Patent Grant
9045975
The present invention concerns a well tool and a method for in situ introduction of a treatment fluid into any annulus in a subsurface well, for example a hydrocarbon well or an injection well. Moreover, this invention may be used in any type of well, including a vertical well, a deviation well, a multi-lateral well and a horizontal well. The invention is suitable for use both in uncased, open well bores and also in cased well bores.
This invention is especially suitable for remedial well operations during the completion phase of a well, i.e. the phase after the well has been completed and is in operation.
In this context, said treatment fluid may, for example, be comprised of a suitable sealing mass, for example fusible plastics, thermosetting plastics, epoxy, metal or other material of a suitable type. If the sealing mass is a solid-state material of the fusible type, the well tool should also comprise a heating device for melting the sealing mass before introduction into an annulus in a well. As an alternative or addition, the fusible sealing mass may be melted before conveyance into the well, after which it is kept in a molten state until introduction into said annulus.
As another example, the treatment fluid may be comprised of a well stimulation means, for example an acid, a liquid with a proppant material added thereto, a soluble material, a consolidation liquid, a scale inhibitor, etc.
The background of this invention is problems and disadvantages associated with the prior art concerning introduction of a treatment fluid, for example a remedial seal, into an annulus in a well after completion of the well and during the operating phase thereof. It is emphasized, however, that the present invention may be used in any phase during the lifetime of a well.
With respect to remedial seals, and according to prior art, it is customary to use various well packers to isolate zones, for example one or more reservoir zones, along a well pipe when placed in, or being placed in, a well. Packers of this type are normally placed on the outside of the specific well pipe and before it is conveyed into the well. This type of packer is commonly referred to as an external casing packer—“ECP”, for example a so-called inflatable packer. When the well pipe has been conveyed and is positioned at the corrected location in the well, the packer(s) is/are activated in the annulus around the well pipe and is/are forced outwards and against surrounding rocks, or against a surrounding well pipe. Activation of such a packer may be carried out hydraulically and/or mechanically. A so-called swell packer may also be used that will expand upon contact with, for example, oil and/or water in the well. Packer setting techniques of this type constitute prior art.
Yet further, during the post-completion phase of a well, and particularly in connection with recovery of hydrocarbons from a reservoir, production-related problems or conditions may arise that require or generate a need for installing one or more additional annulus packers in the well. Installation of such remedial annulus packers may form part of an appropriate production management strategy, water injection management strategy or reservoir drainage strategy. Alternatively, such an installation may be carried out to remedy an acute situation in the well. Accordingly, a need may exist for isolating one or more zones in a well, for example in a production well or in an injection well, and the need may arise at any time throughout the lifetime of a well. Normally, the need will be the greatest in horizontal wells and highly deviated wells. Deficient or failing zone isolation may restrain or prevent various efforts to stimulate the recovery from a well, which may reduce the recovery factor and profitability of the well and/or the reservoir. Insufficient zone isolation may also lead to unfortunate and/or dangerous conditions in the well. It may also concern other isolation/treatment needs in any annulus in a well, including an annulus between an uncased borehole wall and a well pipe, or an annulus between two well pipes. Thus it may concern, for example, a cemented annulus requiring after-treatment, or an annulus between two well pipes, along the entire length or longitudinal sections of the well.
The following examples point out some well conditions in which effective and selective annulus sealing may be of great significance to the performance of a well:
Use of external casing packers (“ECP's”) as well as use of so-called gravel packs constitute two main techniques employed for zone isolation/zone control of annuli, particularly in open well bores. The methods may be used individually or in combination, and the purpose thereof is to seal an annulus completely (external casing packer) or to significantly restrict a fluid flow in the annulus (gravel pack). An external casing packer mau fail whilst being set or after being set in the annulus in the well, whereby the annulus is sealed in an unsatisfactory manner.
Employment of external casing packers and gravel packs, however, takes place before or during completion of the well. In order to form a remedial annulus seal in a well after being completed, it is most common in the art to carry out so-called squeeze cementing where a suitable cement slurry is forced into a well annulus via openings in a pipe structure. Alternatively, a suitable gel may be forced into the well annulus. The openings in the pipe structure may, for example, be perforations or slots in a casing, or filter openings in a sand screen, etc. In order to transport cement slurry or gel onto a desirable location in the well, a pipe string is typically used, for example coiled tubing or drill pipes. In this context, also at least one so-called straddle packer is typically used to define at least one injection zone in the well for injection of said cement slurry or gel.
The use and/or efficiency of these known techniques involve(s), among other things, increased operational complexity and risk, as well as further completion costs for a well. The zone isolation techniques also lack the operational flexibility desirable during a well's operating phase after completion.
With respect to the present invention, however, the closest prior art appears to be described in WO 2006/098634 (Triangle Technology AS). This publication describes a method and device for in situ formation of a seal in an annulus in a well. According to WO 2006/098634, the device comprises, among other things, a perforation device for allowing a hole to be made through a pipe wall, and also a packer injection module for allowing a liquid packer material to be forced into said annulus in the well. Thereafter the liquid packer material will enter into solid state and form a seal in the annulus. For this purpose the packer injection module comprises at least a packer chamber containing a solid-state, fusible packer material; a heating device to allow the solid-state packer material to be melted; a driving device with an associated propulsion device for allowing molten, liquid packer material to be driven out of the packer chamber; and a connection means for allowing the packer chamber to be connected in a flow-communicating manner to said hole through the pipe wall and then to conduct liquid packer material further into the annulus.
One disadvantage of the invention according to WO 2006/098634 is that it is confined to the use of a solid-state, fusible packer material for making a remedial seal in an annulus in a well. It does not describe a technical solution suitable for introduction of a more general treatment means into said annulus, wherein this treatment means may be a suitable sealing mass, but wherein the treatment means just as well may be a well stimulation means or other liquid material.
In one embodiment disclosed in WO 2006/098634, also the packer injection module is connected in a flow-communicating manner to a flow-through connection module comprising said perforation device for making a hole through the pipe wall. A connection module to be used both for perforation of the pipe wall and for subsequent hole connection involves both a technical and operational complexity which may prove difficult during use as, among other things, a source of operational problems and potential shutdown.
Due to the above-mentioned problems and disadvantages associated with prior art in this field, a great interest therefore exists in the industry for technical solutions rendering in situ introduction of a suitable treatment means into an annulus in a well simpler and less costly, especially during the operating phase after completion.
The primary object of this invention is to avoid or reduce at least one of the above-mentioned problems and disadvantages of the prior art.
More specifically, the object of the invention is to provide a technical solution for in situ introduction of a treatment means into an annulus located outside a pipe structure in a well.
The objects are achieved by virtue of features disclosed in the following description and in the subsequent claims.
According to a first aspect of the present invention, a well tool for in situ introduction of a treatment means into a region of an annulus located outside a pipe structure in a well is provided. For example, the pipe structure may be comprised of a well pipe or a sand screen or similar in the well. According to this first aspect, the well tool comprises:
The distinctive characteristic of the well tool is that said anchoring body is disposed in an anchoring module;
References to “axial” in this description refer to the direction of the longitudinal centre line of the well tool.
Said distinctive characteristic of the present well tool differs from all of the above-mentioned, known well tool for injection of a mass into an annulus in a well.
By means of the present well tool and method, in situ introduction of a suitable treatment means into a region of said annulus may be carried out, wherein the treatment means is conveyed into the well together with the well tool. This brings about obvious technical, operational and cost-related advantages with respect to said prior art.
In this context, the treatment means may, for example, be comprised of a sealing mass, including fusible plastics, thermosetting plastics, epoxy, metal, sulphur or other material of a suitable type. The treatment means may also be comprised of a well stimulation means, including stimulation chemicals, scale inhibitors, gel materials, etc. Moreover, any treatment means suitable for the particular task in the annulus of the well may be used. The essential thing of the present invention is not which treatment means is used in the annulus, but the manner in which the treatment means is introduced at its location within the annulus.
Further, the well tool may be structured for conveyance into the pipe structure by means of a connection line. Thus, the connection line may comprise a pipe string, for example a pipe string composed of coiled tubing. The connection line may also comprise a flexible cable, for example an electric cable. By so doing, the well tool may be conveyed into the well by means of conventional conveyance means.
For use particularly in highly deviated wells and horizontal wells, the well tool may also be structured for connection to a well tractor for conveyance into the pipe via the connection line. Such a well tractor is usually provided with wheels, rollers or similar movement bodies for contact with, and movement within, the surrounding well pipe. In this context, also the lower and free end of the well tool may be provided with suitable movement bodies for support and movement within the well pipe. Alternatively, the lower and free end of the well tool may be operatively connected to a movable guide section, which forms a protective and stabilizing front end of an assembly of the well tool and the guide section. Similar to the well tractor, such a guide section may also be provided with suitable movement bodies for support and movement within the well pipe.
Yet further, the well tool may be structured for operation within the pipe structure without having to use a connection line between the well tool and surface. Such an embodiment requires that the well tool is structured more or less in an autonomous manner, wherein the control signals are transmitted wirelessly, and wherein the well tool is self-sufficient with respect to energy. Such a well tool may also comprise suitable movement bodies for contact with, and movement within, the surrounding well pipe.
Alternatively, such a well tool may be connected to a remote-controlled well tractor structured for wireless operation. For example, the well tool and a potential well tractor may be conveyed into the pipe structure, or be pulled out therefrom, by means of a slick steel line or another connection line of the above-mentioned types.
For conveyance into the pipe structure, such a well tool and a potential well tractor may also be dropped down into the pipe structure in a controlled manner. In order to avoid damage to the well tool and a potential well tractor whilst descending down through the pipe structure, the well tool/well tractor may be connected to a piece of speed-braking equipment or similar. Then, and via wireless remote control, said movement bodies may be employed to move the well tool and a potential well tractor onwards to the desired location in the pipe structure.
Hereinafter, constructive features of the present well tool will be discussed in further detail.
According to a first embodiment of the well tool, also said perforation device may be operatively connected to the injection module;
In this context, said perforation device may be disposed in a perforation module operatively connected to the injection module.
The well tool according to this first embodiment constitutes a one-trip well tool, i.e. a well tool structured in a manner allowing it to carry out all necessary downhole operations by means of one trip into the well.
In this one-trip well tool, the injection module may be movably connected to a rotation-preventing guide means associated with the anchoring module.
Thus, this guide means may comprise at least one of the following guide elements: a guide pin; a guide track; a guide shoe; a guide bar; and a guide rail.
Such a guide means will prevent rotation of the injection module whilst being moved axially relative to the anchoring module, which remedies the axial alignment of the connection device relative to said hole through the wall of the pipe structure.
In this one-trip well tool, the injection module and the anchoring module may be connected in an axially movable manner via at least one connection body.
As an example, this connection body may be comprised of an axially movable piston rod;
As another example, this connection body may be comprised of an axially movable shaft;
Yet further, said axially movable connection body may be non-rotatably connected to the anchoring module. This non-rotatable connection body constitutes an alignment means for axial alignment of the connection device relative to said hole through the wall of the pipe structure.
As an example of the latter, the well tool may therefore comprise a rotation-preventing connection between the axially movable connection body and the anchoring module. Further, this rotation-preventing connection may comprise a tongue-and-groove type of connection, for example a connection comprised of spline connection.
As another example of the latter, the axially movable connection body may have a non-circular cross-sectional shape, whereas the anchoring module comprises an axial opening having a complementary, non-circular cross-sectional shape relative to that of the connection body. Also this will constitute a rotation-preventing connection.
According to a second embodiment of the present well tool, said perforation device may be operatively connected to a perforation module;
The well tool according to this second embodiment constitutes a two-trip well tool, i.e. a well tool structured in a manner allowing it to carry out all necessary downhole operations by means of two or more trips into the well.
This two-trip well tool may comprise an orientation instrument including a first orientation means and a second orientation means;
Accordingly, this orientation instrument may comprise at least one of the following orientation elements:
Furthermore, the perforation device of the present well tool may be comprised of one of the following perforation means for being able to make said hole:
The present well tool may also comprise:
In this context, said connection line may be structured in a manner allowing it to transmit energy and control signals to the power unit and control unit for operation of the well tool.
As an alternative, the well tool may also comprise:
When using said more or less autonomous well tool, which is operated without a connection line, the latter embodiment must be used.
The treatment means to be introduced into a region of said annulus, may also be located in a replaceable receptacle placed in said storage chamber in the injection module of the well tool.
Hereinafter, reference will be made to a second aspect of the present invention. According to this second aspect, a method for in situ introduction of a treatment means into a region of an annulus located outside a pipe structure in a well is provided.
The distinctive characteristic of the method is that it comprises the following steps:
The method according to steps (A)-(J) applies both to said one-trip and two-trip well tools according to the first aspect of the present invention.
In step (B), the method may comprise the step of conveying the well tool into the pipe structure by means of a connection line of the above-mentioned types.
According to a first embodiment, the method may also comprise the following steps:
This first embodiment of the method involves use of said one-trip well tool.
According to a second embodiment, the method may also comprise the following steps:
This second embodiment of the method involves use of said two-trip well tool.
In the present method, the treatment means may, for example, be comprised of a sealing mass or a well stimulation means, as mentioned above in context of describing the present well tool.
Further, the present method may be used in various contexts and for various purposes.
Thus, in step (I) of the method, the treatment means may be injected into a region of an annulus located outside a sand screen associated with the pipe structure. Alternatively, the treatment means may be injected into a gravel pack disposed in the annulus. As a further alternative, the treatment means may be injected into a region of an annulus defined by said pipe structure and an external pipe.
Hereinafter, reference will be made to two non-limiting, exemplary embodiments of the present invention.
In order to facilitate the understanding of the invention, the figures are drawn in a somewhat simplified manner and show only the most essential components and elements of the present well tool. The shapes, relative dimensions and mutual positions of the components and elements may also be somewhat distorted. Moreover, all references to “upper” and “lower” in context of a component or element refer to a location being closer or further away, respectively, from the surface of the well.
Exemplary Embodiment No. 1
In another exemplary embodiment (not shown), the well tool 2 may just as well be used to force a treatment means, for example a liquid sealing mass, into a region of an annulus located between two casings of different diameters, or similar pipe structures.
As viewed in sequence from above and downwards, said main constituents (cf.
The connector 16 interconnects the electric cable 10 and the well tool 2 when being used in the well 6, the connector 16 connecting the cable 10 to an upper end of the anchoring module 18.
This anchoring module 18 (cf.
In order for the anchoring module 18 to carry out its first function, a first part 36 thereof is provided with four radially movable gripping elements 38, only three gripping elements 38 of which are shown in
Further, the pistons 50a, 50b, the piston rod 54 and the first piston cylinder 52 define a ring-shaped cylinder chamber 62a, 62b. A ring-shaped fixed piston 64 is fixed to the inside of the outer sleeve portion 60 and extends radially inwards into the ring-shaped cylinder chamber 62a, 62b, and inwards onto the piston rod 54 of the double piston 50a, 50b. At its inner periphery, the fixed piston 64 is provided with a gasket ring 66, which is in sealing contact with the piston rod 54. Thereby, the fixed piston 64 separates the ring-shaped cylinder chamber of the double piston 50a, 50b into an upper cylinder chamber 62a and a lower cylinder chamber 62b.
Two hydraulic conduits 68, 70 (shown schematically with dashed lines in
In order to carry out its second function, the first part 36 of the anchoring module 18 is also provided with a ring-shaped second piston cylinder 84a, 84b formed at the lower end of the module 18. A ring-shaped piston 86 is fixed to the outside of said massive piston rod 34. The ring-shaped piston 86 extends outwards into the second piston cylinder 84a, 84b and further outwards onto an outer sleeve portion 88 of the cylinder 84a, 84b. At its periphery, the piston 86 is provided with a ring gasket 90, which is in sealing contact with the mantle wall 88. Thereby, the piston 86 separates the second piston cylinder into an upper cylinder chamber 84a and a lower cylinder chamber 84b. At the upper and lower end of the piston cylinder 84a, 84b, the first part 36 of the module 18 is also provided with respective ring gaskets 92, 94, which are in sealing contact with the piston rod 34.
Two further hydraulic conduits 96, 98 (shown schematically with dashed lines in
Upon supplying pressurized hydraulic oil to said upper cylinder chamber 84a via the hydraulic conduit 96, the ring-shaped piston 86 may be driven in the axial direction downwards and towards the lower end of the anchoring module 18, as shown in
Hereinafter, the construction and/or function of the valve module 20, the control module 22, the hydraulic oil module 24, the hydraulic pump module 26, the storage module 28, the injection module 30 and the perforation module 32 will be discussed in further detail. However, the valve module 20 and the control module 22, which are shown in FIGS. 1 and 11-18, will not be described in the same detail as for the anchoring module 18. The reason for this is that the modules 20, 22 comprise components known per se, and modes of operation thereof, so as to be considered to represent prior art to a person skilled in the art.
When the well tool 2 is in operation in the well 6, electric energy and control signals are transmitted from surface and down to the control module 22 via the electric cable 10, the connector 16, the anchoring module 18 and the valve module 20. The control module 22 may comprise electronic components, including suitable processors and software, as well as sensors, signal transmitters, electric wires, batteries, etc. to the degree considered necessary for providing a functional operation of various components in the well tool 2. Energy and control signals, possibly also suitable fluids, may be transmitted via lines, pipes, conduits and/or hoses, as well as couplings, valves and similar (not shown in the figures) which are suitably disposed in or on the connector 16 and the various modules 18, 20, 22, 24, 26, 28, 30, 32 of the well tool 2.
The valve module 20 comprises a group of suitable valves (not shown) for supply and suitable distribution of fluids, such as hydraulic oil in this example, to various movable components in the well tool 2. The opening and closing of the valves is controlled by control signals from the control module 22. Motive power for the opening and closing of the valves may come from the control module 22 and/or be provided by independent power sources and/or devices in the valve module 20. Thus, the valve module 20 and the control module 22 may provide for a suitable supply and control of hydraulic oil to/from said ring-shaped double piston 50a, 50b and ring-shaped piston 86. By so doing, the gripping elements 38 and the massive piston rod 34, respectively, may be moved in a suitable manner relative to the anchoring module 18, as shown in
The hydraulic oil module 24 (cf.
In this exemplary embodiment, said reservoir for hydraulic oil is comprised of a ring-shaped hydraulic oil cylinder 104a, 104b. This cylinder 104a, 104b is provided with a ring-shaped and axially movable free-float piston 106 having an external ring gasket 108 and an internal ring gasket 110 for sealing contact with an outer sleeve 112 and an inner sleeve 114, respectively, the sleeves of which collectively define the ring-shaped hydraulic oil cylinder 104a, 104b. The free-flow piston 106 separates the hydraulic oil cylinder into an upper cylinder chamber 104a and a lower cylinder chamber 104b. At its upper end, the outer sleeve 112 is provided with a radial vent bore 116, which connects the upper cylinder chamber 104a in a flow-communicating manner with a well liquid 118 (and the pressure in the well liquid 118) in the casing 4, whereby the upper cylinder chamber 104a is filled with well liquid 118. The lower cylinder chamber 104b, however, is filled with hydraulic oil 120. At its lower end, the inner sleeve 114 is provided with a radial bore 122, which connects the lower cylinder chamber 104b in a flow-communicating manner to several hydraulic pipes carried along an axial bore 124 through the hydraulic oil module 24. Even though the axial bore 124 comprises several such hydraulic pipes, only two hydraulic pipes 126, 128 are shown schematically with dashed lines in
The hydraulic pump module 26 (cf.
The storage module 28, which is operatively connected to the injection module 30, comprises a cylinder-shaped storage chamber 142a, 142b provided with an axially movable free-float piston 144 having an external ring gasket 146 for sealing contact with an enclosing sleeve 148. The free-float piston 144 separates the storage chamber into an upper chamber 142a and a lower chamber 142b. The upper chamber 142a is connected in a flow-communicating manner to said hydraulic pipe 140 from the pump device 132, whereby the chamber 142a is filled with hydraulic oil 150 from the pump device 132. The lower chamber 142b, however, is filled with a treatment means, which in this exemplary embodiment is comprised of a liquid sealing mass 151. The enclosing sleeve 148 is also provided with axially directed hydraulic conduits 152, 153, which are connected in a flow-communicating manner to said corresponding hydraulic pipes 126, 128 through the pump module 26 and the storage module 28.
An axial bore 154 is directed further outwards from the lower end of the storage chamber 142a, 142b. A cylindrical plug 156 having a peripheral ring gasket 158 is attached within the bore 154 by means of a radial shear pin 160, which connects the plug 156 to the lower portion of the storage module 28. Upon pumping hydraulic oil 150 at sufficient pressure from the pump device 132, via the hydraulic pipe 140 and onwards into the upper chamber 142a, the free-float piston 144 is forced against the liquid sealing mass 151 so as to drive the mass against the plug 156 until the shear pin 160 fails and is severed. Then, the plug 156 and the sealing mass 151 will move out of the bore 154 and onwards into the injection module 30. As such, the pump device 132, the free-float piston 144 and the hydraulic oil 150 constitute a driving means for forcing the sealing mass 151 out of the storage chamber 142a, 142b.
In an alternative embodiment not shown in the figures, the lower chamber 142b of the storage chamber may be filled with a treatment means in the form of a sealing mass being a solid-state material of the fusible type, for example fusible plastics or a suitable metal. In such an alternative embodiment, the lower chamber 142b should be connected to a heating device for allowing the solid-state sealing mass to be melted before introduction into said region of the annulus 12 in the well 6. As an alternative in the event that the solid-state sealing mass was melted before placement into the well tool 2, such a heating device may be used for keeping the melted sealing mass in the melted state during conveyance of the tool 2 into the well 6. As mentioned above, the treatment means may also be a well stimulation means or other liquid material. Moreover, the storage module 28 and its storage chamber 142a, 142b may assume any shape and size suitable for the particular well purpose and/or treatment means.
The injection module 30 (cf.
In order to carry out its primary injection function, among other things, the injection module 30 of this exemplary embodiment is provided with four flow-through connection devices in the form of radially movable connection pads 192, only some pads 192 of which are shown in
Each connection pad 192 may move radially outwards from the cylindrical cavity 168 via a corresponding opening 220 in the outer sleeve 182 of the injection module 30. For this purpose, a hinge joint 222 is disposed between each connection pad 192 and the attachment collar 190 on the piston rod 188. The hinge joint 222 is pivotally attached to the attachment collar 190 and to a lower portion of the connection pad 192.
Further, the axial bore 162 in the upper portion of the injection module 30 corresponds to the axial bore 154 in the lower portion of the storage module 28. When the axially movable piston 178 of the module 30 is in its active position so as to extend the connection pads 192 radially outwards from the cavity 168, said sealing mass 151 may be forced onwards from the storage module 28 and further onwards to and through each connection pad 192. This is achieved by activating said pump device 132 and force the free-float piston 144 of the storage module 28 downwards within the storage chamber 142a, 142b. By so doing, said plug 156 and the sealing mass 151 are driven out of the bore 154 in the storage module 28 and into the axial bore 162 in the injection module 30 and onwards to the manifold 164 thereof. The plug 156 is captured in the manifold 164, and the sealing mass 151 is distributed to said four manifold conduits 166. The sealing mass 151 flows from each manifold conduit 166 and onwards through the respective ball head joint 210 and the sealing mass conduit 198 in the respective connection pad 192, thereby ending at the circular recess 200 in the outside surface 194 of the pad. This is carried out after having formed a corresponding hole 236 (see
The perforation module 32 (cf.
Hereinafter, reference is made to
In step (A) of the method, the above-mentioned one-trip well tool 2 is used.
In step (B), and by means of the electric cable 10, the well tool 2 is conveyed into the casing 4 to a location in the well 6 vis-à-vis said region of the annulus 12 to be provided with said liquid sealing mass 151 (cf.
In step (C) (cf.
In step (D) (cf.
In step (E) (cf.
Thereby, as stated in step (F), also the four radially movable connection pads 192 of the injection module 30 are moved to a position in vicinity of the respective hole 236. In
In the well tool 2, the connection pads 192 in the injection module 30 and the respective perforation devices 234 in the perforation module 32 are aligned with respect to each other, and at an axial distance corresponding to the stroke of said massive piston rod 34 in the anchoring module 18. This arrangement thus constitutes, as stated in step (G), an alignment means which allows the connection pads 192 to be aligned vis-à-vis the respective holes 236.
In step (H) (cf.
In step (I), liquid sealing mass 151 is forced out of the storage chamber 142a, 142b and is injected into said region of the annulus 12 via the connection pads 192 and the holes 236 in the casing 4, as shown in
Finally, and in step (J), the connection pads 192 (in the injection module 30) and the gripping elements 38 (in the anchoring module 18) of the well tool 2 are disconnected from the casing 4, after which the well tool 2 is pulled out of the well 6, as shown in
Exemplary Embodiment No. 2
In this context it is mentioned that the well tool 302a, 302b, in another exemplary embodiment (not shown), just as well may be used to force a treatment means, for example the sealing mass 151, into a region of an annulus located between two casings of different diameters, or similar pipe structures.
The two-trip well tool 302a, 302b comprises the following main constituents from the one-trip well tool 2: the connector 16 onto which the electric cable 10 is connected; the valve module 20; the control module 22; the hydraulic oil module 24; the hydraulic pump module 26; the storage module 28. Additionally, the well tool 302a, 302b comprises a running tool 304, an anchoring module 318; an injection module 330; and a perforation module 332.
In this embodiment, the anchoring module 318, the perforation module 332 and the injection module 330 are structured as separate modules, wherein both the perforation module 332 and the injection module 330 are structured in a manner allowing them to be releasably connected to the anchoring module 318. Thereby, both the perforation module 332 and the injection module 330 are movable relative to the anchoring module 318. This is of significance for the use of the two-trip well tool 302a, 302b in the well 6.
In context of the first trip down into the well 6, the first tool assembly 302a of the well tool is conveyed into the casing 4. As viewed from above and downwards, this first tool assembly 302a comprises the connector 16, the running tool 304, the perforation module 332 and the anchoring module 318, as shown in
In this context, the running tool 304 constitutes a simplified combination tool replacing many of the functions described for the above-mentioned valve module 20, control module 22, hydraulic oil module 24 and hydraulic pump module 26. The running tool 304 is therefore structured in a manner allowing it to transmit suitable motive power and control signals for operation of both the perforation module 332 and the anchoring module 318. The construction and the function of the running tool 304 will not be described in further detail here given that its function and mode of operation has been discussed via the description of said modules 20, 22, 24 and 26. Running tools are also considered to constitute prior art given that they exist in different variants for use in context of various downhole operations in a well.
Neither the perforation module 332 (cf.
An orientation pin 308 thus constitutes a first orientation means, whereas an orientation track 306, 410 constitutes a second orientation means in an orientation instrument for the well tool 302. If desirable, the orientation means may be exchanged, such that the orientation track 306, 410 constitutes the first orientation means, whereas the orientation pin 308 constitutes the second orientation means. Such a orientation track may also have another shape, for example a helical shape into which an orientation pin or similar is screwed into upon insertion into the orientation track.
With respect to the perforation module 32, the orientation elements 306 and 308 have already been assembled at surface before said first tool assembly 302a is run into the casing 4. With respect to the injection module 30, however, the orientation elements 410 and 308 are first assembled down in the well 6, which will be explained hereinafter.
Now the anchoring module 318 will be explained in further detail (cf.
Thus, and similar to the module 18, the anchoring module 318 comprises four radially movable gripping elements 338 disposed within a recessed cavity 340. Each gripping element 338 is provided with external gripping teeth 342 as well as two hinge joints 344, 346 disposed pivotally at an upper and lower axial portion, respectively, of the gripping element 338. The lower hinge joint 346 is pivotally connected to a fixed lower wall 348 of the recessed cavity 340, whereas the upper hinge joint 344 is pivotally connected to a lower portion of an axially movable guide sleeve 350. The guide sleeve 350 is axially movable along the inside of an outer sleeve portion 352, which defines a cylindrical cavity 354. A release sleeve 356 having an upper collar 358 is disposed on the inside of the guide sleeve 350. The collar 358 is attached to the guide sleeve 350 by means of a shear pin 360, the function of which will be discussed in further detail in the following, and in context of the injection module 330. The internal release sleeve 356 also comprises a graduated lower portion 362, the circumference of which is provided with several radially and outwardly directed, spring-loaded locking dogs 364. By means of the locking dogs 364, the lower portion 362 of the release sleeve 356 is releasably attached to the inside of a graduated upper portion 366 of an axially directed piston rod 334. The locking dogs 364 are carried through corresponding openings 368 in the upper portion 366 of the piston rod 334 and onwards into a corresponding and ring-shaped locking groove 370 formed on the inside of the guide sleeve 350. Thereby, the upper portion 364 of the piston rod 334 is located between the lower portion 362 of the release sleeve 356 and the guide sleeve 350.
Further, a ring-shaped piston 386 is fixed to the outside of the piston rod 334 and extends outwards onto an outer sleeve portion 388 of a piston cylinder 384a, 384b formed at a lower portion of the anchoring module 318. Thereby, the piston 386 separates the piston cylinder into an upper cylinder chamber 384a and a lower cylinder chamber 384b. A hydraulic conduit 390 (shown schematically with a dashed line in
At an upper portion of the anchoring module 318, and at the inside of said outer sleeve portion 352, a ring-shaped locking groove 402 facing into the cavity 354 is also formed. Additionally, said orientation pins 308 (only one pin 308 of which is shown in
Hereinafter, reference is made to
In order to carry out said first function in the well 6, the injection module 330 comprises all constituents from the injection module 30. These constituents have the same construction and mode of operation as described in context of the injection module 30. In
In order to carry out said second function in the well 6, the injection module 330 also comprises a connection unit 406 structured for controlled and releasable connection to the anchoring module 318. An upper portion of the connection unit 406 comprises an external, ring-shaped lock ring 408 structured for releasable connection to said ring-shaped locking groove 402 at the inside of the outer sleeve portion 352 in the anchoring module 318. This upper portion also comprises said external and Y-shaped orientation tracks 410, which are structured for controlled reception of said orientation pins 308 at the inside of the outer sleeve portion 352. This is equivalent to the corresponding orientation means in the perforation module 332.
In order to assist the insertion and the releasable connection within the anchoring module 318, the lower portion of the connection unit 406 is comprised of an axially directed and releasable anchoring shaft 412. At its outer and free end, the anchoring shaft 412 is provided with a connector head 414 having a lock ring 416 comprised of radially biased and axially directed locking segments 416a which, at an inner end thereof, are fixed to the shaft 412, and which, at an outer and free end thereof, are provided with respective locking dogs 416b. The anchoring shaft 412 also comprises a narrower longitudinal portion forming an axially directed depression 418 within which the locking segments 416a and the locking dogs 416b may flex radially inwards and outwards in context of connection to or from the anchoring module 318.
After the injection module 330 has injected the sealing mass 151 into said region of the annulus 12, the injection module 330 may be released from the anchoring module 318 by pulling the connection unit 406 on the injection module 330 out of the anchoring module 318. This is carried out by pulling the electric cable 10 upwards using a sufficient release force. In this context, said shear pin 360 will be severed, and said spring-loaded locking dogs 364 will be forced out of their locking groove 370 in the guide sleeve 350. Thereby, the release sleeve 356 will be released from the guide sleeve 350 in the anchoring module 318 and, due to said collar 358 on the release sleeve 356 as well as said lock ring 416 on the anchoring shaft 412, will follow the anchoring shaft 412 when being pulled out of the anchoring module 318. The latter is not shown in any figures.
Hereinafter, reference is made to
In step (A) of the method, the above-mentioned two-trip well tool 302a, 302b is used.
In step (B), and by means of the electric cable 10, the well tool's first tool assembly 302a, which is releasable, is conveyed into the casing 4 to a location in the well 6 vis-à-vis said region of the annulus 12 to be provided with said liquid sealing mass 151 (cf.
In step (C) (cf.
In step (D) (cf.
In step (E) (cf.
In step (F) (cf.
In step (G) (cf.
In step (H) (cf.
In step (I) (cf.
Finally, in step (J) (cf.
| Number | Date | Country | Kind |
|---|---|---|---|
| 20092315 | Jun 2009 | NO | national |
| Filing Document | Filing Date | Country | Kind | 371c Date |
|---|---|---|---|---|
| PCT/NO2010/000227 | 6/14/2010 | WO | 00 | 12/15/2011 |
| Publishing Document | Publishing Date | Country | Kind |
|---|---|---|---|
| WO2010/147476 | 12/23/2010 | WO | A |
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| 20090173500 | Orban et al. | Jul 2009 | A1 |
| Number | Date | Country |
|---|---|---|
| WO 03072905 | Sep 2003 | WO |
| WO 2006098634 | Sep 2006 | WO |
| Number | Date | Country | |
|---|---|---|---|
| 20120085539 A1 | Apr 2012 | US |
