Method for concurrent-separate operation of several beds via one force well in turns

FIELD: mining industry.

SUBSTANCE: at least one pipes column is lowered into well with constant or variable diameter with or without plugged end, with at least one packer lowered below upper bed of hydraulic and/or mechanical effect with or without column separator. Below and above packer mounting assemblies are lowered in form of well chamber, or nipples with removable valve for feeding working agent through them respectively into lower and upper beds, mounting packer and pressing it from downwards and/or upwards. Minimal absorption pressure for each bed is determined during pressing. Working agent is pumped from mouth into pipes column hollow at given pressure, directing it into upper and/or lower beds through appropriate detachable valves in mounting assemblies. Total flow of working agent is measured on the surface as well as mouth pressure and/or temperature in pipes column hollow and behind-pipe well space. Face pressure of upper bed is determined as well as pressure in pipes column and behind-column space at depth of detachable valve in mounting assembly above the packer. Flow of working agent pumped into upper bed through detachable well is determined, subtracted from total flow and flow of working agent fed into lower bed is determined. Actual flows of working agent for beds are compared to planned values. In case of differences mouth pressure is changed ad/or detachable valves for one or more beds are extracted from mounting assemblies by rope gears. Their characteristics and/or parameters are determined and altered. After that each detachable valve is mounted again into appropriate mounting assembly by rope gears and pumping of working agent through them into appropriate beds is resumed.

EFFECT: higher efficiency.

25 cl, 11 dwg

 

The invention relates to the production of hydrocarbons (oil, gas, gas hydrate) on multilayer fields and can be used for dual (OCR) and/or alternate (PZ) injection of the working environment (water, gas, foam, steam, emulsions, mixtures, etc. in one or more objects (layers) in order to maintain the project reservoir pressure maintenance (rpm) in the area of selection of the fluid, and/or preventing or eliminating cones, water and gas, and/or disposal of excess water or gas, as well as for the combined (combined) method "injection (ARI or PZ) - mining (OSA or PD)" if the injection well to one or more temporarily producing formations.

Known sources of information on dual use (mirzadjanzade AH Technology oil production. M., Nedra, 1986; RF Patent №2194152, E 21 In 43/12, 34/06, Bulletin No. 34 from 10.12.02, Directory. Equipment for separate operation of multiple zone oil and gas wells. Containertypes., 1988, p.43-45), including the descent into the well pipe string, with one or more packers and regulators.

The aim of the invention is the use and effectiveness of technology dual (DC) and/or alternate (PE) operation of multiple injection and/or temporary production facilities (dps who VDT) each injection well stacked on the field.

The effectiveness of the technology for multilayer fields mainly achieved through targeted redistribution and injection of the working fluid for the reservoir injection wells to maintain the project reservoir pressure maintenance (rpm) in the area of sampling formation fluid and/or additional production of hydrocarbons, and/or disposal of excess water or gas into the reservoir(s), and/or downhole production fluid from a reservoir and pumping it in another layer of one well, including through opportunities:

1) disaggregation of development objects by separating groups of layers in different layers and layers on isolated layers depending on their permeability, reservoir pressure and/or the terms and objectives of the operation;

2) OCR and/or health-promoting work environment multiple (two or more) layers of one injection well;

3) PZ working environment and PD fluid from one or more injection and mining temporarily layers one injection well, including periodic discharge inside the borehole fluid (for example, formation of gas or gas-liquid mixture from a reservoir of high pressure in the other layer of low pressure and PZ with the mouth (or from another reservoir wells) working agent (e.g. water) in the reservoir of low pressure gas and/or water-gas influence on productive place is;

4) ARI working environment and PD fluid from one or more injection and mining temporarily layers one injection well;

5) PZ or ARD working environment and HORDES of fluid from one or more injection and mining temporarily layers one injection well;

6) download and direction of the working environment in each layer, with the mouth over a separate connection pipe, to be able to measure, record expenses and to regulate the mode of injection for each layer separately;

7) rapid installation and regulation of the flow rate at the mouth for each reservoir injection wells by selecting the appropriate for them wellhead valve or regulator;

8) simultaneous injection of different columns of tubes in one layer of environments with different physico-chemical and temperature properties;

9) reduce capital expenditure on the drilling of new wells;

10) accelerated development of multilayer deposits limited number of wells;

11) simultaneous injection of steam and cold water to prevent man-caused negative impacts on the reservoir from its cooling while maintaining reservoir pressure;

12) optimization of injectivity profile by creating differentiated repression on the layers and/or layers with different permeability;

13) use the of technology for non-stationary reservoir stimulation as due to a change in the mode of injection of the working environment, and due to the changing modes of extraction fluid injection wells;

14) use technology to the combined "ARD and HORDES" and/or "PZ and DD" method of production of high-viscosity oil (fountain, pump, gas lift or jet ski lift) from the injection well by sending and heating it below the producing formation due to the high geothermal temperature of rocks, and by reducing losses temperatures of high-viscosity oil in the direction from the bottom in the channel of a smaller diameter pipe and fracture patterns of high-viscosity oil, adding water, which is pumped from the mouth or extracted from the lower and/or upper reservoir;

15) use of technology for hydraulic fracturing (interval, selective, directional, point) of the individual layers and interlayers;

16) use of technology for industrial gas production in the development of gas hydrates (gas reserves in the permafrost and in ocean floor in the form of the bottom pan and sediments of the Arctic and Antarctic seas) by injection of the fluid (steam, hot water) through a single channel tube, and through another pipe channel - selection hydrocarbon gas in a continuous mode or selection in periodic mode;

17) use technology to the development of the oil rim and oil is ascendency fields with gas cap and water oil deposits by creating a (continuous or periodic) of the blocking barrier of the working agent to reduce gas and/or water (prevention their breakthrough to the borehole and the formation of a cone in the bottom-hole zone);

18) use technology to the time of extraction of oil from oil-saturated site and download a working environment in water saturated portion of one layer of injection wells, in particular by injection environment through a single channel tube, and through another pipe channel - selection of oil in a continuous mode or selection in periodic mode.

The positive effect from the use of technological solutions is achieved due to: create and/or maintain the project (optimal) reservoir pressure in the area of selection and/or increasing the production fluid, as well as targeted regulation of fluid flow to the reservoir, reducing costs and time to carry out repair work on the well, increasing the service life of wells and underground equipment, reducing capital expenditures for the drilling of additional wells.

The purpose of the invention is achieved by carrying out the following operations.

Lowered into the borehole, at least one string of pipe with constant or variable diameter without (open) or plugged the end, at least one lowered below the upper layer of the packer hydraulic and/or mechanical action, with or without disconnector columns, below and above which launched at least one knots landing is a downhole camera or fitted with a removable valve for flow through them working agent (working environment) respectively in the lower and upper layers.

Put the packer and presoviet it (leak) from the bottom and/or top.

Determine if the pressure testing of the packer minimum pressure absorption of each layer (conditionally accept him equal Plast pressure, calculated or measured in the borehole pressure gauge).

Download the working agent from the mouth into the cavity of the pipe string at a given pressure (including at its maximum value), directing it at the top and/or bottom layers through the appropriate removable valves (i.e. through their channels) in the boarding nodes.

Measured in accordance with the specified (estuarine) pressure total flow of the working agent (for example, a flow meter on the mouth or above the injection point with dual injection), wellhead pressure and/or temperature in the cavity of the tubing and/or annulus of the well.

Determine (for example, by calculating or measuring gauge or depth sounder, etc.) the pressure in the string of pipe and the annulus at a depth removable valve in a landing site above the packer.

Find (with dual injection) flow of the working agent, injected into the upper layer through a removable valve, subtract it from the total flow of the working agent, injected into the lower reservoir.

Compare actual expenditures operating agent for the reservoir project their values, and when their ex is chii (largely outside the inaccuracy of the measuring instrument) change wellhead pressure and/or remove one or both layers of removable valves of landing sites by using rope techniques.

Define and modify their characteristics and/or parameters removable valve, then re-install each removable valve in the appropriate landing site using rope techniques and continue pumping the working agent through them in the appropriate layers.

These technological and technical solutions in General increase the effectiveness of the technology at the same time separate and/or sequential operation of multiple injection and/or temporarily producing objects (layers) of each injection wells on the stacked field. The above-mentioned operations, in particular, allow us to define and regulate the flow of the working agent injected into the reservoirs of one well as in dual and sequential injection. Moreover, by changing the removable valve is changing downhole and, accordingly, the reservoir pressure at a given value of the wellhead pressure. In addition, based on surface parameters of technological solutions allow you to determine the characteristics (coefficient of acceleration, etc. of each layer.

Also when implementing the method, depending on operating conditions, perform the following operations.

Reveal several additional layers below the top layer, the lower and establish between them at the same time repositoryfile several packers hydraulic and/or mechanical action, with or without disconnector columns and define for each additional layer of minimum pressure absorption and/or reservoir pressure, and/or pickup.

Determine the acceleration and/or pressure of each of the layers, alternately opening only one insulating layer and other layers from the cavity of the pipe string by setting in the respective landing sites removable valve in the form of a hollow tube, and/or upload a working agent separately in each layer at one or more different values of flow rate, measure and/or determine the appropriate pressure in the string of pipe and build the dependence of changes in the flow pipe from the pressure.

Measure and/or determine the pressure in the string of pipe at a depth of removable flaps and/or landing sites for injection through them working agent in the reservoir, and then for each layer, respectively, determine the actual costs of the working agent from the dependence of the flow pipe from the pressure.

Change wellhead pressure in the string of pipe, measure and determine the corresponding total flow rate through the borehole and expenses of the strata upon which to build according to changes of the flow through the borehole and expenses for the layers from the wellhead pipe pressure, then ask wellhead pressure necessary to ensure injection regime of the flow through the borehole and expenditure for individual layers, regulate the mode of injection by changing the diameter of the mouth of the nozzle or the wellhead staterail using wellhead pressure regulator after itself.

Above the upper landing site or a lower packer in the well column pipe of relatively larger diameter to reduce pressure loss by friction during pumping (in large volume) of the working agent in the layers.

In the well above the upper reservoir lower packer mechanical and/or hydraulic action, with or without disconnector columns for isolation (in particular, worn out, leaking) casing pressure (if this pressure exceeds the pressure of her crimp) injection, and over the landing site with a removable valve for circulation and/or crimp the pipe string.

Isolate one or more layers from the cavity of the pipe string by setting in the respective landing sites removable valve in the form of a hollow tube and provide an opening of only one layer, measured wellhead pressure or dynamic fluid level in the cavity of the pipe string after its stabilization and measure and/or determine the formation pressure of the corresponding layer.

Isolate at least one layer from the cavity of the pipe string when another or other layers by reducing wellhead pressure injection working agent to close in one or more landing sites removable valve with a relatively large opening pressure.

Isolate the upper layer from the cavity Colo is by pipes, measured wellhead pressure or dynamic fluid level in the annulus after its stabilization, and then determine the corresponding pressure of the upper layer and the coefficient of his pickup.

Fill partially the annulus buffer inert atmosphere with a density less than the density of the working agent to prevent freezing and/or protect the casing from corrosion.

The string of pipe at a depth of reservoir equipped with two or more landing sites with a removable valve for increasing the flow of the working agent, injected into the formation, and/or the removable valve in the form of the underlying instrument (for example, pressure gauge, thermometer, flow meter, nozzle, etc.) to measure physical parameters.

Equip the string of pipe above the upper layer of the packer mechanical action, with at least two packer lowered into the borehole on one string of pipe in a single descent, with the upper packer set by creating him axial loads after planting and crimp on the tightness of the lower packer.

To ensure the reliability of the downhole installation by acid treatment of the reservoir is injected into the column pipe acid solution of a given concentration portions, alternating and washing her work agent.

Removable valves you anaut in the form of a controller with one or two internal opposite interchangeable fittings with or without reverse spring-loaded nodes to provide one-way or the opposite flow direction, and/or gas-lift valve for regulating the pressure of the flow and/or pressure regulator to themselves or after, and/or differential pressure regulator for maintaining the flow rate and/or depth gauge, with or without a thermometer for measuring pressure and temperature before and/or after and/or flow regulator with pressure gauge and/or pressure gauge with a bleed for measuring pressure while flow through him working agent or produced fluid, and/or flow meter, and/or cut and/or stabilizer, and/or deaf tube.

Landing sites with removable valves to pump installed at the site of perforation interval seams to eliminate the negative impact of the flow of injected through a removable valve operating agent on the production casing and/or improve the accuracy of measurement of the physical parameters of the reservoir with removable valve - depth measuring device.

Choose and set the opening pressure of the removable valve for each of the layers, then in the injection process, change the number of open reservoirs, which are injected by discrete changes wellhead pressure by changing the diameter of the mouth of the nozzle or wellhead fitting or using wellhead pressure regulator after itself.

Determine the depth position of each packer, assessing to what Yu participation in work well together dissected layers or separate perforated intervals of the formation based on the results of photocamera, thermometry or combining into a single object multiple intervals of the formation in the presence of cross-flows between them, or a pre-packer in turn is mounted above each perforation interval of the reservoir, determine the acceleration per unit of power, and, if the specific pickup later added interval of the reservoir close to the value of the previous interval or intervals, the packer is lifted and set on the next perforation interval and repeat the process of determining his pickup, in this case, if the interval with a specific pickup differs from the previous one by more than the permissible value, then it is separated by a packer from the preceding for further impact on each of them differential repression.

Define and share the packer saturated the area from the water-saturated part of the reservoir injection wells, the working agent is injected into water-saturated area, selecting the oil continuously or periodically from the oil-saturated part of the formation.

Define the boundary of the buffer inert medium with the working agent in the annulus of the ultrasonic method in case of leakage and the rise of the interface above the specified level, increase the amount of buffer inert environment in the annulus by the periods of the systematic or continuous paging.

Simultaneously with the pumping of the working agent in one or more layers of injection wells learn and/or temporarily extract fluids from another or other layers with a temporary connection to the oil and gas.

Before injection of the working agent in the upper or lower oil reservoir of his master, producing formation fluids through the annular space or the string of pipe, at the same time, continuously or periodically pumped working agent in the lower or bottom separated layers through the string of pipe or the top of the reservoir through the annular space.

Learn one or more layers of injection wells swabbing and/or creation of high depression on the formation and/or aeration of the liquid in the backwashing process well, and/or gas and/or pump and/or discharge of water - spouting, and if necessary to increase the acceleration of one or more layers of hydraulic fracturing and/or the bottomhole zone treatment acids, and/or solutions of surface-active substances, and/or use of thermal methods of bottomhole zone treatment.

Reservoir pressure for each of the layers is determined by the pressure recovery in the stopped hole or the minimum pressure at the beginning of the absorption layer, and downhole pressure and/or flow rate during pumping of the working agent to the each layer determine root device.

Down in the hole a few packers on a single string of pipe in a single descent, and stress failure at the same time all of the packers to extract them from the wells installed within 8-12 tons by redistributing the number of prescribed shear screws one packer for all packers.

This solution allows the use of technology and techniques for OCR and/or PZ, implementation of a combined method "injection-production, including OCR and/or OSA, and/or PZ, and/or PD, as well as for managed downhole flow and/or injection environment in one or more pressure and/or time of producing layers of one injection well and/or create a barrier from the work (insulation) protection between oil and/or gas and/or water-saturated intervals of the reservoir.

Principal views of some of the targets for the implementation of the method is given in figures 1-11, in particular: figure 1 shows the setup for OCR and/or PP, or a combined method "injection and/or production; 2 - the same, only with a variable diameter of the column pipe; figure 3 is the same, only with an open bottom end; figure 4 is the same, only with two columns of tubes; figure 5 is the same, only without or with a pump; figure 6 - installation for the combined method, "injection and/or production; 7 is the same, with only two packers; Fig removable valve in the form of a pressure gauge with a bleed and/or flow meter; figure 9 - the flow (flow) with one spring-loaded shutter in the saddle; figure 10 - flow regulator with two opposing fittings, with or without spring-loaded valves; figure 11 is a differential pressure regulator for maintaining a differential pressure (flow rate).

Installation for implementing the method shown in figure 1, includes the descent (primary or secondary production string in the well 1 of the column tube 2 with muted the lower end 3 of the shank (from several pipes) 4 to collect sand and down between the layers (for example, N1andP2) packer 5 (disconnector two cavities between well 1 and the column tube 2). Above the packer 5 top can be lowered disconnector column 6 (in particular, with the internal bore channel under a removable valve) to be able to disconnect the string of pipe 2 from the packer 5 and remove it from the well 1, and repeated trigger and connect the tubing 2 with the retainer 5. Below and/or above the packer 5 is equipped with one or more landing sites as well chambers 7 and/or 8 and/or 9 and/or 10 with a removable valve 11 and/or 12 and/or 13 and/or 14 (for example, in the form of a hollow tube and/or controller and/or flow and/or pressure gauge etc). Installation can also be about namena landing site in the form of a Central nipple 15 above the packer 5 to install the removable valve when the casing pressure testing of the pipe 2 and/or regulate the operation mode of the lower layer of the P 2.

This setting (see figure 1) can be used for OCR and/or health-promoting work environment through a common channel of the column tube 2 in the layers of the P1and P2and for the combined method, in particular ARD or PZ working environment in the formation of the P2one channel of the pipe 2 and the OSA or PD fluid from the reservoir P1on strobo or, on the contrary, with the working medium, which is pumped into the bottom of the P2or the top of the P1layer partially (regularly or occasionally) through removable valve 14 may be directed to strobo for hydraulic and/or destruction of the structure of the viscous fluid (oil)extracted respectively from the upper P1or lower P2layer, and, in addition, for operations with high-viscosity oil downhole camera 7, 8, or 9, 10 can be lowered as far as possible, below the extracted layer to warm the high viscosity of the oil due to the mining of lower temperatures breeds and/or reducing the loss of its temperature. Installation according to figure 1 can also be used to create a barrier between the water and/or gas layer and the oil rim reservoir by continuous or periodic pumping of the working environment within their borders through the annulus or annular space. At the same time to prevent breakthrough of gas from the gas cap above the packer 5 plot of P1is their border - gas-oil contact, and P2p is animalsa for oil-saturated interval oil production from the oil rim.

The installation shown in figure 2, is fitted above the packer 5 and/or downhole camera 10 column tube 2 with a larger diameter to reduce pressure loss by friction and can be used for a large flow rate. The installation shown in figure 3, is fitted under the packer 5 pipe 2 (shank) with an open bottom end and landing site 16 without or with removable valve 17.

The installation shown in figure 4, has two columns greater pipe 2 and smaller 18 diameter, and the cavity between a bottom separated by the packer 19 of smaller diameter. Packer (disconnector) 19, in the particular case, may be made in the form of housing 20 with a sealing stem 21. The lower packer 5 and the housing 20 is lowered into the well 1 to the string of pipe 2 with a larger diameter. And after the landing of the packer 5 and crimp it on the tightness of the top and/or bottom descends sealing the shaft 21 on the string of pipe 18 of a smaller diameter and is installed in the chassis 20 in the casing 20 can be opened, the circulation channels 22).

This setting (see figure 4) can also be used for the combined method, in particular ARD or PZ working environment in the formation of the P1on strobo and HORDES or PD fluid from the reservoir P2the column pipe 18, and the fluid extracted from the formation of the P2gas-lift or jet (if this is removable which the first valve is in the form of a jet pump) operation, pumping a working medium (gas, oil, etc) in the cavity between the pipe 2 and 18, and PZ of the working environment in the formation of the P2cutting out a layer of P1and PD fluid from the reservoir P1cutting out, on the contrary, the formation of the P2.Moreover, the formation of the P1or P2periodically clipped by setting, respectively, in the downhole camera 8 or 9 removable valve 12 or 13 in the form of a hollow tube. Also the formation of the P1cut through the application and closing for him removable check valve 13 and the opening of the removable valve 12 for formation of the P2occurs under high injection pressure of the working agent in the string of pipe 18, and, conversely, when you stop pumping and the pressure in the string of pipe 18 is removable closure valve 12 and opening removable check valve 13 for the extracted layer of the P1. There is also at least one downhole camera 9 can be lowered as far as possible, below the extracted layer of the P1the purpose of heating the heavy oil through the mountain temperatures lower rocks and/or reducing the loss of its temperature at the bottom of it into the cavity of the tube.

The installation shown in figure 5, can be equipped with an additional column of larger diameter pipes 23 with or without a packer 26 to protect the production casing 1 and/or the pump 24. In this first packer descends into the well 1 to the string of pipe 2, and then installed and tested for tightness at the top and/or bottom, and then detaches the column tube 2 from the packer 5 using the switch columns 6 and retrieved from the well 1. Further down in the well 1 column pipe 23 of larger diameter, with or without the retainer 26, and then through it descends the column tube 2 of smaller diameter, with or without a pump 24 and/or the downhole cameras 9, 10 and tightly, but not rigidly connected with the packer 5.

This setting (see figure 5) can be used for the combined method, namely for ARD or PZ working environment in the upper layer of the P1on strobo or cavity between the pipe 23, 2 and ORD or PD fluid from the lower reservoir P2or, Vice versa, and also for downhole injection of fluid. When downhole injection pump 24 may be in the form of an inverted ESP, in particular, with the outer casing 25, hermetically isolating the pump intake 24 from Strube and, Vice versa, connecting the intake of the pump 24 with the cavity of the pipe string 2 to the direction of flow of the produced fluid (water) from the upper layer of the P1in the string of pipe 2 (for example, through the downhole camera 10 and/or removable valve 14) above the pump 24, and then the direction of its cavity from the pipe 2 into the casing 25 and from there to the pump intake 24 and its subsequent injection into the lower reservoir P2. The consumption of liquid (water)is injected into the lower reservoir P2from areeda depth meter spokeman in the interval between the downhole camera 10 and the pump 24.

Installation (see Fig.6, 7) can also be equipped with a packer 26 and/or the downhole chambers 27, 28 with removable valves 29, 30. These settings can also be applied respectively for ARD or PZ working environment in the 3-or 2-layer, as well as for the combined method "injection - extraction".

In installations downhole camera, in the particular case, can be performed type KT1-60B, KT1-73, KT1-B, KVM and other, side pockets which are removable valves, such as gas-lift 5G-25, 5G-25R, G-38, G-R with fittings (seated) and without or with bellows (development Bureau Neftemash), type differential KA-25 and KAU-25 (development starting his career), and others.

Removable valve (see Fig), in the particular case, can also be the form of a pressure gauge with a bleed (saddle) and/or flow meter, which consists of a housing 31 (from one or multiple parts) with flow channels 32, the upper 33 and lower 34 outer seals (cuffs), shank (tip) 35 with lock 36, bandwidth, channels 37 and the cylinder 38. Inside the housing 31 posted by the measuring system 39, and lower bandwidth channels 32 of the saddle 40 (e.g., choke, choke, etc). Also, in some cases, in the channel of the shank 35 may be an additional fitting 41 (e.g., smaller diameter). In addition, over the saddle 40 which may be placed thrust bearing 42 to eliminate the possibility of failure of the seat 40 at high pressure drops.

Removable valve (see Fig.9), in the particular case, may also be in the form of a flow regulator with a single spring-loaded saddle, which also consists of a housing 31 (from one or multiple parts) with flow channels 32, the upper 33 and lower 34 outer seals (cuffs), shank (tip) 35 with lock 36, bandwidth, channels 37 and the cylinder 38. Inside the housing 31, is the seat 40 with the spring loaded (spring 43) return unit 44 (e.g., in the form of a sphere, cone, piston etc). Removable valve (see figure 10), in addition, you may be furnished with two seats 40 and 45 and the opposite nodes 44 and 46, and the cylinder 38 is made with crossing channels 47. Removable valve (see 11) is made with a saddle 40 in the form of a bolt (piston) without or with a choke (inductor), while on the saddle 40 and the spring 43 has the ability to control efforts.

When implementing the method are carried out the following operations.

Descend into the well column pipe 2 with a constant (for example, see figure 1, 3, 5-7) or variable (see figure 2, 4) diameter without (open 16) or with muted 3 end, bottom and/or top packers 5 and/or 26 (with or without disconnector column 6), some landing sites 7, 8, 9, 10, 15, 16, 27, 28, without or with removable valves 11, 12, 13, 14, 17, 29, 30. Put each packer 5 and/or 26, presoviet its bottom and/or top for leaks and determine the minimum pressure is ogloszenia (Cog) each open layer (for example, the Assembly CA, connecting the wells to the line etc) and/or its formation (RPL) pressure (for example, conventionally taken as equal to the minimum pressure of the absorption layer or measured its value in the borehole pressure gauge, or is determined by calculation). Download the working agent from the mouth into the cavity of the pipe string 2 and/or 18, and/or 23 when changing estuarine (Rui) pressure (for example, when i=2 or 3 values, including at its maximum value), directing it at the top and/or bottom layers through the channels some removable valve 11, 12, 13, 14, 17, 29, 30 and/or only through the channels of some of the landing sites 7, 8, 9, 10, 15, 16, 27, 28 (when there are no removable valves) and measure corresponding to each osteoma pressure (PNi) - total consumption (Qithe operating agent (e.g., wellhead flow meter or descent of the deep flow in the string of pipe 2 above the point of injection borehole camera 10) acute respiratory infections and/or consumption for each individual layer (Qkwhere k is the ordinal number of the layer) at PZ, and/or flow agent (Q2or Q3) on the bottom layer with OCR, and/or wellhead pressure and/or temperature in the cavity of the pipe string (Ruiand/or Theiand/or the annulus (Rstiand/or TSTi) wells. Determine (for example, by calculating or measuring gauge or depth sounder, etc.) press the tion in the pit (Rsab i) upper reservoir and/or the string of pipe (RTRi), and/or annulus (RSETion the depth of the top and/or bottom layer (removable valve and/or landing site). Find acute respiratory infections (for example, two layers) the flow of the working agent on top (Q1) or lower (Q2) layer by subtracting from the total consumption (Q) working agent, respectively, flow injection working agent (calculated or measured depth meter) at the bottom (Q2or upper (Q1) layer (for 3 or more layers determine the flow rate of the layers similarly as for 2 layers). Calculate the results of measurements of the ratio of pickup (CRCkeach layer, calculate and choose the characteristics (for example, the diameter of the fitting, etc. and/or parameters (e.g., pressure calibration, etc.) removable valve on the basis of the project (Qk) expenses (set of field development) layers. Make a change or set the selected removable valve 11 and/or 12, 13 and/or 14, 29 and/or 30 in the appropriate landing sites 7 and/or 8, 9 and/or 10, 27 and/or 28, and then upload and repeat the measurement and determine the actual costs (Qkthe operating agent (by calculating and/or measuring meter deep) layers, compare actual expenditure (Qk) with project (Qktheir value is s, change in the difference (largely outside the inaccuracy of the measuring instrument) and actual project cost wellhead pressure (PN) and/or to remove the upper and/or lower layers of the gas lift valve of the landing sites by using rope techniques, determine and modify the features and/or parameters removable valve, then repeat the installation of each of them in an appropriate landing site using rope techniques and continue pumping the working agent through them in the appropriate layers (in particular, prior approval and actual project costs by layers).

When translating well at PZ (for example, for pumping the working environment first month on one layer and the next month on another layer) or the definition of pick-up, or organize a reliable accounting of the injected water in the reservoir of each of the layers isolated by one or more layers from the cavity of the pipe string 2 and/or 18 by installation of appropriate planting sites 7 and/or 8, 9 and/or 10, 27 and/or 28 removable valve 11 and/or 12, 13 and/or 14, 29, and/or 30 in the form of a hollow tube. In this case, it may be provided for pumping the working agent in one layer with one or several different consumption values to determine the dependence of the change of flow from pipe pressure at the depth of each layer, for example Q1=f (TJ is) and Q 2=f (RTR). Having these dependencies and pressure RTR1,RTR2with OCR, you can determine the actual Q1and Q2for the corresponding layer of the P1and P2.

You can also build dependencies Q=f (P), Q1=f (P) and Q2=f (P) and determine the required mode of injection (total) flow rate through the borehole and expenditure for individual layers (where R may be a wellhead or pipe, or annulus, or annular, or bottom-hole pressure).

The pressure reservoir and/or bottomhole pressure, and/or pipe pressure and/or flow agent layers determined or calculated based on surface parameters, or by measuring their physical values of the underlying instrument, in particular, with removable valve in the form of a pressure gauge and/or thermometer, or regulator-fitting with a combined pressure gauge and/or flow meter installed in the borehole camera or nipple.

When combined (combined) operation "injection environment in a layer - extraction of fluid from another layer of" injection well mastered and temporarily extract fluids from one or more of its layers (e.g., fountain, gas lift or pumping method), with connections to the oil and gas. Over time, when each of the upstream reservoir (for example, using a pump, fountain or gas-lift lift) becomes arent belnem, then he was transferred to the injection. Also when using technology to OCR and HORDES and/or PP and PD formation fluids, including high-viscosity oil, dobiasova fountain, pump, gas lift or jet ski lift of the injection wells by sending and heating it below the productive formation (P1or P2) due to the high geothermal temperature of rocks, as well as by increasing the flow velocity and, correspondingly, reduce the loss of temperature-viscosity oil in the direction from the bottom (for example, on figure 4, respectively, through the downhole camera 9 or 8 and/or removable valve 13 or 12) in the cavity of smaller diameter and fracture patterns of high-viscosity oil, adding water, which is pumped from the mouth or extracted from the lower (P2or upper (P1) layer. Moreover, this technology allows to deepen the insertion point of the working environment through the downhole camera 10 (see figure 4), in particular injected gas below the upper layer of the P1. In addition, when combined method "PD and PZ" turn inside the well is produced and pumped fluid "layer gas or gas-liquid mixture from a reservoir of high pressure in the other layer of low pressure (through the corresponding downhole camera with removable valve) and PZ (for example, from the mouth or from another layer is quaini) working agent (water) in the reservoir low pressure (see figure 1-7) for gas and/or water-gas influence on the reservoir. While PD and PZ is carried out on one or two different channels of the pipes, and when the PD layer high pressure opens and hydraulically connected through the corresponding downhole camera with a layer of low pressure, and at PZ, on the contrary, the formation of high pressure tightly clipped from the reservoir to the low pressure by planting hollow tube or removable closure of a control valve in the downhole camera on the depth of the formation of low pressure and/or closing the valve in the Central landing nipple 14. In addition, the process and the installation according to figure 7 can be used for cyclic effects (gas and/or water) on the top layer of P1through periodic bypass gas within the well from the lower reservoir P2with high pressure in the upper layer of the P1with low pressure, and then cut the bottom layer of the P2(for example, a removable check valve 15 above the packer 5) under high wellhead pressure injection and discharge from the mouth working agent (water) in the upper layer of the P1or it can be used, on the contrary, for the cyclical impact on the bottom layer of P2.

If for measuring pressure and/or flow rate of the removable valve (see Fig) made in the form of a pressure gauge with a bleed and/or spending the Omer, then the flow goes through his saddle (fitting) 40 and simultaneously acts on the measuring system 39, which recorded its pressure and/or temperature and/or flow rate. Also to be able to crimp the tightness of the installation removable valve in the downhole camera and/or regulate the pressure of the flow of he (see Fig.9) is in the form of a flow regulator with a single spring return unit 44 over the saddle 40, which opens from the pressure of the flow under the saddle 40. Removable valve (see figure 10), if performed with two seats 40 and 45, the working medium or fluid passes through both saddle 40, 45 and the consumption increases with the limited diameter of the valve. Removable valve (see 11), if made in the form of the liquid flow regulator, its operation is derived from the differential pressure before and after the saddle 40 (fitting). That is, when the pressure change before and/or after the saddle the last 40 moves up or down, changing the cross-section bandwidth of the channels 32, the result of which is supported by the differential pressure on the valve to control fluid flow.

A specific example of OCR (figure 6) for wells with three injection layers Yu1, S2and th3(with the initial formation pressure, respectively, 29.3, 29.5 and 29.6 MPa) is shown below:

1) in the hole descends: tubing - 73 mm (pos.2) with plugged end (POS) to a depth of 2990 m; packer hydraulic action (pos.5) with disconnector columns (pos.6) to a depth 2956 m, packer mechanical action (option 26) to a depth of 2946 meters, borehole camera (pos.7, 9, 27) for removable valves (pos.11, 13, 29) to a depth 2960, 2950 and 2930 meters for flow through them working agent, respectively, in the lower Yu3(perforation interval 2958-2970 meters), the average Yu2(perforation interval 2944-2954 meters) and u1(perforation interval 2928-2934 meters) formations;

2) is fit and crimp hydraulic packer (5) the top and bottom and at the mouth of the measured pressure at the beginning of the absorption layer Yu3- 1.2 MPa, based on which, taking into account the density of water (ρin) is determined by the current reservoir pressure reservoir Yu3:

CLu=Baguin*g*Hu*10-6=1.2+1015*9.8*2964*10-6=30.7 MPa;

3) is fit and crimp mechanical packer (option 26) top and bottom and measure the pressure at the beginning of the absorption layer Yu2- 4.8 MPa and a layer of Yu1- 5.8 MPa, on the basis of which considering the density of water (ρinalso the current reservoir pressure to layers Yu2and th1:

CLJ2=BagJ2in*g*HJ2*10-6=4.8+1015*9.8*2949*10-6=34.2 MPa,

CLU1=BagU1in*g*HU1*106 =5.8+1015*9.8*2931*10-6=35 MPa;

4) pump water from the mouth into the cavity of the pipe string (2) under the two regimes, characterized by two wellhead pressures 9 and 15 MPa, respectively, measure the total water flow rate Qo (flow meter on the mouth or in the borehole at a depth of 100 metres) - 440 and 895 m3/day through the borehole;

5) whenever PN=9 and 15 MPa down the flow in the column pipe (2) successively to a depth of between downhole cameras (pos.7 and 9.9 and 27) and measure the water flow in the pipe (2) for formation Yu3(Q3=148 334 m3/day) and for layers Yu2and th3(Q2,3=401 and 828 m3/day)the results of which determine the flow of water layers (bottom to top) for each PN:

- (Qu)1=148 m3/day;

- (QJ2)1=(QJ2,3)1-(Qu)1=401-148=253 m3/day;

- (QU1)1=Q1-[(QJ2)1+(Qu)1]=440-(253+148)=39 m3/day;

- (Qu)2=334 m3/day;

- (QJ2)2=(QJ2,3)2-(Qu)2=828-334=494 m3/day;

- (QU1)2=Q2-[(QJ2)2+(Qu)2]=895-(494+334)=67 m3/day;

(QU1)1and (QU1)2you can also define for top removable valve (POS) based on the measured pressures PN and RSAT evaluated in depth SK is agenoy camera (POS);

6) on the basis of measurements Q1, Q2and Ru1, Ru2calculate the pressure in the column pipe Rzab (pos.2) at the depth of the reservoir Yu1or upper borehole camera (POS) - 37.1 MPa when the first mode, and 39.8 MPa in the second mode;

7) determine the coefficient of injectivity of the reservoir Yu1(given the loss of pressure in the string of pipe):

CRCU1=(QU1)2-(QU1)1/(Rsub-Rsub)=(334-148)/(39.8-37.1)=69 m3/(day*MPa).

The coefficients pickup for layers Yu2and th3identify similar and they will be equal CRCU1=84 and CRCU1=5.8 m3/(day*MPa). Also for simplicity of calculation of the CRC can be determined when measured two very close values of Q under the simplified formula (loss of pressure on the friction considered equal):

CRCth=[(Qth)2-(Qth)1]/(PY2Ru1).

Attention! It should be noted that when the stop is well measured flow of water from the upper reservoir Yu1(45 m3/day) partially into the reservoir Yu2(22 m3/day) and into the reservoir Yu3(23 m3/day) allows to check the correctness of the found of reservoir parameters:

QU1=KCR(RZab-RPL)=QJ2+Qu=(34.46-34.2)*84+(34.7-30.7)*5.8=45.

Due to the fact that the reservoir Yu1is zbytocny compensation selection of its formation fluids by pumping water, and its pressure in the zone selection exceeds the maximum allowable 34 MPa (determined from hydrodynamic modeling), it is necessary to limit the download and install it at the level of 120 m3/day. At this flow rate should be reduced compensation to the optimum level and pressure in the zone of discharge to an acceptable value. Therefore, for a given stratum was set the regulator flow rate of injected water (see 11), supporting the setpoint flow rate regardless of changes in downhole pressure and repression on the layer.

Due to the fact that the reservoir Yu2made excess payment of his selection of reservoir fluids by pumping water, but pressure in the zone selection is within the permissible limits 34-35 MPa (determined from hydrodynamic modeling), it is necessary to limit the download and install it on level 245 m3/day, stabilizing the optimal value of the bottomhole pressure, but preventing its further growth. This is the water injection will also help to provide an optimal level of compensation, selection of fluids from the reservoir Yu2. So for reservoir Yu2installed the pressure regulator after themselves (type gas-lift valve of the Ministry of health-25), supporting the value specified bottomhole pressure (repressi the reservoir and the reservoir pressure in the actuation zone) c check valve to prevent flow from the upper reservoir at the time of stop of the well.

On the other hand, the reservoir Yu3due to insufficient compensation of sampling formation fluids by pumping water necessary to maximize water pumping. So for reservoir Yu3:

- first, it identified the critical pressure of 41 MPa, in which there is an abrupt increase of the coefficient pickup with 5.8-12.9 m3/(day*MPa).

secondly, there was installed a two-way fitting (figure 10), with a maximum throughput minimizes the pressure drop across it).

Option 1 (Assumption). If the ratio of pickup for reservoir Yu3remained unchanged (constant, i.e. no jump),then the method is implemented as follows.

Determine the pressure in the string of pipe (2) at the depth of the top removable valve (with limited income strata Yu1and th2) when the maximum wellhead pressure of 15 MPa. When consumption 439 m3/day pressure at the depth of the reservoir Yu1well 43.1 MPa and the depth of the reservoir Yu3- 43.5 MPa (more than in the second mode at a flow rate of 895 m3/day, due to the reduction of friction losses), and injected into the reservoir Yu3without limitation (without compromising water flow), respectively:

Qu=(RZab-RPL)*CRCu=(43.5-30.7)*5.8=74 m3/day.

Make sure that the differential pressure on the removable valve to place the W 3ΔPu=(RTR)u-(Rsab)ureally does not lead to a significant loss of energy:

ΔPu=0.5*ρ{Qu/[0,785*(Du/103)2*86400*α]}2

=0.5*1015*{74/[0,785*(12.4/1000)2*86400*0.8]}2=39926 PA=0,04 MPa,

where:

Du- equivalent diameter of bilateral fitting removable valve to reservoir Yu3equal to 12.4 mm;

α - expenditure ratio, equal to 0.8.

Thus, the water injection Yu3at constant factor pickupwould maintain the maximum possible level 74 m3/day.

Option 2 (Fact). The coefficient pickup for reservoir Yu3changed abruptly.

Due to the fact that at a pressure of more than 41 MPa coefficient of permeability of the reservoir Yu3increases from 5.8 to 12.9 m3/(day*MPa), so the injection of water it will be more than 74 m3/day. The increase of hydrostatic pressure up to a critical level (pressure opening microcracks) managed to provide for reducing the overall water consumption on other layers and, consequently, reduce friction losses in the string of pipe (item 2). That is, the smaller the total water consumption, the more the bottomhole pressure and the more likely it exceeds the critical value, leading to an increased ratio of pickup (potamoidea proposed alternate water injection into the reservoirs may be more advantageous than the joint or even dual injection water in all layers).

When you measure the actual water injection Yu3was 154 m3/day when downhole pressure 42.7 MPa, and the total water consumption amounted to 519 m3/day. When this pressure drop ΔPuremovable valve (POS) for reservoir Yu3he was insignificant in value:

ΔPu=0.5*1015*{154/[0,785*(12.4/1000)2*86400*0.8]}2=

=172919 PA=0.17 MPa.

After installation into the corresponding borehole camera (pos.7, 9 and 27) of the respective removable valves-regulators (pos.11, 13 and 29) annulus (annular) space filled with aggregate CA-320 degassed oil with a density of 850 kg/m3in a volume of 25 cubic metres. This is done to prevent corrosion of the production casing (item 1) and the tubing (item 2). The oil took the upper part of the annulus to a depth 2815 meters.

Downhole pressure at the depth of the reservoir Yu1first was 36.8 MPa, which could be controlled by the pressure in the annulus, equal to 12.2 MPa.

RzabU1=PZATn*g*Hn*10-6in*g*dHin*10-6=

=12.2+850*9.8*2815*10-6+1015*9.8*(2931-2815)*10-6=36.8 MPa.

After two months of work, the bottomhole pressure at the depth of the reservoir Yu1amounted to 35.7 MPa, mo who you can control the pressure in the annulus, equal to 11.1 MPa.

RzabU1=PZATn*g*Hn*10-6in*g*dHin*10-6=

=11.1+850*9.8*2815*10-6+1015*9.8*(2931-2815)*10-6=35.7 MPa.

When this pressure in the actuation zone stabilized at an acceptable level 34 MPa:

CLU1=PU1-QU1/CRCU1=35.7-120/69=34 MPa.

That is, the reservoir Yu1was injected into the specified operation.

On the reservoir Yu2preset mode was maintained thanks to the reliable operation of the encoder supports constant bottomhole pressure.

On the reservoir Yu3the mode of injection water through the removable double-sided nipple valve (with equivalent diameter of 12.4 mm) with non-return valve (to prevent overflow of water from the upper reservoir at the time of stop) was 154 m3/day. This equivalent diameter is determined by the formula:

where ΔP - pressure drop removable valve MPa.

The total water injection through the injection well and extraction of water by interacting producing wells decreased in comparison with the regime of joint water injection simultaneously in three layers at 376 m3day:

ΔQabout=ΔQU1+ΔQJ2+ΔQu=

=(120-334)+(245-494)+(154-67)=-376 m3/day.

Evaluation of the effectiveness of this techno is Ogii additional oil production by interacting producing wells was made in the following manner. For each of the reservoirs on the basis of a hydrodynamic model that is configured on actual statistical data were obtained according to the relationship change oil when you change the water injection Ton/adepending on the ratio of compensation of sampling formation fluids by pumping water. These relationshipsn/afor well under the current compensation coefficients for layers Yu1, S2and th3respectively, 0.05, 0.04 and 0.35.

Thus, redistribution (with partial reduction of flow rate) of the injected water between zones within a single borehole due to differential effects on layers (limit injection in leached layers and a more intense effect on less covered by water flooding layers) allowed to increase the current daily oil production ΔQngroup interactive production wells at 9.8 tons per day (at a late stage of development of the field is equivalent to new wells with an average production rate of oil):

ΔQn=(Cn/a)U1*ΔQU1+(n/a)J2*ΔQJ2+(n/a)u*ΔQu=

=0.05*(120-334)+0.04*(245-494)+0.35*(154-67)=

=-10.7-10+30.5=+9.8 tons/day.

1. The method of dual and sequential operation of multiple layers of a single injection wells, including descent in the UK is the azhina, at least one pipe string, with constant or variable diameter, with or without muffled by the end of the at least one lowered below the upper layer of the packer hydraulic and/or mechanical action, with or without disconnector columns, below and above which launched at least one landing site, a downhole camera or the nipple with a removable valve for flow through them working agent, respectively, in the lower and upper layers, landing packer and test it from below and/or above, when determining the minimum pressure testing pressure absorption of each layer, the injection of working agent from the mouth into the cavity of the pipe string at a given pressure, directing it at the top and/or bottom layers through the appropriate removable flaps in the landing sites, measured on the surface of the common flow of the working agent, wellhead pressure and/or temperature in the cavity of the pipe string and the annulus of the well, determine the bottomhole pressure of the upper reservoir, the pressure in the string of pipe and the annulus at a depth removable valve in a landing site above the packer, find the flow of the working agent, injected into the upper layer through a removable valve, proofread it out of the public and determine the flow of the working agent injected into the lower reservoir, compare actual expenditures working agent to place the s with project their values, moreover, when the difference of the change wellhead pressure and/or remove one or both layers of removable valves of landing sites by using rope techniques, determine and modify their characteristics and/or parameters, then re-install each removable valve in the appropriate landing site using rope techniques and continue pumping the working agent through them in the appropriate layers.

2. The method according to claim 1, characterized in that below the upper reservoir reveal several layers, and accordingly between lowered and set at the same time or successively several packers hydraulic and/or mechanical action, with or without disconnector columns, and when the crimping of each packer on the bottom and/or top to determine the minimum pressure absorption and/or permeability of each of the layers.

3. The method according to claim 1 or 2, characterized in that translated well on sequential injection and/or determine the acceleration of each of the layers, isolating one or more layers from the cavity of the pipe string by setting in the respective landing sites removable valve in the form of a hollow tube, ensure the injection of the working agent in a single layer in one or more different values of flow rate, measure and/or determine the appropriate pressure in the string of pipe, based on which the build dependency changes flow from pipe pressure at the depth of each layer.

4. The method according to claim 1 or 2, characterized in that measure and/or determine the pressure in the string of pipe at a depth of removable flaps in the landing sites for injection through them working agent in the reservoir, and then for each layer, respectively, determine the actual costs of the working agent from the dependence of the flow pipe from the pressure.

5. The method according to claim 1 or 2, characterized in that the change wellhead pressure in the string of pipe and measure the corresponding total costs for the well, and determine the costs for individual layers upon which to build according to changes of the flow through the borehole and expenses for the layers from the wellhead pressure, then ask wellhead pressure necessary to ensure injection regime of the flow through the borehole and expenditure for individual layers, regulate the mode of injection by changing the diameter of the mouth of the nozzle or wellhead fitting, or using wellhead pressure regulator after itself.

6. The method according to claim 1 or 2, characterized in that above the upper landing site or a lower packer in the well column pipe of relatively larger diameter to reduce pressure loss by friction during pumping of the working agent in the layers.

7. The method according to claim 1 or 2, characterized in that in the well above the upper reservoir lower packer mechanical and/or hydraulic action, with or without R is shedenhelm columns, above the landing site with a removable valve.

8. The method according to claim 1 or 2, characterized in that isolate one or more layers from the cavity of the pipe string by setting in the respective landing sites removable valve in the form of a hollow tube and provide an opening of only one layer, measured wellhead pressure or dynamic fluid level in the cavity of the pipe string after its stabilization and calculate the reservoir pressure of the corresponding layer.

9. The method according to claim 1 or 2, characterized in that the isolate at least one layer from the cavity of the pipe string when another or other layers by reducing wellhead pressure injection working agent to close in one or more landing sites removable valve with a relatively large opening pressure.

10. The method according to claim 1, characterized in that isolate the upper layer from the cavity of the pipe string, measured wellhead pressure or dynamic fluid level in the annulus after its stabilization, and then calculate the corresponding pressure upper reservoir and determine the ratio of his pickup.

11. The method according to claim 1 or 2, characterized in that the partially fill the annulus buffer inert atmosphere with a density less than the density of the working agent to exclude the possibility zamerzanii/or protect the casing from corrosion.

12. The method according to claim 1 or 2, characterized in that the string of pipe at a depth of reservoir equipped with two or more landing sites with a removable valve for increasing the flow of the working agent, injected into it.

13. The method according to claim 1 or 2, characterized in that equip the string of pipe above the upper layer of the packer mechanical action, while the packers are lowered into the borehole on one string of pipe in a single descent, with the upper packer set by creating him axial loads after planting and crimp on the tightness of the lower packer.

14. The method according to claim 1 or 2, characterized in that to maintain plant reliability by acid treatment of the reservoir is injected into the column pipe acid solution of a given concentration portions, alternating and washing her work agent.

15. The method according to claim 1 or 2, characterized in that the removable valve operates as a controller with one or two internal opposite interchangeable fittings with or without reverse spring-loaded nodes to provide one-way or the opposite flow direction, and/or gas-lift valve for regulating the pressure of the flow and/or pressure regulator to themselves or after, and/or differential pressure regulator for maintaining the flow rate and/or depth gauge, with or without a thermometer for measuring pressure and temperature before and/what if after themselves, and/or flow regulator with pressure gauge and/or pressure gauge with a bleed for measuring pressure while flow through him working environment or produced fluid, and/or flow meter, and/or cut and/or stabilizer and/or a hollow tube.

16. The method according to claim 1 or 2, characterized in that the planting sites with removable valves to pump installed at the site of perforation interval seams to eliminate the negative impact of the flow of injected through a removable valve operating agent on the production casing and/or improve the accuracy of measurement of the physical parameters of the reservoir with removable valve - depth measuring device.

17. The method according to claim 1 or 2, characterized in that the chosen and set opening pressure, a removable valve for each of the layers, then in the injection process, change the number of open reservoirs, which have pumped by discrete changes wellhead pressure by changing the diameter of the mouth of the nozzle or wellhead fitting, or using wellhead pressure regulator after itself.

18. The method according to claim 1 or 2, characterized in that to determine the depth of the packer, evaluating the share of participation in work well together dissected layers or separate perforated intervals of the formation based on the results of photocamera, thermometry, or by the Dean of the object multiple intervals of the formation in the presence of cross-flows between them, or pre-packer in turn is mounted above each perforation interval of the reservoir, determine the acceleration per unit of power, and, if the specific pickup later added interval of the reservoir close to the value of the previous interval or intervals, the packer is lifted and set on the next perforation interval and repeat the process of determining his pickup, if the interval with a specific response that is different from the previous one by more than the permissible value, then it is separated by a packer from the preceding for further exposure on each differential repression.

19. The method according to claim 1 or 2, characterized in that define and divide the packer saturated the area from the water-saturated part of the reservoir injection wells, the working agent is injected into water-saturated area, selecting the oil continuously or periodically from the oil-saturated part of the formation.

20. The method according to claim 11, characterized in that define the boundary of the buffer inert medium with the working agent in the annulus ultrasonic method, when the leakage and the rise of the interface above the specified level increase the volume of buffer inert environment in the annulus by periodic or continuous podcast is.

21. The method according to claim 1 or 2, characterized in that simultaneously with the injection of the working agent in one or more layers of injection wells learn and/or temporarily extract fluids from another or other layers with a temporary connection to the oil and gas.

22. The method according to claim 19, characterized in that before the injection of the working agent in the upper or lower oil reservoir of his master, producing formation fluids through the annular space or the string of pipe, at the same time, continuously or periodically pumped working agent in the lower or bottom separated layers through the string of pipe or the top of the reservoir through the annular space.

23. The method according to claim 1 or 2, characterized in that the master one or more layers of injection wells swabbing and/or creation of high depression on the formation and/or aeration of the liquid in the backwashing process well, and/or gas and/or pump and/or discharge of water - spouting, and if necessary to increase the acceleration of one or more layers of hydraulic fracturing and/or the bottomhole zone treatment acids, and/or solutions of surface-active substances, and/or use of thermal methods of bottomhole zone treatment.

24. The method according to claim 1 or 2, characterized in that the reservoir pressure for each of the layers is determined by restoring the managing pressure in a stopped hole or the minimum pressure at the beginning of the absorption layer, and the bottomhole pressure during injection of the working agent is determined by the underlying device is a pressure sensor that is installed in one of the landing sites associated with the current layer.

25. The method according to claim 1 or 2, characterized in that at several packers on a single string of pipe stress breakdown packers to extract them from the wells installed within 8-12 t by redistributing the number of prescribed shear screws one packer for all packers.



 

Same patents:

FIELD: oil and gas extractive industry.

SUBSTANCE: device has operation columns of upper and lower well zones, placed eccentrically one inside the other in upper zone of well, double airlift column, mounted in upper well zone, and double airlift column, connected to operation well of lower well zone, separation column, mounted coaxially to operation column of upper well zone, and cementation pipe. According to invention, in a well with significant power of non-productive zone it is equipped with additional separating column with cleaning channels for lowering drilling tool therein and drilling well to lower well zone with removal of drilling slurry by double airlift column of upper zone through cleaning channels. Additional separating column is combined coaxially with operation column of lower well zone and is rigidly fixed to separation column.

EFFECT: higher efficiency.

1 dwg, 3 cl

The invention relates to the field of the oil industry and can be used for watering operation of oil wells with multi-layer heterogeneous structure of the productive interval

The invention relates to the oil and gas industry

The invention relates to pumping units for separate operation of several reservoirs

The invention relates to borehole development and operation of multilayer deposits of hydrocarbons

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The invention relates to the oil industry, in particular to the wells, revealing when drilling several productive strata

The invention relates to the development of hydrocarbon fields, and in particular to methods of developing hydrocarbon resources, complicated by the presence of zones of different permeability rocks, and may find application in the development of gas condensate and gascondensate-oil fields

The downhole choke // 2162931
The invention relates to the oil and gas industry, in particular to the downhole equipment of oil and gas fields

FIELD: oil and gas extractive industry.

SUBSTANCE: device has operation columns of upper and lower well zones, placed eccentrically one inside the other in upper zone of well, double airlift column, mounted in upper well zone, and double airlift column, connected to operation well of lower well zone, separation column, mounted coaxially to operation column of upper well zone, and cementation pipe. According to invention, in a well with significant power of non-productive zone it is equipped with additional separating column with cleaning channels for lowering drilling tool therein and drilling well to lower well zone with removal of drilling slurry by double airlift column of upper zone through cleaning channels. Additional separating column is combined coaxially with operation column of lower well zone and is rigidly fixed to separation column.

EFFECT: higher efficiency.

1 dwg, 3 cl

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EFFECT: higher efficiency.

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EFFECT: simplified construction, higher efficiency, higher reliability.

2 dwg

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FIELD: oil field development, particularly to obtain oil from a multiple-zone well.

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1 ex, 2 dwg

FIELD: oil field development, particularly obtaining oil from a deposit by flooding.

SUBSTANCE: method involves drilling injection and production wells; injecting liquid in wells and extracting product. Wells are drilled along with local valleys and projections investigating. Natural formation water directions are assigned as water flow direction from projections to valleys. Then formation permeability anisotropies created by above flow are determined. Peripheral and line injection wells are located in correspondence with natural formation water flow direction, namely at outer oil-bearing contour from natural formation water flow entering side. Intracontour well rows are additionally arranged substantially transversally to natural formation water flow direction. Production wells are drilled substantially transversally to natural formation water flow direction.

EFFECT: increased oil output due to improved high-permeable formation injectivity and decreased number of injection wells.

1 ex, 2 dwg

FIELD: oil and gas industry, particularly downhole equipment to be installed in oil and gas reservoirs.

SUBSTANCE: device comprises hollow body with discharge channels threadedly connected to flow string. The body is provided with shell having orifices and pressure nut. Spring, valve and replaceable head are arranged in annular gap between the body and the shell. The spring is installed between upper and lower support washers. The valve is located between upper support washer and shell ledge. The replaceable head is secured to the shell by means of pressure nut. Sleeve with orifices is coaxially installed inside the body between body extensions so that the sleeve may be displaced by wire-line equipment tool to misalign or align sleeve and shell orifices with discharge body channels.

EFFECT: provision of fluid flow from underlying reservoir to overlaying one.

2 cl

FIELD: oil and gas production industry, particularly methods or apparatus for obtaining oil, gas, water and other materials from multizone wells.

SUBSTANCE: device comprises packer with flow blocking means formed as hollow body with orifices located over and under sealing member of the packer. Pipe is arranged inside the body so that the pipe is concentric to body axis. Lower pipe end is connected to the body, upper part thereof cooperates with annular bush over outer pipe surface. Annular bush may move in axial direction and is provided with annular sealing means and with shear pins, which fixes the bush inside the body. After pin cutting annular bush moves downwards and closes body orifices located over sealing packer member to cut-off flow leaving orifices below sealing packer member.

EFFECT: extended water-free oil well operation period, increased oil recovery and reduced oil production costs due to elimination of water lifting charges and prevention of well bore zone contamination.

4 dwg

FIELD: oil industry.

SUBSTANCE: method comprises setting the jet pump into the well. The housing of the pump is provided with the central nozzle, openings for inflow of fluid, and radial passages. The openings for inflow of fluid are shut off by means of valving members. The jet pump is mounted between the top and bottom oil-bearing beds.

EFFECT: enhanced efficiency.

2 dwg

FIELD: oil production, particularly to produce watered oil and produced water utilization.

SUBSTANCE: pumping plant comprises pumps, which may be serially installed in well and provided with inlet and outlet means, drives and packer. Packer may be located inside well between beds. One bed is filled with oil-water mixture, another bed, namely lower one, is adapted for water receiving. Plant comprises screw pumps with drives installed on surface and polished shaft with gasket to connect worm shaft of upper pump with that of lower one. Lower screw pump has inlet means with radial orifices to receive water phase separated from oil-water mixture, as well as with slots. Lower pump comprises case, which defines channel for water injection into lower bed via above channel and through slots made in inlet means of lower pump during the same auger shaft rotation.

EFFECT: increased efficiency due to surface-driven screw pump usage.

3 dwg

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