RU2344274C1 - Method of dual oil production from layers of one well with submersible pump set (versions) - Google Patents

Method of dual oil production from layers of one well with submersible pump set (versions) Download PDF

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RU2344274C1
RU2344274C1 RU2007114215/03A RU2007114215A RU2344274C1 RU 2344274 C1 RU2344274 C1 RU 2344274C1 RU 2007114215/03 A RU2007114215/03 A RU 2007114215/03A RU 2007114215 A RU2007114215 A RU 2007114215A RU 2344274 C1 RU2344274 C1 RU 2344274C1
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Russia
Prior art keywords
fluid
submersible pump
pump
packer
electric submersible
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RU2007114215/03A
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Russian (ru)
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RU2007114215A (en
Inventor
Махир Зафар Оглы Шарифов (RU)
Махир Зафар оглы Шарифов
Василий Александрович Леонов (RU)
Василий Александрович Леонов
Алексей Николаевич Соколов (RU)
Алексей Николаевич Соколов
Рашит Гилемович Сальманов (RU)
Рашит Гилемович Сальманов
Хубали Фатали оглы Азизов (RU)
Хубали Фатали оглы Азизов
Фатали Хубали оглы Азизов (RU)
Фатали Хубали оглы Азизов
Иль Васильевич Леонов (RU)
Илья Васильевич Леонов
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ООО НИИ "СибГеоТех"
ООО НТП "Нефтегазтехника"
Махир Зафар оглы Шарифов
Василий Александрович Леонов
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Priority to RU2007114215/03A priority Critical patent/RU2344274C1/en
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Abstract

FIELD: oil and gas industry.
SUBSTANCE: group of inventions is related to production of carbohydrates, and is intended for dual operation of at least two layers of single well equipped with submersible pump set and packer. Provides improvement of method efficiency. Substance of invention: according to one version, method includes lowering of packer installed between two layers in well concentrically to two columns of pipes - internal and external, as well as lowering of two artificial lifts. At that lower of them, for production of fluid from lower layer, is lowered on external column of pipes and is arranged as electro-submersible, comprising mainly pump with inlet module and submersible electric motor with power cable. According to invention, lower electro-submersible pump is selected with working parameters according to debit of lower layer. It is lowered in well below packer with cable lead and installed at the depth higher, lower or at the level of lower layer for fluid production from it along circular space created between two columns of pipes. Above electro-submersible pump, device of cross flow is installed, arranged with eccentric channels for lifting of lower layer fluid and cross channel with axial outlet for inflow of upper layer fluid. Upper artificial lift is selected with working parameters according to debit of upper layer. At that it is lowered separately into external column of pipes higher than the device of cross flow on internal column of pipes and is installed at the depth higher, lower or at the level of upper layer for fluid production from it along internal column of pipes. Upper artificial lift is equipped with either sealing jacket with cable lead or tailpiece, every of which has lower sealing hollow stem installed tightly in axial outlet of cross channel for separation of fluid flows of upper and lower layers. Electro-submersible pump and upper artificial lift are put into operation simultaneously or serially, or periodically for separate production of fluid from layers along different columns of pipes with the possibility of further account of their debits on the well surface. Other versions have differences depending on operation conditions and properties of produced carbohydrates.
EFFECT: improvement of method efficiency.
31 cl, 8 ex, 19 dwg

Description

The invention relates to technology and techniques for hydrocarbon production and is intended for simultaneous and separate operation (WEM) of at least two formations of one well equipped with a submersible pumping unit and a packer, without or with the possibility of isolation (lower or higher, or between operating layers) the leakage interval of the production string or one or more flooded and / or developed unexploited formations.
Known technology and a well installation for the separate operation of two horizons (A.P. Silash. Oil and gas production and transportation. Moscow, "Nedra", 1980, see Fig. 4.1-105, page 364), which includes the descent into the well at a pipe string of at least one packer located between two layers, a centrifugal electric pump and a sucker rod pump.
Known technology and a downhole installation for simultaneous separate and alternate operation of several layers in one well (RF patent for inventions No. 2262586, ЕВВ 43/12, 34/06, 2005, bull. No. 29), including descent into the well on a pipe string of a submersible pump installation and packer, without or with a disconnector, telescopic connection and downhole chambers with removable valves.
The known technology and pumping unit for simultaneous and separate operation of two layers in the well (RF patent for the invention 2291953, ЕВВ 43/14, F04B 47/00, bull. No. 2, 2007), containing a column of elevator pipes, cable, packer, liner and two separate pumps for pumping out the formation products, which are enclosed in the upper and lower shells, the pump for pumping out the products of the lower layer is electrically submersible, and the lower casing of the electric submersible pump is equipped with a cable sealing unit and communicates from below with the under-packer space through the shank, to The one above the packer is equipped with a bypass device that is able to provide hydraulic communication between the over-packer space of the well and its under-packer space through the liner when the pressure of the bypass device is reached in the well, while the output of the electric submersible pump is in communication with the upper casing, which is connected to the column of elevator pipes from above and is equipped with a side a channel, the upper pump being a rod pump, the rod string of which is hollow and hermetically connected to the plunger of the rod pump the reception of this pump via the side channel is communicated with the over-packer space.
These technologies and installations have a limited scope, in particular, they do not provide for the operation of formations of one well with two submersible electric centrifugal pump units, without or with the possibility of isolation (lower or higher, or between the exploited formations) of the leakage interval of the production string or one or more flooded and / or produced reservoirs, as well as the production of fluid from two reservoirs by one submersible centrifugal pump with the ability to turn off and on from the well surface about bottom (lower or upper) layer in the study of the parameters of another (respectively upper or lower) layer.
The aim of the invention is to increase the efficiency of technology for simultaneous-separate production (ORD) of fluid from at least two layers of one well, equipped with at least one submersible pump with or without a packer, with or without isolation (lower or higher, or between exploited formations) of an unpressurized interval or of one or more flooded and / or developed unexploitable formations.
The technological result in the implementation of the proposed method is achieved through research and regulation of the operating parameters of at least one layer.
The technical result during the completion of the completion of operations is achieved by equipping the well with downhole equipment, which allows to separately take into account the operating parameters of at least one formation, in particular, to measure the flow rate of oil, water and gas at one or several different bottomhole pressure values.
The ORD technology includes the descent into the well of one or concentrically two pipe columns, a packer located between two layers and two artificial elevators, the lower of which, designed to extract fluid from the lower layer, is lowered on the external pipe string and is made of electric submersible, consisting mainly of , from a pump with an input module and a submersible motor with a power cable.
The objective of the invention is achieved by the following solutions.
Option 1. Select the lower electric submersible pump with operating parameters in accordance with the flow rate of the lower formation, lower it into the well below the packer with the cable entry and place it at a depth above, below or at the level of the lower formation to extract fluid from it in the annular space formed between the two columned pipes. Above the electric submersible pump, a cross-flow device is installed, made with eccentric channels for raising (extracting, pumping, pumping, transporting, bypassing, inflowing) the fluid of the lower reservoir and a cross channel with an axial outlet for the inflow (flow) of the fluid of the upper reservoir. The upper artificial lift with operating parameters is selected in accordance with the flow rate of the upper formation, and it is lowered separately into the external pipe string above the cross flow device on the internal pipe string and placed at a depth higher, lower, or at the level of the upper formation to extract fluid from it through the internal string pipes. In turn, the upper artificial lift is equipped with either a sealing casing with a cable entry or a shank, each of which has a lower sealing hollow rod, which is sealed in the axial outlet of the cross channel to separate the fluid flows of the lower and upper reservoirs. Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a bypass channel with a check valve for bleeding free gas from under the packer, a gas separator located above the packer, an inkjet apparatus with a receiving chamber located under the packer, an additional sealing a casing with a cable entry for the lower electric submersible pump, changing the direction of the fluid flow of the lower reservoir, a silencing device located above and / or below the pack a meter, a measuring system, a centralizer, an additional packer located lower or higher, or between operating layers to isolate the leakage interval of the production string or one or more flooded and / or worked out layers, a column disconnector above the additional packer located below the layers, a borehole chamber with removable valve, blank plug, liquid level stabilizer or gas pressure regulator. For well operation, the (lower) electric submersible pump and the upper artificial lift are put into operation simultaneously or sequentially or periodically for separate production of fluid from the reservoirs for different pipe columns with the possibility of further accounting for their flow rates on the well surface.
As the top artificial lift use:
Either an electric submersible pump - a centrifugal or screw pump, or an electric diaphragm pump, is controlled by each of the submersible electric motors or through an individual power cable, each of which is connected to an individual or common control station on the surface, and each electric submersible pump is equipped with an immersion telemetry system for research formation parameters and regulation of its operation modes, and the (lower) electric submersible pump located under the packer is equipped with a gas dispersing stupa yum.
Or a sucker rod pump - plunger or screw.
Or a hydraulic drive pump - jet or hydraulic piston, or screw, or hydraulic rod, or hydroimpulse.
Either continuous or periodic gas lift (compressor, non-compressor, downhole, natural, fountain method as a type of natural gas lift).
Option 2. Select an electric submersible pump with operating parameters in accordance with the flow rate of the lower formation, lower it into the well below the packers with cable entry and place it at a depth above, below or at the level of the lower formation to extract fluid from it through the annular space formed between the pipe columns or pipe string and wellbore. The upper artificial lift with operating parameters is selected in accordance with the flow rate of the upper formation, and it is installed above the packers and above the upper formation to extract fluid from it through the pipe string. A cross-flow device is installed under the upper artificial elevator, made with eccentric channels for the inflow of the upper formation fluid and a cross channel with an axial inlet and a sealing shaft (located below the cross-flow device) for lifting (passing) the lower formation fluid. In this case, the lower submersible pump and the upper artificial lift are lowered into the well either simultaneously on one pipe string, or separately on two - external and internal - pipe columns, or the lower electric submersible pump with the upper artificial lift on one pipe string, and then outside it is lowered by a string of pipes of larger diameter to guide the annular space of the reservoir fluid of the lower reservoir. Moreover, the upper artificial elevator is equipped on the outside with either a sealing casing with a cable entry, consisting of one or several sections and connected to the pipe string or pump through an adapter or flange, or it is separately lowered into the external pipe string above the cross flow device on the internal pipe string. The pipe string between the packers is equipped with a circulation device (hole in the pipe or perforated pipe, or bypass valve) for the influx of formation fluid (upper formation). Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a bypass channel with a check valve for bleeding free gas from under the packer, a gas separator, a jet apparatus, a swivel, an additional casing for guiding the flow of the lower reservoir fluid, a device jamming, measuring system, centralizer, an additional packer to isolate the leakage interval of the production string or one or more flooded and / or yrabotannyh formations disconnector column over an additional packer located below the operating formations downhole valve chamber with a removable, hollow tube, the liquid level stabilizer or gas pressure regulator. An electric submersible pump and an overhead artificial lift are put into operation simultaneously or sequentially or periodically for separate production of fluid from the corresponding reservoirs along the annular space and the pipe string with the possibility of further accounting for their flow rates on the well surface.
As the top artificial lift use:
Either an electric submersible pump - a centrifugal or screw pump, or an electric diaphragm pump, is controlled by each of the submersible electric motors or through an individual power cable, each of which is connected to an individual or common control station on the surface, and each electric submersible pump is equipped with an immersion telemetry system for research formation parameters and regulation of its operation modes, and the (lower) electric submersible pump located under the packer is equipped with a gas dispersing stupa yum.
Or a sucker rod pump - plunger or screw.
Or a hydraulic drive pump - jet or hydraulic piston, or screw, or hydraulic rod, or hydroimpulse.
Either continuous or intermittent gas lift.
Option 3. Select an electric submersible pump with operating parameters in accordance with the flow rate of the lower reservoir, lower it into the well below or above the packer and place it at a depth above, below or at the level of the lower reservoir. Pump (lift, pump) with this pump the fluid of the lower reservoir to receive the upper artificial lift. For a controlled flow of fluid from the upper formation, an overflow valve is installed above the electric submersible pump (shutoff valve), which closes when the pressure drop set on it (pressure rise up to it or pressure decrease after it) or a spring-loaded or free valve located in the borehole chamber, or the channel of the bypass device, or in the cross channel of the cross-flow device, communicating the upper layer with the reception of the upper artificial lift. The upper artificial lift with the operating parameter is selected in accordance with the total flow rate of the upper and lower reservoirs, lower it above the valve for a controlled inflow of the upper reservoir and placed at a depth higher, lower, or at the level of the upper reservoir (for producing fluid simultaneously from the lower and upper reservoirs) . The upper artificial lift is lowered into the well with a sealing casing with a cable entry, consisting of one or several sections and connected to the pipe string or to the pump through an adapter or flange. Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a bypass channel with a check valve for bleeding free gas from under the packer, a cable entry for the packer, a gas separator located above the packer, an inkjet apparatus, a silencing device, a measuring device system, centralizer, swivel, additional casing for the lower electric submersible pump, additional packer to isolate the leakage interval of the production string or one or more flooded and / or worked-out formations, a column disconnector, an additional downhole chamber with a removable valve, a blank plug, a liquid level stabilizer, or a gas pressure regulator. The electric submersible pump (lower) is put into operation periodically both during the study of parameters and in the process of producing fluid only from the lower formation when cutting off the upper formation by closing the bypass or check valve with increasing pressure in the pipe string at its level, and the upper artificial lift is launched mainly for the simultaneous production of fluid from the upper and lower reservoirs with an open bypass or check valve.
As the top artificial lift use:
Either an electric submersible pump - a centrifugal or screw pump, or a diaphragm pump with an electric drive, while controlling each of the submersible electric motors either through an individual power cable, each of which is connected to an individual or common control station on the surface, or through one power cable with a minimum number of cores 3, by which electricity is supplied to two submersible motors in parallel or sequentially, simultaneously or alternately, each electric submersible pump being equipped with a system oh submersible telemetry for studying formation parameters and the adjustment of its operating modes, a (lower) submersible pump disposed below the packer, equipped with a gas dispersion steps.
Or a sucker rod pump - plunger or screw.
Or a hydraulic drive pump - jet or hydraulic piston, or screw, or hydraulic rod, or hydroimpulse.
Either continuous or intermittent gas lift.
The parameters of the lower reservoir are examined (oil, gas and water flow rates are measured) at various bottomhole pressures above the saturation pressure established by changing either the current frequency or the wellhead pressure, or the pressure on the outflow of the upper artificial lift, or the pressure on the outflow of the electric submersible pump.
Option 4. Select the (lower) electric submersible pump with operating parameters in accordance with the flow rate of the lower reservoir, lower it into the well below or above the packer on the pipe string and position it at a depth above, below or at the level of the lower reservoir to produce fluid from only one - lower layer. Above the electric submersible pump, a shut-off valve is installed (a regulator triggered by pipe or annular pressure or from a differential pressure on it) in the center of the pipe string above or below the packer or between two packers, or two downhole chambers or two bypass valves with a plug between them, are installed, blocking the pipe string for the passage (bypass, overflow) of the fluid of the lower reservoir, first through the lower from the pipe to the annular space, and then through the upper from the annular to the pipe space and then to receive hnego artificial lift. The upper artificial lift with the operating parameter is selected in accordance with the total flow rate of the upper and lower reservoirs, it is lowered above the cutoff valve and placed at a depth higher, lower, or at the level of the upper reservoir to extract fluid from the lower and upper reservoirs, and the control characteristics of the cutoff valve are selected from the possibility of how to close it when the lower submersible pump is turned off, for operation and research of the parameters of the upper layer, within the adjustment dependence of the upper artificial elevator, and its opening when you start the work of the (lower) electric submersible pump or when increasing the productivity of the upper artificial lift over its nominal mode. The upper artificial lift is lowered into the well with a sealing casing with a cable entry, consisting of one or several sections and connected to the pipe string or to the pump through an adapter or flange. Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a bypass channel with a check valve for bleeding free gas from under the packer, a cable entry for the packer, a gas separator, a jet apparatus, a casing for changing the direction of the formation fluid flow, jamming device, measuring system, centralizer, additional packer for isolating the leakage interval of the production string or one or more waterlogged and / Whether depleted formations disconnector column downhole valve chamber with a removable, hollow plug, stabilizer liquid level, the gas pressure regulator, the pressure regulator wellhead buffer or inverter frequency current, shut off valve control system. When the (lower) electric submersible and upper artificial lift is put into operation, fluid is extracted from the upper and lower seams with the shut-off valve open, and the lower electric submersible pump is shut off periodically both when examining the parameters and when the upper stratum is operated (only) with the shut-off valve closed.
As the top artificial lift use:
Either an electric submersible pump - a centrifugal or screw pump, or a diaphragm pump with an electric drive, while controlling each of the submersible electric motors either through an individual power cable, each of which is connected to an individual or common control station on the surface, or through one power cable with a minimum number of cores 3, in which electricity is supplied to two submersible electric motors in parallel or in series, simultaneously or alternately. Each electric submersible pump is equipped with a submersible telemetry system to study formation parameters and control its operating modes, and the (lower) electric submersible pump located under the packer is equipped with gas-dispersing steps.
Or a sucker rod pump - plunger or screw.
Or a hydraulic drive pump - jet or hydraulic piston, or screw, or hydraulic rod, or hydroimpulse.
Either continuous or intermittent gas lift.
Option 5. Select (lower) electric submersible pump with operating parameters in accordance with the flow rate of the lower reservoir, lower it into the well below or above the packer and placed at a depth above, below or at the level of the lower reservoir. Raise (pump) with the help of it (this electric submersible pump) the fluid of the lower layer to receive the upper artificial lift, which pass (pass) through one or more of the following devices (located above the lower electric submersible pump) - shutoff valve, actuated by differential pressure, electric valve shutoff, hydraulic actuator shutoff valve, bypass valve, valve (adjustable) in the borehole chamber (or in the cross-flow device). The upper artificial lift with the operating parameter is selected in accordance with the total flow rate of the upper and lower reservoirs (but with the ability to produce products of only the upper reservoir), lower it above the valve for a controlled inflow of the lower reservoir fluid and placed at a depth higher, lower, or at the level of the upper reservoir. Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a bypass channel with a check valve for bleeding free gas from under the packer, a cable entry for the packer, a gas separator located above the packer, an inkjet apparatus, and a silencing device, measuring system, centralizer, casing for the lower electric submersible pump, an additional packer to isolate the leakage interval of the production string or one or more their flooded and / or depleted formations, a column disconnector, an additional borehole chamber with a removable valve, a blind plug, a liquid level stabilizer or a gas pressure regulator, and the electric submersible pump and the upper artificial lift are put into operation simultaneously to extract fluid from the upper and lower layers when open a controlled valve installed between them, and when the electric submersible pump is turned off and the valve is closed, the formation fluid of the upper formation is produced by the upper artificial elevator.
Either an electric submersible pump is used as a top artificial lift - a centrifugal or screw pump, or an electric diaphragm pump, or a sucker rod pump - a plunger, screw, or hydraulic drive pump - a jet, hydraulic piston, screw, hydraulic rod, hydroimpulse, or gas lift - continuous, periodic.
One or more of the following elements is used as a valve for a flow shutoff valve (regulator): a spring-loaded check valve, a shut-off valve, a control valve, an automatic pressure regulator, a butterfly valve, a butterfly valve, a hydraulic bypass device that operates from a differential pressure, a hydraulic valve controlled by pressure impulse, hydraulic valve controlled from the surface of the well through impulse tubes, pneumatically actuated valve, electric valve eral actuator, solenoid valve, controlled via an individual cable or via the power cable. The adjusting characteristics of the shut-off valve are selected with the possibility of closing and shutting off the fluid flow from the lower reservoir with the lower electric submersible pump switched off within the regulatory dependence of the upper artificial lift and opening it when the lower electric submersible pump is started, and the adjusting characteristics of the lower electric submersible pump are selected with the possibility of maintaining bottom-hole pressure at lower layer at the value of the pressure of saturation of oil with gas.
Option 6. Select the lower electric submersible pump with operating parameters in accordance with the flow rate of the lower reservoir, lower it into the well below or above the packer on the pipe string and position it at a depth above, below or at the level of the lower reservoir. Above the electric submersible pump and packer, but below the upper layer, an additional packer is installed, forming a receiving chamber in the interpacker space for fluid accumulation. A cross-flow device made with eccentric channels for passing to the surface of the reservoir fluid (lower and upper, and if there is a middle layer) and with a cross channel equipped with a check valve and communicating cavities behind the pipe string above and below additional packer (upper layer with the reception of the upper artificial lift). The upper artificial lift with the operating parameters is selected in accordance with the total production rate of the strata (lower, upper and middle, if any), lower it below the cross flow device and placed between the packers. Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a bypass channel with a check valve for bleeding free gas from under the packer (lower or additional), cable entry for the packer (lower or additional), gas separator, jet apparatus, silencing device, measuring system (without or with flow meters), centralizer, column disconnector, borehole camera with removable valve, blind plug, level stabilizer gas or gas pressure regulator, flow meter. The lower electric submersible pump is put into operation periodically both during the study of the parameters and during the production of fluid from the lower reservoir when the upper reservoir is cut off by closing the check valve in the cross flow device with increasing pressure in the pipe string, and the upper artificial lift is launched while the fluid is being produced of all (upper and lower) formations with an open check valve.
As the top artificial lift use:
Either an electric submersible pump - a centrifugal or screw pump, or an electric diaphragm pump (in this case, control each of the submersible electric motors or through an individual power cable, each of which is connected to an individual or common control station on the surface, and each electric submersible pump is equipped with an immersion telemetry system for research formation parameters and regulation of its operation modes, and the lower electric submersible pump located under the packer is equipped with gas dispersing steps yami).
Or a sucker rod pump - plunger or screw.
Or a hydraulic drive pump - jet or hydraulic piston, or screw, or hydraulic rod, or hydroimpulse.
Either continuous or intermittent gas lift.
The technology of this method can also be used for the production of hard-to-recover fluids, for example viscous oil, and its implementation is possible without installing a packer between the layers from one or two concentric or eccentric pipe columns and two artificial elevators, the lower of which is lowered onto the pipe column and made submersible, consisting mainly of a pump with an input module and a submersible motor with a power cable.
The objective of the invention is achieved by the following solutions.
Option 7. Lower the lower electric submersible pump into the well below the reservoir with difficult to extract (viscous, complicating the extraction of the upper artificial lift) fluid, pump out (the upper artificial lift) ordinary (normal) fluid (non-viscous product), while ensuring the flow of difficult to remove fluid (viscous oil) into the pipe string (hoist) at a predetermined depth above the lower electric submersible pump, and after lifting (receiving) them to receive the upper artificial lift (additional upper submersible pump), disconnect the last one and the lower electric submersible pump is put into operation, displacing from the pipe string (elevator, tubing) to the surface difficult to extract fluid (viscous oil) with ordinary (non-viscous) fluid coming either in the form of associated water from the upper reservoir (with viscous oil), or in the form of an ordinary (inviscid, highly watery reservoir) fluid from a (other) downstream formation, while the cavity of the pipe string (elevator, tubing) is isolated from the formation with a hard-to-recover fluid (viscous oil) check valve (installed in the nipple or in the well Ina chamber). At the same time, the lower submersible pump and the upper artificial lift are lowered into the well simultaneously on one pipe string or separately on two - external (for the lower electric submersible pump) and internal - pipe columns (for the upper artificial lift). Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a packer, a device for switching the reception of the upper artificial lift from the external column to the annular space between the external and internal columns, a cross-flow device, a bypass channel with a non-return valve for bleeding free gas from the packer, a gas separator, a jet device, a casing for directing fluid flow, a silencing device, a measuring system d, a centralizer, an additional packer to isolate the leakage interval of the production string or one or more flooded and / or worked-out formations, a string disconnector above the additional packer located below the operated formations, a borehole chamber with a removable valve, a blind plug, a liquid level stabilizer or pressure regulator gas. Moreover, the lower electric submersible pump and the upper artificial elevator are put into operation alternately (with predetermined periods of their operation and shutdown).
As the top artificial lift use:
Either an electric submersible pump - a centrifugal or screw pump, or an electric diaphragm pump (in this case, control each of the submersible electric motors or through an individual power cable, each of which is connected to an individual or common control station on the surface, and each electric submersible pump is equipped with an immersion telemetry system for research formation parameters and regulation of its operation modes, and the lower electric submersible pump located under the packer is equipped with gas dispersing steps yami).
Or a sucker rod pump - plunger or screw.
Or a hydraulic drive pump - jet or hydraulic piston, or screw, or hydraulic rod, or hydroimpulse.
Or continuous, periodic gas lift.
Option 8. The electric submersible pump is lowered into the well below the reservoir with difficult to extract (viscous) fluid, one (first) of the columns is connected to the intake of the upper artificial lift and the ordinary (normal) fluid (inviscid production) is pumped out of it by the upper artificial lift, while ensuring flow hard-to-recover fluid (viscous oil) into this (first) column at a predetermined depth above the lower electric submersible pump, and after it is received by the upper artificial lift (additional electric submersible pump) they receive the last one from this (first) column and switch it to another (second) column, at the same time they connect the discharge of the lower electric submersible pump to the first column, displacing the hard-to-recover fluid (viscous oil) from it onto the surface with an ordinary (non-viscous) fluid, coming either in the form of associated water from a formation with hard-to-recover fluid (viscous oil), or in the form of an ordinary (inviscid formation) fluid from another downstream formation, or from the cavity of another (second) column used at that moment to accumulate Niya of hard-fluid. Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a packer, a device for switching the reception of the upper artificial lift from one column to another, a device for switching the reception of the lower electric submersible pump from one column to another pipe string, a device for switching discharge of the lower electric submersible pump from one column to another, with a cross-flow device, a bypass channel with a check valve for bleeding off free gas from under the packer, gas separator, jet apparatus, additional casing for directing fluid flow, silencing device, measuring system, centralizer, additional packer for isolating the leakage interval of the production string or one or more flooded and / or produced reservoirs, the disconnector of the column above an additional packer located below the operating formations, a borehole chamber with a removable valve, a blind plug, a liquid level stabilizer or regulator ION gas. Moreover, the lower electric submersible pump is either started periodically, as hard-to-recover fluid is accumulated in one of the pipe columns, or it is operated continuously, switching its flow from the first column to the second pipe string in turn with simultaneous switching (connection) of receiving the upper artificial lift and / or receiving the lower submersible pump, respectively, from the second column to the first. Then the process is repeated by alternately using pipe columns to accumulate hard-to-recover fluid and then displacing it with ordinary fluid (water, flooded products).
As the top artificial lift use:
Either an electric submersible pump - a centrifugal or screw pump, or a diaphragm pump with an electric drive, while controlling each of the submersible electric motors either through an individual power cable, each of which is connected to an individual or common control station on the surface, or through one power cable with a minimum number of cores 3, by which electricity is supplied to two submersible motors in parallel or sequentially, simultaneously or alternately, each electric submersible pump being equipped with a system oh submersible telemetry for studying formation parameters and the adjustment of its operating modes, and the lower electric submersible pump disposed below the packer, equipped with a gas dispersion steps.
Or a sucker rod pump - plunger or screw.
Or a hydraulic drive pump - jet or hydraulic piston, or screw, or hydraulic rod, or hydroimpulse.
Either continuous or intermittent gas lift.
Implementations of the ARD method, depending on the characteristics and parameters of the wells, can be carried out using the plants in different versions, shown in figures 1-16. Figure 1-4 shows the installation for separate production of fluid from the reservoirs for different pipe columns; figure 5 - installation for separate production of fluid from the reservoirs in the annulus and the pipe string; 6-10 - installation for the extraction of fluid from the reservoirs along one pipe string with an upper elevator having either a liner or a casing; 11-12 installation for the extraction of fluid from the reservoirs for one pipe string without a casing on the upper pump; on Fig - installation for the production of fluid from two reservoirs with a receiving storage chamber; on Fig - installation for the production of fluid from three reservoirs with a receiving storage chamber for one pipe string and without a casing; on Fig-16 - installation for the extraction of fluid from two layers, and from the top produce hard to extract - high viscosity fluid in two concentrically deflated pipe columns; on Fig.17-18 - installation for the production of fluid from two reservoirs, and from the top produce hard-to-extract - highly viscous fluid through two eccentrically deflated pipe columns with two submersible pumps; on Fig - installation for the extraction of fluid from two reservoirs, and from the top produce hard to extract - highly viscous fluid through two eccentrically deflated pipe columns with one lower electric submersible and two upper artificial elevators - submersible pumps.
ARD technology is implemented using the installation shown in figures 1-14, and includes the descent into the well of production casing 1 of one 2 or concentrically two 2 and 3 pipe columns of at least one packer 4 and an electric submersible pump (EPN), consisting mainly of a pump 5 with an input module 6 and a submersible motor 7 with a power cable 8. EPN also includes a hydraulic protection 9 and an immersion telemetry system 10.
The implementation of the ARD method is carried out in the following sequence.
For option 1 (see Figs. 1-4), lower electric submersible pump including pump 5 with input module 6, submersible electric motor (PEM) 7 is lowered on the outer pipe string 2 into the production casing 1 of the well to a depth below the packer 4 with cable entry 11 with power cable 8, hydroprotection 9 and telemetry system (TMS) 10. Select this pump (pos. 5-10) with operating parameters in accordance with the flow rate of the lower layer (hereinafter “Layer 1”) and place it at a depth higher, lower or at the level of the lower reservoir (“Plast 1”) for production from “Plast 1” fluid along the annular space formed between two pipe columns - external 2 and internal 3. Above the electric submersible pump, a cross-flow device 12 is installed, made with eccentric channels 13 for lifting (passing) the fluid of the lower layer “Plast 1” and the cross channel 14 with axial exit 15 for the inflow of fluid in the upper reservoir (hereinafter “Formation 2”). The upper (optional) artificial lift is selected — a submersible pump 16 (with power cable 17) with operating parameters selected in accordance with the flow rate of the upper layer (“Layer 2”), separately lowered into the outer pipe string 2 above the cross-flow device 12 on the inside pipe string 3 and is located at a depth above, below, or at the level of the top operating formation “Plast 2” for producing fluid from it through the inner pipe string 3. Upper - an additional submersible pump 16 is equipped with either a sealing casing 18 with cable gland house 19 (for example, see figure 1), or a shank 25 (for example, see figure 2), each of which has a lower sealing hollow rod 20, which is sealed in the axial outlet 15 of the cross channel 14 (without or with a check valve 28). This solution allows you to separate the fluid flows of the formations - "Plast 1" and "Plast 2".
Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a measuring system 10 for the lower electric submersible pump, an additional measuring system 10 for the upper artificial lift; a gas separator 22 located above the packer 4; an inkjet apparatus 21 located above the packer 4 with a receiving chamber 23 located below the packer 4 (for example, see FIG. 1); a bypass channel 26 or 27 with a check valve 28 for bleeding free gas from under the packer 4, an additional sealing casing 29 with a cable entry 30 for the lower electric submersible pump, changing the direction of fluid flow "Plast 1"; a silencing device 24 located above and / or below the packer 4; a borehole chamber 31 with a removable 32 valve or a blank plug, or a liquid level stabilizer, or a gas pressure regulator (for example, see figure 2); an additional top packer 33 with cable entry 34 located between the operated Plast 2 and Plast 1 reservoirs to isolate one or more (Insulated Stratum A, Insulated Stratum B) flooded and / or mined reservoirs with a bypass valve 35 , an additional lower packer 37, located deeper than the lower operating reservoir “Plast 1”, a liner 36, a disconnector of the column 38, a centralizer 39, a valve 40 that is activated by a differential pressure - opens when the pressure at the intake of the electric submersible pump decreases (for example, see Fig. 3), with an additional top packer 41 with a cable entry 42 located above the top operated “Plast 2” to isolate the leakage interval of the production string (“Leakage”) or one or more flooded or not put into development layers located above the upper exploited layer "Plast 2" (for example, see figure 4).
The lower electric submersible pump and the upper artificial lift (submersible pump) are put into operation simultaneously or sequentially or periodically for separate production of fluid from the reservoirs for different pipe columns 2 and 3 with the possibility of further accounting for their flow rates on the well surface.
When using an electric submersible pump as the top artificial lift, each of the submersible electric motors is controlled through an individual power cable 8 and 17, each of which is attached to an individual or common control station on the surface. Or they equip a submersible pump installation with one power cable 8 with a number of cores of at least 3, through which electricity is supplied to two submersible electric motors simultaneously and / or alternately. For quick measurement of fluid flow parameters, each electric submersible pump is equipped with a submersible telemetry system 10 for studying reservoir parameters and regulating its operation modes.
For option 2 (see Fig. 5), an electric submersible pump is selected (pos. 5-7) with operating parameters in accordance with the “Plast 1” flow rate, it is lowered into the production casing 1 of the well below packers 4 and 33 with cable entries 11 and 34 on the pipe string 3 and place it at a depth higher, lower, or at the level of the lower reservoir “Plast 1” to produce fluid from it in the annular space formed between the pipe string 3 and pipe string 2 or between pipe string 3 and production string (barrel wells) 1. Select the top artificial ift - an additional submersible pump 16 with operating parameters in accordance with the flow rate of only the top operating reservoir - “Plast 2”, install it above the packers 4, 33 and are located at a depth above the upper exploited reservoir “Plast 2” for producing fluid from it along the pipe string 3 or 2. Under the upper artificial lift (additional submersible pump) 16, a cross-flow device 43 (similar to an inverted device 12) is installed, made with eccentric channels 13 for the flow of fluid from “Plast 2” and cross m channel 14, made with an axial inlet 15 and a sealing shaft 44, on the inside of which pass (rise, pumping) of the fluid of the lower reservoir - "Plast 1", pumped by the lower electric submersible pump (5-10), bypassing the upper artificial lift 16. In this case, submersible pumps are lowered into the well in the first case simultaneously on one pipe string 2, in the second case separately on two pipes - external 2 (for the lower pump) and internal 3 (for the upper pump) - pipe columns. Moreover, in the first case, the (optional) upper submersible pump 16 is equipped on the outside with a sealing casing 18 with a cable entry 19. In this case, the casing consists of one or more sections connected to the pipe string 3 or to the pump 16 through an adapter or flange. The inner pipe string 3 is loosely hung with emphasis on the packer 4 and / or 33. After that, the external pipe string 2 of a larger diameter is lowered to a depth above the upper pump (in the vertical part of the well). In the second case, the upper submersible pump 16 is lowered separately into the outer pipe string 2 above the cross-flow device 43 on the inner pipe string 3. The pipe string 2 between the packers 4 and 33 is equipped with a circulating device 45 for fluid flow from the upper reservoir - “Plast 2” through eccentric channels 13 for receiving the upper submersible pump, and in the second case, the pipe string 3 above the packer 33 and above the casing 18 is also equipped with a similar additional circulation device 45 for directing the pumped fluid flow from the lower reservoir - " Plast 1 "in the annular space between columns 2 and 3.
Depending on the operating conditions of well 1, the submersible pump installation is additionally equipped with one or more of the elements - a bypass channel inside the liner 44 and a circulation device 45, a gas separator 21 or a jet device 22 for bypassing gas from under the packer 4 or 33, a silencing device 24, an additional a casing 29 for directing the fluid flow of the lower reservoir “Plast 1” without or with cable entry 30; measuring system 10; centralizer 39; an additional packer 37 for isolating the leakage interval of the production string or one or more flooded and / or depleted formations; a column disconnector 38 over an additional packer 37; downhole chamber 31 with a removable valve or a blank plug, or a stabilizer of the liquid level, or a gas pressure regulator 32.
The upper and lower submersible pumps are put into operation simultaneously or sequentially or periodically for separate production of fluid from the corresponding layers of the pipe string 3 and in the annular (annular space between 1 and 3) or annular (annular space between 2 and 3) space with the possibility of further separate accounting for their flow rates on the surface of the well. In the latter case, associated gas is discharged through the annulus between columns 1 and 2. They control each of the submersible electric motors through an individual power cable 8 and 17, each of which is connected to an individual or common control station on the surface. Or they equip a submersible pump installation with one power cable 8 with a number of cores of at least 3, through which electricity is supplied to two submersible electric motors simultaneously and / or alternately. Each electric submersible pump is equipped with a submersible telemetry system 10 to study the parameters of the reservoirs and regulate its operating modes.
For option 3 (see FIGS. 6 and 7), the lower electric submersible pump (pos. 5-10) is selected with the operating parameters in accordance with the flow rate of the lower reservoir being used - “Plast 1”, it is lowered into the production casing 1 of the well below or above the packer 4 on the pipe string 2 and is located at a depth higher, lower, or at the level of “Plast 1” for the production of fluid from the lower operating reservoir “Plast 1”. The lower layer fluid is pumped by the lower electric submersible pump to receive the upper artificial lift through the column 2. If the electric submersible pump is used as the upper artificial elevator, it is equipped with a casing connected to the lower end with the column 2 above the packer 4. Above the lower electric submersible pump and packer 4 for controlled ( adjustable) fluid flow into the column 2 from the upper reservoir “Plast 2” is installed one or more control devices: either the borehole chamber 46 with a spring-loaded spring with a free or open valve 47 (for example, see Fig. 6), or a bypass valve 35, which closes when the pipe pressure rises above the annular valve, or a cross-flow device 12 made with eccentric channels 13 for lifting (bypassing) the fluid from Plast 1 and a cross channel 14 with an axial outlet or a through axial channel 15, equipped with a seat 48 with a check valve 49 free or spring-loaded spring 50, adjustable nut 51 (for example, see Fig.7). This channel provides an adjustable fluid flow from “Plast 2” with the reception of the upper artificial lift - the submersible pump 16. At the same time, the upper - additional submersible pump 16 with the operating parameter is selected in accordance with the total flow rate of “Plast 1” and “Plast 2”, lower it is above the borehole chamber 46 or bypass valve 35, or cross-flow device 12 and is located at a depth higher, lower or at the level of “Plast 2” for simultaneous production of fluid from “Plast 1” and “Plast 2”.
For option 4 (see Figs. 8-10), an electric submersible pump is selected with operating parameters in accordance with the flow rate of the lower reservoir in use - “Plast 1”, lowered into the production casing 1 below or above the packer 4 on the pipe string 2 and placed at a depth above, below or at the level of "Plast 1" for the extraction of fluid from only one - the lower reservoir, and above the electric submersible pump, a shutoff valve is installed in the center of the pipe string 2.
In the first case (see Fig. 8), the shutoff valve can be made in the form of a plate (fungal type) 53, which is pressed against the seat 52 by means of a spring 54, the rigidity of which is regulated by the nut 55. In this case, the fluid of the lower layer passes through the through axial channel 57 the bypass device 56 only when the lower electric submersible pump is started, and the formation fluid of the upper formation freely enters the reception of the upper artificial lift (submersible pump) 16 through the L-shaped channel in the bypass device 56.
In the second case (see Fig. 9), the shutoff valve can be made in the form of a spring-loaded check valve (ball, fungal, disk) 59. The upper artificial lift is lowered into the well with a sealing casing 18 with a cable entry 19, consisting of one or several sections and connected to the pipe string 2 or to the pump 16 through an adapter or flange. For ease of connection of the casing 18 with the downstream column 2, the swivel 60 can be used during installation of the installation.
In the third case (see Fig. 10), the flow from the lower reservoir is controlled by two bypass valves 35 or two downhole chambers with valves and a plug 61 located between them. Moreover, these bypass valves (downhole chambers) are located on the pipe string above the packer 4 , but below the packer 33 (if any) and below the reception of the top artificial lift. In this case, the fluid from the upper exploited reservoir can be received by the upper artificial lift through a similar bypass valve or through holes in the pipe string 2 (through a perforated pipe).
Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - gas separator 21, cable entry 11 for packer 4, measuring system 10 (for example, see Fig. 8) or packer 4 without cable entry, column disconnector 38, an additional casing 29 with a cable entry 30 by one or more centralizers 39 (see Fig. 9); an additional downhole chamber 31 with a removable 32 blank plug, a valve, a liquid level stabilizer or a gas pressure regulator (see Figs. 8, 9, 10), an additional packer 33 with a cable entry 34, and bypass valves 35 that are activated by differential pressure (see figure 10).
Select the upper (optional) submersible pump 16 with an operating parameter in accordance with the total flow rate of the two operating formations - “Plast 1” and “Plast 2”, lower it above the shutoff valve 53 or 59 or bypass valves 35 and position them at a depth higher, lower or at the level of "Plast 2", and the adjusting characteristics of the shut-off valve (s) (bypass valves, valves installed in the borehole chambers) are selected with the possibility of closing it when the lower submersible pump is turned off, for operation and research parameters "Plast 2", within the regulatory dependence of the upper submersible pump, and its opening when you turn on the lower electric submersible pump or when increasing the performance of the upper submersible pump 16 over the nominal mode.
They also control each of the submersible motors through an individual power cable 8 and 17, each of which is attached to an individual or common control station on the surface. Or they equip a submersible pump installation with one power cable 8 with a number of cores of at least 3, through which electricity is supplied to two submersible electric motors simultaneously and / or alternately. Each electric submersible pump is equipped with a submersible telemetry system 10 to study the parameters of the reservoirs and regulate its operating modes.
By combining options 3 and 4 (for example, see Fig. 9), the adjustment characteristics of the submersible pump unit can be further expanded. In this case (see Fig. 9), the installation of a spring-loaded check valve 59 in the center of the pipes 2 allows you to adjust the flow from the lower reservoir - “Plast 1”, and the installation of the valve 47 to the downhole chamber 46 allows you to adjust the fluid flow from the upper reservoir— “Plast 2 ".
For option 5 (see Figs. 11-12), a lower electric submersible pump (pos. 5-10) is selected with operating parameters in accordance with the flow rate of the lower formation, lowered into the production casing 1 of the well below or above the packer 4 and placed at a depth above , lower or at the level of the lower exploited layer "Plast 1". With the help of pump 5, the fluid of the lower layer is raised (received) by the intake of the upper artificial lift 16. Moreover, it (fluid) passes through the pipe string 2 through the through channel 63 in the bypass device 62 and then through the bypass valve 35 or through the valve 47 in the well chamber 46, triggered by a differential pressure, with the bypass fluid of the lower reservoir from the pipe string 2 into the annulus. In this case, the associated gas accumulated under the packer 4 is passed through the bypass device 62 through the U-shaped channels 64 with a spring-loaded shutter 65 (see Fig. 11).
In the second case, the fluid of the lower reservoir passes through the valve shutoff valve 59, which is activated by a differential pressure, with the bypass fluid from the pipe string 2 into the annulus through the perforated pipe 66 (hole in the pipe string 2).
In the third case, the pass of the lower reservoir fluid is controlled through an electric actuator valve shut-off valve 67, which is driven either by an individual electric motor through a separate cable 68 (lowered to it from the surface) or driven by the energy of a submersible electric motor of the upper electric submersible pump (for example, an additional solenoid drive).
In the fourth case, the pass of the lower formation fluid is controlled through a hydraulic valve shutoff valve 69, which is driven from the surface through the impulse tube 70 (see Fig. 12).
The upper artificial lift 16 with the operating parameter is selected in accordance with the total flow rate of the upper and lower layers. It is lowered (upper pump) 16 above the valve for a controlled inflow of the lower formation and is placed at a depth higher, lower, or at the level of the upper formation.
Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a bypass channel with a check valve for bleeding free gas from under the packer, a cable entry for the packer, a gas separator 21 located above the packer 4, an inkjet apparatus 22, and a device jamming 24, measuring system 10, centralizer 39, casing 29 for the lower electric submersible pump, an additional packer 37 or 41 to isolate the leakage interval of the production string or Nogo or more watered and / or depleted formations column disconnector 38, an additional hole or chamber 31, 46 with a removable flap 32 or 47, hollow stopper 32, the liquid level regulator 32 and gas pressure regulator 32, filter 71.
The lower electric submersible pump 5 and the upper artificial lift 16 are put into operation simultaneously to produce fluid from the upper “Plast 2” and lower “Plast 1” formations with an open valve 35, 47, 59, 67, 69 installed between them. To study “Plast 2” and produce reservoir fluid only from the upper layer “Plast 2”, the electric motor 7 is turned off, stopping the lower electric submersible pump 5, while valves 35, 47, 59, 67, 69 are closed and shut off the flow from the lower layer “Plast 1 ". Valves 67, 69 can be used for short-term shutdown of fluid from the lower "Plast 1" when the lower electric submersible pump is in the "closed gate" mode. In this case, the performance of the upper submersible pump should vary in the range from the maximum flow rate of "Plast 1" + "Plast 2" to the minimum flow rate of only "Plast 2". And the adjusting characteristics of valves 35, 47, 59 should be selected so that they open when the lower electric submersible pump starts and close when it stops.
One or more of the following elements can be used as a flow shutoff valve: a spring-loaded check valve 59, a shut-off valve, a control valve, an automatic pressure regulator, a butterfly valve, a butterfly valve, a hydraulic bypass valve 35, which operates from a differential pressure, hydraulic pressure-controlled valve, hydraulic valve 69, controlled from the surface of the well through an impulse pipe 70, pneumatically actuated valve, valves n 67 with electric drive, solenoid valve controlled via individual cable 68 or via power cable. Moreover, the adjusting characteristics of the shutoff valve are selected with the possibility of closing and shutting off the fluid flow from the lower reservoir with the lower electric submersible pump switched off within the control dependence of the upper artificial lift and opening when the lower electric submersible pump is started.
When using an electric submersible pump as the top artificial lift, each of the submersible electric motors is controlled through an individual power cable 8 and 17, each of which is connected to an individual or common control station on the surface, or one submersible pump installation is equipped with one power cable 8 with at least 3 cores , which produce electricity to two submersible electric motors simultaneously and / or alternately. For quick measurement of fluid flow parameters, each electric submersible pump is equipped with a submersible telemetry system 10 for studying reservoir parameters and regulating its operation modes.
For option 6 (see FIGS. 13 and 14), a lower electric submersible pump (pos. 5-10) is selected with operating parameters in accordance with the flow rate of the lower reservoir “Plast 1”. It is lowered into the production casing 1 of the well below or above the packer 4 on the pipe string 2 and placed at a depth above, below or at the level of the lower formation “Plast 1” for the production of fluid from it. An additional packer 41 with a cable entry 42 is installed above the electric submersible pump 5 and packer 4, receiving the upper artificial lift, but below the upper layer ("Plast 2" in Fig. 13 or "Plast 3" in Fig. 14), thereby forming an interpacker the space (above packer 4 and below packer 41) a receiving chamber for accumulating formation fluid. A bypass device is placed above or inside the optional packer 41. In the first case (see Fig. 13), a cross-flow device 72 made with eccentric channels 73 for passing all exploited reservoirs (lower and upper reservoirs, and in the presence of a middle one) to the fluid surface, and with a cross U-shaped channel 74, equipped with a non-return valve 75, a spring-loaded spring 76. In the second case (see Fig. 14), the bypass device 82 is made with an axial through channel 83 for letting all exploited reservoirs (lower and upper reservoirs, and if there is a middle one) onto the fluid surface, and with p-image th channel 84, equipped with an annular elastic sealing membrane (elastic member) 85.
This bypass channel 74, 84 communicates the cavity behind the pipe string above and below the additional packer 41 when creating pressure under the packer 41 less than above it. Conversely, the upper layer divides above the packer 41 and the reception of the upper artificial lift 16 when creating pressure under the packer 41 is greater than above it.
The upper artificial lift 16 is selected — an additional submersible pump with an operating parameter in accordance with the total flow rate of the exploited reservoirs “Plast 1” and “Plast 2” in FIG. 13 or “Plast 1” + “Plast 2” + “Plast 3” in FIG. fourteen. It is lowered below the bypass device 72, 82 and placed between the packers 4 and 41, and in turn, a bypass device 23 is installed between the additional submersible pump 16 and the lower packer 4.
Depending on the operating conditions of the well 1, the submersible pump installation is additionally equipped with one or more of the elements shown in options 1-4 of the method, namely, the bypass channel 27 with the check valve 28 (for example, see Fig. 11) for bleeding free gas from under packer 4; cable entry 11 for packer 4, gas separator 21 or jet apparatus 22, or silencing device 24 (see Fig.6, 7); measuring system 10, centralizer 39 (see Fig.9); an additional packer 33 or 37, or 40 (for example, see Figs. 3, 4 of embodiment 1) to isolate the leakage interval of the production string or one or more flooded and / or worked out formations; column disconnector 38 (see FIG. 9); a borehole chamber 31 with a removable blind plug 32, a valve, a liquid level stabilizer or a gas pressure regulator.
The lower electric submersible pump is put into operation periodically both during the study of the parameters and during the production of fluid from “Plast 1” when cutting off the upper reservoir (“Plast 2” in Fig. 13 or “Plast 3” in Fig. 14) by closing non-return valve 75 in the cross-flow device 72 (see Fig. 13) or the sealing elastic element 85 (see Fig. 14) with an increase in pipe pressure, and the upper - additional submersible pump 16 is started while the fluid is extracted from all of the exploited reservoirs "Plast 1 "and" Plast 2 "on f ig. 13 or “Plast 1” and “Plast 2” and “Plast 3” in Fig. 14 with the non-return valve 75, 85 open.
Accounting for products from each layer can be ensured using additional flow meters 77, 78, 79, 80, 81, respectively installed:
77 - under the lower electric submersible pump 5-10 (see Fig.13 and 14);
78 - above the lower electric submersible pump 5-10 inside the pipe string 2 (see Fig. 13);
79 - above the upper artificial lift 16 inside the pipe string 2 (see Fig. 13);
80 - under the upper artificial lift 16 outside the pipe string 2 (see Fig. 14);
81 - above the upper artificial lift 16 outside the pipe string 2 (see Fig. 14).
To increase the accuracy of the measurement, one or more flow meters can be equipped with special devices 81 for guiding the formation fluid and not tightly shutting off its flow (for example, using elastic cuffs).
In addition, one or more flow meters are combined with a measuring device for recording one or more parameters - pressure, temperature, water cut and gas content.
For example (see Fig. 14), the flow rate of the lower reservoir “Plast 1” is determined by the flowmeter 77, the flow rate of the middle reservoir of the reservoir “Plast 2” is determined by the difference in readings by the flow meter 81 and 77, the flow rate of the upper reservoir by the reservoir “Plast 2” is determined by the flow meter 80. When their sum is checked and corrected by the readings of surface measuring devices.
For option 7 (see FIGS. 15 and 16), pipe columns 2 and two artificial elevators 5-10 and 16 are lowered into the well, the lower of which is electrically submersible, consisting mainly of pump 5 with an input module 6 and a submersible motor 7 with a power cable 8, hydroprotection 9 and a telemetry system 10. Lower the lower electric submersible pump (5-10) into the well below the reservoir with hard-to-recover fluid “Plast 2”, pump the usual fluid with an upper artificial lift 16, while ensuring the flow of hard-to-reach fluid from “ Layer 2 "into the pipe string 2 at the Anna depth above the lower electrical submersible pump (5-10). After lifting it (hard-to-recover fluid) to receive the upper artificial lift 16, turn off the last one (16) and start the lower electric submersible pump (5-10), displacing the hard-to-recover fluid from the pipe string 2 to the surface with ordinary fluid, either in the form of associated fluid water from the upper exploited reservoir - “Plast 2”, or in the form of a conventional fluid from the downstream exploited reservoir “Plast 1”. In this case, the cavity of the pipe string is isolated from the formation with a difficult-to-recover fluid check valve 28. In the first case, the lower electric submersible pump and the upper artificial lift are lowered into the well simultaneously on one pipe string 2 (see Fig. 16). In the second case, the upper artificial lift 16 is lowered separately on the additional external pipe string 3 (see Fig. 15). Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - a packer 4 with a cable entry 11, a casing for directing the fluid flow 29 without or with a cable entry 30, a silencing device 24, an overflow channel 26 or 27 with a check valve 28 for bleeding free gas from under the packer 4, gas separator 21, inkjet apparatus 22, measuring system 10, centralizer 39, additional packer 33, 37, 41 to isolate the leakage interval of the production string or one or more flooded and / or worked-out formations, a column disconnector 38 above an additional packer 37 located below the operated formations, a borehole chamber 31 with a removable valve 32, a blind plug 32, a liquid level stabilizer 32 or a gas pressure regulator 32, a cross-flow device 12 s eccentric channels 13 for passing fluid pumped by the lower electric submersible pump and a cross channel 14 for inflowing difficult-to-recover fluid (high-viscosity oil) into the pipe string (see 15), a device 87 for inflowing hard-to-recover fluid from the upper formation into the pipe string 2 (such a device may be a bypass valve 35, a borehole chamber 46 with a valve 47, an electric actuator 67, and a hydraulic actuator 69 valve), a device for switching reception of the upper artificial elevator from the outer column to the annular space between the outer and inner column 88.
When producing hard-to-recover fluids, the lower electric submersible pump (5-10) and the upper artificial lift 16 are put into operation alternately. To accumulate the formation fluid in the pipe string 2, the usual fluid (high-water oil) is pumped out by the upper elevator 16, and after its accumulation, the lower electric submersible pump 5-10 is switched on to expel the hard-to-recover fluid onto the day surface with ordinary fluid (for example, high-water-cut products of the lower produced reservoir )
As the top artificial lift 16 use:
- either an electric submersible pump, for example a centrifugal or screw pump, or an electric diaphragm pump;
- either a sucker rod pump, for example a plunger or screw pump;
- either a hydraulic drive pump, for example, a jet or hydraulic piston, or screw, or hydraulic rod, or hydroimpulse, while the working agent is fed through a device 88 (for example, a jet device).
- or gas lift — continuous, periodic, while the working agent is supplied through device 88 (for example, start-up couplings, downhole chamber 31 with gas lift valve 32).
For option 8 (see FIGS. 17-19), two either concentric (external 2 and internal 3) see FIG. 17, or eccentric 2,3 columns of pipes, see FIG. 18 and two artificial elevators (5- 10) and 16, the lower of which (5-10) is lowered on the pipe string 2 and is made electric submersible, consisting mainly of a pump 5 of the input module 6 and a submersible electric motor 7 with a power cable 8, hydroprotection 9, telemetry system 10. The electric submersible pump (5-10) is lowered into the well below the reservoir “Plast 2” with hard-to-recover (for example, highly viscous) fluid.
In the first case (see Fig. 17), with concentric deflated columns, annular space between external 2 and internal column 3 is connected with the help of device 90 to receive the upper artificial lift 16 and the usual fluid is extracted from this receiving chamber in the annular space, while simultaneously providing the entry of hard-to-recover fluid into this space at a predetermined depth above the lower electric submersible pump (5-10) through the receiving and distributing device 87, and after it (hard-to-recover fluid) is received artificial lift 16, disconnect the reception of the last 16 using the device 90 from the annular space between the inner 3 and outer 2 columns and switch it 16 (top artificial lift) to the inner column 3. At the same time, connect the annular space between the inner 3 and outer 2 columns with the discharge of the lower electric submersible pump (5-10) using the device 89 (a device for switching the discharge of the lower electric submersible pump from the annular space to the inner pipe string), displacing from the ring the space between the inner 3 and outer 2 columns to the surface is difficult to extract fluid with ordinary fluid coming either in the form of associated water from the reservoir - “Plast 2” with hard-to-recover fluid, or in the form of a regular fluid from the downstream reservoir - “Plast 1”, or from another cavity pipe string 3, which is used at this moment to accumulate hard-to-recover fluid using a switching device 91. Then the process is repeated - the hard-to-remove fluid is displaced from the inner string by a conventional fluid, and in the annular space hard-to-recover fluid accumulates.
In the second case (see Fig. 18), when the columns are eccentrically deflated, for example, from the left eccentric column 3, ordinary fluid is pumped out with an upper artificial elevator 16, while ensuring the entry of hard-to-recover fluid into this column 3 at a predetermined depth above the lower electric submersible pump through an overflow valve 35. After receiving it (hard-to-recover fluid) at the reception of the upper artificial lift 16, the reception of the latter from this column 3 is turned off and it is switched to another (right) column 2 using a switching device 9 3. At the same time, the lower electric submersible pump (5-10) is connected to the first column 3 by means of a switching device 91, displacing the column 3 from the surface of the hard-to-recover fluid with ordinary fluid coming either in the form of associated water from the reservoir with hard-to-recover fluid - “Formation 2”, either in the form of a conventional fluid from an underlying formation - “Formation 1”, or from the cavity of another pipe string 2, which is used at that moment to accumulate hard-to-recover fluid that opens by the bypass valve 35.
Then the process is repeated - hard-to-recover fluid is displaced from the right column 2 by the usual fluid, and hard-to-recover fluid is accumulated in the left-hand column 3.
To separate the upper and lower exploited formations, a packer 94 with a cable entry 95 for the cable and with a pipe 96 and a valve 97 for venting associated gas can be used.
In the third case (see Fig. 19), in contrast to the second case (see Fig. 18), two upper artificial elevators 16 are used, each of which is installed on its (individual) pipe string. The first of them, for example, on the left eccentric column 3 pumps out ordinary fluid, while ensuring the entry of difficult to extract fluid into this column 3 at a predetermined depth above the lower electric submersible pump through the bypass valve 35. After it (difficult to remove fluid) arrives at the reception of the upper artificial lift 16 turn it off and turn on the second artificial lift 16 on the right eccentric pipe string. At the same time, the discharge of the lower electric submersible pump (5-10) is connected to the first column 3 by means of a switching device 91, displacing the column 3 from the surface of the fluid that is difficult to recover with the usual fluid coming either in the form of associated water from the reservoir with hard to recover fluid - " Formation 2 ", either in the form of a conventional fluid from the underlying formation -" Formation 1 ", or from the cavity of another pipe string 2, used at this moment to accumulate hard-to-recover fluid that opens with the bypass valve 35.
Then the process is repeated - hard-to-recover fluid is displaced from the right column 2 by the usual fluid, and hard-to-recover fluid is accumulated in the left-hand column 3.
Depending on the operating conditions of the well, the submersible pump installation is additionally equipped with one or more of the elements - packer 4, device 91 for switching the intake of the lower electric submersible pump from one column to another, cross-flow device, bypass channel 26 or 27 with non-return valve 28 for bleeding free gas from under the packer 4, a gas separator 21, an inkjet apparatus 22, a casing for directing fluid flow 29, a silencing device 24, a measuring system 10, a centralizer 39, additional a packer 33, 37, 41 to isolate the leakage interval of the production string or one or more flooded and / or worked-out formations, the casing disconnector 38 above the additional packer 37 located below the formations used, the borehole chamber 31 with a removable valve 32, blind plug 32, a stabilizer fluid level 32 or gas pressure regulator 32.
The lower electric submersible pump is either started periodically, as hard-to-recover fluid pipes accumulate in the pipe string, or it is operated continuously, switching its flow from the first column to the second one at a time with simultaneous switching (connection) of receiving the upper artificial lift 16 and / or receiving the lower electric submersible pump (5 -10), respectively, from the second column to the first.
The following are specific examples of the use of the proposed installation in oil production using two ESPs for two layers.
Option 1. In well No. 1111 with a production string of 178 mm, only one lower layer was initially operated.
The lower layer had the following characteristics: depth 3,500 meters; reservoir pressure in the selection zone of 35 MPa; productivity coefficient 10 m3 / day / MPa; the water content of 0.9. The parameters of the technological regime of the lower reservoir at a design bottomhole pressure of 16 MPa — fluid production with the use of ECM 5-200-2400 was 190 m3 / day; oil 19 m3 / day.
It was decided to apply the proposed method - to open an additional upper layer for separate operation of the lower and upper layers.
The upper layer had the following characteristics: depth of 2400 meters; reservoir pressure in the selection zone 24 MPa; productivity coefficient 5 m3 / day / MPa; water cut 0.1. The parameters of the technological regime of the upper reservoir at a design bottomhole pressure of 8 MPa — liquid production using the upper additional electric submersible pump ETSNM 5-80-1600 was 80 m3 / day; oil 72 m3 / day.
To implement the method, 178 mm (with an inner diameter of 164 mm) were lowered into the production casing: an external pipe string: in the lower part, 73 mm; and in its upper part, above the cross-flow device, the production casing is 140 mm in diameter (with an internal diameter of 121.3 mm, with an external diameter of 149 mm).
Below the packer 2-PIM-KV-NSh-150 with cable entry was lowered above the lower layer to a depth of 2800 meters ETsNM 5-200-2400 with a telemetry system SPT 1. Above the electric submersible pump and above the upper layer to a depth of 2100 meters, a cross flow device UPS for the inflow of fluid in the upper reservoir to the reception of the upper electric submersible pump located directly above this device. In turn, the intake of the upper electric submersible pump was isolated from the annular (annular) space with a hermetic casing made with a cable entry connected to its lower end with a cross-flow device.
The lower electric submersible pump ETsNM 5-200-2400 and the upper electric submersible pump ETsNM 5-80-1600 can be operated simultaneously or sequentially or periodically for separate production of fluid from the reservoirs for different pipe columns with the possibility of further accounting for their flow rates on the well surface. The fluids of the lower reservoir are recovered through an annular space formed between two column pipes of the outer 140 and inner 73 mm (with the outer diameter of the couplings 89).
At the same time, each of the submersible motors is controlled through an individual power cable, each of which is attached to a common control station on the surface.
In this case, the parameters of the technological regime from the total production of reservoir fluid in the lower and upper reservoirs simultaneously amounted to 270 (190 + 80) m3 / day; oil 91 (19 + 72) m3 / day. That is, oil production increased by more than 4 times.
Option 2. In well No. 2222, the characteristics of the formations and their modes are the same as for well No. 1111, but well No. 2222 with a production string of 168 mm and therefore, due to the small size, the solution according to option 1 for two electric submersible pumps is not acceptable for it . It would be possible to lower another submersible pump (for example, UShGN) as the top artificial lift. But in the application only examples with two ESPs are considered.
To implement the method, an external pipe string was lowered into an production casing 178 mm (with an inner diameter of 164 mm): in the lower part above the lower layer, an ETSNM 5-200-2400 with a telemetry system SPT 1 was lowered to a depth of 2800 meters on a casing 73 mm in diameter parts of the pipe string — above the cross-flow device — lowered the production string with a diameter of 127 mm (with an inner diameter of 108.6 mm and an outer diameter of 141 mm) by connecting it to the casing of the upper electric submersible pump ЭЦНМ 5-80-1600, located at a depth of 2100 meters, insulating its reception from the annular (annular) space with a hermetic casing made with a cable entry. Above the upper packer and above the upper formation to a depth of 2100 meters, a cross-flow device was installed for the influx of fluid from the upper formation to the intake of the upper electric submersible pump located directly above this device. The upper part of the tubing string above the upper electric submersible pump had a diameter of 60 mm. After the landing of two 2-PIM-KV-NSh-150 packers with cable entry above and below the upper exploited formation, it was left in the free position and after that they started lowering the outer pipe string 114 mm with an inner diameter of 100 mm to the depth of the upper vertical part of the well - at 800 meters.
The lower electric submersible pump ETsNM 5-200-2400 and the upper electric submersible pump ETsNM 5-80-1600 can be operated simultaneously or sequentially or periodically for separate production of fluid from the reservoirs for different pipe columns with the possibility of further accounting for their flow rates on the well surface. The fluid of the lower reservoir was extracted through the annular space formed between the two columns of pipes of outer 114 and inner 60 mm (with the outer diameter of couplings 78), and associated gas was extracted through the annulus (between the production string and 114 mm string).
Option 3. Well No. 3333, identical to Well No. 2222.
To implement the method according to option 3, an overflow valve was triggered to open a fluid inflow from the upper reservoir above the lower electric submersible pump ЭЦНМ 5-200-2400 and above the packer directly under the intake of the upper electric submersible pump ЭЦНМ 5-250-2400 to a depth of 2700 meters when the pressure in the annulus exceeds the pressure in the pipe string for simultaneous production of fluid from the upper and lower reservoirs with the open bypass valve. To study the parameters of the lower reservoir, the lower pump ЭЦНМ 5-200-2400 was launched, while the pressure in the pipe string was increased, and the bypass valve was closed, cutting off the fluid flow from the upper reservoir.
Option 4. Well No. 4444 is identical to well No. 3333.
To implement the method according to option 4, a spring-loaded check valve was installed in it above the lower electric submersible pump and installed directly in the center of the column, which triggered to open when the pressure drop above and above the valve was exceeded by 16 MPa at the time the lower electric submersible pump was started for bypass through it reservoir fluid of the lower reservoir.
Option 5. In well No. 5555 with a production string of 146 mm, only one upper layer was initially operated. It had the following characteristics: depth 2500 meters; reservoir pressure in the selection zone 25 MPa; productivity coefficient 8 m3 / day / MPa; the water content of 0.9. The parameters of the technological regime of the upper reservoir at a design bottomhole pressure of 8 MPa — liquid production using the upper electric submersible pump ETSNM 5-160-1600 was 153 m3 / day; oil 15 m3 / day.
It is impossible to implement option 1 at this well due to the restriction on the external dimensions of the production string for an electric submersible installation with a casing. Therefore, it was decided to use two electric submersible pumps without a casing, that is, apply the proposed method according to option 5.
Pre-opened additionally the lower layer with the following characteristics: depth 3,500 meters; reservoir pressure in the selection zone of 35 MPa; productivity coefficient 3 m3 / day / MPa; water cut 0.1.
To implement the method, they lowered 146 mm into the production casing on a tubing string 73 mm below the packer 2-PIM-KV-NSh-122 with cable entry and above the lower layer to a depth of 2400 meters, ЭЦНМ 5-50-2400 with telemetry system SPT 1 for oil production from lower layer. Above this electric submersible pump and above the packer to a depth of 2300 meters, a bypass valve PKSh 73 / 118-35 was installed, which operates when the pressure in the pipe string exceeds the pressure in the annulus by more than 16 MPa to bypass the fluid of the lower reservoir only when the lower electric submersible pump is operating. In this case, instead of a bypass device, any other blocking device could be used with the possibility of pre-setting or real-time control of the opening pressure and closing pressure (in general, different from each other).
The parameters of the technological regime of the lower reservoir at a design bottomhole pressure of 16 MPa — fluid production using an ECM 5-50-2400 was 57 m3 / day; oil 51 m3 / day.
Above it, to the depth of 2200 meters on the same pipe string, the upper electric submersible pump ЭЦНМ 5-200-1600 was lowered.
The lower electric submersible pump ETsNM 5-50-2400 and the upper electric submersible pump ETsNM 5-200-1600 are operated simultaneously for the production of fluid from the lower and upper reservoirs. To determine the productivity of the upper layer and the properties of the produced fluid extracted from it, temporarily lower the electric submersible pump, which is controlled from the surface by an individual power cable.
In this case, the parameters of the technological regime from the total production of reservoir fluid in the lower and upper reservoirs simultaneously amounted to 210 (57 + 153) m3 / day; oil 67 (57 + 15) m3 / day. That is, oil production increased by more than 4 times.
Option 6. Well No. 6666, identical to Well No. 5555.
To implement this method, the electric submersible pump ЭЦНМ 5-160-1600 was lowered deeper than the upper layer to a depth of 2600 meters, and an additional packer was installed above this pump, and a cross-flow device with a spring-loaded check valve communicating the upper layer with the intake was placed inside this packer pump with a pressure drop of more than 16 MPa.
Option 7. In well No. 7777 with a production string of 168 mm (with an internal diameter of 150.5 mm), only one lower layer was initially operated.
The lower layer had the following characteristics: depth of 2700 meters; reservoir pressure in the selection zone 23 MPa; productivity coefficient 10 m3 / day / MPa; saturation pressure 14 MPa; gas factor 140 m3 / m3; water cut of 0.95. The parameters of the technological regime of the lower reservoir at a design bottomhole pressure of 12 MPa — liquid production using an ECM 5-125-2100 was 110 m3 / day; oil 5.5 m3 / day.
It was decided to apply the proposed method - to open an additional upper layer with highly viscous oil.
The upper layer had the following characteristics: depth of 1200 meters; reservoir pressure in the selection zone of 12 MPa; productivity coefficient 5 m3 / day / MPa; saturation pressure 6 MPa; gas factor 60 m3 / m3; water cut 0.1.
The parameters of the technological regime of the upper layer at a design bottomhole pressure of 6 MPa - liquid production using the upper additional electric submersible pump ETsNM 5-30-900, if the products were not highly viscous, would be 30 m3 / day; oil 27 m3 / day.
However, due to the high viscosity of the formation fluid, the pump was shut off for protection, and it was not possible to extract highly viscous fluid using the ESP.
It was decided to use the proposed method according to option 7.
To do this, they lowered 73 mm pipe columns with an ECMN 5-200-2100 without a packer into the well, a bypass valve was released to a depth of 1600 meters, which closes when the pressure in the pipe string exceeds the pressure in the annulus.
A column of pipes with a larger diameter of 127 mm was lowered above it.
An additional electric submersible pump ЭЦНМ 5-50-600 was lowered into a 127 mm column on a 60 mm pipe string. At start-up, formation fluid was pumped out, while ensuring the entry of hard-to-recover fluid from the upper formation into the pipe string 2 above the bypass valve. After raising the hard-to-recover fluid to receive the upper electric submersible pump, it turned off and the lower electric submersible pump ЭЦНМ 5-200-2100 was launched. At the same time, he pumped out of the annulus a high-flooded reservoir fluid entering his intake from the lower reservoir and associated water, which comes with high-viscosity oil from the upper reservoir. Due to the difference in densities between these conventional fluids (water) and high-viscosity oil, a hard-to-recover fluid - high-viscosity oil, water-oil emulsion with a high content of mechanical impurities was displaced from the pipe string to the surface. At the same time, the cavity of the pipe string is isolated from the upper formation with a difficult-to-recover fluid non-return valve - a bypass valve. The displacement process continues until only a highly watered low viscosity fluid enters the surface. Then the lower electric submersible pump is turned off and the upper electric submersible pump is restarted.
Option 8. Well No. 8888, identical to Well No. 7777.
To implement the method of this option, two electric submersible pumps were lowered into the well on two eccentric pipe columns with a diameter of 60 mm with an offset offset depth of their couplings without a packer (although a packer for two columns could be installed between the layers).
When the upper ECMN 5-50-600 was launched, the formation fluid was pumped out alternately from the first and second columns, while ensuring the hard-to-recover fluid from the upper formation in turn entered into these pipe columns through the corresponding bypass valves. After raising a hard-to-recover fluid to receive the upper electric submersible pump, it disconnected (by sensor or timer) from one column and switched to another, connecting the first column with a bypass line to displace a highly viscous fluid through it. At the same time, the discharge of the lower electric submersible pump was simultaneously switched to the same column, which continuously (or periodically) pumped out of the annulus a highly watered formation fluid, arriving at its intake from the lower layer and associated water coming together with highly viscous oil from the upper layer. Due to the difference in densities between these conventional fluids (water) and high-viscosity oil, a hard-to-recover fluid - high-viscosity oil, water-oil emulsion with a high content of mechanical impurities was displaced from the pipe string to the surface. At the same time, the cavity of the pipe string is isolated from the upper formation with a difficult to extract fluid bypass valve. After this, the process was repeated by changing columns.
Other examples of the implementation of the present invention are clear from the drawings.

Claims (31)

1. The method of simultaneous and separate oil production from the strata of one well with a submersible pump installation, comprising lowering concentrically two - external and internal - pipe strings, a packer located between the two strata and two artificial elevators, the lower one for production fluid from the lower reservoir, lowered on the outer pipe string and is made electric submersible, consisting mainly of a pump with an input module and a submersible motor with a power cable, characterized in that they select the lower electric submersible pump operating parameters in accordance with the flow rate of the lower formation, lower it into the well below the packer with the cable entry and position it at a depth above, below or at the level of the lower formation to extract fluid from it in the annular space formed between the two pipe columns, and install above the electric submersible pump cross-flow device made with eccentric channels for raising the fluid of the lower reservoir and a cross channel with an axial outlet for the flow of fluid of the upper reservoir, select the upper artificial an elevator with operating parameters in accordance with the flow rate of the upper formation, and it is lowered separately into the external pipe string above the cross-flow device on the internal pipe string and placed at a depth higher, lower or at the level of the upper formation for producing fluid from it in the internal pipe string, in in turn, the upper artificial lift is equipped with either a sealing casing with a cable entry or a shank, each of which has a lower sealing hollow rod, which is sealed in the axial exit of the cross channel to separate the fluid flows of the lower and upper reservoirs, and the electric submersible pump and the upper artificial lift are put into operation simultaneously or sequentially or periodically for separate production of fluid from the reservoirs for different pipe columns with the possibility of further accounting for their flow rates on the well surface.
2. The method according to claim 1, characterized in that the submersible pump installation is additionally equipped with one or more technological elements - a bypass channel with a check valve for bleeding free gas from under the packer, a gas separator located above the packer, an inkjet apparatus with a receiving chamber, located under the packer, an additional sealing casing with a cable entry for the lower electric submersible pump, providing the ability to change the direction of flow of the fluid of the lower reservoir, a silencing device located above and / or below the packer, a measuring system for determining flow parameters, a swivel for connecting the upper and lower parts of the pipe string, a centralizer, an additional packer located lower or higher, or between the reservoirs to isolate the leakage interval of the production string or one or several flooded and / or worked-out formations, a column disconnector above an additional packer located below the operated formations, a borehole chamber with a removable valve, blind timid stabilizer liquid level or gas pressure regulator, a buffer controller wellhead pressure transducer current frequency.
3. The method according to claim 1, characterized in that an electric submersible pump is used as a top artificial lift - a centrifugal or screw pump or an electric diaphragm pump, while each of the submersible electric motors is controlled or through an individual power cable, each of which is connected to the surface to an individual or general control station, and each electric submersible pump is equipped with a submersible telemetry system to study formation parameters and regulate its operation modes, and electric the submersible pump located under the packer is equipped with gas dispersing steps.
4. The method according to claim 1, characterized in that the top artificial lift uses a sucker rod pump - a plunger or screw pump, or a hydraulic drive pump - a jet or hydraulic piston, or a screw, or hydraulic rod, or hydraulic pulse, or gas lift - continuous or periodic.
5. A method for simultaneously and separately producing oil from the layers of one well with a submersible pump installation, comprising lowering into the well one or concentrically two columns of pipes, packers located above or below, or between two layers and two artificial elevators, the lower of which, for fluid production from the lower reservoir, launched on a pipe string and made electric submersible, consisting mainly of a pump with an input module and a submersible motor with a power cable, characterized in that they select an electric submersible pump with working steam according to the flow rate of the lower formation, by means of gauges, lower it into the well below the packer with cable entry and place it at a depth above, below or at the level of the lower formation to extract fluid from it in the annular space formed between the pipe columns or pipe string and the wellbore, the upper artificial lift with operating parameters in accordance with the flow rate of the upper layer, and it is installed above the packers and above the upper layer to extract fluid from it through the pipe string, in turn under the upper artificial a cross-flow device is installed with an elevator, made with eccentric channels for inflowing fluid from the upper reservoir and a cross channel with an axial inlet and a sealing liner to raise the fluid of the lower reservoir, while the lower submersible pump and the upper artificial lift are lowered into the well either simultaneously on the same pipe string, or separately on two - external and internal - pipe columns, or they lower the lower electric submersible pump with the upper artificial lift on one pipe pipe, and then outside it they accelerate the pipe string of larger diameter to guide the formation fluid of the lower formation along the annular space, the upper artificial elevator being equipped on the outside with either a sealing casing with a cable entry, consisting of one or several sections and connected to the pipe string or pump through an adapter or flange, or it is separately lowered into the outer pipe string above the cross-flow device on the inner pipe string, as well as the column between the packers, is equipped with a circulation device for inflowing formation fluids ida, moreover, the electric submersible pump and the upper artificial lift are put into operation simultaneously or sequentially or periodically for separate production of fluid from the corresponding reservoirs along the annular space and the pipe string with the possibility of further accounting for their flow rates on the well surface.
6. The method according to claim 5, characterized in that the submersible pump installation is additionally equipped with one or more technological elements - a bypass channel with a check valve for bleeding free gas from under the packer, a gas separator, an inkjet apparatus, an additional casing for guiding the flow of lower fluid reservoir, silencing device, measuring system for determining flow parameters, swivel for connecting the upper and lower parts of the pipe string, centralizer, additional packer located below the sludge and above, or between exploited reservoirs to isolate the leakage interval of the production string or one or more flooded and / or mined reservoirs, a column disconnector above an additional packer, a borehole chamber with a removable valve, a blind plug, a liquid level stabilizer or gas pressure regulator, wellhead regulator buffer pressure, current frequency converter.
7. The method according to claim 5, characterized in that an electric submersible pump is used as a top artificial lift - a centrifugal or screw pump, or an electric diaphragm pump, while each of the submersible electric motors is controlled or through an individual power cable, each of which is connected to the surface to an individual or common control station, or through one power cable with a number of cores of at least 3, through which electricity is supplied to two submersible motors in parallel or in series about, simultaneously or alternately, each electric submersible pump is equipped with a submersible telemetry system to study the parameters of the reservoirs and regulate its operation modes, and the electric submersible pump located under the packer is equipped with gas dispersing steps.
8. The method according to claim 5, characterized in that the top artificial lift uses a sucker rod pump - a plunger or screw pump, or a hydraulic drive pump - a jet or hydraulic piston, or a screw, or hydraulic rod, or hydraulic pulse, or gas lift - continuous or periodic.
9. The method of simultaneous and separate oil production from the reservoirs of one well with a submersible pumping unit, including the descent into the well of a string of pipes, a packer located between two layers, and two artificial elevators, the lower of which is lowered to produce fluid from the lower reservoir the pipe string and is made of electric submersible, consisting mainly of a pump with an input module and a submersible motor with a power cable, characterized in that they select an electric submersible pump with operating parameters in accordance with the lower flow rate formation, lower it into the well below or above the packer and positioned at a depth higher, lower or at the level of the lower formation, with it help raise the fluid of the lower formation to receive the upper artificial lift, and for the controlled flow of fluid of the upper formation above the electric submersible pump, install a bypass valve, closing when the pressure drop set on it, or a spring-loaded or free check valve located in the borehole chamber, or in the channel of the bypass device, or in the cross channel of the device, is closed and the cross flow, communicating the upper reservoir with the reception of the upper artificial lift, select the upper artificial lift with the operating parameter in accordance with the total flow rate of the upper and lower layers, lower it above the valve for a controlled flow of fluid from the upper layer and place it at a depth higher, lower, or at the level the upper layer, and the upper artificial lift is lowered into the well with a sealing casing with a cable entry, consisting of one or more sections and connected to the pipe string or to the pump through cut the adapter or flange, and the electric submersible pump is put into operation periodically, both in the process of studying the parameters and in the process of extracting fluid from the lower reservoir when cutting off the upper reservoir by closing the bypass or check valve with an increase in pressure in the pipe string at its level, and the upper artificial lift is launched mainly for the simultaneous production of fluid from the upper and lower reservoirs with an open bypass or check valve.
10. The method according to claim 9, characterized in that the submersible pump installation is additionally equipped with one or more technological elements - a bypass channel with a check valve for bleeding free gas from under the packer, a cable entry for the packer, a gas separator located above the packer, jet apparatus, an additional sealing casing with a cable entry for the lower electric submersible pump, providing the possibility of changing the direction of the fluid flow of the lower reservoir, a silencing device, measuring with a system for determining the flow parameters, a swivel for connecting the upper and lower parts of the pipe string, a centralizer, an additional packer located lower or higher, or between the operating layers to isolate the leakage interval of the production string or one or more flooded and / or wrought layers, the column disconnector above the additional packer, additional borehole chamber with a removable valve, blind plug, liquid level stabilizer or gas pressure regulator, regulator buffer wellhead pressure transducer current frequency.
11. The method according to claim 9, characterized in that an electric submersible pump is used as a top artificial lift - a centrifugal or screw pump, or an electric diaphragm pump, while each of the submersible electric motors is controlled or through an individual power cable, each of which is connected to the surface to an individual or general control station, or through one power cable with a number of cores of at least 3, through which electricity is supplied to two submersible motors in parallel or a follower on simultaneously or alternately, each equipped with electric submersible pump submersible telemetry system for the study of formation parameters and control its operating modes, and electric submersible pump located below the packer, equipped with a gas dispersion steps.
12. The method according to claim 9, characterized in that the top artificial lift uses a sucker rod pump - a plunger or screw pump, or a hydraulic drive pump - a jet or hydraulic piston, or a screw, or hydraulic rod, or hydraulic pulse, or gas lift - continuous or periodic.
13. The method according to claim 9, characterized in that the parameters of the lower reservoir are examined at different bottomhole pressures above the saturation pressure, established by changing either the current frequency or the wellhead pressure, or the pressure on the upper part of the artificial lift, or the pressure on the left side of the electric submersible pump.
14. The method of simultaneous and separate oil production from the reservoirs of one well with a submersible pump installation, comprising lowering into the well a string of pipes, a packer located between two layers, and two artificial elevators, the lower of which, for the production of fluid from the lower reservoir, was lowered to the pipe string and is made of electric submersible, consisting mainly of a pump with an input module and a submersible motor with a power cable, characterized in that they select an electric submersible pump with operating parameters in accordance with the lower flow rate formation, lower it into the well below or above the packer on the pipe string and position it at a depth above, below or at the level of the lower formation, and above the electric submersible pump, install a shut-off valve in the center of the pipe string above or below the packer or install between two packers or two downhole chambers, or two bypass valves with a plug between them, overlapping the pipe string for passing the lower reservoir fluid, first through the lower bypass valve from the pipe to the annular space, and then through the upper - from the annular to t the bottom space and then to receive the upper artificial lift, select the upper artificial lift with the operating parameter in accordance with the total flow rate of the upper and lower layers, lower it above the shut-off valve and position it at a depth higher, lower or at the level of the upper layer to extract fluid from the lower and the upper layers, and the adjusting characteristics of the shutoff valve are selected with the possibility of how to close it when the lower submersible pump is turned off, for operation and study of the parameters of the upper formation, within the regulatory dependence of the upper artificial lift, and its opening when the electric submersible pump is started up or when the productivity of the upper artificial lift is increased over the nominal mode, and the upper artificial lift is lowered into the well with a sealing casing with a cable entry consisting of one or several sections and connected to the pipe string or to the pump through an adapter or flange, whereby the electric submersible pump and the upper artificial lift are launched into operation for one temporary production of fluid from the upper and lower reservoirs with the shut-off valve open and the electric submersible pump is switched off periodically, both when examining the parameters and when operating only the upper reservoir with the shut-off valve closed.
15. The method according to 14, characterized in that the submersible pump installation is additionally equipped with one or more technological elements - a bypass channel with a check valve for bleeding free gas from under the packer, cable entry for the packer, gas separator, jet apparatus, additional sealing a casing with a cable entry for the lower electric submersible pump, providing the ability to change the direction of flow of the fluid of the lower reservoir, a silencing device, a measuring system for determining pa flow rates, a swivel for connecting the upper and lower parts of the pipe string, a centralizer, an additional packer located lower or higher, or between exploited reservoirs to isolate the leakage interval of the production string or one or more flooded and / or worked-out reservoirs, a column disconnector above the additional packer , an additional borehole chamber with a removable valve, a blind plug, a liquid level stabilizer or gas pressure regulator, wellhead buffer pressure regulator Nia or current frequency converter, the valve control system.
16. The method according to 14, characterized in that as the top artificial lift use an electric submersible pump - a centrifugal or screw pump, or a diaphragm pump with an electric drive, while controlling each of the submersible motors or through an individual power cable, each of which is connected to the surface to an individual or general control station, or through one power cable with a number of cores of at least 3, through which electricity is supplied to two submersible motors in parallel or a follower but, simultaneously or alternately, each electric submersible pump is equipped with a submersible telemetry system to study the parameters of the reservoirs and regulate its operating modes, and the electric submersible pump located under the packer is equipped with gas-dispersing steps.
17. The method according to 14, characterized in that the top artificial lift uses a sucker rod pump - plunger, screw or hydraulic drive pump - jet, hydraulic piston, screw, hydraulic rod, hydraulic impulse or gas lift - continuous, periodic.
18. The method of simultaneous and separate oil production from the reservoirs of one well with a submersible pump installation, including the descent into the well of a string of pipes, a packer located between two layers, and two artificial elevators, the lower of which, for the production of fluid from the lower reservoir, was lowered to the pipe string and is made of electric submersible, consisting mainly of a pump with an input module and a submersible motor with a power cable, characterized in that they select an electric submersible pump with operating parameters in accordance with the lower flow rate formation, lower it into the well below or above the packer and placed at a depth above, below or at the level of the lower formation, with it help raise the fluid of the lower formation to receive the upper artificial lift, passing through one or more of the following devices - shutoff valve from differential pressure, electric actuator-shutoff valve, hydraulic actuator-shutoff valve, bypass valve, valve in the borehole chamber, select the top artificial lift with an operating parameter in accordance with the total flow rate of the upper and lower layers, lower it above the valve for a controlled inflow of the lower layer and place it at a depth higher, lower or at the level of the upper layer, with the electric submersible pump and the upper artificial elevator being launched simultaneously to extract fluid from the upper and lower layers with the valve open between them, and when the electric submersible pump is turned off and the valve is closed, the formation fluid of the upper formation is produced by the upper artificial elevator.
19. The method according to p. 18, characterized in that the submersible pump installation is additionally equipped with one or more technological elements - a bypass channel with a check valve for bleeding free gas from the packer, cable entry for the packer, a gas separator located above the packer, jet apparatus, a casing for the upper electric submersible pump, an additional sealing casing with a cable entry for the lower electric submersible pump, providing the possibility of changing the direction of the fluid flow lower of the reservoir, a silencing device, a measuring system for determining flow parameters, a swivel to connect the upper and lower parts of the pipe string, a centralizer, an additional packer located lower or higher, or between the reservoirs to isolate the leakage interval of the production string or one or more flooded and / or produced formations, a column disconnector above an additional packer, an additional downhole chamber with a removable valve, a blind plug, a liquid level stabilizer bone or gas pressure regulator, wellhead buffer pressure regulator or current frequency converter, valve control system.
20. The method according to p. 18, characterized in that the quality of the top artificial lift is either an electric submersible pump - a centrifugal or screw pump, or a diaphragm pump with an electric drive, or a rod pump - a plunger, screw, or a hydraulic drive pump - a jet, hydraulic piston, screw, hydraulic rod pump , hydroimpulse, or gas lift - continuous, periodic.
21. The method according to p. 18, characterized in that one or more of the following elements is used as a flow shutoff valve — a spring-loaded check valve, a shut-off valve, a control valve, an automatic pressure regulator, a butterfly valve, a butterfly valve, a butterfly valve differential pressure triggered hydraulic valve, pressure pulse controlled hydraulic valve, hydraulic valve controlled from the surface of the well through impulse tubes, pneumatically operated valve m actuator, an electrically actuated valve, an electromagnetic valve controlled through an individual cable or through a power cable, moreover, they select the control characteristics of the shut-off valve with the possibility of closing and blocking the fluid flow from the lower reservoir with the lower electric submersible pump switched off within the control dependence of the upper artificial lift and opening it when starting the lower electric submersible pump, and the adjusting characteristics of the lower electric submersible pump are selected with the possibility the ability to maintain bottomhole pressure in the lower reservoir at the pressure of oil saturation with gas.
22. A method for simultaneous and separate oil production from the reservoirs of one well with a submersible pump installation, which includes lowering into the well a string of pipes, a packer located between two layers, and two artificial elevators, the lower of which is lowered to produce fluid from the lower reservoir the pipe string and is made of electric submersible, consisting mainly of a pump with an input module and a submersible motor with a power cable, characterized in that they select a lower electric submersible pump with operating parameters in accordance with the flow rate of the lower layer, lower it into the well below or above the packer on the pipe string and position it at a depth higher, lower or at the level of the lower layer, and above the electric submersible pump and packer, but install an additional packer below the upper layer, forming a receiving chamber in the inter-packer space to accumulate fluid, a cross-flow device made with eccentric channels for passing to the surface of the formation fluid and with a cross channel equipped with with a flap valve and communicating cavities behind the pipe string above and below the additional packer, the top artificial lift with operating parameters is selected in accordance with the total flow rate of the layers, lowered below the cross flow device and placed between packers, and the lower electric submersible pump is launched periodically, both in the process of studying the parameters, and in the process of producing fluid from the lower reservoir when cutting off the upper reservoir by closing the check valve in the cross-flow device with increasing pressure in the pipe string, and the upper artificial lift is launched while simultaneously extracting fluid from all the layers with the check valve open.
23. The method according to p. 22, characterized in that the submersible pump installation is additionally equipped with one or more technological elements - a bypass channel with a check valve for bleeding free gas from under the packer, cable entry for the packer, gas separator, jet apparatus, casing for the upper electric submersible pump, an additional sealing casing with a cable entry for the lower electric submersible pump, providing the ability to change the direction of flow of the fluid of the lower reservoir, measuring system for determining flow parameters, a swivel for connecting the upper and lower parts of the pipe string, a centralizer, an additional packer located lower or higher, or between the operating seams to isolate the leakage interval of the production string or one or more flooded and / or worked out seams , a column disconnector above an additional packer, an additional borehole chamber with a removable valve, a blind plug, a liquid level stabilizer or pressure regulator Nia gas pressure regulator wellhead buffer or converter current frequency valve control system.
24. The method according to p. 22, characterized in that as the top artificial lift use either an electric submersible pump - a centrifugal or screw pump, or a diaphragm pump with an electric drive, or a sucker rod pump - a plunger, screw, or a hydraulic drive pump - a jet, hydro piston, screw, hydraulic rod, hydroimpulse, or gas lift - continuous, periodic.
25. A method for simultaneous and separate oil production from the strata of one well with a submersible pump installation, comprising lowering a string of pipes and two artificial elevators into the well, the lower of which is lowered onto the pipe string and made electric submersible, consisting mainly of a pump with an input module and a submersible electric motor with a power cable, characterized in that the lower electric submersible pump is lowered into the well below the reservoir with hard-to-recover fluid, the usual fluid is pumped out with an upper artificial elevator, while ensuring the blunting of the difficult to extract fluid into the pipe string at a predetermined depth above the lower electric submersible pump, and after lifting it to receive the upper artificial lift, the latter is turned off and the lower electric submersible pump is put into operation, displacing the difficult to remove fluid from the pipe string to the surface with ordinary fluid, either entering in the form of associated water from the upper reservoir, or in the form of ordinary fluid from a lower reservoir, while the cavity of the pipe string is isolated from the reservoir with a difficult to recover fluid check valve m, and the lower electric submersible pump and the upper artificial lift are lowered into the well either simultaneously on the same pipe string, or the upper one is lowered separately on the additional inner pipe string, and the lower electric submersible pump and the upper artificial lift are put into operation alternately.
26. The method according A.25, characterized in that the submersible pump installation is additionally equipped with one or more technological elements - a packer, a device for switching the reception of the upper artificial lift from the outer column to the annular space between the outer and inner column, cross-flow device, bypass channel with check valve for bleeding free gas from under the packer, gas separator, jet device, casing for the upper electric submersible pump, additional sealing m a casing with a cable entry for the lower electric submersible pump, providing the possibility of changing the direction of the fluid flow of the lower reservoir, a silencing device, a measuring system for determining flow parameters, a swivel to connect the upper and lower parts of the pipe string, a centralizer, an additional packer located lower or higher, or between exploited formations to isolate the leakage interval of the production string or one or more flooded and / or mined formations, disconnect the column column above the additional packer, additional borehole chamber with a removable valve, blind plug, liquid level stabilizer or gas pressure regulator, wellhead buffer pressure regulator, current frequency converter, valve control system.
27. The method according A.25, characterized in that as the top artificial lift use either an electric submersible pump - a centrifugal or screw pump, or a diaphragm pump with an electric drive, or a sucker rod pump - a plunger, screw, or a hydraulic drive pump - jet, hydraulic, piston, screw, hydraulic rod, hydroimpulse, or gas lift - continuous, periodic.
28. A method for simultaneous and separate oil production from the strata of one well with a submersible pump installation, comprising lowering into the well two concentric or eccentric pipe columns and at least two artificial elevators, the lower of which is lowered onto the pipe string and made electric consisting mainly of a pump with an input module and a submersible motor with a power cable, characterized in that the electric submersible pump is lowered into the well below the reservoir with hard-to-recover fluid, one of the columns is connected to by means of the upper artificial lift and they pump out the usual fluid, while ensuring the delivery of hard-to-recover fluid into this column at a predetermined depth above the lower electric submersible pump, and after it arrives at the reception of at least one upper artificial lift, they disconnect the latter from this column and switch it to another column, at the same time connect to the first column the discharge of the lower electric submersible pump, while displacing the hardly recoverable fluid from it onto the surface with an ordinary fluid, falling either in the form of associated water from a reservoir with difficult to extract fluid, or in the form of a conventional fluid from a downstream formation, or from the cavity of another pipe string used at that moment to accumulate hard-to-recover fluid, and the lower electric submersible pump is either started periodically, as it accumulates in the string pipes of hard-to-recover fluid, or it is operated continuously, alternately switching its flow from the first column to the second with simultaneous switching - by connecting the reception of the upper artificial lift and / or receiving the lower electric submersible pump, respectively, from the second column to the first.
29. The method according to p. 28, characterized in that the submersible pump installation is additionally equipped with one or more technological elements - a packer, a device for switching reception of the upper artificial lift from one column to another, a device for switching reception of the lower electric submersible pump from one column to another , a device for switching the discharge of the lower electric submersible pump from one column to another, a cross-flow device, a bypass channel with a check valve for bleeding freely gas from under the packer, gas separator, jet apparatus, a casing for the upper electric submersible pump, an additional sealing casing with a cable entry for the lower electric submersible pump, which provides the possibility of changing the direction of the fluid flow of the lower reservoir, a silencing device, a measuring system for determining flow parameters, swivel for connecting the upper and lower parts of the pipe string, with a centralizer, an additional packer located lower or higher, or between the operating seams the leakage interval of the production casing or one or more flooded and / or worked-out formations, a casing disconnector above an additional packer, an additional borehole chamber with a removable valve, a blind plug, a liquid level stabilizer or gas pressure regulator, a wellhead buffer pressure regulator, a current frequency converter, valve control system.
30. The method according to p. 28, characterized in that as the top artificial lift use an electric submersible pump - a centrifugal or screw, or a diaphragm pump with an electric drive, while controlling each of the submersible motors or through an individual power cable, each of which is connected to the surface to an individual or general control station, or through one power cable with a number of cores of at least 3, through which electricity is supplied to two submersible motors in parallel or a follower but, simultaneously or alternately, each electric submersible pump is equipped with a submersible telemetry system to study the parameters of the reservoirs and regulate its operating modes, and the electric submersible pump located under the packer is equipped with gas-dispersing steps.
31. The method according to p. 28, characterized in that the top artificial lift use a sucker rod pump - plunger, hydraulic screw pump - jet, hydraulic piston, screw, hydraulic rod, hydraulic impulse or gas lift - continuous, periodic.
RU2007114215/03A 2007-04-16 2007-04-16 Method of dual oil production from layers of one well with submersible pump set (versions) RU2344274C1 (en)

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