scholarly journals Aquathermolysis of high-viscosity oil terrigenic sediments in the presence of iron oxide (II, III)

2021 ◽  
Vol 3 (3) ◽  
pp. 75-81
Author(s):  
A. V. Vakhin ◽  
S. A. Sitnov ◽  
I. I. Mukhamatdinov
Keyword(s):  
Iron Oxide ◽  
Oil Recovery ◽  
Heavy Oil ◽  
High Viscosity ◽  
Steam Treatment ◽  
Thermal Methods ◽  
Water Steam ◽  
Catalytic Aquathermolysis ◽  
Stage Of Development ◽  
Hydrocarbon Fields

Nowadays, it is especially important and relevant to improve the efficiency of existing methods of enhanced oil recovery, in particular, thermal methods using water steam. The use of catalysis at the stage of development of unconventional hydrocarbon fields, namely super-viscous and bituminous oils, will allow solving this problem. This work is devoted to the study of the transformation of heavy oil from the Ashalchinskoye field in the process of catalytic aquathermolysis. The oil samples were extracts from sandstone, which was subjected to thermal steam treatment in a high-pressure reactor at temperatures of 200 and 250C for 24 h. Nanosized iron (II, III) oxide in complex with a hydrogen donor was used as a catalytic composition. According to the results of SARA-analysis, it was found that at a temperature of 200C, iron oxide does not show its catalytic properties, and there is no noticeable improvement in the composition of heavy oil. The destruction of resins and asphaltenes is observed after thermocatalytic treatment at 250C. This leads to the enrichment of oil with lighter hydrocarbons, which is confirmed by GC-MS data of the saturated fraction of oil. All this provides a significant decrease in the viscosity of heavy oil compared to the non-catalytic process from 1140 cP to 37 cP The formation of coke-like substances adsorbed on sandstone as a result of thermocatalytic action at 250C was revealed by the results of TG-DSC.

scholarly journals EFFICIENCY IMPROVEMENT OF THE CYCLIC STEAM TREATMENT OF WELLS IN THE UPPER PERMIAN DEPOSIT OF THE USINSKOYE FIELD BASED ON THE HYDRODYNAMIC MODEL

2020 ◽  
Vol 20 (2) ◽  
Author(s):  
Maksim B. Savchik ◽  
◽  
Daria V. Ganeeva ◽  
Aleksei V. Raspopov ◽  
◽  
...  
Keyword(s):  
Oil Recovery ◽  
Steam Injection ◽  
High Viscosity ◽  
Steam Treatment ◽  
Upper Permian ◽  
Physical Factors ◽  
Thermal Methods ◽  
Optimum Parameters ◽  
Wide Range ◽  
Permian Deposit

Development of the Upper Permian high viscosity oil deposit is expected to involve thermal methods of enhanced oil recovery, in particular, cyclic steam treatment of wells. The simulator used for the deposit modeling is to be capable of computing the change in the rock fluid thermal properties, and of solving the heat and mass transfer equations. The modeling of the cyclic steam treatments used CMG STARS, a numerical simulator with a wide range of applications including modeling of thermal processes. The cyclic steam treatment includes three basic stages, such as the steam injection period, the soak period, and the production period. The number of cycles has been selected by computation on the basis of an optimum well operation. To determine the optimum quantity, computations with 7, 5 and 3 cycles were performed. Another predictive computation was performed for a well operation without cyclic steam treatments. The computations helped to determine the operation scenario with the highest cumulative oil production. During the assessment of the cyclic steam treatment efficiency by using hydrodynamic modeling, we obtained dependencies on a number of geological and physical factors, such as steam dryness fraction, formation thickness, steam injection rate, soaking time. The numerical experiments resulted in conclusions and recommendations concerning the case-by-case approach to selecting optimum parameters of the cyclic steam treatments for each individual well, taking into account the structure and specific features. Factor analysis was used to select the optimum parameters for the cyclic steam treatment of the wells drilled in the Upper Permian deposit of the Usinskoye field. For comparison, three predictive scenarios of the well operation have been computed. Cost-performance indicators of the well operation scenarios in the Upper Permian deposit of the Usinskoye field were evaluated, assuming that the wells will be operated in conditions of the natural recovery drive and multiple cyclic steam treatments, in the baseline and recommended scenarios.

scholarly journals Innovative methods of enhanced oil recovery

2021 ◽  
Author(s):  
Smirnov VI ◽  
Sudad H Al-Obaidi
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Steam Injection ◽  
High Viscosity ◽  
Steam Treatment ◽  
Thermal Methods ◽  
Natural Production ◽  
Innovative Methods

The production of oil and gas from hydrocarbon reservoirs with the aging of these reservoirs makes them consuming their natural production energy and become depleted. Then, conducting researches and investigations to use other energy resources to improve oil production becomes an urgent need. The article presents the generaldirections of methods for enhancing oil recovery and focuses on steam-thermal methods. Based on the classification of enhanced oil recovery methods, it has been shown that thermal methods (in particular, thermal steam) are the most favourable when applied in fields with a depth of about 1000 meters. The technology of cyclic steam injection is presented and the main stages of this process are indicated. Recommendations on the technology of steam-thermal treatment are given. For example, two oil fields have been selected to show the efficiency of the use of thermal steam treatment for reservoirs with high-viscosity oils.

scholarly journals The Prospect of Electrical Enhanced Oil Recovery for Heavy Oil: A Review

2020 ◽  
Vol 8 (2) ◽  
pp. 73-94
Author(s):  
Muhammad Khairul Afdhol ◽  
Tomi Erfando ◽  
Fiki Hidayat ◽  
Muhammad Yudatama Hasibuan ◽  
Shania Regina
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
New Technology ◽  
High Viscosity ◽  
Electrical Heating ◽  
Oil Viscosity ◽  
Thermal Methods ◽  
Excessive Heat ◽  
Light Oil ◽  
Oil Crisis

This paper presents a review of electrical heating for the recovery of heavy oil which the work adopts methods used in the past and the prospects for crude oil recovery in the future. Heavy oil is one of the crude oils with API more than 22 which has the potential to overcome the current light oil crisis. However, high viscosity and density are challenges in heavy oil recovery. The method is often used to overcome these challenges by using thermal injection methods, but this method results in economic and environmental issues. The electrical heating method could be a solution to replace conventional thermal methods in which the methodology of electrical heating is to transfer heat into the reservoir due to increasing oil mobility. Because the temperature rises, it could help to reduce oil viscosity, then heavy oil will flow easily. The applications of electrical heating have been adopted in this paper where the prospects of electrical heating are carried out to be useful as guidelines of electrical heating. The challenge of electrical heating is the excessive heat will damage the formation that must be addressed in the prospect of electrical heating which must meet energy efficiency. The use of Artificial intelligence becomes a new technology to overcome problems that are often found in conventional thermal methods where this method could avoid steam breakthrough and excessive heat. Therefore, it becomes more efficient and could reduce costs.

A New Approach Utilizing Liquid Catalyst for Improving Heavy Oil Recovery

2021 ◽  
Vol 143 (7) ◽  
Author(s):  
Ali Alarbah ◽  
Ezeddin Shirif ◽  
Na Jia ◽  
Hamdi Bumraiwha
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
High Viscosity ◽  
Heavy Oil Recovery ◽  
Oil Viscosity ◽  
Recovery Processes ◽  
Reduced Viscosity ◽  
Effective Form ◽  
Recovery Techniques ◽  
Original Oil In Place

Abstract Chemical-assisted enhanced oil recovery (EOR) has recently received a great deal of attention as a means of improving the efficiency of oil recovery processes. Producing heavy oil is technically difficult due to its high viscosity and high asphaltene content; therefore, novel recovery techniques are frequently tested and developed. This study contributes to general progress in this area by synthesizing an acidic Ni-Mo-based liquid catalyst (LC) and employing it to improve heavy oil recovery from sand-pack columns for the first time. To understand the mechanisms responsible for improved recovery, the effect of the LC on oil viscosity, density, interfacial tension (IFT), and saturates, aromatics, resin, and asphaltenes (SARA) were assessed. The results show that heavy oil treated with an acidic Ni-Mo-based LC has reduced viscosity and density and that the IFT of oil–water decreased by 7.69 mN/m, from 24.80 mN/m to 17.11 mN/m. These results are specific to the LC employed. The results also indicate that the presence of the LC partially upgrades the structure and group composition of the heavy oil, and sand-pack flooding results show that the LC increased the heavy oil recovery factor by 60.50% of the original oil in place (OOIP). Together, these findings demonstrate that acidic Ni-Mo-based LCs are an effective form of chemical-enhanced EOR and should be considered for wider testing and/or commercial use.

Thirty Years of Experience in the Application of Thermal Methods of Heavy Oil Recovery in the Permian-Carboniferous Reservoir of the Usinsk Field

2012 ◽  
Author(s):  
Evgenii N. Taraskin ◽  
Stanislav Ursegov ◽  
Vladimir Muliak ◽  
Mikhail Vasilievich Chertenkov ◽  
Andrey Alabushin
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Years Of Experience ◽  
Heavy Oil Recovery ◽  
Thermal Methods

Indoor Study of Viscosity Reducer for Thickened Oil of Huancai

2012 ◽  
Vol 268-270 ◽  
pp. 547-550
Author(s):  
Qing Wang Liu ◽  
Xin Wang ◽  
Zhen Zhong Fan ◽  
Jiao Wang ◽  
Rui Gao ◽  
...  
Keyword(s):  
Interfacial Tension ◽  
Oil Recovery ◽  
Heavy Oil ◽  
High Viscosity ◽  
Oil Field ◽  
Viscosity Reduction ◽  
Oil Viscosity ◽  
Low Viscosity ◽  
Viscosity Reducer ◽  
Oil Water

Liaohe oil field block 58 for Huancai, the efficiency of production of thickened oil is low, and the efficiency of displacement is worse, likely to cause other issues. Researching and developing an type of Heavy Oil Viscosity Reducer for exploiting. The high viscosity of W/O emulsion changed into low viscosity O/W emulsion to facilitate recovery, enhanced oil recovery. Through the experiment determine the viscosity properties of Heavy Oil Viscosity Reducer. The oil/water interfacial tension is lower than 0.0031mN•m-1, salt-resisting is good. The efficiency of viscosity reduction is higher than 90%, and also good at 180°C.

scholarly journals Influence of Oil Viscosity on Alkaline Flooding for Enhanced Heavy Oil Recovery

2013 ◽  
Vol 2013 ◽  
pp. 1-8 ◽  
Author(s):  
Yong Du ◽  
Guicai Zhang ◽  
Jijiang Ge ◽  
Guanghui Li ◽  
Anzhou Feng
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
High Viscosity ◽  
Low Permeability ◽  
Oil Viscosity ◽  
Low Viscosity ◽  
Medium Permeability ◽  
Tertiary Oil Recovery ◽  
Different Temperatures ◽  
Water Drops

Oil viscosity was studied as an important factor for alkaline flooding based on the mechanism of “water drops” flow. Alkaline flooding for two oil samples with different viscosities but similar acid numbers was compared. Besides, series flooding tests for the same oil sample were conducted at different temperatures and permeabilities. The results of flooding tests indicated that a high tertiary oil recovery could be achieved only in the low-permeability (approximately 500 mD) sandpacks for the low-viscosity heavy oil (Zhuangxi, 390 mPa·s); however, the high-viscosity heavy oil (Chenzhuang, 3450 mPa·s) performed well in both the low- and medium-permeability (approximately 1000 mD) sandpacks. In addition, the results of flooding tests for the same oil at different temperatures also indicated that the oil viscosity put a similar effect on alkaline flooding. Therefore, oil with a high-viscosity is favorable for alkaline flooding. The microscopic flooding test indicated that the water drops produced during alkaline flooding for oils with different viscosities differed significantly in their sizes, which might influence the flow behaviors and therefore the sweep efficiencies of alkaline fluids. This study provides an evidence for the feasibility of the development of high-viscosity heavy oil using alkaline flooding.

scholarly journals Application of an Oil-Displacing Composition for Increasing Flow Rate of Low Producing High-Viscosity Oil Wells of the Usinskoye Oil Field

2016 ◽  
Vol 18 (2) ◽  
pp. 133
Author(s):  
L.K. Altunina ◽  
I.V. Kuvshinov ◽  
V.A. Kuvshinov ◽  
V.S. Ovsyannikova ◽  
D.I. Chuykina ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Oil Production ◽  
High Viscosity ◽  
Oil Field ◽  
Thermal Methods ◽  
Cold Stimulation ◽  
Well Production ◽  
Well Stimulation ◽  
High Viscosity Oil ◽  
Stimulation Of

The results of a pilot application of a chemical composition for enhanced oil recovery developed at the IPC SB RAS are presented. The EOR-composition was tested in 2014 at the Permian-Carboniferous heavy oil deposit at the Usinskoye oil field. It is very effective for an increase in oil production rate and decrease in water cuttings of well production. In terms of the additionally produced oil, the resulting effect is up to 800 tons per well and its duration is up to 6 months. The application of technologies of low-productivity-well stimulation using the oil-displacing IKhNPRO system with controlled viscosity and alkalinity is thought to be promising. This composition is proposed for the cold’ stimulation of high-viscosity oil production as an alternative to thermal methods.

The heat exchange intensification under incomplete hydrophobization oil reservoirs

2019 ◽  
Vol 5 (4) ◽  
pp. 58-78
Author(s):  
Rustam Sh. Salikhov ◽  
Ruslan F. Mazitov ◽  
Yuriy V. Pacharukov
Keyword(s):  
Oil Recovery ◽  
Layer Structure ◽  
Adsorbed Layer ◽  
Mathematic Model ◽  
High Viscosity ◽  
Limiting Factor ◽  
Surface Acting ◽  
Thermal Methods ◽  
Acting Agent ◽  
High Viscosity Oil

High-viscosity oil recovery often requires thermal methods of enhanced oil recovery combining surface acting agent (SAA) injection. Thermal treatment allows increasing hydrocarbon movability. Efficiency raisings’ limiting factor of this method includes injecting agent’s thermal loss (water and steam) as well as SAA molecules thermal destruction. This article assesses nanoparticles adding in SAA water solution’s influence. The authors consider a theoretic capability of increasing heat exchange’s inetnsity between oil reservoir and injected agents by means of adding nanoparticles as well as increase of the SAA thermostability’s capability under high temperatures influence. The results of the laboratory experiments on SAA’s adsorbed layer structure on the surface of solid state show the structure’s dependence on SAA concentration in the solution. According to the developed mathematic model, a periodic adsorbed field will lead to the increase of heat transfer coefficient by means of the Nusselt number increment. This will allow increasing efficiency of thermal methods EOR application.

Sign in / Sign up

Export Citation Format

Share Document