Unit of inflatable packer and method of development of packers pair in well

FIELD: oil and gas industry.

SUBSTANCE: group of inventions relates to packers used during sampling of strata fluid medium and includes method of sampling and device for its implementation. Unit of inflatable packer contains one extensible tubular member with couple of annular dead-end poles, herewith one of supports is movable and the other is fixed on mandrel. Also at this packer it is annular fixing unit, developed from one of dead-end poles for reinforcement of tubular member during creation in it of pressure and its extension. Annular fixing unit contains multitude of plates, pivotally connected to support. Unit can contain the second similar extensible tubular member and the second annular fixing unit. Unit can contain between tubular members centraliser. Movable dead-end pole can allow directed inside surface, area of which increases area of directed outside surface. Method of development of couple of inflatable packers includes creation of pressure in packers, sampling of medium in interpacker space, pressure release for replacement of packers' unit, restriction of packer deformation at stage of pressure creation with usage of annular fixing unit.

EFFECT: reliability growth and increasing of durability of inflatable packers, simplification of process of its pacling and transaportation.

12 cl, 12 dwg

 

1. The technical field to which the invention relates.

The present invention relates to inflatable packers are used during downhole operations, in particular to inflatable packers, adapted for use when sampling reservoir fluid.

2. Description of the prior art,

When an oil well is drilled, the operator is often necessary to obtain data on downhole conditions, such as the results of pressure measurements and sampling data of the reservoir of fluid for analysis. These tasks are usually carried out by means of downhole tools, such as modular tools lowered into the well on a pulley rope, or drilling tools with evaluation capabilities, using probes for assaying breed and establish the movement of fluid for the measurement of pressure and sample of the downhole fluid. Fluid typically absorbed in the downhole tool through the inlet probe. In some cases, related to dense rocks with low permeability, probes for sampling is often replaced by a node with two inflatable packers. Examples of such systems with probe and packer described, for example, in U.S. patent No. 4860581 and 4936139 owned by Schlumberger.

On figa-1B schematically shows a typical configuration with the two packer elements 10 in their respective lowered and the pressurized state. Packer elements 10 are from each other along the downhole tool 12, a floating pulley rope 14 in the bore 18 of the borehole through a subterranean formation 20. Although the illustrated tool, the descent into the well on a rope, suitable for such purposes other downhole tools, lowered the drillstring, pipe coils, etc. When the packer elements 10 are inflated, they interact to seal or insulating section 16 of the wall 18 of the wellbore in such a way as to facilitate the flow of fluid from the surrounding formation (layers).

When inflating the packer elements (typically made of rubber) their ends often experience large deformation and Flexural stresses, which can lead to a circular rupture and failure of the system. In addition, because often the trunks of the wells are exposed to high temperatures, especially at great depths, the packer elements are often exposed to significant thermal stresses.

Attempts were made to prevent damage to the packer. Accordingly, the inflatable packer section or elements are often provided with reinforcing elements in the form of metal cords or plates. Although these reinforcing elements can be used to increase the lifetime of the packer elements, the reinforcing elements may machining is being plastic deformation and to prevent unwanted swelling (as shown in FIGU-1C) under the influence of strong stresses, when the packer element is inflated and comes in contact with the wall 18 of the high-temperature borehole. In addition, the reinforcing elements (i.e. metal plates or cords) may have limited strength, and elastic material of the packer element, typically rubber, may decrease with increasing temperature. The resulting deformation can be fatal and, thus, will prevent the return of the packer elements within the required diameter after sampling. In other words, the packers may be unable to successfully recover the profile shown in figa. Thus, the operation of these so-called "plate packers" there is an increased risk of getting stuck in the wellbore.

Despite the advances in technology create the packers still need to obtain packer with a long service life in severe operating conditions in the well. It is desirable that such a packer restricted or restrained deformation, which the packer is subjected in the course of work in the wellbore, thus, to achieve a more "moderate" profile in the inflated state (for example, excluding the receipt of expanded profile shown in FIGU-1C) and, thus, to increase the service life of the packer. Preferably this solution could be the lighting is for use with known packer buildings or elements. It is also desirable that the packers returned to their original configuration (shown in figa) thus, to reduce the probability of jamming of the downhole tool in the wellbore. Preferably according to this solution to achieve the necessary return to the original configuration and balance of the loads applied to each of the packers downhole tool could have been used for the ambient pressure of the downhole fluid.

Another problem that occurs with nodes dual packers, refers to the axial distance between the packer elements. Increasing this distance, for example, to increase the isolated area of a wall of a wellbore in a typical case, increasing the risk of bending of the trunk, which divides the packers. Accordingly there is a need for solving the bending sites posted by the two packers.

Definition

Some of the terms defined in this description as used before, while some other terms used in this description are defined below.

"Deployed" means moved from one position or configuration to another position or configuration, in particular, through the expansion or deployment.

"Turned inward" means facing toward the center or the middle of the pre is meta or group of items (for example, facing toward the center of the packer).

"Lower" means located deeper in the wellbore (for example, the lower end bearing packer having two end supports).

"Frame" means a rod, shaft, spindle or the tubular element around which are collected or held other components, in particular, to perform one or more operations in the wellbore.

"External" means situated or located physically at a point or on the boundary.

"Turned out" means facing outwards from the center or middle of a subject or group of subjects (e.g., facing outwards from the center of the packer).

"Top" means located at a lesser depth within the wellbore (for example, the upper packer configuration with two packers).

The invention

According to the invention created node inflatable packer, containing the first expandable tubular element having a pair of ends, a first pair of annular end supports for securing the respective ends of the first tubular element relative to the mandrel located in the first tubular element, with one of the end supports is movable and the other end bearing fixed relative to the mandrel, and the first annular fixing node deployed from one of the end supports for the amplification of the first tubular element is as if the creation of the pressure and its extension, pivotally connected to one of its ends with one of the end supports for the amplification of the first tubular element in the creation of pressure and its extension, is able to expand to the other end and containing a number of plates arranged in an annular configuration, pivotally connected by one end with the movable end support and having each a width increasing from its hinged end to the other end.

The node may further comprise a first locking element to limit axial movement of the movable end support.

The node may further comprise a second expandable tubular element having a pair of ends, a second pair of annular end supports for securing the respective ends of the second tubular element relative to the mandrel, and the first and second pairs of end supports interact to set the axial distance between the first and second tubular elements, and a second annular mounting site, pivotally connected to one of its ends with one of the end supports for the amplification of the second tubular element in the creation of pressure and its extension.

The node may further comprise an expandable centralizer mounted on the mandrel at a distance in the axial direction from the first and second tubular elements and between them for soprotivlyajsya mandrel. The centralizer may include a pair of supports mounted on the mandrel, one of which is able to move axially along the mandrel, a multitude of pairs of pivotally connected levers, the levers of each pair having first ends pivotally connected to the respective supports, and second ends pivotally connected to each other, and the actuator mounted on the mandrel, for the message of the axial movement of each moveable support so that the hinge connected to the second ends of each pair of levers are able to move radially outward, applying force to the borehole wall, which is essentially centers the mandrel in the well.

The node may further comprise a set of spring leaves, each of which has its ends pivotally connected to the respective supports so that the spring leaves are arranged between the respective pairs of hinge arms and the wall of the well bore, and spring leaves and pivot levers interact for the application of forces to the wall of the wellbore, which essentially center the mandrel in the well.

The centralizer may contain three pairs of articulated levers, spaced essentially evenly spaced around the circumference of the mandrel.

End bearing may be facing the inside surface area of which exceeds the area facing outward surface, the result is what the downhole pressure of the fluid exerts a resultant force, moving the movable end support to the outside when the pressure relief in the first tubular element and its reduction.

According to the invention results from the deployment method of the pair located at a distance from each other inflatable packers installed on the mandrel, located in a borehole traversing a subterranean formation containing the following steps:

creating pressure in the packers to isolate the annular side wall of the wellbore;

the selection of one or more samples of the reservoir fluid in an isolated part of the wall of the wellbore;

the pressure in the packers to move the mandrel in the borehole;

limit deformation of the packers at the stage of creating pressure using the ring fixing node

each packer includes an expandable tubular element having a pair of ends and a first pair of annular end supports for securing the respective ends of the tubular element relative to the mandrel, with one of the end supports is movable and the other end bearing fixed relative to the mandrel, and a movable end support is provided inward facing surface having an area greater than the area facing outward surface, the pressure of the downhole fluid exerts a resultant force that moves the movable limit the Yu prop out when removing the pressure in the tubular element and its reduction.

The method may further comprise limiting the deformation of each packer using mechanical stopper member that restricts the movement of the mobile tail support.

The method may further comprise the step of actively reducing packers using the ambient pressure in the well bore, attached to the movable end supports.

The method may further comprise essentially centering the mandrel between the packer to create resistance to the bending mandrel.

Other objects and advantages of the invention will be understood when reading the following description and the appended claims.

Brief description of drawings

To make the above features and advantages of the present invention can be understood in detail, more particular description of the invention briefly described above can be found with links to options for its implementation, which is shown in the accompanying drawings. However, it should be noted that the appended drawings illustrate only typical embodiments of the present invention and, thus, should not be construed as limiting its scope, the invention may admit to other equally effective ways of its implementation.

Figa depicts a schematic view from usaimage traveling on the rope known downhole tool, equipped with a pair of inflatable packers.

Figw - view of the downhole tool shown in figa, with inflated packers subjected to swelling on the sides of low pressure.

Figs - detailed view of the upper packer shown in figv.

Figure 2-3 depict schematic views of a known descent on the pulley rope downhole tool that can be used in the present invention to obtain the advantages.

Figa depicts a view of the downhole tool, equipped with inflatable packer ring and the mounting site.

Figw - view of the downhole tool shown in figa, with the inflated packer and advanced ring mounting unit for resistance to swelling packer.

Figa - partial view of a section made along the line 5A-5A in figa.

Figw - partial view of a section made along the line 5B-5B in figv.

Figs - partial view of a section made along the line 5C-5C in figv.

Figa - view portion of the inflatable packer of the first alternative mounting ring node.

Figw - view of the packer shown in figa, in the inflated condition and the first alternative mounting ring node in extended condition for resistance to swelling packer.

Figa - view portion of the inflatable packer and a second mounting ring node.

Figw - type p is Kera, shown in figa, in inflated condition and a second mounting ring node in the expanded condition to resist swelling packer.

Figa - view portion of the inflatable packer and the third alternative mounting ring node.

Figw - view of the packer shown in figa, in inflated condition, and the third alternative mounting ring node in the expanded condition to resist swelling packer.

Figure 9 - view of the node contraction of the packer.

Figa - type annular mounting site shown in figa-4V, and node contraction of the packer shown in Fig.9, applied with inflatable packer.

Figw - view of the packer shown in figa, in inflated condition and mounting ring node in the expanded condition to resist swelling packer.

11 is a view of the tool, turn on the pulley rope having a knot with a pair of packers, provided with a centralizer for resistance to bending of the tool, located between the packers.

Fig - view of the downhole tool, equipped with a pair of inflatable packers, each of which has a node contraction of the packer shown in Fig.9, with the upper packer inverted so that the low pressure both relevant packers recorded, and the downhole tool is also equipped with alternatives, the first centralizer, different from the shown figure 11.

Detailed description of the invention

Figure 2 and 3 schematically illustrates an example device in which with advantage can be used in the present invention. You can use other downhole tools, such as drilling, pipe coils, to complete the well or other tools. Device And is a downhole tool that can be lowered into the wellbore (not shown) traveling on a rope (not shown) to study characteristics of the layer. The device As described in more detail in U.S. patent No. 4860581 and 4936139, assigned Schlumberger. For informational purposes here are some details of the device. The cable connection to the instrument And and electronic media related to the power supply and connection, not shown for clarity. Power and communication lines that pass through the entire length of the tool, shown in General by the reference position 208. These components for power supply and communication of well-known experts in the field of technology and was already in commercial use. The control equipment of this type is usually mounted in the upper end of the tool near the connection of pulley rope with the instrument, and electrical lines pass through the tool to various components.

In the variant shown in figure 2, the device And has a hydraulic power module C, packer module P and the measuring module E. Measuring unit E shown with one measurement node 210, which can be used for permeability studies or sampling the fluid. When using the tool to determine anisotropically permeability and structure of the manifold vertically according to known technologies to the measuring module E can be added multipoint sampling module F, as shown in figure 2. Multipoint measurement module F has nodes 212 and 214 to research by way of the test pumping. Can also be used by other modules L, D.

The hydraulic power module includes a pump 216, the reservoir 218 and the motor 220 to control the operation of the pump 216. Low-oil switch 222 also forms part of the control system and used to control operation of the pump 216.

Line 224 to supply the working fluid is connected to the discharge opening of the pump 216 and passes through the hydraulic power module and the adjacent module to use as the source of hydraulic power. In the variant shown in figure 2, line 224 to supply the working fluid passes through the hydraulic power module into the measuring modules E and/or F depending on what uses the I configuration. The hydraulic circuit is closed through return line 226 to the working fluid, which in figure 2 passes from the measuring module E back into the hydraulic power module, where it terminates at the reservoir 218.

Module M pumping (figure 3) can be used to remove unwanted samples by pumping the fluid through the waste pipe 254 in the well bore or may be used to pump fluid from the wellbore into the waste pipe 254 for inflating double inflatable packers (also known as a dual packers) 288 and 230. In addition, a suction module M can be used for the suction formation fluid from the wellbore through the measuring module E or F and then to pump formation fluid in the module's selected camera with overcoming the pressure contained in the buffer fluid. Reciprocating pump 292, driven by the working fluid coming from the pump 291, may be aligned so that it is sucked from the hydraulic line 254 and dumped unwanted sample through a hydraulic line 295, or it can be aligned in such a way as to suck the fluid from the wellbore through the hydraulic line 295) in the hydraulic line 254. The pumping module can also be confit is wirawan, when the hydraulic line 295 is connected with a hydraulic line 254, in such a way that fluid can be sucked from the bottom of the hydraulic lines 254 and injected into the upper part or Vice versa.

Module M pumping has the necessary control devices for regulating piston pump 292 and combine hydraulic line 254 with a hydraulic line 295 for pumping. It should be noted that the piston pump 292 can be used for suction of samples in the module (s) selected cameras, including the creation of excess pressure in such samples, if needed, as well as for pumping a sampling module (s) selected camera using the module M pumping. Module M pumping can also be used to effect the discharge with constant pressure and flow rate, if necessary. When sufficient power module M pumping can be used to discharge the fluid with high costs, allowing you to create cracks in the reservoir to measure the voltage.

In an alternative embodiment, the dual inflatable packers 228 and 230, as shown in figure 2, can swell the downhole fluid medium and to deflate using a piston pump 292. As you can see, the selective actuation module M Tkacheva the I to activate piston pump 292, combined with selective operation of the valve 296 control, and pumping and lowering of the valve I may cause selective inflation or lowering packers 228 and 230. Packers 228 and 230 mounted on the outer peripheral surface 232 of the device and have the buildings or elements, which are typically made of flexible material that is compatible with the downhole fluid environments and temperatures in the borehole. Packer elements are installed in such a way that the packers 228 and 230 are located in their cavity. When piston pump 292 is open and the valve of the first pump is installed in the proper position, fluid from the hydraulic line 254 passes through the valves of the first inflation/lower and hydraulic line 238 to the packers 228 and 230.

After inflating packers 228 and 230 and the job of installation of the transmitter 210 and/or probes 212 and 214, you can begin your research by way of the test pumping. Hydraulic line 254 for the sample passes from the probe 246 measuring module E down to the outer peripheral surface 232 at a point between the packers 228 and 230 through adjacent modules and modules S for sampling. Vertical probe 210 and the transmitter 214 for research by way of the test pumping, thus, miss the downhole fluids in a hydraulic line 254 to the sample via one or more sensors 256 resistivity measurements, give the TWT 258 and pressure measurement mechanism 259 preliminary tests in accordance with the required configuration. In addition, the hydraulic line 264 allows the passage of the downhole fluid in the hydraulic line 254 sampling. When you use a module or set of modules E and F stop valve 262 set after sensor 256 resistivity. In the closed position, the stop valve 262 limits the internal volume of the hydraulic lines, improving the accuracy of dynamic measurements performed by the sensor 258 pressure. After you have completed the initial pressure test, the stop valve 262 may be opened to flow to other modules in the hydraulic line 254.

The module's selected camera can then be used for sampling fluid filed under hydraulic lines 254 and adjusted module N flow control, which gives an advantage, but is not necessary for sampling fluid. Referring first to the upper module's selected camera is shown in figure 3, note that the valve 280 is opened, and the valves 262, A and B held closed, resulting in the formation fluid is directed through hydraulic line 254 in the cavity C for accumulation of the sample in the chamber 284 of the module's selected camera, after which the valve 280 is closed to isolate the sample. Luggage 284 has a cavity C for accumulation of the sample and the cavity R high pressure/buffer cavity. For the em tool can be moved to another location, and the process can be repeated. Now will be described the specific objects of the present invention finds use with downhole tools, such as described above tool A. On figa-4B shows a portion of the downhole tool 400 with node 410 inflatable packers. Although such packer nodes are typically equipped with pairs of sealing elements, here shown only one packer element 412 with the corresponding fixing node 426 for ease and clarity of description. Specialists in the art will understand that a single packer elements are separate application in some embodiments of the application separately from the configurations of the dual packer. On figa shows the packer element 412 in a deflated condition for lowering into the well bore 418 and rise from it, while figv shows the packer element 412 in the pressurized state and the annular fixing node 426 nominated to prevent swelling packer element.

The node 410 inflatable packer includes expanding a tubular packer element 412 having a pair of ends 414, 416 and the first pair of annular end supports 420, 422, having corresponding flat annular cutouts 419, 421 for fixing the respective ends 414, 416 of the first tubular packer element 412 relative to the mandrel 424, at least partially located inside the PE the first tubular packer element 412. Lower end bearing 422 mobile, and the upper end bearing 420 is fixed relative to the mandrel 424. Alternatively, the top and bottom end bearing can be locked (not shown) provided that the packer element 412 has a suitable design to provide additional elastic deformation.

The first annular fixing node 426 can be deployed from the lower end of a support 422, being pivotally connected by one of its ends 430 with the lower end of the support 422, for amplification of the first tubular packer element 412 with the creation of the pressure and its extension (i.e. pumping). Specialists in the art it will be clear that to obtain the advantages you can use other methods of deployment (for example, moving the translational motion). The annular fastening element 426 operates as an external mechanical support for the tubular packer element 412 and effectively closes the gap between the end support 422 (which is made of metal) and the barrel wall 418 of the well. It acts to eliminate the need for mechanical strength flexible packer element 412 for holding itself (for example, by using a reinforcing inserts, such as inserts). The fastening element provides support to facilitate the formation of the tubular packer element is m 412 seal between the wall 418 of the well bore and the mandrel 424.

The first annular fixing node 426 may expand its end 432 opposite to the pivotally attached end of the 430, so the node 426 takes the form of a truncated cone when the pumping tubular packer element 412 (see figv). Packer node may include a second mounting ring node 428, pivotally connected to the end 429 with the upper end of the support 420 for additional amplification of the first tubular packer element in the creation of pressure and its extension (i.e. pumping). Although this variant embodiment of the invention shown using two mounting ring nodes 426, 428, specialists in the art it will be clear that to obtain the advantages can be used one such node. In the latter case one mounting ring node will typically be located on the low pressure side of the tubular packer element 412 (e.g., on the side exposed to the reduced pressure at the site for sampling fluid with two packers), because this side is more likely prone to swelling and subsequent deformation than the high pressure side (i.e. the side exposed to ambient pressure in the wellbore) tubular packer element.

In different versions of the annular mounting site can be used is the substance of many of the plates or plates, located in an annular configuration and is pivotally connected, at least one of their ends to the movable end support and/or with a fixed end support. On figa shows a partial view of a cross section along the line 5A-5A in figa many plates 434, included in the first annular fixing node 426. Plate 434 is shown as having a stepped configuration in cross-section, in which each of the two plate sections 436, 438 slightly curved to follow the curved perimeter of the tubular packer element 412, and oriented radially jumper 440 connects the plate sections 436, 438. This design easily ensures that adjacent plates 434 overlap and together form a circular mounting node 426. However, specialists in the art it will be clear that with the receipt of benefits may be used other more simple configuration of the cross section (for example, one plate section).

On FIGU shows a partial cross-section of the annular fixing node 426 in the inflated position, made along the line 5B-5B in figv. On figs similarly shows a partial view of a cross section of the annular fastening element 426 in the inflated position, made along the line 5C-5C in figv. Thus, as shown in figv, it is preferable that each of the plates 434 kalasiris, increasing from its articulated end 430 to its other, extended end 432, although such a profile width is not necessary. In addition, the configuration with overlapping plates designed to fit to the nomination ends 432 in contact with the wall 418 of the wellbore with the permanent preservation of at least a partial overlap between adjacent plates 434. This ensures that the tubular packer element 412 is fully supported throughout its area, which otherwise could swell and be subjected to plastic deformation, as shown in FIGU-1C.

Thus, inflating the tubular packer element 412 causes an increase in the external diameter of the element of diameter D1up to a diameter D2as shown in figa-4B, 5A and (especially) 5C. This inflation occurs by injection of the surrounding borehole fluid into the cavity 441 tubular packer element 412 as is well known to experts in the art and as described to some extent in relation to the downhole tool As shown above in figure 2-3. Tubular packer element 412 descend through the issuance of downhole fluid contained in the cavity 441, back in the wellbore, as well known to specialists in this field of technology.

For sod is istia to restore the original position of the annular mounting hub and the tubular packer element 412, shown in figa, when the tubular packer element 412 is lowered, use one or more spring couplers 442, each of which has an appropriate spring stiffness. Each spring plate 442 has ends connected to one or more plates 434 and the lower end support 422, and under pumping tubular packer element 412 (see figv) they bend in the position in which the spring stiffness of the tie carries the packer element 412 in its shortened position.

On figa-6B shows a part of a node 610 inflatable packer, which is located in the trunk 618 wells, and consistent deployment of alternative mounting ring node 626. On figa shown mounting ring node in the lowered position of the packer, and figv shown mounting ring node in the extended position. As in the variant shown in figa-4B, the tubular packer element 612 has a pair of ends (shown only end 616) and the first pair of annular end supports (shown only end bearing 622)having corresponding flat annular notch (shown only flat circular neckline 621) for securing the respective ends of the first tubular packer element 612 relative to the mandrel 624, at least partially located inside the first tubular packer element 612. The lower angle connector 622 is movable and the upper end is a first bearing (not shown) fixed relative to the frame 624.

Packer node 610 works fine from packer node 410, described above, in particular, how the ring mounting node 626 is deployed out from the end support 622. Thus, the annular mounting site contains many plates 634 installed with the possibility of moving the translational motion in the many relevant channels 635 formed in end supports 622. The working fluid is served by one or more hydraulic lines 633 of the mandrel 624 known method (for example, when the control of pumps and valves, located in the trunk 624 or in the working position connected with him) so as to cause coordinated movement of the plates 634 between the retracted position while running in the hole shown on figa, and extended mounting position shown in figv. Channels 635 preferably interconnected with the message on the liquid so that the pressure increase and the pressure in them is at the same time.

On figa-7B shows a part of a node 710 inflatable packers and consistent deployment of alternative mounting ring node 726. On figa shown mounting ring node in the retracted position, and figv shown mounting ring node in the extended position. Just as shown in figa-4B, the tubular packer element 712 has a pair of ends (indicated telkomnet 716) and the first pair of annular end supports (indicated only end bearing 722), having corresponding flat ring (indicated only flat ring 721) for securing the respective ends of the first tubular packer element 712 relative to the mandrel 724, at least partially located inside the first tubular packer element 712. Lower end bearing 722 movable and the upper end bearing (not labeled) fixed relative to the frame 724.

Packer node 710 works like packer node 410, described above, except as packer node 710 is removed in its position for lowering into the well when the released position of the tubular packer element 712. In particular, the spring plate 442 of the above described variants of the invention, replaced by a sliding sleeve 742, which moves down (for example, when the control of pumps and valves, located in the mandrel 724 or in the working position United with him in a lower position to allow extension of the tubular packer element 712 and extension outer ends 732 plates 734, which essentially form the annular mounting the node 726 shown in figv. When lowering the tubular packer element 712 sleeve 742 is moved upward to help reduce the tubular packer element 712 and cleaning the mounting ring node 726.

On figa-8B shows a portion of the inflatable packer node 810 and is using serial deployment of another alternative mounting ring node 826. On figa shown packer node 810 in a shortened position, and figv shown packer node 810 in the pressurized position in contact with the wall 818 wellbore. Like shown in figa-4B and 7A-7B, a tubular packer element 812 has a pair of ends (indicated by only one end 816) and the first pair of annular end supports (indicated only end bearing 822)having corresponding flat annular notch (indicated only flat circular neckline 821) for fastening the respective ends of the first tubular packer element 812 relative to the mandrel 824 at least partially located inside the first tubular packer element 812. Lower end bearing 822 mobile, and the upper end bearing 820 is fixed relative to the mandrel 824.

Packer node 810 works like packer nodes 410 and 710 described above, except as the end 830 annular mounting site pivotally connected to the lower end support 822 and how packer node 810 is reduced in its position for lowering into the well when the released position of the tubular packer element 812. Thus, the end 830 annular fixing node 826 forms a flange, which is tightly seated in the recess 821r lower end bearing 822.

In addition, the spring plate 442 and the sleeve 742 of the above-described embodiments of the invention replaced the binder material is Yalom 842, applied between the tubular packer element 812 and plates 834, which essentially comprise an annular mounting node 826. Accordingly, the plate 834 follow tubular packer element 812 during its movement in short deflated state to descend into the well, shown in figa. Specialists in the art will understand that the linking plates 834 with a tubular packer element 812 using a binder material 842 creates a tensile force in a tubular packer element 812 when it is pumping, which seeks to reject the item back in its position for lowering into the well, thus contributing to the reduction packer node 810 when it is blowing.

Although embodiments of the packer site, shown in figa-8B, it is shown as having only one tubular packer element, in a typical configuration of such packer nodes, use a pair of packer elements related to each other along the mandrel. Accordingly packer node may further include a second extending tubular packer element (not shown in these drawings)having a pair of ends and a second pair of annular end supports (not shown in these drawings) for securing the respective ends of the second tubular packer element relative to the mandrel. In a typical embodiment, one of the second PA the s end of the supports can be moved, and the other end bearing fixed relative to the stem. The first and second pairs of end supports interact to set the distance of displacement in the axial direction (similar to a distance of 16 explode shown in figv) between the first and second tubular packer elements. The second annular mounting site pivotally attached to one of its ends to one of the second pair of end supports for reinforcing the second tubular packer element in the creation of pressure and its extension.

Figure 9 shows the node 910 reduction of the packer. This node contraction of the packer in a typical case can be used in configuration with a pair of inflatable packers, such as described here, and in this case, figure 9 shows the lower end portion of each packer element in configuration with a pair of packers. Node 910 inflatable packer includes an expandable tubular packer element 912 having a pair of ends (one denoted by the reference position 916), and a pair of annular end supports 922 (shown only last for fastening the respective ends of the tubular packer element 912 (e.g., by means of mating threaded connections 916t and 922t) relative to the mandrel 924 at least partially located inside the first tubular packer element 912. Lower end bearing 922 movable and the upper end bearing (not until the Ana) fixed relative to the frame 924. Movable end bearing 922 provided with the inward facing surface (A1+A2), the area of which is preferably greater than the area facing outward surface And3, resulting in the pressure of the surrounding borehole fluid (which affects these surface) creates a resultant force, which moves the movable end support to the outside (i.e. down in the case of the lower end support 922), when the tubular packer element 912 depressurized and he shrinks (i.e. blown).

Figure 9 shows the bottom end bearing 922 in its lower position before sliding up under pumping packer. As noted, reducing power (pointing down), acting on the lower end support 922, arises from the difference of the Dminand Dmaxand corresponding to the difference between the square facing the inside surface (A1+A2and the area facing outward surface And3. Thus, when the surrounding borehole fluid creates hydrostatic pressure around the packer node 910, in the typical case will be created to reduce power. This reduces the strength of preferably always acts on the lower end support 922 during downhole operations, reducing packer element 912 in conditions of low hydrostatic pressure environment. In addition, Krausa force is preferably not prevent the inflation of the packer under conditions of high hydrostatic pressure environment.

In the embodiment of the invention, shown in Fig.9, the movable end bearing 922 may perform an axial movement relative to the sleeve 944 recorded on the mandrel 924. The sleeve 944 has a stepped radius, forming the minimum diameter Dminand the maximum diameter of Dmaxthat in turn correspond facing the inside surface (A1+A2and facing outward surface And3the movable end support 922. Movable end bearing 922 and the sleeve 944 in interaction form the camera 948 low pressure, which creates the atmospheric pressure, the pressure close to vacuum, or other suitable low pressure and which is sealed with o-ring seals 921, 923 (for example, heat-resistant o-ring seals). Luggage 948 low pressure allows the movement of the mobile tail support 922 relative to the sleeve 944 under the influence of the pressure of the downhole fluid.

The sleeve 944 is preferably provided with a mechanical locking element 946, located in the compact camera 948 low pressure to limit axial movement of the movable end support 922 along the sleeves. The locking element 946 prevents the excessive rise of the lower part of the lower end of a support 922 and loss of sealing contact of the lower part of the sleeve 944 under pumping tubular packer is lementa 912. In addition, by limiting the upward movement of the lower end of a support 922 locking element 946 reduces the deformation experienced by the tubular packer element 912 near its lower end 916, where the bend radius is small and there is a significant stress concentration. Get (more reasonable) deformation increases the period of normal operation of the packer element 912 due to the exclusion of the rectangular transition zone, which is otherwise formed in a conventional inflatable packer when the packer element is bent near the movable end support. In addition, limiting the upward movement of the lower end of a support 922 using a mechanical locking element 946 serves to increase the tensile forces created in the packer element 912, and prevent plastic deformation of the packer element or metal inserts in it (if they are used).

Described here, the locking element independently useful in packer node, and accordingly can be used regardless of the node contraction of the packer. In addition, the locking element may not necessarily be designed as a rigid locking mechanism, shown as the locking element 946, but instead it can be malleable (e.g., may include a spring component)to do more than post the limiting military force in case of prolonged displacement of the movable end support.

On figa-10B shows an annular mounting site shown in figa-4V, and the node contraction of the packer shown in Fig.9, with both of them applied in a node of the inflatable packer. On figa shown mounting ring node in the retracted position, and figv shown mounting ring node in the extended position. Accordingly, the node 1010 inflatable packer includes an expandable tubular packer element 1012 having a pair of ends 1014, 1016, and a pair of annular end supports 1020, 1022, having corresponding flat annular cutouts for securing the respective ends of the tubular packer element relative to the mandrel 1024 at least partially located inside the first tubular packer element 1012. Lower end bearing 1022 movable and the upper end bearing 1020 is fixed relative to the mandrel 1024.

Movable end bearing 1022 is facing the inside surface (A1+A2), the area of which is preferably greater than the area facing outward surface And3, resulting in the pressure of the downhole fluid (which affects these surfaces) exerts a resultant force, which moves the movable end support to the outside (i.e. down in the case of the lower end support 1022), when the tubular packer element 1012 depressurized and he shrinks (i.e. blown).

1+A2and facing outward surface And3the mobile terminal supports 1022. The densified Luggage 1048 low pressure allows the movement of the mobile tail support 1022 relative to the sleeve 1044 under the action of the pressure of the downhole fluid. Preferably the sleeve 1044 is provided with a mechanical locking element 1046 (essentially ring, retreating around the parts with a maximum diameter), which is located in the chamber 1048 low pressure to limit axial movement of the movable end support 1022 along the sleeves. The locking element 1046 prevents the excessive rise of the lower part of the lower end of a support 1022 and loss of sealing contact in the lower part of the sleeve 1044 under pumping tubular packer element 1012.

Ring mounting site 1026 hinged by one of its ends 1030 with the lower end support 1022 for amplification of the first tubular packer element 1012 with the increase in its pressure and expansion (i.e. pumping). The annular fastening element 1026 acts as a mechanical support for the tubular packer element 1012 and effectively closes the gap between the end support 1022 (koterayama of metal) and the barrel wall 1018 well. It acts to eliminate the need for mechanical strength flexible tubular packer element 1012 to hold itself (for example, by using the reinforcing inserts) and allows for more reliable operation of the tubular packer element 1012 to create a proper seal between the wall 1018 well bore and the mandrel is 1024.

Ring mounting site 1026 may expand its end 1032, opposite the hinge attached to the end 1030, allowing the node 1026 when inflated tubular packer element 1012 takes the form of a truncated cone (pigv). Although this variant embodiment of the invention is shown using a single mounting ring node 1026, specialists in the art it will be clear that with the receipt of benefits may be used other such fastening site on the upper end of the support 1020.

Figure 11 shows the drilling tool 1110 having the node dual packer with centralizer 1160 to prevent bending of the tool between the packers. Thus, the drilling tool 1110, which is composed of many interconnected mandrel a, 1150b and is shown as promoted by the drillstring 1114 in the wellbore, the limited wall 1118 wellbore. The tool is adapted for sampling a downhole fluid credif within part 1116, limited wall 1118 wellbore isolated two inflatable packer elements 1112.

Expanding the centralizer 1160 retained mandrel 1150b in the axial direction between the first and second packers 1110 to prevent bending of the mandrel during the execution of the operations of the sampling fluid. The mandrel 1150b represents at least part of the so-called "spacer columns between the packer elements 1112, which provides the necessary axial distance between the packer elements. Accordingly, the centralizer 1160 serves as a spacer element columns. The centralizer 1160 includes a pair of supports 1162, 1164, held on the mandrel a, with at least one of the supports can be moved in the axial direction along the mandrel. The centralizer in these embodiments of the invention also includes a set of (preferably at least three) pairs of pivotally connected levers 1166. The levers of each pair having first ends pivotally connected to the respective supports, 1162, 1164, and second ends pivotally connected to each other swivel 1168.

On one of the interconnected bars a/b/installed with the actuator (not shown) for messages axial movement of each moveable support (supports 1162, 1164) so that the hinge connected to the second ends 1168 each pair of factors is ahow moved radially outward to apply a force to the wall 1118 wellbore, which essentially centers the shaft in the hole.

When performing sampling in a loose hole (uncased borehole), the centralizer preferably additionally includes a set of spring leaves 1170, each of which has its ends pivotally attached to the respective supports 1162, 1164 thus, to position the spring leaves 1170 between the respective pairs of pivotally connected pairs of levers 1166 and wall 1118 wellbore. Spring leaves 1170 and pivotally connected levers 1166 interact for the application of forces to the wall of the wellbore, which essentially center the mandrel (preferably all three of the mandrel a/b/C) in the wellbore. Other aspects related to the centralizer, known to experts in the art, for example, as evidenced by the description of U.S. patent No. 5358039, although it appears that such units have not been applied previously in such packer nodes, as described here.

On Fig shows the downhole tool 1200 equipped with a pair of inflatable packer elements a,b, each of which has a node reduction packer, similar to node 910, shown in Fig.9, with the upper packer a, inverted so that the side of low pressure (i.e. the inner end of support) both of the respective packer elements are fixed. what then is the difference from a typical configuration with dual packer, in which the lower end bearing in each of the first and second pairs of end supports is movable end support for adaptation to the inflation of the packer. When the pressure between two packer elements is reduced to less than hydrostatic pressure to generate a flow of well fluid through the isolated portion (not shown in Fig) wall of the wellbore, the upper side of the upper packer element is loaded with tension, while the lower element is loaded with compression. In the so-called "inverted" configuration, shown in Fig, the upper packer element a fixed in the lower part of the fixed end support a, thus eliminating the load with the extension on the top end.

Thus, the upper packer element a applied to the movable upper end bearing a and a fixed lower end bearing a. Conversely, the lower packer element is applied a fixed upper end bearing 1220b and a movable lower end bearing 1222b. Movable end support a, 1222b interact with the respective sleeves a, 1244b similar to the interaction of the mobile terminal supports 922 and sleeve 944, shown in Fig.9, for the active contraction of the tubular packer element a, 1212b when deflating. Thus, the movable end bearing a will move the up, and a movable end bearing 1222b will move downward under the pressure of the surrounding borehole fluid, acting on different area facing the inside surface (A1+A2and facing outward surface And3. Sealed chamber low pressure (not denoted by reference positions) allow movement of the movable end of the supports relative to the sleeve under the influence of the pressure of the downhole fluid.

The downhole tool shown in Fig also have alternative centralizer different from the centralizer figure 11. The centralizer 1260 like centralizer 1160 in that it applied pivotally connected levers 1266 having first ends pivotally connected to the respective supports, 1262, 1264, and second ends pivotally connected to each other pivotal connection 1268. The centralizer 1260 has no spring sheets, such as sheets 1170, as shown at 11, although such sheets if necessary can be used (usually in conditions in uncased wellbore).

In this embodiment of the invention the lower bearing 1264 fixed, and the upper bearing 1262 mobile. The upper bearing 1262 is moved axially along the mandrel 1250 actuator, which includes a piston 1280 and rod 1282 piston. The piston performs a reciprocating movement inside the cylinder 184 under the action of pressure fluid, thus, by moving the upper support up and down as needed for the nomination or sadhane pivotally connected ends 1268 articulated levers 1266. With this extension ends 1268 come into contact with the wall 1218 wellbore with sufficient strength for durable retention of the centralizer 1260 in the center of the wellbore. A spiral spring 1286 fixed to part with a reduced diameter 1250, pressurizes the upper support 1262 towards its upper position, causing the ends 1268 default move into position for lowering into the well. On the side of the piston opposite side under pressure in the cylinder, the pressure acting on it, corresponds to a pressure in the interval (i.e. the pressure in the interval of the wellbore packer isolated elements a,b, when they are inflated). Thus, when the pressure in the interval decreases, the force exerted on the piston 1280 to the stock 1282 piston will increase, even if the pressure in the cylinder remains constant. This provides an increase in the forces acting on the stabilizing levers 1266 and ends 1268, to counteract the increased bending forces generated when the pressure in the interval. In embodiments where the piston 1280 centralizer does not require a significant pressure drop to achieve adequate centering force, the pressure in the cylinder 1284 which may be formed of the same fluid medium, which is used to create pressure in the packer elements a,b (not necessarily for the same hydraulic lines), and the side of the piston 1280, the opposite side of the pressure in the cylinder may be provided with the medium under hydrostatic pressure (i.e. the pressure in the wellbore outside the interval bounded by the packer). Thus, the pressure acting on the piston 1280 may be only the pressure of inflation of the packer.

The use of two or more drive pistons could allow independent deployment of the centering levers 1266. This could enable centering in the bore with a non-circular cross-section. In addition, you can use many of these stabilizing sections simultaneously, which could give the opportunity to create any necessary separation of the packers or any length of the interval.

Summing up, we note that several objects of the present invention provide reliable deployment of the pair located at a distance from each other inflatable packers installed on the mandrel, located in a borehole traversing a subterranean formation. The usual estimator of the parameters of the productive formation using dual inflatable packer includes the steps of creating a pressure in the packers to isolate the annular side wall of the wellbore, selection of one or Bo is her sample of the downhole fluid within an isolated part of the wall of the wellbore and pressure relief in the packers to move the mandrel in the well. The present invention provides a receiving method of sampling and device for its implementation, giving the following benefits: limit deformation of the packers when pumping up using the ring mounting site; active reduction of packers using the ambient pressure in the well and substantially centering the mandrel between the packers for the resistance to bending of the frame.

From the preceding description it will be understood that in the preferred and alternative embodiments of the present invention can be made of various modifications and changes without departing from its true nature.

This description is given only for illustration, and it should not be interpreted in a restrictive sense. Scope of this invention should be determined only by the language of the following claims. The term "comprising" in the claims means "including at least", with the above listed elements in the claims are incomplete group. It is implied that the articles "a", "an" and other terms in the singular shall include the plural, if it is not specifically excluded.

1. The site of the inflatable packer, containing the first expandable tubular element having a pair of ends, a first pair of annular end supports for securing the compliance with the plans ends of the first tubular element relative to the mandrel, located in the first tubular element, with one of the end supports is movable and the other end bearing fixed relative to the mandrel, and the first annular fixing node deployed from one of the end supports for the amplification of the first tubular element in the creation of pressure and its extension pivotally connected to one of its ends with one of the end supports for the amplification of the first tubular element in the creation of pressure and its extension, is able to expand to the other end and containing a number of plates arranged in an annular configuration, pivotally connected by one end with the movable end support and having, each, a width increasing from its hinged end to the other end.

2. The node according to claim 1, additionally containing the first locking element to limit axial movement of the movable end support.

3. The node according to claim 1, additionally containing a second expandable tubular element having a pair of ends, a second pair of annular end supports for securing the respective ends of the second tubular element relative to the mandrel, and the first and second pairs of end supports interact to set the axial distance between the first and second tubular elements, and a second annular mounting site, pivotally connected od them of its ends with one of the end supports for the amplification of the second tubular element in the creation of pressure during extension.

4. The node according to claim 3, additionally containing an expandable centralizer mounted on the mandrel at a distance in the axial direction from the first and second tubular elements and between the resistance to bending of the frame.

5. The node according to claim 4, in which the centralizer comprises a pair of supports mounted on the mandrel, one of which is able to move axially along the mandrel, a multitude of pairs of pivotally connected levers, the levers of each pair having first ends pivotally connected to the respective supports, and second ends pivotally connected to each other, and the actuator mounted on the mandrel, for the message of the axial movement of each moveable support so that the hinge connected to the second ends of each pair of levers are able to move radially outward, applying force to the borehole wall, which is essentially centers the mandrel in the borehole.

6. The node according to claim 5, additionally containing a number of spring leaves, each of which has its ends pivotally connected to the respective supports so that the spring leaves are arranged between the respective pairs of hinge arms and the wall of the well bore, and spring leaves and pivot levers interact for the application of forces to the wall of the wellbore, which essentially center the mandrel in the well.

7. The node according to claim 4, in which the torus centralizer contains three pairs of articulated levers, posted essentially evenly spaced around the circumference of the mandrel.

8. The node according to claim 1, in which the end bearing is facing the inside surface area of which exceeds the area facing outward surface, causing the downhole pressure of the fluid exerts a resultant force that moves the movable end support to the outside when the pressure relief in the first tubular element and its reduction.

9. The method of deployment of the pair located at a distance from each other inflatable packers installed on the mandrel, located in a borehole traversing a subterranean formation containing the following steps:
creating pressure in the packers to isolate the annular side wall of the wellbore;
the selection of one or more samples of the reservoir fluid in an isolated part of the wall of the wellbore;
the pressure in the packers to move the mandrel in the borehole;
limit deformation of the packers at the stage of creating pressure using the ring fixing node,
each packer includes an expandable tubular element having a pair of ends and a first pair of annular end supports for securing the respective ends of the tubular element relative to the mandrel, with one of the end supports is movable and the other end bearing fixed relative to the op is where it is refuelled, and a movable end support is provided inward facing surface having an area greater than the area of the face outward surface, the pressure of the downhole fluid exerts a resultant force that moves the movable end support out when removing the pressure in the tubular element and its reduction.

10. The method according to claim 9, further containing the constraint deformation of each packer using mechanical stopper member that restricts the movement of the mobile tail support.

11. The method according to claim 9, further containing the step of actively reducing packers using the ambient pressure in the well bore, attached to the movable end supports.

12. The method according to claim 9, further containing essentially centering the mandrel between the packer to create resistance to the bending mandrel.



 

Same patents:

FIELD: oil and gas industry.

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18 cl, 17 dwg

FIELD: oil and gas industry.

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1 ex

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26 cl, 42 dwg

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18 cl, 24 dwg

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2 dwg

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4 dwg

FIELD: oil and gas production.

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23 cl, 30 dwg

Mechanical packer // 2383714

FIELD: oil and gas industry.

SUBSTANCE: invention refers to oil and gas industry and can be implemented at development and operation of oil and gas wells for sealing their various zones. Units of sealing and anchoring are installed on rod 1 equipped with a lengthwise slot and connecting thread 3 and 4 on ends; cone 5 designed to travel lengthwise is arranged between the said units. Rotating bushing 6 with a system of shaped slots is mounted on rod 1. The sealing unit consists of packing element 12 enveloping rod 1 on sides and made out of elastic material and of stop 13 of packing element 12. The anchor unit contains cylinder sleeve 14 with pins secured onto it, the said pins enter sections of the slot system of bushing 6. The pin secured on sleeve 14 enters the lengthwise slot of rod 1. Spring loaded slip sockets 19 are attached to sleeve 14; the slip sockets are equipped with teeth 22 and decline from rod 1 in radial direction for engagement with internal walls of a casing pipe. The packer is secured to the flow column (FC) and is lowered to a place of anchoring (packing). Tube space is sealed by reverse motion of the packer in the well due to lengthwise compression of packing element 12 applying force to it with stop 13. The packer is reliably blocked in a transport position with symmetrical U-shaped sections of shaped slot system of bushing 6.

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6 cl, 10 dwg

FIELD: oil and gas industry.

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33 cl, 9 dwg

FIELD: oil-and-gas industry.

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EFFECT: offered additional casing string cementing device provides significantly increase in operation safety, as it allows to centralise the device and additional tubing string, the offered device descends on the tubing string end inside of the failed string, which assures ACS high quality cementing, also the device allows to take it out in case of parkers non-hermetic landing before ACS cementing, which excludes ACS cementing under the parker, and excludes incident in the well.

2 dwg

FIELD: oil-and-industry.

SUBSTANCE: double-barreled parker with cable inlet contains form two parker barrels, a parker unit, with hydraulic or mechanical drive and a cable inlet sealing unit, and chemical reagents pumping lines. A parker barrels and an internal one, installed one into another and fix between each other with cable inlet orientation, entering barrels ring space through the parkers side window. The cable input sealing unit with chemical reagents pumping lines, consisting of a sealing element with support washers by ends, located in the ring space between barrels, under a press bushing. The sealing unit is joint-splitable and the sealing element separated with a wall with hydro-channels, connected with a control bulk channel.

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3 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: invention related for a tubing string disconnection and the following connection to bottomhole equipment. Proposed hydraulic installation device consists of a case, a connecting unit and a collet, a nut. The case executed borings for bores on the collet leafs, which depth is equal to bores height. In the connection unit, between top and bottom parts executed radial holes for washing and located in staggered order. The boring executed stepped with two bores, the boring of the smaller diametre is for sealing, boring of the bigger diametre for the piston with cylindrical step displacement. At that length of the bottom boring cylindrical part is greater than the top boring length, but smaller than distance from a base of external cylinder case to boring for bores on the collet leafs. The piston executed with a cylindrical step and cannels, on the step for share bolts, in a middle part under the collet leafs and on the ends under sealing. In the piston top end part a ball located and an internal cant executed. The case connected with the connecting unit through the collet and the piston and fixed with a nut. The nut executed with boring for collet base bore.

EFFECT: reliability and efficiency of parker installation works increase, time consumption decrease.

4 cl, 5 dwg

Parker-anchor // 2379471

FIELD: oil-and-gas industry.

SUBSTANCE: well parker-anchor, containing a case, an anchor unit, consisting of a void cone and a ram, installed under a sealing element, located between a top fixed stop block and a bottom stop block, and a drive, made as a piston with pass through channel, equipped with pass though narrowing on the bottom, and from the top - with a void bar, which stiffly and axially connected with the cone from the top, stiffly fixed with the case. The piston installed inside of the movable cylinder, and the inside void between the cylinder and the piston connected with the bar void over the pistons pass through channel narrowing, at that the top stop block executed spring loader from the top and with ability of limited upwards movements, and the bottom stop block equipped with radial windows and is movable, has upwards movement ability, interaction with the cylinder at the bottom. Rams made roller shaped with longitude holes, installed in the bottom stop block windows on axis, which fixed perpendicularly to the case axis, at that the rollers longitude hole diametre is bigger then axis external diametre, and the rollers external surface serially interacts with the void bar external surfaces, the cone, the case and the wells wall during the bottom stop block movement relatively to the case. In the offered parker-roller design, which roles between the well wall and the case, achieves a reliable borehole separation in result to the tubing string weight, because of that parkering and unparkering executed with tubing string movement, which location controlled on the borehole head.

EFFECT: design simplification, operational reliability increase, manufacturing and maintenance works cast cutting due to simple and processible spare part use, their quantity decrease.

7 dwg

Parker // 2379470

FIELD: oil-and-gas industry.

SUBSTANCE: parker contains a channel with sealing element, executed as a set of sleeves, and a hydraulic anchor, including a ram holder, rams and a cone, and an electrical cable, at that the hydraulic anchor has a case-piston, connected to the channel and creating a piston void together with creping its over the ram holder, connected through the channel wall hole with the channel external void, hydraulic anchor case-piston and the parker case connected with nipples over the sealing elements, inside the case-piston channel located a sickle shaped tube adjusting to its external surface, connected to the nipples inclined holes, the electrical cable goes throughout the sickle shaped tube, which cores enters the nipples inclined holes and connected to located on the nipples inclined holes ends cable connectors, with its help cable cores going through the sickle shaped tube connected to extension cables, at that the nipple connected to the channel, connected with tubing string, with the aid of which the parker installed inside the borehole with ability to of tubing string supply through nipples, the parkers channel and the hydraulic anchor case-piston medium produced form the well, at that nipples ends inclined holes and the sickle shaped tube ends mutual dislocation in one plane created because of the nipple position fixing relatively to the parkers channel and the hydraulic anchor case-piston, correspondingly with a help of a retainer nut, screwed on the parkers channel, which rotation relatively to the parkers channel limited with a stop screw, and nipples connected to the channel with captive nuts, screwed on the nipple screw till it external end meets retainer nuts.

EFFECT: parker operation reliability increase.

4 cl, 1 dwg

FIELD: oil-and-gas industry.

SUBSTANCE: device includes a cylindrical case with a sealing element and a parachute-centraliser and a seat, executed with an ability of the sealed element and the seat hermetic interaction. The seat executed as a pump lock support. The sealing element executed with an external cone part, replying to the pump support lock cone part, and an internal cone part, having coning direction opposite to a coning direction of the external cone part. The case has top cylindrical part and bottom cone part, located inside of the sealing elements internal cone part. The sealing element internal cone part and the case bottom cone part executed with a possibility of hermetic interaction. The parachute-centraliser is a barrel shaped, fixed on the case top cylindrical part with the barrel walls directed to the bottom. The barrel walls have holes. A share pin located in the case top cylindrical part flush to the sealing element.

EFFECT: device allows to simplify design and decrease technology operation time during operation, cast cutting.

2 dwg

Drilled parker // 2379468

FIELD: oil-and-gas production.

SUBSTANCE: drilled parker contains setting tool, which includes hydraulic cylinder with bottom support, piston with adapter on the top, top and bottom connecting rods, the connecting rod made with radial canals and stiffly connected with a tip with a process holes to a perforated nipple, a sealing unit, which includes a sleeve, a deformable barrel and a drift with widening angle on its top, connected on the bottom part with a fitting, through a share ring - with the tip and the perforated nipple, which telescopically installed into the drift, equipped with external cylindrical sections, a cutting-off valve and a blind valve, fixed on the tip with a lock ring. The is telescopically installed directly into the deformed barrel and into the bottom support, relatively to which the tip in its transport position fixed with a share bolt. The shut-off valve made as a plug with external ring sampling, hermetically installed into the tip and fixed with stoppers, installed into the tip's process holes with ability of limited movements towards outside incase of share ring destroy and the drift penetration, also with ability to interact in transport position plug ring sampling from the inside, and with drift - from the outside, which external cylindrical sections have a similar diametre, separated with at least one ring cavity with a edge, directed to the sealing unit, at that the drift's widening angle is 20-25 relatively to the parker axis. The deformable barrel's internal cylindrical surface is double-stepped with the smaller diametre on the top, and the upper rod over the piston equipped with outside ring cavity, and the cylinder's sub in its upper part equipped with inside selection with a spring ring, executed with ability to interact with the upper rod ring cavity and piston fixation in the extreme upper position. Use of the bored parker because of drift improved design, which angle is 20-25 relatively to the parker axis, and external sections have the same diametres, separated with at least one ring cavity with the edge, allows to drift widening barrel twice for a drift's single pass, which it its turn made double - staged with the smaller diametre (D1<D2) on the top.

EFFECT: received cone is pressing the sleeve to the production string walls, which increases the bored parker setting reliability in the wells defined interval and avoids its sliding, avoids its resealing during the bored parker installation in to the well.

2 dwg

Drilled out parker // 2374427

FIELD: oil-and-gas production.

SUBSTANCE: invention related to oil-and-gas production, particularly used to protect casing string from high pressure. Drilled out parker contains setting tool, including hydro cylinder with bottom support, piston, top and bottom rods, bottom one has radial canal and fixedly connected via tip with access holes to perforated nipple, seal assembly, including collar, deformable sleeve and dron with nozzle, connected on top to sleeve holder, telescopically fixed to support, and on the bottom with a nozzle via share ring with a tip and perforated nipple, which telescopically installed into dron, equipped with external cylindrical areas with external diameters increasing from top to bottom, cutoff valve and end plug, fixed on nozzle with stop collar. Sleeve holder and external support in its transit condition fixed between each other with shear bolt, cutoff valve consists of end plug with external ring , hermetically installed into tip and fixed with stoppers, which installed into nozzle access holes, allowing it limited outwards displacement in case of share ring damage and dron pass through, and also allowing in transit condition internal interaction with plug ring, externally - with dron, which external cylindrical areas connected via smooth transition.

EFFECT: application of drilled out parked with dron improved design allow to increase its installation safety and avoid "creep", and also cutoff valve designed as a plug except leakage during drilled out parker installation into well.

2 dwg

Packer // 2245986

FIELD: oil and gas extractive industry.

SUBSTANCE: packer has body in form of pipe, whereon collar compactors are placed with limiting washers, saddles for locking tool dropped from surface, cover, upper and lower fixing elements, made in form of anchoring assemblies, upper conical bushing, rigidly connected to pressing bushing and movably to the body, lower conic bushing, made rigidly together with body, guide of this conic bushing made in form of plate spring, placed by one end moveably in guiding groove in lower portion of lower die with teeth, and by other end fixed rigidly on greater diameter of this conic bushing, auxiliary pipe, placed inside the body. Packer in lower portion is provided with check valve, placed inside recess of body, concurrently being also the body of valve. Oppositely to valve saddle on same axis stepped locking bushing is placed with possible sliding inside body recess with limited drive and possible overlapping of radial grooves made in body, which, in its turn, is rigidly connected to auxiliary pipe via shear pin. Between stepped locking bushing and saddle compression spring is placed. Fixing elements of collar compactors are made in form of comb with inner teeth and outer conic generators in nose portion. On the side of collar compactors these are enveloped by inner conic portion of compression bushing, in its turn rigidly connected to upper conic bushing, and on the other side combs with inner teeth are placed sliding-moveably in radial grooves of guiding bushing placed between ends of upper conic bushing and inner conic portion of compression bushing with possible engagement by inner teeth of comb to slanting walls of body groove and interaction to all elements of this assembly.

EFFECT: higher reliability.

5 dwg

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