Method for displacement of high-viscosity oil from oil deposit in permafrost zone

FIELD: oil and gas industry.

SUBSTANCE: in a method for the displacement of high-viscosity oil from an oil deposit in a permafrost zone including injection of a heated polymer solution through injectors, flushing of the polymer solution up to the bottomhole of the producer by brine water with the displacement of high-viscosity oil from the stratum with its further extraction and transportation through the producer hole to the surface, the hydrophobic polymer solution (HPS) is used and this HPS is obtained by gauging of water-methanol injection (WMI) with the ratio of water:methanol equal to 60:40 at the ratio of the water-soluble polymer:WMI equal to 1:1, HPS is heated up to the reservoir temperature and the ratio of its viscosity to the viscosity of lock oil is not less than 1:10 at the pressure of flushing that does not exceed the pressure of bottom water and gas cap, at that water-soluble cellulose derivatives or polyacrylamide or hydrolysed polyacrylonitrile are used as the water-soluble polymer.

EFFECT: ensuring the displacement of high-viscosity oil without the contamination of the production stratum and without thawing of permafrost rock surrounding the wells.

 

The invention relates to the oil and gas industry, namely to production of high-viscosity oil, in particular to the displacement of heavy oil from oil deposits located in the zone of permafrost.

With the decline of oil production from major fields, an increasing attention is paid to the production of stranded heavy oil from smaller and more remote fields. In Western Siberia there are more than 40% of the heavy oil of Russia, characterized by different values of the viscosity [Makarevich V. N., Iskrica N. And., Bogoslovsky S. A. Resource potential of heavy oils of the Russian Federation: prospects of development // Neftegazovaya Geologiya. Theory and practice. - 2010. - T. 5. - No. 2].

In world practice, widespread in the extraction vicoveanca oils have found the following methods: displacement of oil heated water; displacement of oil by steam; cyclic steam stimulation; in situ combustion; impact on oil surfactants; step-out flooding; alkaline flooding; polymer flooding; wag.

In conditions of high oil viscosity pressure boundary plantar water is ineffective, although the final oil recovery reaches about 1%. The influence of steam may not be effective in case of presence for�Alannah flows or water and gas breakthrough to the faces of producing wells.

The effect of the measures on stimulation in the form protoplay treatments may be low because of the possible breakthrough of steam to downhole. Displacement of oil by the method of in-situ combustion hitherto insufficiently studied, therefore, to predict the impact of the flame burning the oil is still not possible. The impact on oil surfactants in the presence of permafrost is ineffective due to the low temperature reservoir, slowing down technological reaction. Alkaline flooding although theoretically worked out, but almost never been tested.

Thus, from the existing technological processes of oil displacement are the most appropriate injection into the reservoir of hot water (the least expensive), wag and polymer flooding [Crateres D. G. Theory and practice of development of deposits of heavy oil. - Krasnodar: Publishing house "Soviet Kuban, 2004. - 336 p] and [Butorin O. I., Pekow G. N. The generalization of experimental studies to determine the effectiveness of gas and water-gas reservoir stimulation // Oilfield business. 1995. No. 8. - S. 54-59].

For the conditions of deposits located in the North of Western Siberia, injected into the formation water must have the�erature in the range of 100-110°C. The results show that at this temperature, the coefficient of oil displacement can be increased in 1.5 times and to reach a value of 0.75 D. units. in Other words, the displacement of oil from the reservoir is increased by 50%. With further increase in temperature, visible oil displacement is not observed.

When water-gas in addition to the impact of oil displacement occurs additional laundering of residual oil gas. When increasing the share of gas water-gas mixture in the oil displacement efficiency increases. Injection wells effect is even more noticeable, as there is a fold or more increase in the intake capacity of these wells.

The use of an aqueous solution of the polymer as the displacing agent is very effective. So, in the experiments [Dubov I. B. Evaluation of promising technologies for the development of complex heavy oil on the example of the Tazovsky oil and gas // Drilling and oil. 2012. No. 5. - S. 28-30] when the reservoir temperature displacement efficiency reached the value 0,62 D. units by heating the polymer, the efficiency of oil displacement was increased, for example, by heating the polymer up to 60°C displacement factor reached 0,69 D. units, and when heated to 80°C - 0,72 D. units Established that increase in temperature increases the relative permeability of oil and the solution of polymer by viscosity reduction f�of widow and, as a consequence, there is an increase in the displacement efficiency. However, it should be noted that at equal temperatures marked increase in the displacement efficiency in the case of injection of the polymer solution from 8 to 23% compared with the injection of water by leveling the viscosities of the injected agent and reservoir oil.

Further increase in the heating temperature may lead to thawing of permafrost, which is unacceptable. On the other hand, the use of an aqueous solution of the polymer in conditions of low ambient temperatures also fraught with troubles associated with the freezing temperatures.

The principle of operation of technological processes of oil displacement consists in the injection of the displacing agent in injection wells, forcing them from the bottom of the injection well to the face producing well with the removal of these agents, and the produced oil to the surface.

The known method of reservoir development, including injection through injection wells polymer solution [RU No. 2148155 C1, IPC 7 E21B 43/20, E21B 43/22, publ. 27.04.2000].

The disadvantage of this method is that the displacement of heavy oil from oil deposits located in the zone of permafrost, gelled polymer solution on the basis of water may freeze or sagittata and not let coolant�these effect.

The known method of displacement of heavy oil from oil deposits, consisting in the injection of the composition comprising 0.5 to 1% solution of polyacrylamide (PAA), which is forced in the bottomhole zone of reservoir water [RU No. 2117755 C1, IPC6 E21B 43/22, publ. 20.08.1998], thus attain the reduction of corrosion activity impact solutions used, to increase the depth of injection and lower injection pressures.

The disadvantage of this method is the low efficiency of displacement of heavy oil from oil deposits located in the zone of permafrost, because of the complex composition of the injected composition.

A method of developing oil and gas fields, namely that the injection is carried out in the form of heated to 90-95°C polymer solution in the reservoir fluid whose viscosity is controlled by changing the concentration of the polymer as long as the value of the solution viscosity of the polymer does not become equal to the value of oil viscosity [RU No. 2439308 C1, IPC E21B 43/24 (2006.01), publ. 10.01.2012]. The selection of a viscous oil is performed producing wells while continuing the injection of the heated solution of the polymer.

The disadvantage of this method is the high probability of the thawing of permafrost and subsequent compression of the walls of the well.

The challenge when creating the invent�tion, is the possibility of displacement of heavy oil without pollution of the productive formation and without the thawing of permafrost surrounding the well.

Achieved technical result, which is obtained as a result of the invention is to improve the efficiency of displacement of heavy oil from oil deposits located in the zone of permafrost.

The task and the technical result is achieved in that in the method of displacement of heavy oil from oil deposits located in the zone of permafrost, including injection through injection wells heated polymer solution, forcing him to shabadabada wells formation water displacement in the reservoir of heavy oil with subsequent extraction and transportation through the well bore to the surface, the feature is that is used as a hydrophobic polymer solution polymer solution - SNR obtained using the mixing photometering fluid - TRP with a ratio of water:methanol 60:40 at a ratio of water soluble polymer:TEMPORARY 1:1, HLOOKUP heated to reservoir temperature and the ratio of viscosity to the viscosity of the reservoir oil is not less than 1:10, when the pressure forcing, not exceeding the pressure�of bottom water and gas cap, at the same time as hydrophobic polymer solution used water-soluble derivatives of cellulose, or polyacrylamide or hydrolyzed polyacrylonitrile.

The polymer solution shut to non-freezing liquid, additionally will possess hydrophobic properties, i.e. to repel water from oil.

Hydrophobic polymer displacement of viscous oil helps to improve the mobility ratio of the fluids and to reduce the volatility of the process of displacement, to prevent the introduction of produced water in oil reservoir. In addition, hydrophobic polymer displacement has no negative impact on permafrost (MMP), which is particularly important for conditions of the Northern fields.

The viscosity of the fluid is chosen from the ratio of the viscosity of the reservoir oil and pump agent polymer solution, which affects the ratio of reservoir sweep efficiency. (impact) and on the coefficient of oil displacement from the reservoir.

The method is as follows.

In injection wells located in oil deposits in the zone of widespread permafrost, pumped hydrophobic polymer solution 3 shut on photometering fluid, heated to reservoir temperature. Injected into an injection well an agent photomechanically RA�Shuttle (hydrophobic polymer solution has a salinity equal to the salinity of formation water. The mixed polymer solution with a liquid reagent photometering liquid in a ratio of 40 (methanol) : 60 (fluid - reservoir fluid) caused by the necessity of pumping it through low-permeability and low-temperature reservoir, through which polymer solutions and polymer gels penetrate into the formation to lack of depth and do not penetrate into it far then there can't be pumped to the distance between the downhole (e.g., 100 m between the downhole). The mixed polymer solution solutions based photometering fluid it

pumping through the formation and subsequent extraction without heating, at lower temperatures, as it eliminates gidratoobrazovaniya. Hydrophobic polymer solution may have the following relation: polymer:photometadata liquid 1:1.

As the hydrophobic polymer solution can be used water-soluble cellulose derivatives, polyacrylamide, hydrolyzed polyacrylonitrile, etc.

Forced hydrophobic polymer solution through the formation to the slaughtering of the producing well with the displacement of heavy oil in the reservoir. The temperature of the pumped solution corresponds to the temperature of the reservoir fluid and pressure pumping a polymer solution does not exceed the pressure aquifer cha�ti layer (water layer, underlying the oil reservoir and the pressure in the gas cap, if any, should be placed above oil reservoir).

To prevent thawing of permafrost surrounding the well, pump and compressor pipes, which are mounted in the composition of the tubing string in its upper part in the permafrost interval, you can use insulated pipes, reducing heat transfer of the transported polymer solution and extracted formation fluid.

For more coverage of the formation impact or displacement of the hydrophobic polymer solution viscosity is chosen from the ratio of not less than 1:10 reservoir oil viscosity and pump agent. The concentration of polymer is calculated from this ratio. Under these conditions, when the ratio of the reservoir oil viscosity and the viscosity of the displacing agent is equal to or less than 10, not growing phenomenon of the so-called viscous instability.

After that, master production well with subsequent extraction of heavy oil to the surface and with further transportation to the consumer.

In conditions of abnormally low pressure operation call flow is advantageously carried out with the help of a flexible tube put into the internal cavity of the tubing, which facilitates the call flow and reduces the duration of the operation.

Method of displacement high�owasco oil from the oil reservoir, located in the zone of permafrost, including injection through injection wells heated polymer solution, forcing it to the bottom producing well formation water displacement in the reservoir of heavy oil with subsequent extraction and transportation through the well bore to the surface, characterized in that is used as a hydrophobic polymer solution polymer solution - SNR obtained using the mixing photometering fluid - TRP with a ratio of water:methanol 60:40 at a ratio of water soluble polymer:TEMPORARY 1:1, HLOOKUP heated to reservoir temperature, and the ratio of viscosity to the viscosity of the reservoir oil is not less than 1:10, when the pressure forcing, not exceeding the plantar pressure of the water and the gas cap, wherein the water-soluble polymer used water-soluble derivatives of cellulose, or polyacrylamide or hydrolyzed polyacrylonitrile.



 

Same patents:

FIELD: oil and gas industry.

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FIELD: oil and gas production.

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25 cl, 1 tbl, 3 ex

FIELD: oil and gas production.

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2 cl, 2 tbl, 2 ex

FIELD: oil and gas production.

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EFFECT: increased oil production, prolonged overhaul period, improved environmental safety, and lowered production expenses.

2 tbl, 3 ex

FIELD: oil and gas extractive industry.

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EFFECT: higher efficiency.

7 cl, 5 dwg

FIELD: oil extractive industry.

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EFFECT: higher efficiency.

2 cl, 2 tbl

FIELD: oil and gas extractive industry.

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EFFECT: higher productiveness.

2 cl, 3 ex, 6 tbl, 2 dwg

FIELD: oil and gas extractive industry.

SUBSTANCE: method includes placing water solution of carnallite ore, either modified, concentrated, or mixtures thereof, said solution is used at maximal for well temperature conditions concentration and is pumped in amount, necessary and enough for forming a hydraulic column in well shaft above ceiling of productive bed and along remaining shaft height well is filled with water up to mouth. Carnallite ore used has composition, in percents of mass: potassium chloride 20.5-21.5; sodium chloride 19.5-22.5; magnesium chloride 24.0-27.0; crystallization water 29.5-30.5. Modified ore has composition, in percents of mass: potassium chloride 23.0-29.5; magnesium chloride 31.8-46.0; crystallization water - the rest. Said water solution is prepared by dissolving ore in fresh technical water, drained from oil preparation plants, or in bed water. In case of dissolving in bed water, the latter is pumped from well at temperature 60-90°C. During perforation of well, value of technological liquid hydraulic column above productive bed ceiling is taken equal to (1.03-1.07)-(1.05-1.1)Pb, where Pb - productive bed pressure. Water solution of carnallite ore is used at density 1.23-1.37 t/m3. During use of said solution as working body of force wells it is used at density 1.05-1.20 t/m3, and solution also contains swelling inhibitor for argillaceous component of oil and gas bearing bed, like oxyethylenedendiphosphone acid, in amount 0.05-0.15% of used dissolved ore mass.

EFFECT: higher efficiency.

1 cl, 4 ex

FIELD: oil industry.

SUBSTANCE: method includes treatment of face area of oil bed by hydrophobic agent in organic solvent and pressing oil from collector with following delivery of oil from face area of product well for treatment of oil terrigenic bed, in form of hydrophobic agent solution of ethylene copolymer with vinylacetate in ethylbenzol or fraction thereof is used in relation 1:1 - 10, treatment of face area is performed with following ratio of components, in percents of mass: ethylene copolymer with vinylacetate 0.05-2.0, ethylbenzol or fraction 0.05-20.0, organic solvent - the rest.

EFFECT: higher efficiency.

2 tbl, 2 ex

FIELD: mining industry and alternative fuels.

SUBSTANCE: coal is affected by methanogenic consortium of microorganisms with culture medium utilizing continuous pumping of culture medium through wells and tank wherein methanogenic consortium of microorganisms with culture medium is placed. Tank is installed on the surface above wells and pumping of culture medium from the bottom of tank through methanogenic consortium of microorganisms. Process produces biogas and coal-water fuel.

EFFECT: increased yield of biogas to continuously effecting culturing of microorganisms.

1 dwg, 2 tbl

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