RU2614169C1 - Method and equipment for interval research of formation parameters at tubes - Google Patents

Abstract

FIELD: mining.

SUBSTANCE: method includes the downhole equipment lowering into the well to the specified depth, consisting of an oilwell tubing column (OWT), upper and lower inflatable packers with the radial holes in the inflation chambers, the outer and inner flexible sleeves with disposed between them the metal plate frame, switching of the upper and lower inflatable packers from transport to working position. The assembly and lowering of the downhole equipment is carried out in the following sequence: the plug, the circulation full bore tube valve with the shear pins, the lower centralizer, inflate and bypass valve of the inflatable packers layout (IBVIPL) underpackers, the lower inflatable packer and inflate valve, interpacker disconnect switch, interpacker IBVIPL, upper inflatable packer and inflate valve, the upper centralizer, overpacker disconnect switch, circulation valve. At the beginning of the downhole equipment lowering, the inflate valves of the inflatable packers, underpacker IBVIPL and interpacker IBVIPL are in the closed position. When the casing pressure is exceeded over the OWT column pressure, the opening of the bypass holes of underpacker and interpacker IBVIPL and filling of OWT column with borehole fluid is carried out. The bypass holes of underpacker and interpacker IBVIPL are closed automatically, then provide the first fluid supply. At that the inflate and bypass holes of underpacker and interpacker IBVIPL are closed and build the pressure, at which the upper and lower inflate valves of the upper and lower inflatable packers are opened respectively, bringing the inflatable chambers into the working position. The downhole equipment is stand under the pressure, then slowly carry out the first pressure releasing: if it reaches the value, the inflate valves are closed completely. The inflatable packers are moved to the working position and intervally overlap the wellbore. At the first pressure release in the underpacker IBVIPL there is the opportunity to open the bypass holes, then the fluid selection is carried out from the underpacker area. The inflate and bypass holes of interpacker IBVIPL are closed. The second fluid supply is performed and the constant pressure is built, at which the inflate holes are opened in underpacker IBVIPL . If necessary, the process fluid inflate to the underpacker area is carried out, during which the inflate and bypass holes of interpacker IBVIPL are closed. Produce the second pressure release, at which there is the opportunity to open the bypass hole in the interpacker IBVIPL. The fluid selection from interparcker area is performed during which the inflate and bypass holes of underpacker IBVIPL are closed. The third fluid supply is performed and the pressure is built, at which the inflate holes of interpacker IBVIPL are opened, and the inflate and bypass holes in underpacker IBVIPL are closed. Produce the third pressure release, at which the inflate and bypass holes of both IBVIPL come to the starting position.

EFFECT: acceleration of works on the sample fluid selection or process fluid inflate into the underpacker and interpacker well areas at one tripping process.

2 cl, 6 dwg

Description

The invention relates to the oil and gas industry and can be used to study the parameters of the reservoir of two or more intervals with one descent of the equipment into the well.

Known designs of inflatable packers with metal frames according to patents US 4458752, prior. 06/10/1984; US 4,544,165, prior. 10/01/1985; US 4,768,590, prior. 09/06/1988; US 5,280,824, prior. 01/25/1994; US 6752205, prior. 06/22/2004; GB 2192416, prior. 08/03/1988; GB 2388387, prior. 11/12/2003.

A common disadvantage of the known designs of inflatable packers is that their use does not provide the possibility of trouble-free extraction of submersible equipment from horizontal open-hole wells.

Known inflatable hydraulic packer (patent No. 2128279, publ. 03/27/1999), selected as an analogue. The device comprises a hollow barrel on which the sealing element is concentrically mounted and forms with it the main hydraulic cavity, consisting of the outer and inner elastic layers with a power cord and end supports located between them, a movable inner piston and a hydraulic cavity. A housing is concentrically placed on the hollow barrel, which, together with the sealing element, is fixed to the barrel by means of a nut and a support having longitudinal channels. The movable inner and outer pistons installed between the hollow barrel and the housing form hydraulic cavities with the housing and the inner sleeve: upper, middle, and lower. Radial channels are made on the trunk in the upper and lower hydraulic cavities.

A disadvantage of the known inflatable hydraulic packer is the lack of the possibility of: sampling or injecting process fluid into the reservoir, reinstalling the submersible equipment two or more times without extraction to the surface.

A sequential inflatable packer is known (patent CA 1217131, prior. 04/05/1984), taken as an analogue, in which the method of sequentially inflating packers from the bottom up is applied, which is achieved by controlling the flow rate of the inflation fluid in each packer: in the lower packer, the flow rate of the inflation fluid is significantly higher than in the overlying packer, which allows you to control the inflation time of each packer.

A disadvantage of the known sequential inflatable packer is the inability to: take samples or pump technological fluid into the reservoir, reinstall the submersible equipment two or more times without being removed to the surface, and the impossibility of trouble-free extraction of submersible equipment from horizontal open-hole wells.

A well-known inflatable hydraulic packer (patent No. 2155857, publ. September 10, 2000), selected as an analogue, comprising a housing, a sealing element mounted on it such as an elastic expanding sleeve, a hollow barrel and a main piston coaxially placed in the housing. They form a discharge hydraulic chamber. Between the body and the barrel, an external piston is mounted above the main piston. It forms an additional cavity with the main piston. This cavity through radial holes in the barrel communicates with the in-tube space. The barrel has the possibility of axial movement relative to the housing and the sealing element. There is a shoulder on the barrel to abut the main piston. A spring is mounted concentrically on the barrel, abutting against the body. The discharge chamber is filled with clean hydraulic fluid when assembling the packer. The additional cavity is filled with the working mixture of the well.

A disadvantage of the known inflatable hydraulic packer is the lack of the possibility of sampling or pumping process fluid into the reservoir, reinstalling the submersible equipment two or more times without extraction to the surface, and the impossibility of accidentally removing submersible equipment from horizontal open-hole wells.

Known inflatable packer with advanced elements (patent US 4923007, publ. 08.05.1990), taken as a prototype, containing the upper and lower heads of the packer, inflatable elastomeric sealing element, an outer tubular shell, radially covering the sealing element, and a number of overlapping metal reinforcing elements located in the annular space between the sealing sleeve element and the tubular shell of the packer. During the installation of the packer, the overlapping metal reinforcing elements can make a sliding movement relative to another overlapping metal reinforcing element, each of which has a locking element located between the heads of the packer and serving to limit the relative sliding movement to a predetermined value so that the gaps between the reinforcing elements are minimized or missing. The locking elements on the reinforcing elements can be stamped, and the recess stamped on one reinforcing element is made so that it includes a protrusion stamped on the adjacent reinforcing element, which allows to prevent further sliding movement of these elements with respect to each other.

A disadvantage of the known inflatable packer with advanced elements is the lack of the possibility of: sampling or injecting process fluid into the reservoir, reinstalling the submersible equipment two or more times without extraction to the surface. Another disadvantage is the mechanical destruction of the outer tubular shell in non-vertical, especially in horizontal open boreholes: the outer tubular fractured shell will not be able to squeeze the plate frame into its original transport position, which is why the frame elements when lifting, moving along the horizontal wellbore, collect large cuttings , which leads to jamming of the layout elements with the formation of emergency sticking and the subsequent need to eliminate the accident, requiring certain times ny and cash costs.

The problem solved by the invention is the acceleration of work on sampling fluid or pumping process fluid into the sub-packer and interpacker zones of the well during one tripping operation, ensuring the reinstallation of submersible equipment at other required intervals of the well two or more times without extraction to the surface, the availability of trouble-free lifting equipment at the wellhead from horizontal uncased wells.

The specified technical result is achieved by the fact that:

- assembly and descent of the submersible equipment is carried out in the following sequence: a plug, a full bore circulation valve with shear pins, a lower centralizer, an injection and bypass valve for the layout of inflatable packers (KZPKNP) subpacker, lower inflatable packer and inflation valve, an interpacker disconnector, KZPCNP interpacker inflatable packer and blow-off valve, upper centralizer, over-packer disconnector, circulation valve, at the beginning of the descent of the submersible equipment, inflatable packer blow-off valves, KZP The subpacker and interpacker NPs are in the closed position, when the pressure in the annulus exceeds the pressure in the tubing string, the KZPKNP bypass openings and interpacker openings are opened and the tubing string is filled with borehole fluid, thus the differential pressure is equalized, after which the KZPKNP bypass and the interpacker is automatically closed, then the pump unit is connected to the tubing string, then the first fluid supply is made, during which the KZPKN The injection and bypass openings are closed on the inter-packer and sub-packer, and create a pressure, for example 15 MPa, at which the lower and upper inflatable valves open respectively at the lower and upper inflatable packers, bringing the inflatable chambers into working position, then withstand immersion equipment under pressure, for example 18 , 5 MPa, for five minutes, then slowly carry out the first pressure relief: when a value of, for example, 15 MPa is reached, the inflatable valves close completely, the inflatable packers are put into working position and they overlap the wellbore at the first pressure release - in the KZPKNP sub-packer, the bypass openings can open, then fluid is taken from the sub-packer zone, during which the openings for pumping and bypass KZKNP of the inter-packer are closed, a second fluid supply is created and a constant pressure is created, for example 10 MPa, at which injection holes are opened in KZPKNP sub-packer, if necessary, process fluid is pumped into the sub-packer zone, during which closing The openings of the KZPKNP interspacker injection and bypass are removed, then a second pressure relief is performed, at which the openings of the KZPKNP interspacker have the opportunity to open the bypass holes, then the fluid is sampled from the interpacker zone, during which the holes for the injection and bypass of the KZPKNP are closed, the third fluid supply is performed and create a pressure at which injection holes open in KZPKNP interpacker, and injection and bypass holes are closed in KZKPNP subpacker, then carry out a third pressure relief, etc. and where the injection and bypass holes of both KZKPNP come to their original position;

- that at one descent into the well, depending on the number of specified intervals, the submersible equipment can be reinstalled two or more times without being removed to the surface.

Acceleration of fluid sampling or injection of reagents into the formation in the sub-packer and inter-packer zones of the well during one round-trip operation is provided by the presence of sub-packer and interpacker KZKNP, each of which has injection and bypass pistons that serve to open and close the injection and bypass holes, having the ability to occupy six positions, the switching of which is carried out by creating pressure in the tubing string and its subsequent discharge.

Ensuring the reinstallation of equipment at other intervals of the well two or more times without extraction to the surface is achieved thanks to the design of inflatable packers that can repeatedly move from the working position to transport, reinstall and overlap the required intervals of the wellbore.

The possibility of trouble-free lifting of equipment at the wellhead from horizontal uncased wells is achieved thanks to the technology used to extract the submersible equipment to the surface: if necessary, to re-set to a different interval, the upward axial load is applied to the submersible equipment, fixed and left in tension. The drop in load on the hook indicates the breakdown of inflatable packers. Further, the submersible equipment is left at rest, for example, for 10 minutes, so that the inner and outer elastic sleeves of the lower and upper inflatable packers fully accept the initial outer diameter, then the submersible equipment is slowly moved up to the next installation interval, and the circulation valve opens and fluid flows from the inner cavity of the tubing string into the annulus — the differential pressure is equalized when the desired int the movement distance is stopped and lowered down, for example by 100-300 mm, as a result of which the circulation valve closes, then the immersion equipment is fixed in the required interval.

In FIG. 1 shows a diagram of equipment for interval study of formations. In FIG. 2 shows a diagram of KZPKNP subpacker and interpacker. In FIG. 3 shows a diagram of an inflatable packer with an inflation valve in three positions: a - in the transport position when descending into the well; b - in the process of inflation; in - in transport position when lifting up. In FIG. 4 shows a scan of the grooves of KZPKNP subpacker. In FIG. Figure 5 shows a scan of the grooves of the KZPKNP interpacker. In FIG. 6 shows a diagram of the circulation valve: a - in the closed position; b - in the open position.

The equipment layout includes: a plug 1, a full bore circulation valve with shear pins (КЦПТС) 2, a lower centralizer 3, КЗПКНП sub-packer 4, lower inflatable packer 5 and a blower valve 6, interpacker disconnector 7, KZPCNP mezhpacker 8, upper and inflatable packer 9 pressurization 10, upper centralizer 11, overpack disconnector 12, circulation valve 13, tubing 14.

Above the plug 1 is installed KTSPTS 2, which serves to organize the communication of the internal cavity of the tubing 14 with the annulus.

The lower 3 and upper 11 centralizers located above the KSPTS 2 and the upper inflation valve 10, respectively, are designed to center the submersible equipment in the well.

KZPKNP subpacker 4 and interpacker 8 (Fig. 1), located under the lower inflatable 5 and upper inflatable 9 packers, respectively, consist of a housing 15 (Fig. 2, b), inside of which are located: an injection valve, consisting of a movable injection piston 16 ( Fig. 2, a), the upper spring 17 and the holes 18 (Fig. 2, c) injection, and the bypass valve, including a movable bypass piston 19 (Fig. 2, a), the lower spring 20 (Fig. 2, c) and hole 21 (Fig. 2, b) bypass.

The axial movement of the movable bypass piston 19 is limited by the end of the movable injection piston 16. The axial movement of the movable piston of injection 16 is limited by the fixed lock 22. On the rod 23 of the movable injection piston 16 are milled continuous grooves 24 that interact with the fixed lock 22 and allow the movable pistons of injection 16 to be occupied and bypass 19 six positions (Fig. 4, 5). KZPKNP subpacker 4 and interpacker 8 are used to pump the process fluid from the tubing string 14 into the annulus and transfer fluid from the annulus into the cavity of the tubing string 14.

The lower inflatable 5 and upper inflatable 9 packers (Fig. 1), which serve for interval overlapping of the wellbore, are located above the KZPKNP subpacker 4 and interpacker 8, respectively, have radial holes 25 (Fig. 3, b) in the inflation chambers 26, inner 27 ( Fig. 3, a) and outer 28 elastic sleeves with a metal plate frame 29 placed between them. The inner elastic sleeve 27 is hermetically attached to the stem 30 (Fig. 3, b) using a fixed sleeve 31 (Fig. 3, c), to which is connected to the housing 32 (Fig. 3, c) of the inflation valves 6, 10 (Fig. 1), and movable in tulki 33 (Fig. 3, a), into which the casing 34 is screwed (Fig. 3, c) with a return spring 35 placed in it (Fig. 3, a).

The lower 6 and upper 10 (Fig. 1) inflation valves located above the lower 5 and upper 9 inflatable packers, respectively, include a housing 32 (Fig. 2, c), a movable piston 36 (Fig. 2, b) with a spring 37. B the housing 32 is placed a movable sub 38 (Fig. 3, c) with a tapered thread 39 (Fig. 3, a).

The interpacker 7 (Fig. 1) and the overpacker 12 disconnector of the tubing string 14 located above the lower inflation valve 6 and the upper centralizer 11, respectively, if necessary, as well as during repairs, allow the tubing string 14 to be disconnected with the upstream equipment without killing the well.

Circulating valve 13 installed in the tubing 14 in the interval of the cased part of the well and including a stationary body 40 (Fig. 6, a), a movable body 41 with a casing 42 (Fig. 6, b), equipped with straps 43 (Fig. 6, a) on retractable springs 44, it opens when the tubing string 14 moves upward, due to which fluid flows from the inner cavity of the tubing string 14 into the annulus — pressure differential is balanced.

The implementation of the method is described in the description of the equipment for the interval study of formations.

Before the descent of the equipment, a well is modeled (not shown in the drawing). The equipment is assembled in the following sequence: plug 1 (Fig. 1), KTSPTS 2, lower centralizer 3, KZPKNP sub-packer 4, lower inflatable packer 5 and inflator valve 6, disconnector mezhpakerny 7, KZKPNP super-packer 8, upper inflatable packer 9 and inflation valve 10 , top centralizer 11, switch disconnector 12, circulation valve 13.

Then make the descent of the equipment on the tubing string 14 (Fig. 1) to the bottom. At the beginning of the descent process, the lower 6 and upper 10 pressurization valves of the packers, KZPKNP subpacker 4 and interpacker 8 are in the closed position. When the pressure in the annulus exceeds the pressure in the tubing string 14, the openings of the bypass 21 (Fig. 2, b) KZKNPP of the subpacker 4 and interpacker 8 open and the tubing string 14 is filled with borehole fluid. Thus, the differential pressure is equalized, after which the bypass openings 21 KZKPNP subpacker 4 and interpacker 8 are automatically closed.

Next, a pumping unit (not shown) is connected to the inner cavity of the tubing string 14, the first fluid supply is made and pressure is created, for example 15 MPa, under which the lower 6 and upper 10 inflation valves open at the lower 5 and upper 9 inflatable packers, respectively. bringing the inflatable chambers 26 into operation (Fig. 3, b), then withstand submersible equipment under pressure, for example 18.5 MPa, for five minutes, then slowly carry out the first pressure release: when a value is reached, for example 15 MPa, lower 6 ( Fig. 1) and the upper 10 inflation valves are completely closed, the lower 5 and upper 9 inflatable packers are moved to the working position and block the wellbore interval.

When the liquid was first supplied and the pressure was created, the movable injection pistons (Fig. 2, a) and the bypass 19 move from position a (Fig. 4, 5) to position b, while in both KZKNP injection holes 18 (Fig. 2, c) and bypass 21 (Fig. 2, b) are closed. The lower 5 and upper 9 inflatable packers are transferred from the transport position to the working one.

Then carry out the first pressure relief. The movable injection pistons 16 (Fig. 2, a) and bypass 19 pass in both KZKNPP in position in (Fig. 4, 5). At the same time, in the KZPKNP subpacker 4 have the opportunity to open the bypass holes 21, through which the fluid is sampled from the subpacker zone, during which the holes of the bypass 18 and the injection 21 of the KZPKNP interpacker 8 are closed.

A second fluid supply is made and a constant pressure is created, for example, 10 MPa, at which the movable injection pistons 16 and bypass 19 go into position g (Figs. 4, 5). At the same time, injection holes 18 (Fig. 2, c) are opened in KZPKNP sub-packer 4 (Fig. 1), through which, if necessary, the process fluid is pumped into the sub-packer zone, during which the injection holes 18 and bypass port 21 of KZKPNP mezhpakerny 8 are closed.

Next, produce a second pressure relief. The movable injection pistons 16 and bypass 19 at both of the KZPKNP go to position D. At the same time, bypass ports 21 can be opened in the KZKNP interpacker 8, through which the fluid is sampled from the interpacker zone, during which the pumping holes 18 and bypass 21 of the KZPKN are closed four.

A third fluid supply is made and a pressure is created at which the movable injection pistons 16 and bypass 19 in both KZKNPP move to position e. In this case, injection holes 18 are opened in KZKNP interpacker 8, and injection holes 18 and bypass 21 are closed in KZKNPP subpacker 4.

With the third pressure relief, the movable injection pistons 16 and bypass 19 at both KZPNPPs return to their original position.

If it is necessary to reset to a different interval, an axial load directed upward is applied to the submersible equipment, fixed and left in a taut state. The load drop on the hook (not shown in the drawing) indicates the breakdown of inflatable packers. Further, the submersible equipment is left at rest, for example, for 10 minutes, so that the inner 27 (Fig. 3, a) and 28 outer elastic sleeves of the lower 5 (Fig. 1) and upper 9 inflatable packers fully accept the initial outer diameter, then they slowly move the submersible equipment up to the next installation interval, while the circulation valve 13 opens and fluid flows from the inner cavity of the tubing string 13 into the annulus — pressure differential is balanced, etc. achieving the desired interval movement is stopped and lowered downwards, for example 100-300 mm, whereby the circulating valve 13 is closed, submersible equipment then fixed in the desired range.

To extract the submersible equipment, a pressure is supplied, for example, 22 MPa, at which the pins (not shown) of the CPCTS 2 are cut, which leads to the communication of the inner cavity of the tubing 14 with the annulus. Next, the lower 5 and upper 9 inflatable packers are disrupted in the above sequence.

The claimed invention allows to accelerate the work of sampling fluid or pumping process fluid into the sub-packer and inter-packer zones of the well during one tripping operation, to ensure the reinstallation of submersible equipment for interval study of formations at the required intervals of the well two or more times without extraction to the surface, to ensure trouble-free rise equipment at the wellhead from horizontal open-hole wells.

Claims (2)

1. A method for studying the parameters of formations in pipes, including the descent into the well to the bottom or the specified depth of the submersible equipment, consisting of a string of tubing, upper and lower inflatable packers having radial openings in the pressurization chambers, external and internal sleeves with a metal plate frame placed between them, the lower and upper inflatable packers are transferred from the transport position to the working position, characterized in that the assembly and lowering of the submersible equipment is carried out in of the following sequence: a plug, a full bore circulation valve with shear pins, a lower centralizer, an inflatable packer injection and transfer valve (KZKNP), an underpacker, a lower inflatable packer and an inflatable valve, an interpacker disconnector, a KZPKNP interpacker, an upper inflatable packer and an upper inflatable packer , disconnector nadpakerny, circulation valve, at the beginning of the descent of the submersible equipment valves inflatable inflatable packers, KZPKNP subpacker and interpacker are in a closed position In case of excess of pressure in the annulus above the pressure in the tubing string, the openings of the KZPKNP subpacker and interpacker bypass open and the tubing string is filled with borehole fluid, thus the differential pressure is equalized, after which the openings of the KZKNP bypasser and interpacker are automatically closed, then to the tubing string the pump unit is connected, then the first fluid supply is made, during which the injection openings are closed at KZPCNP of the interpacker and subpacker bypass, and create a pressure at which the lower and upper inflatable packers open at the lower and upper inflatable packers, respectively, bringing the inflatable chambers into working position, then hold the submersible equipment under pressure for five minutes, then slowly carry out the first pressure relief: upon reaching the inflatable valves are fully closed, the inflatable packers are put into working position and block the wellbore interval, at the first pressure release in KZKPNP sub-packer they can l open the bypass openings, then carry out the selection of fluid from the sub-packer zone, during which the openings of the injection and bypass of the KZPKNP interpacker are closed, produce a second fluid supply and create a constant pressure at which the pumping holes open in the KZKPNP sub-packer, if necessary, pump the process fluid into the under-packer zone, during which the openings for pumping and bypassing the KZPKNP are closed, then a second pressure relief is performed, at which the core can open the bypass holes, then fluid is sampled from the interpacker zone, during which the pumping and pumping bypass holes of the subpacker are closed, the third fluid supply is performed and the pressure is created at which the injection holes are opened in the KZPKNP interpacker, and the holes are closed in the KZPKNP subpacker injection and bypass, then carry out a third pressure relief, at which the injection and bypass holes of both KZKPNP come to their original position. 2. Equipment for studying the parameters of reservoirs on pipes, including a plug, a full bore circulation valve with shear pins (KTSPTS), a lower centralizer, an inflatable packer injection and transfer bypass valve (KZPKNP), sub-packer, lower inflatable packer and an inflation valve, interpacker disconnector, KZZN interpacker, upper inflatable packer and pressurization valve, upper centralizer, overpack disconnector, circulation valve, tubing, characterized in that KTSPTS is installed above the plug, lower and upper centralizers They are located above the KSPTS and the upper inflation valve, respectively, KZPKNP subpacker and interpacker are located under the lower inflatable and upper inflatable packers, respectively, and consist of a housing inside which are located: an injection valve, consisting of a movable injection piston, an upper spring and injection holes, and a bypass valve, which includes a movable bypass piston, a lower spring and a bypass hole, the axial movement of the movable bypass piston is limited by the end of the movable injection piston, the axial movement of the movable piston beyond The tabs are limited by a fixed clamp, profile grooves of continuous movement are milled on the rod of the movable injection piston, made to interact with the fixed clamp, and allow six positions to be occupied by the movable pistons of injection and bypass, the interpacker and overpacker disconnectors of the tubing string are located above the lower inflation valve and the upper centralizer, respectively and made with the possibility of disconnecting the tubing string, the circulation valve is made with the possibility of opening when the tubing string is screwed .

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