Patent Grant
6942044
This invention relates to the drilling of boreholes in underground formations, and more particularly, to a three-dimensional steering tool that improves extended reach directional drilling of boreholes.
There is a need for drilling multiple angled, long reach boreholes from a fixed location such as from an offshore drilling platform. Historically, several methods have been used to change the direction of a borehole. With the requirement for multiple extended reach drilling of wells from offshore platforms came the need for a means for steering the drilling assembly more accurately. In the 1970s, the downhole motor and Measurement-While-Drilling (MWD) with a bent sub were introduced. Steering was accomplished by stopping rotary drilling and installing the downhole motor-bent sub assembly and an orientation tool. After making a trip into the borehole, the orienting tool was actuated and locked into the desired tool face angle—the angle of the assembly at the bottom of the hole similar to the points of a compass. The downhole motor's bent sub (typically with a two-degree bend) is actuated by increasing pump pressure, thus turning the motor and the drill bit. The assembly drills ahead with the drill string sliding forward and only the drill bit rotating, thus increasing the hole build angle approximately 2 degrees per length of the motor until the desired angle is achieved. It is during the sliding advancement of the drill string that differential sticking (a significant and frequently incurred problem) is most prevalent. The downhole motor is retrieved, thus requiring another trip to the surface. In later designs, after drilling the build section and when a short straight hole section is required, a trip to the surface can be delayed by rotating the bent sub downhole motor at drilling speeds (5-150 RPM) until the short straight section is drilled. This method can drill an approximately straight but slightly enlarged hole for short distances. The amount of time between trips is typically limited by the life of the downhole motor (80-100 hours), rather than the life of the bit (the preferred condition) which can be as high as 350-400 hours.
Thus, drilling with a downhole motor and a bent sub has disadvantages of being expensive and time consuming because of the trips in and out of the borehole when steering to each desired new angle, and this approach is unreliable because the downhole motor has a greater tendency to break down under these conditions.
Later, steering tools that were directly attached to the drill string were developed. Modern steering tools of this type are either discrete or integrated. Discrete steering tools include Halliburton's TRACS 2D, Maersk's “wall grabber” style tool, Directional Drilling Dynamics' tool that rotates through a bend, and the Cambridge Radiation tool that includes a non-rotating body that deflects the drill string.
Integrated steering tools are part of an assembly of other downhole tools including downhole sensors. Suppliers of these include Halliburton's TRACS 2D, Smith Red Barron which includes a non-rotating near bit stabilizer (Wall Grabber), and the ANADRILL tool that is being integrated into a Camco tool. Baker Hughes Inteq has the AUTO TRAK tool that includes directional resistivity and vibration measurements. Camco has a 3-D SRD tool with sensors that can perform five jobs without a major overhaul.
Certain prior art steering tools can change azimuth and inclination simultaneously. These tools, one of which is manufactured by Schlumberger, utilizes three pistons which extend laterally outwardly from the drill string at different distances to push the drill string off center to change orientation of the drill string. This approach avoids use of a bent sub. However, use of pistons in a small diameter drill hole to make steering adjustments is not desirable; and they are costly and less reliable because of the large number of mechanical parts.
The previously mentioned MWD system is a separate standalone assembly comprising survey equipment which uses an inclinometer or accelerometer for measuring inclination and a magnetometer for measuring azimuth angle. Inclination angle is typically measured away from vertical (90 degrees from the horizontal plane), and azimuth angle is measured as a rotational angle in a horizontal plane, with magnetic North at zero degrees and West at 270 degrees, for example.
There is a need for a low cost, highly reliable, long life three-dimensional rotary drilling tool that provides steering in both azimuth and inclination while drilling. It is also desirable to provide a steering tool which can change both inclination and azimuth angles without use of a downhole motor and bent sub and the time consuming and expensive trips to the surface for changing orientation of the steering tool. It would also be desirable to avoid use of wall grabber type systems that require contact with the wall of the borehole to push the drill string off center in order to change drilling angles.
The present invention provides a steering tool which can change inclination and azimuth angles either continuously (simultaneously) or incrementally while rotary drilling and while making such steering adjustments in three dimensions. Changes in inclination and azimuth while rotary drilling can be made with drilling fluid flowing through the drill string and up the bore. The steering assembly of this invention can respond to electrical signals via onboard mud pulse telemetry to control the relative azimuth and inclination angles throughout the drilling process. Such three dimensional steering can be achieved without stopping the drilling process, without use of a downhole motor or bent sub, and without borehole wall contacting devices that externally push the drill string toward a desired orientation. The invention provides a steering tool having lower cost, greater reliability, and longer life than the steering tools of the prior art, combined with the ability to improve upon long reach angular drilling in three dimensions with reduced torque and drag.
Briefly, one embodiment of the invention comprises a three-dimensional steering tool for use in drilling a borehole in an underground formation in which an elongated conduit extends from the surface through the borehole and in which the steering tool is mounted on the conduit near a drill bit for drilling the borehole. The steering tool comprises an integrated telemetry section, rotary section and flex section. The steering tool includes an elongated drive shaft coupled between the conduit and the drill bit. The flex section includes a deflection actuator for applying a lateral bending force to the drive shaft for making inclination angle adjustments at the drill bit. The rotary section includes a rotator actuator for applying a rotational force transmitted to the drive shaft for making azimuth angle adjustments at the drill bit. The telemetry section measures inclination angle and azimuth angle during drilling and compares them with desired inclination and azimuth angle information, respectively, to produce control signals for operating the deflection actuator to make steering adjustments in inclination angle and for operating the rotator actuator for making steering adjustments in azimuth angle.
In another embodiment of the invention, the flex section includes an elongated drive shaft coupled to the drill bit, and a deflection actuator for hydraulically applying a lateral bending force lengthwise along the drive shaft for making changes in the inclination angle of the drive shaft which is transmitted to the drill bit as an inclination angle steering adjustment. The rotary section is coupled to the drive shaft and includes a rotator housing for transmitting a rotational force to the drive shaft to change the inclination angle of the drive shaft which is transmitted to the drill bit as an azimuth angle steering adjustment. The telemetry section includes sensors for measuring the inclination angle and azimuth angle of the steering tool while drilling. Command signals proportional to the desired inclination angle and azimuth angle of the steering tool are fed to a feedback loop for processing measured and desired inclination angle and azimuth angle data for controlling operation of the deflection actuator for making inclination angle steering adjustments and for controlling operation of the rotator actuator for making azimuth angle steering adjustments.
In an embodiment of the invention directed to rotary drilling applications, a rotary drill string extends from the surface through the borehole, and the steering tool is coupled between the rotary drill string and a drill bit at the end for drilling the borehole. The steering tool includes an elongated drive shaft coupled between the drill string and the drill bit for rotating with rotation of the drill string when drilling the borehole. The flex section comprises a deflection actuator which includes a deflection housing surrounding the drive shaft and an elongated deflection piston movable in the deflection housing for applying a lateral bending force lengthwise along the drive shaft during rotation of the drill string for changing the inclination angle of the drive shaft to thereby make inclination angle steering adjustments at the drill bit. The rotary section includes a rotator housing surrounding the drive shaft and coupled to the deflection housing. A rotator piston contained in the rotator housing applies a rotational force to the deflection housing to change the azimuth angle of the drive shaft during rotation of the drill string to thereby make azimuth angle steering adjustments at the drill bit. The telemetry section measures present inclination angle and azimuth angle during drilling and compares it with desired inclination and azimuth angle information to produce control signals for operating the deflection piston and the rotator piston to make steering adjustments in three dimensions.
The description to follow discloses an embodiment of the telemetry section in the form of a closed loop feedback control system. One embodiment of the telemetry section is hydraulically open loop and electrically closed loop although other techniques can be used for automatically controlling inclination and azimuth steering adjustments.
Although the description to follow focuses on an embodiment in which the steering tool is used in rotary drilling applications, the invention can be used with both rotary and coiled tubing applications. With coiled tubing a downhole mud motor precedes the steering tool for rotating the drill bit and for producing rotational adjustments when changing azimuth angle, for example.
In one embodiment in which inclination and azimuth angle changes are made simultaneously, the steering tool can include a packerfoot (gripper) for contacting the wall of the borehole to produce a reaction point for reacting against the internal friction of the steering tool, not the rotational torque of the drill string.
These and other aspects of the invention will be more fully understood by referring to the following detailed description and the accompanying drawings.
Referring to
The steering tool is controlled by the mud pulse telemetry section 22 and related surface equipment. The mud pulse telemetry section at the surface includes a transmitter and receiver, electronic amplification, software for pulse discrimination and transmission, displays, diagnostics, printout, control of downhole hardware, power supply and a PC computer. Within the tool are a receiver and transmitter, mud pulser, power supply (battery), discrimination electronics and internal software. Control signals are sent from the mud pulse telemetry section to operate onboard electric motors that control valves that power the rotary section 24 and the inclination or flex section 26. The steering tool is equipped with standard tool joint threaded connections to allow easy connection to conventional downhole equipment such as the drill bit 28 or drill collars.
For the rotary section, the drilling fluid in the input line 38 enters the inlet side of a rotary control valve 56, preferably a three position, four port drilling fluid valve. When the rotary section is operated to produce rotation of the steering tool, for adjustments in azimuth angle, the control valve 56 opens to pass drilling fluid through a line 58 to a rotator piston 60 schematically illustrated in FIG. 3. The rotator piston functions like a double-acting piston; it moves linearly but is engaged with helical gears to produce rotation of the deflection housing containing the flex piston. Drilling fluid enters the rotator piston which travels on splines to prevent the piston's rotation. The piston drives splines that rotate the deflection housing 42 and thus, the orientation of the flex shaft, which causes changes in the azimuth angle of the steering tool. Drilling fluid from the rotator piston is re-circulated back to the rotary section valve 56 through a return line 61. Piston travel of the rotator piston is measured by a rotary position transducer 62 that produces a position signal measuring the instantaneous position of the rotator piston. The rotary position signal is provided as a position feedback signal in a closed loop feedback control system described below. The feedback signal is proportional to the amount of travel of the rotator piston for use in producing desired rotation of the steering tool for making azimuth angle adjustments. After the steering tool has achieved the desired azimuth adjustment, the rotary section valve is shifted to allow the fluid to drain through a discharge line 64 to the annulus.
The mud pulse telemetry section 70 includes surface hardware and software 76, a transmitter and receiver 78, an actuator controller 80, a power supply (battery or turbine generator) 82, and survey electronics with software 84. The survey equipment uses a inclinometer or accelerometer for measuring inclination angle and a magnetometer for measuring azimuth angle. The mud pulse telemetry receives inclination and azimuth data periodically, and the controller translates this information to digital signals which are then sent to the transmitter which comprises a mud pulse device which exhausts mud pressure into the annulus and to the surface. Standpipe pressure variations are measured (with a pressure transducer) and computer software is used to produce input signal information proportional to desired inclination and azimuth angles. The position of the tool is measured in three dimensions which includes inclination angles (tool face orientation and inclination) and azimuth angle. Tool depth is also measured and fed to the controller to produce the desired inclination and azimuth angle input data.
The mud pulse telemetry section includes 3-D steering tool control electronics 86 which receive data inputs 88 from the survey electronics 84 to produce steering input signals proportional to the desired inclination angle and azimuth angle. In the flex section controller 72, a desired inclination angle signal 90 is fed to a comparator 92 along with an inclination angle feedback signal 94 from the flex position transducer 54. This sensor detects positional changes from the flex section piston, as described above, and feeds that data back to the comparator 92 which periodically compares the feedback signal 94 with the desired inclination angle input signal 90 to produce an inclination angle error signal 100. This error signal is fed to a controller 102 which operates the flex section valve motor 98 for making inclination angle adjustments.
In the rotary section control loop 74 a desired azimuth angle signal 104 is fed to a comparator 106 along with a rotary position feedback signal 108 from the rotary position transducer 62. This sensor detects positional changes from the rotator section piston described above and feeds that position data back to the comparator 106 which compares the feedback signal 108 with the azimuth angle input signal 104 to produce an error signal 114 for controlling azimuth. The error signal 114 is fed to a controller 116 which controls operation of the rotary valve section motor 112 for making azimuth angle adjustments.
The flex position sensor 54, which is interior to the steering tool, measures how much the flex shaft is deflected to provide the position feedback information sent to the comparator. The rotary position sensor 62 measures how much the rotator piston is rotated. This sensor is located on the rotator piston and includes a magnet which moves relative to the sensor to produce an analog output which is fed back to the comparator 106.
A packerfoot 118 is actuated to expand into the annulus and make contact with the wall of the borehole in situations where changes in inclination angle and azimuth angle are made simultaneously. The packerfoot is described in more detail below. An alternative gripper mechanism can be used to assist the rotary section. One of these is the Flextoe Packerfoot, which has a multiplicity of flexible members (toes) that are deflected onto the hole wall by different mechanisms, including inflating a bladder, or lateral movement of a wedge-shaped element into the toe. These are described in U.S. patent application Ser. No. 09/453,996, incorporated herein by reference. These gripping elements may incorporate the use of a mandrel and splines that allow the gripper to remain in contact to the hole wall while the tool advances forward. Alternatively, the component can remain in contact with the hole wall and be dragged forward by the weight of the system. The design option to drag or allow the tool to slide relative to the gripper depends upon the loads expected within the tool for the range of operating conditions of azimuth and inclination angle change.
The cross-sectional view of
The exploded perspective view of
The cross-sectional view of
The cross-sectional view of
The relatively stiff deflection housing provides a structural reaction point for the internal flex shaft. The internal support structure provides a means for allowing the flex shaft to react against. As mentioned, the deflection piston runs the length of the flex section and the pressure is applied to the top of the piston to displace the flex shaft. The amount of this displacement of the deflection piston is greatest at its mid section between the hemispherical bearings at the ends of the flex section. The space is provided to allow the deflection piston to move or deflect within the deflection housing and this deflection varies along the length of the tool and is greatest at the midpoint between the hemispherical end bearings.
The flex shaft 120 rotates within the deflection piston 136. The region between the deflection housing and the flex shaft has its hydraulic bearing 164 lubricated either by mud (if in an open system which is preferred) or hydraulic oil (if sealed) and may include Teflon low friction materials. Pressure delivered between the deflection housing and the deflection piston (through the line 148) moves both the deflection piston and the flex shaft, while the flex shaft rotates with the drill string.
The reaction points for the skin and deflection housing are the multiple stabilizers 124 located on the forward and aft ends of the tool, although in one configuration a third set of stabilizers is located at the center, as shown in the drawings. The stabilizers may be either fixed or similar to a non-rotating style hydraulic bearing. The stabilizers cause the skin and the deflection housing to be relatively rigid compared to the flex shaft.
In one embodiment, the deflection housing and deflection housing cap are both made from rigid materials such as steel. The flex shaft, in order to facilitate bending, is made from a moderately high tensile strength material such as copper beryllium.
Control for the flex section may be located in either the flex section or the rotary section but preferably in the rotary section. Again, the mud pulse telemetry is used to provide controls to the steering tool. Mud pulses are sent down the bore of the drill string, received by the mud pulse telemetry section, and then commands are sent to the flex and rotary sections. The flex section's electrical controls operate the electrical motor in a pressure compensated environment which controls the valve that delivers a desired drilling fluid pressure to the deflection housing, producing a desired change in inclination. The inclination angle changes produced by flexing the flex shaft and transmitted to the steering tool are at the end of the flex shaft.
The transducer used to measure deflection of the flex shaft or deflection housing provides feedback signals measuring the change in inclination of the tool as described previously. Other means of measuring flex shaft deflection can be used. Different types of displacement transducers can be used to determine the displacement of the shaft.
Significantly, because of this system design, the steering tool can be operated to change either inclination or azimuth separately and incrementally, or inclination or azimuth continuously and simultaneously, thus avoiding the downhole problem of differential sticking.
The aft end of the deflection housing is equipped with teeth that mesh into matching teeth in the rotary section. The joining of the deflection housing to the rotary section allows the rotary section to rotate the deflection housing to a prescribed location. The size and number of teeth can be varied depending upon tool size and expected deflection range of the flex section. The construction and operation of the rotary section is described as follows.
Referring to
A filter/diffuser 173 is contained within the motor housing, and drilling fluid passes through the drive shaft via a multiplicity of holes and into the filter/diffuser. Drilling fluid from the flex section valve 40 moves through flow passages through a valve housing 175 to the deflection housing 132, thereby pressurizing the flex piston 136. The flex valve housing is mounted in a recess in the rotary section opposite from the rotary valve housing. The flex section valve 40 is a spool type valve made tungsten carbide. Fluid returning from the deflection housing is discharged to the annulus between the steering tool and the wall of the borehole.
Referring to
The perspective view of
The rotary section achieves changes in the azimuth by the following method. At the surface, a signal is sent to the tool via the mud pulse telemetry section. The mud pulse telemetry section receives the mud pulse, translates the pulse into electrical instructions and provides an electrical signal to the 3-D control electronics. (Pressurization and actuation of the flex piston has been described previously. Both the rotary and flex sections are pressurized and actuated simultaneously for the steering tool to produce both azimuth and inclinational changes.) The 3-D electrical controls provide an electrical signal to either or both of the electric motors for the rotary and the flex section valves. When the rotary valve is actuated, fluid from the bore passes through the filter and into the valve that delivers drilling fluid to the double-acting piston. The double-acting piston is moved forward for driving the helical gears connected via a coupling to the deflection housing, which rotates relative to the flex shaft. The position of the double-acting piston allows positioning from zero to 360 degrees in clockwise or counter-clockwise rotation, thus changing the orientation of the deflection housing relative to the skin (which is resting on the hole wall thus providing a reaction point). Drilling fluid under pressure is delivered to the flex section and azimuthal change begins as follows. (Drilling fluid under pressure can be applied via the method described to the reverse side of the double-acting piston to re-position the housing in a counter-clockwise orientation.)
After the tool has drilled ahead enough to allow the drill string to follow the achieved azimuth, the valve changes position, the double-acting piston receives drilling fluid, the flex piston is returned to neutral, and straight drilling resumes.
The present invention can be applied to address a wide range of drilling conditions. The steering tool can be made to operate in all typical hole sizes from 2⅞ inch slim holes up to 30-inch holes, but is particularly designed to operate in the 3¾-inch up to 8¾-inch holes. The tool length is variable, but typically is approximately 20 feet in length. The tool joint coupling and threaded end of the flex shaft can have any popular oil field equipment thread such as various American Petroleum Institute (API) threads. Threaded joints can be made up with conventional drill tongs or similar equipment. The tool can withstand a range of weight on bit up to 60,000 pounds, depending upon tool size. The inside diameter of the drive shaft/flex shaft can be range from 0.75 to 3.0 inches to accommodate drilling fluid flow rates from 75-650 gallons per minute. The steering tool can operate at various drilling depths from zero to 32,000 feet. The steering tool can operate over a typical operational range of differential pressure (the difference of pressure from the ID of the steering tool to outside diameter of the tool) of about 600 to 3,500 PSID, but typically up to about 2,000 PSID. The size of the drive shaft/flex shaft can be adjusted to accommodate a range of drilling torque from 300 to 8,000 ft-lbs. depending upon tool size. The steering tool has sufficient strength to survive impact loads to 400,000 lbs. and continuous absolute overpull loads to 250,000 lbs. The tool's drive shaft can operate over the typical range of rotational speeds up to 300 rpm.
In addition, the rotary section and flex section require little drilling fluid. Because the rotary section drilling fluid system is of low volume, the operation of the rotary section requires from less than 4 GPM to operate. The flex section is also a low volume system and can operate on up to 2 GPM. Thus, the steering tool can perform its function with up to 6 GPM, which is from 1 to 5% of the total drilling fluid flowing through the tool.
For the rotary section, the velocity of the rotary double-acting piston can range from 0.002 inches per minute to up to 8 inches per minute depending upon the size of the piston, flow channel size, and helical gear speed.
The steering tool control section includes a helical screw position sensor or potentiometer (not shown), as well as the previously described mud pulse telemetry actuator/controller electronics, survey electronics, 3-D control electronics, power supply, and transmitter.
One type of flex position transducer can be a MIDIM (mirror image differential induction-amplitude magetometer). With this design, a small magnetic source is placed on the flex piston or the rotary double acting piston and the MIDIM (manufactured by Dinsmore Instrument Company, 1814 Remell St. Flint, Mich. 48503) within the body of the deflection housing or the rotary housing, respectively. As the magnetic source moves as a result of the pressure on the piston, a calibrated analog output provides continuous reading of displacement. Other acceptable transducers that use the method described above include a Hall effect transducer and a fluxgate magnetometer, such as the ASIC magnetic sensor available from Precision Navigation Inc., Santa Rosa, Calif.
The mud pulse telemetry section provides the control information to the surface. These systems are commercially available from such companies as McAllister-Weatherford Ltd. of Canada and Geolink, LTD, Aberdeen, Scotland, UK as are several others. Typically these systems are housed in 24 to 60-inch long, 2⅞ to 6¾-inch outside diameter, 1 to 2 inch inside diameter packages.
Included in the telemetry section is a mud pulse transmitter assembly that generates a series of mud pulses to the surface. The pulses are created by controlling the opening and closing of an internal valve for allowing a small amount of drilling fluid volume to divert from the inside the drill string to the annulus of the borehole. The bypassing process creates a small pressure loss drop in the standpipe pressure (called negative mud pulse pressure telemetry). The transmitter also contains a pressure switch that can detect whether the mud pumps are switched on or off, thus allowing control of the tool.
The actuator/controller regulate the time between transmitter valve openings and the length of the pulse according to instructions from the survey electronics. This process encodes downhole data to be transmitted to the surface. The sequence of the data can be specified from the surface by cycling the mud pumps in pre-determined patterns.
The power supply contains high capacity lithium thionyl chloride batteries or similar long life temperature resistance batteries (or alternatively a downhole turbine and electrical generator powered by mud).
The survey electronics contain industry standard triaxial magnetometers and accelerometers for measuring inclination (zero to 180 degrees), and azimuth (zero to 360 degrees) and tool face angle (zero to 360 degrees). Tool face angle is the orientation of the tool relative to the cross-section of the hole at the tool face. Included are typically microprocessors linked to the transmitter switch that control tool functions such as on-off and survey data. Other types of sensors may also be placed in the assembly as optional equipment. These other sensors include resistivity sensors for geological formation information or petroleum sensors.
The data are transmitted to the surface computer system (not shown). At the surface, a transmitter and receiver transmits and receives mud pulses, converts mud pulses to electrical signals, discriminates signal from noise of transmissions, and with software graphically and numerically presents information.
The surface system can comprise a multiplexed device that processes the data from the downhole tool and also directs the information to and from the various peripheral hardware, such as the computer, graphics screen, and printer. Also included can be signal conditioning and intrinsic safety barrier protections for the standpipe pressure transducer and rig floor display. The necessary software and other hardware are commercially available equipment.
Instructions from the mud pulse telemetry section are delivered to the 3-D control electronics, (the electrical control and feedback circuits described in the block diagrams). The 3-D control electronics receive and transmit instructions to and from the actuator/controller to provide communication and feedback to the surface. The 3-D steering electronics also communicate to the rotary position sensor and the flex position sensor. A feedback circuit (as described in the block diagram of
Thus, changes in direction are sent from the surface to the steering tool through the surface system, to the actuator/controller, to the 3-D steering electronics, and to the electric motors of the rotary and flex section valves that move either the flex piston or rotary double-acting piston. The new position of the piston is measured by the sensor, compared to the desired position, and corrected if necessary. Drilling continues with periodic positional measurements made by the survey electronics, sent to the actuator/controller to the transmitter, and then to the surface, where the operator can continue to steer the tool.
The electrical systems are designed to allow operation within downhole pressures (up to 16,000 PSI). This is typically accomplished with atmospheric isolation of electrical components, specially designed electrical connectors that operate in the drilling environments, and thermally hardened electronics and boards.
The steering tool can include an optional flex toe gripper whose purpose is to ensure a fixed location of the tool to an azimuth orientation. When the flex toe is activated it grips the wall of the borehole for making changes in inclination and/or azimuth. The flex toe design includes flex elements that are pinned at one end and slide on the opposite end. Underneath the flex elements are inflatable bladders that are filled with drilling fluid when pressurized and collapse when depressurized. Drilling fluid is delivered to the bladder via a motorized valve, typically the rotary valve described previously. The valve is controlled in a manner similar to the motorized valves for the flex section or rotary section via mud pulse telemetry or similar means.
The flex toe is optional depending upon the natural tendency for the 3-D steering tool's skin not to rotate; it can be provided as an option to resist minor twisting of the drill string and maintain a constant reference for the tool motion.
In a similar manner to the flex toe, a packerfoot (shown schematically in
Specific types of materials are required for parts of the steering tool. Specifically, the shaft and flex piston must be made of long fatigue life material with a modulus lower than the skin and housing. Suitable materials for the shaft and flex piston are copper-beryllium alloys (Young's modulus of 19 Million PSI). The tool's skin and housing can be various steel (Young's modulus of 29 Million psi) or similar material.
Specialized sealing materials may be required in some applications. Numerous types of drilling fluids are used in drilling. Some of these, especially oil-based mud or Formate muds are particularly damaging to some types of rubbers such as NBR, nitrile, and natural rubbers. For these applications, use of specialized rubbers such as tetraflourethylene/propylene elastomers provides greater life and reliability.
The tool operates by means of changes in inclination or by changes of azimuth in separate movements, but not necessarily both simultaneously. Typical operation includes drilling ahead, telemetry to the 3-D steering tool, and changes in the orientation of the drill bit, followed by change in the inclination of the bore hole. The amount of straight hole drilled before changes in inclination can be as short as the length of the 3-D steering tool.
For azimuthal changes, drilling ahead continues (with no inclination), telemetry from the surface to the tool with instruction for changes in azimuth, internal tool actions, followed by change in the azimuth of the bore hole.
Other instruments can be incorporated into the steering tool, such as Weight-on-Bit, Torque-on-Tool, bore pressure, or resistivity or other instrumentation.
This application is a division of application Ser. No. 10/282,481, filed Oct. 28, 2002, now U.S. Pat. No. 6,708,783 which is a continuation of application Ser. No. 09/549,326, filed Apr. 13, 2000, now U.S. Pat. No. 6,470,974 which claims the priority of U.S. provisional application No. 60/129,194, filed Apr. 14, 1999. The entire disclosures of these applications are incorporated herein by reference.
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| Child | 10697575 | US |
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| Child | 10282481 | US |
