Development method of deposit of high-viscosity oil or bitumen

FIELD: oil and gas industry.

SUBSTANCE: in a development method for a deposit of high-viscosity oil or bitumen including construction of the upper injector and the lower producer with horizontal sections placed one over the other the above sections are equipped with filters, at that a pipe string of a pipe-in-pipe type with inner spaces isolated from each other by packers is run down to the injector while output openings of the pipe strings are placed in the filter and spread along the length of the horizontal section dividing it into heating zones, injection of a heat carrier through the horizontal injector with the stratum heating, creation of a steam chamber and extraction of the product through the horizontal producer, at that thermograms of the steam chambers are recorded, the heating state is analyzed regarding the evenness of heating and availability of temperature peaks, considering the obtained thermograms even heating of the steam chamber is made by changing the heating zones and delivery of a required quantity of the heat carrier to the respective pipe string in order to exclude the breakthrough of the heat carrier to the producer through the most heated zone, at construction of the injector with a horizontal section for evener heating of the stratum the filters and pipe strings are made with an increased total cross-section area of the openings from the beginning of the horizontal section in the stratum towards the bottomhole. During operation upon a 3-5 time increase in viscosity of the extracted product injection of the heat carrier to the injector is stopped and a gaseous hydrocarbon solvent is injected through the respective pipe string to the heating zone with the least temperature until the temperature of the extracted product is reduced per 10-25%. Thereafter injection cycles of vapour and gaseous hydrocarbon solution to the respective heating zones and product extraction are repeated.

EFFECT: enabling continuous control over the change in viscosity of the extracted product, potential regulation of the injection process, even heating of the stratum, increased output of high-viscosity oil and bitumen with the simultaneous reduction of material costs and energy consumption.

1 dwg

 

The proposed method relates to the oil industry, in particular to the field of development of deposits of heavy oil or bitumen under the cyclic influence of steam and hydrocarbon solvent to the reservoir through the horizontal injection wells.

The known method of development of deposits of heavy oil (patent RU №2387818, IPC E21B 43/24, publ. 27.04.2010, bull. 12), whereby they inject steam into the reservoir, heating the reservoir to create steam chamber, co-injection of steam and hydrocarbon solvent and the selection of products. According to the invention as a hydrocarbon solvent, a mixture of saturated hydrocarbon aliphatic and aromatic series, the main component of which is benzene. Joint injection of steam and hydrocarbon solvent is carried out after reaching the temperature in the steam chamber is not less than the phase transition temperature of the mixture of steam and hydrocarbon solvent with the temperature in the steam chamber is not below the phase transition temperature of the mixture steam - hydrocarbon solvent.

The disadvantage of this method is that steam injection and hydrocarbon solvent into the reservoir are carried out without regard to their influence on the change in the viscosity of the product in the reservoir. Not carried out the monitoring of the evolution of the fractional composition of oil during injection, p�RA and hydrocarbon solvent, no data on the amount deposited in the reservoir of oil fractions with high boiling points and high viscosity. Method can not solve the problem of uniform heating of the steam chamber, since it does not use non-uniform perforations throughout the horizontal length of the injection well that allows you to disable areas of temperature peaks, aligning the front for the advancement of steam on horizontal trunk and reducing the likelihood of a breakthrough of the injected steam in horizontal producing well. The result is wasted steam and costly hydrocarbon solvent, are not reached planned levels of selection of high-viscosity oil.

The closest in technical essence is a method of development of deposits of heavy oil or bitumen with the regulation of injection of fluid into the borehole (patent RU №2412342, IPC E21B 43/24, publ. 20.02.2011, bull. 5), including the construction of upper injection well and lower mining wells with horizontal sections located one above the other, the pumping of the coolant through the horizontal injection well with a warm-up layer, creating a steam chamber and selection of products through horizontal production well, which removed thermograms of the steam chamber, analyze the state of her about�Reva on the uniformity of heating and the presence of temperature peaks. Taking into account the obtained thermograms carry out uniform heating of the steam chamber by changing the heating area. In the construction of wells, their horizontal sections are equipped with filters to the injection well down the column of pipes of the type "pipe in pipe" with insulated from each other inner spaces, and outlet columns, pipes placed in the filter and spaced along the length of the horizontal section by dividing it into a heating zone so as to prevent breakthrough of the coolant in the production well through the warmer zone. At the mouth of the column for pumping coolant equip each independent pipelines with adjustable valves that regulate the flow of coolant depending on thermograms of the steam chamber taken in a producing well.

The disadvantage of this method is that steam injection into the reservoir are carried out without regard to their influence on the change in the viscosity of the product in the reservoir and the component composition of heavy oil or bitumen. This method cannot solve the problem of uniform heating of the steam chamber, since it does not use non-uniform perforations throughout the horizontal length of the injection wells, allowing for the injection of coolant to reduce the number of zones of temperature peaks and to minimize the possibility of breakthrough of the injected steam in the horizon�iny plot producing well. With nonuniform perforation is not necessary to divide the horizontal area on a large number of heating zones, which leads to a reduction in the number of columns of tubes used for pumping the coolant and therefore saving material costs for the construction of horizontal wells. Continuous injection of steam increases the steam consumption for heating compared with cyclic use. The result is wasted steam, not achieved the planned levels of selection of heavy oil or bitumen.

Technical tasks of the proposed method are the increased level of extraction of heavy oil or bitumen, reducing material costs and energy savings resulting from continuously monitoring the viscosity change of the output, uniform heating of a formation, using irregular perforations throughout the horizontal length of the injection wells with the release of heating zones, allowing you to adjust the volume of injection of steam and associated gas.

The technical problem solved by the method of development of heavy oil or bitumen, including the construction of upper injection well and lower mining wells with horizontal sections located one above the other, which will be equipped with filters, and in magnetfeld�Yu the well down the column of pipes of the type "pipe in pipe" with insulated from each other with the help of packers interior spaces and outlet columns, pipes are placed in the filter and is distributed along the length of the horizontal section by dividing it into a heating zone, the pumping of heat carrier is produced through a horizontal injection well with a warm-up layer, creating a steam chamber and selection of products through horizontal production well, which removed thermograms of the steam chamber, analyze the state of her warm-up on the uniformity of heating and the presence of temperature peaks, and taking into account the obtained thermograms carry out uniform heating of the steam chamber by changing a heating zone by the supply of the required amount of coolant in the appropriate column of pipes to prevent breakthrough of the coolant in the production well through the warmer zone.

What is new is that in the construction of injection wells with horizontal section for more uniform heating of the reservoir filters and tubing perform with increasing total cross-sectional area of holes from the beginning of the horizontal section in the reservoir to the bottom, and in the operation after increasing the viscosity of the selected products in 3-5 times cease the pumping of heat carrier into the injection wells and pumped gaseous hydrocarbon solvent using an appropriate column of pipes in the heating zone of lowest temperature to reduce the temperature from�iremos production by 10-25%, then the cycles of steam injection into the corresponding heating zone and a gaseous hydrocarbon solvent with a selection of products, repeat.

The drawing shows a diagram of the proposed method of development of deposits of heavy oil or bitumen.

The inventive method is carried out in the following sequence.

Deposit 1, comprising one or more layers, razvarivat wells on a sparse grid. Clarify the geological structure of the deposits 1. Determine the permeability, the porosity of the reservoir, the viscosity of the heavy oil or bitumen. Conduct hydrodynamic studies with determination of reservoir pressure, temperature. Selecting the area with the net pay thickness h over 15 m.

First, build injection 2, then mining 3 wells with horizontal sections b. They are placed one above the other in the same vertical plane at a distance l=5,0-7,0 m, which prevents premature breakthrough of the condensate to extractive horizontal well 3. In the process of construction of wells 2, 3 horizontal sections b respectively equipped with filters 4.

In injection well 2 down the column of tubes 5, 6 of the type "pipe in pipe" with insulated from each other inner spaces with the help of packers 7 in interval of the productive formation 1. The lower end of the tubing 6 is muted.

EXT�describing a horizontal well 3 is carried out in the most permeable bed, moreover, it is located above the base layer 1 of high-viscosity oil or bitumen at a distanceand=3,0-4,0 m, and oil-water contact 9 is at a distanceand≥6.0 m, anhydrous increasing the period of operation of the well. A shorter distance to oil-water contact 9 will lead to a breakthrough of bottom water to the horizontal section of producing well 3 as a result of sharp differences in the viscosities of heavy oil or bitumen and produced water. In production well 3 down the column tubing 10 with submersible pump 11 at the end.

According to the tax code of the Russian Federation, with the introduction of a differentiated tax on mineral extraction (met), adopted the following classification of oil to viscous (heavy) oil is oil, whose viscosity at reservoir conditions is 200-10000 MPa·s, to sverkhvysokogo (bitumen) oil viscosity at reservoir conditions of over 10,000 MPa·s.

High viscosity oil or bitumen causes the application of borehole heat reservoir development methods 1 further fix gaseous hydrocarbon solvents, which are the individual chemical compounds or mixtures capable of dissolving a variety of substances, i.e., to form with them a homogeneous system of variable composition, consisting of two or more components�clients. When exposed to heavy oil or bitumen gaseous hydrocarbon solvents there is a complete mixing them with a solvent, whereby the viscosity is reduced.

The mechanism of displacement of heavy oil or bitumen with steam is to spread the zone of influence of steam on stratum 1 with increasing reservoir pressure. The injected steam tends to the upper part of the formation. On the boundary of the steam chamber when the transfer of the condensation heat, and the heated heavy oil or bitumen are displaced under the action of gravity to the bottom of the extractive horizontal well 3.

When you fix the coolant is uneven heating of the steam chamber along the horizontal section b of the injection well 2. Maximum warm layer at the beginning of the horizontal section b and in the direction of bottom the temperature is reduced.

For more uniform heating of the steam chamber along the entire horizontal section b of the injection well 2 weekends of the perforations 8 columns of tubes 5, 6 placed inside the filter 4, is distributed unevenly along the length of the horizontal section b, dividing it into a heating zone to c and d. Uneven perforation allows to divide the horizontal area on the optimal number of heating zones, which leads to a reduction in the number of columns of tubes used for� injection of the coolant.

Regulation front for the promotion of the coolant in the reservoir 1 will smooth out temperature peaks obtained during the recording of thermograms, preventing breakthrough of the coolant in the horizontal section of producing well 3, or completely disable some of the most warm intervals of the horizontal section b of the injection well 2, which has been a breakthrough of the coolant in the horizontal section of producing well 2.

Injection of steam is carried from the steam generator (not shown) into the injection horizontal well 2 with the heating layer 1, the creation of the steam chamber, cyclically with simultaneous selection of products from extractive horizontal wells 3 and control the rate and degree of heating of the formation. As during warming up, and during operation conduct monitoring of the temperature in the steam chamber of the borehole 2 by means of special sensors (thermocouples), launched inside paramagnetically pipes 5, 6. The results of these temperature sensors are built thermoclines, which places the breakthrough of steam from the steam chamber into the filter 4 horizontal section b producing well 3 are shown as temperature peaks.

Taking into account the obtained thermograms using special valves (not shown) regulates the volume of the injected steam in the appropriate column of pipes 5, 6 n�gnetales horizontal wells 2, in front of which there was a breakthrough a couple. Uniform heating of the steam chamber is performed by increasing the total area of the perforations 8 of the horizontal section b - from its beginning in the direction of the slaughter, which use nonuniform density perforations in the heating zones c and d. Supplied with the necessary quantity of the coolant in the corresponding column of pipes 5, 6 eliminates breakthrough of the coolant in extractive horizontal well 3 via over-heated area.

The steam injection mode may be different, however, the bottomhole pressure must not exceed the overburden pressure, i.e. the pressure under which the rock in the reservoir. It must be borne in mind that the higher the steam flow, the more is taken of condensate from extractive horizontal wells 3. Mandatory conditions of steam injection are gradual warming up of horizontal injection wells 2 and uniform heating of the casing and cement to prevent them from cracking.

After injection of the heat carrier (steam) in the upper horizontal injection well 2, exposure to thermocapillary impregnation, extractive horizontal well 3 starts to work. When the temperature of the layer to 100°C and higher the viscosity of heavy oil or bitumen is sharply reduced, increased permeability of the rocks composing the aquifer. Selection of product from the reservoir increases. The higher the heterogeneity of the heavy oil or bitumen, the slower the decrease of the viscosity. Fractional composition of oil shows the content of different components having different boiling points. In the reservoir in the first place, reduction in the viscosity of a light fraction with a relatively low boiling point (100°C and above) and their selection. In the process of further steam injection increases the coverage area of reserve recovery of heavy oil or bitumen, which leads to the loss of heat in the reservoir and increase the viscosity of products. The proportion of light fractions is reduced, increasing the share of fractions with a high viscosity and boiling point. Heavy oil is deposited in the reservoir, resulting in reduced permeability and, as a result, the oil production rates.

By increasing the viscosity of the selected products in a 3.0-5.0 times compared with the initial viscosity at the beginning of the cycle, stop the injection of steam into the injection horizontal well 2 and pumped gaseous hydrocarbon solvent using an appropriate column of tubes 5, 6 in the heating area C and d with the lowest temperature. When the temperature selected products on 10-25% of the cycles of steam injection into the corresponding heating zone c or d and gaseous hydrocarbon solvent with a selection of products, repeat.

�gas form the hydrocarbon solvent is injected into the injection horizontal well 2, that allows you to not heat up the casing string, but it increases the temperature of the injected into the formation 1 gaseous hydrocarbon solvent and increases the reserve of elastic energy in the reservoir 1, providing further flow of product from the reservoir in extractive horizontal well 3. Increasing the pressure leads to the increase in displacement due to the additional areas of the reservoir. In order to avoid uneven distribution of the displacement front heavy oil or bitumen, bottom-hole pressure in the injection horizontal well 2 does not exceed the pressure of hydraulic fracturing. Under these conditions the lowest steam consumption for production of one tonne of heavy oil or bitumen.

An example of a specific implementation

Deposit 1 heavy oil, presented in a single layer, razvarivat wells on a grid of 40×400 m. Choose a site with effective net pay thickness h≥20,0 m. the Lower boundary for the reservoir oil-water contact is 9. Determine the permeability of the formation, which is of 0.146 μm2. The porosity varies in the interval from the 16.8 to 20.3%. Oil viscosity is an average of 835 MPa·s.

Build horizontal injection well 2 with the length of the horizontal part b Below 700 m. in the horizontal seam is drilled Committee�th hole 3 with the length of the horizontal part of 730 m. Horizontal boreholes 2, 3 are placed in the same vertical plane. The casing is installed in the productive stratum 1, cemented the annulus of casing (not shown) to the top of formation 1.

In injection horizontal well 2 down the column of tubes 5, 6 of the type "pipe in pipe" with insulated from each other inner spaces with appropriate packers 7 in interval of the productive formation 1. The lower end of the tubing 6 is plugged. The weekend of the perforations 8 columns of tubes 5, 6 are placed along the entire length of the horizontal section b of the injection well 2 unevenly, breaking it into two heating zone: the first zone extends from the beginning of the horizontal section b up to 350 m, the second d - from 350 to 700 m. For more uniform heating of the reservoir 1, the total cross-sectional area of the perforations 8 of the filter columns 4 and tubes 5, 6 from the beginning of the horizontal section in the reservoir to the working face double (determined empirically).

The distance l between the horizontal injection well 2 and primary 3 wells is 5.5 m. the trajectory of the horizontal producing well 3 have the above oil-water contact 9 of 10.0 m minimum distance and increasing anhydrous period of well operation. Install tubing 10 with a submersible pump�m 11 on the end equipped with centralizers.

Injection of steam is carried from the steam generator (not shown) through the upper horizontal injection well 2 with the wellhead. Horizontal section b in the reservoir 1 is divided into two areas with the warm and d, so the steam is pumped through two columns of insulated tubing 5, 6. Periodically determine the volume of injected steam, petroleum gas, used as the gaseous hydrocarbon solvent, and crude production, water cut, pressure at the mouth and the bottom of the wells 2, 3. The results of these temperature sensors taking into account the obtained thermograms using special valves (not shown) regulates the volume of the injected steam in the appropriate column of pipes 5, 6 horizontal injection wells 2.

In injection horizontal well 2 was pumped 2,04 thousand tons of steam and 161 thousand m3associated gas. The fix vapor temperature of 175-200°C was carried out at a pressure at the mouth of 1.3-1.6 MPa cycles, not exceeding 2,0 days. The average rate of discharge was 2.8 t/h or 67,0 t/day. The maximum amount of steam injection in two zones of heating produced per cycle, amounted 96,0 t, the average - 30,0 t water Cut reached 71,0%. The specific steam consumption per 1 ton of produced heavy oil amounted to 0.76 T.

To relieve intense heat�I with the production casing horizontal injection wells 2 and increasing selection of products from extractive horizontal wells 3 when the viscosity increase of 3.5 times to of 122.5 MPa·s compared to the initial viscosity (35,0 MPa·s) at the beginning of the cycle of steam injection into the formation, injection of steam was replaced by injection of the associated gas into the injection horizontal well 2. After two days when the temperature drops in the reservoir 22.0% to 132°C resumed pumping steam into the reservoir 1. Further cycles are repeated. As a result of cyclic steam injection and associated gas into the reservoir 1, the heavy oil production rates increased from 0.3 to 0.8 t/day to 1.5-3.8 tons/day.

Compared to the prototype method in the proposed method for uniform heating of a formation 1 ferry applies uneven perforation 8 of the horizontal section b of the injection well 2, which allows to reduce the number of columns of pipes, lowered into the borehole, from three to two. The number of heating zones c and d, which separates the horizontal section b, is reduced from several to two. Material costs for the construction of the well down to 30%.

When cyclic injection of steam and associated gas into the reservoir, the steam consumption for heating is reduced in proportion to the length of the cycle. Cyclic injection of associated gas as a gaseous hydrocarbon solvent multiples will reduce material costs.

The proposed method allows to carry out continuous monitoring of changes in the viscosity of the produced product, provides the ability to control the process of downloading parai associated gas allows to reduce energy consumption for heating of the steam during its cyclic use, to reduce the number of pump-compressor pipes due to the alignment of the injected steam into the reservoir, unevenly perforeret horizontal portion of the injection well and smashing it on the optimal number of zones of heating, disconnecting the intervals of breakthrough of steam in horizontal producing well.

Method of development of deposits of heavy oil or bitumen, including the construction of upper injection well and lower mining wells with horizontal sections located one above the other, which will be equipped with filters, and injection well down the column of pipes of the type "pipe in pipe" with insulated from each other inner spaces with the help of packers and outlet openings of the columns of tubes placed in the filter and spaced along the length of the horizontal section by dividing it into a heating zone, the pumping of the coolant through the horizontal injection well with a warm-up layer, creating a steam chamber and selection of products through horizontal production well, in which removed thermograms of the steam chamber, analyze the state of her warm-up on the uniformity of heating and the presence of temperature peaks, and taking into account the obtained thermograms are implementing RA�hit steam heating chamber, changing a heating zone by the supply of the required amount of coolant in the appropriate column of pipes to prevent breakthrough of the coolant in the production well through the warmer zone, characterized in that the construction of the injection well with a horizontal section for more uniform heating of the reservoir filters and tubing perform with increasing total cross-sectional area of holes from the beginning of the horizontal section in the reservoir to the bottom, and in the operation after increasing the viscosity of the selected products in 3-5 times cease the pumping of heat carrier into the injection wells and pumped gaseous hydrocarbon solvent using an appropriate column of pipes in the heating zone of lowest temperature until the temperature of the selected products by 10-25%, then the cycles of steam injection into the corresponding heating zone and a gaseous hydrocarbon solvent with a selection of products, repeat.



 

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SUBSTANCE: method of high-viscosity oil field production with horizontal wells involves drilling of two horizontal wells, injector and producer, in the oil reservoir thickness. Producer is positioned below injector level, steam is injected to the injector and oil is swept from producer, presence of bottom water is checked, and if present, minimum height of producer path above water and oil interface, optimum distance between producer and injector, minimum distance from injector to formation top, and optimum thickness of oil reservoir allowing for parallel position of the producer and injector in the same vertical plane are determined, and if oil reservoir thickness drops below the optimum, injector drilling path in the oil reservoir space against the producer is modified by reducing the vertical distance between the wells, and injector is lead away from the producer in horizontal plane with account of reservoir anisotropy, preserving permeability gradient between the injector and producer.

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3 ex

FIELD: oil and gas industry.

SUBSTANCE: dry mixture comprises a copolymer of acrylamide and acrylic acid - 71.4-83.3 wt %, paraformaldehyde - 10.0-17.8 wt % and resorcinol - 6.3-11.4 wt % or copolymer of acrylamide and acrylic acid - 69.5-82.5 wt %, paraformaldehyde - 9.5-17.7 wt %, resorcinol - 6.1-10.6 wt %, and aerosil - 0.9-3.0 wt %. The gelling composition is prepared by dissolving any of the said compounds in water. At that the gelling composition without aerosil can also be obtained by the introduction of paraformaldehyde in water immediately after the copolymer of acrylamide and acrylic acid, and resorcinol - after complete dissolution of the copolymer of acrylamide and acrylic acid. The resulting gelling composition comprises a copolymer of acrylamide and acrylic acid - 0.17-0.80 wt %, paraformaldehyde - 0.03-0.20 wt %, resorcinol - 0.02-0.12 wt %, water - the rest, or a copolymer of acrylamide and acrylic acid - 0.17-0.80 wt %, paraformaldehyde - 0.03-0.20 wt %, resorcinol - 0.02-0.12 wt %, aerosil - 0.01-0.03 wt %, water - the rest.

EFFECT: increasing the efficiency and manufacturability of the gelling composition by ensuring the solubility in water used for its preparation of the dry mixture, simplifying of preparation of the composition at high mechanical and thermal resistance.

3 cl, 3 tbl, 5 dwg, 8 ex

FIELD: oil and gas industry.

SUBSTANCE: method involves installation of oil-well tubing string with well sucker-rod pump in a well. Additionally, the string features a liner with filter, heating cable along external surface from wellhead to the well sucker-rod pump, capillary well pipeline from wellhead to a depth below the well sucker-rod pump, entering inner space of the liner. Well operation involves simultaneous product extraction through oil-well tubing string by the well sucker-rod pump. Electric current runs over the heating cable. Mix of Intat asphaltene, resin and paraffin sediment solvent and Rekod demulsifier is injected via capillary well pipeline. Demulsifier to solvent ratio is (1:18)-(1:22). Cable with maximum heating temperature up to 105°C and maximum power up to 60 kWh is used as the heating cable.

EFFECT: enhanced efficiency of viscous oil emulsion production.

1 ex, 1 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: group of inventions relates to development and accumulation of biogenic gas in anaerobic geological formation containing carbon-bearing material. According to the method of increase of biogenic gas blowdown in anaerobic geological formation with carbon-bearing material the access to this anaerobic formation is provided. The rate of blow down of biogenic gases in this anaerobic formation is increased, for example, by holding of accumulated biogenic gases and their keeping in the anaerobic formation. The flowing of reservoir water into the anaerobic formation is provided after increase of biogenic gas blow down. Flowing of reservoir water comprises the circulation of reservoir water between the anaerobic formation reservoir and carbon-bearing material and back into the reservoir.

EFFECT: improvement of efficiency of biogenic gas production.

23 cl, 6 dwg

FIELD: oil and gas industry.

SUBSTANCE: method of high-viscosity oil well development and operation involves landing of tubing string with well pump with power cable to the well, and landing of capillary tube parallel to the power cable and attached to external surface of the tubing string by clamps. Oil or oil-containing reservoir fluid is produced. Chemical reagent is injected to the well from a tank by a metering pump through the capillary tube. Power cable is inserted to the well through cable gland. Power cable and capillary tube are protected against direct contact with internal well surface by protectors. Electric heater with extension unit, well pump with power cable and sleeve with radial hole to which the capillary tube is connected are inserted into the tubing upwards from the bottom at the wellhead. Electric heater extension unit is connected to the power cable of well pump. The tubing is landed to the well so that its shoe is located at least 2 m lower than bottom of high-viscosity oil reservoir, and electric heater is facing perforation interval of the high-viscosity oil reservoir. At the wellhead, power cable is connected to well pump and electric heater control stations and inserted to the well through cable gland. Capillary tube is inserted to the well through sealed side tap of the well X-mas tree. Electric heater is actuated, and a process break is made for 8 hours to heat bottomhole zone of reservoir in the perforation interval and high-viscosity oil heating at the inlet of well pump. After the process break, well pump is launched simultaneously with the metering pump supplying high-viscosity oil flux via the capillary tube through the radial hole in the sleeve to inner space of the tubing above the well pump.

EFFECT: enhanced well yield, reduced load in the well pump.

1 dwg

FIELD: oil and gas industry.

SUBSTANCE: method of high-viscosity oil or bitumen field development involves construction of two horizontal wells, one above the other, steam injection to the reservoir, reservoir heating by steam pocket formation, steam and hydrocarbon solvent injection to horizontal injector, and product sweeping from horizontal producer. Associated gas is used as hydrocarbon solvent. Steam and associated gas are injected in sequence in cycles. Steam is injected to the reservoir until extracted product viscosity is 3-5 times higher than initial viscosity at the cycle start, associated gas injection is started along with product extraction until extracted product temperature is reduced by 10-25%, then steam and associated gas injection cycles are repeated.

EFFECT: expanded reservoir coverage, higher level of high-viscosity oil and bitumen production along with material and power cost reduction.

1 ex, 1 dwg

FIELD: oil and gas industry.

SUBSTANCE: invention relates to the heavy oil extraction from underground field. Method of the heavy oil extraction from underground field includes: nanoemulsion (oil-in-water) injection to one or more injection wells, extraction of the specified heavy oil from one or more operation wells, where the specified nanoemulsion is produced using the method including: production of the uniform mixture (1) water/oil product with interfacial tension 1 mN/m maximum, containing water in quantity from 65% to 99.9% by weight, with a view to total mixture weight (1), and at least two surface-active substance (SAS) having different hydrophilic-lipophilic balance (HLB), selected from not-ionic, anionic, polymer SAS, preferably not0ionic; these SAS are in such quantity that to make the mixture (1) uniform mixture (1) dilution by the dispersion medium containing water with added at least one SAS selected from the specified SASs; this dispersion medium and SAS quantities are such that nanoemulsion is produced (oil-in-water) having HLB exceeding HLB of the mixture (1). Invention is developed in subclaims.

EFFECT: increased extraction efficiency.

34 cl, 1 dwg, 2 ex

FIELD: oil and gas industry.

SUBSTANCE: group of inventions is related to production of heavy hydrocarbons. In the in situ multistage solvent extraction method of heavy oil from oil pools at first liquids and gases are extracted from zones of contact with heavy oil in order to increase interfacial area of unextracted heavy oil subject to contact with solvent. Then solvent is injected in the form of steam to the above zones in order to increase pressure in the pool up to accumulation of sufficient quantity of solvent in the form of liquid to ensure contact with enlarged interfacial surface of heavy oil. Then the pool is isolated for the period sufficient to ensure diffusion of solvent to unextracted oil through the interfacial surface at ageing stage so that the mixture of solvent and oil with low viscosity is obtained. One or more parameters of the pool are measured to determine the degree of unextracted oil liquefaction in the pool by solvent. Oil extraction from the pool is commenced by gravity drainage when viscosity of oil becomes rather low to flow through the pool to the production well.

EFFECT: maximising liquefaction of heavy oil and maximising its extraction as a result.

19 cl, 11 dwg

FIELD: oil and gas industry.

SUBSTANCE: method involves displacement of the first fluid on a hydrocarbon basis, which is present at a non-cased interval of a well shaft, with the second fluid, contact of the second fluid to acid natural formation fluid so that the third fluid is formed, where the second fluid contains aqueous liquid dispersed as a disperse phase in oily liquid, and surface active substance (SAS) based on amine and chosen so that the above contact performs protonation of at least some part of SAS with formation of the third fluid included in an emulsion containing oily liquid reversely dispersed as a disperse phase in aqueous liquid, where at least 40 vol % of any solid substances that do not refer to a proppant and are present in the fluid are water-soluble at pH that is lower than or equal to 6.5, and SAS has the above said structure. An underground well treatment system. The fluid containing a reversible invert emulsion containing an aqueous liquid dispersed as a disperse phase in oily phase and the above SAS.

EFFECT: improving destruction efficiency of a filter cake.

20 cl, 6 dwg, 3 tbl, 2 ex

FIELD: oil and gas industry.

SUBSTANCE: under the method of development of oil deposits with nonuniform permeability comprising successive injection via the injection well of the water suspension containing polymer, mud powder and SAS solution, prior to the suspension injection in the deposit the initial intake of the injection well is determined under pressure in water line ands water mineralisation; in water with salinity level 0.15-40 g/l complex action SASs with pour point not exceeding minus 30°C and kinematical viscosity 35-50 sSt are used, i.e. water-alcohol solution of non-ionic SAS-monoalkyl esters of PEG at the following ratio wt %: specified SAS 0.001-1.0, specified water rest, suspension and SAS solution are injected in volume ratio (1-3):1 depending on initial intake of the injection well - at intake 200-400 m3/day - 1-2:1, 400-500 m3/day - 2-3:1, over 500 m3/d - 3:1, between suspension and SAS solution water with salinity level 0.15-40 g/l or water suspension of polyacrylimide with concentration 0.0001-0.1 wt % is injected. Under another option during this method in water with salinity level 40-300 g/l the complex SAS with pour point minus 40°C max is used, containing complex action SAS with pour point minus 30°C max. and kinematical viscosity 35-50 sSt - water-alcohol solution of non-ionic SAS - monoalkyl esters polyoxyethylene glycol 90 wt % and alkyldimethylbenzylammonium chloride 10 % at following ratio of components in wt %: specified SAS 0.001-1.0, specified water - rest, suspension and SA solution are injected to the deposit in volume ratio (1-3): 1 depending on initial intake of the injection well at water line pressure - at intake 200-400 m3/day - 1-2:1, 400-500 m3/day - 2-3:1, over 500 m3/day - 3:1, and between suspension and solution the water with salinity level 40-300 g/l or water suspension of polyacrylimide with concentration 0.0001 0.1 wt % are injected.

EFFECT: increased oil recovery of the deposit.

2 cl, 4 ex, 4 tbl

FIELD: oil and gas production.

SUBSTANCE: invention provides a method of developing oil pool allowing production of oil from water-rich oil reservoir under difficult geological-tectonic conditions in the last development stage. In the method, neutral salt of carbonic acid and acid solution are forced into formation through injecting well with water generated in gas-liquid fringe created in formation. After pumping of neutral salt of carbonic acid, acid solution is pumped by portions alternating with water pumping. Before pumping of acid solution portions beginning by at least second portion, selective insulation of high-permeable formation intervals is performed. Aforesaid neutral salt of carbonic acid utilized is sodium carbonate aqueous solution or aqueous suspension of calcium carbonate and aforesaid acid solution is aqueous hydrochloric acid solution. Selective insulation of high-permeable formation intervals involves use of freshly prepared controllable viscoelastic composition containing water-soluble acrylic polymer, cross-linking agent, thermal stabilizer, surfactant, and water. Summary concentration of acid solution is determined from concentration of neutral salt of carbonic acid on the base of stoichiometric proportions.

EFFECT: increased efficiency of maintaining formation pressure and thereby oil recovery of formation due to leveled displacement front and reduced probability of the rupture of formation rock backbone, and simplified control of phase state of gas-liquid fringe by changing pressure of pumped acid solution portions.

8 cl

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