Rotary steerable drilling tool and method

A directional drilling system includes a rotary steerable tool. The rotary steerable tool includes an extendable member configured to extend outwardly from the rotary steerable tool upon actuation, and a geolocation electronics device configured to track a position of the rotary steerable tool and the extendable member and control actuation of the extendable member. The geolocation electronics device and extendable member are configured to rotate with the rotary steerable tool.

BACKGROUND

This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the presently described embodiments. This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the described embodiments. Accordingly, it should be understood that these statements are to be read in this light and not as admissions of prior art.

Directional drilling is commonly used to drill any type of well profile where active control of the well bore trajectory is required to achieve the intended well profile. For example, a directional drilling operation may be conducted when the target pay zone cannot be reached from a land site vertically above it. Directional drilling operations involve varying or controlling the direction of a downhole tool (e.g., a drill bit) in a wellbore to direct the tool towards the desired target destination. Examples of directional drilling systems include point-the-bit rotary steerable drilling systems and push-the-bit rotary steerable drilling systems. In both systems, the drilling direction is changed by repositioning the bit position or angle with respect to the well bore. Push-the-bit tools use pads on the outside of the tool which press against the well bore thereby causing the bit to press on the opposite side causing a direction change. Point-the-bit technologies cause the direction of the bit to change relative to the rest of the tool.

Many directional drilling systems and techniques are based on rotary steerable systems, which allow the drill string to rotate while changing the direction of the borehole. However, these systems typically require a physical geostationary component near the drill bit which does not rotate with the drill bit in order to keep track of the position of the system.

DETAILED DESCRIPTION

The present disclosure provides methods and systems for directional drilling. Specifically, the present disclosure provides a directional drilling system, such as a rotary steerable system (RSS), with a geolocation device. The geolocation device rotates with the drill shaft while the system tracks tool position and controls actuation of one or more extendable members to direct the drill bit. Thus, the entire system can rotate and stationary parts can be eliminated, resulting in a more reliable and simplistic tool. Specifically, there is no relative rotation between the parts of the system. Thus, bearings can be eliminated and load transfer across components is simplified.

Turning now to the figures,FIG. 1depicts a schematic view of a drilling operation utilizing a directional drilling system100, in accordance with one or more embodiments. The system of the present disclosure will be specifically described below such that the system is used to direct a drill bit in drilling a wellbore, such as a subsea well or a land well. Further, it will be understood that the present disclosure is not limited to only drilling an oil well. The present disclosure also encompasses natural gas wellbores, other hydrocarbon wellbores, or wellbores in general. Further, the present disclosure may be used for the exploration and formation of geothermal wellbores intended to provide a source of heat energy instead of hydrocarbons.

Accordingly,FIG. 1shows a tool string126disposed in a directional borehole116. The tool string126including a rotary steerable tool128in accordance with various embodiments. The rotary steerable tool128provides full3D directional control of the drill bit114. A drilling platform102supports a derrick104having a traveling block106for raising and lowering a drill string108. A kelly110supports the drill string108as the drill string108is lowered through a rotary table112. In one or more embodiments, a topdrive is used to rotate the drill string108in place of the kelly110and the rotary table112. A drill bit114is positioned at the downhole end of the tool string126, and, in one or more embodiments, may be driven by a downhole motor129positioned on the tool string126and/or by rotation of the entire drill string108from the surface. As the bit114rotates, the bit114creates the borehole116that passes through various formations118. A pump120circulates drilling fluid through a feed pipe122and downhole through the interior of drill string108, through orifices in drill bit114, back to the surface via the annulus136around drill string108, and into a retention pit124. The drilling fluid transports cuttings from the borehole116into the pit124and aids in maintaining the integrity of the borehole116. The drilling fluid may also drive the downhole motor129.

The tool string126may include one or more logging while drilling (LWD) or measurement-while-drilling (MWD) tools132that collect measurements relating to various borehole and formation properties as well as the position of the bit114and various other drilling conditions as the bit114extends the borehole108through the formations118. The LWD/MWD tool132may include a device for measuring formation resistivity, a gamma ray device for measuring formation gamma ray intensity, devices for measuring the inclination and azimuth of the tool string126, pressure sensors for measuring drilling fluid pressure, temperature sensors for measuring borehole temperature, etc.

The tool string126may also include a telemetry module134. The telemetry module134receives data provided by the various sensors of the tool string126(e.g., sensors of the LWD/MWD tool132), and transmits the data to a surface unit138. Data may also be provided by the surface unit138, received by the telemetry module134, and transmitted to the tools (e.g., LWD/MWD tool132, rotary steering tool128, etc.) of the tool string126. In one or more embodiments, mud pulse telemetry, wired drill pipe, acoustic telemetry, or other telemetry technologies known in the art may be used to provide communication between the surface control unit138and the telemetry module134. In one or more embodiments, the surface unit138may communicate directly with the LWD/MWD tool132and/or the rotary steering tool128. The surface unit138may be a computer stationed at the well site, a portable electronic device, a remote computer, or distributed between multiple locations and devices. The unit138may also be a control unit that controls functions of the equipment of the tool string126.

The rotary steerable tool128is configured to change the direction of the tool string126and/or the drill bit114, such as based on information indicative of tool128orientation and a desired drilling direction. In one or more embodiments, the rotary steerable tool128is coupled to the drill bit114and drives rotation of the drill bit114. Specifically, the rotary steerable tool128rotates in tandem with the drill bit114. In one or more embodiments, the rotary steerable tool128is a point-the-bit system or a push-the-bit system.

FIG. 2Adepicts a cross-sectional schematic view of the rotary steerable tool128in the borehole116, in accordance with one or more embodiments. The rotary steerable tool128includes a tool body203and a flowbore201through which drilling fluid flows. The rotary steerable tool128further includes one or more pads202located near the outer surface204of the rotary steerable tool128. The pads202are configured to extend outwardly from the rotary steerable tool128upon actuation to direct the drill bit114towards a desired direction. Thus, the pads202are actuated into the extended position only when they are in a certain rotational position. Specifically, for a push-the-bit system, the resultant force of all the actuated pads applied on the wall of the borehole116should be in the opposite direction as the desired driving direction of the drill bit114. Specifically, for a point-the-bit system, a fulcrum stabilizer can be positioned between the rotary steerable tool and the bit. In the case of the point system, the resultant force of all the actuated pads applied on the wall of the borehole116should be in the same direction as the desired driving direction of the bit114. As the pads202are only put into the extended position when in the appropriate position during rotation of the rotary steerable tool128, the pads202are pulled back to the tool once they are no longer in the appropriate position. The pads202can each be controlled independently or in groups. In one or more embodiments, hydraulic pressure is directed to the desired pad202or an associated piston212to actuate the extension of the pad202. However, any suitable means of actuation, including for example mechanical or electrical actuation, may be used.

As an example of hydraulic actuation, in one or more embodiments, extension of the pads202is enabled by generating a pressure differential between the flowbore201of the tool string126and the annulus136surrounding the tool string126and inside the borehole116. Specifically, the pads202, or intermediate actuation devices such as pistons212, are each coupled to the flowbore201via a supply path214and actuation path208formed in the tool body203. The actuation path208is also coupled to a bleed path210formed in the tool body which hydraulically couples to the annulus136. The supply path214is coupled to the actuation path208via an electrically actuated valve206, such as a solenoid valve.

The valve206can be controlled to hydraulically couple and decouple the actuation path208from the supply path214. Valve and flow path configurations include but are not limited to the following configurations as depicted inFIGS. 2B and 2C. As depicted inFIG. 2B, when the valve206is actuated, the actuation path208and the supply path214are coupled to the flowbore201. Due to the pumping of drilling fluid into the flowbore201and the pressure drop at the bit, the flowbore201is at a high pressure relative to the annulus136. As a result drilling fluid flows into the actuation path208from the flowbore201. The increase in pressure in the actuation path208actuates extension of the piston212and pad202. During activation, the activation path208is closed to the bleed path210and thus full differential pressure, between the flowbore201and annulus136, is applied to the piston212. During deactivation of the valve206, the activation path208is open to the bleed path210and piston212is allowed to push the fluid to the annulus136via the bleed path210. As depicted inFIG. 2C, when the valve206is actuated, the actuation path208, supply path214, and bleed path210are coupled to the flowbore201and to each other. Due to the pumping of drilling fluid into the flowbore201and the pressure drop at the bit, the flowbore201is at a high pressure relative to the annulus136. As a result, drilling fluid flows into the actuation path208and bleed path210from the flowbore201. The increase in pressure in the actuation path208actuates extension of the piston212and pad202. It should be noted that some volume of fluid is flowing to the annulus via the bleed path210, and that sufficient restriction215is necessary to maintain sufficient pressure differential between the flowbore201and annulus136in order to extend the piston212and pad202. During deactivation of the valve206, the activation path208is open to the bleed path210and piston212is allowed to push the fluid to the annulus136via the bleed path210. In one or more embodiments, the piston212is coupled to the actuation path and the increase in pressure actuates a piston212. The piston212may extend outward upon actuation and push the pad202outward. In one or more embodiments, the pad202is absent and the piston212pushes against the borehole116.

Each pad202can be opened independently through actuation of the respective valve206. Any subset or all of the pads202can be opened at the same time. The valves206are controlled by a central geolocation device213discussed in more detail below. In one or more embodiments, the amount of force by which piston212or pad202pushes against the borehole116or the amount of extension may be controlled by controlling the flow of drilling fluid into the actuation path208, which can be controlled via the valve206or various other valves or orifices places along the actuations path208or the bleed path210. This helps enable control over the degree of direction change of the drill bit114. In addition to the aforementioned geostationary device, the rotary steerable tool128may contain one or more sensors216for making any measurement including measurement while drilling data, logging while drilling data, formation evaluation data, and other well data.

FIG. 3Adepicts a radial cross-sectional schematic view of the rotary steerable tool128, showing the pads202. As shown, the pads202are close to the tool body203in a closed position and configured to extend outward into an open or actuated position. In the illustrated example, the pads202are coupled to the tool body203and pivot between the closed and open positions via hinges304. As mentioned above, the pads202can be pushed outward and into the open position by the pistons212. In the illustrated embodiment, the tool body203includes recesses306which house the pads202when in the closed position, thereby allowing the pads202to be flush with the tool body203.

As shown, the rotary steerable tool128includes three pads spaced 120 degrees apart around the circumference of the tool128. However, the rotary steerable tool128can have more or less than the three pads202shown. The rotary steerable tool128can even have as few as one pad202. The pad202and piston212mechanism is just one configuration of an extendable mechanism designed to push against the wall of the borehole116to urge the drill bit114in a direction. The rotary steerable tool128may include various other types of extendable members or mechanisms, including but not limited to pistons configured to push against the borehole116directly or pads202configured to be acted on by drilling fluid direction without an intermediate piston.

The pads202, or alternative extendable members or mechanism, may also include a retraction mechanism that moves the pads202back into the closed position, such as when the pads202are out of the appropriate position. For example, the pads202may include a spring that pulls the pads202back into the closed position. In some other embodiments, the pads202may be configured to fall back into the closed position when pressure applied by the drill fluid at the pads drops. In some embodiments, the pads202are coupled to the piston212and thus travel with the piston212. In one or more embodiments, the pads202may also function as centralizers, in which all the pads202remain in the extended position, keeping the rotary steerable tool128centralized in the borehole116. In such embodiments, the retraction mechanism can be disabled or not included. One of the key benefits of being able to keep the pads retracted is reduced wear on the pads202and pistons212.

FIG. 3Bdepicts a radial cross-sectional schematic view of another example rotary steerable tool300, with a different pad and piston configuration. Specifically, the tool300includes a plurality of pads302located around the tool300and a plurality of pistons312configured to push the pads302outwardly. In some embodiments, and as illustrated, each pad302is pushed by two pistons312. The pistons312may also be coupled to the respective pads302. Each piston312is coupled to a hydraulic line316which provides a source of hydraulic pressure. Additionally, in some embodiments, each piston312includes a wear sleeve314for protecting the parts from wear caused by movement of the piston312.

FIG. 4Adepicts a hydraulic circuit400of the rotary steerable tool128using hydraulic actuation to move the pads202, in accordance with one or more embodiments.FIG. 4Ais the embodiment of multiple 3 way-2 position valves that utilize differential mud pressure between the bore201and annulus136. The hydraulic circuit400utilizes a pressure differential between the drilling fluid pumped into the rotary steerable tool128and the annulus136around the rotary steerable tool128. The hydraulic circuit400includes a high pressure line402, which represents the inside of the tool into which fluid is pumped, and a low pressure line404, which represents the annulus136. The high pressure line402is coupled to the drill bit114, which provides flow restriction and the resulting differential pressure. Additionally, a flow restrictor414can be added to increase pressure differential in the case that the bit, alone, does not provide a sufficient pressure differential. The high pressure line402is also coupled to one or more electrically actuated valves408. Each electric valve408is also coupled to a hydraulic piston line406, and the low pressure line404. Generally, there are as many hydraulic piston lines406as there are pistons410or pads202on the rotary steerable tool128. The electrically actuated valves408separate the high pressure line402from the hydraulic piston lines406, thereby separating the high pressure line402from the pistons410. The electrically actuated valves408also separate the hydraulic pad lines406from the low pressure line404, thereby separating the pistons410from the low pressure line404.

The electrically actuated valves408can be individually controlled to couple or decouple the high pressure line402and each of the hydraulic pad lines406. Specifically, in one or more embodiments, when an electrically actuated valve408is actuated, the high pressure line is in fluid communication with the respective hydraulic piston line406and the respective piston410. The pressure differential between the low pressure line404and the high pressure line402pushes drilling fluid through the respective hydraulic piston line406, thereby actuating the piston410. Actuation of the piston410causes pad extension or another protrusion to extend outwardly from the rotary steerable tool128, applying a force on the wellbore, thereby changing the drilling direction. When an electrically actuated valve408is deactivated, the respective piston410is isolated from the high pressure line402, and the piston410is in fluid communication with the low pressure line404, allowing the piston410to retract and drain fluid through the low pressure line404to the annulus136.

FIG. 4Bdepicts a hydraulic circuit400of the rotary steerable tool128using hydraulic actuation to move the pads202, in accordance with one or more embodiments.FIG. 4Bis the embodiment of multiple 2 way-2 position valves that utilize differential mud pressure between the bore201and annulus136. The hydraulic circuit400utilizes a pressure differential between the drilling fluid pumped into the rotary steerable tool128and the annulus136around the tool128. The hydraulic circuit400includes a high pressure line402, which represents the inside of the tool into which fluid is pumped, and a low pressure line404, which represents the annulus136. The high pressure line402is coupled to the drill bit114, which provides flow restriction and the resulting differential pressure. Additionally, if necessary, a flow restrictor414can be added to increase pressure differential in the case where the bit, alone, does not provide a sufficient pressure differential.

The high pressure line402is also coupled to one or more electrically actuated valves408. Each electric valve408is also coupled to a hydraulic piston line406and the low pressure line404. Generally, there are as many hydraulic piston lines406as there are pistons410or pads202on the rotary steerable tool128. The electrically actuated valves408separate the high pressure line402from the hydraulic pad lines406, thereby separating the high pressure line402from the pistons410and the low pressure line404. The electrically actuated valves408can be individually controlled to couple or decouple the high pressure line402and each of the hydraulic piston lines406. Specifically, in one or more embodiments, when an electrically actuated valve408is actuated, the high pressure line is in fluid communication with the respective hydraulic piston line406, its respective piston410, and the low pressure line404. The pressure differential between the low pressure line404and the high pressure line402pushes drilling fluid through the respective hydraulic piston line406, thereby actuating the piston410.

Actuation of the piston410causes pad extension or another protrusion to extend outwardly from the rotary steerable tool128, applying a force on the wellbore, thereby changing the drilling direction. It should be noted that some volume of fluid is flowing to the annulus via the low pressure line404and that sufficient restriction415is necessary to maintain sufficient pressure differential, between the flowbore201and annulus136in order to extend the piston410and pad202. When an electrically actuated valve408is deactivated, the respective piston410is isolated from the high pressure line402, and the piston410is in fluid communication with the low pressure line404, allowing the piston410to retract and drain fluid through the low pressure line404to the annulus136.

FIG. 5Adepicts an embodiment of an internal hydraulic system500that can be used with the rotary steerable tool128using hydraulic actuation to move the pads202, in accordance with one or more embodiments. In one or more embodiments, the hydraulic system500is contained within the rotary steerable tool128(i.e., not open to the annulus) and may utilize a general hydraulic fluid. The hydraulic system500includes a high pressure line502and a low pressure line504.FIG. 5Ais the embodiment of multiple 3 way-2 position valves that utilize differential hydraulic pressure between the high pressure line502and low pressure line504. The high pressure line502is coupled to one or more electrically actuated valves518. Each electric valve518is also coupled to a hydraulic piston line506, and the low pressure line504. Generally, there are as many hydraulic piston lines506as there are pistons516or pads202on the rotary steerable tool128. The electrically actuated valves518separate the high pressure line502from the hydraulic piston lines506, thereby separating the high pressure line502from the pistons516. The electrically actuated valves518also separate the hydraulic piston lines506from the low pressure line504, thereby separating the pistons516from the low pressure line504.

The electrically actuated valves518can be individually controlled to couple or decouple the high pressure line502and each of the hydraulic piston lines506. Specifically, in one or more embodiments, when an electrically actuated valve518is actuated, the high pressure line is in fluid communication with the respective hydraulic piston line506and the respective piston516. The pressure differential between the low pressure line504and the high pressure line502pushes hydraulic fluid through the respective hydraulic piston line506, thereby actuating the piston516. Actuation of the piston516causes pad extension or another protrusion to extend outwardly from the rotary steerable tool128, applying a force on the wellbore, thereby changing the drilling direction. When an electrically actuated valve518is deactivated, the respective piston516is isolated from the high pressure line502, and the piston516is in fluid communication with the low pressure line504, allowing the piston516to retract and drain fluid through the low pressure line504to the return line514.

FIG. 5Bdepicts an embodiment of an internal hydraulic system500that can be used with the rotary steerable tool128using hydraulic actuation to move the pads202, in accordance with one or more embodiments. In one or more embodiments, the hydraulic system500is contained within the rotary steerable tool128(i.e., not open to the annulus) and may utilize a general hydraulic fluid. The hydraulic system500includes a high pressure line502and a low pressure line504.FIG. 5Bis the embodiment of multiple 2 way-2 position valves that utilize differential hydraulic pressure between the high pressure line502and low pressure line504. The high pressure line502is also coupled to one or more electrically actuated valves518. Each electric valve518is also coupled to a hydraulic piston line506and the low pressure line504. Generally, there are as many hydraulic piston lines506as there are pistons516or pads202on the rotary steerable tool128. The electrically actuated valves518separate the high pressure line502from the hydraulic pad lines506, thereby separating the high pressure line502from the pistons516and the low pressure line504.

The electrically actuated valves518can be individually controlled to couple or decouple the high pressure line502and each of the hydraulic piston lines506. Specifically, in one or more embodiments, when an electrically actuated valve518is actuated, the high pressure line is in fluid communication with the respective hydraulic piston line506, its respective piston516, and the low pressure line504. The pressure differential between the low pressure line504and the high pressure line502pushes hydraulic fluid through the respective hydraulic piston line506, thereby actuating the piston516. Actuation of the piston516causes pad extension or another protrusion to extend outwardly from the rotary steerable tool128, applying a force on the wellbore, thereby changing the drilling direction. It should be noted that some volume of fluid is flowing to the low pressure line504and that sufficient restriction515is necessary to maintain sufficient pressure differential, between the high pressure line502and low pressure line504. When an electrically actuated valve518is deactivated, the respective piston516is isolated from the high pressure line502, and the piston516is in fluid communication with the low pressure line504, allowing the piston516to retract and drain fluid through the low pressure line504to the return line514.

The internal hydraulic system500further includes a pump510and a reservoir520for the hydraulic fluid. The pump510draws hydraulic fluid from the reservoir520and circulates the hydraulic fluid. In one or more embodiments, the internal hydraulic system500includes a return line514coupled to the low pressure line504through which hydraulic fluid is circulated back to the reservoir520. High pressure line502may also be coupled to the return line such that the hydraulic fluid can continue to circulate when none of the electrically actuated valves518are actuated and the high pressure line502is not in communication with the low pressure line504. In one or more embodiments, the high pressure line502and the return line514are separated by a flow restrictor508which restricts the flow between the high pressure line502and the return line, thereby maintaining a relatively higher pressure in the high pressure line502. The high pressure line502may also include a check valve512configured to prevent back flow.

FIG. 6depicts a block diagram of the geolocation device213, in accordance with one or more embodiments. The geolocation device213includes a processor602and a suite of sensors, including directional sensors such as accelerometers604, magnetometers606, and gyroscopes608, and the like for determining an azimuth or toolface angle of the drill bit114to a reference direction (e.g., magnetic north). The geolocation device213may include any number of these sensors and in any combination. Based on the azimuth and a desired drilling direction or drilling path, the rotary steerable tool128determines a suitable control scheme to steer the tool string126and drill bit114in the desired direction, thereby creating a directional borehole. The geolocation device213utilizes the sensors to maintain a geostationary reference for steering control of the rotary steerable tool128while the geolocation device213is also in rotation with the rotary steerable tool128, without the need for a physically geostationary component. The geolocation device213may also include various other sensors610such as temperature sensors, magnetic field sensors, and rpm sensors, among others. The sensors are coupled to the processor602. The sensors may be embedded anywhere on the rotary steerable tool128and are programmed or controlled to take respective measurements and transmit the measurements to the processor602in real time.

The processor602is configured to control the pads202through actuation of the valves206according to the measurements made by the sensors as well as a profile of the drilling operation, thereby controlling the drilling direction of the drill bit114. The profile of the drilling operation may include information such as the location of the drilling target, type of formation, and other parameters regarding the specific drilling operation. As the tool128rotates, the sensors (e.g., accelerometers604, magnetometers606, and gyroscopes608) continuously feed measurements to the processor602while rotating with the tool128. The processor602uses the measurements to continuously track the position of the tool128with respect to the target drilling direction in real time. From this the processor602can determine which direction to direct the drill bit114. Since the location of the pads202are fixed with respect to the tool128, the location of the pads202can be easily derived from the location of the tool128. The processor602can then determine when to actuate the pads202in order to direct the drill bit114in the desired direction. Each of the pads202on the tool128can be actuated independently, in any combination, and at any time interval, which allows for agile, fully three dimensional control of the direction of the drill bit114. The directional control may be relative to gravity toolface, magnetic toolface, or gyro toolface.

For example, if the drill bit114needs to be directed towards high side (0 degree toolface angle), then the pads202need to extend and apply force against the borehole at the 180 degree location of the tool128. Thus, a pad202is actuated when it rotates into the 180 degree location and retracts when it rotates out of the 180 degree location. In one or more embodiments, actuation of a pad202includes sending a current through the valve206to which the pad202is coupled. The valve206then couples the pad202to a hydraulic pressure differential, which actuates the pad202. In one or more embodiments, each pad202is actuated as it rotates into the 180 degree location. Frequency of pad202extensions may depend on the speed of rotation of the tool128and the desired rate of direction change. For example, if the tool128is rotating at a relatively high speed, a pad202may only be actuated every other rotation. Similarly, if the desired rate of direction change of the tool128is high, the pad202may be actuated at a higher frequency than if the desired rate of direction change were lower. Such parameters can be controlled by the processor according to the profile of the drilling operation.

The processor602is in communication with a control center612. The control center612may send instructions or information to the processor such as the information related to the profile of the drilling operation such as location of the drilling target, rate of direction change, and the like. In one or more embodiments, the control center612may receive spontaneous control commands from an operator which are relayed as processor-readable commands to the processor602of the geolocation device213. In some other embodiments, the control center612sends preprogrammed commands to the processor602set according to the profile of the drilling operation. The geolocation device213receives power from a power source. Examples of power sources include batteries, mud generators, among others. The power supply actually used in a specific application can be chosen based on performance requirements and available resources.

In addition to the embodiments described above, many examples of specific combinations are within the scope of the disclosure, some of which are detailed below:

A directional drilling system for drilling a directional well, comprising:a rotary steerable tool having a tool body comprising a flowbore;an extendable member configured to extend outwardly from the tool body upon actuation and which rotates with the rotary steerable tool while drilling the well;an electronic device having sensors configured to measure a position or location of the rotary steerable tool and which rotates with the rotary steerable tool while drilling the well; anda processor configured to receive an input from the sensors and to control actuation of the extendable member to deviate the rotary steering tool while drilling the well.

The system of example 1, wherein:the rotary steerable tool further comprises an electrically actuated valve configured to control communication of hydraulic pressure to the extendable member from a hydraulic source; andcommunication of the hydraulic pressure causes the extendable member to extend outwardly from the rotary steerable tool.

The system of example 2, wherein the hydraulic source is drilling fluid flowing through the flowbore.

The system of example 2, wherein the hydraulic source is a hydraulic pump.

The system of example 1, wherein the electronics device is configured to determine a position of the rotary steering tool and control actuation of the extendable member according to the position of the rotary steering tool and a target drilling direction.

The system of example 1, further comprising a plurality of extendable members and wherein the electronics device is configured to control actuation of the each extendable member.

The system of example 1, wherein the extendable member is retractable.

The system of example 1, wherein the position of the rotary steerable tool comprises a rotational position, azimuth or toolface angle, an inclination angle, or any combination thereof.

A method of directionally drilling a borehole, comprising:rotating a tool within the borehole, wherein the tool comprises a geolocation electronics device and an extendable member, the geolocation electronics device and the extendable member rotating with the tool;tracking a position of the rotating tool via the geolocation electronics device;tracking a position of the rotating extendable member via the geolocation electronics device;extending the extendable member outwardly into contact with a wall of the borehole upon the extendable member coming into a designated position with respect to the borehole; andapplying a force against the wall of the borehole to adjust the direction of the drilling of the borehole.

The method of example 9, retracting the extendable member upon the extendable member rotating out of the designated position.

The method of example 9, wherein the geo-locating electronics device comprises one or more directional sensors configured to rotate with the rotary steerable tool.

The method of example 9, wherein extending the extendable member comprises actuating a valve, thereby putting the extendable member in fluid communication with a source of hydraulic pressure

The method of example 12, wherein the source of hydraulic pressure is drilling fluid flowing through a flowbore in the rotary steerable tool or a hydraulic pump within the tool.

The method of example 9, further comprising extending one or more extendable members of the tool individually or as a group.

A directional drilling system, comprising:a rotary steerable tool, comprising:an extendable member configured to extend outwardly from the rotary steerable tool upon actuation; andan electronics device configured to measure a position or location of the rotary steerable tool and the extendable member and control actuation of the extendable member; andwherein the electronics device and extendable member are configured to rotate with the rotary steerable tool.

The system of example 15, comprising a plurality of extendable members, wherein the electronics device is configured to control actuation of the each extendable member.

The system of example 15, wherein the extendable member is hydraulically actuated.

The system of example 17, wherein the electronics device comprises a plurality of directional sensors configured to rotate in with the rotary steerable tool while measuring the position of the rotary steerable tool, and wherein the electronics device controls actuation of the extendable member according to the position of the rotary steering tool and a target drilling direction.

The system of example 17, wherein the rotary steerable tool further comprises an electrically actuated valve, wherein the valve puts the extendable member in fluid communication with a source of hydraulic pressure in an actuated state.

The system of example 19, wherein the source of hydraulic pressure is drilling fluid flowing through a flowbore within the rotary steerable tool or a hydraulic pump within the rotary steerable tool.

The system of example 15, wherein the rotary steerable tool further comprises one or more sensors configured to collect well data, logging while drilling data, measurement while drilling data, formation evaluation data, or any combination thereof.

Certain terms are used throughout the description and claims to refer to particular features or components. As one skilled in the art will appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name but not function, unless specifically stated. In the discussion and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . .” Also, the term “couple” or “couples” is intended to mean either an indirect or direct connection. In addition, the terms “axial” and “axially” generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the central axis. The use of “top,” “bottom,” “above,” “below,” and variations of these terms is made for convenience, but does not require any particular orientation of the components.