Improved Oil Recovery of High-viscosity Oil Pools by Combined Steam Injection and Physicochemical Stimulation

2012 ◽  
Author(s):  
L.K. Altunina ◽  
V.A. Kuvshinov ◽  
S.O. Ursegov ◽  
M.V. Chertenkov
Keyword(s):  
Oil Recovery ◽  
Steam Injection ◽  
High Viscosity ◽  
Improved Oil Recovery ◽  
High Viscosity Oil

scholarly journals Hydrodynamic modeling of field development using enhanced oil recovery methods

2021 ◽  
Vol 317 (2) ◽  
pp. 14-22
Author(s):  
G.Zh. Moldabayeva ◽  
◽  
A.Kh. Agzamov ◽  
R.T. Suleimenova ◽  
D.K. Elefteriadi ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Seismic Data ◽  
Water Injection ◽  
Steam Injection ◽  
High Viscosity ◽  
Oil Fields ◽  
Borehole Data ◽  
Field Development ◽  
High Viscosity Oil ◽  
Cyclic Injection

This article discusses a digital geological model, the transfer of borehole data to the geological grid, and the modeling of the technology of alternating steam and water injection. Alternating injection involves the cyclic injection of steam and water into an injection well in high-viscosity oil fields. The essence of this technology is that during the steam injection for 2-4 months, the formation warms up, leading to a decrease in viscosity and an increase in oil mobility. Then comes the period of water injection, during which the production of already warmed oil continues and the formation pressure is maintained. For digital geological modeling, the following data were collected, processed and prepared: a list of wells that open the object of modeling, coordinates of wellheads, well altitudinal data, inclinometry of well trajectories, GМS data on wells, analysis of wells drilled with core sampling, and digitized seismic data (structural surfaces on the roof of stratigraphic horizons, parameter maps, contact surfaces, faults, structural maps on the roof of target horizons with faults, isochron maps, velocity maps).

scholarly journals Laboratory Studies of Carboniferous Reservoirs of High-Viscosity Oil Fields Using Carbondioxide

2020 ◽  
Vol 20 (4) ◽  
pp. 369-385
Author(s):  
Stanislav A. Kalinin ◽  
◽  
Oleg A. Morozyuk ◽  
Keyword(s):  
Carbon Dioxide ◽  
Heat Carrier ◽  
Oil Recovery ◽  
High Mobility ◽  
High Viscosity ◽  
Laboratory Studies ◽  
Carbon Dioxide Injection ◽  
Recovery Method ◽  
Matrix Blocks ◽  
High Viscosity Oil

It is of current concern for the Permian-Carboniferous reservior of the Usinskoye field to develop low-permeable matrix blocks of carboniferous reservoirs, which contain major reserves of high-viscosity oil. To increase effectiveness of the currently used thermal oil recovery methods, the authors suggest using carbon dioxide as a reservoir stimulation agent. Due to a high mobility in its supercritical condition, СО2 is, theoretically, able to penetrate matrix blocks, dissolve in oil and, additionally, decrease its viscosity. Thus, СО2 applications together with a heat carrier could increase effectiveness of the high-viscosity oil recoveries and improve production parameters of the Permian-Carboniferous reservior of the Usinskoye field. During carbon dioxide injections, including combinations with various agents, some additional oil production is possible due to certain factors. Determination of the influencing factors and detection of the most critical ones is possible in laboratory tests. So, laboratory studies entail the key stage in justification of the technology effectiveness. The paper deals with describing the laboratory facilities and methodologies based on reviews of the best world practice and previous laboratory researches. These aim at evaluating effectiveness of thermal, gas and combined oil recovery enhancement methods. In particular, the authors explore experimental facilities and propose methodology to perform integrated researches of the combined heat carrier and carbon dioxide injection technology to justify the effective super-viscous oil recovery method.

Cyclical Gel-Polymer Flooding Technology is an Effective Method of Enhanced Oil Recovery in High-Viscosity Oil Fields

2020 ◽  
Author(s):  
Svetlana Yur’evna Lobanova ◽  
Berdibek Ulanovich Yelubaev ◽  
Nikolay Evgen’evich Talamanov ◽  
Zhijian Sun ◽  
Chunxi Wang ◽  
...  
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
High Viscosity ◽  
Polymer Flooding ◽  
Oil Fields ◽  
High Viscosity Oil

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.

scholarly journals Laboratory Results of the Influence of Carbon Dioxide on the Development of the Permo-Carboniferous Reservoir of the Usinskoe Deposit

2021 ◽  
Vol 21 (1) ◽  
pp. 28-35
Author(s):  
Stanislav A. Stanislav A. ◽  
◽  
Oleg A. Morozyuk ◽  
Konstantin S. Kosterin ◽  
Semyon P. Podoinitsyn ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Oil Recovery ◽  
Co2 Concentration ◽  
High Viscosity ◽  
Co2 Injection ◽  
Oil Displacement ◽  
Displacement Mode ◽  
Use Of Technology ◽  
Reservoir Conditions ◽  
High Viscosity Oil

As an option for enhancing oil recovery of a high-viscosity Permo-Carboniferous reservoir associated with the Usinskoye field, the use of technology based on technogenic carbon dioxide as an injection agent is considered. In the world practice, several fields are known as close in their parameters to the parameters of the Permo-Carboniferous reservoir, and in which CO2 injection was accepted as successful. Based on this, CO2 injection can potentially be applicable in the conditions of a Permo-Carboniferous reservoir. At present, as a result of the various development technologies implementation, reservoir zones are distinguished, characterized by different thermobaric properties. Depending on reservoir conditions, when displacing oil with gases, various modes of oil displacement can be realized. This article describes the results of studies carried out to study the effect of the concentration of carbon dioxide on the properties of high-viscosity oil in the Permo-Carboniferous Reservoir of the Usinskoye field, as well as the results of filtration experiments on slim models performed to assess the oil displacement regime under various temperature and pressure conditions of the Permo-Carboniferous Reservoir. The study of the influence of CO2 concentration on oil properties was carried out using the standard PVT research technique. The displacement mode was assessed using the slim-tube technique. Based on the performed experiments, it was established that an increase in the concentration of CO2 in high-viscosity oil led to a noticeable change in its properties; for the conditions of a Permo-Carboniferous Reservoir, the most probable mode of oil displacement by carbon dioxide was established. Difficulties associated with the preparation of the CO2-heavy oil system were described separately. Based on a literature review, it was shown that the rate of mixing of oil with carbon dioxide depended on certain conditions.

scholarly journals Enhanced oil recovery from high-viscosity oil deposits by acid systems based on surfactants, coordining solvents and complex compounds

Georesursy ◽  
2019 ◽  
Vol 21 (4) ◽  
pp. 103-113 ◽  
Author(s):  
Lyubov K. Altunina ◽  
Vladimir A. Kuvshinov ◽  
Lyubov A. Stasyeva ◽  
Ivan V. Kuvshinov
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
High Viscosity ◽  
Complex Compounds ◽  
Natural Mode ◽  
Inorganic Acid ◽  
Acid Oil ◽  
Oil Displacement ◽  
Oil Deposits ◽  
High Viscosity Oil

Physicochemical aspects of enhanced oil recovery (EOR) from heavy high-viscosity deposits, developed in natural mode and combined with thermal methods, using systems based on surface-active substances (surfactants), coordinating solvents and complex compounds are considered, which chemically evolve in situ to acquire colloidal-chemical properties that are optimal for oil displacement. Thermobaric reservoir conditions, interactions with reservoir rock and fluids are the factors causing the chemical evolution of the systems. To enhance oil recovery and intensify the development of high-viscosity deposits, acid oil-displacing systems of prolonged action based on surfactants, inorganic acid adduct and polyatomic alcohol have been created. As a result of experimental studies of acid-base equilibrium in the systems with donor-acceptor interactions – polybasic inorganic acid and polyol, the influence of electrolytes, non-electrolytes and surfactants, the optimal compositions of the systems were selected, as well as concentration ranges of the components in the acid systems. When the initially acid system interacts with the carbonate reservoir to release CO2, the oil viscosity decreases 1.2-2.7 times, the pH of the system rises and this system evolves chemically turning into an alkaline oil-displacing system. As a result it provides effective oil displacement and prolonged reservoir stimulation. The system is compatible with saline reservoir waters, has a low freezing point (minus 20 ÷ minus 60 oC), low interfacial tension at the oil boundary and is applicable in a wide temperature range, from 10 to 200 oC. In 2014-2018 field tests of EOR technologies were successfully carried out to intensify oil production in the test areas of the Permian-Carboniferous deposit of high-viscosity oil in the Usinsk oil field, developed in natural mode and combined with thermal-steam stimulation, using the acid oil-displacing system based on surfactants, coordinating solvents and complex compounds. The pilot tests proved high efficiency of EOR technologies, as far as the oil production rate significantly increased, water cut decreased to intensify the development. The EOR technologies are environmentally safe and technologically effective. Commercial use of the EOR is promising for high-viscosity oil deposits.

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.

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