Torsional damping and flexible members in downhole systems and methods

Abstract

The flexible downhole component includes an upper connector for connecting the flexible downhole component to a first downhole tool and a lower connector for connecting the flexible downhole component to a second downhole tool. The flexible downhole component includes a flexible body disposed between an upper connector and a lower connector. The flexible downhole component includes an upper damping component and a lower damping component, each configured to damp torsional oscillations.

Description

[0001] CROSS-REFERENCE TO RELATED APPLICATIONS

[0002] not applicable Technical Field

[0003] The present application relates to torsional damping and compliance components, and more particularly to torsional damping and compliance components in downhole systems and methods. Background Art

[0004] Wellbores may be drilled into surface locations or the seafloor for various exploration or production purposes. For example, wellbores may be drilled to access fluids stored in underground formations, such as liquid and gaseous hydrocarbons, and to extract fluids from the formations. Wellbores for producing or extracting fluids may be formed in earthen formations using earth-boring tools, such as drill bits for drilling the wellbore and reamers for enlarging the diameter of the wellbore.

[0005] Downhole drilling systems may include one or more rotating components. During operation, the rotating components may perform various operations, including power generation, drilling, reaming, casing cutting, milling, steering, and other rotating operations. While rotating, the components may experience various types of vibrations, including axial, lateral, and torsional oscillations. Vibrations or oscillations may fatigue components of the downhole tool (e.g., housing, shaft, etc.), increase wear, reduce tool efficiency, or damage the downhole tool. Summary of the invention

[0006] In some embodiments, the flexible downhole component includes an upper connector for connecting the flexible downhole component to a first downhole tool and a lower connector for connecting the flexible downhole component to a second downhole tool. The flexible downhole component includes a flexible body disposed between the upper connector and the lower connector. The flexible downhole tool includes an upper damping component configured to damp torsional oscillations and a lower damping component configured to damp torsional oscillations.

[0007] In some embodiments, a flexible downhole system includes a flexible body and a first torsional damping component integrally coupled to the flexible body. The first torsional damping component includes a viscous inertial damping element.

[0008] In some embodiments, a method of assembling a flexible downhole component includes coupling an upper damping component to an uphole end of a flexible body. The upper damping component is configured to mitigate a first mode of high frequency torsional oscillation (HFTO) of the flexible downhole component. The flexible body is configured to flex throughout rotation of the flexible downhole component to facilitate a dogleg of a downhole tool connected to the flexible downhole component. The method includes coupling a lower damping component to the downhole end of the flexible body. The lower damping component is configured to mitigate a second mode of HFTO of the flexible downhole component.

[0009] This summary is provided to introduce some concepts that will be further described in the detailed description. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used to help limit the scope of the claimed subject matter. Additional features and aspects of the embodiments of the present disclosure will be set forth herein, and in part will be apparent from the description, or may be learned through practice of these embodiments. BRIEF DESCRIPTION OF THE DRAWINGS

[0010] In order to describe the manner in which the above and other features of the present disclosure can be obtained, a more specific description will be given with reference to the specific embodiments of the present disclosure shown in the accompanying drawings. For better understanding, the same elements are represented by the same reference numerals in the various drawings. Although some of the drawings may be schematic or exaggerated representations of concepts, at least some of the drawings may be drawn to scale. It should be understood that the drawings depict some exemplary embodiments, which will be described and explained with additional specificity and detail through the use of the drawings, in which:

[0011] Figure 1 is a schematic diagram of a drilling system according to at least one embodiment of the present disclosure;

[0012] Figure 1-1 is a schematic diagram of a drilling system according to at least one embodiment of the present disclosure;

[0013] Figure 2 and 2-1 is a schematic diagram of a flexible downhole component according to at least one embodiment of the present disclosure;

[0014] Figure 3 is a schematic diagram of a flexible downhole component according to at least one embodiment of the present disclosure;

[0015] Figure 4 is an exploded schematic diagram of a flexible downhole component according to at least one embodiment of the present disclosure;

[0016] Figure 5 is an exploded schematic diagram of a flexible downhole component according to at least one embodiment of the present disclosure;

[0017] Figure 6-1 is a schematic diagram of a flexible downhole tool according to at least one embodiment of the present invention;

[0018] Figure 6-2 is a schematic diagram according to at least one embodiment of the present disclosure, including exploded and assembled views of a flexible downhole component relative to an upper damping tool and a lower damping tool;

[0019] Figure 7-1 shows example vibration data in accordance with at least one embodiment of the present disclosure;

[0020] Figure 7-2shows example vibration data in accordance with at least one embodiment of the present disclosure;

[0021] Figure 7-3 shows example vibration data in accordance with at least one embodiment of the present disclosure;

[0022] Figure 7-4 illustrates example vibration data in accordance with at least one embodiment of the present disclosure; and

[0023] Figure 8 A flow chart is shown of a method or series of acts for assembling a flexible downhole component as described herein, in accordance with at least one embodiment of the present disclosure. DETAILED DESCRIPTION

[0024] Embodiments of the present disclosure relate to devices, systems and methods for damping vibrations / oscillations in downhole tools. For example, a downhole system may experience various motions, vibrations and oscillations. In some embodiments, the motion is associated with drilling activities. For example, one or more downhole tools may rotate to degrade formations or other downhole materials. Downhole tools may include rotating drill bits, milling cutters or reamer. The engagement of downhole tools and / or drill strings with downhole materials, the flow of drilling or production fluids against or through downhole tools, or other conditions may cause vibrations, torsional oscillations and other motions. For the purposes of this disclosure, the terms vibration, oscillation and other motions may be used interchangeably, unless otherwise specified, and may refer to vibrations in or exhibited by any component of a drilling system, such as axial vibrations, lateral vibrations and torsional oscillations. In some embodiments, the vibrations are high frequency torsional oscillations (HFTO). If not controlled, these torsional oscillations may damage, increase wear or increase fatigue of one or more components of the downhole system, as well as combinations thereof. A damping component may be included in the downhole system to reduce the effects of torsional oscillations. For example, a damping component may be included in one or more downhole tools. The damping components may reduce the amplitude and / or frequency of the torsional oscillations.Of course, vibrations and oscillations may be a problem in other downhole environments besides drilling (eg, testing, perforating, production, artificial lift, etc.), and downhole environments should not be limited to drilling systems.

[0025] Figure 1 and 1-1 One example of a drilling system 100 is shown for drilling a formation 101 to form a wellbore 102. The drilling system 100 includes a drilling rig 103 for rotating a drilling tool assembly 104 extending downwardly into the wellbore 102. The drilling tool assembly 104 may include a drill string 105, a bottom hole assembly (BHA) 106, and a drill bit 110 attached to the downhole end of the drill string 105.

[0026] The drill string 105 may include several joints of drill pipe 108 connected end to end by tool joints 109. The drill string 105 transmits drilling fluid through a central bore and transmits rotational power from the drilling rig 103 to the BHA 106. In some embodiments, the drill string 105 also includes additional components, such as short joints, short joints, etc. The drill pipe 108 provides hydraulic passages through which drilling fluid is pumped from the surface. The drilling fluid is discharged through nozzles, orifices or other orifices in the drill bit 110 for cooling the drill bit 110 and the cutting structure thereon, and for lifting drill cuttings out of the wellbore 102 while drilling.

[0027] The BHA 106 may include a drill bit 110 or other components. An exemplary BHA 106 may include additional or other components (e.g., coupled between the drill string 105 and the drill bit 110). Examples of additional BHA components include drill collars, stabilizers, measurement while drilling (MWD) tools, logging while drilling (LWD) tools, downhole motors, borehole reamers, face mills, hydraulic breakouts, jars, vibration or damping tools, other components, or combinations of the foregoing. The BHA 106 may also include a rotary steerable system (RSS). The RSS may include a directional drilling tool that changes the direction of the drill bit 110, thereby changing the trajectory of the wellbore 102. In some cases, at least a portion of the RSS maintains a geostationary position relative to an absolute reference system (e.g., gravity, magnetic north, or true north). Using measurements obtained using the geostationary position, the RSS can position the drill bit 110, change the course of the drill bit 110, and guide the directional drilling tool on a planned trajectory.

[0028] In some embodiments, the drilling system 100 includes a flexible downhole component 111, such as a flexible sub. The flexible downhole component 111 can facilitate the guidance of the BHA 106 and / or the drill bit 110. For example, Figure 1-1 As shown, the flexible downhole component 111 can bend so that a portion (or all) of the BHA 106 can be advanced through the formation 101 at a certain angle relative to another portion of the wellbore 102. The flexible downhole component 111 can bend in response to the RSS that guides and / or biases the drill bit 110 and / or the BHA 106 in a particular direction. As will be discussed herein, the flexible downhole component 111 can include one or more reduced diameter portions to facilitate bending of the flexible downhole component 111. In many cases, the overall length of the BHA 106 may directly affect the ability to steer the BHA 106, or to achieve a certain degree of sharp turns. For example, a longer BHA 106 may reduce the ability to achieve tight (tight) sharp turns, or the ability to guide the BHA 106 at a more acute angle. Therefore, although the flexible downhole component 111 can bend to facilitate the steering of the BHA 106, the overall length of the BHA 106 can affect how large an angle can be achieved.

[0029] The flexible downhole component 111 is not limited to the just mentioned embodiments, but can be any flexible component used to facilitate directional drilling of the drill bit 110 and / or BHA 106 as described herein. In addition, the flexible downhole component 111 is not limited to being included as part of the BHA 106 (or between the BHA 106 and the drill string 105), but can be included in any (or multiple) positions in the drilling tool assembly 104 of the drilling system 100.

[0030] In general, the drilling system 100 may include additional or other drilling components and accessories, such as special valves (e.g., kelly cocks, blowout preventers, and safety valves). The additional components included in the drilling system 100 may be considered part of the drilling tool assembly 104, the drill string 105, or part of the BHA 106, depending on their location in the drilling system 100.

[0031] In some embodiments, a downhole motor in the BHA 106 generates electricity for the downhole system and / or provides rotational energy for downhole components (e.g., rotating the drill bit 110). The downhole motor can be any type of downhole motor, including a positive displacement pump (e.g., a screw motor) or a turbine. In some embodiments, the downhole motor is powered by drilling fluid. In other words, drilling fluid pumped from the surface to the downhole can provide energy to rotate the rotor in the downhole motor. The downhole motor can operate at an optimal pressure differential or range of pressure differentials. The optimal pressure differential can be a pressure differential at which the downhole motor will not stall, burn out, overspeed, or otherwise be damaged. In some cases, the downhole motor drives the drill bit to rotate. In some embodiments, the rotation of the drill bit is driven by components at the surface of the wellbore 102.

[0032] The drill bit 110 in the BHA 106 can be any type of drill bit suitable for degrading downhole materials. For example, the drill bit 110 can be a drill bit suitable for drilling the formation 101. Example types of drill bits used to drill the formation are fixed cutter or drag bits and roller cone drill bits. In other embodiments, the drill bit 110 can be a mill for removing metals, composites, elastomers, other downhole materials, or combinations thereof. For example, the drill bit 110 can be used with a whipstock to drill into a casing 107 lining the wellbore 102. The drill bit 110 can also be a waste mill for grinding away tools, plugs, cement, other materials, or combinations thereof within the wellbore 102. The cuttings or other cuttings formed by using the mill may be lifted to the surface, or may fall downhole. In other embodiments, the drill bit 110 may include a reamer. For example, a borehole reamer can be used in conjunction with a drill bit, and the drill bit can drill into the formation while the reamer expands the size of the borehole.

[0033] The operation of the rotating drill string 105 and / or the downhole motor may cause oscillations in the drilling tool assembly 104 (e.g., the drill string 105 and / or the BHA 106) in whole or in part. Such oscillations may have various effects. For example, oscillations may be generated by energy input into the system, which may substantially deprive the energy input into the drill bit 110, reducing the effective transfer of energy to the drill bit. The vibrations / oscillations may also damage one or more components of the drilling system 100, such as one or more components of the BHA 106. In some embodiments, the oscillations are associated with the flexible downhole component 111. For example, the vibrations may be at least partially attributed to or caused by the flexible downhole component 111 (e.g., the flexible nature of the flexible downhole component 111 may cause a torsional imbalance or mismatch with other parts of the BHA 106, thereby causing vibrations). In another example, the oscillations (e.g., a significant or peak amplitude of the oscillations) may be present at or near the flexible downhole component 111 (e.g., above and / or below the flexible downhole component 111). Thus, while the flexible downhole component 111 may be important or even necessary for desired guidance of the BHA 106 , implementing the flexible downhole component 111 may result in HFTO, which may damage, wear, fatigue, etc., one or more components of the downhole system.

[0034] In some embodiments, the drilling system 100 includes one or more damping components 112. The damping components 112 can at least partially damp oscillations. The damping components 112 can be positioned on the flexible downhole component. For example, the damping components 112 can be a part of the flexible downhole component 111. One or more damping components 112 can be positioned at the uphole end and / or the downhole end of the flexible downhole component 111. Using the damping components 112 to reduce oscillations in the drilling tool assembly 104 (e.g., in the BHA 106) can reduce damage to components of the BHA 106 and / or more efficiently transfer power / energy to the drill bit 110. In this way, the damping components 112 can help improve system efficiency, reduce downtime, and reduce costs. Therefore, it may be advantageous to include one or more damping components 112 in the downhole system. However, as described above, the length of the BHA 106 may directly affect the ability of the BHA 106 to steer or make sharp turns. Therefore, while reducing and / or mitigating vibrations may be important, it may be critical to include the damping components 112 in a manner that does not increase the overall length of the BHA 106 so that steering / sharp turns are not adversely affected.

[0035] Figure 2 and 2-1 is a schematic diagram of a flexible downhole component 211 according to at least one embodiment of the present disclosure. The flexible downhole component 211 may be included as part of a drilling tool assembly, such as part of a BHA (or at any other location) in a downhole drilling system.

[0036] In some embodiments, the flexible downhole component 211 includes an upper connector 213 and a lower connector 214. The upper connector 213 and the lower connector 214 can each be a connector for connecting the flexible downhole component 211 to a portion of a drilling tool assembly. For example, the upper connector 213 can connect the flexible downhole component 211 to a first downhole tool 216. The lower connector 214 can connect the flexible downhole component 211 to a second downhole tool 217. For example, the first downhole tool 216 and the second downhole tool 217 can each be one or more of a drill pipe, a short joint, a drill bit, a reamer, a stabilizer, an RSS, a motor, an LWD tool, an MWD tool, a tool joint, a BHA as described herein, a drill string, or any other component of a drilling tool assembly, and combinations thereof. The flexible downhole component 211 can be implemented in a downhole system that is connected to a 6 1 / 4 inches, 8 1 is associated with the formation, drilling or widening of a 1 / 2 inch, 9 inch or 12 inch borehole, or any value therebetween.

[0037] In some embodiments, the upper connector 213 and the lower connector 214 are threaded connectors, or are coupled to the first downhole tool 216 and the second downhole tool 217 (respectively) by threaded connectors. In some embodiments, the upper connector 213 and / or the lower connector 214 are male threaded connectors for screwing into the female threaded connectors of the corresponding downhole tools. In some embodiments, the upper connector 213 and / or the lower connector 214 are female threaded connectors for screwing into the male threaded connectors of the corresponding downhole tools. For example, in some embodiments, the upper connector 213 and the lower connector 214 can both be female threaded connectors. In another example, the upper connector 213 and the lower connector 214 can both be male threaded connectors. According to at least one embodiment of the present disclosure, as Figure 2 As shown, the upper connector 213 is a female threaded connector and the lower connector 214 is a male threaded connector. In this manner, the flexible downhole component 211 can be coupled to various components of a downhole system while, for example, including one or more dampers for damping vibrations, as described below.

[0038] In some embodiments, the flexible downhole component 211 includes a flexible body 215. The flexible body 215 may be disposed between the upper connector 213 and the lower connector 214. The flexible body 215 may be integral with or coupled to the upper connector 213 and the lower connector 214. In this manner, one or more downhole tools located above the flexible body 215 and one or more downhole tools located below the flexible body 215 may be coupled through the flexible body 215. For example, the first downhole tool 216 may be a drill string, and the second downhole tool 217 may be a BHA. In this manner, the flexible downhole component 211 may couple the BHA to the drill string. According to at least one embodiment of the present disclosure, the flexible downhole component 211 may be included as part of a BHA of a downhole system. The BHA may include one or more engagement tools, such as a drill bit, and one or more drive and guide tools that may drive the drill bit to rotate and deflect relative to one another. The flexible downhole component 211 may be positioned in the BHA so that the guide component guides the drill bit at a desired angle, thereby facilitating the guidance of the downhole system.

[0039] The flexible body 215 can bend (i.e., flex) throughout the rotation of the flexible downhole component 211. The bending of the flexible body 215 can help position and / or orient one or more downhole components of the drilling system at a certain angle relative to one or more other downhole components. For example, the flexible body 215 can bend and can allow the second downhole tool 217 to extend in a direction that is at a certain angle relative to the first downhole tool 216 (e.g., Figure 1-1 ). The flexible body 215 may bend in this manner during or while the flexible downhole component 211 is rotated, and in this manner, the flexible body 215 may facilitate manipulation of one or more downhole components, such as during downhole drilling operations.

[0040] In some embodiments, the flexible properties of the flexible body 215 are based on a different (e.g., reduced) stiffness of the flexible body 215 relative to other downhole components. For example, the flexible body 215 can have a flexible body stiffness. The upper connector 213 (and / or any other component on the flexible body 215 well) can have an upper connector stiffness. The lower connector 214 (and / or any other component downhole of the flexible body 215) can have a lower connector stiffness. The flexible body stiffness can be less than the upper connector stiffness and / or the lower connector stiffness. This can allow or facilitate the flexible downhole component 211 to bend more than one or more other components, such as the upper connector 213 and / or the lower connector 214, in the manner described herein. The flexible body stiffness, the upper connector stiffness, and the lower connector stiffness can each refer to the stiffness (of the respective component) relative to bending (e.g., bending moment) or relative to torsional loads or both. For example, while the flexible body may exhibit a flexible body stiffness to allow the flexible body 215 to bend when rotating, the flexible body may also (or as a result) exhibit a torsional stiffness that is less than the torsional stiffness of the upper connector 213, the lower connector 214, and / or any other downhole component. This reduced torsional aspect of the flexible body stiffness may be associated with (and / or may cause) vibrations in one or more components of the drilling system, such as the HFTO, as will be described in detail herein.

[0041] In some embodiments, the flexible body stiffness is based on the size of the flexible body 215. For example, the flexible body 215 can have substantially circular dimensions or can be substantially cylindrical. Figure 2-1 As shown, the flexible body 215 can have a flexible body diameter 218. The upper connector 213 can have an upper connector diameter 219, and the lower connector can have a lower connector diameter 220. The upper connector diameter 219 and the lower connector diameter 220 can be measurements of the diameters at the widest points of the upper connector 213 and the lower connector 214, respectively. In some embodiments, the upper connector diameter 219 corresponds to the diameter of the first downhole tool 216 (or any other component above the flexible body 215), and the lower connector diameter 220 corresponds to the diameter of the second downhole tool 217 (or any other component below the flexible body 215). The upper connector diameter 219 and the lower connector diameter 220 can be the same or different. The flexible body diameter 218 can be smaller than the upper connector diameter 219 and / or the lower connector diameter 220. The flexible body diameter 218 reduced in this manner can facilitate the flexible body 215 to bend in the manner described herein (e.g., by rotation of the flexible downhole component 211).

[0042] In some embodiments, at least a portion of the flexible body 215 is made of the same material as the upper connector 213 and the lower connector 214. As described herein, this can help to form the flexible downhole component 211 as a single body. In some embodiments, at least a portion of the flexible body 215 is made of a different material than the upper connector 213 and the lower connector 214. In some embodiments, the flexible body 215 is made of steel, such as low alloy steel or stainless steel. In this way, the flexible downhole component 211 can include the flexible body 215 to facilitate guiding and / or directing one or more downhole tools at a certain angle relative to other parts of the drilling tool assembly.

[0043] In some embodiments, the flexible downhole component 211 includes one or more damping components for damping vibrations (e.g., HFTO). The flexible downhole component 211 may include an upper damping component 212-1. The flexible downhole component 211 may include a lower damping component 212-2. The upper damping component 212-1 and the lower damping component 212-2 may each damp vibrations (e.g., HFTO) experienced and / or presented by the flexible downhole component 211 and / or any other downhole component. For example, the upper damping component 212-1 and the lower damping component 212-2 may damp the same or different modes present in the HFTO. The upper damping component 212-1 and the lower damping component 212-2 may each damp torsional oscillations of the attached BHA.

[0044] The upper damping component 212-1 and / or the lower damping component 212-2 (together, the damping component 212) can be an inertial damping component. For example, the damping component 212 can include a damper body. One or more inertial elements can be disposed in the damper body. The one or more inertial elements can be at least partially suspended in the damper body by a damping feature. The damping feature can include a fluid, a biasing element, or any combination thereof. Forces on the damper body, such as caused by vibrations similar to HFTO, can be transmitted to one or more inertial elements therein through the damping component. The one or more inertial elements resist the change in motion transmitted by the damping feature. At least some of the energy from the motion (e.g., vibration) of the damper body can be dissipated to or transmitted to the inertial elements via the damping feature. For example, the vibration energy transmitted to the damping component 212 can heat the damping feature and one or more inertial elements of the damping component 212. In this way, the damping component 212 (e.g., based on the inertial element) can damp vibrations in the drilling tool assembly.

[0045] It should be understood that the damping component 212 is not limited to the damping techniques just mentioned. Instead, the damping component 212 can be any component for dissipating mechanical energy from a vibrating structure and / or removing mechanical energy (e.g., vibration) from a system. For example, the damping component 212 may include one or more components that operate based on the principles of viscous damping, Coulomb or dry friction damping, structural damping, material or hysteresis damping, sliding or interface damping, magnetic damping, any other form or principle of damping, and combinations thereof. Non-limiting examples and embodiments of the damping component 212 for damping vibrations experienced by one or more downhole tools can be found in U.S. Patent Application No. US2023 / 0142360, which is incorporated herein by reference in its entirety. According to at least one embodiment of the present disclosure, the damping component 212 may help damp torsional vibrations, such as HFTO.

[0046] In some embodiments, the upper damping component 212-1 is located at an uphole portion of the flexible body 215. For example, the upper damping component 212-1 can be located at the upper connector 213 (e.g., but not screwed into the upper connector 213). The upper damping component 212-1 can be coupled to the flexible body 215 at the uphole end of the flexible body 215. In some embodiments, the lower damping component 212-2 is located at a downhole portion of the flexible body 215. For example, the lower damping component 212-2 can be located at the lower connector 214 (e.g., but not screwed into the lower connector 214). The lower damping component 212-2 can be coupled to the flexible body 215 at the downhole end of the flexible body 215. Including and positioning the upper damping component 212-1 and / or the lower damping component 212-2 above and / or below the flexible body 215 in this manner can help damp and / or mitigate one or more modes of HFTO, as will be described herein (e.g., in conjunction with FIG. 7). The upper damping member 212-1 and the lower damping member 212-2 included in or as part of the flexible downhole member 211 may also help maintain a shorter overall length of the flexible downhole member 211 and / or the BHA. This may be in contrast to connecting a separate damping member to the flexible downhole member, which may result in an increased length of the BHA. As described above, this shorter length may help operate the BHA in tighter turns (e.g., as in conjunction with Figure 6-1 and 6-2 described above).

[0047] Figure 3 is a schematic diagram of a flexible downhole component 311 according to at least one embodiment of the present disclosure. The flexible downhole component 311 may include a flexible body 315, an upper connector 313, and a lower connector 314. The flexible downhole component 311 may include an upper damping component 312-1, a lower damping component 312-2, or both.

[0048] In some embodiments, the flexible downhole component 311 is made of a main body. The upper connector 313, the upper damping component 312-1, the flexible body 315, the lower damping component 312-2 and the lower connector 314 can be formed in one piece. For example, the upper damping component 312-1 and the lower damping component 312-2 can each include a damper housing, and one or more separate damping components are located in the damper housing. The damping housing of each of the upper damping component 312-1 and the lower damping component 312-2 can be formed in one piece with the upper connector 312-1, the lower connector 314 and the flexible body. These components can be formed in one piece by machining from the same piece of material, or by casting into a whole. The integrally formed flexible downhole component 311 can include a main body portion of each of the upper damping component 312-1 and the lower damping component 312-2, and the damping mechanism of each damping component can be contained in the main body portion and / or can be operable in the main body portion. The flexible downhole component 311 integrally formed in this manner can facilitate, for example, implementation of the flexible downhole component 311 in a downhole system without requiring any assembly after manufacture or at the drilling site. Including the upper damping component 312-1 and the lower damping component 312-2 in the integral body of the flexible downhole component 311 can also facilitate implementation of these components in a downhole system while, for example, maintaining a short length of the flexible downhole component 311 and / or the BHA (e.g., as described herein in conjunction with Figure 6-1 and 6-2 described above).

[0049] Figure 4 4 is an exploded schematic diagram of a flexible downhole component 411 according to at least one embodiment of the present disclosure. The flexible downhole component 411 may include a flexible body 415, an upper connector 413, and a lower connector 414. The flexible downhole component 411 may include an upper damping component 412-1, a lower damping component 412-2, or both.

[0050] In some embodiments, the flexible downhole component 411 is an assembly. For example, when assembled, two or more components can form the flexible downhole component 411. In some embodiments, one or more of the upper connector 413, the upper damping component 412-1, the lower damping component 412-2, and the lower connector 414 are separated and / or independent from the flexible body 415 and assembled with the flexible body 415 to form the flexible downhole component 411.

[0051] According to at least one embodiment of the present disclosure, the upper connector 413 and the upper damping component 412-1 can be combined into one body (e.g., formed as one piece). In other words, the upper damping component 412-1 may include the upper connector 413. The upper damping component 412-1 and the upper connector 413 can be assembled with the flexible body 415. For example, these components can be coupled to the flexible body 415 by threaded connection, bolted connection, welded connection, or any other suitable connection (and combination thereof) for coupling the upper damping component 412-1 and the upper connector 413 to the flexible body 415. Similarly, the lower connector 414 and the lower damping component 412-2 can be combined into one body (e.g., formed as one piece) and coupled to the flexible body 415.

[0052] In some embodiments, the upper damping component 412-1 and the upper connector 413 are separate and / or independent bodies (e.g., not integrally formed). For example, the upper damping component 412-1 and the upper connector 413 can be separately coupled to the flexible body 415. In another example, the upper damping component 412-1 and the upper connector 413 can be coupled to each other before and / or in order to couple these components to the flexible body 415. The connection between the upper damping component 412-1 and the upper connector 413 (and / or the connection between these components and the flexible body 415) can be a threaded connection, a bolted connection, a welded connection, or any other suitable connection (and combination thereof) for coupling these components as described herein. In this way, the upper damping component 412-1 and the upper connector 413 can be coupled to the flexible body 415 in the same position and / or orientation as described above, but each component can be a separate body and / or can be separately coupled to other components. In some embodiments, the lower damping component 412-2 and the lower connector 414 are separate and / or independent bodies, and it should be understood that the techniques just described are similarly applicable to the connection of the lower damping component 412-2 to the lower connector 414 (and / or the connection of these components to the flexible body 415).

[0053] The components of the flexible downhole component 411 may be assembled and / or combined as part of the manufacture of the flexible downhole component 411. The components of the flexible downhole component 411 may be assembled and / or combined after manufacture, such as at the drilling site, or before arriving at the drilling site. In this manner, one or more components or parts of the flexible downhole component 411 may be modular and / or the flexible downhole component 411 may be an assembly. This may facilitate, for example, including a damping component within an existing flexible body 415, such as part of a retrofit. It should be understood that although Figure 4The flexible downhole component 411 described in the foregoing can be an assembly and can be assembled using, for example, a threaded connection, but the techniques just mentioned are consistent with the techniques described herein for including a damping component as part of or within the flexible downhole component 411 (e.g., without increasing the length). This may be contrasted with, for example, incorporating one or more damping components into an existing or conventional flexible downhole component (e.g., at an upper and / or lower tool connection), resulting in an overall longer assembly of the components. In contrast, the length savings that can be achieved by incorporating the flexible downhole component of the present disclosure will be discussed below in conjunction with Figure 6-1 and 6-2 In this manner, the flexible downhole component 411 can achieve the length goals and / or requirements of the flexible downhole component 411 and / or the BHA, as described herein (e.g., in conjunction with Figure 6-1 and 6-2 ).

[0054] Figure 5 is an exploded schematic diagram of a flexible downhole component 511 according to at least one embodiment of the present disclosure. The flexible downhole component 511 may include a flexible body 515, an upper connector 513, and a lower connector 514. The flexible downhole component 511 may include an upper damping component 512-1, a lower damping component 512-2, or both.

[0055] In some embodiments, the flexible downhole component 511 is an assembly. For example, when assembled, two or more components can form the flexible downhole component 511. According to at least one embodiment of the present disclosure, the upper connector 513, the lower connector 514 and the flexible body 515 can be formed together into an integral body 521. For example, these components can all be machined from the same piece of material, or they can all be cast into a whole. In some embodiments, the upper damping component 512-1 and / or the lower damping component 512-2 (together, the damping component 512) are separate and / or independent bodies from the integral body 521. The damping components 512 can each be coupled to the integral body 521. For example, the upper damping component 512-1 and the lower damping component 512-2 are Figure 5560-1 and 560-2, respectively. The damping component 512 can be coupled to the integral body 521 at the assembly positions 561-1 and 561-2, respectively. In some embodiments, the damping component 512 can be hollow or can have an inner hole so that they can pass over the connector on the integral body 521. In another example, the damping component 512 can have one or more split or open features (or the damping components 512 can each be two or more pieces) so that they can fit and / or close around the outer diameter of the flexible body 515. The damping component 512 can be coupled to the integral body 521, for example, by a threaded connection, a welded connection, a bolted connection, any other suitable connection, and combinations thereof. In this way, the damping component 512 can be positioned on the flexible downhole component 511 as described herein.

[0056] The components of the flexible downhole component 511 can be assembled and / or combined as part of the manufacture of the flexible downhole component 511. The components of the flexible downhole component 511 can be assembled and / or combined after manufacture, such as at a drilling site, or prior to arriving at a drilling site. In this manner, one or more components or parts of the flexible downhole component 511 can be modular and / or the flexible downhole component 511 can be an assembly. In some embodiments, the damping component 512 is included in an existing flexible downhole tool, such as as part of a retrofit. Including the damping component 512 in the flexible downhole component 511 in the manner described herein can help provide the damping effect of the damping component while achieving the length goals and / or requirements of the flexible downhole component 511 and / or BHA described herein (for example, in combination with Figure 6-1 and 6-2 ).

[0057] Figure 6-1 61 is a schematic diagram of a downhole assembly 660 including a flexible downhole component 611-1 according to at least one embodiment of the present disclosure. The flexible downhole component 611-1 may include a flexible body 615, an upper connector 613, and a lower connector 614. The flexible downhole component 611-1 may include an upper damping component 612-1, a lower damping component 612-2, or both. The upper damping component 612-1 may be positioned or located at the upper connector 613, and / or the lower damping component 612-2 may be positioned or located at the lower connector 614. For example, the upper damping component 612-1 and / or the lower damping component 612-2 may be located between the upper connector 613 and the lower connector 614. In this manner, the damping component may be included in or as part of the flexible downhole component 611-1. The flexible downhole component 611-1 may be coupled to one or more downhole tools 623 to form a downhole assembly 661. Figure 6-1 will with Figure 6-2 Discuss together.

[0058] Figure 6-2 is a schematic diagram of a downhole assembly 661. The downhole assembly includes a flexible assembly 670 coupled to one or more downhole tools 623. Figure 6-2 An exploded view 670-1 and an assembled view 670-2 of the flexible assembly 670 are shown. According to at least one embodiment of the present disclosure, the flexible assembly 670 includes a flexible downhole component 611-2, an upper damping tool 622-1, and a lower damping tool 622-2. The flexible downhole component 611-2 may include a flexible body 615-2, an upper connector 613-2, and a lower connector 614-2, each connected to the flexible body 615-2. The damping component may not be included as part of the flexible downhole component 611-2 (e.g., Figure 6-1 In contrast, the upper damping tool 622-1 and / or the lower damping tool 622-2 (together, the damping tool 622) can be coupled or attached to the flexible downhole component 611-2, for example, by coupling to the upper connector 613-2 and / or the lower connector 614-2. The damping tools 622 can each include their own connectors, similar to the upper and lower connectors 613-2 and 614-2. In this way, the flexible downhole component 611-2 can be coupled to additional tools and / or portions of the drilling tool assembly through the damping tool 622 or through connection to the damping tool 622. For example, Figure 6-2 As shown, the flexible assembly 670 can be coupled to the downhole tool 623 to form the downhole assembly 661. The downhole tool 623 can be Figure 6-1 The same downhole tools 623 include the same number and arrangement of downhole tools. In this way, Figure 6-1 The downhole assembly 660 may be shown Figure 6-2 An alternative technology to conventional downhole assemblies 661 is provided for implementing one or more damping devices coupled to a flexible downhole member.

[0059] As described herein, a flexible downhole member (e.g., 611-1 or 611-2) may be included in, for example, a BHA to facilitate steering, or guide the BHA in an angled direction (e.g., a sharp turn). To accomplish this, the flexible body 615 may bend as the BHA rotates. Such a sharp turn may have a variety of uses. For example, in some cases, a geological target may not be directly below the drilling rig, and the BHA may be pointed toward the target. Sharp turns may also be used to bypass geological obstacles or adjust the wellbore trajectory to optimize oil and gas recovery.

[0060] The degree to which the sharp turn angle or wellbore trajectory may change may be related (directly or partially) to the length of the BHA. For example, a shorter BHA may be able to complete or create a tighter sharp turn than a longer BHA. For this reason, it may be critical to keep the BHA within a threshold length to ensure that adequate steering measures can be taken as needed.

[0061] Figure 6-1 The flexible downhole component 611-1 can have an overall length l1. For example, the length l1 can be measured from the uphole end to the downhole end of the flexible downhole component 611-1, or from the upper connector 613 to the lower connector 614. As described herein, the flexible downhole component 611-1 may include one or more damping components 612 (e.g., an upper damping component 612-1 and / or a lower damping component 612-2) as part of the flexible downhole component 611-1 or within the flexible downhole component 611-1. For example, the damping component 612 can be located or positioned at or between the upper and lower connectors 613 and 614 of the flexible downhole component 611-1. In this way, the overall length l1 of the flexible downhole component 611-1 can be unaffected by, for example, the addition of the damping component 612. This can be related to, for example, Figure 6-2 62-2). For example, the length l2 may include the length l1 plus the additional lengths 665-1 and 665-2 associated with the attachment of the upper damping tool 622-1 and the lower damping tool 622-2. In some embodiments, the length l1 is extended by the inclusion of the damping component 612, but to a lesser extent than the inclusion of the damping tool 622, such that the length l1 is still less than the length l2. In this manner, l2 may be greater than l1, or Figure 6-2 The flexible components can lead to Figure 6-1 The flexible downhole component 611-1 has a greater overall length.

[0062] like Figure 6-1 As shown, the flexible downhole component 611-1 can be combined with the downhole tool 623 to form a downhole assembly 660. The corresponding downhole assembly length L1 may be directly dependent on or affected by the length l1. In other words, a longer length l1 results in a longer downhole assembly length L1, while a shorter length l1 results in a shorter downhole assembly length L1. Similarly, Figure 6-2 The downhole assembly 661 in the embodiment may be coupled to the same downhole tool 623 (e.g., as a component coupled to the downhole tool 623). Figure 6-1 The corresponding downhole component length L2 may be directly dependent on or affected by the length l2. Because the length l2 is greater than the length l1, the downhole component length L2 is greater than the downhole component length L1. In other words, Figure 6-2 The flexible assembly 670 can result in an overall longer downhole assembly. Such a longer downhole assembly length can reduce the bending ability of the associated BHA, so it may be advantageous to implement the flexible downhole component 611-1 to achieve a shorter downhole assembly length.

[0063] In some embodiments, the downhole assembly length L1 is within a range having an upper limit, a lower limit, or both, including any of 12 feet, 14 feet, 16 feet, 18 feet, 20 feet, 22 feet, 24 feet, 26 feet, 28 feet, 30 feet, or any value therebetween. For example, the downhole assembly length L1 may be less than 30 feet. In another example, the downhole assembly length L1 may be greater than 12 feet. In yet another example, the downhole assembly length may be between 12 feet and 30 feet. In some embodiments, it is critical that the downhole assembly length L1 is no greater than 20 feet in order to provide sharp turns and / or steering benefits for a BHA as described herein.

[0064] As generally discussed herein, a drilling tool assembly includes any number of drilling tools connected by various connectors. For example, a drill string may include multiple lengths of drill pipe, each of which is connected by a tool joint. A BHA may include several tools that are connected to each other, such as a drill bit, a reamer, a flexible component, an RSS, a stabilizer, etc. In addition, the drill string and the BHA are connected by connectors. In this way, there are many connectors downhole in order to connect the various components of the downhole system.

[0065] However, each of these connectors may represent a weak point in the downhole system, leading to reliability issues. For example, each connector represents a point where the tool is joined together, and these joints are usually weaker than the tool itself. In this way, the connection point may have a tendency to fail, for example, before the tool fails. In another example, the connector needs to be assembled, which requires time and resources. Therefore, assembling and disassembling a drilling tool assembly with an increased number of connectors may be time-consuming and expensive. In another example, the connector that needs to be assembled at the drilling site may be prone to reliability issues due to the location of its assembly, the personnel who assemble the connector, the tools and / or resources that can be used for assembly, etc. Therefore, the pre-assembled connector that can arrive at the drilling site may be more reliable than the field connection due to the connectors assembled in factories with better machines and / or tools, more skilled labor, the ability to use different and / or more complex connection methods, etc. In this way, more connectors that need to be assembled at the drilling site may lead to increased reliability issues and increased resource usage associated with the downhole system.

[0066] In addition to contributing to an overall shorter BHA, the flexible downhole member 611-1 can be used to Figure 6-2The flexible assembly 670 (or similar assembly) shown provides reliability benefits with fewer connectors. For example, the flexible downhole component 611-1 can be formed as a one-piece body. Therefore, compared to conventional flexible downhole components, the flexible downhole component 611-1 including one or both of the upper damping component 612-1 and the lower damping component 612-2 can be implemented in a downhole system without adding any additional connectors. Instead, Figure 6-2 The assembly in (or similar assembly) requires at least one additional connection for each damping tool 622. In this manner, the flexible downhole component 611-1 can provide, for example, reliability benefits and / or cost savings over conventional and / or alternative technologies.

[0067] As described herein, rotation of the drilling tool assembly may (at least in part) result in oscillations in the drilling tool assembly (eg, HFTO), which may have various adverse effects on the operation, wear, productivity, life, etc. of the downhole system. Figures 7-1 to 7-4 Example vibration data 725 corresponding to vibrations in a drilling tool assembly according to at least one embodiment of the present disclosure is shown. Various examples of vibration data 725 may include and / or may represent the frequency and / or amplitude of the vibrations. The vibrations may be HFTO and may be located, exhibited, or detected at the BHA. The BHA may include flexible components for facilitating sharp turns, and the vibrations may be (at least in part) due to or associated with the flexible components, as described herein. The HFTO may typically be a vibration of 40 Hz to 500 Hz, but the techniques described herein may be applied to any other vibrations.

[0068] Figure 7-1 Example vibration data 725-1 is shown. The vibration data 725-1 may correspond to vibrations in a drilling tool assembly that does not implement a damping device such as the (e.g., torsional) damping components described herein. The vibration data 725-1 may be a vibration measurement taken at or corresponding to a specific location in the drilling tool assembly. The vibration data 725-1 may exhibit one or more patterns or modes in the vibration. For example, a vibration pattern may correspond to an instance of vibration at or above a threshold frequency, an instance of vibration at or above a threshold amplitude, any other distinguishable feature in the vibration, and combinations thereof. In some cases, the vibration pattern may correspond to a natural and / or resonant frequency of one or more components of the drilling tool assembly (or the entire drilling tool assembly). For example, a pattern may indicate a more severe vibration (e.g., having a higher peak amplitude) at a frequency corresponding to a natural and / or resonant frequency. The natural frequency of one or more downhole components (or component combinations) may be based at least in part on or affected by mass, elasticity, material, length, or engagement with the formation of the component, or any other factor (and combinations thereof). Thus, one or more vibration modes may be determined and / or altered based on these characteristics.

[0069] The vibration data 725-1 may include a first pattern 726-1 and a second pattern 727-1. The first pattern 726-1 and the second pattern 727-1 may each correspond to a specific frequency or frequency range. The first pattern 726-1 and the second pattern 727-2 may correspond to the same frequency, or one pattern may correspond to a higher frequency than the other pattern. The first pattern 726-1 and the second pattern 727-1 may each represent one or more peaks or spikes in the vibration amplitude of a given frequency or frequency range. The amplitudes of the first pattern 726-1 and the second pattern 727-1 may be the same or different. In this way, the first pattern 726-1 and the second pattern 727-1 may each correspond to a vibration portion that is at or exceeds a threshold severity.

[0070] The amplitude of vibrations such as HFTOs may generally be non-uniform along the length of a downhole tool, BHA, or drilling tool assembly. For example, in some embodiments, the first mode 726-1 and / or the second mode 726-2 may indicate the longitudinal location of one or more increased or peak amplitudes of vibrations. In some embodiments, the modes and / or increased vibration amplitudes may exist at the midpoint, 1 / 4 point, 3 / 4 point, or any other point (and combinations thereof) of the downhole tool, BHA, or drilling tool assembly. In some embodiments, the vibration modes may exist at or near the flexible downhole component.

[0071] In some cases, the increased vibration amplitude may cause or indicate damage to one or more downhole components, reduced efficiency, increased fatigue, wear, etc. Therefore, it may be advantageous to reduce or eliminate these identified vibration modes. In some embodiments, one or more damping components may be positioned at or near the longitudinal position of the known or detected vibration mode. This may help reduce the vibration mode and / or may reduce one or more additional vibration modes at other locations. For example, the vibration mode at the midpoint may be associated with the maximum or peak amplitude. One or more damping components may be positioned accordingly to reduce the midpoint mode, and may also reduce one or more additional modes, such as the mode at the 1 / 4 point or 3 / 4 point. Similarly, positioning one or more damping components to reduce smaller vibration amplitudes, such as at the 1 / 4 point or 3 / 4 point, may reduce the amplitude at the relevant position, and may also reduce the amplitude at one or more additional positions, such as at the midpoint. As described above, in some embodiments, a vibration mode (e.g., at the midpoint, 1 / 4 point, 3 / 4 point, etc.) may exist at a flexible downhole component, such as the component described herein. Thus, including one or more damping components as part of a flexible downhole component may help reduce increased vibration amplitudes at the flexible downhole component and at other locations where increased and / or peak vibration amplitudes occur.

[0072] As described herein, one or more damping components (e.g., in combination with Figure 2 to Figure 6-2 The damping components described herein may be implemented in a downhole system to mitigate, reduce, counteract, adjust, or eliminate vibrations, such as HFTO. Figure 7-2 Example vibration data 725-2 is shown. The vibration data 725-2 may correspond to vibrations in a drilling tool assembly associated with implementing a (e.g., torsional) damping component as described herein. The vibration data 725-2 may be compared to the vibration data 725-1 to illustrate the damping effect of implementing a damping component. As described herein, the damping component implemented in conjunction with the vibration data 725-2 may be implemented as part of a flexible downhole component. The damping component may be included on an uphole portion or a downhole portion of the flexible downhole component in the flexible downhole component.

[0073] Similar to the vibration data 725-1, the vibration data 725-2 may include or present a first mode 726-2 and a second mode 727-2. The first mode 726-2 and the second mode 727-2 may correspond to distinguishable amplitudes or peaks in the vibration data 725-2 at a specific frequency or frequency range. In some embodiments, the first mode 726-2 and / or the second mode 727-2 each correspond to one or more natural or resonant frequencies of the drilling tool assembly and / or the BHA. In some embodiments, a single damping component (e.g., above or below the well relative to the flexible downhole component) may be configured to reduce the amplitude of one of the vibration modes. That is, the damping characteristics of the single damping component may be sized and arranged to target the reduction of the second mode 727-2. For example, as shown, the amplitude of the second mode 727-2 may be reduced to a considerable extent, or even substantially eliminated in some cases. The amplitude of the first mode 726-2 may not change to a great extent, or may remain unchanged in some cases. In some embodiments, a single damping component causes the frequency (or frequency range) of each of the first mode 726-2 and / or the second mode 727-2 to increase or decrease. This can be in addition to or in lieu of the amplitude reduction of the second mode 727-2. In this way, the implementation of a single damping component can help to change and / or mitigate one mode of HFTO, but another mode of HFTO may still exist to a large extent. In other words, the damping component associated with the vibration data 725-2 can have a damping profile for damping a mode (or a frequency) of HFTO. The damping profile can be selected and / or determined based on a specific mode. For example, the damping component can be constructed and positioned in a specific position to provide damping for a specific vibration mode. In this way, the adverse effects of HFTO may be partially mitigated only by implementing a single damping component.

[0074] Figure 7-3Example vibration data 725-3 is shown. The vibration data 725-3 may correspond to vibrations in a drilling tool assembly associated with implementing a (e.g., torsional) damping component as described herein. The vibration data 725-3 may be compared to the vibration data 725-1 to illustrate the damping effect of implementing a damping component. As described herein, the damping component implemented in conjunction with the vibration data 725-3 may be implemented as part of a flexible downhole component. The damping component may be included in the flexible downhole component on an uphole portion of the flexible downhole component or on a downhole portion of the flexible downhole component. In some embodiments, the damping component is included in conjunction with the flexible downhole component. Figure 7-2 The vibration data 725-2 describes the relative positions of the damping components.

[0075] Similar to the vibration data 725-1, the vibration data 725-3 may include or present a first mode 726-3 and a second mode 727-3. The first mode 726-3 and the second mode 727-3 may correspond to distinguishable amplitudes or peaks in the vibration data 725-3 at a specific frequency or frequency range. In some embodiments, the first mode 726-3 and / or the second mode 727-3 each correspond to one or more natural or resonant frequencies of the drilling tool assembly and / or the BHA. In some embodiments, a single damping component (e.g., above or below the well relative to the flexible downhole component) may be configured to reduce the amplitude of one of the vibration modes. That is, the damping characteristics of the single damping component may be sized and arranged to target the reduction of the first damping mode 726-3. For example, as shown, the amplitude of the first mode 726-3 may be reduced to a considerable extent, or even substantially eliminated in some cases. The amplitude of the second mode 727-3 may not change to a considerable extent, or may remain unchanged in some cases. In some embodiments, a single damping component causes the frequency (or frequency range) of each of the first mode 726-3 and / or the second mode 727-2 to increase or decrease. This can be a supplement or alternative to the amplitude reduction of the first mode 726-3. In this way, the implementation of a single damping component can help to change and / or mitigate one mode of HFTO, but another mode of HFTO may still exist to a large extent. In other words, the damping component associated with the vibration data 725-3 can have a damping distribution for damping a mode (or a frequency) of HFTO. The damping distribution can be selected and / or determined based on a specific mode. For example, the damping component can be constructed and positioned in a specific position to provide damping for a specific vibration mode. The damping component associated with the vibration data 725-3 can have the same damping distribution as the damping component associated with the vibration data 725-2, or it can be a different damping distribution. In this way, the adverse effects of HFTO may be partially mitigated only by implementing a single damping component.

[0076] Figure 7-4 Example vibration data 725-4 is shown. The vibration data 725-4 may correspond to vibrations in a drilling tool assembly associated with implementing two damping components as described herein. In other words, the vibration data 725-4 may be compared to the vibration data 725-1 to illustrate the damping effect of implementing the two damping components. As described herein, the two damping components implemented in conjunction with the vibration data 725-4 may be implemented as part of a flexible downhole component. As described herein, the damping components may be included in the flexible downhole component on both the uphole portion and the downhole portion of the flexible downhole component.

[0077] Similar to the vibration data 725-1, the vibration data 725-4 may include or present a first mode 726-4 and a second mode 727-4. The first mode 726-4 and the second mode 727-4 may correspond to distinguishable amplitudes or peaks in the vibration data 725-4 at a specific frequency or frequency range. In some embodiments, the first mode 726-4 and / or the second mode 727-4 each correspond to one or more natural or resonant frequencies of the drilling tool assembly and / or the BHA. In some embodiments, two damping components (e.g., both uphole and downhole relative to the flexible downhole component as described herein) may be configured to reduce the amplitude of the two vibration modes. That is, the damping characteristics of the two damping components may be sized and arranged to target the reduction of the first mode 726-4 and the second mode 727-4. For example, as shown, the amplitude of each of the first mode 726-4 and the second mode 727-4 may be reduced to a considerable extent, or even substantially eliminated in some cases. This reduction in amplitude can be contrasted with the vibration data 725-1 of the flexible downhole component that does not implement a damping component as described herein. In some embodiments, the two damping components cause the frequency (or range or frequency) of each of the first mode 726-4 and the second mode 727-4 to increase or decrease. This can be in addition to or in lieu of a reduction in amplitude of the first mode 726-4 and / or the second mode 727-4.

[0078] The reduction in amplitude of the first mode 726-4 can be within a range having an upper limit, a lower limit, or an upper and lower limit, including any one of 5%, 10%, 10%, 20%, 25%, 30%, 40%, 50%, 60%, 70%, 80%, 90%, 100%, or any value therebetween. For example, the amplitude of the first mode 726-4 can be reduced by less than 100%. In another example, the amplitude of the first mode 726-4 can be reduced by more than 5%. In yet another example, the amplitude of the first mode 726-4 can be reduced by between 5% and 100%. In some embodiments, it is critical to reduce the amplitude of the first mode 726-4 by at least 30% in order to significantly reduce the impact of HFTO on the downhole system, as described herein. In some embodiments, when considering the reduction of fatigue during the working life of the downhole tool, it may be beneficial to reduce the amplitude by as little as 10%.

[0079] The reduction in amplitude of the second mode 727-4 may be within a range having an upper limit, a lower limit, or both, including any one of 5%, 10%, 15%, 20%, 25%, 30%, 40%, 50%, 60%, 70%, 80%, 90%, 100%, or any value therebetween. For example, the amplitude of the second mode 727-4 may be reduced by less than 100%. In another example, the amplitude of the second mode 727-4 may be reduced by more than 5%. In yet another example, the amplitude of the second mode 727-4 may be reduced by between 5% and 100%. In some embodiments, it is critical to reduce the amplitude of the second mode 727-4 by at least 30% in order to mitigate the effects of HFTO on the downhole system, as described herein. In some embodiments, when considering the reduction of fatigue during the working life of the downhole tool, it may be beneficial to reduce the amplitude by as little as 10%.

[0080] like Figures 7-2 to 7-4As shown, each damping component may have a damping profile for damping vibrations of a specific mode (and / or frequency) (e.g., HFTO), but not necessarily two modes. As described herein, by implementing two damping components, the combined damping profile of each damping component can be targeted at two vibration modes, thereby helping to reduce the severity of the two modes of HFTO. In some embodiments, the two damping components damp one or more resonances and / or natural frequencies associated with each of the first mode 726-4 and / or the second mode 727-4. In some embodiments, the two damping components damp one or more increased amplitudes at locations other than the locations directly associated with the first mode 726-4 and / or the second mode 727-4. For example, the first mode 726-4 and the second mode 727-4 may exist at or near the flexible downhole component, and the damping component may be implemented at the flexible downhole component accordingly. In addition to damping the first mode 726-4 and the second mode 727-4 at the flexible downhole component, the damping component may damp one or more increased amplitudes at other locations of the downhole tool, BHA, or drilling tool assembly. In this manner, the adverse effects of HFTO on downhole systems may be more effectively and / or more completely mitigated.

[0081] Figure 8 A flow chart showing a method 800, or series of actions, for assembling a flexible downhole component as described herein, in accordance with at least one embodiment of the present disclosure. Figure 8 Actions according to one embodiment are shown, but alternative embodiments may omit, add, reorder, or modify Figure 8 Any action shown.

[0082] The method 800 may include an action 810 of connecting an upper damping component to a flexible body. The upper damping component may be connected at an uphole end of the flexible body. The upper damping component may be configured to mitigate a first mode HFTO of the flexible downhole component. The flexible body may include an upper connector for connecting the flexible downhole component to a first downhole tool. The upper damping component may be connected to the flexible body at the upper connector. The upper damping component may be connected to the flexible body by integrally forming the upper damping component with the flexible body. The flexible body may be configured to bend throughout the rotation of the flexible downhole component to facilitate sharp turns of the downhole tool connected to the flexible downhole component. In some embodiments, the upper damping component is connected to the flexible body without increasing the length of the BHA including the flexible downhole component.

[0083] The method 800 may include an action 820 of connecting a lower damping component to the flexible body. The lower damping component may be connected to the downhole end of the flexible body. The lower damping component may be configured to mitigate a second mode HFTO of the flexible downhole component. The flexible body may include a lower connector for connecting the flexible downhole component to a second downhole tool. The lower damping component may be connected to the flexible body at the lower connector. The lower damping component may be connected to the flexible body by integrally forming the lower damping component with the flexible body. In some embodiments, the lower damping component is connected to the flexible body without increasing the length of the BHA including the flexible downhole component.

[0084] Industrial Applicability

[0085] The present invention includes a number of practical application scraping features described herein that provide benefits and / or solve problems associated with damping vibrations, such as high frequency torsional oscillations (HFTO) in downhole systems. Some example benefits are discussed herein in conjunction with the various features and functions provided by the damping system. It should be understood that the benefits explicitly discussed in conjunction with one or more embodiments described herein are provided by way of example and are not intended to be exhaustive of all possible benefits of the damping systems, methods, and devices described herein, and further are not intended to limit the scope of the claims.

[0086] For example, as described herein, a downhole system may implement one or more rotating components. The rotation of these components may cause and / or result in vibration, oscillation, and / or periodic motion (e.g., HFTO) of one or more downhole components of the drilling system. In some embodiments, these vibrations may cause damage, wear, fatigue, or failure of one or more downhole components. In some embodiments, these vibrations may adversely affect the efficiency, production, or effectiveness of one or more downhole tools. The damping components described herein may be included, for example, as part of one or more downhole tools to reduce vibration. For example, the damping component may reduce, eliminate, or change the frequency, amplitude, or position of the vibration. Such vibration damping may help reduce or even eliminate the adverse effects of vibration on the downhole system. In this way, the damping component may help reduce damage, increase the life of the downhole system, and / or increase the effectiveness and / or productivity of the downhole system.

[0087] In addition to mitigating unwanted vibrations, the damping components described herein may do so in a manner that does not adversely affect the guidance and / or steering of one or more downhole components (e.g., a BHA). In many cases, a downhole system includes a flexible component (e.g., in a BHA) that can bend to facilitate guiding the BHA and the wellbore at an angle. The angle at which the BHA can be pointed, or the sharp turns that can be achieved, is directly affected by the overall length of the BHA. For example, a shorter BHA may achieve tighter sharp turns than a longer BHA. Therefore, in order to achieve the necessary guidance angle, it may be critical to ensure that the BHA remains within a threshold length. As described above, in some cases, the downhole system may experience vibrations, and damping components may be implemented to counteract these vibrations. In many cases, these vibrations may be related to (or may be most severe at) the flexible components. Therefore, it may be desirable to implement damping components at or in conjunction with the flexible components. The flexible downhole components described herein may include one or more damping components for damping HFTO, and may do so without increasing the length of the BHA beyond a threshold length. In some cases, the flexible downhole components may not increase the length of the BHA at all. In contrast, conventional or alternative approaches may implement damping components that result in a longer overall BHA than achieved when implementing the flexible downhole components described herein. In this manner, the flexible downhole components may provide (eg, torsional) damping to an attached BHA without negatively impacting the ability to steer the BHA.

[0088] In addition, downhole systems implement multiple downhole components that are typically connected end-to-end via tool connectors. These connectors represent a weak point in the downhole system because these connectors are typically more fragile and / or more susceptible to wear (e.g., leakage) than the downhole components themselves. The connectors also require assembly / disassembly, which is both time-consuming and expensive. Therefore, it may be advantageous to reduce the number of connectors in the downhole system where possible. In many cases, the flexible downhole components described herein may include and / or implement one or more damping components without any additional and / or unnecessary connectors. For example, the damping component may be integrated into and / or attached to the flexible downhole component (e.g., its body). This can be contrasted with, for example, connecting one or more damping components to one or more ends of the flexible downhole component and further connecting these damping components to other downhole tools. In this way, by reducing the number of connectors in the downhole system, the flexible downhole component can provide increased reliability and / or cost savings.

[0089] The following non-limiting examples illustrate various permutations contemplated herein.

[0090] A1. A flexible downhole component comprising:

[0091] an upper connector for connecting the flexible downhole component to the first downhole tool;

[0092] a lower connector for connecting the flexible downhole component to a second downhole tool;

[0093] A flexible body disposed between the upper connecting member and the lower connecting member;

[0094] an upper damping member configured to damp torsional oscillations; and

[0095] A lower damping component configured to damp torsional oscillations.

[0096] A2. The flexible downhole component according to A1, wherein the upper damping component is located at the upper connecting member, and the lower damping component is located at the lower connecting member.

[0097] A3. The flexible downhole component of A1 or A2, wherein the upper damping component and the lower damping component are each configured to damp high frequency torsional oscillations between 150 Hz and 300 Hz.

[0098] A4. A flexible downhole component according to any one of A1-A3, wherein the flexible body has a flexible body diameter, the upper connector has an upper connector diameter, the lower connector has a lower connector diameter, and wherein the flexible body diameter is smaller than the upper connector diameter and the lower connector diameter.

[0099] A5. A flexible downhole component according to any one of A1-A4, wherein the flexible body has a flexible body stiffness, the upper connector has an upper connector stiffness, the lower connector has a lower connector stiffness, and wherein the flexible body stiffness is less than the upper connector stiffness and the lower connector stiffness.

[0100] A6. A flexible downhole component according to any one of A1-A5, wherein the upper damping component includes an upper shell for accommodating one or more upper inertial damping elements, the lower damping component includes a lower shell for accommodating one or more lower inertial damping elements, and wherein the upper shell, the lower shell and the flexible body are formed integrally.

[0101] A7. A flexible downhole component according to any one of A1-A6, wherein the length of the downhole assembly including the flexible downhole component is no greater than 20 feet.

[0102] A8. The flexible downhole component according to any one of A1-A7, wherein the upper damping component has a first damping distribution corresponding to a first mode of high frequency torsional oscillation (HFTO), and the lower damping component has a second damping distribution corresponding to a second mode of HFTO.

[0103] A9. The flexible downhole component of A8, wherein the first mode of HFTO corresponds to a first resonant frequency of a downhole system implementing the flexible downhole component.

[0104] A10. The flexible downhole component of A8 or A9, wherein the second mode of HFTO corresponds to a second resonant frequency of a downhole system implementing the flexible downhole component.

[0105] A11. A flexible downhole component according to any one of A1-A10, wherein the upper damping component and the lower damping component each include an inertial element at least partially suspended in a fluid for damping torsional oscillations.

[0106] B1. A flexible downhole system comprising:

[0107] a flexible body; and

[0108] A first torsional damping component is integrally coupled to the flexible body, wherein the first torsional damping component includes an inertial damping element.

[0109] B2. The system of B1, comprising a second torsional damping component coupled to the flexible body opposite the first torsional damping component.

[0110] B3. A system according to B1 or B2, wherein:

[0111] A first torsional damping member is coupled to the uphole end of the flexible body and has a first damping profile for damping high frequency torsional oscillations (HFTO) of a first frequency of the flexible downhole system; and

[0112] The second torsional damping member is connected to the downhole end of the flexible body and has a second damping profile for damping HFTO of a second frequency of the flexible downhole system.

[0113] B4. A system according to B3, wherein the first frequency and the second frequency are the same.

[0114] B5. A system according to B3, wherein the first frequency is greater than the second frequency.

[0115] B6. A system according to B3, wherein the second frequency is greater than the first frequency.

[0116] B7. A system according to any one of B3-B6, wherein the first frequency corresponds to a first resonant frequency of the flexible downhole system.

[0117] B8. A system according to any one of B3-B7, wherein the second frequency corresponds to a second resonant frequency of the flexible downhole system.

[0118] B9. A system according to any one of B3-B8, wherein the first frequency is greater than the second frequency.

[0119] B10. A system according to any one of B3-B8, wherein the second frequency is greater than the first frequency.

[0120] B11. A system according to any of B3-B10, wherein the first torsional damping component damps the first frequency by at least 30%, and wherein the second torsional damping component damps the second frequency by at least 30%.

[0121] B12. A system according to any one of B3-B11, wherein the second torsional damping component is integrally bonded to the flexible body.

[0122] C1. A method for assembling a flexible downhole component, comprising:

[0123] connecting an upper damping member to the uphole end of the flexible body, the upper damping member being configured to mitigate a first mode of high frequency torsional oscillation (HFTO) of the flexible downhole member, and wherein the flexible body is configured to flex throughout rotation of the flexible downhole member to facilitate sharp turns of a downhole tool connected to the flexible downhole member; and

[0124] A lower damping member is coupled to the downhole end of the flexible body, the lower damping member being configured to mitigate a second mode of HFTO of the flexible downhole member.

[0125] C2. The method according to C1, wherein:

[0126] The flexible body includes an upper connector for connecting the flexible downhole member to the first downhole tool, and connecting the upper damping member includes connecting the upper damping member at the upper connector; and

[0127] The flexible body includes a lower connector for connecting the flexible downhole member to the second downhole tool, and connecting the lower damping member includes connecting the lower damping member at the lower connector.

[0128] C3. The method according to C1 or C2, further comprising connecting the upper damping member and the lower damping member without increasing the length of the bottom hole assembly including the flexible downhole member.

[0129] C4. The method according to any one of C1-C3, wherein connecting the upper damping component comprises forming the upper damping component integrally with the flexible body, and connecting the lower damping component comprises forming the lower damping component integrally with the flexible body.

[0130] Embodiments of flexible downhole components have been described primarily with reference to wellbore drilling operations. The flexible downhole components described herein may be used in applications other than drilling a wellbore. In other embodiments, flexible downhole components according to the present disclosure may be used outside of a wellbore or other downhole environment for natural resource exploration or production. For example, the flexible downhole components of the present disclosure may be used in a borehole for placement of a utility line. Therefore, the terms "wellbore," "borehole," and the like should not be construed to limit the tools, systems, assemblies, or methods of the present disclosure to any particular industry, field, or environment.

[0131] One or more specific embodiments of the present disclosure are described herein. These described embodiments are examples of the currently disclosed technology. In addition, in order to provide a concise description of these embodiments, all features of the actual embodiments may not be described in the specification. It should be understood that in the development of any such actual implementation, as in any engineering or design project, many implementation-specific decisions will be made to achieve the developer's specific goals, such as meeting system-related and business-related constraints, which may vary from embodiment to embodiment. In addition, it should be understood that such development efforts may be complex and time-consuming, but for ordinary technicians who benefit from the present disclosure, this is still a routine task of design, production and manufacturing.

[0132] In addition, it should be understood that reference to "one embodiment" or "an embodiment" of the present disclosure is not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the features. For example, any element described with respect to an embodiment here can be combined with any element of any other embodiment described here. The numbers, percentages, ratios, or other values ​​described herein are intended to include the value, as well as other values ​​of "approximately" or "approximately" the value, as understood by those of ordinary skill in the art covered by the embodiments of the present disclosure. Therefore, the value should be interpreted as being broad enough to include values ​​that are at least close enough to the value to perform the desired function or achieve the desired result. The value includes at least the expected changes in a suitable manufacturing or production process, and may include values ​​within 5%, within 1%, within 0.1%, or within 0.01% of the value.

[0133] In view of this disclosure, those of ordinary skill in the art should recognize that equivalent constructions do not depart from the spirit and scope of the disclosure, and that various changes, substitutions, and modifications may be made to the embodiments disclosed herein without departing from the spirit and scope of the disclosure. Equivalent structures, including functional "means plus function" clauses, are intended to cover structures described herein that perform the functions described, including structural equivalents that operate in the same manner and equivalent structures that provide the same functions. It is the express intent of the applicant not to invoke means plus function or other functional claims for any claim, except for those claims in which the words "means for..." appear together with the associated function. Every addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims will be encompassed by the claims.

[0134] As used herein, the terms "approximately," "about," and "substantially" refer to an amount that is close to a stated amount, is within standard manufacturing or process tolerances, or still performs a desired function or achieves a desired result. For example, the terms "approximately," "about," and "substantially" may refer to an amount that is less than 5%, less than 1%, less than 0.1%, and less than 0.01% of a stated amount. Furthermore, it should be understood that any directions or reference frames in the foregoing description are merely relative directions or motions. For example, any references to "up" and "down," or "above," or "below," are merely descriptions of the relative positions or motions of the associated elements.

[0135] Various features are described herein in alternative forms in order to emphasize that these features can be combined in any number of combinations. Each feature should be considered to be combinable with other features unless these features are mutually exclusive. The term "or" used herein is not exclusive unless the contrary meaning is clearly expressed. For example, having A or B includes A alone, B alone, or a combination of A and B. Conversely, having only A or B includes A alone or B alone, but not a combination of A or B. Even if not explicitly stated in multiple independent forms, the specification provides support for the combination of each claim with each other claim (or any combination of other claims).

[0136] Without departing from the spirit or features of the present disclosure, the present disclosure may be implemented in other specific forms. The described embodiments are considered to be illustrative rather than restrictive. Therefore, the scope of the present disclosure is indicated by the appended claims rather than the preceding description. Changes within the meaning and scope of the equivalents of the claims will be included within their scope.

Claims

1. A flexible downhole component, comprising: an upper connector for connecting the flexible downhole component to the first downhole tool; a lower connector for connecting the flexible downhole component to a second downhole tool; A flexible body, the flexible body being arranged between the upper connecting member and the lower connecting member; an upper damping member configured to damp torsional oscillations; and A lower damping component is configured to damp torsional oscillations. 2 . The flexible downhole component according to claim 1 , wherein the upper damping component is located at the upper connecting member, and the lower damping component is located at the lower connecting member.

3. The flexible downhole member of claim 1, wherein the upper damping member and the lower damping member are each configured to damp high frequency torsional oscillations between 150 Hz and 300 Hz.

4. The flexible downhole component of claim 1, wherein the flexible body has a flexible body diameter, the upper connector has an upper connector diameter, the lower connector has a lower connector diameter, and wherein the flexible body diameter is smaller than the upper connector diameter and the lower connector diameter.

5. The flexible downhole component according to claim 1, wherein the flexible body has a flexible body stiffness, the upper connector has an upper connector stiffness, the lower connector has a lower connector stiffness, and wherein the flexible body stiffness is less than the upper connector stiffness and the lower connector stiffness.

6. The flexible downhole component according to claim 1, wherein the upper damping component comprises an upper shell for accommodating one or more upper inertial damping elements, the lower damping component comprises a lower shell for accommodating one or more lower inertial damping elements, and wherein the upper shell, the lower shell and the flexible body are formed integrally.

7. The flexible downhole component of claim 1, wherein the length of the downhole component including the flexible downhole component is no greater than 20 feet.

8. The flexible downhole member of claim 1, wherein the upper damping member has a first damping profile corresponding to a first mode of high frequency torsional oscillation (HFTO), and the lower damping member has a second damping profile corresponding to a second mode of HFTO.

9. The flexible downhole member of claim 1, wherein the upper damping member and the lower damping member each include an inertial element at least partially suspended in a fluid for damping torsional oscillations.

10. A flexible downhole system comprising: a flexible body; and A first torsional damping component is integrally coupled to the flexible body, wherein the first torsional damping component includes a viscous inertial damping element.

11. The system of claim 10, comprising a second torsional damping component coupled to the flexible body opposite the first torsional damping component.

12. The system of claim 11, wherein: A first torsional damping member is connected to the uphole end of the flexible body and has a first damping profile for damping high frequency torsional oscillations (HFTO) of a first frequency of the flexible downhole system; and The second torsional damping member is connected to the downhole end of the flexible body and has a second damping profile for damping HFTO at a second frequency of the flexible downhole system.

13. The system of claim 12, wherein the first frequency and the second frequency are the same. The system of claim 12 , wherein the first frequency is greater than the second frequency.

15. The system of claim 12, wherein the first torsional damping component damps the first frequency by at least 30%, and wherein the second torsional damping component damps the second frequency by at least 30%.

16. The system of claim 10, wherein a second torsional damping component is integrally bonded to the flexible body.

17. A method of assembling a flexible downhole component, comprising: connecting an upper damping member to the uphole end of the flexible body, the upper damping member being configured to mitigate a first mode of high frequency torsional oscillation (HFTO) of the flexible downhole member, and wherein the flexible body is configured to flex throughout rotation of the flexible downhole member to facilitate sharp turns of a downhole tool connected to the flexible downhole member; and A lower damping member is coupled to the downhole end of the flexible body, the lower damping member being configured to mitigate a second mode of HFTO of the flexible downhole member.

18. The method of claim 17, wherein: The flexible body includes an upper connector for connecting the flexible downhole member to the first downhole tool, and connecting the upper damping member includes connecting the upper damping member at the upper connector; and The flexible body includes a lower connector for connecting the flexible downhole component to a second downhole tool, and connecting the lower damping component includes connecting the lower damping component at the lower connector.

19. The method of claim 17, further comprising connecting the upper damping member and the lower damping member without increasing the length of a bottom hole assembly including the flexible downhole member.

20. The method of claim 17, wherein connecting the upper damping component comprises integrally forming the upper damping component with the flexible body, and connecting the lower damping component comprises integrally forming the lower damping component with the flexible body.

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