The present application is a U.S. National Stage Application of International Application No. PCT/US2016/036018 filed Jun. 6, 2016, which is incorporated herein by reference in its entirety for all purposes.
The present disclosure relates generally to subterranean drilling operations, and more particularly, to rotary steerable drilling tools for use with a drilling shaft in subterranean drilling operations.
Hydrocarbons, such as oil and gas, are commonly obtained from subterranean formations that may be located onshore or offshore. The development of subterranean operations and the processes involved in removing hydrocarbons from a subterranean formation are complex. Typically, subterranean operations involve a number of different steps such as, for example, drilling a wellbore at a desired well site, treating the wellbore to optimize production of hydrocarbons, and performing the necessary steps to produce and process the hydrocarbons from the subterranean formation.
Many subterranean operations require drilling boreholes with vertically deviated and horizontal geometries. A technique for drilling horizontal, vertically deviated, and other complex boreholes is directional drilling. Directional drilling involves controlling, with an ability to vary, the direction of the wellbore as it is being drilled. Oftentimes the goal of directional drilling is to reach a position within a target subterranean destination or formation with the drilling shaft. For instance, the drilling direction may be controlled to direct the wellbore towards a desired target destination, to control the wellbore horizontally to maintain it within a desired payzone, or to correct for unwanted or undesired deviations from a desired or predetermined path.
Various options are available for providing steering capabilities to a drilling tool for controlling and varying the direction of the wellbore. For example, directional drilling may be accomplished with a “rotary steerable” drilling system wherein the entire drilling shaft is rotated from the surface, which in turn rotates the drill bit, connected to the end of the drilling shaft. In a rotary steerable drilling system, the drilling shaft may be rotated while the drilling tool is being steered either by being pointed (“point-the-bit”) or pushed (“push-the-bit”) in a desired direction (directly or indirectly) by a steering device.
Some rotary steerable drilling systems may contain a reference housing. The reference housing may generally be used to assist in guiding the drill bit in the desired drilling direction. In the case of “point-the-bit” systems, the reference housing may be disconnected from the drilling shaft in the torsional direction to allow the drilling shaft to rotate freely within the housing. The drilling shaft may be flexed within the reference housing to point the drill bit in a different direction than the reference housing, thereby allowing for directional drilling.
For a more complete understanding of the present disclosure and its features and advantages, reference is now made to the following description, taken in conjunction with the accompanying drawings, in which:
Illustrative embodiments of the present disclosure are described in detail herein. In the interest of clarity, not all features of an actual implementation are described in this specification. It will of course be appreciated that in the development of any such actual embodiment, numerous implementation specific decisions must be made to achieve developers' specific goals, such as compliance with system related and business related constraints, which will vary from one implementation to another. Moreover, it will be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of the present disclosure. Furthermore, in no way should the following examples be read to limit, or define, the scope of the disclosure.
The present disclosure relates generally to subterranean drilling operations, and more particularly, to rotary steerable drilling tools for use with a drilling shaft in subterranean drilling operations. A rotary steerable drilling system may be used with directional drilling systems for steering a drill bit to drill a non-vertical wellbore. These rotary steerable drilling systems generally fall into two classifications. In a “point-the-bit” system, the driveshaft connected to the drill bit is flexed to direct the drill bit in a desired direction. In a “push-the-bit” system, a force is asserted against the borehole to deflect the driveshaft and direct the drill bit in a desired direction.
A “point-the-bit” rotary steerable drilling system may comprise a reference housing surrounding the drilling shaft. The housing may be used to locate the tool within the wellbore. The location of the central axis of the drilling shaft may be altered within the housing to point the drill bit in the desired direction. This may cause the drill bit to drill in a direction different from the longitudinal direction of the housing, thereby directionally drilling. The reference housing may be disconnected from the shaft in the torsional direction to allow the drilling shaft to rotate freely within the housing. However, this eliminates the ability to transmit drive torque from the drilling shaft to the housing.
Because the housing is not rotating with the drilling shaft, there is a potential for the housing to become stuck in the wellbore. The housing can become stuck in numerous ways, but two common causes are formation caving and the housing becoming “kinked” or trapped in the bend of a wellbore during directional drilling. In order to free the housing, it is desirable to create a bottom-hole assembly (“BHA”) for use with a rotary steerable drilling system that is capable of transmitting drive torque from the drilling shaft to the housing. To prevent the housing from getting stuck in the first place, or to further assist in freeing it once it has gotten stuck, it is also often desirable to strategically enlarge the portion of the wellbore uphole from the drill bit where the BHA is located.
As discussed in greater depth below, a BHA that comprises a reference housing capable of selectively engaging with the drilling shaft. When disengaged, the drilling shaft may rotate independently of the reference housing. Once engaged, the housing and the drilling shaft are rotatably coupled such that the housing rotates with the drilling shaft and the drilling shaft transmits drive torque to the housing. The BHA may comprise an expandable reamer. In an inactive and unengaged position, the reamer blades may be in a radially-retracted position where the cutting surfaces of the reamer blades do not contact the wellbore. In an active and engaged position, the reamer blades may be in the extended position that allows the cutting surfaces of the reamer blades to contact a portion of the wellbore, thereby enlarging the portion of the wellbore. The expandable reamer of the present disclosure is well suited for traditional underreaming operations where it is desirable to create an enlarged wellbore. The expandable nature of the disclosed reamer allows for flexible underreaming without requiring multiple trips down the wellbore.
As would be appreciated by one of ordinary skill in the art, having the benefit of the present disclosure, a BHA in accordance with the present disclosure may comprise an actuator for engaging the BHA to rotatably couple the housing to the drilling shaft. In response to a determination that the housing has become stuck in the wellbore, the actuator may be selectively operated to rotatably couple the housing to the drilling shaft. The torque transferred to the housing from the drilling shaft may be sufficient to free the housing. In certain conditions where additional freeing is required, a second actuator may be used to expand the expandable reamer blades to widen the portion of the wellbore surrounding the housing. Alternatively, both features may be engaged using a single actuator.
The present disclosure may be understood with reference to
Drilling system 100 may include drilling shaft 103 coupled to drill bit 101 that is rotated about its axis to form a wide variety of wellbores or bore holes such as generally vertical wellbore 114a or generally horizontal wellbore 114b or any combination thereof. Various directional drilling techniques and associated components of BHA 120 of drilling shaft 103 may be used to form horizontal wellbore 114b. For example, lateral forces may be applied to BHA 120 proximate kickoff location 113 to form generally horizontal wellbore 114b extending from generally vertical wellbore 114a. The term directional drilling may be used to describe drilling a wellbore or portions of a wellbore that extend at a desired angle or angles relative to vertical. Such angles may be greater than normal variations associated with vertical wellbores. Directional drilling may include horizontal drilling.
Drilling system 100 may comprise a control station 130 for controlling BHA 120. Control station 130 may be communicatively coupled to BHA 120. Control station 130 may be permanently installed at the well site. Alternatively, control station 130 may be mounted to a mobile trailer for easy transport to and from the well site. Control station 130 may be used to control at least the direction, speed, and angle of drilling. Control station 130 may be used to actuate or activate one or more features of BHA 120. Control station 130 may receive data from one or more downhole sensors 140. The data received from the one or more downhole sensors 140 may be used to make decisions on whether or not to actuate or activate one or more features of BHA 120. These decisions may be made manually by an operator or automatically by a computer control system such as a DCS, PLC, or similar control system. Drilling system 100 may further comprise a hydraulic pump 150 fluidically coupled to one or more actuators of BHA 120. Hydraulic pump 150 may be located at a surface location. Alternatively, hydraulic pump 150 may be a mud pump located at a downhole location.
A BHA in accordance with the present disclosure may be in operation in its inactive and unengaged position for directional drilling. The drilling shaft 202 is used to rotate a drill bit to create a wellbore in a subterranean formation. During normal drilling operations, the BHA may become stuck in the wellbore due to a portion of the formation caving in around BHA or the curvature of the directionally drilled wellbore being too tight for the BHA to fit without becoming kinked or stuck within the wellbore. The BHA may be switched to the active and engaged position to assist in freeing the BHA from the wellbore by transmitting drive torque to the housing and expanding the expandable reamer blades to enlarge a portion of the wellbore surrounding the BHA. Under certain drilling conditions, it may be desirable to enlarge or widen a portion of the wellbore for purposes other than freeing a stuck BHA.
Referring now to
To activate BHA 200, hydraulic pump 150 may be activated to pressurize the incompressible fluid based actuator 221 inside sealed chamber 222. The hydraulic pump may be located at a surface location or it may be a mud pump located inside a portion of the wellbore. As the pressure inside sealed chamber 222 increases, the actuator 221 exerts a force against reamer blades 212 and second locking mechanism 208. The pressure inside sealed chamber 222 may increase to a pressure sufficient to overcome the forces exerted by the first biasing mechanism 210 and the second biasing mechanism 216. The expandable reamer blade 212 is then pushed outward in the radial direction to its engaged position. Second locking mechanism 208 is also pushed along the longitudinal axis of drilling shaft 202 to engage with the first locking mechanism 206.
The one or more actuators 221 may be located downhole with BHA 200. BHA 200 may be switched from the inactive and unengaged to the active and engaged position when housing 204 becomes stuck in a portion of the wellbore. Determining that housing 204 has become stuck may be done by operators or control systems at a surface location or it may be done by downhole sensors communicatively coupled to the one or more actuators. The one or more actuators 221 may be selectively operated by an operator or control system from an uphole or surface location. The operator may be able to determine whether or not activation is required in response to data received from one or more downhole sensors. The data may indicate that housing 204 is stuck. The data received may be one or more of, pump pressure, axial force exerted downwards on BHA 200 (“weight on bit”), axial force exerted upwards on BHA 200 (“overpull”), or other similar indications from sensor 140. Alternatively, the one or more actuators 221 may also automatically operate in response to downhole conditions, which indicate a need to free the housing 204 or enlarge a portion of the wellbore. Under certain drilling conditions, BHA 200 is swapped from the inactive and unengaged to the active and engaged position when enlarging a portion of the wellbore above the drill bit is desired. In the active and engaged position, the drilling shaft 202 and the housing 204 are rotatably coupled, allowing the drilling shaft 202 to transmit drive torque to the housing 204. As the drilling shaft 202 rotates, so does the housing 204, assisting in freeing the housing 204 from any obstructions. The reamer blades 212 may expand to contact at least a portion of the wellbore. As the housing 204 rotates, the cutting surfaces 220 of the reamer blades 212 carve out and enlarge the portion of the wellbore. As would be understood by one of ordinary skill in the art having the benefit of the present disclosure, BHA 200 may comprise a single actuator for engaging the first and second locking mechanism and extending the expandable reamer. The single actuator may be activated using an electromagnetic signal, a radio signal, an electric signal, a hydraulic pulse signal, or any other type of suitable signal.
Alternatively, BHA 200 may comprise multiple actuators for independently engaging the first and second locking mechanisms and extending the expandable reamer. Referring now to
As would be appreciated by one having ordinary skill in the art having the benefit of the present disclosure, BHA 200 may be returned to the inactive and unengaged position by reversing the one or more actuators 221. Accordingly, the pressure inside sealed chamber 222 may then decrease to a pressure insufficient to overcome the force exerted by the first biasing mechanism 210 and the second biasing mechanism 216. The first biasing mechanism 210 may then disengage the first locking mechanism 206 and the second locking mechanism 208. The second biasing mechanism 216 may then retract the reamer blade 212 removing it from contact with the wellbore. Thus, BHA 200 may be selectively operated between the active and engaged and inactive and unengaged states throughout the drilling process in response to the needs of a particular drilling operation.
An embodiment of the present disclosure is a bottom-hole assembly comprising a generally tubular housing; a drilling shaft positioned within the housing; a first locking mechanism rotatably coupled to the drilling shaft; a second locking mechanism rotatably coupled to the housing and positioned adjacent to the first locking mechanism; and an expandable reamer attached to the housing.
Another embodiment of the present disclosure is a method of underreaming a wellbore comprising rotating a drilling shaft coupled to a drill bit about its axis to form a wellbore; engaging a first locking mechanism rotatably coupled to the drilling shaft with a second locking mechanism coupled to a housing having an expandable reamer attached thereto to rotatably couple the drilling shaft and the housing; expanding the expandable reamer attached to the housing into engagement with the wellbore; and rotating the expandable reamer to widen at least a portion of the wellbore uphole from the drill bit.
Another embodiment of the present disclosure is a method of freeing a bottom-hole assembly comprising determining that a housing coupled to a drilling shaft is trapped in a portion of a wellbore; engaging a first locking mechanism coupled to the drilling shaft and a second locking mechanism coupled to the housing to rotationally couple the drilling shaft to the housing; expanding an expandable reamer attached to the housing to contact a portion of the wellbore; and rotating the drilling shaft to rotate the housing.
Therefore, the present disclosure is well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular embodiments disclosed above are illustrative only, as the present disclosure may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the present disclosure. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee.
Filing Document | Filing Date | Country | Kind |
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PCT/US2016/036018 | 6/6/2016 | WO | 00 |
Publishing Document | Publishing Date | Country | Kind |
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WO2017/213620 | 12/14/2017 | WO | A |
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Entry |
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International Search Report and Written Opinion issued in related PCT Application No. PCT/US2016/036018 dated Jan. 18, 2017, 16 pages. |
Number | Date | Country | |
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20190153785 A1 | May 2019 | US |