HYDRAULICALLY ACTUATED TOOL WITH ELECTRICAL THROUGHBORE
A bottom hole assembly includes a drill string, a bit coupled to an end of the drill string, a rotary steerable system coupled to the drill string above the bit, a hydraulically actuated tool assembly coupled to the drill string above the rotary steerable system, and an electrically controlled tool coupled to the drill string above the hydraulically actuated tool assembly and electrically coupled to the rotary steerable system. A method includes running a bottom hole assembly downhole, the bottom hole assembly including a drill bit, a rotary steerable system, an electrically controlled tool, and a hydraulically actuated tool assembly disposed between the rotary steerable system and the electrically controlled tool. The method includes cutting a formation with the drill bit, actuating the hydraulically actuated tool assembly, and maintaining an electrical connection between the rotary steerable system and the electrically controlled tool during the running, the cutting, and the actuating.
The present application claims priority to U.S. Provisional Application 61/909,456, filed Nov. 27, 2013, the entirety of which is incorporated by reference.
FIELD OF THE INVENTIONAspects relate to downhole drilling operations. More specifically, aspects relate to a hydraulically actuated tool with electrical throughbore.
BACKGROUNDDownhole drilling operations commonly require a downhole tool to be actuated after the tool has been deployed in the borehole. For example, underreamers are commonly tripped into the borehole in a collapsed state (i.e., with the cutting structures retracted into the underreamer tool body). At some predetermined depth, the underreamer is actuated such that the cutting structures expand radially outward from the tool body. Hydraulic actuation mechanisms are used in oilfield services operations and are commonly employed in such operations.
For example, one hydraulic actuation methodology involves wireline retrieval of a plug (or “dart”) through the interior of the drill string to enable differential hydraulic pressure to actuate an underreamer. Upon completion of the reaming operation, the underreamer may be deactuated by redeploying the dart. While commercially serviceable, such wireline actuation and deactuation is both expensive and time-consuming in that it requires concurrent use of wireline or slickline assemblies.
Another commonly used hydraulic actuation methodology makes use of shear pins configured to shear at a specific differential pressure (or in a predetermined range of pressures). Ball drop mechanisms are also known in the art, in which a ball is dropped down through the drill string to a ball seat. Engagement of the ball with the seat typically causes an increase in differential pressure which in turn actuates the downhole tool. The tool may be deactuated by increasing the pressure beyond a predetermined threshold such that the ball and ball seat are released (e.g., via the breaking of shear pins). While such sheer pin and ball drop mechanisms are also commercially serviceable, they are generally one-time or one-cycle mechanisms and do not allow for repeated actuation and deactuation of a downhole tool.
Various other hydraulic actuation mechanisms make use of measurement while drilling (MWD), logging while drilling (LWD) and/or other electronically controllable systems including, for example, computer controllable solenoid valves and the like. Electronic actuation advantageously enables a wide range of actuation and deactuation instructions to be executed and may further enable two-way communication with the surface (e.g., via conventional telemetry techniques). However, these actuation systems tend to be highly complex and expensive and can be limited by the reliability and accuracy of MWD, telemetry, and other electronically controllable systems deployed in the borehole.
SUMMARYIn one aspect, embodiments disclosed herein relate to a tool assembly that includes a tool body configured to connect with a drill string, a mandrel disposed in the tool body, a piston assembly disposed in the mandrel, and a spring member disposed in the tool body and configured to bias the piston assembly towards a first axial position. The piston assembly has a throughbore and includes a valve piston and a cam piston configured to reciprocate axially in the mandrel. The tool assembly further includes a tubular disposed in the tool body and the throughbore of the piston assembly. The tubular is configured to carry an electrical wire.
In another aspect, embodiments disclosed herein relate to a bottom hole assembly that includes a drill string, a bit coupled to an end of the drill string, a rotary steerable system coupled to the drill string axially above the bit, a hydraulically actuated tool assembly coupled to the drill string axially above the rotary steerable system, and an electrically controlled tool coupled to the drill string axially above the hydraulically actuated tool assembly. The electrically controlled tool is electrically coupled to the rotary steerable system.
In another aspect, embodiments disclosed herein relate to a method including running a bottom hole assembly downhole, the bottom hole assembly including a drill bit, a rotary steerable system, an electrically controlled tool, and a hydraulically actuated tool assembly disposed between the rotary steerable system and the electrically controlled tool. The method further includes cutting a formation with the drill bit, actuating the hydraulically actuated tool assembly, and maintaining an electrical connection between the rotary steerable system and the electrically controlled tool during the running, the cutting, and the actuating.
In another aspect, embodiments disclosed herein relate to a method including running a bottom hole assembly downhole, the bottom hole assembly including a drill bit, a rotary steerable system a hydraulically actuated reamer tool assembly, a measurement-while drilling/logging-while-drilling (MWD/LWD) tool, and a reamer. The method further includes dropping an activation ball into the bottom hole assembly and actuating the reamer, cutting a formation with the drill bit and the reamer, the cutting the formation forming a rathole between the drill bit and the reamer, and deactuating the reamer and pulling the BHA upward to position the reamer tool assembly proximate the top of the rathole. The method further includes activating the reamer tool assembly and cutting the rathole with the reamer tool assembly, the running, dropping, cutting the formation, deactuating, actuating, and the cutting the rathole being performed while maintaining electrical connection between the rotary steerable system and the MWD/LWD.
This summary is provided to introduce a selection of concepts that are further described below in the detailed description. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.
Embodiments disclosed herein generally relate to a bottom hole assembly (BHA). More specifically, embodiments disclosed herein relate to a bottom hole assembly including a power drive and a reamer. A bottom hole assembly in accordance with embodiments described herein may include a reamer that allows electrical communication through a central throughbore of the reamer, for example, from a power drive to an electrically controlled or actuated tool, such as a measurement-while-drilling (MWD) and/or logging-while-drilling (LWD) tool, or a caliper tool.
As used herein, a MWD/LWD tool(s) refers to a MWD tool and/or a LWD tool. The MWD/LWD tool may include one or more individual tools. The MWD/LWD tool may evaluate physical properties including, for example, pressure, temperature, and wellbore trajectory, and formation parameters, such as resistivity, porosity, and sonic velocity, as the tool is run downhole. This information may be stored and/or transmitted to the surface by any method known in the art, for example, by wireline.
During a drilling operation, drilling fluid (commonly referred to as “mud” in the art) is pumped downward through the drill string 70 and the bottom hole assembly (BHA) where it emerges at or near the drill bit 72 at the bottom of the borehole. The mud serves several purposes, for example, including cooling and lubricating the drill bit, clearing cuttings away from the drill bit and transporting them to the surface, and stabilizing and sealing the formation(s) through which the borehole traverses. The discharged mud, along with the borehole cuttings and sometimes other borehole fluids, then flow upwards through the annulus 82 (the space between the drill string 70 and the borehole wall) to the surface. In some embodiments of the present disclosure, the tool assembly 100 makes use of the differential pressure between an internal flow channel and the annulus to selectively actuate and deactuate certain tool functionality (e.g., the radial extension of a cutting structure outward from a tool body).
It will be understood by those of ordinary skill in the art that the configuration illustrated in
Referring now to
As shown in
In one embodiment of the present disclosure, tool assembly 100 may include an underreamer configured for selective hydraulic actuation and deactuation. By actuate and deactuate (or activate and deactivate) it is meant that the reamer cutting structures 105 (referred to herein as blades or blocks) may be extended radially outward from the tool body 110 and retracted radially inward towards (or into) the tool body 110.
It will be understood that tool assembly embodiments in accordance with the present disclosure are not limited to underreamers such as depicted on
One example of a tool assembly that may be used in accordance with embodiments disclosed herein is shown and disclosed in U.S. application Ser. No. 13/112,326 (U.S. Publication No. 2011/0284233), which is incorporated herein by reference in its entirety.
The piston assembly 200 is configured to reciprocate between a first low flow position and second and third high (or full) flow positions. In the low flow position, the spring force urges (biases) the assembly 200 in the uphole direction such that an uphole engagement face 245 engages internal shoulder 224 of sub body 120 (as shown in
With continued reference to
Referring back to
In other embodiments, as shown in
Tubular 290 includes a throughbore 273 configured to carry or house an electrical wire or cable extending from one end of the tool assembly 100 to an opposite end of the tool assembly 100. The electrical wire or cable may connect electrical components disposed on the drill string at opposite ends of the tool assembly 100. For example, referring back to
Referring now to
As shown in
With reference to
Downhole tool actuation and deactuation is described in detail in U.S. application Ser. No. 13/112,326 (U.S. Publication No. 2011/0284233). In general, a hydraulically actuated tool assembly as described herein may be selectively switched between the three aforementioned modes of operation. In one embodiment, changing the drilling fluid flow rate to a low flow state and then back to a high (or full) flow state changes actuation modes (from deactivated to activated or from activated to deactivated). This may be accomplished, for example, via cycling the mud pumps off and then back on. In other embodiments, such cycling of the mud pumps may be insufficient to activate or deactivate the downhole tool, and therefore the mud pumps may be cycled substantially any number of times without changing the tool mode (i.e., without activating or deactivating the downhole tool). As described in more detail below, actuation (or deactuation) of the tool assembly may include a fourth mode, referred to herein as an indexing mode that makes use of a corresponding index (indexing) flow.
In
Despite valve piston 210 being urged downhole with cam piston 240, ports 416 remain sealingly engaged with the inner surface 371 of mandrel sleeve 370 (i.e., such that they are axially misaligned with ports 385). Ports 418 also remain sealingly engaged with the inner surface 381 of mandrel 380. Moreover, as also depicted the mandrel ports 385 remain sealingly engaged with the outer surface 411 of valve piston 210. Therefore, the downhole tool remains inactive (in the deactuated state) while substantially full flow is provided through the bore, for example, to a drill bit for a drilling operation.
As described above, cycling the mud pumps between high and low flow is insufficient to activate and deactivate the downhole tool. The mud pumps may be cycled substantially any number of times such that the tool cycles between the first and second operational modes depicted on
The guide pins 327 are initially located in a lower axial end portion 464b of the cam groove that is circumferentially aligned with a cam slot 484. Increased flow urges the cam piston 240 downward causing the guide pins 327 to travel along the groove 465 to upper axial end portion 462a. Movement of the cam piston 240 past the guide pins 327 rotates the cam through an angle of 45 degrees in the embodiment shown such that the guide pin(s) 327 align with cam shoulders 482 (see
In the embodiment shown, actuation of the downhole tool may be effected by indexing the cam such that the guide pins 327 move from one axial end portion of the cam groove to an adjacent axial end portion (from end portion 462a to end portion 462b or from end portion 462b to end portion 462a). This may be accomplished by (i) decreasing the flow rate from high flow to low flow thereby returning the tool to the first mode as depicted on
As discussed above, a tool assembly in accordance with embodiments of the present disclosure provides hydraulic actuation of the tool assembly while simultaneously providing electrical communication through the throughbore of the tool assembly. Therefore, a tool assembly in accordance with embodiments disclosed herein may allow for various configurations of a BHA that may provide an improved rate of penetration, reduced drilling costs, and faster drill times.
For example, in one embodiment, the tool assembly 300 of
In one embodiment, BHA 333 of
BHA 333 of
In the embodiment shown in
One of ordinary skill in the art will appreciate that a hydraulically actuated tool assembly including a tubular extending through a central bore of the tool assembly and configured to carry or house an electrical wire or cable in accordance with embodiments disclosed herein may be disposed at various locations in a BHA. For example, in some embodiments, the hydraulically actuated tool assembly may be disposed above a MWD/LWD tool. A hydraulically actuated tool assembly as described herein may include a caliper measurement tool, a reamer, a stabilizer, or any downhole tool having actuatable (extendable) arms.
One of ordinary skill in the art will appreciate that other hydraulically actuated tools similar to that described with respect to
With reference to
The reamer tool assembly 300 may include one or more reamer blocks 597 having two reamer blades 594 disposed, as shown in
Embodiments disclosed herein may provide a hydraulically actuated tool assembly that allows electrical communication through a throughbore of the tool assembly. Thus, embodiments disclosed herein may provide a tool assembly that may be positioned between electrically connected components of a bottom hole assembly. Further, embodiments disclosed herein may provide a reamer tool assembly that may provide for a reduced rathole during drilling operations.
Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from scope of the present disclosure. Accordingly, all such modifications are intended to be included within the scope of this disclosure and the following claims. In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures. Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.
Claims
1. A tool assembly comprising:
- a tool body configured to connect with a drill string;
- a mandrel disposed in the tool body;
- a piston assembly disposed in the mandrel, the piston assembly having a throughbore and including a valve piston and a cam piston configured to reciprocate axially in the mandrel;
- a spring member disposed in the tool body and configured to bias the piston assembly towards a first axial position; and
- a tubular disposed in the tool body and the throughbore of the piston assembly, the tubular having a throughbore configured to carry an electrical wire.
2. The tool assembly of claim 1, further comprising a first locking apparatus disposed at an upper end and a second locking apparatus disposed at a lower end, the first and second locking apparatus configured to secure the tubular within the tool assembly.
3. The tool assembly of claim 2, wherein the first locking apparatus and the second locking apparatus each include a locking sleeve.
4. The tool assembly of claim 2, wherein the first locking apparatus and the second locking apparatus each include a jam nut.
5. The tool assembly of claim 1, wherein the tubular comprises a centralizer coupled to an outer surface of the tubular and extending radially therefrom.
6. The tool assembly of claim 5, wherein a portion of the tubular radially adjacent the piston assembly is free of the centralizer.
7. The tool assembly of claim 1, further comprising at least one reamer blade coupled to the tool body and configured to extend radially therefrom.
8. A bottom hole assembly comprising:
- a drill string;
- a bit coupled to an end of the drill string;
- a rotary steerable system coupled to the drill string axially above the bit;
- a hydraulically actuated tool assembly coupled to the drill string axially above the rotary steerable system; and
- an electrically controlled tool coupled to the drill string axially above the hydraulically actuated tool assembly, the electrically controlled tool electrically coupled to the rotary steerable system.
9. The bottom hole assembly of claim 8, wherein the electrically controlled tool is a measurement-while-drilling/logging-while-drilling (MWD/LWD) tool.
10. The bottom hole assembly of claim 8, further comprising a reamer coupled to the drill string axially above the electrically controlled tool.
11. The bottom hole assembly of claim 8, wherein the hydraulically actuated tool assembly comprises a tubular disposed in a central throughbore of the hydraulically actuated tool assembly and extending from proximate a first end of the hydraulically actuated tool assembly to proximate a second end of the hydraulically actuated tool assembly.
12. The bottom hole assembly of claim 11, further comprising an electrical wire coupled at a first end to the rotary steerable system, extending through the tubular, and coupled at a second end to the electrically controlled tool.
13. The bottom hole assembly of claim 8, wherein the hydraulically actuated tool assembly is a reamer.
14. The bottom hole assembly of claim 8, wherein the hydraulically actuated tool assembly is a caliper measurement tool.
15. The bottom hole assembly of claim 8, wherein the hydraulically actuated tool assembly is a stabilizer when in a deactuated mode and a reamer when in an actuated mode.
16. A method comprising:
- running a bottom hole assembly downhole, the bottom hole assembly including a drill bit, a rotary steerable system, an electrically controlled tool, and a hydraulically actuated tool assembly disposed between the rotary steerable system and the electrically controlled tool;
- cutting a formation with the drill bit;
- actuating the hydraulically actuated tool assembly; and
- maintaining an electrical connection between the rotary steerable system and the electrically controlled tool during the running, the cutting, and the actuating.
17. The method of claim 15, wherein the maintaining the electrical connection between the rotary steerable system and the electrically controlled tool comprises running an electrical wire through a tubular disposed within the hydraulically actuated tool assembly and coupling the electrical wire to the rotary steerable system and the electrically controlled tool.
18. The method of claim 16, further comprising stabilizing the tubular within the hydraulically actuated tool assembly with at least one centralizer.
19. The method of claim 15, wherein the bottom hole assembly further includes a reamer disposed above the electrically controlled tool and wherein the hydraulically actuated tool assembly includes at least one radially actuated reamer blade, the method further comprising:
- dropping an activation ball into the bottom hole assembly and actuating the reamer;
- cutting the formation with the reamer, the cutting the formation with the drill bit and the cutting the formation with the reamer forming a rathole between drill bit and the reamer;
- deactuating the reamer and pulling the BHA upward to position the hydraulically actuated tool assembly proximate the top of the rathole;
- activating the tool assembly; and
- cutting the rathole with the at least one radially actuated reamer blade of the hydraulically actuated tool assembly,
- wherein the electrical connection is maintained during the dropping, the cutting the formation with the reamer, the deactuating, the activating, and the cutting the rathole.
20. A method comprising:
- running a bottom hole assembly downhole, the bottom hole assembly including a drill bit, a rotary steerable system, a hydraulically actuated reamer tool assembly, a measurement-while-drilling/logging-while-drilling (MWD/LWD) tool, and a reamer;
- dropping an activation ball into the bottom hole assembly and actuating the reamer;
- cutting a formation with the drill bit and the reamer, the cutting the formation forming a rathole between the drill bit and the reamer;
- deactuating the reamer and pulling the BHA upward to position the reamer tool assembly proximate the top of the rathole;
- activating the reamer tool assembly; and
- cutting the rathole with the reamer tool assembly, the running, dropping, cutting the formation, deactuating, actuating, and cutting the rathole being performed while maintaining electrical connection between the rotary steerable system and the MWD/LWD tool.
Type: Application
Filed: Nov 24, 2014
Publication Date: May 28, 2015
Inventors: Mahavir Nagaraj (Spring, TX), John Michael Aubin (Cypress, TX), Renato Pereira (Layfayette, LA), Bhushan Pendse (League City, TX), Francesco Vaghi (Houston, TX)
Application Number: 14/552,187
International Classification: E21B 7/04 (20060101); E21B 17/10 (20060101); E21B 47/00 (20060101); E21B 17/02 (20060101); E21B 10/32 (20060101); E21B 7/28 (20060101);