Viscosity Reduction Of Crude Oil Research Articles

Synthesis and functionalization of carbon nanospheres from asphaltene fraction for crude oil upgrading and viscosity reduction

Nanoparticles provide a promising, cost-effective eco-friendly solution to the challenges posed by heavy-oil reservoirs, significantly enhancing oil recovery rates by reducing viscosity without requiring extensive thermal inputs. In this study, carbon nanospheres (CNSs) and functionalized-CNSs nanofluids were prepared by incorporating surfactants (T80 or BMIMCl). These nanofluids were evaluated for their efficacy in upgrading crude oil, particularly focusing on viscosity-reduction. Rheological tests were conducted across varying shear rates (60–300 s−1) and concentrations (0.02–3 wt.%) to comprehensively assess the impact of these additives on the crude oil’s proprieties. The results showed a notable enhancement in crude oil viscosity reduction, with the following order observed: CNS-TiO2 < CNS-TiO2/DMIMCl < CNS-TiO2/T80, yielding reduction rates of 95%, 95.83%, and 97.08%, respectively, at an optimal dosage of 2.75 wt.% and a shear rate of 300 s−1. The surface functionalization of CNS particles and their crystallinity are the main mechanisms driving the reduction in oil viscosity. Moreover, the properties of the crude oil were investigated upon the utilization of CNS-TiO2/T80 nanofluid. It was found that this nanofluid led to a substantial reduction in sulfur content by 78.32% and a significant decrease in the percentage of heavier molecules, ranging from C12 to C35 and up to C36, with 47.76% and 97.98%, respectively.

Study on low-heat synergistic chemical profile control and flooding technology in Bohai Oilfield

Introduction: Through the combination of hot water and chemical agent, the low-heat synergistic chemical profile control and flooding technology can not only reduce the risks of sand production and string damage caused by high-temperature thermal recovery technology, but also further improve the recovery factor on the basis of hot water flooding.Methods: Based on laboratory testing, the synergism mechanism of thermal energy and chemical agent is studied.Results: The research results showed that in the near wellbore zone of the injection well, crude oil viscosity reduction mainly relies on thermal energy, and chemical agents assist in improving the water oil mobility ratio and reducing the risk of cross flow. After entering the deep formation, due to the decrease in temperature, the thermal energy effect is weakened, but the chemical agents still aggregate at the oil-water interface and continue to act on heavy oil to reduce viscosity. The higher the temperature, the greater the role of heat energy, and the weaker the role of chemical agents. The higher the injection concentration of chemical agent, the more obvious the leading role of chemistry. Based on the comprehensive evaluation index, the optimized temperature is 80°C and the injection concentration is 1500 mg/L. The scheme study of Bohai L Oilfield shows that compared with cold water flooding, hot water flooding can only improve oil recovery by 1.2 percentage points, and low heat collaborative chemical profile control flooding technology can further improve oil recovery by 4.7 percentage points on the basis of hot water flooding, with obvious oil increase effect.Conclusion: It is suggested that Bohai L Oilfield should apply low-heat coordinated chemical profile control and flooding technology to improve the development effect of the oilfield, and provide new technical ideas for safe and economic development of offshore heavy oil.

Novel insights into the effects of asphaltenes on oil phase properties: Crude oil, oil-water interface, and graphene oxide synergistic demulsification

In this work, quantum chemical calculations and molecular dynamics simulations were employed to investigate the aggregation structure of asphaltene (a key component in heavy oil) and the influence of its molecular structure and content on the viscosity of heavy oil. Research suggests that the C5Pe molecules have a strong potential to bind together through π-π interactions (face-to-face). The angle between the two plane normal vectors was 1.4°. The mechanism of asphaltene-oil phase assembly can be succinctly summarized as the “rebar-cement” mode of action. The viscosity of heavy oil increases with the increase of asphaltenes, which can be attributed to the more complete construction of the three-dimensional network structure of asphaltene with the increase of asphaltene mass fraction (especially exceeding 35 wt%). The steered molecular dynamics simulation confirmed that reducing the concentration of asphaltenes in emulsified heavy oil droplets leads to increased susceptibility to mechanical destruction. This observation implies that asphaltenes negatively impact the demulsification and viscosity reduction of crude oil. The findings in this work can contribute to the development of efficient strategies for viscosity control and enhanced production of heavy oil resources.

Super-hydrophobic graphene-based high elastic sponge with superior photothermal effect for efficient cleaning of oil contamination

Oil spills are frequent and often accompanied by chemically corrosive and complex operating environments, so there is an urgent need for new absorbent materials that can absorb oil efficiently and with stable performance. Herein, we reported a reduced graphene oxide coated melamine sponge (F-rGO@MF) modified by silane grafting, which had excellent superhydrophobic/superoleophilic surface properties (WCA up to 157.7°), high absorption capacity (58.7–147.8 g/g) for a variety of oils, and could perform multiple absorption cycles. The separation efficiency of the oil/water mixture was as high as 99.32%, and the separation efficiency could still reach 97.48% after 80 separation cycles. The absorbent could also separate oil and water continuously by peristaltic pump. Besides, F-rGO@MF still retained floating and chemical stability under strong corrosive environment. More importantly, due to the photothermal property of rGO, the surface temperature of F-rGO@MF could rapidly rise to 101 °C under 1.0 kw/m2 light intensity for 225 s, which was contribute to the viscosity reduction of crude oil and absorbed 14.75 g of crude oil in 7 min, providing the possibility of absorbing high viscosity oil spills.

Feasibility and Mechanism of Deep Heavy Oil Recovery by CO2-Energized Fracturing Following N2 Stimulation

There are large, heavy oil reserves in Block X of the Xinjiang oilfields, China. Due to its large burial depth (1300 m) and low permeability (26.0 mD), the traditional steam-injection technology cannot be used to obtain effective development benefits. This paper conducts experimental and simulation research on the feasibility and mechanism of CO2-energized fracturing of horizontal wells and N2 foam huff-n-puff in deep heavy oil reservoirs with low permeability in order to further explore the appropriate production technology. The foaming volume of the foaming agent at different concentrations and the oil displacement effect of N2 foam at different gas/liquid ratios were compared by the experiments. The results show that a high concentration of foaming agent mixed with crude oil is more conducive to increasing the foaming volume and extending the half-life, and the best foaming agent concentration is 3.0∼4.0%. The 2D micro-scale visualization experiment results show that N2 foam has a good selective blocking effect, which increases the sweep area. The number of bubbles per unit area increases as the gas/liquid ratio increases, with 3.0∼5.0 being the optimal gas/liquid ratio. Numerical simulation results show that, when CO2-energized fracturing technology takes into account the advantages of fracturing and crude oil viscosity reduction by CO2 dissolution, the phased oil recovery factor in the primary production period can reach approximately 13.7%. A solvent pre-slug with N2 foam huff-n-puff technology is applied to improve oil recovery factor following primary production for 5∼6 years, and the final oil recovery factor can reach approximately 35.0%. The methodology formulated in this study is particularly significant for the effective development of this oil reservoir with deeply buried depth and low permeability, and would also guide the recovery of similar oil deposits.

Study on the thermal storage performance of a new electric heating device with phase change materials

The heating method for reducing the viscosity of crude oil is mainly electric heating currently. In order to meet the needs of environmental protection and industrial production, a new electric heating device with phase change thermal storage is designed by combining the crude oil viscosity reduction heating method, off-peak electricity, and phase change materials. Numerical simulation research is carried out for the phase change thermal storage and release performance of the device, and the structure is optimized according to the research results. Also, the influences of different inlet flow rates and metal foams porosity on the heat release process are analyzed. The results show that the outlet temperature decreases continuously with the increase of the working medium inlet flow rate. With the addition of nickel foam, the internal temperature of PCMs becomes more uniform as the porosity of the added metal foam decreases in the range of 0.7–1.0. Using this device to reduce the viscosity of crude oil cannot only maintain high heat exchange efficiency but also reduce production costs, which provides a reference for the design and operation of crude oil viscosity reduction methods.

Experimental and Numerical Investigation on Infilled Vertical Well LASER-Assisted SAGD

In the SAGD process with dual horizontal wells in heterogeneous reservoirs, the injection pressure of steam huff-n-puff by infilled interwell vertical wells is too high, and the heat communication between SAGD wellpairs and infilled wells is too long, which leads to a series of problems. The solvent-assisted vertical well stimulation (LASER) technology is proposed to solve the problems above. The solvent formula was optimized, and its key mechanism was studied by viscosity reduction experiments, multicomponent phase behavior experiments at high temperature and high pressure, and scaled two-dimensional physical experiments. The experimental results show that when adding 10% 2# or 3# solvent oil, the viscosity reduction of crude oil can reach 96.65% and 96.73%, respectively. The HTHP visualized phase behavior experiment results show that the mixture of low flash point solvent oil 2# with high flash point solvent oil 3# (volumetric ratio 3 : 2) has excellent high temperature oil solubility stability and is similar to water vapor phase behavior, so it is determined as the ideal formula. The scaled two-dimensional physical experiment results show that the solvent-assisted vertical well huff-n-puff has the key mechanism of reducing injection pressure and porous flow resistance, expanding the sweep region of injected fluid and accelerating thermal communication. The cycle of huff-n-puff was reduced from 6 to 3, which greatly shortened the thermal communication time. From the scaled physical experiments, the oil rate and the oil recovery of SAGD were improved by 19.86% and 6.3%, respectively. Field-scale numerical simulation was performed, and the production performance compared with SAGD and conventional infilled CSS-SAGD was investigated, which shows that by adding solvent into steam stimulation, 6 cycles were reduced, and the incremental oil recovery factor was 27.3% and 13.2%, respectively. The performance of accelerating thermal communication and production improvement by LASER has been validated by 4 SAGD wellpairs in field practice, and its long-term prediction result shows significant potential in similar heterogeneous SAGD reservoirs.

Photothermal bio-based membrane via spectrum-tailoring and dual H-bonding networks strategies for seawater treatment and crude oil viscosity reduction

To reach global carbon neutralization, the use of clean energy and biomaterials has become a trend to reduce CO2 emission. With the increasing concerns about freshwater shortage and crude oil pollution, water purification and sewage treatment have become particularly urgent. Solar energy is an environment-friendly energy to mitigate freshwater shortage stress and reduce crude oil pollution. However, how to make solar energy applied to effectively drive freshwater generation and crude oil pollution remedy is crucial. Herein, the electrospun membrane was explored as sustainable matrix with desirable solar-to-thermal performance. The strategy of spectrum-tailoring was proposed to tailor bandgap energy of vanadium disulfide (VS2) for photothermal conversion promotion and interfacial evaporation efficiency. Inspired by mussel, dopamine was polymerized on surface of VS2 (VS2@PDA) for spectrum tailoring (Solar absorptance, α, is 89.34 %). Bandgap energy of the complex favorably decreased from 2.06 to 1.41 eV. Combining the dual H-bonding networks, water evaporation enthalpy of the membranes dramatically decreased from 2370 to 1990.2 J/g and the resulted evaporators showed excellent salt resistance, with evaporation rate of 1.40 kg m-2h−1 (enhancement factor is 2.032) and extraordinary cyclic evaporation performance. Additionally, sunflower-inspired tilting model was architectured to eliminate disturbance of sun irradiation incident angles for effective solar-driven interfacial generation. The resulted membrane effectively treated the seawater and decreased high viscosity of the super-viscous crude oil under the sun irradiation, thus showing great potential in seawater treatment and crude oil pollution remedy. The designs maximized utilization of solar energy and evaporation rates by treating seawater and reducing crude oil pollution without consuming additional energy, thus contributing to carbon neutralization. Therefore, the integration of dual H-bonding networks and spectrum-tailoring strategies would facilitate the structure-functional unification and desirable photothermal capabilities, and bring about an application potential in the development of composite evaporators for carbon neutralization.

Performance of thermophilic strain on the reduction of viscosity of crude oil under high pressure and high temperature conditions: Experiments and modeling

The matured reservoirs all over the world leads on the way to highly viscous crude oil. The heavy and waxy oil would act as an alternative to conventional reserves, only with the application of a technology to reduce the viscosity. This study aims to analyze the microbial activity on crude oil, and the synergetic effect of microbial interaction, pressure and temperature on viscosity. The reports on application of microorganisms on the viscosity reduction of crude oil are very rare at high temperature and high pressure environment. The application of Bacillus subtilis , a thermophilic bacterium for improving the flow properties of waxy crude oil is investigated at various temperatures and pressures in a high pressure cell. This study has been carried out to simulate the microbiological phenomenon occurring in the reservoir, when a bacteria is introduced for viscosity reduction. Bacillus subtilis could grow well from 0.1 to 5 MPa, and less growth was observed at 10 MPa. The maximum 52.1% of viscosity of crude oil was reduced at the pressure of 1 MPa, temperature of 50 °C, and at the shear rate of 1000 s −1 by microbial interaction. The implicit correlations as a function of pressure, temperature, and shear rate has been developed to predict the viscosity of crude oil during the microbial treatment. This work also proposed a new model incorporating the thermodynamic and microbial kinetics to estimate the viscosity of crude oil during the process of microbial degradation. The proposed model has provided satisfactory predictions when compared with the experimental values of degradation. All these findings demonstrate the influence and suitability of Bacillus subtilis in crude oil production and transportation. • Suitability of Bacillus subtilis at high temperature and pressure was explored. • Interaction of crude oil and Bacillus subtilis were examined for viscosity reduction. • Analyzed the synergetic effect of pressure and temperature on viscosity reduction. • Viscosity of crude oil was reduced by 52.1% at 1 MPa, 50 °C, and 1000 s −1 . • Proposed a model to predict viscosity during microbial degradation of crude oil.

Viscosity reduction of heavy crude oil by co-heating with hydrothermal liquid product of cotton stalk

Abstract Hydrothermal process (HT) is an economical and simple method in upgrading agriculture wastes. The liquid product obtained from HT is interesting because of abundant active chemical group. The present work tried to co-heat the HT liquid product of cotton stalk (CS) with heavy crude oil to reduce its viscosity. The optimization study was performed to obtain the best condition of co-heating and mechanism study was completed by comparing the viscosity reduction efficiency and analyzing group composition of crude oil before and after co-heating with HT liquid products of CS, cellulose, hemicellulose and lignin. The results show that the crude oil viscosity reduced obviously after co-heating with CS-HT liquid product under the optimized condition (220°C, 1 h, 3 g treatment liquid, 30 ml crude oil). The preliminary mechanism study results suggest that the main function component of CS that cause viscosity reduction of heavy oil is lignin. The current work provides a new idea of lignocellulosic biomass upgrading and heavy crude oil viscosity reduction.

Molecular dynamics study on emulsified oil droplets with nonionic surfactants

The stability of heavy crude oil is closely related to the netlike structure formed by the aggregation of asphaltene and resin molecules inside the oil droplets, and the aggregation is too complex to accurately obtain the microstructure of these molecules experimentally. In this paper, molecular dynamics (MD) simulation was performed to investigate the structure of emulsified oil droplets on the molecular level. The simulation results showed: (i) The stacking structure of asphaltene and resin molecules form the netlike structure of the oil droplet, and it is also considered as the main reason of high stability and viscosity of heavy crude oil. (ii) When nonionic surfactants were introduced, some of them can adsorb to the surface of oil droplet and change its hydrophilicity; others can enter the interior of the oil droplets and destroy the stacking structure of asphaltene or resins inside the oil droplet. The decreased viscosity of emulsified heavy oil in the present of surfactants attributed to the increase of hydrophilicity on the oil drop surface and the damage of stacking structure inside the oil drops. (iii) the steered molecular dynamics (SMD) simulation proved that the mechanical properties of emulsified heavy oil droplet become easier to be destroyed with the increase of surfactant concentration, and it indicates that nonionic surfactant is beneficial to promote demulsification and viscosity reduction of crude oil.

Influence of poly (stearyl acrylate co-behenyl acrylate) as flow improvers on the viscosity reduction of Malaysian crude oil

Pipelines are the most appropriate means of transporting crude oils in different parts of the world. Nevertheless, the high viscosity of crude oil at low temperatures is one of the main challenges when transporting crude oils through the pipeline, which needs adequate and expensive methods of transporting crude oil, and wax depositions in the pipeline that is caused by high viscosity of crude oil. Therefore, several ways have been investigated to boost the mobility of crudes in stimulating pipeline transportation. In this study, poly (stearyl acrylate co-behenyl acrylate) (SA-co-BA) pour point depressant PPD copolymer was synthesized as flow improvers for reducing the viscosity of crude oil to improve the flowability. SA-co-BA copolymer has been synthesized by using free-radical polymerization method and characterized by FTIR. The viscosity of blank crude oil increases with decreasing temperature after the addition of (SA-co-BA) copolymer to the blank crude oil at various concentrations. The results exhibited that the mass ratio (1:2) at a concentration of 1000 ppm was the highest performance of viscosity reduction by 90.57% from 70 mPa.s to 6.6 mPa.s at 5 °C of crude oil temperature. The influence of the (SA-co-BA) copolymer was clearly seen on the viscosity reduction of crude oil at different conditions, because of the acrylate groups which have a long alkyl chain. It is observed that a major reduction in the viscosity of the crude oil sample was observed at low temperatures, which makes it a reasonable recommendation for offshore applications. The results of characterization revealed that FTIR characteristics showed absorption peaks at 2914.86 cm−1 and 2848.09 cm−1, respectively, as typical absorption peaks of CH3– and –CH2-. The ester group's sharp absorption peak C = O was recorded at 1731.71 cm−1. Therefore, SA-co-BA copolymer recorded an appreciable minimization in the viscosity of crude oil.

Analysis of the viscosity reduction of crude oil with nano-Ni catalyst by acoustic cavitation

The present study discusses ultrasound wave and heterogeneous catalysts act synergistically on viscosity reduction of crude oil. The reasons for the possible viscosity reduction were analyzed from the structural changes of asphaltene. This paper presents a systematic and unified approach to analyzing asphaltene clusters structure based on FTIR spectra and XRD patterns. The results reveal that the cavitation effect can be intensified by the addition of metallic nickel particles. The cavitation effect destroys the spatial network structure formed by resin, asphaltene and wax crystals, so that the viscosity of the treated oil sample tends to be stable. With the addition of metallic nickel particles which has a synergistic effect on cavitation, the asphaltene molecules have undergone a cracking reaction and decomposed into small molecular hydrocarbon compounds, contributing to viscosity reduction. However, when added a certain amount of metallic nickel particles, the degree of surface cavitation leads to increasing number of cavitation bubbles, free radicals recombination, and aromatic hydrocarbons polymerizing to form secondary asphaltenes. This leads to a slight rise in viscosity.

Heavy crude oil viscosity reduction by dilution with hydrocarbons obtained via pyrolysis of polypropylene and polystyrene

Liquid hydrocarbons obtained from the pyrolysis of polypropylene and polystyrene were used as diluents to reduce the viscosity of a Mexican heavy crude oil of 10.6°API. Blends of oil and diluents were formulated with fractions of 5, 10 and 15 vol% of diluent. Viscosity results were plotted as a function of temperature and diluent volume fractions. The degree of viscosity reduction at room temperature was of 96 – 97% using 15 vol% of the proposed materials. Results show that viscosities lower than 400 cP, the classical maximum for pipeline transportation, are achieved at relatively low temperatures (45 – 65 °C).

Effect of N2O produced by indigenous denitrifiers in oil reservoir on the physical properties of crude oil

The success of microbial enhanced oil recovery (MEOR) relies on complex microbial processes. Nevertheless, the contribution and mechanism of in-situ denitrification to microbial oil recovery remain unclear. In this study, eight denitrifying bacterial strains, designated T1, D1, D44, D46, D15, S1, S2 and S6, were isolated from the produced water of Xinjiang Oilfield, China, by a double layered plate method. The16S rDNA gene sequences of these denitrifying strains shared 100% similarity with Pseudomonas stutzeri (T1, D1, and D44), Pseudomonas putida (D46 and D15), and Pseudomonas aeruginosa (S1, S2, S6), respectively. The N2O production effects of these strains on the physical properties of crude oil were evaluated with batch experiment. Results showed that the highest total gas yield was observed with sucrose as carbon source, and the maximal concentration of N2O occurred with glycerol as carbon source. The denitrification process by these bacterial strains led to volume expansion and viscosity reduction of crude oil. Crude oil expansion rate was positively correlated with the concentration of N2O, with a correlation coefficient of 0.983, but not correlated with the volume of total gas production. Strain S1, S2, and S6 produced 530-730 mg·L-1 of surfactant using glycerol as ole carbon source, which could reduce surface tension and emulsify crude oil. However, these surfactant-producing strains produced less N2O, exhibited weaker effects on oil swelling and viscosity reduction, compared to the none-surfactant-producing denitrifying strains. Our results suggested that more attention should be paid to the ability of N2O production by denitrifying bacteria when exploiting microbial resources towards enhancing oil recovery.

The Influence of Infrasonic Impacts on the Crude Oil Viscosity Reduction

The Influence of Infrasonic Impacts on the Crude Oil Viscosity Reduction

Effect of organic alkali, n-alkanol, and nonionic surfactant ternary compound system on viscosity reduction of viscous crude oil

To reduce the viscosity of viscous crude oil and flow resistance, the effect of a ternary compound system including organic alkali, n-alkanol, and nonionic surfactants on viscous crude oil viscosity reduction was studied. The results showed that n-alkanol effectively reduced the droplet size of an emulsion and the viscosity of viscous crude oil and improved the fluidity of viscous crude oil. Of the low-carbon n-alkanols, n-pentanol has the best viscosity-reducing effect. The organic alkali avoids the phenomenon of fouling and corrosion caused by inorganic alkali and reacts with the acidic macromolecular components in viscous crude oil to generate alkanolamides, which produce synergistic effects with nonionic surfactants and reduce the interfacial tension between oil and water. In the ternary compound of organic alkali, n-alkanol, and nonionic surfactant, the viscosity reduction effect of viscous crude oil is significantly enhanced compared with that of a single reagent. The viscosity reduction rate of viscous crude oil of the diethanolamine ternary compound system reached 98.1% and was the best choice by experimental validation. It is shown that a reasonable formula of compound system and dosage can significantly reduce the viscosity of viscous crude oil.

Tertiary Amine‐Naphthenic Acid Self‐Assembled Surfactants for Viscosity Reduction of Crude Oil

AbstractThe formation of low‐viscosity emulsions is a vital method for viscosity reduction of crude oil. Naphthenic acids, which are present in crude oil, are potential surface‐active substances. Tertiary amines with CO2 response can be self‐assembled in situ with the naphthenic acids in the crude oil to form a surfactant, which can emulsify the heavy crude oil and water to form an emulsion. The emulsion can be easily demulsified in the presence of CO2. N,N‐Dimethylbutylamine, N,N‐dimethyloctylamine, and N,N‐dimethyldodecylamine were used to prepare heavy crude oil emulsions in this work. This convenient emulsification and demulsification approach provides a new concept for pipeline transportation of heavy crude oil.

Experimental study of Iranian heavy crude oil viscosity reduction by diluting with heptane, methanol, toluene, gas condensate and naphtha

Abstract Due to the high viscosity of heavy crude oils, production from these reservoirs is a demanding task. To tackle this problem, reducing oil viscosity is a promising approach. There are various methods to reduce viscosity of heavy oil: heating, diluting, emulsification, and core annular flow. In this study, dilution approach was employed, using industrial solvents and gas condensate. The viscosity of two Iranian heavy crude oils was measured by mixing with solvents at different temperatures. Dilution of both oil samples with toluene and heptane, resulted in viscosity reduction. However, their effect became less significant at higher concentrations of diluent. Because of forming hydrogen bonds, adding methanol to heavy crude oil resulted in higher viscosity. By adding condensate, viscosity of each sample reduced. Gas condensate had a greater impact on heavier oil; however, at higher temperatures its effect was reduced. Diluting with naphtha decreased heavy oil viscosity in the same way as n-heptane and toluene. Besides experimental investigation, different viscosity models were evaluated for prediction of heavy oil/solvent viscosity. It was recognized that Lederer' model is the best one.

ON STABILITY OF THE OIL DISPLACEMENT FRONT UNDER CONDITIONS OF THERMOGAS IMPACT ON THE OIL BEARING LAYER

The method of thermogas impact on the oil bearing layer is a perspective one to improve oil recovery. It is now under experimental implementation in Belarus. Stability of the thermal front and that of the oil displacement is a point of principle for the given technology. The article offers solution based on the method of small perturbations for the problem of the oil-displacement front stability under thermogas impact on the oil layer. The perturbation growth increment is shown to be quite different from that of the gas filtration combustion. Being determined by the perturbation wave number (or wave length), by difference in speed of the blowing filtration and that of the heat development front, by the ratios of densities, filtration coefficients, compressibility of the displacement agent and the displaced oil mass, and by other parameters. The author analyses the main parameters influencing the stability of the front. Recommendations are given on possible methods and procedures improving stability of the displacement front (neutralizing perturbation growth). The mechanisms of suppression or compensation of the front perturbation growth are as follows: the crude oil viscosity reduction and increase of that of the displacement agent, the displacement agent compressibility increase, increase of the thermogas impact heat-front width in the first instance at the expense of the temperature growth and alteration in the chemism (low temperature catalysts utilization, etc.), reduction in speed of the front propagation and/or correspondingly of the displacement agent feed. Utilization of the gas or water-gas displacement agent as well as the agent impregnation with hydrophobic gases provides a relatively better stability of the front as compared to that employing water based compounds. Analytical data and derived recommendations are offered for utilization within the framework of general techniques and procedures of the thermogas impact process management in the context of developmental and experimental-industrial oil extraction. Further research into methods and mechanisms of the displacement front perturbation compensation, including the front dynamics at nonlinear stage, might be conducted via detailed 2D and 3D numerical simulation of the system.