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•Hydrophobic pads collect ignitable liquids from the surface of water.•Analysis of petroleum distillates recovered using hydrophobic pads are easily identifiable.•Gasoline recovered from the surface of water using hydrophobic pads shows loss of lower molecular weight compounds. Significant amounts of water are used to extinguish fires, and finding evidence of ignitable liquid residue can be challenging for investigators. Hydrophobic pads have been designed to collect oil-based products from the surface of water and preferentially absorb non-polar compounds while repelling water. In this study hydrophobic pads are used to collect various classifications of ignitable liquids from the surface of water for analysis using passive headspace concentration and GC/MS analysis. Hydrophobic pads were found to be effective in collecting ignitable liquids containing hydrocarbons greater than C8, classifications medium and heavy petroleum distillates, from 10 microliters of ignitable liquids added to the surface of 100 milliliters of water. Gasoline and 50% evaporated gasoline were also recovered using the hydrophobic pads with 25 microliters of sample.

A method is proposed for producing carbon adsorbent as an extrudate based on heavy petroleum tar and various carbon fillers. To obtain sorbent granules, a heavy tar suspension is dissolved in excess heptane. With continuous mixing, filler is added to the solution, followed by concentrated sulfuric acid. After the formation of binder from the tar, the solid product is isolated. Green granules are extruded from the paste and then carbonized, with subsequent activation by steam. The proportions corresponding to carbon granules with the best specific surface (up to 900 m 2 /g) and mechanical strength are as follows: a 0.5 : 1 ratio of tar and filler; and a 1 : 1 ratio of acid and tar (by mass in both cases).When using two different fillers—walnut shell and coke from heavy tar—differences are noted in the micropore and mesopore structure of the carbon granules after activation: the samples based on coke have a more uniform micropore structure, with fewer mesopores. Since the parameters—the tar properties and the component ratios—may be closely controlled in the course of production, carbon granules with stable characteristics (specific surface, mechanical strength) may be produced.

The article presents a comparative assessment of various processes of demetallization of heavy petroleum feedstock (HPF). By the example of TAIF-NK JSC, which operates a slurry hydrocracking unit based on VCC process, the possibility of mastering secondary processes aimed at deepening oil refining is shown.

Biodesulfurization of fossil fuels is a promising method for treating the sour oil due to its environmental friendliness and ability to get rid of the recalcitrant organosulfur compounds. In this study, many types of microorganisms such as Ralstonia eutropha, Rhodococcus erythropolis, Acidithiobacillus ferrooxidans, and Acidithiobacillus thiooxidans applied on a sour heavy crude oil (sulfur content was 4.4%). Also, a colony isolated from the crude oil and oil concentrate was examined by supplying it with PTCC 106. The various official and famous mediums were significantly evaluated such as (PTCC 2, PTCC 105, PTCC 106 (9K), PTCC 116, PTCC 123, PTCC 132), sulfur-free MG-medium, basal salts medium, and mineral salts. It was found that Rhodococcus erythropolis and Acidithiobacillus ferrooxidans from microorganisms and SFM and the medium PTCC 105 were selected as the higher desulfurization efficiencies of crude oil equaling 47 and 19.74% respectively. The bioreactions depend on the treated fluid, targeting sulfur compounds as these represent the environmental status (amounts and types of nutrients), and the type of biotreaters whether microorganism are septic, semiseptic, or aseptic. The optimum operation conditions have been designed by using Definitive method such as mixing speed, temperature, surfactant dose, OWR, acidity. The optimum efficiencies obtained here are better than the previous efforts even though those gained by bioengineering. Biodesalination was a simultaneous process with the BDS.

The overall impact of a crude oil spill into a pristine freshwater environment in Canada is largely unknown. To evaluate the impact on the native microbial community, a large-scale in situ model experimental spill was conducted to assess the potential role of the natural community to attenuate hydrocarbons. A small volume of conventional heavy crude oil (CHV) was introduced within contained mesocosm enclosures deployed on the shoreline of a freshwater lake. The oil was left to interact with the shoreline for 72 h and then free-floating oil was recovered using common oil spill response methods (i.e. freshwater flushing and capture on oleophilic absorptive media). Residual polycyclic aromatic hydrocarbon (PAH) concentrations returned to near preoiling concentrations within 2 months, while the microbial community composition across the water, soil, and sediment matrices of the enclosed oligotrophic freshwater ecosystems did not shift significantly over this period. Metagenomic analysis revealed key polycyclic aromatic and alkane degradation mechanisms also did not change in their relative abundance over the monitoring period. These trends suggest that for small spills (<2 l of oil per 15 m2 of surface freshwater), physical oil recovery reduces polycyclic aromatic hydrocarbon concentrations to levels tolerated by the native microbial community. Additionally, the native microbial community present in the monitored pristine freshwater ecosystem possesses the appropriate hydrocarbon degradation mechanisms without prior challenge by hydrocarbon substrates. This study corroborated trends found previously (Kharey et al. 2024) toward freshwater hydrocarbon degradation in an environmentally relevant scale and conditions on the tolerance of residual hydrocarbons in situ.

The generation of hydrogen from unconventional oil is expected to increase significantly during the next decade. It is commonly known that hydrogen is an environmentally friendly alternative fuel, and its production would partially cover the gap in energy market requirements. However, developing new cheap catalysts for its production from crude oil is still a challenging area in the field of petroleum and the petrochemical industry. This study presents a new approach to synthesizing and applying promising catalysts based on Ni, Co, and Ni-Co alloys that are supported by aluminum oxide Al2O3 in the production of hydrogen from extra-heavy crude oil in the Tahe Oil Field (China), in the presence of supercritical water (SCW). The obtained catalysts were characterized via scanning electron microscopy (SEM), Brunauer-Emmett-Teller (BET) surface area analysis, transmission electron microscopy (TEM), and, X-ray diffraction analysis (XRD). The obtained XRD data showed 3.22% of Co2+ in the Co/Al2O4 catalyst, 10.89% of Ni2+ in the Ni/Al2O4 catalyst, and 1.51% of Co2+ and 2.42% of Ni2+ in the Ni-CoAl2O3 bimetallic catalyst. The BET measurements of the obtained catalysts showed a surface area ranging from 3.04 to 162 m2/g, an average particle size ranging from 0.037 to 0.944 µm, and micropore volumes ranging from 0.000377 to 0.004882 cm3/g. The thermal, SCW, and catalytic upgrading processes of the studied samples were conducted in a discontinuous autoclave reactor for 2 h at a temperature of 420 °C. The obtained results revealed that thermal upgrading yielded 1.059 mol.% of H2, and SCW led to 6.132 mol.% of H2; meanwhile, the presence of Ni-CoAl2O3 provided the maximal rate of hydrogen generation with 11.783 mol.%. Moreover, Ni-CoAl2O3 and NiAl2O3 catalysts have been found to possess good affinity and selectivity toward H2 (11.783 mol.%) and methane CH4 (40.541 mol.%). According to our results, the presence of SCW increases the yield of upgraded oil (from 34.68 wt.% to 58.83 wt.%) while decreasing the amount of coke (from 51.02 wt.% to 33.64 wt.%) due to the significant amount of hydrogen generation in the reaction zone, which reduces free-radical recombination, and thus, improves oil recovery. Moreover, the combination of SCW and the synthetized catalysts resulted in a significant decrease in asphaltene content in the upgraded oil, from 28% to 2%, as a result of the good redistribution of hydrogen over carbons (H/C) during the upgrading processes, where it increased from 1.39 to 1.41 in the presence of SCW and reached 1.63 in the presence of the Ni-CoAl2O3 catalyst. According to the XRD results of the transformed form of catalysts (CoNi3S4), after thermal processing, heteroatom removal from extra-heavy crude oil via oxidative and adsorptive desulfurization processes is promoted. These findings contribute to the expanding body of knowledge on hydrogen production from in situ unconventional oil upgrading.

Microbial Enhanced Oil Recovery (MEOR) is a potential technology for residual heavy oil recovery. Many heavy oil fields in Oman and elsewhere have difficulty in crude oil recovery because it is expensive due to its high viscosity. Indigenous microbes are capable of improving the fluidity of heavy oil, by changing its high viscosity and producing lighter oil fractions. Many spore-forming bacteria were isolated from soil samples collected from oil fields in Oman. Among the isolates, an autochthonous spore-forming bacterium was found to enhance heavy oil recovery, which was identified by 16S rDNA sequencing as Paenibacillus ehimensis BS1. The isolate showed maximum growth at high heavy oil concentrations within four days of incubation. Biotransformation of heavy crude oil to light aliphatic and aromatic compounds and its potential in EOR was analyzed under aerobic and anaerobic reservoir conditions. The isolates were grown aerobically in Bushnell-Haas medium with 1% (w/v) heavy crude oil. The crude oil analyzed by GC-MS showed a significant biotransformation from the ninth day of incubation under aerobic conditions. The total biotransformation of heavy crude oil was 67.1% with 45.9% in aliphatic and 85.3% in aromatic fractions. Core flooding experiments were carried out by injecting the isolates in brine supplemented with Bushnell-Haas medium into Berea sandstone cores and were incubated for twelve days under oil reservoir conditions (50°C). The extra recovered oil was analyzed by GC-MS. The residual oil recovered from core flood experiments ranged between 10-13% compared to the control experiment. The GC-MS analyses of the extra recovered oil showed 38.99% biotransformation of heavy to light oil. The results also indicated the presence of 22.9% extra aliphatic compounds in the residual crude oil recovered compared to that of a control. The most abundant compound in the extra recovered crude oil was identified as 1-bromoeicosane. The investigations showed the potential of P. ehimensis BS1 in MEOR technology by the biotransformation of heavy to lighter crude oil under aerobic and reservoir conditions. Heavy oil recovery and biotransformation to lighter components are of great economic value and a few studies have been done.

Heavy and extra heavy oil exploitation has attracted attention in the last few years because of the decline in the production of conventional crude oil. The high viscosity of heavy crude oil is the main challenge that obstructs its extraction. Consequently, catalytic aquathermolysis may be an effective solution to upgrade heavy crude oil to decrease its viscosity in reservoir conditions. In this regard, a series of acidic ionic liquids, 1-butyl-1H-imidazol-3-ium 4-dodecylbenzenesulfonate (IL-4), 1-decyl-1H-imidazol-3-ium 4-dodecylbenzenesulfonate (IL-10), and 1-hexadecyl-1H-imidazol-3-ium 4-dodecylbenzenesulfonate (IL-16), were utilized in the aquathermolysis of heavy crude oil. Of each IL, 0.09 wt % reduced the viscosity of the crude oil by 89%, 93.7%, and 94.3%, respectively, after the addition of 30% water at 175 °C. ILs with alkyl chains equal to 10 carbon atoms or more displayed greater activity in viscosity reduction than that of ILs with alkyl chains lower than 10 carbon atoms. The molecular weight and asphaltene content of the crude oil were decreased after catalytic aquathermolysis. The compositional analysis of the crude oil before and after catalytic aquathermolysis showed that the molar percentage of lighter molecules from tridecanes to isosanes was increased by 26–45%, while heavier molecules such as heptatriacontanes, octatriacontanes, nonatriacontanes, and tetracontanes disappeared. The rheological behavior of the crude oil before and after the catalytic aquathermolytic process was studied, and the viscosity of the crude oil sample was reduced strongly from 678, 29.7, and 23.4 cp to 71.8, 16.9, and 2.7 cp at 25, 50, and 75 °C, respectively. The used ILs upgraded the heavy crude oil at a relatively low temperature.

With the increasing scarcity of conventional light crude oil resources in our country, the efficient development of heavy oil resources is of great strategic significance for ensuring national energy security. Asphaltene, as the component with the strongest polarity and the largest molecular weight in heavy crude oil, is prone to association deposition phenomena due to internal component changes and the influence of external temperature and pressure environments, generating various engineering and technical problems. In this paper, the molecular dynamics simulation method is adopted to systematically reveal the interaction between asphaltene model compounds and dispersants, and analyze the interaction energy of the dissolution system. The simulation results show that the molecular weight, the number of conjugated rings, the length and quantity of alkyl side chains in asphaltene molecules all have significant effects on the aggregation behavior of asphaltene molecules. When the polarity of the solvent increases, the solubility of different asphaltenes decreases. In particular, for organic solvents, the interaction energy of perylene model compounds modified by benzene rings is relatively low, and for inorganic solvents, the interaction energy of perylene model compounds modified by heteroatoms is also relatively low. When a dispersant is present in the dissolution system, the solubility will further increase, but the degree of solubilization varies due to the influence of different molecular structures, the amount of dispersant and temperature. Therefore, these asphaltene model compounds can be utilized for simulation analysis to better explore the dissolution law and influencing factors of asphaltenes. It can also provide corresponding simulation methods for exploring the selection of asphaltene dispersants in the laboratory later, and offer guiding directions for the screening of efficient asphaltene dispersants.

Heavy oil resources are attracting considerable interest in terms of sustaining energy demand. However, the exploitation of such resources requires deeper understanding of the processes occurring during their development. Promising methods currently used for enhancing heavy oil recovery are steam injection methods, which are based on aquathermolysis of heavy oil at higher temperatures. Regardless of its efficiency in the field of in situ upgrading of heavy oil, this technique still suffers from energy consumption and inefficient heat transfer for deeper reservoirs. During this study, we have developed a molybdenum-based catalyst for improving the process of heavy oil upgrading at higher temperature in the presence of water. The obtained catalyst has been characterized by a set of physico-chemical methods and was then applied for heavy oil hydrothermal processing in a high-pressure reactor at 200, 250 and 300 °C. The comparative study between heavy oil hydrothermal upgrading in the presence and absence of the obtained molybdenum-based oil soluble catalysts has pointed toward its potential application for heavy oil in situ upgrading techniques. In other words, the used catalyst was able to reduce heavy oil viscosity by more than 63% at 300 °C. Moreover, our results have demonstrated the efficiency of a molybdenum-based catalyst in improving saturates and light hydrocarbon content in the upgraded oil compared to the same quantity of these fractions in the initial oil and in the non-catalytically upgraded oil at similar temperatures. This has been explained by the significant role played by the used catalyst in destructing asphaltenes and resins as shown by XRD, elemental analysis, and gas chromatography, which confirmed the presence of molybdenum sulfur particles in the reaction medium at higher temperatures, especially at 300 °C. These particles contributed to stimulating hydrodesulphurization, cracking and hydrogenation reactions by breaking down the C-heteroatom bonds and consequently by destructing sphaltenes and resins into smaller fractions, leading to higher mobility and quality of the upgraded oil. Our results add to the growing body of literature on the catalytic upgrading of heavy oil in the presence of transition metal particles.