COILED TUBING CONVEYED ELECTRICAL ORIENTER

Abstract

A bottom hole assembly can include a cable head configured to connect the bottom hole assembly to a cable in a coiled tubing, an electrical orienter to rotate multiple sensor packages downhole, and multiple conductors extending between the cable head and the sensor packages via the electrical orienter. A method can include connecting a bottom hole assembly to a coiled tubing, the bottom hole assembly comprising an electrical orienter, a sensor package including ranging equipment, a fluid motor and a drill bit, deploying the coiled tubing and the bottom hole assembly into the well, activating the electrical orienter to rotate the ranging equipment, and then drilling an offset wellbore toward a target wellbore located using the ranging equipment. An electrical orienter can include an electric motor, a flow path extending completely longitudinally through the electrical orienter, and multiple conductors extending completely longitudinally through the electrical orienter.

Description

BACKGROUND

This disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in an example described below, more particularly provides a coiled tubing conveyed electrical orienter.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a representative partially cross-sectional view of an example of a well system and associated method which can embody principles of this disclosure.

FIG. 2 is a representative elevational view of an example of a bottom hole assembly which may be used in the FIG. 1 system and method.

FIG. 3 is a representative cross-sectional view of an example of portions of an electrical orienter and sensor package.

FIG. 4 is a representative schematic view of an example of the electrical orienter with multiple sensor packages.

FIG. 5 is a representative elevational view of another example of the bottom hole assembly.

FIG. 6 is a representative elevational view of another example of the electrical orienter.

FIGS. 7 & 8 are representative cross-sectional views of an example of a section of a cable head.

FIG. 9 is a representative cross-sectional view of an example of a section of a check valve.

FIG. 10 is a representative partially cross-sectional and perspective view of the check valve.

FIGS. 11 & 12 are representative cross-sectional views of an example of a torque weak point section of the electrical orienter.

DETAILED DESCRIPTION

Representatively illustrated in the accompanying figures is a system for use with a subterranean well, and an associated method, which can embody principles of this disclosure. However, it should be clearly understood that the system and method are merely one example of an application of the principles of this disclosure in practice, and a wide variety of other examples are possible. Therefore, the scope of this disclosure is not limited at all to the details of the system and method described herein and/or depicted in the drawings.

Disclosed herein is a dual/multi-conductor electrical orienter allowing for a dedicated return conductor used for active magnetic ranging in one example. This feature also provides for additional applications, some examples of which are described below.

A coiled tubing conveyed rotatable bottom hole assembly (BHA) is described below for use in logging, drilling, navigation, magnetic ranging and other operations. Multiple conductors can be utilized to operate multiple sensor assemblies, either with a chassis ground/return or with one or more dedicated ground/return conductor(s).

A primary sensor package included in the BHA can operate in conjunction with the electrical orienter. In one example, the sensor package includes weight on bit, torque on bit, downhole tubing temperature, downhole annulus temperature, downhole tubing pressure and downhole annulus pressure sensors.

Multiple conductors pass through the electrical orienter, allowing for single or multiple sensor packages in the BHA. The primary sensor package and any additional sensor packages can operate with chassis ground/return or via a single dedicated ground/return conductor or via multiple separate dedicated ground/return conductors (one conductor for each sensor package), or any combination of chassis or dedicated ground/return.

For the purpose of logging, a straight BHA can be run with sensor packages below the electrical orienter. Rotating the lower BHA about its axis changes an orientation of a sensor axis for collecting additional data, in cases which include setting an orientation of a magnetic axis for the purpose of magnetic ranging, or rotating a focused logging tool to gain a full 360 degree scan of a wellbore.

For the purpose of drilling navigation, multiple sensor packages can be stacked within a single BHA without the need for customization and collaboration between sensor package equipment providers. Instead, each sensor package runs independently. Connecting the stacked sensor packages can be completed with custom crossovers utilizing pass through conductors within each sensor package or via a hookup wire around an outside of the sensor package.

Additionally, for navigation the sensor packages can be located within an axially aligned housing and/or in an angular offset section of the BHA. Such cases include using a measurement while drilling (MWD) probe in the axial section, thereby providing directional data and toolface data to navigate multi-laterals, and a downhole camera within the angular offset section for the purpose of being able to navigate sidetracks through vision and/or to inspect a targeted lateral. To shorten the BHA, this camera configuration can be completed without the MWD sensor package, whereby the camera toolface is aligned with high-side and locked into position (physically or via procedure) such that the electrical orienter is used to steer the bend and rotate the camera as needed for viewing.

For the purpose of magnetic ranging, more specifically active magnetic ranging via current injection, all sensor packages can have dedicated ground/return conductors. For this purpose, the ground potential of each sensor package can be optimized for enhanced magnetic ranging data.

In advanced situations the BHA can be conveyed with a combination of fiber optic and electrical lines within the coiled tubing. In this example, the electrical line(s) is/are utilized for rotating or steering the BHA, and the fiber optic line(s) is/are used for distributed acoustic sensing/distributed temperature sensing (DAS/DTS) logging. Such a system could be adopted in all specific examples described herein.

A motor control system described herein enables an electrical conductor assignment useful for active magnetic ranging. The motor control system is an improvement over an existing system described in U.S. Pat. No. 10,294,777, the entire disclosure of which is incorporated herein by this reference for all purposes.

In an example described below, a pressure barrier is provided between a feed-through bulkhead and a wireline anchor. This pressure barrier is a primary sealing element for the wireline conductors, with the feed-through bulkhead being a secondary pressure barrier for the conductors.

Dielectric grease is applied above the feed-through bulkhead to help prevent fluid ingress at the feed-through bulkhead. The dual pressure barrier creates a chamber for the dielectric grease to be retained, thus further helping the secondary pressure barrier (the feed-through bulkhead) to seal. In order to fill the dielectric grease chamber, a high pressure check valve is located about the primary pressure barrier, so that dielectric grease can be pumped in from the feed-through bulkhead and allow air to evacuate the chamber as the chamber is filled with the dielectric grease.

In an example described below, a torque weak point is provided at an output drive shaft between gearboxes and a bearing assembly of the electrical orienter. A failure of the torque weak point will result in the electrical orienter not rotating, but no part of the BHA is left downhole a result of the weak point failure.

The weak point consists of multiple shear keys which will shear if excessive torque is applied. Once sheared, no transfer of torque is experienced between upper and lower sections of the BHA, but both sections remain attached. In this event, the entire BHA is pulled from the well. The shear keys can be replaced, instead of replacing expensive gearbox/drive assembly components.

In one example described below, a flowtube is extended to sit within an upper check valve of the BHA. In addition, a non-magnetic lower check valve is connected above a mud motor. During normal operation, if the coiled tubing were to pinhole, crack or break, the upper check valve and/or the lower check valve will prevent reverse flow through the BHA and coiled tubing. The check valve can fail, in which case the entire BHA will remain intact, since the lower check valve contains locking flapper valves (for example, of the type marketed by Thru Tubing Solutions, Inc. of Newcastle, Oklahoma).

If the BHA becomes stuck in a wellbore, and the hydraulic disconnect is activated, the ball seat of the hydraulic disconnect will shift downhole to release the hydraulic disconnect and allow the check valve to close. This prevents the check valve from getting damaged during regular operation, but allowing it to be available when needed after activating the hydraulic disconnect.

The electrical orienter in one example is used with sensors for measuring weight-on-bit (WoB), torque-on-bit (ToB), downhole tubing pressure (DHTP), downhole annular pressure (DHAP) and other parameters (such as, vibration, temperature, etc.). The stand-alone electrical orienter has the capability of running single or multiple sensor packages below it. The electrical orienter and/or sensor packages can be operated with chassis or dedicated line ground/return.

In one example, a relay (e.g., a solenoid operated switch) can be included downhole (such as, connected to or part of, and activated by, a motor controller) to separate a brushless DC motor of the electrical orienter from ground. This keeps the motor chassis isolated from ground while injecting electrical current for active magnetic ranging. It allows for re-connecting the motor chassis to ground when not ranging.

A deviated flow path provides for fluid flow through the BHA. This enables the fluid flow to be used to operate a fluid motor to rotate a drill bit at a distal end of the BHA.

The flow path extends through an annular space formed between the sensor assembly and an outer housing surrounding the sensor assembly. The flow path also extends through a strain gauge assembly for measuring weight on bit and torque on bit.

The sensor assembly is connected to the conductors extending through the coiled tubing above the BHA. In this example, a dedicated return line is provided for the sensor assembly. Another of the conductors is provided for power and data communication. Thus, at least two conductors are connected to the sensor assembly, and these two conductors extend through the electrical orienter.

An electronics package includes a motor controller, which is connected to a brushless DC motor. The electronics package is also connected to the relay, which is operable to selectively connect and disconnect the motor chassis with ground. In this example, when the BHA is being used for ranging, the motor is disconnected from ground. The motor is reconnected to ground when it is desired to rotate the BHA below the orienter (for example, to change an orientation of the sensor assembly (e.g., including a magnetometer thereof), to change an orientation of a camera of the BHA to observe a lateral wellbore, to change a trajectory of a wellbore being drilled using the BHA (e.g., to change an orientation of a bent sub), or for another purpose).

Referring specifically now to FIG. 1, a partially cross-sectional view of a first example of a system 10 for use with a subterranean well, and an associated method, are representatively illustrated. In this example, it is desired to intercept an existing well 12. The well 12 may be used (or may have previously been used) to produce any type of fluid (such as, water, oil, gas, steam, etc.) for commercial municipal, agricultural, industrial, private or other purposes. However, the scope of this disclosure is not limited to equipment or procedures for intercepting an existing well.

The well 12 includes a wellbore 14 that penetrates a subterranean formation 16. The wellbore 14 in this example is substantially vertical, but in other examples the wellbore could be inclined relative to vertical. An upper portion of the wellbore 14 is lined with casing 18 and cement 20.

In order to increase production from the well 12, access the wellbore 14 downhole of an obstruction, or for other purposes, an offset well 22 is drilled to intersect the wellbore 14. The offset well 22 includes an offset wellbore 24 that is drilled so that it intersects the wellbore 14. Thus, the wellbore 14 is referred to herein as a “target” wellbore.

In the FIG. 1 example, the offset wellbore 24 is drilled using a coiled tubing rig 26. Continuous coiled tubing 28 is stored on a spool 30 at the surface. The coiled tubing 28 is deployed into the offset well 22 through an injector head 32 and blowout preventer stack 34. In other examples, other types of drilling rigs or other types of coiled tubing rigs may be used.

As depicted in FIG. 1, an upper portion of the offset wellbore 24 is substantially vertical, the offset wellbore bends or curves to a more horizontal orientation, and the offset wellbore extends substantially horizontally through the formation 16. In other examples, the upper portion of the offset wellbore 24 may be inclined from vertical, and the portion extending through the formation 16 may be inclined from horizontal. Thus, it will be appreciated that the scope of this disclosure is not limited to any particular details of the well system 10 as depicted in FIG. 1 or described herein.

In the FIG. 1 example, the offset wellbore 24 extends a substantial distance through the formation 16, thereby exposing a substantial surface area of the formation to the offset wellbore. The offset wellbore 24 intersects the target wellbore 14, and so the fluids produced from the formation surface area exposed to the offset wellbore 24 can be produced to the surface via the target wellbore 14.

As depicted in FIG. 1, the offset wellbore 24 intersects the target wellbore 14 in the formation 16. In other examples, it may be desirable for the offset wellbore 24 to intersect the target wellbore 14 in an earth formation other than the formation 16.

In the FIG. 1 example, the offset wellbore 24 extends substantially straight through the formation 16, and extends past the target wellbore 14. In other examples, the offset wellbore 24 may bend or curve in different directions in the formation 16 (for example, to follow a high quality zone of the formation, to follow a relatively high productivity channel in the formation, etc.).

To drill the offset wellbore 24 and steer it toward the target wellbore 14, a bottom hole assembly (BHA) 36 is connected at a distal end of the coiled tubing 28. In this example, the BHA 36 includes a drill bit 38, a mud motor 40, a steering tool 42, ranging equipment 44, and logging tools 46. Other tools or equipment, and other combinations of tools, may be used in other examples.

The logging tools 46 can include continuous gamma, resistivity, nuclear magnetic resonance and/or other types of logging tools. The outputs of the logging tools 46 may be used to determine how to steer the offset wellbore 24, so that it follows a high quality zone of the formation 16, so that it follows a relatively high productivity channel in the formation, etc. However, the scope of this disclosure is not limited to any particular purpose or combination of purposes for use of the logging tools 46.

The ranging equipment 44 may include equipment for active or passive ranging to the target wellbore 14. For example, the ranging equipment 44 could include a magnetometer, a rotating magnet, a current injection tool or another type of ranging equipment. The ranging equipment 44 is used in the FIG. 1 system to determine how to steer the offset wellbore 24, so that it intersects the target wellbore 14.

Ranging equipment 48 may also be used in the target wellbore 14. For example, the ranging equipment 48 could include a magnetometer (e.g., to detect a magnetic field produced from a rotating magnet of the ranging equipment 44 in the offset wellbore 24), a magnet, a current injection tool (e.g., to inject current into the casing 18 if it is near or at the desired wellbore intersection, or to inject current directly into the earth), or another type of ranging equipment.

Note that the drilling and ranging operations can be performed while the coiled tubing 28 remains in the offset wellbore 24. The drilling and ranging operations can be performed in a single trip of the coiled tubing 28 with the BHA 36 into the offset wellbore 24.

The steering tool 42 is used to steer the drill bit 38 and thereby steer the drilling of the offset wellbore 24. Various different types of steering tools are commercially available and known to those skilled in the art.

The BHA 36 can also include an electrical orienter tool to selectively rotate the BHA downhole of the orienter tool. The orienter tool can be used to rotate the ranging equipment 48 as desired relative to the target wellbore 14, or to direct the BHA 36 toward a selected lateral wellbore in some examples.

The fluid motor 40 is used to rotate the drill bit 38 and thereby drill the offset wellbore 24. Fluid circulated through the coiled tubing 28 causes the fluid motor 40 to rotate the drill bit 38. The fluid exits nozzles in the drill bit 38 and returns to the surface via an annulus formed between the wellbore 24 and the coiled tubing 28.

Referring additionally now to FIG. 2, an elevational view of another example of the bottom hole assembly 36 is representatively illustrated. For convenience, the FIG. 2 bottom hole assembly 36 is described below as it may be used in the FIG. 1 system 10 and method, but the FIG. 2 bottom hole assembly 36 may be used with other systems and methods in keeping with the scope of this disclosure. In this example, the bottom hole assembly 36 includes the drill bit 38, the fluid motor 40, a flex sub 50, a sensor package 52, an electrical orienter 54, a hydraulic disconnect 56, and a combined coiled tubing connector and cable head 58.

The head 58 is used to connect the bottom hole assembly 36 to the coiled tubing 28 with an armored cable 60 extending through the coiled tubing. The cable 60 comprises multiple insulated conductors, which are described more fully below.

The hydraulic disconnect 56 is conventional. A suitable hydraulic disconnect for use in the bottom hole assembly 36 is marketed by Thru Tubing Solutions, Inc. In this example, the hydraulic disconnect 56 includes an internal seat which is engaged by a plug (such as, a ball or a dart) deployed into the coiled tubing 28 from the surface. Pressure applied to the coiled tubing 28 creates a pressure differential across the plug and seat, thereby causing the seat to shift downhole and disconnecting an uphole section of the bottom hole assembly 36 from a downhole section of the bottom hole assembly.

The electrical orienter 54 includes an electric motor (not visible in FIG. 2) which, when activated, rotates a downhole section 54a of the orienter relative to an uphole section 54b of the orienter. In this manner, a downhole section of the bottom hole assembly 36 (e.g., from the orienter downhole section 54a to the drill bit 38) can be rotated relative to an uphole section of the bottom hole assembly (e.g., from the orienter uphole section 54b to the head 58).

The sensor package 52 includes a sensor assembly 62 contained in an outer housing 64. Multiple sensor packages 52 can be connected in the bottom hole assembly 36 downhole of the electrical orienter 54. The sensor assembly 62 can include the logging tools 46 and/or ranging equipment 44 described above.

The flex sub 50 aids in negotiating curved wellbore sections, or otherwise reducing stress concentrations in the bottom hole assembly 36. In this example, the flex sub 50 is made of non-magnetic materials, so that interference with active magnetic ranging (e.g., using the ranging equipment 44 of the sensor package 52) is minimized.

A flow path 66 extends completely longitudinally through the coiled tubing 28 and the bottom hole assembly 36. Fluid 68 can be circulated completely through the bottom hole assembly 36, for example, to cause the fluid motor 40 to rotate the drill bit 38 to further drill the wellbore 24.

Referring additionally now to FIG. 3, a more detailed cross-sectional view of an example of portions of the electrical orienter 54 and sensor package 52 is representatively illustrated. In this example, the flow path 66 converges from an annulus 70 to a central tube 72 in the electrical orienter 54. In the sensor package 52, the flow path 66 diverges into an annulus 74 formed radially between the outer housing 64 and the sensor assembly 62.

The electrical orienter 54 includes a sensor 76 disposed in an outer housing 78. The sensor 76 includes a generally tubular mandrel 80 surrounding the tube 72 in this example. Strain gauges 82 are attached to an outer surface of the mandrel 80.

A section of the mandrel 80 to which the strain gauges 82 are attached is isolated from pressure downhole by the tube 72 and the outer housing 78. In this manner, the strain gauges 82 can be used to measure torque (e.g., torque on bit) and longitudinal load (e.g., weight on bit), without the measurements being influenced by downhole pressure.

Referring additionally now to FIG. 4, a schematic view of an example of the electrical orienter 54 with multiple sensor packages 52 is representatively illustrated. The FIG. 4 electrical orienter 54 and sensor packages 52 may be used with any of the bottom hole assembly 36 examples described herein.

In the FIG. 4 example, the armored cable 60 includes multiple insulated electrical conductors 82, 84. Although only two conductors 82, 84 are depicted in FIG. 4, the armored cable 60 may include any number of the conductors.

At the surface, the conductor 82 is connected to electrical ground 86. The conductor 84 is connected to surface instrumentation 88, for example, for recording, processing and analyzing measurements output by the sensor packages 52.

Each of the sensor packages 52 is connected to the conductors 82, 84. The conductor 84 is used in this example for delivering electrical power to the electrical orienter 54 and the sensor packages 52, and for communication between the sensor packages and the surface instrumentation 88. The conductor 82 provides for a selected electrical potential relative to the conductor 84.

The electrical orienter 54 includes an electric motor 90 for rotating the downhole section 54a relative to the uphole section 54b (see FIG. 2). An electronics package 92 controls operation of the motor 90. The electronics package 92 is connected to the conductors 82, 84 for communication with, and supply of electrical power from, the surface.

In this example, the electronics package 92 is used in part to operate an electrical switch 94. The switch 94 is activated by the electronics package 92, depending on whether the sensor packages 52 are being used to obtain measurements downhole. More specifically, an electrically conductive chassis 96 of the motor 90 is connected via the switch 94 to ground 86 via the conductor 82 only when the sensor packages 52 are not being used to obtain measurements downhole. In this manner, the measurements are not affected by operation of, or electromagnetic interference or noise generated by, the motor 90.

Referring additionally now to FIG. 5, an elevational view of another example of the bottom hole assembly 36 is representatively illustrated. The bottom hole assembly 36 may be used in the FIG. 1 system 10 and method, or it may be used with other systems and methods.

In the FIG. 5 example, the bottom hole assembly 36 includes a check valve 98, the flex sub 50, multiple sensor packages 52, the electrical orienter, the hydraulic disconnect 56, a check valve 100, the cable head 58 and a coiled tubing connector 102. The fluid motor 40 and the drill bit 38 are not depicted in FIG. 5, but they would typically be connected downhole of the check valve 98 in this example.

Each of the check valves 98, 100 permit flow through the flow path 66 (see FIG. 2) in a downhole direction (e.g., from the connector 102 to the drill bit 38), but prevent flow in an uphole direction through the flow path. The check valve 98 prevents reverse flow into the bottom hole assembly 36, and the check valve 100 prevents reverse flow into the coiled tubing 28 in the event the hydraulic disconnect 56 is actuated.

In the FIG. 5 example, the cable head 58 is used to anchor the armored cable 60, and to connect the conductors 82, 84 to the bottom hole assembly 36. The cable head 58 maintains electrical isolation between the conductors and from conductive materials in the bottom hole assembly 36.

Referring additionally now to FIG. 6, an elevational view of an example of the electrical orienter 54 is representatively illustrated. Only the uphole section 54b of the electrical orienter 54 is depicted in FIG. 6.

A shaft 104 extends outward from the uphole section 54b of the orienter 54. The shaft 104 is rotated by the motor 90 (see FIG. 4). The flow path 66 (see FIG. 2) extends through the shaft 104. Multiple connectors 106 are provided at a lower end of the shaft 104 for the conductors 82, 84 (see FIG. 4).

Referring additionally now to FIGS. 7 & 8, cross-sectional views of an example of a section of the cable head 58 are representatively illustrated. In this view, the manner in which the armored cable 60 is anchored to the cable head 58, the conductors 82, 84 are connected, and the flow path 66 extends through the cable head can be seen.

A cable anchor 108 is used to secure the armored cable 60 in the cable head 58. The conductors 82, 84 extend from the armored cable 60 to a pressure isolating connector 110 in a primary bulkhead 112 of the cable head 58.

The bulkhead 112 seals between an outer housing 114 and a central flow tube 116 through which the flow path 66 extends. In this example, the bulkhead 112 and the flow tube 116 are integrally formed, but in other examples the bulkhead and the flow tube could be separately formed.

Another feed-through bulkhead 118 seals between the flow tube 116 and the outer housing 114. Multiple electrical feed-throughs 120 are installed in the bulkhead 118 to provide for electrically isolated extension of the conductors 82, 84 through the bulkhead.

An annular chamber 122 is isolated axially between the bulkheads 112, 118 and radially between the outer housing 114 and the flow tube 116. Preferably, the chamber 122 is filled with dielectric grease to prevent fluid incursion and to enhance the seals of the bulkheads 112, 118, connector 110 and feed-throughs 120.

A grease injection port 124 is provided in the feed-through bulkhead 118 for injecting the dielectric grease into the chamber 122. A check valve 126 in the bulkhead 112 allows air to escape from the chamber 122 as the dielectric grease fills the chamber.

Referring additionally now to FIG. 9, a cross-sectional view of an example of a section of the check valve 100 is representatively illustrated. In this example, the check valve 100 is initially maintained in an open position, in which flow is permitted in both longitudinal directions through the flow path 66, until the hydraulic disconnect 56 is actuated, at which point flow in the uphole direction is prevented.

As depicted in FIG. 9, a flapper 128 is pivotably mounted relative to an annular seat 130. A spring (not visible in FIG. 9) biases the flapper 128 to pivot toward and seal against the seat 130 to prevent flow through the flow path 66 in the uphole direction.

A flow tube 132 has an upper end that engages the flapper 128 and prevents the flapper from pivoting toward the seat 130. The flow tube 132 is connected to a tubular mandrel 134 that extends into the hydraulic disconnect 56 connected downhole of the check valve 100.

When the hydraulic disconnect 56 is actuated, the mandrel 134 and the flow tube 132 are displaced downhole with the plug seat in the hydraulic disconnect. The downward displacement of the flow tube 132 permits the flapper 128 to pivot upward toward the seat 130, thereby preventing fluid flow in the uphole direction through the flow path 66.

Preferably, the check valve 100 is made entirely, or substantially exclusively, of non-magnetic material. In this manner, the check valve 100 does not interfere with ranging equipment 44 of the bottom hole assembly 36.

Referring additionally now to FIG. 10, a perspective view of the check valve 100 is representatively illustrated, with an outer housing 136 of the check valve removed. In this view a manner in which the conductors 82, 84 extend through the check valve 100 can be seen.

Multiple feed-throughs 138 are installed in an upper bulkhead 140. Further feed-throughs 142 are installed in a lower housing 144. The conductors 82, 84 are connected between the feed-throughs 138, 142.

Referring additionally now to FIGS. 11 & 12, cross-sectional views of an example of a torque weak point section of the electrical orienter 54 is representatively illustrated. In this example, the electrical orienter 54 includes a torque weak point 146 connected downhole from the motor 90 (see FIG. 40).

A shaft 148 of the torque weak point 146 is driven by the motor 90. One or more gearboxes may be connected between the motor 90 and the torque weak point 146. The flow path 66 extends through the shaft 148.

In the FIGS. 11 & 12 example, the torque weak point 146 includes multiple circumferentially distributed shear keys 150 received in an upper end of the shaft 148. Torque applied to the shaft 148 is transmitted through the shear keys 150, which tends to shear the shear keys.

A connector 152 is rotatable in an outer housing 154. When a predetermined shear level is reached, the keys 150 will shear, thereby preventing transmission of torque from the motor 90 to the bottom hole assembly 36 downhole of the electrical orienter 54 via the connector 152.

It may now be fully appreciated that the above disclosure provides significant advancements to the art of selectively orienting a bottom hole assembly in a wellbore. In examples described above, the electrical orienter 54 can be used to orient ranging equipment 44 and other types of sensor packages 52 in the wellbore 24. Multiple sensor packages 52 can be connected downhole of the electrical orienter 54, with multiple conductors 82, 84 extending through the orienter to the sensor packages. The bottom hole assembly 36 can be used for logging, ranging and drilling, in a single trip of the bottom hole assembly into the wellbore 24.

The above disclosure provides to the art a system 10 and method, in which an electrically-powered orienter 54 is connected in a coiled tubing 28 conveyed BHA 36, the electrical orienter having multiple conductors 82, 84 connected to at least one sensor package 52 downhole of the orienter. Each of the multiple conductors 82, 84 may be isolated from ground in the wellbore 24. The multiple conductors 82, 84 may be connected to multiple sensor packages 52 downhole of the orienter 54.

Multiple pressure barriers (e.g., bulkheads 112, 118) may be disposed between a wireline anchor 108 and a feed-through bulkhead 118. A torque weak point 146 may fail if a torque output of a motor 90 assembly (e.g., including any gearboxes, etc.) exceeds a predetermined level.

A non-magnetic check valve 100 may be connected uphole of a fluid motor 40 in the BHA 36. The electrical orienter 54 may include a DC motor 90 and a relay or switch 94 that selectively isolates a chassis 96 of the motor 90 from ground in the orienter.

In another aspect described above, an electrically-powered orienter 54 is connected in a coiled tubing 28 conveyed BHA 36. The orienter 54 includes a DC motor 90 and a relay or switch 94 that selectively isolates a chassis 96 of the motor from ground in the orienter.

A bottom hole assembly 36 for use with a subterranean well is disclosed herein. In one example, the bottom hole assembly 36 comprises: a cable head 58 configured to connect the bottom hole assembly 36 to a cable 60 in a coiled tubing 28; multiple sensor packages 52, each of the sensor packages 52 being configured to measure respective parameters downhole; an electrical orienter 54 configured to rotate the sensor packages 52 downhole; and multiple conductors 82, 84, each of the conductors 82, 84 extending between the cable head 58 and the sensor packages 52 via the electrical orienter 54.

The electrical orienter 54 may be connected uphole of the sensor packages 52. The sensor packages 52 may comprise ranging equipment 44. The electrical orienter 54 may be configured to rotate the ranging equipment 44.

The cable head 58 may comprise multiple pressure barriers 112, 118 that isolate an annular chamber 122. The annular chamber 122 may contain a dielectric grease.

The annular chamber 122 may be formed between an outer housing 114 and a flow tube 116 in the outer housing 114. The flow tube 116 may surround a flow path 66 that extends through the cable head 58 and the electrical orienter 54.

The electrical orienter 54 may comprise a torque weak point 146. The torque weak point 146 may be configured to fail at a predetermined torque output by a motor 90 of the electrical orienter 54.

The bottom hole assembly 36 may include a check valve 100 connected between the sensor packages 52 and a fluid motor 40. The check valve 100 may be configured to prevent fluid flow through a flow path 66 from the fluid motor 40 to the sensor packages 52. The bottom hole assembly of claim 8, in which the check valve 100 may consist essentially of non-magnetic material.

The electrical orienter 54 may include a motor 90 having a conductive chassis 96, and a switch 94 that selectively connects the chassis 96 to electrical ground 86 via one of the conductors 82. The electrical orienter 54 may include an electronics package 92 configured to selectively operate the switch 94 based on an activation state of the sensor packages 52. The electronics package 92 may be further configured to disconnect the motor chassis 96 from electrical ground 86 when at least one of the sensor packages 52 is activated.

A method for use in a subterranean well is also provided to the art by the above disclosure. In one example, the method comprises: connecting a bottom hole assembly 36 to a coiled tubing 28, the bottom hole assembly 36 comprising an electrical orienter 54, a sensor package 52 including ranging equipment 44, a fluid motor 40 and a drill bit 38; deploying the coiled tubing 28 and the bottom hole assembly 36 into the well; activating the electrical orienter 54 to rotate the ranging equipment 44; and then drilling an offset wellbore 24 toward a target wellbore 14 located using the ranging equipment 44.

The activating and the drilling steps may be performed in a single trip of the bottom hole assembly 36 into the well. The drilling step may include flowing a fluid 68 through a flow path 66 extending through the electrical orienter 54, the sensor package 52, the fluid motor 40, and the drill bit 38.

The electrical orienter 54 may include an electric motor 90. The method may include disconnecting the electric motor 90 from electrical ground 86. The disconnecting step may be performed in response to activating the sensor package 52. The disconnecting step may be performed in response to activating the ranging equipment 44.

The method may include connecting a check valve 100 between the fluid motor 40 and the electrical orienter 54 in the bottom hole assembly 36. The check valve 100 may consist essentially of non-magnetic material.

The electrical orienter 54 may include a torque weak point 146. The torque weak point 146 may be configured to fail at a predetermined torque output by an electric motor 90 of the electrical orienter 54.

The above disclosure also provides to the art an electrical orienter 54 for use in a subterranean well. In one example, the electrical orienter 54 can comprise: an electric motor 90 configured to rotate a first section 54a of the electrical orienter relative to a second section 54b of the electrical orienter; a flow path 66 extending completely longitudinally through the electrical orienter 54; and multiple conductors 82, 84 extending completely longitudinally through the electrical orienter 54.

All of the multiple conductors 82, 84 may be isolated from an outer housing 78 of the electrical orienter 54.

The electrical orienter 54 may include a switch 94 connected between one of the conductors 82 and a conductive chassis 96 of the electric motor 90. The electrical orienter 54 may include an electronics package 92 configured to activate the switch 94 to disconnect the motor chassis 96 from the one of the conductors 82 when a sensor package 52 is activated.

Although various examples have been described above, with each example having certain features, it should be understood that it is not necessary for a particular feature of one example to be used exclusively with that example. Instead, any of the features described above and/or depicted in the drawings can be combined with any of the examples, in addition to or in substitution for any of the other features of those examples. One example's features are not mutually exclusive to another example's features. Instead, the scope of this disclosure encompasses any combination of any of the features.

Although each example described above includes a certain combination of features, it should be understood that it is not necessary for all features of an example to be used. Instead, any of the features described above can be used, without any other particular feature or features also being used.

It should be understood that the various embodiments described herein may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of this disclosure. The embodiments are described merely as examples of useful applications of the principles of the disclosure, which is not limited to any specific details of these embodiments.

In the above description of the representative examples, directional terms (such as “above,” “below,” “upper,” “lower,” “upward,” “downward,” etc.) are used for convenience in referring to the accompanying drawings. However, it should be clearly understood that the scope of this disclosure is not limited to any particular directions described herein.

The terms “including,” “includes,” “comprising,” “comprises,” and similar terms are used in a non-limiting sense in this specification. For example, if a system, method, apparatus, device, etc., is described as “including” a certain feature or element, the system, method, apparatus, device, etc., can include that feature or element, and can also include other features or elements. Similarly, the term “comprises” is considered to mean “comprises, but is not limited to.”

Of course, a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the disclosure, readily appreciate that many modifications, additions, substitutions, deletions, and other changes may be made to the specific embodiments, and such changes are contemplated by the principles of this disclosure. For example, structures disclosed as being separately formed can, in other examples, be integrally formed and vice versa. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example only, the spirit and scope of the invention being limited solely by the appended claims and their equivalents.

Claims

1. A bottom hole assembly for use with a subterranean well, the bottom hole assembly comprising: a cable head configured to connect the bottom hole assembly to a cable in a coiled tubing;multiple sensor packages, each of the sensor packages being configured to measure respective parameters downhole;an electrical orienter configured to rotate the sensor packages downhole; andmultiple conductors, each of the conductors extending between the cable head and the sensor packages via the electrical orienter.

2. The bottom hole assembly of claim 1, in which the electrical orienter is connected uphole of the sensor packages.

3. The bottom hole assembly of claim 1, in which the sensor packages comprise ranging equipment, and in which the electrical orienter is configured to rotate the ranging equipment.

4. The bottom hole assembly of claim 1, in which the cable head comprises multiple pressure barriers that isolate an annular chamber, and in which the annular chamber contains a dielectric grease.

5. The bottom hole assembly of claim 4, in which the annular chamber is formed between an outer housing and a flow tube in the outer housing.

6. The bottom hole assembly of claim 5, in which the flow tube surrounds a flow path that extends through the cable head and the electrical orienter.

7. The bottom hole assembly of claim 1, in which the electrical orienter comprises a torque weak point, the torque weak point being configured to fail at a predetermined torque output by a motor of the electrical orienter.

8. The bottom hole assembly of claim 1, further comprising a check valve connected between the sensor packages and a fluid motor.

9. The bottom hole assembly of claim 8, in which the check valve is configured to prevent fluid flow through a flow path from the fluid motor to the sensor packages.

10. The bottom hole assembly of claim 8, in which the check valve consists essentially of non-magnetic material.

11. The bottom hole assembly of claim 1, in which the electrical orienter comprises a motor having a conductive chassis, and a switch that selectively connects the chassis to electrical ground via one of the conductors.

12. The bottom hole assembly of claim 11, in which the electrical orienter comprises an electronics package, and the electronics package is configured to selectively operate the switch based on an activation state of the sensor packages.

13. The bottom hole assembly of claim 12, in which the electronics package is further configured to disconnect the motor chassis from electrical ground when at least one of the sensor packages is activated.

14. A method for use in a subterranean well, the method comprising: connecting a bottom hole assembly to a coiled tubing, the bottom hole assembly comprising an electrical orienter, a sensor package including ranging equipment, a fluid motor and a drill bit;deploying the coiled tubing and the bottom hole assembly into the well;activating the electrical orienter to rotate the ranging equipment; andthen drilling an offset wellbore toward a target wellbore located using the ranging equipment.

15. The method of claim 14, in which the drilling comprises flowing a fluid through a flow path extending through the electrical orienter, the sensor package, the fluid motor, and the drill bit.

16. The method of claim 14, in which the electrical orienter comprises an electric motor, and further comprising disconnecting the electric motor from electrical ground.

17. The method of claim 16, in which the disconnecting is performed in response to activating the sensor package.

18. The method of claim 16, in which the disconnecting is performed in response to activating the ranging equipment.

19. The method of claim 14, further comprising connecting a check valve between the fluid motor and the electrical orienter in the bottom hole assembly.

20. The method of claim 19, in which the check valve consists essentially of non-magnetic material.

21. The method of claim 14, in which the electrical orienter comprises a torque weak point, the torque weak point being configured to fail at a predetermined torque output by an electric motor of the electrical orienter.

22. The method of claim 14, in which the activating and the drilling are performed in a single trip of the bottom hole assembly into the well.

23. An electrical orienter for use in a subterranean well, the electrical orienter comprising: an electric motor configured to rotate a first section of the electrical orienter relative to a second section of the electrical orienter;a flow path extending completely longitudinally through the electrical orienter; andmultiple conductors extending completely longitudinally through the electrical orienter.

24. The electrical orienter of claim 23, in which all of the multiple conductors are isolated from an outer housing of the electrical orienter.

25. The electrical orienter of claim 23, further comprising a switch connected between one of the conductors and a conductive chassis of the electric motor.

26. The electrical orienter of claim 25, further comprising an electronics package configured to activate the switch to disconnect the motor chassis from the one of the conductors when a sensor package is activated.

27. The electrical orienter of claim 23, further comprising a torque weak point configured to fail at a predetermined torque output by the electric motor.