the optical fiber monitoring results show that the perforation number of eight per cluster can realize the simultaneous initiation and uniform propagation of six fractures or five fractures within one stage. This work is of great significance for the efficient development of the Mahu conglomerate reservoir through HWMF. Full article
(This article belongs to the Special Issue Heavy Oils Conversion Processes (II))
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20 pages, 3282 KiB  
Article
The Influence of Reservoir Clay Composition on Heavy Oil In Situ Combustion
by Ilgiz F. Minkhanov, Alexander V. Bolotov, Aidar R. Tazeev, Vladislav V. Chalin, Anini Franck D. Kacou, Ranel I. Galeev, Rustam N. Sagirov, Ameen A. Al-Muntaser, Dmitrii A. Emelianov, Mohammed Amine Khelkhal and Mikhail A. Varfolomeev
Processes 2022, 10(11), 2308; https://doi.org/10.3390/pr10112308 - 06 Nov 2022
Cited by 2 | Viewed by 1384
Abstract
Thermally enhanced oil recovery methods, such as in situ combustion and steam injection, are generating considerable interest in terms of improving oil reserve exploitation and satisfying oil demand and economic growth. However, the early breakthrough of the in situ combustion front and the [...] Read more.
Thermally enhanced oil recovery methods, such as in situ combustion and steam injection, are generating considerable interest in terms of improving oil reserve exploitation and satisfying oil demand and economic growth. However, the early breakthrough of the in situ combustion front and the significant amount of heat loss associated with steam injection for deeper reservoir applications are the main challenges that require urgent solutions. Further data collection related to the effects of a reservoir’s physical and chemical properties, temperature, and pressure on in situ combustion front propagation and steam injection heat transfer inefficiency would be needed to achieve better reservoir oil recovery. Most studies have focused on the application of catalytic systems and the investigation of minerals’ effects on combustion front stabilization; however, the effect of clay interlayers’ minerals on the performance of in situ combustion is still poorly understood. This paper takes a new look at the role played by the interlayers’ minerals in stabilizing the combustion front using X-ray diffraction (XRD), thermogravimetry (TG), differential scanning calorimetry (DSC) combined with nuclear magnetic resonance (NMR), and combustion tube experiments. The studied samples’ compositions were analyzed by XRD, TG/DSC, and NMR techniques. Meanwhile, the effects of interlayers’ minerals on oil production were screened by combustion tube experiments. The data obtained from this study suggest that clay dispersion within a reservoir would improve oil recovery via in situ combustion, and our study led us to obtain an 80.5% recovery factor. However, the experiments of models with clay interlayers showed less recovery factors, and the model with interlayers led to a 0% recovery factor in the presence of air injection. Meanwhile, the same model in hydrothermal and air injection conditions led to a 13.9% recovery factor. This was due to the hydrothermal effect improving permeability and pore enlargement, which allowed the transfer of heat and matter. Moreover, our study found that clay minerals exhibit excellent catalytic effects on the formation of fuel deposition and the coke oxidation process. This effect was reflected in the significant role played by clay minerals in decreasing the number of heteroatoms by breaking down the C-S, C-N, and C-O bonds and by stimulating the processes of hydrocarbon polymerization during the in situ combustion. Our results add to a growing body of literature related to in situ combustion challenges and underline the importance of a reservoir’s physical parameters in the successful application of in situ combustion. Full article
(This article belongs to the Special Issue Heavy Oils Conversion Processes (II))
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9 pages, 682 KiB  
Article
Selection of Solvents for the Removal of Asphaltene–Resin–Paraffin Deposits
by Sandugash Tanirbergenova, Yerdos Ongarbayev, Yerbol Tileuberdi, Ainur Zhambolova, Ernar Kanzharkan and Zulkhair Mansurov
Processes 2022, 10(7), 1262; https://doi.org/10.3390/pr10071262 - 24 Jun 2022
Cited by 2 | Viewed by 2213
Abstract
In this study, we aimed to select the optimal solvents for the removal of asphaltene–resin–paraffin deposits. The effectiveness of various solvents was determined based on the asphaltene–resin–paraffin deposits (ARPDs) of the Zhanaozen (Ozen) crude oil field. These deposits affect the geological, physical, and [...] Read more.
In this study, we aimed to select the optimal solvents for the removal of asphaltene–resin–paraffin deposits. The effectiveness of various solvents was determined based on the asphaltene–resin–paraffin deposits (ARPDs) of the Zhanaozen (Ozen) crude oil field. These deposits affect the geological, physical, and technological conditions of the oil field, thus influencing its development. According to the results, we found that the most effective composite solvent is a composition comprising a 50% gasoline fraction and a 50% kerosene fraction. This composition showed mass loss of deposits of 97.7% and a dissolving power of 93.5 g/cm3 after 5 h. We confirmed the effectiveness of this composition by the paraffinic type of the deposits, which is explained by the high content of paraffin in the oil from the Zhanaozen field. Aromatic solvents showed a relatively low dissolving power compared with aliphatic solvents, which also confirms the low content of resins and asphaltenes in the ARPD. Full article
(This article belongs to the Special Issue Heavy Oils Conversion Processes (II))
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20 pages, 4213 KiB  
Article
Composition of Oil after Hydrothermal Treatment of Cabonate-Siliceous and Carbonate Domanic Shale Rocks
by Galina P. Kayukova, Zukhra R. Nasyrova, Anastasiya N. Mikhailova, Igor P. Kosachev, Firdavs A. Aliev and Alexey V. Vakhin
Processes 2021, 9(10), 1798; https://doi.org/10.3390/pr9101798 - 11 Oct 2021
Cited by 3 | Viewed by 1531
Abstract
The hydrocarbon compositions of shale oils, generated from two different lithological–facial Domanic deposits of the Tatarstan Republic (Russia), were studied under hydrothermal impact with 30% of water addition in a 350 °С and CO2 environment. The samples were extracted from carbonate–siliceous rocks [...] Read more.
The hydrocarbon compositions of shale oils, generated from two different lithological–facial Domanic deposits of the Tatarstan Republic (Russia), were studied under hydrothermal impact with 30% of water addition in a 350 °С and CO2 environment. The samples were extracted from carbonate–siliceous rocks of the Semiluky–Mendym deposits of the Berezovskaya area, and carbonate deposits of the Dankovo–Lebedyan horizon of the Zelenogorskaya area of the Romashkino oil field. The distinctive features of rocks are in the composition and content of organic matter (OM), its thermal stability, as well as the structural-group composition of the shale oil products. The hydrothermal treatment of the rock samples increased the content of saturates and decreased the content of aromatics, resins and asphaltenes in the composition of crude oil. The decomposition of the polymer-like kerogen structure and destruction processes of high-molecular compounds, such as resins and asphaltenes, are accompanied with the formation of substances highly rich in carbons—carbenes and carboids. The contents of n-alkanes and acyclic isoprenoids increase in the composition of saturated hydrocarbons. According to the chemical classification of Al. A. Petrov, the character of the molecular mass distribution of such substances corresponds to oil type A1, which is considered paraffinic. The contents of dibenzothiophene, naphthalene and phenanthrene are increased in the composition of aromatic hydrocarbons, while the contents of tri-methyl-alkyl-benzene and benzothiophene are decreased. The increase in the aryl isoprenoid ratio (AIR = С13–С17/С18–С22) and maturity parameter (4-MDBT/1-MDBT) under the influences of hydrothermal factors indicates the increasing thermal maturity degree of the hydrocarbon system. The differences in the distribution behavior of saturated and aromatic hydrocarbons—biomarkers in rocks of various lithological-facies types, which are reasoned by different conditions of initial organic matter transformation as well as under the impact of hydrothermal factors—were revealed. Full article
(This article belongs to the Special Issue Heavy Oils Conversion Processes (II))
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