HYDRAULIC ACTUATION OF A DOWNHOLE TOOL ASSEMBLY
A downhole tool assembly is configured for repeated and selective hydraulic actuation and deactuation. A piston assembly is configured to reciprocate axially in a downhole tool body. The piston assembly reciprocates between a first axial position and second and third axial positions that axially oppose the first position. The downhole tool is actuated when the piston assembly is in the third axial position and deactuated when the piston assembly is in either of the first or second axial positions. A spring member biases the piston assembly towards the first axial position while drilling fluid pressure in the tool body urges the piston assembly towards the second and third axial positions. Downhole tool actuation and deactuation may be controlled from the surface, for example, via cycling the drilling fluid flow rate.
This application is a continuation of U.S. patent application Ser. No. 13/112,326, entitled “Hydraulic Actuation of a Downhole Tool Assembly,” filed May 20, 2011, which the claims the benefit of, and priority to, U.S. Provisional Application Ser. No. 61/347,318 entitled “Reamer on Demand Actuator,” filed May 21, 2010. Each of the foregoing applications is expressly incorporated herein by this reference in its entirety.
TECHNICAL FIELDThe present disclosure relates generally to a hydraulic actuation mechanism for use in downhole tools. More specifically, the disclosure relates to a hydraulic actuation assembly enabling a substantially unlimited number of actuation and deactuation cycles of a downhole tool, such as a reamer, without having to break or trip a tool string.
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 well known in oilfield services operations and are commonly employed, and even desirable, in such operations.
For example, one well-known 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 predetermine 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 typically allow for repeated actuation and deactuation of a downhole tool.
Various other hydraulic actuation mechanisms make use of measurement while drilling (MWD) 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 severely limited by the reliability and accuracy of MWD, telemetry, and other electronically controllable systems deployed in the borehole. As a result, there are many applications in which their use tends to be undesirable.
There remains a need in the art for a hydraulic actuation assembly that enables a downhole tool, such as an underreamer, to be actuated and deactuated substantially any number of times during a drilling operation without breaking the tool string and/or tripping the tool out of the borehole. Such an assembly is preferably purely mechanical and therefore does not require the use of electronically controllable components.
SUMMARYExample aspects of the present disclosure are intended to address the above described need for an improved hydraulic actuation mechanism. Aspects of the disclosure include a downhole tool assembly that may be repeatedly and selectively hydraulically actuated and deactuated without breaking or tripping the tool string. Tool embodiments in accordance with the present disclosure include a piston assembly configured to reciprocate axially in a downhole tool body. The piston assembly reciprocates between a first axial position and second and third axial positions that axially oppose the first axial position. The downhole tool is actuated when the piston assembly is in the third axial position and deactuated when the piston assembly is in either of the first or second axial positions. A spring member biases the piston assembly towards the first axial position while drilling fluid pressure in the tool body urges the piston assembly against the spring bias and towards the second and third axial positions. Downhole tool actuation and deactuation may be controlled from the surface, for example, via cycling the drilling fluid flow rate.
Example embodiments of the present disclosure advantageously provide several technical advantages. For example, embodiments of the present disclosure enable a downhole tool to be selectively and repeatedly actuated and deactuated substantially any number of times without breaking the drill string and/or or tripping the tool out of the borehole. The disclosure further obviates the need for physical actuation and deactuation (e.g., including the use of darts, ball drops, and the like).
Moreover, embodiments of the disclosure advantageously allow a downhole tool to be in a deactuated state while providing full drilling fluid flow through the tool. In certain example embodiments of the disclosure unobstructed flow may be advantageously provided through a central bore. This tends to minimize both the pressure drop through the tool and erosion of internal tool components during use. Being purely mechanical (not requiring the use of any electronic monitoring or control), downhole tool assemblies in accordance with the present disclosure also tend to be highly reliable and serviceable.
Certain embodiments of the disclosure may also be configured to provide an indication to the surface of the tool actuation/deactuation status, for example, a pressure drop indicating tool actuation. Such an indication tends to advantageously reduce operational uncertainties. Various embodiment of the disclosure also allow the drilling fluid flow rate to be repeatedly cycled between high and low flow rates without actuating or deactuating the downhole tool. This feature of embodiments of the disclosure may also enhance operational certainty as it tends to eliminate inadvertent actuation and deactuation.
In one aspect, embodiments of the present disclosure include a downhole tool assembly having a downhole tool body configured for connecting with a drill string. A mandrel including at least one port is deployed in the tool body. A piston assembly having a through bore is deployed in the mandrel. The piston assembly includes at least a valve piston and a cam piston configured to reciprocate axially in the mandrel between a first axial position and second and third axial positions that axially oppose the first axial position. A spring member is deployed in the tool body and is disposed to bias the piston assembly towards the first axial position. The mandrel port is configured to be in fluid communication with the through bore when the piston assembly is in the third axial position and is sealingly engaged with an outer surface of the piston assembly when the piston assembly is in either the first axial position or the second axial position.
In another aspect, embodiments of the present disclosure include a downhole tool assembly. The tool assembly includes a downhole tool body having a through bore and is configured for connecting with a drill string. A cam piston is deployed in the tool body and includes first and second uphole and downhole facing cam profiles formed thereon. The cam piston is configured to reciprocate axially in the tool body between a first axial position in which at least a first guide pin engages the first cam profile and second and third axial positions that axially oppose the first axial position in which at least a second guide pin engages the second cam profile. A spring member is deployed in the tool body and is disposed to bias the cam piston towards the first axial position. A fluid flow path is disposed to be in fluid communication with the through bore when the cam piston is in the third axial position and is disposed to be out of fluid communication when the cam piston is in either the first axial position or the second axial position.
In a further embodiment, the present disclosure includes a downhole tool assembly having a downhole tool body configured for connecting with a drill string. A mandrel including at least one port is deployed in the tool body. A piston assembly is deployed in the mandrel. The piston assembly has a through bore and includes at least a valve piston and a cam piston configured to reciprocate axially in the mandrel between a first axial position and second and third axial positions that axially oppose the first axial position. A spring member is deployed in the tool body and is disposed to bias the piston assembly towards the first axial position. The valve piston includes at least a first radial port formed therein, the radial port being axially aligned with and in fluid communication with the mandrel port when the piston assembly is in the third axial position. The radial port is axially misaligned with the mandrel port and sealingly engaged with an inner surface of the mandrel when the piston assembly is in either the first axial position or the second axial position.
The foregoing has outlined rather broadly the features and technical advantages of embodiments of the present disclosure in order that the detailed description that follows may be better understood. Additional features and advantages of embodiments of the present disclosure will be described hereinafter which form the subject of the claims of the invention. It should be appreciated by those skilled in the art that the conception and the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the present disclosure. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the disclosure herein.
For a more complete understanding of the present disclosure, and the advantages thereof, reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:
Referring to
During a typical 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 example embodiments of the present disclosure, the tool assembly 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 deployment illustrated on
In one example embodiment of the 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) may be extended radially outward from the tool body 110 and retracted radially inward towards (or into) the tool body 110.
Embodiments of the present application provide an actuation/deactuation system that enables a downhole tool, such as a reamer, to be actuated and deactuated substantially any number of times without breaking the tool string or tripping it out of the borehole. For example, embodiments of the present application may enable a drilling tool assembly having a reamer disposed on the drill string to drill a portion of the wellbore with the reamer deactivated (with the reamer blades 105 retracted as depicted on
It will be understood that tool assembly embodiments in accordance with the present disclosure are not limited to underreamers such as depicted on
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, spring force urges assembly 200 in the uphole direction such that an uphole engagement face 245 engages uphole guide pin(s) 125 (as depicted on
It will be understood that the disclosure is not limited to the use of a shear sleeve 230. In alternative embodiments, the valve piston 210 may be coupled to cam piston 240, for example, via locking nut 238. The shear sleeve 230 is intended to provide redundant functionality, allowing for a one-time ball drop actuation. In such embodiments, shear sleeve 230 includes in internal ball seat (not shown) sized and shaped to receive a ball dropped from the surface. Increasing the flow rate (pressure) to a predetermined level shears the pins connecting the valve piston 210 and shear sleeve 230 thereby allowing the downhole end of valve piston 210 to move axially into the shear sleeve 230. In this configuration, drilling fluid may be diverted and the actuated. Again, the disclosure is not limited in these regards.
With continued reference to
It will be understood that substantially any suitable guide pin configuration may be utilized. However guide pins having a substantially flat engagement end are generally preferable in that they enable the pin to support higher engagement forces without shearing. Embodiments that make use of multiple guide pins (e.g., four uphole and four downhole pins circumferentially spaced at 90 degree intervals) are also generally preferable and that they tend to more effectively distribute the engagement forces. Those of ordinary skill in the art will appreciate that the disclosure is not limited to any particular guide pin configuration or to any particular number or spacing of the guide pins.
Downhole tool actuation and deactuation is now described in more detail with respect to
With continued reference to
In
Despite valve piston 210 being urged downhole, ports 215 remain sealingly engaged with the inner surface 171 of lower mandrel 170 (i.e., such that they are axially misaligned with mandrel ports 172 and 174). Moreover, as also depicted, mandrel port 172 remains sealingly engaged with the outer surface 217 of valve piston 210. Therefore, the downhole tool remains inactive (in the deactuated state) while substantially full flow is provided through the assembly, for example, to a drill bit for drilling.
In
In
Tool assembly 300 is similar to tool assembly 100 in that the piston assembly 400 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 400 in the uphole direction such that an uphole engagement face 445 engages internal shoulder 324 of sub body 320 (as depicted on
With continued reference to
Downhole tool actuation and deactuation is now described in more detail with respect to
In
Despite valve piston 410 being urged downhole with cam piston 440, 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 410. 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
In the example embodiment depicted, actuation of the downhole tool requires indexing of 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 is typically accomplished as shown schematically on
In
In
In one example embodiment of the disclosure an indexing flow rate may be in the range from about 400 to about 600 gallons per minute. In this particular embodiment, a flow rate of less than about 400 gallons per minute is in the pre-index range, while a flow rate greater than about 600 gallons per minute is in the operating range (or in a transitional range between the index range and operating range). It will be understood that the disclosure is not limited to any particular flow rates and/or pressures and that those of ordinary skill in the art would be readily able to compute suitable flow rates based on various tool geometry parameters (e.g., the tool diameter).
Although embodiments of the present disclosure and some features thereof have been described in detail, it should be understood that various changes, substitutions, and alternations can be made herein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims
1. A downhole tool, comprising:
- a tool body having a through bore;
- a mandrel in the tool body, the mandrel including at least one port; and
- a piston assembly having the through bore extending therethrough, the piston assembly including at least one piston configured to reciprocate axially between a first, second, and third axial positions, and fluid flow being permitted through the through bore when the piston assembly is in each of the first, second, and third axial positions.
2. The downhole tool of claim 1, further comprising:
- a bias member in the tool body and configured to bias the piston assembly toward the first axial position.
3. The downhole tool of claim 2, the piston assembly being configured to move against the bias of the bias member in response to fluid flow in the through bore.
4. The downhole tool of claim 1, the piston assembly being at least partially positioned in the mandrel.
5. The downhole tool of claim 1, further comprising:
- a plurality of expandable cutting structures configured to be in a radially extended position when the piston assembly is in the third axial position, and to be in a radially retracted position when the piston assembly is in at least one of the first axial position or the second axial position.
6. The downhole tool of claim 1, the at least one piston including first and second cam profiles, the first cam profile being oriented in an uphole direction and the second cam profile being oriented in a downhole direction, and the tool body including at least one guide pin, the at least one guide pin being configured to engage the first cam profile when the piston assembly is in the first axial position, and to engage the second cam profile when the piston assembly is in at least one of the second or third axial positions.
7. The downhole tool of claim 6, the at least one guide pin including at least a first guide pin configured to engage the first cam profile when the piston assembly is in the first axial position, and a second guide pin configured to engage the second cam profile when the piston assembly is in at least one of the second or third axial positions.
8. The downhole tool of claim 7, the second cam profile including alternating deep and shallow troughs, and the second guide pin being configured to engage a corresponding one of the shallow troughs when the piston assembly is in the second axial position and a corresponding one of the deep troughs when the piston assembly is in the third axial position.
9. The downhole tool of claim 1, the piston assembly being configured to transition from the second axial position to the first axial position and then to the third axial position when a fluid flow rate is cycled from a high flow rate to a low flow rate and back toward the high flow rate.
10. The downhole tool of claim 1, the at least one piston including a cam piston having at least one groove in a radially outward facing surface of the cam piston, and the tool body including at least a first guide pin engaging the at least one groove.
11. The downhole tool of claim 10, the cam piston including alternating cam slots and cam shoulders formed on an axial end of the cam piston, and the tool body including at least a first stop configured to engage at least one of the cam shoulders when the piston assembly is in the second axial position and at least one of the cam slots when the piston assembly is in the third axial position.
12. The downhole tool of claim 1, the piston assembly being configured to transition from the second axial position to the first axial position and then to the third axial position when a fluid flow rate is cycled from a high flow rate, to a low flow rate, to an indexing flow rate, back to the low flow rate, and then toward the high flow rate.
13. The downhole tool of claim 1, the at least one piston including a valve piston having at least one port configured to provide fluid communication between the through bore and an annular region between the tool body and a portion of the piston assembly when the piston assembly is in the third axial position, the valve piston port being sealingly engaged with the mandrel when the piston assembly is in at least one of the first or second axial positions.
14. The downhole tool of claim 13, the port of the valve piston providing an alternative flow path around a nozzle when the piston assembly is in the third axial position, the alternative flow path being configured to route fluid from the through bore, through the annular region, and back into the through bore.
15. The downhole tool of claim 13, the at least one piston including a cam piston having a plurality of apertures providing fluid communication between the annular region and the through bore.
16. A tool, comprising:
- a tool body having a through bore;
- a cam piston in the tool body, the cam piston including first and second cam profiles thereon, the cam piston configured to reciprocate axially in the tool body between a first axial position in which at least one guide pin engages the first cam profile and second and third axial positions in which the at least one guide pin engages the second cam profile, a radial fluid flow path being in fluid communication with the through bore when the cam piston is in the third axial position and out of fluid communication with the through bore when the cam piston is in at least one of the first or second axial positions, while fluid flow is permitted axially through the throughbore when the piston assembly is in each of the first, second, and third axial positions; and
- a bias member in the tool body and configured to bias the cam piston toward the first axial position.
17. The tool of claim 16, the at least one guide pin including a first guide pin configured to engage the first cam profile when the cam piston is in the first axial position, and a second guide pin configured to engage the second cam profile when the cam piston is in the second and third axial positions.
18. The tool of claim 17, the second cam profile including circumferentially spaced, alternating deep and shallow troughs, and the second guide pin being configured to engage a corresponding one of the shallow troughs when the cam piston is in the second axial position and a corresponding one of the deep troughs when the cam piston is in the third axial position.
19. The tool of claim 16, further comprising:
- a plurality of expandable cutting structures configured to extend radially outward from the tool body when the fluid flow path is in fluid communication with the through bore.
20. A method for reaming a wellbore, comprising:
- using a drill string to position a reamer within a wellbore, the reamer including: a reamer body coupled to the drill string, the reamer body having a through bore; a mandrel in the tool body, the mandrel including at least one port; a piston assembly in the tool body, the piston assembly including at least one piston configured to reciprocate axially between first, second, and third axial positions using a cam and at least one guide pin; and a plurality of expandable cutting structures in a retracted state and configured to selectively expand in response to movement of the piston assembly; and
- adjusting a drilling fluid flow rate within the reamer, which adjusting of the drilling fluid flow rate causes the piston assembly to move using the cam and at least one guide pin in a cycle that includes: from the first axial position to the second axial position; from the second axial position back to the first axial position; from the first axial position to the third axial position; and from the third axial position back to the first axial position.
Type: Application
Filed: Sep 26, 2014
Publication Date: Jan 15, 2015
Inventors: Jian Wu (Houston, TX), Jianbing Hu (Houston, TX), Dwayne P. Terracina (Spring, TX), Tommy G. Ray (Houston, TX)
Application Number: 14/497,455
International Classification: E21B 34/06 (20060101); E21B 7/28 (20060101);