CN1748073B - Downhole tool - Google Patents

Abstract

A downhole tool comprising: an axial drive unit ( 10 ) having a connection for an electric power cable extending up the borehole, and including an anchoring mechanism ( 12, 16 ) operable in the borehole between a first configuration in which the anchoring mechanism resists rotational and axial movement of the unit, and a second configuration in which the anchoring mechanism is moveable axially inthe borehole, an axial drive mechanism that moves the anchoring mechanism axially down the borehole when in the second configuration; a motor ( 28 ) mounted on the drive unit at the downhole end thereof; an hydraulic pump ( 30 ) connected to the motor, the pump providing a source of hydraulic power; and a functional unit connected below the hydraulic pump and powered thereby, operation of the axial drive mechanism acting to move the functional unit axially down the borehole.

Description

Downhole tools

technical field

This invention relates to downhole tools, and more particularly to drilling tools for use in such wells as oil, water and natural gas wells.

Background technique

In the construction and handling of subterranean wells, there are many basic techniques for transporting and operating drilling tools. For example, when drilling, a drill bit is secured at the lower end of a drill string formed by a series of empty drill pipes joined end to end. By rotating the drill string at the surface, or by using a perforating motor, the drill bit is rotated, and this rotation and the weight applied to the bit allow drilling to occur. To remove drilled material and to help pump drilling mud (commonly known as "mud") down the inside of the drill string during drilling to exit the drill bit and surround the annulus outside the drill string The drilled material ("cuttings") is transported back to the surface. Drilling mud also provides support for drilling and balances the hydraulic pressure of the formation due to the hydrostatic pressure generated by the liquid column. In a development of this technology, the motor, typically in the form of a Moyno (Positive Displacement) unit, is installed in the drill string above the bit. The motor is driven by the mud flow and can be used to turn the drill bit independently of the rotation of the drill string. This technology, combined with a curved perforating assembly ("bent sub") and directional sensors enables the direction of drilling to be controlled. For straight line drilling, a technique of rotating the drill string ("rotary drilling") and rotating the bit with an electric motor is used. To change direction, stop rotary drilling, restart drilling by rotating the drill string from the surface and using the perforating motor to rotate the bit, and apply heavy pressure to the bit from the surface through the drill string (“slip mode drilling”), bending the submersible Orientate so that the face of the drill is pointing in the intended direction. When the desired direction is obtained, the rotary drilling is resumed.

The measuring device may also be provided in the lower part of the drill string ("Bottom Hole Assembly" or "BHA"). When the BHA is withdrawn from the hole, these devices, for example, measurement-drilling ("MWD") devices are used for measurements related to the drilling process: bit weight, ROP, direction and inclination, or drilling measurement ("LWD") devices For measurements involving formations: resistance, nuclear measurements, acoustic measurements, data can be provided to the surface via mobile storage devices, via cables arranged in the drill string, or via mud pulse telemetry, which is carried out at the surface through An alarm located in the BHA detects pressure pulses generated while drilling the mud.

Any activity involving the use of a drill string requires the presence of a drilling platform at the surface. Also, the time it takes to put the drill string into the core and pull the drill string out of the well is quite long, especially in very deep wells.

Once the hole has been drilled, the surveying device can be lowered into the hole with a cable ("wire", "wire", "smooth wire") that provides power and data communication between the downhole tool and the surface. This operation does not require the use of a drilling rig and can be performed fairly quickly. However, so far, it has only been possible to use wires for drilling operations in a small area, considering the difficulty in providing power, torque, and weight to the perforating bit. Coring is an example of a drilling activity that is conducted via a wireline system. Coring is the use of a cylindrical drill bit to extract a solid core of material from the rock surrounding the hole, which is returned to the surface for analysis. An example of a wire core unit is shown in US4,354,558. Another wire arrangement has been proposed for drilling relatively small holes from the side of the main hole. All of these devices provide only relatively short drainage holes and all have problems providing torque and weight to the drill bit, especially the metal casing that needs to be drilled through the well before drilling into the rock. One approach, as shown in US 6,167,968, involves separating the act of drilling or milling through casing using short hard milling cutter elements from the act of drilling into rock using elastic drill elements. In another technique, the flexible drill shaft is surrounded by a series of discs that both provide support and allow pressure to be applied to the drill bit. This technique is shown in US6,276,453. Another way to provide traction and torque separately is shown in US 5,687,806.

Another problem when drilling horizontal wellbores is gravity. In vertical or not very deviated semi-vertical wellbores, wires, cables, coiled tubing, tubular ropes and tools introduced into the wellbore are lowered down the wellbore by gravity. When the cable reaches 70° from vertical, gravity no longer provides the required force and resulting tension to move the tool into the wellbore. For example, in US Pat. No. 4,463,814, some prior art methods disclose retractors with anchoring devices.

EP1247936 describes a wire tool that can go inside a drill pipe and is used to drill outside a drill string via a side exit mandrel in a bottom hole assembly to obtain core. In this device, a packer is expanded inside the drill pipe, an electronic piston submersible (sub) is positioned above the packer, and a drilling motor and core bit are positioned below the packer. The piston provides heavy pressure to the drill bit drive through a sliding seal in the packer, and torque is provided by the mud flow transferred from the inside of the drill string to the drilling motor below the packer. Drilling mud and cuttings are returned to the surface in the normal manner via the annulus at the sides of the center hole and the annulus of the main hole. The packers in this setup act as reaction points for applying torque and weight to the drill bit during drilling. It also flows drilling mud through the motor. However, because it needs to provide a sliding seal through the packer, this design limits its ability to provide extended drilling depths. Also, it must supply drilling mud from the surface and return the annulus of drilling mud and cuttings.

One particular use of such drilling tools is drilling re-entry, where further drilling operations are performed on exiting the well for increased production, corrections, and the like. A review of this technique can be found in Hill DNerne E, Ehlig-Economides C, and Mollinedo M, "Reentry Drilling Gives New Life to Aging Fields", Oilfield Review (1996 Found in 4-14 August). One particular tool described is the VIPER Coiled Tubing Drilling System (Coiled Tubing Drilling System), which includes a drill module with connectors for electrical cables, an anchor tool including many sensors and associated electronics, including motors and power equipment directional tool, and a drilling unit with a steerable motor. Although the system provides power and data via the wireline, it also needs to provide coiled tubing to push the tool along the well.

Contents of the invention

It is an object of the present invention to provide a downhole tool which can be run with wire and which can provide sufficient torque and weight to the drill bit to enable efficient drilling.

According to the present invention, there is provided a downhole tool comprising: an axial drive unit having connections for extending a power cable to a wellbore, and comprising an anchoring mechanism operable in a first configuration in said wellbore ) and a second configuration in which the anchoring mechanism resists rotational and axial movement of the drive unit in which the anchoring mechanism is in the second configuration axially movable in the well; an axial drive mechanism which axially moves the anchoring mechanism along the well when in the second arrangement; a motor mounted on the drive unit which is the downhole end of the drive unit; a hydraulic pump connected to the motor, which pump provides a source of hydraulic power; and a functional unit connected below the hydraulic pump and powered thereby, the axial Operation of the drive mechanism is used to move the functional unit axially down said well.

Preferably the orientation unit is located below the drive unit, which allows at least part of the tool below the drive unit to pivot about an axis, thereby allowing asymmetry in the orientation of the functional unit in a particular orientation. A diverting member, such as a kick plate, may be located below the functional unit to push the unit in a predetermined direction upon operation of the drive unit, propelling the functional unit down into the wellbore.

The well is generally filled with fluid, which is preferably used by the hydraulic pump as a supply of hydraulic fluid to provide hydraulic power.

A functional unit has many possible functions: drilling, well filling, measurement, stimulation, remediation, etc. functions, and any combination of these functions. Wherein the functional unit has a drilling function, it preferably comprises a drilling motor powered by hydraulic fluid from the pump. The drilling motor is generally connected to the pump (which is driven by the motor) through a hollow drill shaft through which fluid flows, and the drilling unit is pushed forward by the drive unit. The drill can be connected to a drilling motor.

By appropriate use of a recoil plate and/or a bend sub in a drilling tool (e.g., the bend sub is positioned along a plane substantially perpendicular to the recoil plate, with the drill bit facing away from the plate), it is possible to Keep the drill bit away from the well to drill. The extension of drilling away from the well depends on the length of the drill shaft. Preferably, at least one support is provided on the drill shaft to avoid bending during drilling.

To prevent drilled material from blocking the well or causing the tool to get stuck, a cuttings collector can be located under the drilling unit and mounted to the tool, the collector (usually a bag or storage tube) can be pulled out of the well with the tool along with the wireline . Diverters (eg rubber caps) may be located above and below the drilling unit to force cuttings into the collector. In this case, it is preferred to provide circulation pipes to circulate the fluid back into the wellbore from which cuttings have been removed. Alternatively, one or more baffles are provided to direct fluid containing cuttings downhole below the tool to avoid sticking.

Optionally, the drilling unit may also include a measurement unit and a swell packer for providing pressure isolation of part of the well. The latter feature is useful when using the tool for formation pressure measurements.

Alternative forms of functional units may include completion units. It generally consists of a tubular packing member, such as a casing or screen, which is advanced into the well, typically with the aid of a properly positioned recoil plate or whipstock, and is disengaged as the tool is withdrawn from the well. stay in place. The pack may be packed with a fill fluid, such as a binder slurry or gravel pack, which is pumped out of the pack by means of a hydraulic pump into the well around the pack.

The tool also includes a storage unit located in the well, wherein at least one functional unit can be stored when not in use. In this case, preferably a latching system is provided for disengaging the functional unit stored in the storage unit from the rest of the tool.

Another embodiment of the tool includes an imaging device for locating the portion of the well on which the tool will operate.

Description of drawings

Describe the present invention below by the embodiment shown in the accompanying drawing, wherein:

Fig. 1 represents the common feature of the first embodiment of the present invention;

Fig. 2 represents the structure that the embodiment of Fig. 1 is used for drilling;

Figures 3a and 3b show the embodiment of Figure 2 at different stages of drilling operations;

Fig. 4 represents the structure that the second embodiment of the present invention is used for drilling;

Fig. 5 represents the structure that the third embodiment of the present invention is used for drilling and measuring;

Fig. 6 shows the structure for drilling and pressure measurement of the fourth embodiment of the present invention;

Figures 7a and 7b represent the structure and structure used to complete different stages of operations in the fifth embodiment of the present invention.

Fig. 8 shows the structure of the sixth embodiment of the present invention for multiple operations.

Detailed ways

Referring now to the drawings, there are shown various embodiments of the invention. While all of these embodiments described herein are open hole, it should be understood that this could also be a cased well, or include drill string or production tubing. All such understandings are included in the use of the term "drilling". Also, in the context of well and tool arrangements, the term "upper" is used to mean a direction toward the surface, and "down" means a direction away from the surface, even if the well in question is not vertical. A first embodiment of the invention is shown in Figure 1 and comprises a drive unit 10 comprising connections for an electrical cable (not shown). The drive unit 10 is basically a tractor unit such as that described in US 5,954,131. However, in the structure described here, it sits on top of the tool string and is used to push the tools along the well rather than pull them behind it. Also, wires are used to provide power and data below the unit 10 .

The drive unit is operated by means of a locking member 12 located at one end of the unit 10 extending against a drilling wall 14 . Corresponding locking members 16 are provided at the other end of the drive unit 10 , however, in this first arrangement they are not locked relative to the drilling well 14 . The portion of the drive unit between the locking members 12 , 16 includes an extension and retraction mechanism 18 . The mechanism 18 is operated to push the lower portion of the drive unit downhole. Once the mechanism 18 is fully extended, the unit is advanced by locking the lower part 16 relative to the well 14, the upper part 12 unlocked from the well 14, and retracting the mechanism 18, thereby pulling the upper part of the unit down the well. This cycle can be repeated whenever necessary. When it is desired to transport the tool to a vertical part of the well or to withdraw the tool from the well, the set of parts 12, 16 is unlocked and the tool is moved down by gravity or pulled back to the surface by the cable in the usual manner.

Next, the orientation submersible 20 is located below the drive unit 10 . It is essentially the same submersible used in the above-mentioned VIPER coiled-tube drilling system. The directional submersible includes a motor and allows relative axial rotation between the upper tool section and the lower submersible.

The control submersible 22 is located below the orientation submersible 20 . Controlling the submersible 22 includes a number of functions for controlling the tool (including power supplies), and for controlling the telemetry system, system control logic, and the like.

Below the control vehicle 22 (or possibly forming part of the control vehicle 22 ) is the navigation vehicle 24 . It includes accelerometers, magnetometers and gyroscopes for determining the position and orientation of the tool in the well 14 . Suitable sensors include Schlumberger's GPIT inclinometer, or the aforementioned VIPER tool's navigation sensor. Navigation subs can sit on top of orientation subs. In this case, a pointer function is required to record the relative position of the tool part under the orientation submersible relative to the navigation submersible.

A pumping unit 26 comprising a motor 28 driving a Moyno (positive displacement) pump 30 is located below the navigator submersible 24 . The size and power of the motor 28 and pump 30 are selected according to operating constraints. For example, the power of the motor 28 depends on the amount of power available on the wireline and the maximum size constraints that the tool string can pass through the drilling well, production tubing, etc. The output of the pump 30 is affected by the output power of the motor 20, the speed of the motor 28, and the size constraints of the operation. The pump has an inlet 32 at its upper end to allow drilling fluid to flow into the pump and an outlet 34 at its lower end from which fluid is pumped to provide hydraulic power supply.

The functional unit of the invention is mounted at the outlet port 34 of the pump 30 . Figures 2-7 represent functional units in the form of drilling tools. As shown in FIG. 2 , a drill shaft 36 in the form of a small diameter drill pipe (eg, 1.5") connects the output of the pump 30. The length of the shaft depends on the maximum length of any side hole drilled from the main well 14. Drill motor 38 Located at the lower end of the shaft 36. The drill motor 38 is generally a Moyno device (similar to the pump 30, except in this configuration, it is driven by fluid flow from the pump 30 via the drill pipe 36 to the motor). 38 is generally relatively small (21/8" or 23/8") and generally includes a bend in the housing like known directional drilling operations. It is actually preferred to use a bending motor with a The distance forms a sufficient angle to form an effective side hole from the main bore 14 .

A drill bit 40 (eg, 2.4") is mounted to the drill motor 38 in the normal manner.

The recoil plate 42 is located below the drill bit, but is connected directly to the upper part of the drive unit 10 by a support 43 . The recoil plate 42 comprises a plate or other flat surface that is angled relative to the axis of the well and is used to propel the drill bit in a particular direction relative to the well. In operation, the recoil plate functions in a similar manner to a whipstock, as described below. The support 43 is connected to the drive unit via a lockable sliding connection 44 . A swivel 46 is provided part way along the support 43 to allow the recoil plate 42 to be oriented during drilling by operating the directional submersible 20 . The function of the recoil plate 42 is described in detail below.

In use, the tool is lowered into the well using the wireline until the desired depth is reached. In this position the drive unit 10 locks and drives the electric pumping unit 26 by operating the locking part 12 . Fluid ("mud") is pumped from the main well 14 into the small drill pipe 36. The mud flows into the drill pipe 36 and to the motor 38 which rotates the drill bit 40 .

The directional submersible 20 ensures that the drill motor 38 is flexed and the recoil plate 42 is facing the correct direction (often referred to as the "tool face") before starting to drill. Axial displacement and weight on bit (“WOB”) are transmitted through the drive unit 10 .

This combination technique allows the drill bit 40 to advance into the formation and drill a curved hole due to the curved drilling motor 38 . The bend angle is chosen such that side hole 50 is turned 90 degrees over its length (typically about 100 feet), as shown in Figures 3a and 3b. Mud circulation in the side bore 50 is provided by the pumping unit 26 in the main bore 14 via the small drill string and drill bit. The cuttings in the side holes 50 are transported by mud and fed into the main hole 14 and deposited in the cuttings collection device as described below with reference to FIG. 4 .

When drilling of one side hole 50 is complete, if the cuttings collection bag is not full, the wire drilling system can move to another depth and start drilling another side hole.

The recoil plate 42 is a guide plate set at an angle to the axis of the main bore 14 . The plate 42 acts as a whipstock to generate lateral force on the bit 40 and propel the bit into the formation. Such a recoil plate 42 is generally connected to the drive unit 10 via a sliding connection 44 . The recoil plate 42 may remain in a fixed position on the well 14, or fixed at a distance from a stationary part of the drive unit 10 when recoil plate drilling is activated. During a first pushing displacement of the driving unit 10, the drill bit 40 is pushed into contact with the recoil plate 42 after the upper part of the driving unit 10 is locked in the well. Once the drill bit 40 begins to penetrate the wellbore wall to form the side hole 50, the kickback plate 42 may move away from the point of entry when the drive unit 10 is repositioned in the wellbore 14.

In an alternative, the recoil plate is held by two support tubes parallel to the drill string. These tubes slide into connection 44 of the drive unit 10 and use a swivel joint, as described above. Connections for support tubes are mounted to the middle or upper part of the drive unit. The sliding of the support tube in the connection can be controlled by a locking system in the connection, as follows:

a) At the beginning of the drilling of a new side hole, the drive unit is shortened so that the upper and lower parts are together, then its upper part is locked in the hole while its lower part is released.

b) Locking system locking for recoil plate support tubes. This fixes the tube relative to the upper part of the drive unit.

c) Then, the drive unit starts to extend. This pushes the bottom member (including the drill string) towards the bottom. The bit hits the recoil plate and is displaced axially, forcing the bit into the formation.

d) When the drill bit has sufficiently entered the lateral formation, the locking system for the support pipe can be released. In some cases, it requires some option to maintain the recoil plate in its initial position relative to the well, rather than relative to the drive unit, during the completion of the side hole drilling operation.

Another embodiment of the invention, shown in Figure 4, ensures that the well around the recoil plate 42 is hydraulically isolated. This isolation is achieved by two rubber caps 52 , 54 (replaced by two packers), which seal the upper and lower drilled sections of the well 14 . This isolation forces mud that flows out of side hole 50 during drilling into a cuttings collection bag 56 mounted on lower cap 54 . As the tool is moved in the wellbore, the rubber cap or packer contracts or shrinks.

Cuttings bag 56 includes a large bag mounted on or near kickback plate 42 . The bag collects cuttings carried by the mud coming out of the side hole 50 during drilling. In the preferred arrangement, bag 56 extends below recoil plate 42, as shown in FIG. The filling mechanism allows the cuttings to circulate correctly (with mud flow back to ensure proper filling), eg a "bellows" type bag mounted on the lower cap 54 . A circulation pipe 58 is installed between the caps 52 and 54 . The bag 56 is permeable so that the cuttings are retained while the mud passes back into the pipe 58 and into the well 14 near the pumping unit 26 . Alternative devices include permeate tubes that collect cuttings instead of bags, or baffle devices that direct cuttings to the well 14 below the tool, if not necessary to enable re-entry into the lower part of the well.

The drill tube 36 between the pumping unit 26 and the motor 38 transmits the axial force from the drive unit 10 to the drill bit 40 in a compressed state and ensures the overweight of the bit (WOB). The diameter of the pipe is generally small (maybe between 1-1.75") and the pipe length is about 150 feet. In some drilling applications, up to 3 tons of WOB are required. This axial loading can have destabilizing effects in the drill pipe (buckling effect). In large-diameter drilling, the drill pipe may produce large deformations, which will be detrimental to the structure of the drill pipe and the drilling process. In order to avoid the instability of the drill pipe 36 in the large hole part, the pipe guide 60 can be along the pipe 36 are installed at different distances. These guides may comprise a cross-shaped part whose size approximates the diameter of the main bore. The tube 36 slides in the guide 60. The guides 60 are connected to each other with elastic connectors 62, thereby limiting the maximum spacing. The connectors 62 The upper end is connected with the driving unit 10 , and the lower end is connected with the recoil plate 42 .

The WOB is generated by the drive unit 10, which preferably operates at a constant force rather than a constant speed. When the drill motor 38 stops (which can be detected by real-time pump pressure monitoring), it is controlled to rapidly reduce WOB.

A small logging measurement) submersible 64 may be installed between the drilling pipe 36 and the motor 38, as shown in FIG. 5 . When having an internal bore of approximately 1" for internal mud flow, this submersible 64 typically has approximately OD. This submersible contains at least the smallest components to support the measurement and is connected to the control submersible 22 below the drive unit 10. Communication can be based on wire or wireless telemetry. The control submersible 22 controls the measurement submersible feeder 64, and transmit data to the ground through cables.

The survey sub 64 may include the following functions:

- Resistance measurement. This can be electrode based (side recording), induction coil based, or loop antenna based. Localized electronics can be used for measurements while limiting crosstalk effects.

- Inclinometer to determine the inclination of the side hole.

- Miniature gamma ray detector.

- Pore pressure measurement in the damaged area as shown in Figure 6. An expandable packer 66 may be provided to isolate the annulus of side hole 50 . A pressure gauge is mounted inside the drill string 36 below the pumping unit 26 . Packer 66 seals the small annulus while pump 30 is run in reverse phase mode to "clean out" small wellbore 50 near drill bit 40 during the measurement. This allows formation pressure to be measured. If the pump 30 used for drilling cannot generate low enough pressure near the drill bit 40, a piston pump (not shown) can be used in parallel for large pressure reduction (valve is required to isolate the drilling pump).

An integrated logging and drilling method allows the determination of a profile of logged data versus axial distance from the borehole. High definition features perpendicular to the main wellbore can be achieved.

The ability to re-enter the small side hole 50 after the tool has been withdrawn from the borehole 14 is important. Since depth and direction measurements may not be sufficient, wellbore images (from electronic or ultrasonic images, such as Schlumberger's FMI, OBMI or UBI tools) are required. These images allow the operator to visualize small radius holes (which appear as oblong ellipses on the well wall). For this application, the drilling system should allow for "though-wiring" so that the imaging tool can be installed under the recoil plate. Logging on top was initially performed to locate the keyhole. When positioned, the drive unit 10 is used to lower the drill bit 40 to the correct depth (and in the correct orientation). The improved positioning of the device for re-entry into the side hole and the depth deviation between the imaging system and the device can be measured by the displacement of the drive unit.

In the embodiment of the invention shown in Figures 7a and 7b, the drilling arrangement of the tool described above is replaced by a filling function. In the illustrated example, a liner 70 preloaded with binder slurry 72 and provided with pistons at the top 74 and bottom 76 is connected to the end of a drill pipe 73 using a drive Unit 10 and recoil plate 42 are drilled into bore 14 and advanced into side hole 50 . When the liner 70 is in the side hole 50 (FIG. 7b), the pumping unit 26 is operated to pump the upper piston 74 down inside the liner, forcing the lower piston 76 out (or severing the seal at the lower end of the liner). ), and forces the adhesive slurry into the annulus around the liner 70 in the side hole 50, allowing it to settle there. The liner 70 is then disengaged from the drill pipe 73 and the tool is withdrawn from the well 14 . If the liner 70 extends from the side hole 50, it needs to protrude from the milled portion of the wellbore wall. This may be done with a special tool or a suitable functional unit installed on the tool of the present invention.

Other fill options are also available, as follows:

a) The liner may be a slotted liner.

b) The filling may consist of a scintilite-packed filter. Again, for delivery into the pores, the packaged asterite is contained inside the filter and pumped out in the same manner as above for bonding. In this case it is necessary to provide a temporary liner inside the barrier to allow the package to be pumped out of the end of the barrier.

c) Intelligent completion with integrated valve and measuring system.

In some applications it is important to perform multiple operations in one run of the main bore. An example is a lateral drilling and lateral permanent sensor installation.

For this application, two head systems can be used. Initially, the system is oriented so that the drill bit faces the correct direction laterally. After drilling, the directional submersible turns the drill bit 180 degrees (without a kick pad). In this case, the clutch is disengaged from the recoil pad (when needed) in the direction of the drill. Then, another drill bit is positioned in front of the recoil pad, ready to go into the side hole. For example, this could be a permanently installed system for lateral orientation.

Figure 8 shows the structure of an embodiment of the present invention for multiple operations. The recoil pad 42 provides a clutch system for rotation (or non-rotation) with the directional submersible 20 and the drilling motor. Also, the recoil pad can be equipped with two or more barrels 80, 81 to house the motor and other functional elements when unlatched.

For this application, the motor 38 is connected to the drill pipe 36 through a latch system 82 controlled by the control submersible 22 . This allows the motor 38 to be unlatched so that it is left in the large recoil bucket 80 . The drill pipe latch 82 may then be introduced into another keg 80 in the recoil pad 42 . This keg 80 can be loaded with different functional units 84 stopped by a latch system 82 . This allows the drill pipe 36 to be latched onto the latch system 82 . The tool can then be used to push the functional unit 84 into the side hole 50 and install it permanently (if desired), as described above.

The invention can also be applied to cased wells. In this case, the first run to the proper location requires a milling cutter to create a window in the casing, after which drilling and/or other operations can be performed, as described above.

Changes are also required when the tool is ready for use in passing production tubing. For example, a wireline fishable whipstock may be used in place of the kickback plate. Also, tools such as multi-finger calipers can replace imaging tools for locating holes in casings.

Claims (22)

1. downhole tool, it comprises:

(i) an axial driver element (10), it has and is used for the connection that power cable extends to drilling well (14), and comprises

One anchor mechanism (12,16), it is operable in described drilling well (14) between one first layout and one second layout, it resists the rotation of described unit (10) and axial moving in this first layout, can move axially in described drilling well (14) at anchor mechanism (16) described in this second layout

One axial actuating mechanism (18), it axially moves described anchor mechanism (16) when arranging when being in described second along described drilling well;

It is characterized in that it also comprises:

A (ii) motor (28) that is installed on the described driver element (10), it is in the downhole end of described driver element (10);

A (iii) hydraulic pump (30), it connects described motor (28), and this pump provides a hydraulic power supply; With

A (iv) functional unit (38,40), it is connected below the described hydraulic pump (30) and is supplied to power thus, and the operation of described axial actuating mechanism (18) is used for this functional unit is axially moved on under the described drilling well (14).

2. instrument as claimed in claim 1 wherein also comprises a directed unit (20), and it allows the pivoting to the small part instrument below described driver element (10).

3. instrument as claimed in claim 1 wherein also comprises a turning member (42), and it is positioned at below the described functional unit (38,40), and it is used for promoting described functional unit along a predetermined direction when operation driving mechanism (18).

4. instrument as claimed in claim 1, wherein said hydraulic pump (30) use the fluid in the described drilling well (14) that hydraulic power supply is provided.

5. instrument as claimed in claim 1, wherein said functional unit are well construction devices.

6. instrument as claimed in claim 5, wherein said well construction device comprises a drilling assembly.

7. instrument as claimed in claim 6, wherein said drilling assembly comprise a probing motor (38), and it obtains power by the hydraulic power supply that comes from described pump (30).

8. instrument as claimed in claim 7 wherein also comprises a drill bit (40), and it is driven by described probing motor (38).

9. instrument as claimed in claim 7, wherein said probing motor (38) connects described pump (30) by a hollow auger spindle (36), and hydraulic fluid flows through this hollow auger spindle.

10. the instrument shown in claim 9 comprises also that wherein at least one is installed in the support component on the described auger spindle, and opposing is crooked to support when drilling.

11. as each described instrument among the claim 6-10, wherein also comprise at least one deflection plate (42), its drilling cuttings that is configured to get out is directed at the well under the described instrument.

12. as each described instrument among the claim 6-10, wherein also comprise a swarf collector for drills (56), it is positioned at below the described drilling assembly and is installed on the described instrument, is used to collect the material that described drilling assembly gets out.

13. instrument as claimed in claim 12 wherein also comprises a plurality of steering gears (52,54), its be positioned at the top of described drilling assembly and below, enter described gatherer to force drilling cuttings.

14. instrument as claimed in claim 13 wherein also comprises a circulation pipe (58), it extends between described a plurality of steering gears, to allow fluid loop back up to the drilling well of removing drilling cuttings.

15., wherein also comprise a measuring unit (64) that is arranged in described drilling assembly as each described instrument among the claim 6-10.

16. as each described instrument among the claim 6-10, wherein also be included in the swell packers (66) above the described drilling assembly, it allows that described at least drilling assembly is positioned at the pressure isolation of part drilling well wherein when expanding.

17. instrument as claimed in claim 5, wherein said well construction device comprises a filler cells.

18. instrument as claimed in claim 17, wherein said well construction device comprises a tubulose filling component (70), it can advance to by the operation of described driver element (10) in the drilling well (14), when described instrument when described drilling well (14) is extracted out, broken away from and remained on the appropriate location.

19. instrument as claimed in claim 18, wherein said filling component is filled with a fill fluid (72), and this fill fluid comes out to go forward side by side around the drilling well of described filling component from described filling component pumping by means of hydraulic pump (30).

20. as each described instrument among the claim 1-10, wherein also comprise a memory cell that is arranged in described drilling well, at least one functional unit can be stored in this memory cell when not using.

21. instrument as claimed in claim 20 wherein also comprises a latch system (80,81), it is used for making the functional unit that is stored in described memory cell to break away from and being connected of remaining instrument.

22. as each described instrument among the claim 1-10, wherein also comprise an imaging device, it is used to locate the drilling well part of described instrument with operation.

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