DEVICES AND METHODS FOR CONVEYING A TOOL ALONG A WELLBORE

Abstract

An apparatus for flowing a tool string along a wellbore tubular includes a flow restrictor having a diametrically expanded position and a diametrically retracted position. The flow restrictor sealingly engages the wellbore tubular when in the diametrically expanded position. The apparatus also includes a joint connected to the flow restrictor. The joint actuates the flow restrictor between the expanded position to the retracted position while moving between an open and a closed position.

Description

BACKGROUND OF THE DISCLOSURE

1. Field of the Disclosure

This disclosure relates generally to method and devices for conveying tools along a wellbore.

2. Background of the Art

During the drilling, completion, workover, and remediation of a hydrocarbon-producing wellbore, it may be necessary to convey a tool string to one or more target depths along that wellbore. One conventional method for conveying a tool string along a wellbore is a “pump down” operation. A “pump down” operation typically involves pumping a liquid (e.g., water) to propel a tool string along a wellbore tubular in the wellbore. The tool string may include “swab cups” or other fixed annular rings or fins that resist fluid flow. For wellbores that have extended non-vertical sections, a significant amount of fluid must flow past the swab cups at a high flow rate in order to provide this propulsive force.

In some aspects, the present disclosure addresses the need for devices and methods that can reduce the amount of fluid needed for pump down operations.

SUMMARY OF THE DISCLOSURE

In one aspect, the present disclosure provides an apparatus for flowing a tool string along a wellbore tubular. The apparatus may include a flow restrictor having a diametrically expanded position and a diametrically retracted position. The flow restrictor sealingly engages the wellbore tubular when in the diametrically expanded position. The apparatus also includes a joint connected to the flow restrictor. The joint actuates the flow restrictor between the expanded position and the retracted position while moving between an open and a closed position.

In another aspect, the present disclosure provides a method for flowing a tool string along a wellbore tubular. The method may include disposing a flow restrictor and the tool string into the wellbore tubular, wherein the flow restrictor has a diametrically expanded position and a diametrically retracted position; pumping fluid into the wellbore tubular; propelling the flow restrictor and the tool string through the wellbore by sealingly engaging a surface of the wellbore tubular with the flow restrictor in the diametrically expanded position; actuating the flow restrictor from the expanded position to the retracted position by applying a tension force on a joint connected to the flow restrictor; and retrieving the flow restrictor from the wellbore tubular while the flow restrictor is in the retracted position.

Examples of certain features of the disclosure have been summarized rather broadly in order that the detailed description thereof that follows may be better understood and in order that the contributions they represent to the art may be appreciated. There are, of course, additional features of the disclosure that will be described hereinafter and which will form the subject of the claims appended hereto.

BRIEF DESCRIPTION OF THE DRAWINGS

For a detailed understanding of the present disclosure, reference should be made to the following detailed description of the embodiments, taken in conjunction with the accompanying drawings, in which like elements have been given like numerals, wherein:

FIG. 1 illustrates a well that may use flow tools in accordance with the present disclosure;

FIG. 2 schematically illustrates a flow tool made in accordance with one embodiment of the present disclosure;

FIG. 3 schematically illustrates an embodiment of a flow tool made in accordance with one embodiment of the present disclosure that uses petals as a flow restrictor;

FIG. 4 schematically illustrates an embodiment of a flow tool made in accordance with one embodiment of the present disclosure that uses a sail as a flow restrictor;

FIGS. 5 and 6 schematically illustrate an embodiment of a flow tool made in accordance with one embodiment of the present disclosure that uses a flexible shell as a flow restrictor;

FIGS. 7 and 8 schematically illustrate an embodiment of a flow tool made in accordance with one embodiment of the present disclosure that uses bellows as a flow restrictor;

FIG. 9 schematically illustrates an embodiment of a slip joint for use with bellows; and

FIG. 10 schematically illustrates an embodiment of a slip joint for use with an umbrella-type of flow restrictor.

DETAILED DESCRIPTION OF THE DISCLOSURE

In aspects, the present disclosure provides methods and devices that can reduce the amount of fluid used while conveying a tool along a wellbore. FIG. 1 illustrates an exemplary wellbore 10 that has been drilled through the earth 12 and into formations 14, 16 from which it is desired to produce hydrocarbons. The wellbore 10 may be cased by metal casing, as is known in the art. The wellbore 10 may have a vertical leg 17 and a non-vertical leg 19. While leg 19 is shown substantially horizontal, a non-vertical leg may be inclined between a vertical and horizontal. The wellbore 10 has a wellbore tubular 20 that extends downwardly from a wellhead 24 at the surface 26 of the wellbore 10. The wellbore tubular 20 may be formed of known wellbore tubulars such as drill string, jointed pipe, coiled tubing, or production tubing. The wellbore tubular 20 defines an internal axial flowbore 28 along its length. An annulus 30 is defined between the production assembly 20 and the wellbore casing.

Also shown in FIG. 1 is a tool string 40 configured to perform one or more selected operations in the wellbore 10. The tool string 40 may include perforating guns, packers, bridge plugs, circulating subs, casing collar locators, formation evaluation tools, casing or pipe evaluation tools, wellbore evaluation tools, frac tools, well treatment equipment, and/or other tools used in the course of completing, recompleting, logging, evaluating, remediating, or working over the wellbore 10. The tool string 40 may be tethered to a non-rigid conveyance device 42 such as a wireline (power and data), an e-line (power only), or a slickline (no power or data). The non-rigid conveyance 42 may be a flexible cable that has sufficient tensile strength to pull the tool string 40 out of the wellbore 10. A fluid mover 44 may be used to pump pressurized fluid into the wellbore tubular 20. The fluid mover 44 may be a pump for pumping water, drilling mud, or any other suitable liquid carrier into the flow bore 28 of the tubing 20. This fluid may return via the annulus 30 to the surface. The tool string 40 may include one or more flow tools that use adjustable flow restrictors to selectively block fluid flow along the wellbore tubular 20. Specifically, these flow tools can open to propel the tool string 40 into the wellbore 10 and then close while retrieving the tool string 40 out of the wellbore 10. Illustrative embodiments are discussed in connection with FIGS. 2-9 below.

Referring to FIG. 2, there is shown one embodiment of a flow tool 50 in accordance with the present disclosure. The flow tool 50 may be connected to a tool string 52 that is configured to perform one or more desired well operations. The flow tool 50 may include a variable diameter flow restrictor 54 that is actuated by a slip joint 56. Centralizers 59, which may be bow springs, ribs or stands, may be used to center the flow tool 50 in the wellbore tubular 20. The flow restrictor 54 is an annular-shaped member that can diametrically expand and retract to block flow along an annulus 55 between the wellbore tubular 20 and the flow tool 50. In the diametrically expanded condition, the flow restrictor 54 may be approximately the same diameter as an inner diameter of a wellbore tubular 20 and form a sliding seal with the adjacent wellbore wall 21. This form of contact may be referred to a hydraulic sealing engagement or simply ‘sealing engagement,’ but does not require physical contact between adjacent surfaces. Rather, fluid flow is sufficiently restricted to generate pressure differential sufficient to propel the flow tool 50 along the wellbore. A space or gap may separate the flow restrictor 54 partially or completely along a circumference during a sealing engagement. This seal allows the relatively higher pressure uphole of the flow tool 50 to propel the tool string 52 through the wellbore tubular. Moreover, the seal may be compliant in that the flow restrictor 54 may bend or deform as needed to pass through obstructions along the flow bore 20 and expand once the obstruction has been passed. It should be understood that the seal need not be a fluid-tight seal and that some fluid flow may still occur through the seal.

Referring now to FIGS. 2 and 3, there is shown a flow tool 50 that uses flow restrictor 54 formed as petals 62. The petals 62 may be segmented pie-shaped members that are circumferentially arrayed around a body or support 64. The support 64 may be a mandrel, a tube, a rod, or other suitable support member. The petals 62 may be interleaved and fixed at one end to the support 64. Thus, the petals 62 rotate about the fixed end when opening. When open, the petals 62 form a basket shape that captures flowing fluids. The petals 62 may be formed of a metal, an elastomeric material (e.g., rubber), and/or a composite material. As seen in FIG. 2, in some embodiments, the flow tool 50 may also include a liner 58 that lines the radially inner surface of the petals 62. The liner 58, which may also be connected to the slip joint 56, catches debris and other material that may otherwise become lodged in the petals 62.

FIG. 4 shows an embodiment of a flow tool 50 that is similar to that shown in FIGS. 2 and 3. However, in the FIG. 4 embodiment, the flow restrictor 54 is formed as a sail 72 (or canopy) that is fixed to the support 64. The sail 72 may include pleats for folding into a compact condition. In embodiments, the sail 72 may include rigid or semi-rigid support members 74 such as rods that assist in the sail 72 having a pre-defined shape (e.g., annular) when opened. The sail 72 may open in an umbrella-type fashion with the concave side facing the downwardly flowing fluid. The sail 72 may be formed of pliant materials such as fabric, cloth, an elastomer, or suitable material.

Referring to FIGS. 2-4, the petals 62 or the sail 72 may be closed using a ring 66 that may be pulled around the petals 62. The ring 66 may be disposed on the outer surface of the support 64 such that the ring 66 can slide axially over the petals 62 or the sail 72. In the first position shown in FIG. 2, the ring 66 may be positioned near the support 64 so that the petals 62 or the sail 72 are free to expand diametrically. In the second position shown in FIG. 4, the ring 66 slides over and compacts the petals 62 or the sail 72.

Referring to FIG. 4, in embodiments, the slip joint 56 may be used to axially slide the ring 66 between the first position at the support 64 and the second position around the petals 62 or the sail 72. The slip joint 56 may be a tubular assembly that can axially lengthen and shorten depending on the amount of applied tension. In some arrangements, the slip joint 54 may be a telescoping type device that has an upper section 78 that is connected to a lower section 80. The upper and lower sections 78, 80 may slide relative to one another. The upper section 78 may be connected to the conveyance device 42 (FIG. 2) and the lower section may be connected to the ring 66 using one or more links 82. The links 82 may pass through slots (not shown) or other suitable openings in the petals 62 or the sail 72. The ring 66 may also be axially displaced by other arrangements such as tethers or cables that go over the sail 72. When the joint 56 is in the axially shortened condition, the ring 66 is near or at the support 64. Axial movement of the upper section 78 away from the lower section 80 pulls the links 72 away from the lower section 80 and slips over the ring 66 and retracts the flow petals 62 or the sail 72.

The slip joint 56 may also be configured to pull the liner 58 out of the petals 62 or the sail 72 before either of these features are closed. For example, the liner 58 may be connected by a suitable linkage or wire to the upper section 78. The connection may be arranged that the liner 58 is moved before the petals 62 or sail 72 are closed.

Depending on the application, additional features may be used to facilitate the opening and closing of the flow restrictor 50. For example, biasing elements such as springs may be used to urge the slip joint 56 to either the open or the closed position. Similarly, biasing elements may be used to urge the flow restrictor 50 to either the diametrically expanded or the diametrically retracted condition. These biasing elements may be used to establish a force value (e.g., tension, pressure, etc.) that must be exceeded for an action to occur or to provide additional force for moving or shifting to a particular position or condition.

An exemplary mode of use will be described in connection with FIGS. 1-4. To begin, the flow tool 50 and the tool string 52 are inserted into the wellbore tubular 20 (FIG. 1). The tool string 52 may be coupled to a conveyance device such as a wireline 24. Initially, the lower section 80 positions the ring 66 such that the petals 62 are free to radiate outward and obstruct the flowing fluid. The flow tool 50 and the tool string 52 may travel primarily under the force of gravity down the vertical section 17 and then enter the horizontal section 19. Because no fluid is being pumped into the wellbore tubular 20 during this initial descent, the petals 62 remain in a generally retracted condition. After entry into the horizontal section 19, or when gravity can no longer move the tool string 52, a fluid, such as water, is pumped into the wellbore tubular 20 using a fluid mover 44 (FIG. 1). The flowing fluid causes the petals 62 to rotate radially outward and contact the adjacent wellbore tubular surface 21. This fluid obstruction generates a pressure differential that propels the tool string 52 along the wellbore tubular 20. When the tool string 52 is positioned at the desired depth along the wellbore, the fluid circulation is stopped and one or more desired well operations may commence.

After one or more desired well operations are completed, a tension is applied to the wireline 42. When the tension exceeds the activation level of the slip joint 56, the slip joint 56 axially lengthens. This lengthening is caused by the upper section 78 moving away from the lower section 80 and the petals 62. As the upper section 78 slides upward, the connected links 82 pull the ring 66 over the outer surfaces of the petals 64, which collapses the petals 64 into a radially compact closed position. At this stage, the tool string 52 and the flow tool 50 may be retrieved from the wellbore. It should be appreciated that the sail 72 of the FIG. 4 embodiment may also be deployed in a similar manner.

Referring now to FIG. 5, there is shown another flow tool 50 according to the present disclosure wherein a flow restrictor is formed as a shell. The flow tool 50 may include expandable members 102, a shell 104 enclosing the expandable members 102, and a slip joint 56. The expandable members 102 may be rods, arms, plates, strips, bands, tubes, or other like structures that are suitable for displacing the shell 104 radially outward. In one arrangement, the expandable members 102 may include one or more circumferentially arrayed link assemblies 106 that extend radially outward when compressed. The link assemblies 106 may include pair hinged links that are connected between the upper section 78 of the slip joint 56 and the lower section 80 of the slip joint 56. The shell 104 may be shaped as a sleeve that is connected at the upper end to the upper section 78 and the lower section 80 using suitable fastening elements such as bands 108. The shell 104 may be formed of a pliant material; e.g., a sheet of a rubber-type material that includes woven fabric layers or other flexible material suitable for downhole use. In some embodiments, the outer surface of the shell 104 may include features such as ribs 110 to enhance a sealing contact with an adjacent wellbore tubular surface. Also, the shell 104 may include rigid or semi-rigid support members such as rods (not shown) that assist the shell 104 to have a pre-defined shape (e.g., annular) when opened.

When the slip joint 56 closes, the links 106 rotate as they are pushed together and move to an extreme outer diametrical position, which expands the shell 104 to a diametrically enlarged position. When the slip joint 56 opens, the links 106 are pulled apart and radially retract toward the slip joint 56. FIG. 6 shows the links 106 in a diametrically retracted condition where the slip joint 56 is open and the expandable members 102 are diametrically retracted.

Referring now to FIG. 7, there is shown yet another embodiment of a flow tool 50 in accordance with the present disclosure wherein the flow restrictor is formed as bellows. The flow tool 50 may include bellows 120, and a slip joint 56. The bellows 120 may include a foldable sleeve 122 made of a suitable flexible material. Fastening elements 124 may be used to attach the distal ends of the bellows 120 to the slip joint upper and lower sections 78, 80, respectively. When the slip joint 56 is an axially shortened condition (closed), the bellows 120 is folded and compressed, which causes the material of the sleeve 122 to radially expand and obstruct the fluid flow path between the pump down tool 50 and an adjacent wellbore tubular wall. When a preset amount of tension is applied, the upper section 78 and the lower section 80 of the slip joint 56 move axially away from one another. This relative motion causes the slip joint 56 to radially lengthen and unfold the bellows 120, which causes a minimal flow obstruction along the flow tool 50 as shown in FIG. 8.

Referring now to FIG. 9, there is shown an embodiment of a slip joint 56 that may be used to actuate the bellows 120. The flow tool 50 may include bellows 120, and a slip joint 56. The bellows 120 is shown in the de-activated position wherein fluid flow through the annulus 55 is only minimally blocked. This de-activated position is associated with the slip joint 56 being in an open position, i.e., axially lengthened. The slip joint 56 includes an upper section 78 that may be formed as a cylinder 130 and a lower section 80 can includes a piston 132 that reciprocates in the cylinder 130. A shaft 134 may connect the piston 132 to the lower end of the tool string 40. In some embodiments, the slip joint 56 may include a biasing element 136 to urge or push the piston 132 toward a desired position (e.g., open or closed). The biasing element 136 may be a coiled spring, leaf spring, spring washers, or other similar structure for applying a biasing force to the piston 132. In FIG. 9, the biasing element 136 is shown pushing the piston 132 uphole, which would tend to close the slip joint 56 and maintain the bellows 120 in the diametrically expanded, flow-blocking condition. Thus, applying a tension force on the conveyance device 42 (FIG. 1) overcomes the spring force of the biasing element 136, which opens the slip joint 56 and closes retracts the bellows 120.

Referring now to FIG. 10, there is shown an embodiment of a slip joint 56 that may be used to actuate a sail, petals, or other umbrella-type of flow restrictors that spread and retract circumferentially. The flow tool 50 may include a variable diameter umbrella-type flow restrictor 150 and a slip joint 56. The flow restrictor 150 is shown in the activated position wherein fluid flow through the annulus 55 is substantially blocked. This activated position is associated with the slip joint 56 being in a closed position, i.e., axially shortened. The slip joint 56 includes an upper section 78 that may be formed as a cylinder 130 and a lower section 80 can includes a piston 132 that reciprocates in the cylinder 130. A shaft 134 may connect the piston 132 to the lower end of the tool string 40. In some embodiments, the slip joint 56 may include a biasing element 136 to urge or push the piston 132 toward a desired position (e.g., open or closed). The biasing element 136 may be a coiled spring, leaf spring, spring washers, or other similar structure for applying a biasing force to the piston 132. An expander 152 may be used to expand and retract the flow restrictor 150. An expander 152 may be connected to the upper section 78 and slide along an inner surface of the flow restrictor 150. The flow restrictor 150 is connected at one end to the lower section 80.

In FIG. 10, the biasing element 136 is shown pushing the piston 132 uphole, which would tend to close the slip joint 56 and maintain the flow restrictor 150 in the diametrically expanded, flow-blocking condition. When the expander 152 slides axially away from the free end of the flow restrictor 150 to the connected end of the flow restrictor 150, the flow restrictor 150 expands diametrically outward. This action is due to the ramp-like interaction between the flow restrictor 150 and the expander 152. The expander 152 may be connected to the flow restrictor 150. For example, the expander 152 may ride along slots or rails formed on the flow restrictor 150. Applying a tension force on the conveyance device 42 (FIG. 1) overcomes the spring force of the biasing element 136, which opens the slip joint 56 and allows the flow restrictor 150 to retract. Biasing elements (not shown) may be used to bias the flow restrictor 150 to the closed position.

While the present disclosure discusses a hydrocarbon producing well, the present teachings may also be used with other types of wells (e.g., geothermal wells, water wells, etc.) While the foregoing disclosure is directed to the one mode embodiments of the disclosure, various modifications will be apparent to those skilled in the art. It is intended that all variations within the scope of the appended claims be embraced by the foregoing disclosure.

Claims

1. An apparatus for flowing a tool string along a wellbore tubular, comprising:

a flow restrictor having a diametrically expanded position and a diametrically retracted position, wherein the flow restrictor sealingly engages the wellbore tubular when in the diametrically expanded position; and

a joint connected to the flow restrictor, the joint actuating the flow restrictor between the expanded position and the retracted position while moving between an open and a closed position.

2. The apparatus of claim 1, wherein the flow restrictor expands to engage an inner surface of the wellbore tubular in response to a pressure applied by a fluid flowing in the wellbore tubular.

3. The apparatus of claim 1 wherein the joint moves between the open position and the closed position in response to a preset value of applied tension; and further comprising a conveyance device connected to the joint, the conveyance device being configured to apply at least the preset value of the applied tension to the joint.

4. The apparatus of claim 3, wherein the conveyance device is one of: (i) a wireline, (ii) a slickline, and (iii) an e-line.

5. The apparatus of claim 3, wherein the joint includes a first section in sliding engagement with a second section, and further comprising at least one link having an end connected to the first section, wherein the at least one link radially rotates when the first section moves relative to the second section.

6. The apparatus of claim 5, wherein the flow restrictor includes a support and a ring slidably disposed on the body, the ring being connected to one of: (i) the at least one link, and (ii) the first section of the slip joint.

7. The apparatus of claim 6, wherein the flow restrictor further includes at least one radially projecting petal coupled to the support, wherein the ring slides over the at least one radially projecting petal when the joint moves between the open and the closed position.

8. The apparatus of claim 6, wherein the flow restrictor further includes a sail coupled to the support, wherein the ring slides over the sail when the joint moves between the open and the closed position.

9. The apparatus of claim 5, wherein the flow restrictor includes a shell enclosing the at least one link.

10. The apparatus of claim 1, wherein the joint includes a first section in sliding engagement with a second section, wherein the flow restrictor includes a bellows having an upper end connected to the first section of the slip joint and a lower end connected to the second section of the slip joint, and wherein the bellows diametrically expands when the first section of the slip joint slides toward the second section of the slip joint.

11. The apparatus of claim 1, further comprising a liner lining the flow restrictor, the liner being coupled to the joint, wherein the joint extracts the liner from the flow restrictor while moving from the closed position to the open position.

12. A method for flowing a tool string along a wellbore tubular, comprising:

disposing a flow restrictor and the tool string into the wellbore tubular, wherein the flow restrictor has a diametrically expanded position and a diametrically retracted position;

pumping fluid into the wellbore tubular;

propelling the flow restrictor and the tool string through the wellbore by sealingly engaging a surface of the wellbore tubular with the flow restrictor in the diametrically expanded position;

actuating the flow restrictor from the expanded position to the retracted position by applying a tension force on a joint connected to the flow restrictor; and

retrieving the flow restrictor from the wellbore tubular while the flow restrictor is in the retracted position.

13. The method of claim 12, further comprising expanding the flow restrictor to engage an inner surface of the wellbore tubular using a pressure applied by the fluid flowing in the wellbore tubular.

14. The method of claim 12 further comprising connecting a conveyance device to the joint, and using the conveyance device to apply at least a preset value of tension to move the joint between the open position and the closed position.

15. The method of claim 12, wherein the joint includes a first section in sliding engagement with a second section, and wherein the tension force applied to the first section actuates the flow restrictor to the retracted position.

16. The method of claim 12, wherein the flow restrictor includes at least one of: (i) at least one radially projecting petal, (ii) a sail, (iii) a shell and (iv) a bellows.

17. The method of claim 12, further diametrically expanding the flow restrictor by using at least one link connected to the joint.

18. The method of claim 12, wherein a liner lining the flow restrictor, and further comprising extracting the liner from the flow restrictor while moving from joint from the closed position to the open position.