Orientation of high-sided energy transfer mechanism connections in a well.

Abstract

Provided is a well system and a method. The well system, in one aspect, includes a wellbore extending through one or more subterranean formations, and a tubular located within the wellbore. The well system, according to one aspect, further includes an energy transfer mechanism coupled to the tubular, wherein the energy transfer mechanism is located above 3 o'clock or above 9 o'clock relative to gravity.

Description

1 / 33 Orientation of high-sided energy transfer mechanism connections in a well. CROSS-REFERENCE ON RELATED REQUEST

[0001] This application claims priority over U.S. Serial No. 18 / 604,605, filed March 14, 2024, entitled “ORIENTING ENERGY TRANSFER MECHANISM CONNECTIONS HIGH SIDE IN A WELL”, which claims the benefit of U.S. Provisional Application Serial No. 63 / 490,294, filed March 15, 2023, entitled “ORIENTING WET MATE CONNECTIONS HIGH SIDE IN A WELL” and U.S. Provisional Application Serial No. 63 / 490,281, filed March 15, 2023, entitled “COMPLETION AND PRODUCTION MONITORING AND CONTROL VIA A SINGLE DOWNHOLE WET-MATE (EG., FIBER OPTIC WET-MATE), METHODS, SYSTEMS, AND DEVICES FOR RECORDING DOWNHOLE COMPLETION-ACTIVITY (E.G., FRAC-PACKING) WITH THE ABILITY TO SWITCH TO LONG-TERM PRODUCTION DATA GATHERING AND TRANSMISSION TO SURFACE”, all of which are commonly assigned with this application and incorporated by reference in their entirety. BACKGROUND

[0002] A variety of well operations require selective access to specific areas of the wellbore. One such selective well operation is horizontal multi-stage hydraulic stimulation, as well as multi-stage hydraulic fracturing (frac or fracturing). In multi-lateral wells, multi-stage stimulation treatments are performed within multiple lateral wellbores. Efficient access to all lateral wellbores is critical to completing a successful pressure stimulation treatment, as is selectively entering the multiple lateral wellbores with other downhole devices. BRIEF DESCRIPTION

[0003] Reference is now made to the following descriptions taken together with the attached drawings, in which: Petition 870250068013, dated 04 / 08 / 2025, page 33 / 123 2 / 33

[0004] FIGS. 1 to 23 illustrate several different forms of disclosure, many of which are related to the positioning of an upper wet mate;

[0005] FIG. 24 illustrates a well system designed, manufactured and operated in accordance with one or more embodiments of the disclosure;

[0006] FIG. 25 illustrates an embodiment of a multilateral joint designed, manufactured and / or operated in accordance with one or more embodiments of the disclosure;

[0007] FIGS. 26A to 261 illustrate several different views of a slotted orientation apparatus designed, manufactured and operated according to one or more embodiments of the disclosure;

[0008] FIGS. 27A to 27D illustrate several different views of a slotted orientation apparatus designed, manufactured and operated according to one or more alternative embodiments of the disclosure;

[0009] FIGS. 28A to 28D illustrate different views of a keyway tool designed, manufactured and operated according to one or more embodiments of the disclosure; and

[0010] FIGS. 29A to 29F illustrate one embodiment for aligning a downhole tool in accordance with the disclosure. DETAILED DESCRIPTION

[0011] In the following drawings and descriptions, similar parts are typically marked throughout the descriptive report and in the drawings with the same reference numerals, respectively. The figures drawn are not necessarily to scale. Certain features of the disclosure may be shown exaggerated to scale or in some schematic way, and some details of certain elements may not be shown in the interest of clarity and conciseness. This disclosure may be implemented in different forms.

[0012] Specific modalities are described in detail and shown in the drawings, with the understanding that the present disclosure shall be considered an exemplification of the principles of disclosure and is not intended to limit disclosure to that illustrated and described in this document. It shall be fully acknowledged that the different teachings of the modalities discussed in this document may be employed separately or in any suitable combination to produce desired results. Petition 870250068013, dated 04 / 08 / 2025, page 34 / 123 3 / 33

[0013] Unless otherwise specified, the use of the terms connect, engage, couple, fix, or any other similar term describing an interaction between elements is not intended to limit the interaction to direct interaction between the elements, and may also include indirect interaction between the elements described.

[0014] Unless otherwise specified, the use of the terms “above,” “upper,” “upward,” “hole above,” “upstream,” or other similar terms shall be interpreted as generally away from the lower terminal end of a well, regardless of the orientation of the wellbore; similarly, the use of the terms “below,” “lower,” “downstream,” “bottom of the well,” “downstream,” or other similar terms shall be interpreted as generally towards the lower terminal end of a well, regardless of the orientation of the wellbore. The use of any one or more of the foregoing terms shall not be interpreted as denoting positions along a perfectly vertical axis. Unless otherwise specified, the use of the expression subsurface formation shall be interpreted as encompassing both exposed belowground areas and belowground areas covered by water, such as ocean or freshwater.

[0015] To broaden the scope of this announcement, the following phrases will be used: • Energy Transfer Mechanism (ETM) - a device for transferring energy. In some embodiments, the device may comprise a coupling, a wet mate coupling, an inductive coupling, a capacitive coupling, a fluidic coupling, an electrical coupling, a mechanical coupling, a wireless coupling, a combination of more than one type of coupling - of those listed above and / or others not listed, other couplings, other devices, etc. In some embodiments, an ETM may comprise a transformer where one type of energy is converted into another type of energy (e.g., an electrical solenoid where electricity is converted into mechanical energy). • First Equipment Section - in one or more embodiments, the first equipment section comprises a lower completion string (which may include a sand control string, a liner, screens, a flow control device, a packer, an anchor, a shoe, a sensor, a control line (electrical, hydraulic, fiber optic, a combination of one or more, including a pipe-encapsulated conductor (TEC) or Petition 870250068013, dated 04 / 08 / 2025, page 35 / 123 4 / 33 metal tube (e.g., pure stainless steel), etc.), one or more ETMs for engaging / connecting / communicating with another coupling, one or more ETMs associated with the second equipment section and / or third equipment section and / or other tools or devices, a guidance device for guiding a third equipment section (or parts thereof) or other tools or devices, one or more Dry Mates, one or more Wet Mates, a tool face or other feature to indicate the high side (12 o'clock position) of the first equipment section or one or more components of the first equipment section, one or more communication devices to transmit, receive or both (e.g., transceiver) one or more signals from / to below and / or to / from above the communication device, etc. • Second Equipment Section - In some embodiments, the second equipment section comprises a working string (also known as a service string, fracturing string, setup string, stimulation string, etc.). In some embodiments, the second equipment section is used to transport the first equipment section into a wellbore. The second equipment section may have other uses, such as pumping fluid(s) to the first equipment section for stimulation (and / or other purposes). In this disclosure, the second equipment section may also comprise a guidance device and / or a communication device. • Orientation Device - The orientation device, shown in FIG. 3 and FIG. 5, will determine the orientation of the device relative to gravity. The orientation device may comprise a “tool face” – a face, mark, reference point whose angle can be calculated / measured relative to the orientation of the wet mate connection of the first section of the equipment. Knowing the orientation (angle) of the “tool face” relative to gravity, the second section of the equipment (e.g., work string) can be rotated so that a known feature (e.g., wet mate connection of the first section of the equipment) can be positioned on the high side (e.g., less than ±45 degrees, less than ±30 degrees, less than ±20 degrees, less than ±10 degrees, less than ±5 degrees, less than ±1 degree) in the wellbore. In at least one embodiment, it is desired that the wet mate connection of the first section of the equipment be Petition 870250068013, dated 04 / 08 / 2025, page 36 / 123 5 / 33 oriented towards the high side. Furthermore, on the surface, before operating the tools, it is desirable to know the orientation of the tool face of the second orientation device of the equipment section relative to the orientation of the wet mate connection of the first equipment section. Thus, when at the bottom, the work column can be rotated to orient the wet mate connection of the first equipment section towards the high side. • Communication Device - The communication device, also shown in FIG. 3 and FIG. 5, will transfer data to / from the first and / or second section of the equipment (e.g., completion string and / or work string) to the surface. In some embodiments (e.g., when used with the work string), orientation data (orientation of the “tool face” and / or the first ETM (also known as the first fiber optic coupler (bottom) / wet mate)) is used to ensure that the first ETM is aligned with the high side of the wellbore to ensure that debris moves away from the first ETM by gravity. • Wet Mate - a connection that is capable of, but not necessarily, being made in a wet environment and still maintaining a good, reliable, and sealed connection. A wet mate can also be made in a dry environment (e.g., hole-up). • Dry Mate - a connection that must be made in a dry environment (e.g., either above or at the bottom of a well) and still maintain a good, reliable, and sealed connection. • Third Equipment Section – In some embodiments, a third equipment section comprises a completion string (also known as a production string, top completion string, intermediate completion string, etc.). In some embodiments, the third equipment section is used to provide a conduit for fluids from the first equipment section to a hole location above or over the first equipment section (e.g., surface, subsea tree, etc.). The third equipment section may have other uses, such as, for example, carrying tools to the first equipment section, or other sections, for various reasons, such as production evaluation, cleanup operations, and / or other purposes. In this disclosure, the third equipment section may also comprise a guidance device and / or a communication device, such as those described herein, or other types of guidance devices and / or communication devices.For example, the third. Petition 870250068013, dated 04 / 08 / 2025, p. 37 / 123 Section 6 / 33 of the equipment may comprise an orientation sensor and / or device for monitoring the orientation of the third section of equipment (or one or more of its components) while it is being deployed in a well.The third equipment section may comprise one or more ETMs for engaging / connecting / communicating with another coupling of one or more ETMs associated with the second equipment section and / or third equipment section and / or other tools or devices, a guidance device for guiding a third equipment section (or parts thereof), or other tools or devices, one or more Dry Mates, one or more Wet Mates, a tool face or other feature for indicating the high side (12 o'clock position) of the third equipment section (or of one or more components of the first or third equipment section), one or more communication devices for transmitting, receiving or both (e.g., transceiver) one or more signals from / to below and / or to / from above the communication device.

[0016] This disclosure acknowledges that there are certain instances, particularly during production, completion, stimulation and / or fracturing operations, where it may be desirable to employ an energy transfer mechanism (e.g., wet mate connection) in a wellbore (e.g., wet environment). This disclosure, based on that acknowledgment, recognizes that debris, such as fracturing sand in one embodiment, may substantially impede the energy transfer mechanism (e.g., wet mate connection) from achieving a good, reliable and sealed connection.With this in mind, the present disclosure has designed, in one embodiment, an apparatus with the placement of the ETM (e.g., wet mate connection) on a high side of the tubular (e.g., so that the ETM is located above 3 o'clock or above 9 o'clock relative to gravity (e.g., gravity being located at 6 o'clock), above 2 o'clock or above 10 o'clock relative to gravity (e.g., gravity being located at 6 o'clock), above 1 o'clock or above 11 o'clock relative to gravity (e.g., gravity being located at 6 o'clock), etc.), which greatly reduces this problem. In another embodiment, the ETM has a first coupling surface configured to couple with a second opposite coupling surface of a second ETM, and further, the first coupling surface is located above 3 o'clock or above 9 o'clock relative to gravity (e.g., gravity being located at 6 o'clock), above 2 o'clock. Petition 870250068013, dated 04 / 08 / 2025, p. 38 / 123 7 / 33 or above 10 hours relative to gravity (e.g., gravity being located at 6 o'clock), above 1 hour or above 11 hours relative to gravity (e.g., gravity being located at 6 o'clock), etc. In at least one other modality, all portions of the ETM are located above 3 hours or above 9 hours relative to gravity (e.g., gravity being located at 6 o'clock), above 2 hours or above 10 hours relative to gravity (e.g., gravity being located at 6 o'clock), above 1 hour or above 11 hours relative to gravity (e.g., gravity being located at 6 o'clock), etc.The reverse can also be true, where no portion of the ETM is located below 3 o'clock or below 9 o'clock relative to gravity (e.g., gravity is located at 6 o'clock), below 2 o'clock or below 10 o'clock relative to gravity (e.g., gravity is located at 6 o'clock), below 1 o'clock or below 11 o'clock relative to gravity (e.g., gravity is located at 6 o'clock), etc.

[0017] According to at least one embodiment, a guidance tool, as discussed in detail below, may be coupled to a slotted guidance device, the guidance tool being configured to guide the energy transfer mechanism (e.g., wet mate connection) and the slot of the slotted guidance device within the wellbore (e.g., on the high side of the tubular). In another embodiment, the guidance tool is a measurement-drilling (MWD) tool that uses pressure pulses to guide the energy transfer mechanism (e.g., wet mate connection) and the slot of the slotted guidance device within the wellbore.

[0018] One or more projects intend to implement a power transfer mechanism (e.g., a fiber optic wet mate connection at the bottom of the well) to monitor sensors at the bottom of the well. Coupling power transfer mechanisms (e.g., wet mate connections) in a downhole environment is a risky process. The process can worsen if the power transfer mechanisms (e.g., wet mate connections) are oriented towards the bottom side of the wellbore, where debris, sediment, supporting agents, etc., can accumulate and prevent wet mate connection coupling. The solution is to orient the power transfer mechanisms (e.g., wet mate connections) towards the top side of the wellbore (e.g., depending on the project, so that no part of the power transfer mechanism (e.g., wet mate connection) is located below the 3 o'clock position or Petition 870250068013, dated 04 / 08 / 2025, page 39 / 123 8 / 33 below 9 o'clock relative to gravity, below 2 o'clock or below 10 o'clock relative to gravity, below 1 o'clock or below 11 o'clock relative to gravity, etc.) so that debris, sediment, supporting agents, etc. settle on the downside of the wellbore, away from the couplers. This will prevent debris from interfering with the coupling and uncoupling of the power transfer mechanism (e.g., wet mate connection).

[0019] A tool that determines tool orientation and communicates orientation information to the surface is Halliburton's Work String Orientation Tool (WOT). The WOT incorporates mud pulse telemetry technology to relay "tool face" information to the surface. This information allows drillers to rotate the work string until the correct "tool face" orientation is achieved. In most embodiments, the "tool face" of the WOT (or similar orientation device) is measured relative to the orientation of the first ETM (also known as the first fiber optic coupler (bottom) / wet mate) that is attached to the first section of the equipment (bottom completion string). This allows the driller (and others) on the rig floor to know the orientation of the first ETM so that it can be oriented to the high side.The high side is typically defined as 180 degrees relative to the low side – the direction of Earth's gravitational vector. The high side can be defined by an orientation range such as + / -90 degrees high side, + / -60 degrees high side, + / -45 degrees high side, + / -30 degrees high side, + / -20 degrees high side, + / -15 degrees high side, + / -10 degrees high side, whether symmetrical or asymmetrical, etc.

[0020] In some embodiments, the high side (or high side range) may be related to the angle of repose, as shown in FIG. 1. The angle of repose is the angle at which a material on the slope face is about to slide. By keeping the orientation of the first ETM greater than the angle of repose of the debris in the well, it can be ensured that the debris will slide out of the sides (features) of the ETM coupling, or even slide out of the features of other devices associated with the well (e.g., previously installed and / or to be installed later) and / or associated with well operations (e.g., stimulation tools, cleaning tools, etc.) in certain embodiments, thus not interfering with the coupling / uncoupling / engagement / alignment of the ETM(s).

[0021] Returning to TABLE 1, the angles of repose of some materials that can be classified as debris in a well are illustrated. Petition 870250068013, dated 04 / 08 / 2025, page 40 / 123 9 / 33

[0022] Returning to FIG. 2, one embodiment of the dissemination is illustrated. In at least one embodiment, an apparatus is provided that can be used with a well and includes a first section of equipment comprising a first oriented ETM and a second section of equipment. The second section of equipment can be adapted to be run on the wellbore, removablely attached to the first section of equipment. A mechanism (orientation device) of the apparatus indicates when the first oriented ETM is substantially oriented in opposition to the Earth's gravitational field by at least 90, 60, 45, 30, 20, 15, 10 degrees. In at least one other embodiment, the apparatus comprises a mechanism for relaying information from the apparatus to the surface (or other remote location) (reference communication device(s) in FIG. 2).The information includes at least the orientation of the first oriented ETM or similarly oriented mechanism / component (e.g., WOT's gravimeter or other similar device).

[0023] In at least one other embodiment, the apparatus comprises a second ETM, for example, coupled to the first ETM. In this embodiment, the second ETM can be coupled to the first ETM when the first and second sections are coupled together, for example, being run in the borehole. Thus, the first ETM and the second ETM could be substantially oriented opposite to the Earth's gravitational field by at least 90, 60, 45, 30, 20, 15, 10 degrees, as discussed above.

[0024] In at least one other embodiment, the apparatus may have a first equipment section that includes a first oriented ETM and a third equipment section that includes a third ETM. The third equipment section may be adapted to run downhole after the first equipment section has been positioned and oriented downhole and, in one embodiment, after the second equipment section and the second ETM have disconnected from the first ETM. A mechanism of the apparatus may propel the third ETM to the same orientation as the first oriented ETM. The first oriented ETM may be substantially oriented opposite to the Earth's gravitational field, as discussed above.

[0025] In at least one embodiment, the device includes a mechanism to encourage rotational alignment of the third ETM with the first oriented ETM. For example, the device may include a mechanism to encourage axial alignment of the third ETM with the first Petition 870250068013, dated 04 / 08 / 2025, page 41 / 123 10 / 33 The apparatus may include a mechanism to encourage the releasable locking of the third ETM with the first oriented ETM, or include a mechanism to encourage the gradual engagement (shock / spring device) of the third ETM with the first oriented ETM. In at least one other embodiment, the apparatus may include a mechanism to encourage the gradual engagement (shock / spring device) of the third ETM with the first oriented ETM, or it may include a mechanism to exclude debris, clean coupling components before engagement, inject a fluid to clean the coupling components before engagement, sliding sleeves (or similar components) to protect one or more surfaces / seals / components. In at least one other embodiment, the apparatus may perform fiber applications for electric submersible pumps (ESP).

[0026] The ability to detect one or more parameters related to a tool (e.g., orientation of a tool feature, temperature, etc.) and / or the operation (fluid pumping, etc.) being performed, then relay information such as the orientation of a tool to a remote location (e.g., surface) and then adjust a tool feature (e.g., orientation) under adverse conditions (dirty environment (solids, contaminated fluids such as drilling mud or completion fluid), extreme pressures (e.g., differential >20,000 psi), extreme temperatures (e.g., < -20 F to > 300 F), makes this disclosure suitable for use in adverse environments such as outer space (e.g., satellites, spacecraft, etc.), aeronautics (aircraft), on land (swamps, bogs, etc.), below ground (mines, caves, etc.).), ocean (surface and underwater), underground (mineral extraction, storage wells (carbon sequestration, carbon capture and storage (CCS), etc.) and other energy recovery activities (geothermal, steam, etc.).

[0027] Certain commercial competitive advantages of this disclosure include: 1) reliably connecting fiber optic couplers (and / or other Wet Mates) without the risk of debris, sediment, supporting agents, etc. interfering with the process; 2) providing customers with the assurance of a risk-free sand compaction completion system; 3) outperforming the competition; 4) applying to various deepwater projects (e.g., projects in Guyana); 5) applying to carbon capture, utilization and storage (CCUS) markets.

[0028] One proposed solution is a device 300, for example, using a guidance device 310 to guide a first ETM 320 to the high side of the wellbore 390, as shown in FIG. 3. The first ETM 320, as illustrated in FIG. 3, can be installed in the first section of equipment 330 (e.g., bottom completion, control string of Petition 870250068013, dated 04 / 08 / 2025, page 42 / 123 11 / 33 sand, etc.) and oriented towards the high side of wellbore 390, as shown. This provides the advantage that debris will fall off the first ETM 320 during subsequent operations (e.g., fracturing compaction, sand compaction, production, etc.). Similarly, debris will not interfere with the coupling / uncoupling of the first ETM 320, for example, uncoupling the first ETM with a second ETM, or the subsequent coupling of the first ETM 320 with a third ETM.

[0029] In some embodiments, a second ETM 340 forming part of a second equipment section 350 may be coupled to the first ETM 320 while the first equipment section 330 (e.g., bottom completion, sand control string, etc.) is being lowered into the well (see FIG. 3) and during the execution of other operations (such as fracturing compaction) at the bottom of the well. As shown in FIG. 3, the orientation of the first ETM 320 is known relative to the orientation of the orientation device 310 (e.g., WOT tool face) before operating the equipment in the well. The orientation device 360 ​​may transmit its orientation (and / or the orientation of the first ETM 320) to the surface via one or more communication devices. Transmission may occur continuously during equipment operation in the well, intermittently, or only when the equipment is near the bottom of the well or at the desired depth.

[0030] In at least one embodiment, the guidance device 310 may be two or more devices, for example; 1) a sensor device for detecting orientation; and 2) a communication device 315 for transmitting information (for example, to / from the guidance sensor(s) and / or other sensors / devices). The communication device 315 may comprise one or more components and / or devices for communicating information to / from the surface or other location.

[0031] If it is desirable to monitor the orientation continuously during the operation of the equipment in well 390, wired tubing or other technology for continuously transmitting signals to the surface may be employed. If the orientation needs to be known less frequently, other communication devices / protocols may be considered. For example, mud pulse telemetry, acoustic signals, and a combination of both may be employed. One or more other methods / systems may be used to transfer “energy” signals from the orientation device 310, the communication device 315, the first ETM 320, the second ETM 340 Petition 870250068013, dated 04 / 08 / 2025, page 43 / 123 12 / 33 and / or other devices. Note that other signals (power signals, communication signals, sensor readings, data, etc.) can also be transmitted via one or more 320, 340, etc. oriented ETMs. Furthermore, one or more 360 ​​sensors can be associated and / or coupled to the first equipment section, so that the first 320 ETM can be used to assist in transmitting information obtained from one or more 360 ​​sensors above.

[0032] In other embodiments, a third ETM 420 may be coupled to the first ETM 320, as shown in FIG. 4. In some of these embodiments, the third ETM 420 may be run with a third equipment section 430, as shown in FIG. 4. The third ETM 420 may engage with the first ETM 320 before / during / after the third equipment section 430 engages with the first equipment section 330.

[0033] In certain embodiments, the first ETM 320 is maintained in a high-side orientation due to the weight of the first equipment section 330, anchors, packers, materials placed between the outer surface of the first equipment section 330 and the wellbore (or partial sections thereof) (e.g., proppant, cement, fracturing compaction), etc. In some embodiments, the first equipment section 330 has one or more devices 510 to propel the third ETM 420 to the same orientation as the first ETM 320, as shown in FIG. 5. In the embodiment illustrated in FIG. 5, the third equipment section 430 includes the third ETM 420, one or more devices 510, as well as a communication device 520 (e.g., control line, whether a fiber optic line, an electrical line, a hydraulic line, a combination thereof, etc.). Some of these devices can be described as a shell assembly (e.g., FIG.6), a horseshoe assembly (FIGs. 7 and 8) and a guide groove assembly (FIG. 9), a bishop's hat, a propeller, etc.

[0034] In some embodiments, the first equipment section may have one or more devices for releasable anchoring, fixed anchoring, and / or positioning the second ETM or the third ETM to the first ETM. In some embodiments, the first equipment section, the second equipment section, and / or the third equipment section may comprise one or more devices. In some embodiments, the first equipment section may have one or more devices for attenuating or dampening the landing and / or engagement of the second ETM and / or the third ETM to the first ETM. Two such examples are shown in FIGS. 10 and 11. Similarly, the second equipment section and / or the third equipment section may have Petition 870250068013, dated 04 / 08 / 2025, p. 44 / 123 13 / 33 one or more devices to attenuate or dampen or improve engagement, coupling, uncoupling, etc. events.

[0035] In some alternative embodiments, a second ETM is installed in the second equipment section and a communication device 315 is employed, as shown in FIG. 3. Consequently, signals can be transmitted to the surface (and back from the surface) during hole movement, during orientation, during packer setup, during sand compaction, during the stimulation process, etc. In FIG. 3, the second ETM 340 is coupled to the first ETM 320 while the first equipment section (e.g., bottom completion, sand control string, etc.) is being run in the hole, as well as while other operations (such as fracture compaction) are being conducted.

[0036] Returning to FIG. 12, an embodiment is illustrated in which one or more communication devices, methods, etc. and / or ETM devices, methods, etc. for transferring energy (data, signals, energy and / or other things) to or from other locations (e.g., including but not limited to the surface, etc.) are shown. In some embodiments, the communication device may be a fiber optic line, a fiber optic line shielded in a control line, a fiber optic line connected to a tubular column (drill pipe, pipe string, work column, etc.), etc. In some embodiments, the communication device may be an electrical line. In some embodiments, the communication device may be a combination of power conduits. Other embodiments may include sound, optics, pressure pulses, other energies or combinations thereof, etc.Consequently, unless otherwise required, this disclosure should not be limited to any specific energies.

[0037] In some alternative embodiments, the first section of equipment (e.g., bottom completion string) (e.g., examples are shown in FIGS. 3 and 13) may include sand screens, fracturing compaction screens, expandable screens, oriented screens, a base pipe, inlet control valves (e.g., ICVs), inlet control devices (e.g., ICDs), autonomous inlet control devices (e.g., AICDs), electric inlet control devices (elCDs), casing, liner, drilled pipe, etc.). As shown in FIG. 13, the first ETM may be a downhole wet mate that is connected to a control line that includes (e.g., consisting of one or more Petition 870250068013, dated 04 / 08 / 2025, page 45 / 123 14 / 33 power transfer lines) a fiber optic cable, a power line, a water line and / or other type of power transfer line.

[0038] In some alternative embodiments, the first energy transfer mechanism may consist of more than one type of energy transfer mechanism. For example, the first energy transfer mechanism may comprise a fiber optic wet mate and an electrical wet mate. The wet mates may be aligned in series, in parallel, or in any other configuration that allows both to be connected to other wet mates.

[0039] In some alternative embodiments, the first equipment section (e.g., bottom completion string) and / or the second equipment section (e.g., work string) and / or the third equipment section (e.g., top completion string) may include one or more other devices to enhance or improve the performance and / or reliability of the overall disclosure. For example, sensors, valves, pumps, analyzers, controllers, logic devices, computing devices, memory devices, AI devices, TinyML devices, etc. may be employed. Certain real-time operations may occur and / or be performed. For example, in at least one embodiment, a second ETM (e.g., fiber optic or other Wet Mate) is installed in the second equipment section (e.g., work string) and a communication device (e.g., wired tube, HalSonics, etc.) is employed, as shown in FIGS. 3 and 12.In at least one embodiment, this can be integrated into a digital reservoir management system (e.g., such as Halliburton's Clarity® digital reservoir management system) and thus interconnected to seamlessly share data and provide real-time solutions from ideation to reservoir management. Operators on the surface would be able to monitor what is happening downhole in real time. Some of these embodiments may require fiber optic, electrical, and / or other types of conduits (cables) to pass signals (and energy) to / from the surface. Other means of communication to and from the surface may also be employed, such as pressure pulses, acoustic waves, etc.

[0040] Returning to FIGS. 14 to 23, several different views of a multilateral guidance tool are illustrated, which includes a new control line design.

[0041] This disclosure acknowledges that there are certain instances, particularly during stimulation and / or fracturing operations, where it may be desirable to employ a device of Petition 870250068013, dated 04 / 08 / 2025, p. 46 / 123 15 / 33 grooved orientation (e.g., also known in the art as a grooved horseshoe) for positioning a downhole tool within a wellbore. The present disclosure, based on this recognition, acknowledges that debris, such as fracturing sand in one embodiment, can accumulate within the groove in the grooved orientation device and present problems with a key of an associated keyed through-hole tool slipping within the groove. With this in mind, the present disclosure has designed, in one embodiment, a grooved orientation device with the placement of the groove on a high side of the tubular (e.g., so that no portion of the groove is located below 3 o'clock or below 9 o'clock relative to gravity), which greatly reduces this problem.In yet another embodiment, the groove may be replaced by a feature that would traditionally fit into the groove (e.g., a pin), and the groove would be in the second or third section of the equipment. For example, such an embodiment could employ a groove that extends radially around the tubular 180 degrees or less, and in another embodiment a groove that has its radial center point positioned at 12 o'clock relative to gravity. According to at least one embodiment, a guiding tool may be coupled to the grooved guiding device, the guiding tool configured to guide the groove of the grooved guiding device within the wellbore (e.g., on the high side of the tubular). In yet another embodiment, the guiding tool is a measurement-drilling (MWD) tool that uses pressure pulses to guide the groove of the grooved guiding device within the wellbore.

[0042] This disclosure also acknowledges that it can sometimes be difficult to align the keys of the keyed passage tool with the groove in the grooved orientation device. This disclosure acknowledges that this can be especially the case when the groove in the grooved orientation device does not extend entirely around the tubular, as is the case with the aforementioned grooved orientation device with the groove placed on the high side of the tubular. With this acknowledgment in mind, this disclosure has designed a keyed passage tool having two or more keys movable between a radially retracted state and a radially extended state, wherein the adjacent keys of the two or more are displaced laterally from each other and radially displaced from each other by Y degrees, wherein Y is 180 degrees or less. Given this design, ideally at least one of the two keys should be Petition 870250068013, dated 04 / 08 / 2025, p. 47 / 123 16 / 33 would fit into the groove when the keyed through tool was being deployed at the bottom of the well.

[0043] FIG. 24 illustrates a well system 2400 designed, manufactured, and operated in accordance with one or more embodiments of the disclosure. The well system 2400 includes a platform 2420 positioned over an underground formation 2410 located below the Earth's surface 2415. The platform 2420, in at least one embodiment, has a lifting device 2425 and a tower 2430 for raising and lowering a downhole transport 2440, such as a drill string, casing string, tubing string, spiral tubing, through-tool, etc. Although an onshore oil and gas platform 2420 is illustrated in FIG. 24, the scope of this disclosure is not thereby limited and could potentially apply to offshore applications. The teachings of this disclosure can also be applied to other onshore multilateral wells different from those illustrated.

[0044] The 2400 well system, in one or more embodiments, further includes a main wellbore 2450. The main wellbore 2450, in the embodiment illustrated, includes piping 2460, 2465, which may have different tubular diameters. Extending from the main wellbore 2450, in one or more embodiments, there may be one or more side wellbores 2470. In addition, a plurality of multilateral junctions 2475 may be positioned at the junctions between the main wellbore 2450 and the side wellbores 2470. The multilateral junctions 2475 may be designed, manufactured and operated according to one or more embodiments of the disclosure. According to at least one embodiment, the multilateral joint 2475 may include a grooved guiding device and / or a keyed through-tool, according to any of the embodiments, aspects, applications, variations, designs, etc. disclosed in the following paragraphs.

[0045] The 2400 well system may additionally include one or more 2480 ICVs positioned at various locations within the main wellbore 2450 and / or one or more lateral wellbores 2470. The 2400 well system may additionally include a 2490 control unit. The 2490 control unit, in this embodiment, is operable to provide control to, or receive signals from, one or more downhole devices.

[0046] Returning to FIG. 25, an embodiment of a 2500 multilateral junction designed, manufactured and / or operated in accordance with one or more embodiments of the disclosure is illustrated. The junction Petition 870250068013, dated 04 / 08 / 2025, page 48 / 123 17 / 33 multilateral 2500, in the illustrated embodiment, includes a grooved orientation apparatus 2510. In at least one embodiment, the grooved orientation apparatus 2510 includes a tube with a wall thickness (t). The grooved orientation apparatus 2510, in at least one other embodiment, further includes a groove extending at least partially through the tubular, the groove having first and second axial portions displaced laterally from each other by a distance (ds), and an angular portion connecting the first and second axial portions, wherein the groove extends radially around the tubular X degrees, wherein X is 180 degrees or less. In one or more embodiments, the groove extends entirely through the wall thickness (t) of the grooved orientation apparatus 2510, but in other embodiments the groove extends only to an inner surface of the grooved orientation apparatus 2510 (e.g., only partially through the wall).

[0047] The multilateral joint 2500, in the embodiment illustrated, additionally includes a tubular spacer 2520 positioned in the wellbore of the slotted guide device 2510, a deflection wedge 2530 positioned in the wellbore of the tubular spacer 2520, and a Y-block 2540 positioned in the wellbore of the deflection wedge 2530. In the embodiment of FIG. 25, the multilateral joint 2500 additionally includes a main bore leg 2550 and a side bore leg 2560 coupled to a wellbore end of the Y-block.

[0048] A keyed through tool (not shown) can be used to position (e.g., rotationally position) one or more features within the multilateral junction 2500. For example, the key(s) of the keyed through tool can slide within the groove of the grooved orientation device 2510 to position one or more features within the multilateral junction 2500. In at least one embodiment, the keyed through tool is configured to position the bypass 2530 (e.g., a “TEW” pipe outlet bypass) in a desired lateral and rotational position within the multilateral junction 2500. Notwithstanding the foregoing, the grooved orientation device 2510 can be used to position different features within the multilateral junction 2500 or, alternatively, it can be used to position different features not associated with the multilateral junction 2500.

[0049] Returning to FIGS. 26A to 26H, several different views of a slotted orientation device 2600 designed, manufactured and operated according to one or more embodiments of the disclosure are illustrated. FIG. Figure 26A illustrates a top-down view of the device. Petition 870250068013, dated 04 / 08 / 2025, p. 49 / 123 Figures 18 / 33 illustrate the slotted orientation apparatus 2600, while Figures 26B to 26D illustrate various different sectional views of the slotted orientation apparatus 2600 obtained from the top-down view of Figure 26A. In contrast, Figure 26E illustrates a right-side view of the slotted orientation apparatus 2600, while Figures 26F to 26H illustrate various different sectional views of the slotted orientation apparatus 2600 obtained from the right-side view of Figure 26E. Each of the views illustrated in Figures 26A to 26H further illustrates the clock configurations as they would relate to the illustrated gravity point. The slotted orientation apparatus 2600, in at least one embodiment, is configured for use with a keyed passage tool, such as that discussed below, and may be positioned within another tubular structure, such as an enclosure.

[0050] The grooved orientation apparatus 2600, in the embodiment illustrated in FIGS. 26A to 26H, includes a tubular 2610 having a wall thickness (t). Many different tubular materials and wall thicknesses (t) can be used for the tubular 2610 and remain within the scope of the disclosure. However, in at least one embodiment, the tubular 2610 is a steel tube, and the wall thickness (t) varies from 0.07 cm to 5 cm. Furthermore, in at least one embodiment, the tubular can have a length (1) varying from 5 cm to 18.5 m.

[0051] According to at least one other embodiment of the disclosure, the grooved orientation apparatus 2600 includes a groove 2620 extending through the tubular 2610. In one or more embodiments, the groove 2620 has first and second axial portions 2630, 2640 displaced laterally from each other by a distance (ds) and an angular portion 2635 connecting the first and second axial portions 2630, 2640. The groove 2620, in at least one embodiment, extends radially around the tubular 2610 by X degrees, wherein X is 180 degrees or less. In at least one other embodiment, X is less than 180 degrees. Yet in another embodiment, as shown in FIGS. 26A to 26H, X is 120 degrees or less and, in one embodiment, 120 degrees. In yet another configuration, X is 90 degrees or less. As will be discussed in more detail below, the actual degrees for X may be related to the number of keys employed in the keyway tool.For example, if three equally spaced keys are used, X will equal 120 degrees. If four equally spaced keys are used, X will equal 90 degrees. If five equally spaced keys are used, X will equal 72 degrees. Petition 870250068013, dated 04 / 08 / 2025, page 50 / 123 19 / 33

[0052] Angle X can also be based on the coefficient of friction between the material inside the tubular 2610 (e.g., fracturing sand, coated fracturing proppan, forming fines, etc.) and the angled surfaces of the groove 2620, as well as the angle of repose of the material inside the tubular 2610. For example, in at least one embodiment, fracturing sand is being implanted in the tubular 2610. Consequently, the fracturing sand may have an angle of repose of Z degrees (e.g., wet sand has an angle of repose of 45 degrees), and angle X can be chosen based on the aforementioned coefficient of friction and the angle of repose of Z degrees (e.g., say, for example, 45 degrees). Thus, the combination of the coefficient of friction between the fracturing sand and the lower edge of the groove 2620, along with the angle of repose of Z degrees, would cause the fracturing sand not to accumulate on the angled surfaces of the groove 2620.

[0053] As an example, angle X may be less than twice a complementary angle of repose of the material within the tubular 2610 (e.g., X < 2*(90° - angle of repose of the material, or 0Rep)) when a radial center point of the groove 2620 is positioned at 12 o'clock relative to gravity, as shown in FIG. 261. In one embodiment, the material may have an angle of repose (0Rep) of at least 15 degrees (e.g., water-filled sand), and angle X would be less than 150 degrees (e.g., X < 2*(90° - 15°)). In another embodiment, the material may have an angle of repose (0Rep) of at least 260 degrees (e.g., water-filled sand), and angle X would be less than 120 degrees (e.g., X < 2*(90° - 30°)). In yet another embodiment, the material may have an angle of repose (0Rep) of at least 40 degrees, and the angle X would be less than 100 degrees (for example, X < 2* (90° - 40°)).In another embodiment, the material may have an angle of repose (0Rep) of at least 45 degrees, and the angle X would be less than 90 degrees (for example, X < 2* (90° - 45°)).

[0054] The groove 2620, in certain embodiments, is located on a high side of the tubular 2610, such that no portion of the groove 2620 is located below 3 o'clock or below 9 o'clock relative to gravity. In such embodiments, X would need to be less than 180 degrees to accommodate a width of the first and second axial portions 2630, 2640. For example, depending on the width of the first and second axial portions 2630, 2640, X may need to be 175 degrees or less to accommodate the aforementioned high side. In certain other Petition 870250068013, dated 04 / 08 / 2025, Page 51 / 123 In 20 / 33 modes, such as that shown in FIGS. 26A to 26H, a radial center point of the 2620 groove is positioned at 12 o'clock relative to gravity.

[0055] In addition to the embodiment of FIGS. 26A to 26H, the groove 2620 may have a length (ls), and the first and second axial portions may have a length (lap). Thus, according to one or more embodiments, the length (ls) varies from 2.5 cm to 900 cm and the length (lap) varies from 1 cm to 600 cm. Similarly, in one embodiment, the distance (ds) varies from 1 cm to 900 cm, among others. Given certain dimensions of the groove 2620, an angle (Θ) of the angled portion 2635 may vary from 15 degrees to 60 degrees and, in yet another embodiment, from 25 degrees to 50 degrees.

[0056] Returning to FIGS. 27A to 27D, several different views of a slotted orientation apparatus 2700 designed, manufactured, and operated according to one or more alternative embodiments of the disclosure are illustrated. FIG. 27A illustrates a top-down view of the slotted orientation apparatus 2700, while FIGS. 27B to 27D illustrate several different sectional views of the slotted orientation apparatus 2700 obtained from the top-down view of FIG. 27A. The slotted orientation apparatus 2700 is similar in many respects to the slotted orientation apparatus 2600. Consequently, similar reference numbers have been used to indicate similar, if not identical, features. For example, the slotted orientation apparatus 2700 includes the first axial portion 2630, the angular portion 2635, and the second axial portion 2640.However, the slotted orientation device 2700 employs an open-type slot 2720, unlike the more closed-type slot 2620 of the slotted orientation device 2600.

[0057] Returning to FIGS. 28A to 28D, different views of a keyed through-tool 2800 designed, manufactured and operated according to one or more embodiments of the disclosure are illustrated. FIG. 28A illustrates an isometric view of the keyed through-tool 2800, while FIGS. 28B to 28D illustrate cross-sectional views taken from various different locations of the keyed through-tool 2800. The keyed through-tool 2800, in at least one embodiment, is configured for use with a grooved guiding device, such as the grooved guiding device 2600 illustrated above in relation to FIGS. 26A to 27D.

[0058] The keyed through tool 2800 illustrated in FIGS. 28A to 28D, in one or more embodiments, includes a housing 2810. The housing 2810 may comprise many forms, Petition 870250068013, dated 04 / 08 / 2025, Page 52 / 123 21 / 33 different lengths and / or materials, remaining within the scope of disclosure. In at least one embodiment, however, the housing 2810 comprises steel. The housing 2810 may comprise more than one component to perform its function (securing more than one wrench, aligning the wrenches, securing the main housing to the tools at one or both ends).

[0059] The keyed through-tool 2800, according to an embodiment of the disclosure, includes two or more keys 2820 extending from the housing 2810. The two or more keys 2820, in certain embodiments, are movable between a radially retracted state (e.g., where they may be flush with an outer diameter of the housing 2810) and a radially extended state (e.g., as shown, where they extend beyond the outer diameter of the housing 2810). For example, the two or more keys 2820 may be two or more spring-loaded keys 2820 and remain within the scope of the disclosure. In the embodiment of FIGS. 28A to 28D, the keyed through-tool 2800 includes three keys 2820.

[0060] According to one embodiment of the disclosure, the adjacent keys of two or more 2820 keys are radially offset from each other by Y degrees, where Y is 180 degrees or less. For example, depending on the number of 2820 keys, Y may vary. For example, if three equally spaced keys are used, Y will be equal to 120 degrees. If four equally spaced keys are used, Y will be equal to 90 degrees. If five equally spaced keys are used, Y will be equal to 72 degrees. In certain cases, it may be advantageous to have an odd number of equally spaced keys, so that none of them are radially offset from each other by 180 degrees. In certain cases, it may be advantageous to have three or more keys spaced at different angles from each other.For example, if the assembly needs to be pushed into a specific orientation, but its center of mass is not positioned along the centerline, then having two keys engaged in a specific orientation can distribute the stresses over a larger area to reduce stress on the keys (and grooves). Similarly, the keys can be wider to increase the load-bearing area of ​​the keys in order to reduce stress on the keys and the orientation groove.

[0061] According to one embodiment of the disclosure, the adjacent keys of two or more 2820 keys are displaced laterally from each other. For example, adjacent keys of two or more keys are displaced laterally from each other by a maximum distance (dm). In at least Petition 870250068013, dated 04 / 08 / 2025, p. 53 / 123 22 / 33 In one modality, the maximum distance (dm) varies from 2.5 cm to 900 cm. However, other values ​​for maximum distance (dm) are within the scope of disclosure.

[0062] In certain embodiments, the value for Y (e.g., the radial displacement of the 2820 keys) and the value for X (e.g., the extent to which the groove of the grooved guiding device extends radially around the tubular) are related to each other. For example, there are certain embodiments in which the value of Y is substantially equal to the value of X. The term “substantially equal,” as used herein with respect to the associated values ​​for Y and X, means that the values ​​are within 10 percent of each other, for example, to accommodate a 2820 key width. In other embodiments, the value of Y is ideally equal to the value of X. The term “ideally equal,” as used herein with respect to the associated values ​​of Y and X, means that the values ​​are within 5% of each other, for example, to accommodate a 2820 key width. Still in other embodiments, the value of Y is exactly equal to the value of X.The term "exactly equal," as used here with respect to the associated values ​​for Y and X, means that the values ​​are within 1 percent of each other.

[0063] Similarly, in certain embodiments, the maximum distance (dm) (e.g., the maximum lateral displacement of the adjacent key 2820) and the length (ls) of the groove of the slotted orientation device are related to each other. For example, in certain embodiments, it is beneficial for two or more keys 2820 to reside in the groove at the same time. Thus, in at least one embodiment, the maximum distance (dm) is less than the length (ls). However, in certain other embodiments, it is beneficial for the two or more keys 2820 to reside within the first and second axial portions of the groove, respectively, so that the maximum distance (dm) is greater than the distance (ds) (e.g., the lateral distance between the first and second axial portions).

[0064] The keyed through-tool 2800, in one or more embodiments, may additionally include a rotating support 2830 coupled to an upper end of the housing 2810. In at least one embodiment, the rotating support 2830 is configured to allow the housing 2810 and the two or more keys 2820 to rotate when following a groove in a grooved guiding device. The keyed through-tool 2800 may additionally include an engagement member 2840 coupled to a wellbore end of the housing 2810. The engagement member 2840, in at least one embodiment, is configured to engage with a Petition 870250068013, dated 04 / 08 / 2025, page 54 / 123 23 / 33 downhole tool and rotationally position the downhole tool within a wellbore in which it is located. For example, the engagement member 2840 can engage with a deflection wedge, such as the deflection wedge 230 illustrated in FIG. 25, in which case the keyed through tool 2800 would be used to rotationally position the deflection wedge 2530 within the multilateral joint 200. The keyed through tool 2800 can be used in other hydrocarbon construction and production processes or phases, such as, but not limited to: during production, completion, stimulation, reconditioning, redrilling and / or fracturing operations, etc. In one or more embodiments, coupling member 2840 may comprise an energy transfer mechanism (ETM), a guidance device, a communication device, a wet mate, a dry mate, an optical fiber coupler (wet mate) as mentioned in this application.In some embodiments, the coupling member 2840 may comprise an ETM, guidance or communication device, wet mate, dry mate, fiber optic coupler other than those mentioned in this application. The coupling member 2840 may comprise a mechanical device (such as a clamp, spring, hydraulic damper, shoulder, debris excluder, barrier, pressure barrier, reservoir, accumulator, profile, etc.), an electrical device (a resistor, capacitor, battery, sensor, switch, etc.), a fluidic device (reservoir, accumulator, choke, trigger, line, rupture disc, vent, logic device, amplifiers, triodes, amplifier, oscillator, etc.), an electronic device (a computer, a chip, a sensor, a power converter, memory storage, logic chip / device, MEMS, etc.), a power line (i.e., electrical, hydraulic, fiber, heat, etc.).), a power transfer line (i.e., electrical, hydraulic, fiber, heat, etc.), etc.

[0065] Returning now to FIGS. 29A to 29F, an embodiment for aligning a downhole tool is illustrated according to the disclosure. For example, the embodiment for aligning a downhole tool may include the use of a grooved orientation device 2900 and a keyed through-tool 2950 for aligning a downhole tool. In at least one embodiment, the grooved orientation device 2900 and the keyed through-tool 2950 are similar to the grooved orientation device 2600 and the keyed through-tool 2800 discussed above. Thus, in at least one embodiment, the grooved orientation device 2900 may include a tubular Petition 870250068013, dated 04 / 08 / 2025, page 55 / 123 24 / 33 2910, as well as a groove 2920 extending through the tubular, the groove having first and second axial portions 2930, 2940 offset laterally from each other by a distance (ds), and an angular portion 2935 connecting the first and second axial portions 2930, 2940. According to at least one embodiment, the groove 2920 extends radially around the tubular 2910 by X degrees, where X is 180 degrees or less. Similarly, in at least one embodiment, the keyed through tool 2950 may include a housing 2960, as well as two or more keys 2970 extending from the housing 2960, the two or more keys 2970 movable between a radially retracted state and a radially extended state. According to at least one embodiment, the adjacent keys of two or more 2970 keys are displaced laterally from each other and radially displaced from each other by Y degrees, where Y is 180 degrees or less.The 2900 grooved guidance device may comprise one or more grooves or features to improve the functional requirements and reliability of the device and the system. In some embodiments, one or more sets of axial and helical grooves. For example, 2900 may comprise 3 sets of axial grooves (2930 and / or 2940) and / or grooves (angular / helical) (2920, 2935, etc.). An advantage of having 3 sets of grooves is that, if there are 3 wrenches (e.g., 2970a, b, c), more than one wrench can fit into more than one groove. This, in turn, can reduce the amount of stress placed on a wrench and groove during the guidance / alignment process. Furthermore, the torque generated by more than one wrench would be less and distributed around the axis of the 2950 tool and components / assemblies coupled to it. As an example, referring to FIG.29D, another groove or grooves may be positioned so that Key 2970a can engage at least one of the grooves in unison with Key 2970b engaging groove(s) 2930, 2920, 2940, etc. In some embodiments, when Key 2970c is fitted into a groove (for example, as shown in FIG. 29E), Keys 2970a and / or 2970b may be engaging one or more other grooves.

[0066] In the embodiment of FIGS. 29A to 29F, the groove 2920 of the grooved guiding device 2900 extends radially around the tubular 2910 by 120 degrees. Similarly, the keyed through-hole tool 2950 includes three keys, including a downhole key 2970a, an intermediate key 2970b, and an overhole key 2970c. In addition to the embodiment of FIGS. 29A to 29F, the downhole key 2970a, the intermediate key 2970b and Petition 870250068013, dated 04 / 08 / 2025, p. 56 / 123 25 / 33 the key hole above 2970c are radially offset from each other by 120 degrees. While a design of three 2970 keys and 120 degrees is being illustrated and described with respect to FIGS. 29A to 29F, another number of 2970 keys and radial spacing are within the scope of the disclosure.

[0067] With reference to FIG. 29A, the keyed through tool 2950 is initially at least partially engaged with the grooved guiding device 2900. For example, in the embodiment illustrated in FIG. 29A, the downhole wrench 2970a is laterally aligned with the groove 2920 when the keyed through tool 2950 is being pushed into the wellbore. Thus, in the embodiment of FIG. 29A, the downhole wrench 2970a can engage with the groove 2920, as shown. Although FIG. Figure 29A illustrates the downhole wrench 2970a positioned in the angled portion 2935 of the groove 2920. Depending on the initial radial alignment between the downhole wrench 2970a and the groove 2920, the downhole wrench 2970a may alternatively engage initially in the first axial portion 2930 or engage initially in the second axial portion 2940.Additionally, since the 2970 keys are movable between radially retracted and radially extended states, a location where the 2970 keys fit into the 2920 groove has no effect on the 2970 keys.

[0068] With reference to FIG. 29B, the keyed passage tool 2950 of FIG. is illustrated. 29A after continuing to push the keyed through tool 2950 into the wellbore, causing the downhole wrench 2970a to rotate within the groove 2920 until the downhole wrench 2970a is positioned within the second axial portion 2940 of the groove 2920 and the intermediate wrench 2970b is positioned within the first axial portion 2930 of the groove 2920. Since the maximum distance (dm) between the downhole wrench 2970a and the intermediate wrench 2970b is less than the length (ls) of the groove 2920, both the downhole wrench 2970a and the intermediate wrench 2970b can be located simultaneously within the groove 2920. Furthermore, in certain embodiments, the relationship between the maximum distance (dm) and the length (ls) determines that no more than two wrenches 2970 can be... activated in slot 2920 at any time.Furthermore, since the radial value for X is substantially similar to the radial value for Y, the downhole key 2970a and the intermediate key 2970b can be located simultaneously in the second axial portion 2940 and the first axial portion 2930, respectively. Petition 870250068013, dated 04 / 08 / 2025, page 57 / 123 26 / 33

[0069] With reference to FIG. 29C, the keyed through tool 2950 of FIG. 29B is illustrated after continuing to push the keyed through tool 2950 into the bottom of the well, causing the downhole wrench 2970a to move to its radially retracted state (e.g., within the tubular 2910) and the intermediate wrench 2970b to rotate to the angled portion 2935 of the groove 2920. Given the spacing between adjacent wrenches 2970, in one or more embodiments, if a wrench (e.g., the intermediate wrench 2970b) is located within the angled portion 2935 of the groove 2920, an adjacent wrench 2970 (e.g., the downhole wrench 2970a or the hole-above wrench 2970c) cannot also be located within the groove 2920.

[0070] With reference to FIG. 29D, the keyed passage tool 2950 of FIG. is illustrated. 29C after continuing to push the keyed through tool 2950 into the bottom of the well, causing the intermediate wrench 2970b to rotate within the groove 2920 until the intermediate wrench 2970b is positioned within the second axial portion 2940 of the groove 2920 and the hole-over wrench 2970c is positioned within the first axial portion 2930 of the groove 2920. Since the maximum distance (dm) between the intermediate wrench 2970b and the hole-over wrench 2970c is less than the length (ls) of the groove 2920, both the intermediate wrench 2970b and the hole-over wrench 2970c can be located simultaneously within the groove 2920. Furthermore, since the radial value for X is substantially similar to the radial value for Y, the intermediate wrench 2970b and the hole-over wrench 2970c can be located simultaneously in the second axial portion. 2940 and in the first axial portion 2930, respectively.

[0071] With reference to FIG. 29E, the keyed through tool 2950 of FIG. 29D is illustrated after continuing to push the keyed through tool 2950 into the bottom of the well, causing the intermediate key 2970b to also move to its radially retracted state (e.g., into the tubular 2910) and the hole-up key 2970c to rotate into the angled portion 2935 of the groove 2920. Given the spacing between adjacent keys 2970, in one or more embodiments, if a key (e.g., the hole-up key 2970c) is located within the angled portion 2935 of the groove 2920, the adjacent key 2970 (e.g., the downhole key 2970a or the intermediate key 2970b) cannot also be located within the groove 2920. Petition 870250068013, dated 04 / 08 / 2025, p. 58 / 123 27 / 33

[0072] With reference to FIG. 29F, the keyed through tool 2950 of FIG. 29E is illustrated after continuing to push the keyed through tool 2950 into the wellbore, causing the hole-up key 2970c to rotate within the groove 2920 until the hole-up key 2970c is positioned within the second axial portion 2940 of the groove 2920. At this stage, at least in the embodiment of FIGS. 29A to 29F, the keyed through tool 2950 reaches the bottom and therefore cannot move further into the wellbore. Furthermore, in certain embodiments, any downhole tool coupled to the keyed through tool 2950 is positioned rotationally and laterally into a desired position within the wellbore.

[0073] The embodiment of FIGS.Figures 29A to 29F assume that the downhole wrench 2970a is initially radially aligned with the groove 2920 such that, as the keyed through tool 2950 is pushed into the downhole, the downhole wrench 2970a would engage in at least one of the first axial portion 2930, the angled portion 2935, or the second axial portion 2940. However, in certain cases, the downhole wrench 2970a would become radially misaligned with the groove 2920 such that, as the keyed through tool 2950 is pushed into the downhole, the downhole wrench 2970a would not engage in the groove 2920. In this case, either the intermediate wrench 2970b or the hole-over wrench 2970c may initially align radially with the groove 2920.

[0074] In the case where the downhole wrench 2970a is radially misaligned with the groove 2920, but the intermediate wrench 2970b is at least partially radially aligned with the groove 2920, the keyed through tool 2950 would be pushed into the bottom of the well, causing the downhole wrench 2970a not to reach the groove 2920 and the intermediate wrench 2970b to initially engage and rotate within the groove 2920 until the intermediate wrench 2970b was positioned within the second axial portion 2940 of the groove 2920 and the uphole wrench 2970c was positioned within the first axial portion 2930 of the groove 2920, very similar to that shown in FIGS. 29C and 29D.After that, the process would continue by pushing the keyed through tool 2950 into the wellbore, causing the hole-up key 2970c to rotate within the groove 2920 until the hole-up key 2970c was positioned within the second axial portion 2940, at which point the holebore tool would be positioned rotationally within the wellbore, similar to that shown in FIGS. 29E and 29F. Petition 870250068013, dated 04 / 08 / 2025, page 59 / 123 28 / 33

[0075] In the case where the downhole wrench 2970a and the intermediate wrench 2970b are radially misaligned with the groove 2920, but the uphole wrench 2970c is at least partially radially aligned with the groove 2920, the keyed through tool 2950 would be pushed into the downhole, causing the downhole wrench 2970a and the intermediate wrench 2970b to not reach the groove 2920 and the uphole wrench 2970c to initially engage and rotate within the groove 2920 until the uphole wrench 2970c was positioned within the second axial portion 2940, at which point the downhole tool would be positioned rotationally within the wellbore, very similar to that shown in FIGS. 29E and 29F.

[0076] Exclusive to at least one embodiment of the project, regardless of the radial alignment between the keyed through tool 2950 and the grooved guiding device 2900, at least one of the downhole wrenches 2970a, the intermediate wrench 2970b, or the above hole wrench 2970c will align at least partially with the groove 2920. Thus, regardless of radial alignment, in at least one embodiment, the above hole wrench 2970c will always end up in the second axial portion 2940, resulting in the downhole tool that is coupled to a downhole end of the keyed through tool 2950 being positioned laterally and rotationally as desired within the wellbore.

[0077] It should be evident to one skilled in the art that the keyed passage tool 2950 can also align itself with respect to the grooved orientation device 2900 when moving from under the grooved orientation device 2900 in an upward motion (for example, provided that the keys 2970a, 2970b and 2970c have the appropriate profile to engage in the groove 2920 in the grooved orientation device 2900). For example, the keys 2970a, 2970b and 2970c could fit into the groove 2920 in the opposite manner to that described above with respect to FIGS. 29Aa29F.

[0078] It should also be noted that the grooved guiding device 2900 may have an upward retaining mechanism to hold the keyed through tool 2950 in an axial position until a desired amount of upward force is exerted to cause the retaining mechanism (not shown) to allow further upward movement. In some embodiments, one or more keys (e.g., hole-over key 2970c) may provide Petition 870250068013, dated 04 / 08 / 2025, page 60 / 123 29 / 33 the desired resistance to temporarily stop the upward movement of the keyed through tool 2950 (for example, until additional force is applied).

[0079] It should also be noted that the grooved guide device 2900 can be designed to slide / fit inside a standard API-type enclosure or a specially designed tubular with an outside diameter similar to (or different from) that of a standard API enclosure, tubing or other tubular.

[0080] It should be noted that the lengths of the first and second axial portions 2930, 2940 need not be the same. In some instances, it may be desirable that the keyed passage tool 2950 be held in a particular orientation by one or more keys 2970 until an additional distance has been traversed – or a certain event has occurred (e.g., coupling with another assembly pre-installed in the well). In one or more embodiments, the additional distance may be used to decrease the rate of descent of 2950 by including one or more devices, such as a hydraulic damper, a spring, a pad, a shock absorber, or a combination thereof, to resist the movement of 2950 and the components connected to it. One or more components of such a device may be positioned between the distal end of 2900.In some embodiments, one or more devices may be used to removablely lock 2950s and / or associated components / assemblies (e.g., swivel, ETM, etc.) in place. In one or more embodiments, it may be beneficial to allow the 2950 and / or associated components (e.g., ETM, fiber optic wet mate, production tubing, etc.) to move after coupling. For example, after an ETM coupling (e.g., fiber optic wet mate, electrical wet mate, a combination of ETMs) is coupled, the production string (e.g., tubing) may expand or contract due to changes in pressure (e.g., expansion, etc.) or thermal changes (e.g., due to pumping a cold fluid into a warm / hot production tubing string, etc.) or for other reasons. In such cases, it would be pertinent to allow the ETM (and / or related parts) to move at least axially so that the loads generated by swelling, heating / cooling, etc.Do not press on the ETM couplings and attempt to force them apart. A device that allows the control line to expand / contract without generating forces on the ETM would be preferable. The device may comprise a coiled or bent control line that can allow (axial) movement without inducing high stresses or loads on the line. Petition 870250068013, dated 04 / 08 / 2025, page 61 / 123 30 / 33 control and / or related components (such as the ETM). The space between the distal end of 2900 and the first piece of equipment (e.g., bottom completion wet mate, bottom completion sand control string, etc.) would be a preferred location for the aforementioned devices (e.g., mechanical device (such as a clamp, spring, hydraulic damper, etc.), an electrical device (a sensor, switch, etc.), a fluidic device (reservoir, accumulator, a seat valve, a check valve, etc.), an electronic device (a sensor, a MEMS device, etc.), etc. Other devices, technologies, etc. may also be employed in this area.In some or most cases, the lower components of the third equipment section (also known as the upper completion string) may have complementary features, devices, and assemblies that may function in conjunction with the items mentioned above (e.g., items located at the distal end of 2900). The foregoing is not intended to limit the use of the area above 2900; similar or different features, devices, and assemblies may be used above 2900 to assist in the efficient and reliable installation and use of the items disclosed herein.The items, features, devices, and assemblies mentioned above are applicable for use with a second equipment section (e.g., work column) or other equipment sections, such as another equipment section similar to the second equipment section (e.g., work column) that may be used before the third equipment section and / or after the third equipment section.

[0081] It should be clear that the grooved orientation device (e.g., grooved orientation device 2600, 2900) and the keyed passage tool (e.g., keyed passage tool 2800, 2950) disclosed herein can be used to perform other actions regardless of whether debris is a problem or not. For example, the grooved orientation device can be used to orient tools for forming evaluation, production evaluation, tool / equipment condition evaluation, etc. In at least one embodiment, the grooved orientation device can orient a feeler gauge (e.g., multi-finger device) to measure erosion in various orientations.

[0082] A keyed through-tool, according to the disclosure, may be a sleeve-type device in which, after orienting a tool, it remains located in the grooved orientation device while the oriented tool (and the spiral tube) continues Petition 870250068013, dated 04 / 08 / 2025, page 62 / 123 31 / 33 moving downwards. For example, the sleeve-type keyed through-hole tool can orient the tool so that it enters the main bore leg of a multi-sided joint. After the oriented tool is aligned, the sleeve-type keyed through-hole tool can be released from the pipe (e.g., spiral pipe), so that the oriented tool can continue to be lowered into the main bore through the pipe. In at least one other embodiment, the sleeve-type keyed through-hole tool may have a snap-fit ​​profile, so that when the other tool is pulled back above a Y-block, the sleeve-type keyed through-hole will be indexed 90 degrees and the other tool will enter the side bore of the multi-sided joint and / or Y-block.

[0083] Returning to FIG. 25', as well as FIGS. 29A' to 29F', a hydraulic stimulation device designed, manufactured and / or operated according to one or more embodiments of the disclosure is illustrated. The hydraulic stimulation device is similar in many respects to the multilateral junction 2500 and the grooved orientation apparatus 2900 disclosed above and therefore may share many of the same features.

[0084] The aspects disclosed in this document include: A. A wellbore system, the wellbore system including: 1) a wellbore extending through one or more subsurface formations; 2) a tubular located within the wellbore; and 3) a power transfer mechanism coupled to the tubular, wherein the power transfer mechanism is located above 3 o'clock or above 9 o'clock relative to gravity. B. A method, the method including: 1) forming a wellbore through one or more underground formations; 2) positioning a tubular inside the wellbore, the tubular having a power transfer mechanism coupled to it; and 3) rotating the power transfer mechanism so that the power transfer mechanism is located above 3 o'clock or above 9 o'clock relative to gravity.

[0085] Aspects A and B may have one or more of the following additional elements in combination: Element 1: wherein the energy transfer mechanism has a first coupling surface configured to couple with an opposite second coupling surface of a second energy transfer mechanism and further wherein the first coupling surface is located above 3 o'clock or above 9 o'clock relative to gravity. Petition 870250068013, dated 04 / 08 / 2025, page 63 / 123 32 / 33 Element 2: where all portions of the energy transfer mechanism are located above 3 o'clock or above 9 o'clock relative to gravity. Element 3: where the energy transfer mechanism is a wet mate energy transfer mechanism. Element 4: where the tubular and the wet mate energy transfer mechanism are a first tubular and a first wet mate energy transfer mechanism associated with a lower completion string. Element 5: further including a second tubular and a second wet mate energy transfer mechanism positioned within the wellbore adjacent to the first wet mate energy transfer mechanism. Element 6: where the second tubular engages with the first tubular and the second wet mate energy transfer mechanism engages with the first wet mate energy transfer mechanism.Element 7: wherein the second tubular and second wet mate energy transfer mechanism are associated with a working string. Element 8: wherein the second tubular and second wet mate energy transfer mechanism are associated with an upper completion string. Element 9: wherein the energy transfer mechanism is located above 1 o'clock or above 11 o'clock relative to gravity. Element 10: wherein the energy transfer mechanism has a first coupling surface configured to couple with an opposite second coupling surface of a second energy transfer mechanism, and wherein the rotation includes rotating the energy transfer mechanism so that the first coupling surface is located above 3 o'clock or above 9 o'clock relative to gravity.Element 11: wherein rotation includes rotating the energy transfer mechanism so that all portions of the energy transfer mechanism are located above 3 o'clock or above 9 o'clock relative to gravity. Element 12: wherein the energy transfer mechanism is a wet mate energy transfer mechanism. Element 13: wherein the tubular and the wet mate energy transfer mechanism are a first tubular and a first wet mate energy transfer mechanism associated with a lower completion string. Element 14: further including a second tubular and a second wet mate energy transfer mechanism positioned within the wellbore adjacent to the first wet mate energy transfer mechanism. Element 15: wherein the second tubular engages with the first tubular and the second wet mate energy transfer mechanism engages with the first wet mate energy transfer mechanism.Element 16: in which the second tubular element is... Petition 870250068013, dated 04 / 08 / 2025, page 64 / 123 Element 17: wherein the second tubular and second wet mate energy transfer mechanism are associated with an upper completion string. Element 18: further including the use of a downhole orientation tool to rotate the energy transfer mechanism so that the energy transfer mechanism is located above 3 o'clock or above 9 o'clock relative to gravity.

[0086] Those skilled in the art to which this application relates will understand that other additions, deletions, substitutions, and further modifications may be made to the modalities described. Petition 870250068013, dated 04 / 08 / 2025, page 65 / 123

Claims

1 / 3 1. Well system, characterized in that it comprises: a wellbore extending through one or more underground formations; a pipe located within the wellbore; and a power transfer mechanism coupled to the pipe, wherein the power transfer mechanism is located above 3 o'clock or above 9 o'clock relative to gravity.

2. Well system according to Claim 1, characterized in that the energy transfer mechanism has a first coupling surface configured to couple with a second opposite coupling surface of a second energy transfer mechanism, and further in that the first coupling surface is located above 3 o'clock or above 9 o'clock relative to gravity.

3. Well system according to Claim 2, characterized in that all portions of the energy transfer mechanism are located above 3 o'clock or above 9 o'clock relative to gravity.

4. Well system according to Claim 1, characterized in that the energy transfer mechanism is a wet mate energy transfer mechanism.

5. Well system according to Claim 1, characterized in that the tubular and wet mate energy transfer mechanism are a first tubular and wet mate energy transfer mechanism associated with a lower completion string.

6. Well system, according to Claim 5, characterized in that it further includes a second tubular and a second wet mate energy transfer mechanism positioned inside the wellbore near the first wet mate energy transfer mechanism. Petition 870250068013, dated 04 / 08 / 2025, pp. 117 / 123 2 / 3 7. Well system according to Claim 6, characterized in that the second tubular engages with the first tubular and the second wet mate energy transfer mechanism couples with the first wet mate energy transfer mechanism.

8. Well system according to Claim 6, characterized in that the second tubular and second wet mate energy transfer mechanism are associated with a working string, or optionally in that the second tubular and second wet mate energy transfer mechanism are associated with an upper completion string.

9. Well system according to Claim 1, characterized in that the energy transfer mechanism is located above 1 o'clock or above 11 o'clock relative to gravity.

10. Method, characterized in that it comprises: forming a well hole through one or more underground formations; positioning a tubular pipe inside the well hole, the tubular pipe having an energy transfer mechanism coupled to it; and rotating the energy transfer mechanism so that the energy transfer mechanism is located above 3 o'clock or above 9 o'clock relative to gravity.

11. A method according to Claim 10, characterized in that the energy transfer mechanism has a first coupling surface configured to couple to a second opposite coupling surface of a second energy transfer mechanism, and further in that the rotation includes rotating the energy transfer mechanism so that the first coupling surface is located above 3 o'clock or above 9 o'clock relative to gravity, or optionally in that the rotation includes rotating the energy transfer mechanism so that all portions of the energy transfer mechanism are located above 3 o'clock or above 9 o'clock relative to gravity. Petition 870250068013, dated 04 / 08 / 2025, pp. 118 / 123 3 / 3 12. Method according to Claim 10, characterized in that the energy transfer mechanism is a wet mate energy transfer mechanism.

13. Method, according to Claim 10, characterized in that the tubular and wet mate energy transfer mechanism are a first tubular and a first wet mate energy transfer mechanism associated with a lower completion string.

14. Method according to Claim 13, characterized in that it further includes a second tubular and a second wet mate energy transfer mechanism positioned within the wellbore near the first wet mate energy transfer mechanism, or optionally in which the second tubular engages with the first tubular and the second wet mate energy transfer mechanism couples to the first wet mate energy transfer mechanism, or optionally in which the second tubular and the second wet mate energy transfer mechanism are associated with a working string, or optionally in which the second tubular and the second wet mate energy transfer mechanism are associated with an upper completion string.

15. Method, according to Claim 10, characterized in that it further includes the use of a bottomhole guidance tool to rotate the power transfer mechanism so that the power transfer mechanism is located above 3 o'clock or above 9 o'clock relative to gravity. Petition 870250068013, dated 04 / 08 / 2025, pp. 119 / 123

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