WO2021007430A1

WO2021007430A1 - Downhole tool with retractable and extendable device that controls movement of the device in a wellbore without a wireline

Info

Publication number: WO2021007430A1
Application number: PCT/US2020/041405
Authority: WO
Inventors: Cary VALERIO; Chadbourne W. ALBURY
Original assignee: Oilfield Fishing Solutions LLC
Current assignee: Oilfield Fishing Solutions LLC
Priority date: 2019-07-09
Filing date: 2020-07-09
Publication date: 2021-01-14
Anticipated expiration: 2022-01-09

Abstract

A tool for use in a wellbore includes a housing and a first plurality of arms. Each arm includes a first end coupled to the housing and a second end spaced apart from the first end. The plurality of arms is extendable from a first position in which the first end and the second end of each arm is proximate the housing and a second position in which at least the second end of each arm is displaced radially away from the housing. At least one panel is extendable between at least two arms of the first plurality of arms when the first plurality of arms is in the second position. An actuator is coupled to the first plurality of arms and extends the first plurality of arms from at least the first position to at least the second position.

Description

DOWNHOLE TOOL WITH RETRACTABLE AND EXTENDABLE DEVICE THAT CONTROLS MOVEMENT OF THE DEVICE IN A WELLBORE WITHOUT A

WIRELINE

PRIORITY CLAIM

[0001] The present international patent application claims the benefit of and priority to U.S. Provisional Patent Application No. 62/872,004, filed July 9, 2019, and entitled “DOWNHOLE TOOL WITH RETRACTABLE AND EXTENDABLE DEVICE THAT CONTROLS MOVEMENT OF THE DEVICE IN A WELLBORE WITHOUT A WIRELINE,” the entire contents of which is incorporated herein by reference.

BACKGROUND

[0002] The present application relates to a downhole tool or apparatus configured to be lowered and raised within a well bore under the action of a dynamic fluid pressure interacting with an umbrella-like structure that may include a panel extendable between at least two arms of a first plurality of arms.

BRIEF SUMMARY

[0003] The purpose of the disclosed tool or apparatus is to use wellbore pressure in a cased hole (or open hole completion) situation to provide a buoyancy force to a downhole tool string. The tool or apparatus will have an expandable/retractable "umbrella" or "packer" like system to act as a piston to partially seal off the wellbore, so that the wellbore pressure can then move the downhole tool string up (and/or down) by controlling the opening and closing geometry of the umbrella of the tool. In other words, the maximum diameter of the umbrella or arms in the fully opened or expanded position is less than the inner diameter of the open hole or the inner diameter of the casing in which the tool may be disposed.

[0004] Unlike traditional packers or umbrella systems, the objective of the disclosed tool or apparatus with the expanding/retracting arms/elastomers is not to seal against the casing, or provide zonal isolation. Rather, the objective of the arms/elastomers opening and closing is to increase the effective tool outer diameter to provide more area for the wellbore pressure to lift or drive the tool or apparatus into or out of the wellbore.

[0005] Conversely, the arms/elastomers will retract to the tool to reduce this area subject to the wellbore flow/pressure, which will in turn allow the tool to drop. [0006] A control system, that optionally includes a controller, such as an internal computer or CPU, and as described below, may include various sensors, such as

accelerometer, configured to detect a first parameter and to generate a signal representative of that first parameter to the controller. The controller may store a value reflective of the first parameter in an optional memory storage device. The memory storage device may also store an operating program. The controller may perform functions in accordance with the operating program, which may include modulating the expansion and the retraction of the 'umbrella' to the desired pre-programmed downhole speeds required for descending, ascending, and respective logging (evaluation) objectives.

[0007] With sensors inside the tool or apparatus, the internal CPU software will be able to determine if the downhole tool string is moving up or down and at what rate.

[0008] The tool or apparatus may be configured to be added or combined with an existing downhole tool assembly, and in which configuration the use of the tool or apparatus may be to control the ascent, the descent, and the rate at which the entire downhole tool assembly ascends or descends

[0009] Embodiments of a control system for the tool are also disclosed. In addition to the various embodiments of the tool discussed, the control system includes at least a first sensor positioned on the tool that detects a first parameter and generates a first signal reflective of the first parameter. Optionally, the control system may include at least a second sensor that detects at least a second parameter and generates a second signal reflective of the second parameter. A memory storage device stores an operating program configured to calculate an actuation signal as a function of at least one of the first signal and the second signal. A controller is configured to receive at least one of the first signal from the first sensor and the second signal from the second sensor, ran the operating program, and transmit the actuation signal to at least one arm of the tool, which optionally may be coupled to a linear actuation device coupled to at least one arm to transition the at least one arm from a first position to a second position. At least one power source provides power to at least one of the first sensor, the second sensor, the memory storage device, the linear actuation device, and the controller.

[0010] Another embodiment of a control system is configured to calculate an actuation signal for use in actuating a component of a tool positioned in a wellbore. A first sensor detects a first parameter and generates a first signal reflective of the first parameter. Optionally, at least a second sensor detects at least a second parameter and generates a second signal reflective of the second parameter. A memory storage device stores an operating program, which calculates the actuation signal as a function of at least one of the first signal and, optionally, the second signal. A controller is configured to receive at least one of the first signal from the first sensor and the second signal from the second sensor, to ran the operating program, and to transmit the actuation signal to the at least one arm.

[0011] Also disclosed are embodiments of an operating program to calculate an actuation signal as a function of at least one of a first signal reflective of a first parameter as detected and generated by a first sensor and, optionally, a second signal reflective of a second parameter as detected and generated by a second sensor. The actuation signal is used to actuate at least one arm of a tool positioned in a wellbore. The operating program includes, in part, a memory storage device to store the operating program and to store at least one of the first signal and, optionally, the second signal. A controller is configured to receive at least one of the first signal from the first sensor and the second signal from the second sensor, to run the operating program, and to transmit the actuation signal to the at least one arm of the tool. In some embodiments, the operating program calculates the actuation signal as a function of a difference in at least one of the first signal and the second signal at the first time and at the subsequent time. In some embodiments, the actuation signal actuates a component that is a release mechanism.

[0012] In addition, methods of calculating an actuation signal are disclosed. One embodiment of such a method is for calculating an actuation signal for use in actuating a component of a tool positioned in a wellbore. Optionally, the tool includes a first sensor and, optionally, at least a second sensor, and a memory storage device that stores an operating program that calculates the actuation signal. A controller is configured to receive at least one of a first signal generated by the first sensor and, optionally, a second signal generated by the second sensor, to ran the operating program, and to transmit the actuation signal to the at least one arm, which optionally may be coupled to a linear actuation device that in, in operation, causes the at least one arm to extend and/or to retract. The method itself comprises detecting at least one of a first parameter with the first sensor and, optionally, a second parameter with at least a second sensor. The method further includes generating at least one of the first signal representative of the first parameter with the first sensor and, optionally, the second signal representative of the second parameter with the at least second sensor. At least one of the first signal and, optionally, the second signal are stored on the memory storage device. An actuation signal is calculated as a function of the first signal, and/or optionally a function of a difference in at least one of the first signal and, optionally, the second signal at a first time and at a subsequent time. The method also includes transmitting the actuation signal to the at least one arm.

[0013] As used herein, "at least one," "one or more," and "and/or" are open-ended expressions that are both conjunctive and disjunctive in operation. For example, each of the expressions "at least one of A, B and C," "at least one of A, B, or C," "one or more of A, B, and C," "one or more of A, B, or C" and "A, B, and/or C" means A alone, B alone, C alone, A and B together, A and C together, B and C together, or A, B and C together.

[0014] Various embodiments of the present inventions are set forth in the attached figures and in the Detailed Description as provided herein and as embodied by the claims. It should be understood, however, that this Summary does not contain all of the aspects and embodiments of the one or more present inventions, is not meant to be limiting or restrictive in any manner, and that the invention(s) as disclosed herein is/are and will be understood by those of ordinary skill in the art to encompass obvious improvements and modifications thereto.

[0015] These and other advantages, as well as the invention itself, will become more easily understood in view of the attached drawings and apparent in the details of construction and operation as more fully described and claimed below. Moreover, it should be appreciated that several aspects of the invention can be used with other types of cranes, machines or equipment.

BRIEF DESCRIPTION OF THE DRAWINGS

[0016] FIG. 1 is a right side elevation view of down hole tool with at least a plurality of arms in a closed position.

[0017] FIG. 2 is a right side elevation view of the down hole tool with the at least a plurality of arms in an open position.

[0018] FIG. 3 is an embodiment of a control system for the tool in FIGs. 1 and 2.

[0019] The drawings are not necessarily to scale. DETAILED DESCRIPTION

[0020] The present invention will now be further described. In the following passages, different aspects of the embodiments of the invention are defined in more detail. Each aspect so defined may be combined with any other aspect or aspects unless clearly indicated to the contrary. In particular, any feature indicated as being preferred or advantageous may be combined with any other feature or features indicated as being preferred or advantageous.

[0021] A tool 10 may be used in a wellbore 100, such as an oil, gas, water, or other type of wellbore in the earth. The wellbore 100 may be a vertical wellbore or deviated wellbore. For reference, up or out of the wellbore refers to the surface of the earth and down or into the wellbore refers to the bottom of the wellbore, regardless of the actual orientation of the wellbore relative to vertical. The wellbore 100 includes a wellbore wall 105 and a wellbore diameter 110.

[0022] The tool 10 includes a first end 12 and a second end 14 spaced apart from the first end 12. Optionally, the tool 10 includes a connection on at least one of the first end 12 and the second end 14. The connection (unlabeled) may be a threaded connection (box or pin), dimpled connection, welded connection, or any other type of connection typically used to connect tools used in the drilling industry. The tool 10 may be a wireline tool or incorporated into a drill collar or other type of down hole tool or equipment.

[0023] The tool 10 includes a housing 15 with a first housing diameter 20 that is less than the wellbore diameter 110. The tool optionally includes a portion 21 with a second housing diameter 22 that is less than the first housing diameter 20. The portion 21 of the housing may provide space for the first plurality of arms 25 and the second plurality of arms 50 to be received such that in the first position (30/60; discussed below) the diameter of the first plurality of arms 25 and the second plurality of arms 50 is proximate (within +/- 10 %) of the first housing diameter 20.

[0024] As mentioned, the housing 15 includes a first plurality of arms 25. Each arm of the first plurality of arms 25 may be positioned equidistantly radially about an outer circumference of the housing 15. Each arm of the first plurality of arms 25 includes a first end 27 coupled to the housing 15 and a second 29 end spaced apart from the first end 27. Optionally, the first end 27 of each arm is pivotally coupled to the housing 15. Optionally, the first end 27 of each arm is slidably coupled to the housing 15. Each arm of the first plurality of arms 25 is extendable from a first position 30 (FIG. 1) in which the first end 27 and the second end 29 of each arm of the first plurality of arms 25 is proximate the housing 15 and a second position 35 (FIG. 2) in which at least the second end 29 of each arm of the first plurality of arms 25 is displaced radially away from the housing 15 towards the wall 105 of the wellbore 100. In the first position 30, the first end 27 and the second end 29 of the plurality of arms 25 extend a first distance 36 that is proximate (within +/- 10%) of the diameter 14 of the housing 15. In the second position 35, the first end 27 remains proximate the housing 15 and the second end 29 of the plurality of arms 25 extends a second distance 37 that is greater than the diameter 14 of the housing 15 and less than the diameter 110 of the wellbore 100. The second distance 37 can be any distance between the diameter 14 of the housing 15 and the diameter 110 of the wellbore 100. The second distance 37 optionally may be a function of one or more of a flow rate, a density, and a viscosity, of a fluid or fluids in the wellbore 100, the force of gravity, and the pressure exerted on at least one panel 40 as discussed below.

[0025] The tool 10 includes at least one panel 40 extendable between at least two arms of the first plurality of arms 25 when the first plurality of arms 25 are extended in the second position 35. Optionally, the at least one panel 40 comprises at least one of a fabric, an elastomer, a plastic, a rubber, a flexible material, a metal, and combinations thereof.

Optionally, the at least one panel 40 includes at least one perforation or hole (not illustrated) extending through the at least one panel. The at least one perforation or hole may be of any shape, although typically spherical or ovoid shapes may be preferred. Optionally, when the panel 40 is a metal it may include one or more segmented sections, such as a in a fan or other pattern in which the first ends of the segmented sections proximate the first end 27 of the at least a first plurality of arms 25 are proximate each other and in which the second ends of the segmented sections proximate the second end 29 of the first plurality of arms 25 become fanned or spaced apart when the first plurality of arms 25 are in the second position 35.

[0026] The tool 10 also includes an actuator (not illustrated) coupled to the first plurality of arms 25 (and/or, optionally, coupled to the second plurality of arms 50) that extends the first plurality of arms 25 from at least the first position 30 to at least the second position 35. The actuator may be of any type typically used, including a variety of springs, hydraulic cylinders, drive screws, gas or fluid injected from a reservoir or diverted from a stream of fluids in the wellbore through a valve, and other known structures and methods and, consequently, are within the ability of one of ordinary skill in the art and do not require illustration. For example, one actuation mechanism includes those disclosed in U.S. Pat. No. 8,851,193 for a Self-Centering Downhole Tool at Col. 6 - 10, the disclosure of which is incorporated herein by reference.

[0027] Optionally, the tool 10 further comprises a biasing mechanism (not illustrated), such as a spring or other similar device coupled to the first plurality of arms 25, wherein the biasing mechanism urges the first plurality of arms 25 towards the first position 30. The biasing mechanism optionally exhibits or comprises a linear force-distance relationship, such as one that follows Hooke’s Law. In other embodiments, the biasing mechanism is at least one of a spring and a linear actuator. The linear actuator may include various types of hydraulic or pneumatic cylinders, which may optionally include a port on one or both sides of the cylinder head that would allow a technician to add or remove fluid from the cylinder at the surface. Other examples of linear actuators include linear drives, such as drive screws, and other known types. In addition, various combinations of springs and linear actuators may be employed. For example, a combination biasing mechanism includes a spring and a hydraulic or pneumatic cylinder. The biasing mechanism may be of any type typically used and, consequently, are within the ability of one of ordinary skill in the art and do not require illustration. The purpose of the biasing mechanism is to urge the first plurality of arms 25 towards the closed first position 30 absent the extension force of the actuator. This provides a “fail-safer” mechanism that minimizes any reduction in the passable diameter of the wellbore 100 around the tool 10 in the event the tool 10 fails are should become stuck in the wellbore 100.

[0028] Optionally, the tool 10 further includes a second plurality of arms 50. Each arm of the second plurality of arms 50 may be positioned equidistantly radially about an outer circumference of the housing 15. Each arm of the second plurality of arms 50 includes a first end 52 coupled to the housing 15 and a second 54 end spaced apart from the first end 52. Optionally, the first end 52 of each arm is pivotally coupled to the housing 15. Optionally, the first end 52 of each arm is slidably coupled to the housing 15. Each arm of the second plurality of arms 50 is extendable from a first position 30 (FIG. 1) in which the first end 52 and the second end 54 of each arm of the second plurality of arms 50 is proximate the housing 15 and a second position 35 (FIG. 2) in which at least the second end 54 of each arm of the second plurality of arms 50 is displaced radially away from the housing 15 towards the wall 105 of the wellbore 100. In the first position 30, the first end 52 and the second end 54 of the plurality of arms 50 extend a first distance 56 that is proximate (within +/- 10%) of the diameter 14 of the housing 15. In the second position 35, the first end 52 remains proximate the housing 15 and the second end 56 of the plurality of arms 50 extends a second distance 58 that is greater than the diameter 14 of the housing 15 and less than the diameter 110 of the wellbore 100. Optionally the first distances 36 and 56 and/or the second distances 37 and 58 may be equal or within +/- 10% of each other (as measured relative to the distances 36 and 37, respectively) or the distances may be different. The second distance 58 can be any distance between the diameter 14 of the housing 15 and the diameter 110 of the wellbore 100. The second distance 58 optionally may be a function of one or more of a flow rate, a density, and a viscosity, of a fluid or fluids in the wellbore 100, the force of gravity, and the pressure exerted on at least one panel 40 as discussed below.

[0029] Optionally, the second end 54 of the second plurality of arms 50 may be coupled to the second end 29 of the first plurality of arms 25. Optionally the second end 54 may be pivotally coupled to the second end 29.

[0030] Optionally, the second plurality of arms 50 include at least one panel 40 extendable between at least two arms of the second plurality of arms 50 when the second plurality of arms 50 are extended in the second position 35. Optionally, the at least one panel 40 comprises at least one of a fabric, an elastomer, a plastic, a rubber, a flexible material, a metal, and combinations thereof. Optionally, the at least one panel 40 includes at least one perforation or hole (not illustrated) extending through the at least one panel. The at least one perforation or hole may be of any shape, although typically spherical or ovoid shapes may be preferred. Optionally, when the panel 40 is a metal it may include one or more segmented sections, such as a in a fan or other pattern in which the first ends of the segmented sections proximate the first end 52 of the at least a second plurality of arms 50 are proximate each other and in which the second ends of the segmented sections proximate the second end 54 of the second plurality of arms 50 become fanned or spaced apart when the second plurality of arms 50 are in the second position 35. The at least one panel 40 of the second plurality of arms 50 optionally may be made of the same material or a different material as the at least one panel 40 of the first plurality of arms 25. Optionally, at least one panel 40 of the first plurality of arms 25 is coupled and/or integrally formed with at least one panel 40 of the second plurality of arms 50. [0031] As noted, the tool 10 includes an actuator (not illustrated) coupled to the first plurality of arms 25 (and/or, optionally, coupled to the second plurality of arms 50) that extends the first plurality of arms 25 from at least the first position 30 to at least the second position 35 as discussed above. As illustrated in FIG. 2, the actuator raises the first end 52 of the second plurality of arms 50 towards the first plurality of arms 25 and the first end 12 of the tool 10. In so doing, the second ends 29/54 of the first plurality of arms 25 and the second plurality of arms 50, which are pivotally coupled together, each extend radially away from the housing 15 towards the wall 105 of the wellbore 100. As illustrated, the distance 37/58 of the first plurality of arms 25 and the second plurality of arms 50 is less than the diameter 110 of the wellbore 100, allowing fluids present in the wellbore to flow around the tool 10.

[0032] Optionally, the tool 10 further comprises a biasing mechanism (not illustrated), such as a spring or other similar device coupled to the second plurality of arms 50, wherein the biasing mechanism urges the second plurality of arms 50 towards the first position 30. The biasing mechanism may be the same biasing mechanism as that coupled to the first plurality of arms 25 as discussed above or it may be another biasing mechanism identical or similar to the types discussed above. The biasing mechanism may be of any type typically used and, consequently, are within the ability of one of ordinary skill in the art and do not require illustration. The purpose of the biasing mechanism is to urge the second plurality of arms 50 towards the closed first position 30 absent the extension force of the actuator. This provides a“fail-safer” mechanism that minimizes any reduction in the passable diameter of the wellbore 100 around the tool 10 in the event the tool 10 fails are should become stuck in the wellbore 100.

[0033] Also disclosed are embodiments of an optional control system 200 as described below and as illustrated in FIG. 3. The control system 200 is suitable for controlling the tool 10 and, more particularly, the actuation of the actuator.

[0034] The control system 200 optionally includes a first sensor 202 positioned on the tool 10 (indicated as tool 206 in the block diagram). The first sensor 200 is configured to detect a first parameter and generate a first signal 201 reflective of the first parameter. The control system 200 also optionally includes at least a second sensor 204. As with the first sensor 202, the second sensor 204 is configured to detect at least a second parameter and generate a second signal 203 reflective of the second parameter. In some embodiments, at least one of the first sensor 202 and the second sensor 204 are positioned on the tool 10 and, more particularly, one or both of the sensors 202, 204 are positioned on a controller 206. Of course, the sensors 202, 204 can each be positioned on another tool that is electrically coupled to the tool 10 (such as in a wireline or a measurement/logging while drilling string, and/or electrically coupled to the tool 206 via a surface system (not illustrated, but known in the art) and a communication link (not illustrated, but also known, such as mud pulse telemetry, wireline, electro-magnetic telemetry, and so on) between the tool 10 and other tools or the surface system.

[0035] The first sensor 202 and the second sensor 204 optionally are selected from various known sensors. In one embodiment, the first sensor 202 and the second sensor 204 is selected from the group consisting of a resistivity sensor, a power sensor, a vibration sensor, an accelerometer, a pressure sensor, an acoustic sensor, an electromagnetic sensor, a gamma ray sensor, a neutron sensor, magnetometers - including those for use as a collar locater, temperature sensor, flow sensors (sometimes referred to as spinners), and other known types of sensors.

[0036] For example, the first sensor 202 may include a pressure sensor to detect the hydrostatic pressure of a fluid in the wellbore, from which the density of the fluid may be derived.

[0037] The second sensor 204 optionally provides additional data to confirm whether or not the tool 100 is moving, particularly when compared with the data that the first sensor 202 (change in absolute pressure) provides. For example, an accelerometer and/or a flow sensor may provide an indication that the tool is moving.

[0038] The control system 200 also includes a memory storage device 208 configured to store an operating program 210 and, optionally, the first signal 201 and the second signal 203, optionally along with a timestamp. As one will appreciate, the ability to store the first signal 201 and/or the second signal 203 in the memory storage device 208 permits logging of the data at least as a function of time and, given the proper equipment, depth. Thus, the tool 10 enables logging-while-fishing operations in addition to more traditional logging operations. Any such data recorded can be transmitted in whole or in part to the surface via the communication link and/or optionally downloaded to the surface system when the tool 10 is returned to the surface, regardless of whether the tool 10 is fished from the wellbore 100 or returns in the same manner in which the tool 10 was conveyed into the wellbore 100. [0039] The memory storage device 208 includes various types of recordable media, including random access memory, read only memory, removable media, as well as a hard wired specific instruction chip, and other known types. In addition, the memory storage device 208 may be a separate element or it may be incorporated into a computer system or controller 206, as described below.

[0040] The operating program 210 is configured to calculate an actuation signal 207. The actuation signal 207 optionally is a function of at least one of the first signal 201 and the second signal 203. In some embodiments, the actuation signal 207 is calculated as a function of a difference in at least one of the first signal 201 and/or the second signal 203 received by the controller 206 and/or retrieved by the controller 206 from the memory storage device 208 at a first time and at a subsequent time. The memory storage device 208 optionally stores the actuation signal 207.

[0041] As an example of an embodiment of the operating program 210, it may use the first signal 201 generated by the first sensor 202 that, for purposes of this example, is an accelerometer configured to detect the rate and the direction in which the tool 10 is moving either up or down the wellbore 100. The operating program 210 may generate an actuation signal 207 to signals the actuator to operate and to extend or retract at least one or both of the first plurality of arms 25 and the second plurality of arms 50. The interaction of the first plurality of arms 25 and the second plurality of arms 50 with the panels 40 with the fluid in the wellbore (and the viscosity, density, and flow rate of the fluid either up or down the wellbore 100) and the influence of gravity may affect whether or not the tool is moving up or down the wellbore and at what rate (if it is moving) up or down the wellbore. The operating program 210 may then function the actuator to modify the direction and the rate at which the tool 10 travels or hovers/remains stationary in the wellbore in accordance with programmed directions.

[0042] In some embodiments, the operating program 210 and/or the controller 206 may include a provision to allow a user at the surface system to override the program and to instruct the operating program 210 to generate and transmit the actuation signal 207 via the controller 206 to the actuator regardless of the data that the first sensor 202 and/or the second sensor 204 are detecting.

[0043] The control system 200 also includes the controller 206, such as a general-purpose computer, specific purpose computer, reduced instruction set chips, and other known types of controllers and/or processors. The controller 206 receives at least one of the first signal 201 and the second signal 203 either directly from the first sensor 202 and the second sensor 204, respectively, or retrieves the first signal 201 and the second signal 203 from the memory storage device 208 which had previously received it directly from the first sensor 202 and the second sensor 204 or the controller 206. The controller 206 additionally calls 205 the operating program 210 in order to calculate the actuation signal 207. The controller 206 then transmits the calculated actuation signal 207 to the actuator to transition at least one the first plurality of arms 25 and the second plurality of arms 50 from the first position 30 to the second position 35 or vice-versa. In some embodiments, leads or electrical conduits electrically couple the controller 206 to at least one of the first sensor 202, the second sensor 204, the memory storage device 208, the power source 212, and the actuator.

[0044] The control system 200 includes at least one power source 212 that provides power to at least one of the first sensor 202, the second sensor 204, the memory storage device 208 and the controller 206 through, for example, leads or electrical conduits 213. For example, the power source 202 typically is a chemical source of power, such as a battery (rechargeable or otherwise) on the tool 10, although the power source may be located elsewhere. For example, the power source 212 may be a source of electrical power provided by the surface system 30, which transmits the power via the communication link 102 to the tool 100. In other embodiments, the power source 212 may be located on another tool to which the tool 100 is coupled. For examples, the power source 212 may be batteries and/or a generator coupled to a turbine that converts the flow of a drilling fluid into electrical power.

[0045] In addition, methods of calculating the actuation signal 207 are disclosed. One embodiment of such a method is for calculating an actuation signal 207 for use in actuating a component of a tool 10 positioned in a wellbore 100. Optionally, the tool 10 includes a first sensor 202 and at least a second sensor 204, and a memory storage device 208 that stores an operating program 210 that calculates the actuation signal 207. A controller 206 is configured to receive at least one of a first signal 201 generated by the first sensor 202 and optionally a second signal 203 generated by the second sensor 204, to run the operating program 210, and to transmit the actuation signal 207 to the component, such as the actuator. At least one power source 212 provides power to at least one of the first sensor 202, the second sensor 204, the memory storage device 208, and the controller 206. [0046] The method itself comprises detecting at least one of a first parameter with the first sensor 202 and optionally a second parameter with the at least second sensor 204. The method further includes generating at least one of the first signal 201 representative of the first parameter with the first sensor 202 and optionally the second signal 203 representative of the second parameter with the at least second sensor 204. Optionally, at least one of the first signal 201 and the second signal 203 at a first time and at a subsequent time are stored on the memory storage device 208. An actuation signal 207 may be calculated as a function of one or more of: the first signal 201; the second signal 203; and a difference in at least one of the first signal 201 and the second signal 203 at the first time and at the subsequent time. The actuation signal 207 optionally may be a function of one or more of a velocity of the tool 10 (up and/or down) in the wellbore 100, the acceleration of the tool 10 (up and/or down) in the wellbore 100, the effect of gravity on the tool 10, the flow rate of a fluid or fluids in the wellbore 100, the density of the fluid or fluids in the wellbore 100, and the viscosity of the fluid or fluids in the wellbore 100, thereby modulating whether at least one of the first plurality of arms 25 and the second plurality of arms 50 are in the first position 30 or the second position 35.

[0047] The method also includes transmitting the actuation signal 207 to the component, such as the actuator. Optionally, the method includes one or more of: extending the first plurality of arms coupled to the housing of the tool; retracting the first plurality of arms coupled to the housing of the tool; extending the second plurality of arms coupled to the housing of the tool; retracting the second plurality of arms coupled to the housing of the tool; moving the tool one of up the wellbore and down the wellbore; and wherein a flow of a fluid in the wellbore acts upon the panel to urge the tool one of up the wellbore and down the wellbore.

[0100] It should be understood that various changes and modifications to the presently preferred embodiments described herein will be apparent to those skilled in the art. Such changes and modifications can be made without departing from the spirit and scope of the present invention and without diminishing its intended advantages. It is therefore intended that such changes and modifications be covered by the appended claims.

Claims

CLAIMS What is claimed is:

1. A tool for use in a wellbore, said wellbore including a wellbore wall a wellbore diameter, said tool comprising:

a housing that includes:

a first plurality of arms, wherein each arm of the first plurality of arms includes a first end coupled to the housing and a second end spaced apart from the first end, wherein the first plurality of arms is extendable from a first position in which the first end and the second end of each arm of the first plurality of arms is proximate the housing and a second position in which at least the second end of each arm of the first plurality of arms is displaced radially away from the housing;

at least one panel extendable between at least two arms of the first plurality of arms when the first plurality of arms is in the second position; and, an actuator coupled to the first plurality of arms that extends the first plurality of arms from at least the first position to at least the second position.

2. The tool of claim 1, further comprising a biasing mechanism coupled to the first plurality of arms, wherein the biasing mechanism urges the first plurality of arms towards the first position.

3. The tool of claim 1, wherein the tool further comprises a communication link able to at least one of transmit data to and receive data from a surface system.

4. The tool of claim 1, wherein the at least one panel comprises at least one of a fabric, an elastomer, and a metal.

5. The tool of claim 1, wherein the at least one panel includes at least one perforation.

6. The tool of claim 4, wherein the at metal comprises segmented sections.

7. The tool of claim 1, further comprising:

a second plurality of arms, wherein each arm of the second plurality of arms includes a first end coupled to the housing and a second end spaced apart from the first end, wherein the second plurality of arms is extendable from the first position in which the first end and the second end of each arm of the second plurality of arms is proximate the housing and a second position in which at least the second end of each arm of the second plurality of arms is displaced radially away from the housing; and, at least one panel extendable between at least two arms of the second plurality of arms when the second plurality of arms is in the second position.

8. The tool of claim 7, wherein at least one panel of the first plurality of arms is coupled to at least one panel of the second plurality of arms.

9. The tool of claim 7, wherein the second end of at least one arm of the first plurality of arms is pivotally coupled to the second end of at least one arm of the second plurality of arms.

10. The tool of claim 1, further comprising a control system that includes:

at least a first sensor configured to detect a first parameter and generate a first signal

reflective of said first parameter;

a memory storage device to store an operating program, the operating program configured to calculate an actuation signal as a function of at least one of the first signal;

a controller configured to receive at least one of the first signal from the first sensor, to run the operating program, and to transmit an actuation signal to the actuator to transition the at least a first plurality of arms from a first position to a second position; and, at least one power source that provides power to at least one of the first sensor, the memory storage device, and the controller.

11. The tool of claim 10, further comprising at least a second sensor, the second sensor detecting at least a second parameter and generating a second signal reflective of the second parameter.

12. The tool of claim 10, wherein the at least a first sensor is selected from the group consisting of a continuity sensor, resistivity sensor, a power sensor, a vibration sensor, an accelerometer, a pressure sensor, an acoustic sensor, an electromagnetic sensor, a gamma ray sensor, a neutron sensor, a magnetometer, a temperature sensor, and a flow sensor.

13. A method of calculating an actuation signal for use in actuating the actuator of the tool of claim 1, the tool including:

at least a first sensor;

a memory storage device that stores an operating program that calculates the actuation signal;

a controller configured to receive at least one of a first signal generated by the first sensor, to run the operating program, and to transmit the actuation signal to the actuator; at least one power source that provides power to at least one of the at least the first sensor, the memory storage device, and the controller:

detecting at least one of a first parameter with the first sensor;

generating at least one of the first signal representative of the first parameter with the first sensor;

storing at least one of the first signal on the memory storage device;

calculating the actuation signal as a function of the first signal;

transmitting the actuation signal to the actuator;

actuating the actuator;

wherein the method further comprises:

extending the first plurality of arms coupled to the housing of the tool; and,

moving the tool one of up the wellbore and down the wellbore.

14. The method of claim 13, wherein a flow of a fluid in the wellbore acts upon the panel to urge the tool one of up the wellbore and down the wellbore.

15. The method of claim 13, further comprising retracting the first plurality of arms coupled to the housing of the tool.