WO2022039627A1 - Procédé de traitement sélectif de couche de production, et dispositif de mise en oeuvre - Google Patents

Procédé de traitement sélectif de couche de production, et dispositif de mise en oeuvre Download PDF

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Publication number
WO2022039627A1
WO2022039627A1 PCT/RU2021/000362 RU2021000362W WO2022039627A1 WO 2022039627 A1 WO2022039627 A1 WO 2022039627A1 RU 2021000362 W RU2021000362 W RU 2021000362W WO 2022039627 A1 WO2022039627 A1 WO 2022039627A1
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WO
WIPO (PCT)
Prior art keywords
packer
flushing
hydraulic fracturing
tubing
annulus
Prior art date
Application number
PCT/RU2021/000362
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English (en)
Russian (ru)
Inventor
Салават Анатольевич Кузяев
Original Assignee
Салават Анатольевич Кузяев
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Filing date
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Application filed by Салават Анатольевич Кузяев filed Critical Салават Анатольевич Кузяев
Priority to US17/639,080 priority Critical patent/US20230332485A1/en
Publication of WO2022039627A1 publication Critical patent/WO2022039627A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/10—Valve arrangements in drilling-fluid circulation systems
    • E21B21/103—Down-hole by-pass valve arrangements, i.e. between the inside of the drill string and the annulus
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B37/00—Methods or apparatus for cleaning boreholes or wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures

Definitions

  • the invention relates to mining, is used in the repair and operation of oil wells, is intended for selective processing of a productive formation in one round-trip operation with flushing the annulus in real time during downhole operations.
  • One of the measures to avoid an emergency in the well due to stuck downhole equipment is to ensure high-quality flushing of the cavities between the downhole tool and the production string, especially in the productive formation zone, as well as the internal cavities of the equipment used for process fluids.
  • devices that contain various filtration devices, trapping elements and storage containers.
  • a known method of operation of a downhole jet installation which involves flushing the area of the productive formation after hydraulic fracturing (hereinafter hydraulic fracturing) using a downhole jet unit (RF patent No. 2273772, published April 10, 2006, bull. 10).
  • the method consists in lowering into the well on a string of tubing (hereinafter tubing) a downhole installation consisting of a jet pump with a stepped through passage in its body and, located below the jet pump, a packer with a through passage and a liner with an inlet funnel. Then the packer is unpacked, which is installed above the productive formation.
  • a blocking insert with a central passage channel is installed in the stepped flow channel of the jet pump, and a hydraulic fracturing fluid or a mixture of hydraulic fracturing fluid with chemical reagents is pumped into the productive formation.
  • the blocking insert is removed to the surface and a flexible pipe is lowered through the tubing into the well, which is passed through the sealing assembly with the possibility of its movement.
  • the sealing assembly is installed during the descent of the flexible pipe in the stepped flow channel of the jet pump.
  • the lower end of the coiled tubing is installed below or at the level of the lower perforation interval of the productive formation.
  • a liquid working medium is fed into the nozzle of the jet pump through the annulus of the well, and the productive formation is drained by creating drawdown on the productive formation in the under-packer space of the well. Simultaneously or after creating a stable drawdown on the productive formation, liquid is supplied to the well through a flexible pipe to flush the bottom hole.
  • the ratio between fluid pressure in coiled tubing and fluid pressure in the well annulus is maintained in the range (Pg:Pp) ⁇ 0.98.
  • the downhole jet installation used for the implementation of the method comprises a packer with a passage channel installed on the tubing string, a jet pump, in the body of which a nozzle and a mixing chamber with a diffuser are located.
  • the jet pump has a stepped flow channel.
  • Below the jet pump is a shank with an inlet funnel.
  • a sealing assembly or, alternatively, a blocking insert is installed in the stepped passageway.
  • a flexible pipe is passed through the sealing unit, the lower end of which is installed below or at the level of the lower perforation interval of the productive formation.
  • the downhole jet unit is placed in the well so that the jet pump and packer are located above the reservoir.
  • the disadvantage of the known method and the downhole jet installation is the high probability of emergency extraction from the well in case of jamming due to the dusting of the annular space between the tool and the casing string with mechanical debris. Cleaning and extraction of foreign inclusions, in particular flushing the annulus from proppant, is not provided by the method according to the mentioned patent.
  • the design of the jet unit does not allow reverse circulation of the fluid to remove mechanical debris from the well, for example, through the annulus due to the packer being sprinkled on top, which cannot be deactivated.
  • Another disadvantage of this system is that it cannot be used when processing several intervals of a productive formation in one trip, since after flushing the bottom of the well, the installation is immediately removed to the surface.
  • the trap consists of two separate nodes - the upper and lower ones, fixed in the pipe at some distance from each other.
  • the top assembly is equipped with a screen in the form of a sieve, a plug and a three-way adapter.
  • the bottom assembly consists of a screen, a three-way adapter and a ball check valve.
  • the top and bottom assemblies are fixed in the flush tube by known means of connection.
  • the trap works in conjunction with the sand control element in the well.
  • Process fluid with proppant enters the tubing for hydraulic fracturing, while the proppant begins to accumulate in the annulus between the casing string and equipment.
  • the liquid passes through a screen-sieve built into the tubing and enters the wash pipe.
  • the liquid then passes through the lower trap assembly, the ball valve and enters the space of the wash pipe between the nodes and further into the upper trap assembly. Moving, the liquid is additionally filtered in the bonds of the trap. This prevents further propagation of the proppant.
  • the proppant is separated from the fluid by the lower assembly filter and retained by the check valve ball.
  • the amount of proppant in the cavity of the flushing tube between the trap nodes is used to judge the degree of contamination. Without extraction from the well, an indicator of the degree of contamination may be the loss of fluid volume during its return.
  • the reversible tool is designed to remove fluid and debris from the well, especially with large annular gaps.
  • the tool allows reverse flow at reduced pump speeds without compromising debris throughput.
  • the reversible tool contains a cylindrical element with cup-shaped sealing elements that hermetically separate the casing and create two separate annular gaps: one above the sealing elements, the other below the sealing elements.
  • the cylindrical element is equipped with an internal baffle forming two channels in the inner cavity of the tubing, one channel is descending, the other is ascending. Through the descending channel, the flow of liquid or other material is removed from the tubing cavity into the annular space under the sealing element.
  • the flow of liquid or other material rises through the tubing below the sealing element and is discharged into the annular space above the sealing element, while the flow rate decreases, since the cross-sectional area of the tubing is less than the annular space.
  • the annular space above the sealing element can be used to collect debris that cannot be carried by the reduced flow rate, while the debris collectors should not impede flow at the process speed.
  • the reversible tool is part of the fluid circulation system that flows from the tank through the suction line to the pump, which are on the above ground part of the equipment.
  • the pump moves the flushing fluid through the pipeline to the upper tubing string above the cup sealing element.
  • the flushing fluid moves down the upper part of the tubing to the reversing tool, through which it is discharged to the annular space under the cup sealing element.
  • the mixture of drilling fluid and debris then continues to move down the annulus to the bottom of the well and returns to the tubing again. Further, the filtered mixture, moving up the tubing, reaches the reversing tool and is deflected again, enters the annular space above the cup seal. Then, rising along the upper part of the tubing, the flushing fluid enters the reservoir.
  • the reversible tool can work for more than two years of continuous operation, performing more than 4000 cycles during the service life.
  • the system is equipped with alarms in the form of pressure gauges that monitor sudden pressure drops and the ability to block the system to warn the well operator that the traps are full or contain a lot of debris.
  • the disadvantage of this system is the limited area of use, mainly in offshore wells, and does not involve the simultaneous implementation of technological operations for the treatment of productive formations.
  • work The system is based on many levels of filtration, and contains sophisticated equipment for flushing these devices that require periodic replacement.
  • composition and relative position of the main components of the system are similar for all options presented in the patent and includes an anchor, a lower packer, a hydraulic fracturing unit, an upper packer, a mechanical valve, a sand control unit, and an injection unit installed on the tubing (from bottom to top), providing pressure activation in the system.
  • Below the anchor there is a valve that is in the closed position during hydraulic fracturing and a hole for dumping excess fluid.
  • the anchor is designed to fix the device in the well and can be installed by axial movement up and down.
  • the top and bottom packers are designed to isolate the reservoir area.
  • the mechanical valve is an element of the sand control unit and is involved in creating a pressure drop in the annulus below the sand control unit to ensure flushing of the annulus.
  • the sand control unit is located above the hydraulic fracturing unit and is designed to remove produced sand and gravel from the annulus when moving to another treatment zone or to the surface.
  • a flushing device is involved, which provides hydraulic communication with the annular space in the annular gap zone through radial channels.
  • the sand control unit is additionally equipped with a check valve and one or more additional packers.
  • the patent presents three variants of the flushing device, one of which can be activated several times, which ensures flushing of the annular gap when processing several productive formations in one trip.
  • the flushing device is located above the hydraulic fracturing unit, is connected to a mechanical valve and opens when flushing fluid is supplied at an appropriate pressure, which is much higher than the hydraulic fracturing pressure, therefore, during hydraulic fracturing, the flushing device is closed.
  • the flushing device contains a sliding sleeve installed in the housing, a piston and a return spring. The pressure exerted on the piston counteracts the compression force of the spring. Radial holes are made in the housing, blocked by a piston in the closed position of the flushing device. Nozzles are installed in the radial holes, providing a given angle of jet supply to the wellbore for the possibility of flushing the annulus in different directions.
  • the system is also equipped with a release mechanism that activates and deactivates the reservoir packers and the hydraulic fracturing unit.
  • the release mechanism is made in the form of a housing, which is an element of the system, inside which an internal sleeve is installed with the possibility of axial movement.
  • the inner sleeve is provided with a radial hole.
  • a removable sleeve In the cavity between the body and the inner sleeve there is a removable sleeve with grooves forming axially longitudinal cavities hydraulically connected with the annulus.
  • the inner sleeve When the system is idle, the inner sleeve is in the working position, the packers sealing the reservoir area and the hydraulic fracturing unit are not active.
  • the radial hole of the inner sleeve is closed with a removable sleeve.
  • the position of the inner sleeve ensures the passage of fluid through the internal cavity of the piston and closes the hydraulic connection with the annulus through the radial holes in the body.
  • the removable sleeve is kept from displacement relative to the housing by a retainer.
  • the inner sleeve When pressure is applied to the inner cavity of the piston, the inner sleeve, overcoming the action of the return spring, performs axial movement until the hydraulic connection is restored through the radial holes in the inner sleeve and in the housing, which communicate with the cavity between the housing and the sleeve.
  • the pressure in the piston cavity partially drops, the inner sleeve returns to the idle position under the action of the spring.
  • the retainer Under the action of pressure in the piston area, the retainer is displaced into the seat in which it is installed, releasing the removable sleeve.
  • This bushing closes the radial hole in the housing, maintaining the hydraulic connection of the piston cavity with the cavity between the housing and the inner bushing, while the increasing flushing pressure does not exceed the force of the return spring on the inner bushing.
  • the hydraulic fracturing unit is closed, the packers sealing the formation area are not activated.
  • the known system is designed to operate in emergency conditions, when it is impossible to remove the drilling tool from the well, due to the dusting of the upper packer with mechanical debris and the impossibility of flushing the annulus in the annulus between the packers. This leads to the impossibility of controlling the circulating flushing unit, removing the tool from the well, and requires additional units that provide this function for flushing the space above the second packer from the bottom.
  • Another disadvantage of the device is the use of high pressures during flushing, exceeding the hydraulic fracturing pressure by 2-5 times.
  • the flushing pressure will be 1400-3500 atmospheres, which is much higher than the value of 1000 atmospheres - the pressure for which standard hydraulic fracturing equipment is designed.
  • the use of pressure during the operation of the device when flushing the annulus of the well which is several times higher than the hydraulic fracturing pressure, entails the need to use non-standard wellhead equipment, non-standard tubing hanger, non-standard pumping equipment for hydraulic fracturing, which significantly reduces the manufacturability of the known system and significantly limits its use.
  • the objective of the inventions is to increase the efficiency of the treatment of the productive formation in one round trip, to reduce the accident rate and increase the service life of the downhole tool.
  • the technical result is to ensure simultaneous flushing of the inter-packer annular gap between the casing string and the tool, as well as the internal cavities of the tool after each treated interval of the productive formation and to increase the reliability and manufacturability of the device used by simplifying its design.
  • the method of selective treatment of a productive formation includes successive hydraulic fracturing and flushing of the annular gap in the interpacker space of each interval of the productive formation, using a device for its implementation, which is lowered into the tubing to the level of the lowest interval of the productive formation.
  • the device When the device reaches a level at which the interval of the productive formation to be processed is located in the inter-packer space, the device is fixed in the well with a mechanical anchor. Next, the working fluid is supplied under pressure to the tubing cavity, the hydraulic fracturing port, and the productive formation interval is isolated by packers with cup sealing elements. Then hydraulic fracturing is carried out.
  • the first cycle which begins with the injection of flushing fluid into the annulus, then activates the lower packer and flushes out debris from the upper area of the inter-packer annulus through the fracturing port windows up the tubing.
  • the second cycle begins with the transfer of the device to the transport position, then the axial movement of the tubing leads to the displacement of the hollow rod of the device and opens the flushing holes. After that, flushing fluid is supplied under pressure to the tubing, the cup sealing elements of the packers are activated and debris is washed out from the lower region of the interpacker annular gap and the cup seals, moving the mixture along the internal cavity of the device beyond its limits into the well.
  • the flushing liquid is supplied by a pumping unit located on the surface.
  • the mechanical anchor is deactivated by the longitudinal movement of the device.
  • Debris from the upper region of the interpacker annulus is disposed of at the surface by any known method.
  • the device for implementing the method contains a mechanical anchor, a lower pass-through packer, a hydraulic fracturing port, and an upper pass-through packer installed in series on the tubing.
  • Drift packers equipped with cup seals are directed to the hydraulic fracturing port.
  • a hollow rod is located in the internal cavity of the device.
  • the body of the hydraulic fracturing port is divided by a partition into the upper part, in which windows are made, and the lower part, in which flushing holes are located, providing hydraulic connection between the packer annulus with a cavity made in the lower part of the partition.
  • the lower pass packer is provided with a longitudinal cavity on the inner surface, and the hollow rod is provided with protrusions that interact with the cavity, moving along it. The distance between the bottom drift packer and the flush holes does not exceed two casing diameters.
  • the tightness of the flushing holes is ensured by seals placed above and below the flushing holes.
  • the internal cavities of the hollow rod, the lower pass-through packer and the mechanical sleeve locator form a single flushing channel.
  • the hollow rod is rigidly connected to the mechanical anchor.
  • the device can be additionally equipped with a sleeve locator located under the lower drift packer and a centralizer.
  • Flushing of the annulus carried out in two cycles, in each of which debris is removed from the upper or lower region of the annulus, provides high-quality cleaning.
  • the sequence of hydraulic fracturing, the first and subsequent second cycles of flushing the inter-packer annulus annulus ensures unhindered movement of the tool along the casing string.
  • the simple and reliable design of the device for implementing the method ensures the movement of the flushing fluid through two unconnected channels for removing debris, which are controlled by a simple longitudinal movement (activation / deactivation) of the mechanical anchor and due to the interaction of only two elements - a hollow rod and a body of the lower through packer .
  • FIG. 1 shows a general view of the device; in fig. 2 - enlarged view of the hydraulic fracturing port; in fig. 3 is a longitudinal section of the device in the transport position; in fig. 4 is a longitudinal section of a device with an activated mechanical anchor; in fig. 5 is an enlarged view of the hydraulic fracturing port in the position of the device shown in FIG. 3; in fig. 6 - longitudinal section of the device in the position of hydraulic fracturing; in fig. 7 - a diagram of the movement of the working fluid with an activated anchor; in fig. 8 - a diagram of the movement of the working fluid with a deactivated mechanical anchor.
  • the device contains a mechanical anchor (1), a sleeve locator (2), a lower pass-through packer (3), a hydraulic fracturing port (4) and an upper pass-through packer (5) with a centralizer (6) mounted from the bottom up on the tubing string (Fig.1, Fig. .2).
  • Remote nozzles (7) are connected to the centralizer b, the installation of which is determined by the need and conditions for processing intervals of the formation of variable length.
  • Cup sealing elements (8) of the lower floating packer (3) are directed to the hydraulic fracturing port (4).
  • Cup sealing elements (9) of the upper floating packer (5) are also directed to the hydraulic fracturing port.
  • mechanical sleeve locator similar to sleeve locator A 1025-2, presented in the catalog "Tool for maintenance and workover of wells", p. 31 https://www.slb.ru/upload/iblock/d8e/katalog-instrumentov-dla- tekushego-i-kapitalnogo" repair-skvaiin.pdf ):
  • centralizer http://www.coilsolutions.com/products/downhole-tools/drill-and-milling-tools/fluted-centralizers/) or (http://petrolibrary.ru/preduprezhdenie-iskriyleniya-vertikalnyix-skvazhi -skvazhin.html); axial mechanical anchor (YAMO-3, YAMO-2) (https://npf-paker.ru/catalog/tvpe/yakorya/mekhanicheskie/vamo3-yamo2-yam3-yam2).
  • the hydraulic fracturing port 4 contains a partition (11) placed inside the body, in the lower part of which a recess (12) is made, and a divider (1)3 is installed in the upper part (Fig. 3).
  • a divider (1)3 is installed in the upper part (Fig. 3).
  • radial holes (14) are made in the lower part of the port, connecting the recess (12) with the annulus.
  • a hollow rod (15) is placed with the possibility of axial movement, rigidly connected to the mechanical anchor 1 by means of a cone (16).
  • the hollow rod (15) is provided with limiting protrusions (17) that move axially along the cavity (1)9 made on the inner surface of the packer (3), the longitudinal dimension of which determines the stroke “S” of the rod (15) (Fig. 3 and Fig. 4).
  • the hollow rod (15) In the transport position of the device, the hollow rod (15) is in the lower position, in which the protrusions (17) abut against the lower horizontal wall of the cavity (18), the radial flushing holes (14) provide communication between the recess (12) and the annulus between the packers (Fig. 2 and Fig. 3).
  • the cup seals (8) of the lower pass-through packer (3) are located at a distance H1 from the flush holes (14) of the hydraulic fracturing port (4), the value of which depends on the well diameter and does not exceed two casing string diameters.
  • the device for implementing the method works as follows:
  • the device Before running into the well, the device is assembled at the wellhead and installed on the tubing.
  • the device Before treatment of the formation, the device is placed in a blind section of the production casing and pressure testing of the through-flow packers is carried out.
  • the device is installed in such a way that the processing interval is located in the inter-packer space and the mechanical anchor (1) is activated, ensuring that the device is fixed in the well with anchor elements (21) (Fig. 4). Then part of the weight of the tubing is unloaded onto a mechanical anchor (1), while the hollow rod (15) enters the recess (12), hermetically blocking the flushing holes (14) with the help of seals (18) (Fig. 5).
  • hydraulic fracturing fluid is supplied under pressure to the tubing pipes (1) and, due to the counter flow from the hydraulic fracturing port (4), the cup sealing elements (8) and (9) of the through-flow packers (3) and (5) open, providing a tight fit to the the inner wall of the casing pipe, reliably isolating the inter-packer space. Then hydraulic fracturing is performed (Fig. 6).
  • the tubing, the device and the space between the device and the production string are flushed, freeing it from proppant and other mechanical inclusions, ensuring unhindered and saving movement of the device to the next formation interval or recovery from the well.
  • Flushing of the annular space of the well and the cavities of the device is carried out in two cycles as follows.
  • the first cycle begins with the pumping unit, located on the surface, supplying the flushing fluid under pressure into the annulus, while cup sealing elements (8) of the lower pass-through packer (3) are in the active position.
  • the flushing fluid through the windows (10) enters the internal cavity of the hydraulic fracturing port (4), the upper pass-through packer (5) and rises to the surface along the tubing, taking with it the proppant and other inclusions from the upper region of the inter-packer space (Fig. 7). After the technological period of washing, the supply of washing liquid is stopped.
  • the second washing cycle begins with the transfer of the device to the transport position.
  • the mechanical anchor (1) is deactivated by longitudinal movement of the device.
  • the hollow rod (15) moves down until the stop of the limiting projections (17) against the wall of the cavity (19) and opens the flushing holes (14).
  • the flushing fluid is again fed under pressure into the tubing (Fig. 8).
  • the flushing fluid enters the internal cavities of the upper pass-through packer (5), the hydraulic fracturing port (4), exits through the windows (10) into the inter-packer space, activating the upper (5) and lower pass-through packer (3) thoroughly washing out the proppant and other inclusions from the lower area interpacker space.
  • the mixture enters the flush holes (14) and into the internal cavity of the rod (15) and is discharged outside the device into the well through a single flush channel (20).
  • the method is carried out as follows.
  • the device Assembled at the wellhead, the device is installed on the tubing and lowered into the well, the production string of which is pre-pressurized to 15 MPa.
  • the total length along the shaft is 3250 m, including the side shaft - 450 m.
  • the descent is carried out at a speed of not more than 0.25 m/s when moving in a production string with a diameter of 168 mm, a length of 2800 m and at a speed of 0.1 m/s when moving along a sidetrack with a diameter of 114 mm (strength group "E").
  • the device is preliminarily placed in a blind section of the sidetrack and the through-cup packers (5) and (3) are pressure tested with a pressure of 12 MPa.
  • the sequence of processing intervals of the productive formation is set in such a way as to initially carry out the processing of the lowest interval at the level of 3200 - 3215m.
  • the device is installed in the well in such a way that the interval to be treated is located between the cup packers (5) and (3) and fixed device in the well with anchor elements 21 when the mechanical anchor (1) is activated ( Figure 4).
  • hydraulic fracturing fluid is pumped through the internal cavity of the tubing and the packers (5) and (3) with cup seals (8) and (9) are activated, providing a tight fit to the inner wall of the casing and reliably isolating the annular gap between the wall of the casing string and the device in interpacker space. Then hydraulic fracturing is carried out at a burst pressure of 46 MPa. (Fig.6).
  • the annulus annulus is flushed to remove the resulting debris (mechanical particles, proppant).
  • the first cycle of flushing the inter-packer annulus begins with a pressure feed of 100 atm. flushing liquid by a pumping unit located on the surface. Providing a flushing fluid flow rate of 6 l/s, the cup seals 8 of the lower pass-through packer (3) are activated and debris is washed out from the upper area of the annular gap through the windows (1)0 of the hydraulic fracturing port (4), moving it along the tubing to the surface for disposal (Fig. 7).
  • the mechanical anchor (1) is deactivated by the longitudinal movement of the device and the device is transferred to the transport position.
  • axial displacement of the tubing is carried out, while the hollow rod (15) of the device is displaced until the stop of the limiting protrusions (17) into the wall of the cavity (19), opening the flushing holes (14).
  • flushing fluid is supplied under pressure of 12 MPa at a flow rate of 1.5 l/s, activating the lower (3) and upper (5) packers.
  • the flushing fluid cleans the lower area of the inter-packer annulus, flushes out small debris from the cup seals (8) of the lower packer (3) and all internal cavities of the device below the hydraulic fracturing port, while all debris is brought down outside the device into the well.
  • the flushing period of the second cycle is determined by the presence or absence of resistance to movement of the device in the well.
  • the device After flushing is completed, the device is moved upwards to treat the second interval of the productive formation (level 3035-3050m), maintaining the sequence of actions for hydraulic fracturing and flushing the annulus between the packers and device elements.
  • the device After finishing the processing of the third interval (2870-2885 m.) and flushing, the device is removed from the well.
  • the claimed inventions make it possible to provide high-quality, technological cleaning of the inter-packer annular space, accident-free movement of the downhole tool for processing several intervals of the productive formation in one trip, using a simple and reliable device.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
  • Excavating Of Shafts Or Tunnels (AREA)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)

Abstract

L'invention concerne un procédé de traitement sélectif de couche de production, qui consiste à effectuer séquentiellement une fracturation hydraulique de la couche (FHC) et à rincer l'espace annulaire entre les packers de chaque intervalle de la couche de production. L'intervalle soumis à un traitement est fixé dans le puits par un ancrage mécanique d'un dispositif, et on envoie sous pression un liquide de travail dans la cavité de tubes de pompage-compression (TPC), un port de FHC, et on isole l'intervalle avec des packers comprenant des éléments d'étanchéité en coupelle. On effectue ensuite la FHC. On rince le jour annulaire au cours de deux cycles. Dans le premier cycle, on rince les déchets depuis la zone supérieure du jour annulaire via les fenêtres du port FHC vers le haut le long des TPC. Dans le second cycle, on effectue la même opération depuis la zone inférieure du jour et les joints en forme de coupelle, en faisant avancer le mélange dans le puits. Le dispositif comprend, installés séquentiellement sur les TRC, un ancrage mécanique (1), un packer de passage inférieur (3), un port de FHC (4), un packer de passage supérieur (5) et un dispositif de centrage (6). Les packers de passage (3, 5) comportent des joints en coupelles (8, 9) qui sont orientés vers le port de FHC (4). Le corps du port de FHC est divisé par une cloison en une partie supérieure avec des fenêtres et une partie inférieure avec des ouvertures de rinçage.
PCT/RU2021/000362 2020-08-21 2021-08-23 Procédé de traitement sélectif de couche de production, et dispositif de mise en oeuvre WO2022039627A1 (fr)

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US17/639,080 US20230332485A1 (en) 2020-08-21 2021-08-23 Device and method of productive formation selective processing

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RU2020128064 2020-08-21
RU2020128064A RU2747495C1 (ru) 2020-08-21 2020-08-21 Устройство и способ селективной обработки продуктивного пласта

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RU2736078C1 (ru) * 2019-11-01 2020-11-12 Салават Анатольевич Кузяев Способ селективной обработки продуктивного пласта, устройство для его осуществления и порт ГРП

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