Apparatus for performing multiple downhole operations in a production tubing tubular

Abstract

A downhole apparatus including a sleeve, a tool string, a plug, a means for setting the plug wherein an upper portion of the sleeve is connectable to a lower portion of the tool string, and a lower portion of the sleeve is arranged to receive the plug and the means for setting the plug. A method for using the downhole apparatus (1) is disclosed.

Claims

1. A downhole apparatus, the downhole apparatus comprising: a tool string; a plug; a means for setting the plug; an upper portion of a sleeve is connectable to a lower portion of the tool string, and a lower portion of the sleeve is arranged to receive the plug and the means for setting the plug; and wherein the sleeve, between its upper portion and lower portion, is configured to house at least a tubing cutting tool, the tubing cutting tool is connected to the tool string, and the tubing cutting tool is displaceable relative to the sleeve.

2. The downhole apparatus according to claim 1, wherein the sleeve, between its upper portion and lower portion, is configured to house the tubing cutting tool and a tubing punching tool.

3. The downhole apparatus according to claim 1, wherein the sleeve is arranged to house at least a portion of the means for setting the plug.

4. The downhole apparatus according to claim 1, wherein the means for setting the plug communicates with a control device via a communications means.

5. The downhole apparatus according to claim 1, wherein the lower portion of the tool string is connected to the upper portion of the sleeve by a releasable latching mechanism.

6. The downhole apparatus according to claim 1, wherein the sleeve is configured as a junk basket when disconnected from the tool string.

7. Method for a downhole operation using a downhole apparatus comprising a tool string, a plug and a means for setting the plug, an upper portion of a sleeve being connectable to a lower portion of the tool string, and a lower portion of the sleeve being arranged to receive the plug and the means for setting the plug, the sleeve, between its upper portion and lower portion, is configured to house at least a tubing cutting tool, the tubing cutting tool is connected to the tool string and tubing cutting tool is displaceable relative to the sleeve, wherein the method comprises the steps of: a) running the downhole apparatus into a well, and b) setting the plug in a well tubular.

8. The method for a downhole operation according to claim 7, wherein the method, after step b), further comprises the steps of: c) releasing the sleeve from the tool string; d) displacing the tool string relative to the sleeve, and e) cutting the well tubular above the sleeve.

9. The method for a downhole operation according to claim 7, wherein the apparatus further comprises a punching tool, the method, after step b), further comprises the steps of: f) releasing the sleeve from the tool string; g) displacing the tool string relative to the sleeve, and h) perforating the well tubular above the sleeve.

10. The method for a downhole operation according to claim 7, wherein the apparatus further comprises a punching tool, the method, after step b), further comprises the steps of: i) releasing the sleeve from the tool string; j) displacing the tool string relative to the sleeve; k) perforating the well tubular above the sleeve, and i) cutting the well tubular above the sleeve.

Description

BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS

(1) In the following is described an example of a preferred embodiment illustrated in the accompanying drawings, wherein:

(2) FIG. 1 shows a schematic elevation, partially in cross-section, of the downhole apparatus according to one embodiment of the invention;

(3) FIG. 2a shows in a larger scale the detail A of the latching mechanism in FIG. 1;

(4) FIG. 2b shows the downhole apparatus in FIG. 1, comprising a control system.

(5) FIG. 3a shows the downhole apparatus in FIG. 1 in a smaller scale, wherein the plug is set and the tool string disconnected from the sleeve.

(6) FIG. 3b shows the same downhole apparatus as in FIG. 3a, wherein holes have been punched in the well tubular.

(7) FIG. 3c shows the same downhole apparatus as in FIG. 3b, wherein the well tubular has been cut.

(8) FIG. 4a shows a schematic elevation, partially in cross-section, of the downhole apparatus according to another embodiment of the invention;

(9) FIG. 4b shows a schematic elevation, partially in cross-section, of the downhole apparatus according to a third embodiment of the invention.

DETAILED DESCRIPTION OF THE INVENTION

(10) The figures are depicted in a simplified manner, and details that are not relevant to illustrate what is new with the invention may have been excluded from the figures. The different elements in the figures may necessarily not be shown in the correct scale in relation to each other. Equal reference numbers refer to equal or similar elements. In what follows, the reference numeral 1 indicates a downhole apparatus according to the invention.

(11) The downhole apparatus 1 comprises a sleeve 2. An upper portion 210 of the sleeve 2 is releasably connected to a lower portion 310 of a tool string 3 by means of a latching mechanism 32. A lower portion 211 of the sleeve 2 is connected to a plug 4 and a plug setting tool 41. The sleeve 2 is shown housing a tubing punching tool 5 and a tubing cutting tool 6.

(12) FIG. 1 shows the plug 4, in this particular embodiment shown as a temporary barrier plug, connected to the lower portion 211 of the sleeve 2 via the plug setting tool 41. The plug 4 may be installed at a desired location in a production tubular 510 (see FIGS. 3a-3c) by means of the plug setting tool 41. The plug setting tool 41 is housed within the sleeve 2. In another embodiment, the plug setting tool 41 may be an integral part of the plug 4. When the plug 4 is set in the production tubular 510, the sleeve 2 may be released from the tool string 3, and the sleeve 2 may be left in place together with the plug 4 and the plug setting tool 41 (see FIGS. 3a-3c).

(13) FIG. 1 further shows the sleeve 2 housing a tubing punching tool 5, in the following called a puncher. The puncher 5 is connected to the lower portion 310 of the tool string 3. The puncher 5 is configured to punch, i.e. perforate, a production tubular 510 in the well 500 (see FIG. 3a-3c) to allow for circulation of a fluid 600 from the well 500 to an annulus 511 between the production tubular 510 and a casing 512 (see FIG. 3a-3c). The puncher 5 may be an explosive device or a mechanical device or a device of another working principle. After setting the plug 4 and disconnecting the sleeve 2 from the tool string 3, the puncher 5 is pulled out of the sleeve 2. Thus, punching can be performed on the production tubular 510 above the sleeve 2.

(14) A tubing cutting tool 6, in the following called cutter, is connected to the puncher 5. The cutter 6 is configured to cut the production tubular 510 at a desired location above the sleeve 2. After cutting, the tubular 510 above the cut 530 may be retrieved to surface. The cutter 6 may be a mechanical device or an explosive device or a chemical device or a device of another working principle. To avoid risk of the cutter 6 getting stuck due to tubing displacement, for example scissoring, after cutting, it is an advantage to have the cutter 6 at the lower end of the tool string 3, however, this is not a requirement.

(15) FIG. 2a shows a detail of the latching mechanism 32. The latching mechanism 32 has a plurality of latching dogs 321 arranged around a circumference (not shown) of the tool string 3. The latching dogs 321 are moveable between an engaged position and an open position by means of a latching mandrel 322. The latching dogs 321 are complementary to grooves 230 in the internal surface 200 of the sleeve 2. The groove 230 may be a circular, circumferential groove (not shown). To engage the latching mechanism 32, the latching dogs 321 are moved radially out from a longitudinal centre axis 10 of the downhole apparatus 1. When the latching dogs 321 are engaged in the grooves 210, the sleeve 2 will move with the tool string 3. When the latching dogs 321 are open, the tool string 3 is free to move independently of the sleeve 2 in an axial direction.

(16) FIG. 2b shows the downhole apparatus 1 comprising a control device 7 arranged in the tool string 3. The control device 7 may operate the plug setting tool 41. The control device 7 and plug setting tool 41 are connected with a communication line 710. A portion of the communication line 710 is integrated in the body of the sleeve 2. The communication line 710 is shown with inductive couplers 711 for transferring a signal wirelessly from the sleeve 2 to the plug setting tool 41. Several inductive couplers 711 may be arranged around a circumference (not shown) of the plug setting tool 41. The control device 7 may also be used to operate the puncher 5 and/or cutter 6 via communication lines 720, 730. The communication line 730 running between the control device 7 and cutter 6 is shown routed through the puncher 5. It should be understood that other means for communication may be used to operate the plug setting tool 41 and/or puncher 5 and/or cutter 6, for example hydraulic lines.

(17) In use, the downhole apparatus 1 will be lowered into the well 500. The plug 4 is set to isolate a section of the well 500 above the plug 4, see FIG. 3a. The procedure for setting the plug 4 will not be explained in further detail as this is considered standard procedure for a person skilled in the art. The latching mechanism 32 is disengaged and the tool string 3 pulled back/up the well. The sleeve 2 will stay in place together with the plug 4 and the plug setting tool 41. In one embodiment, the sleeve 2 may be configured as a junk basket to gather debris from the well 500 when disconnected from the tool string 3.

(18) At an elevation above the sleeve 2, the puncher 5 can be operated to punch one or more holes 520 in the well tubular 510, see FIG. 3b. Punching can be performed by any working principle. The holes 520 will allow for circulation of the fluid 600 from the well 500 and into the annulus 511 between the production tubular 510 and the casing 512. The cutter 6 can be operated to form a cut 530 in the tubular 510, see FIG. 3c. Cutting can be performed by any working principle. In one embodiment, the tubular 510 above the cut 530 can be retrieved to surface (not shown).

(19) FIGS. 4a and 4b shows the downhole apparatus 1 according to two other embodiments of the invention respectively. FIG. 4a shows the puncher 5 connected to the lower portion 310 of the tool string 3. The operating principle of the plug 4, the plug setting tool 41 and the puncher 5 may be similar to what was described for the embodiments shown in FIGS. 1-3. The downhole apparatus 1 in FIG. 4a allows for plugging and punching of a well tubular 510 in a single run into the well 500. FIG. 4b shows the cutter 6 connected to the lower portion 310 of the tool string 3. The operating principle of the plug 4, the plug setting tool 41 and the cutter 6 may be similar to what was described for the embodiments shown in FIGS. 1-3. The downhole apparatus 1 in FIG. 4b allows for plugging and cutting of a well tubular 510 in a single run into the well 500.

(20) It should be noted that the above-mentioned embodiment illustrates rather than limit the invention, and that those skilled in the art will be able to design many alternative embodiments without departing from the scope of the appended claims. In the claims, any reference signs placed between parentheses shall not be construed as limiting the claim. Use of the verb “comprise” and its conjugations does not exclude the presence of elements or steps other than those stated in a claim. The article “a” or “an” preceding an element does not exclude the presence of a plurality of such elements.

(21) The mere fact that certain measures are recited in mutually different dependent claims does not indicate that a combination of these measures cannot be used to advantage.