DOWNHOLE TELEMETRY SYSTEMS WITH VOICE COIL ACTUATOR
FIELD
[0001] The present disclosure relates generally to oilfield drilling and production, and
more particularly, but not by way of limitation, to systems and methods for communicating
information from downhole to the surface using pulse telemetry that includes one or more
voice-coil actuators.
BACKGROUND
[0002] Drilling and production operations are improved with greater quantities of
information relating to the conditions and drilling parameters downhole. The information is at
times obtained by removing the drilling assembly and inserting a wireline logging tool. With
great frequency today, information is obtained while drilling with measurement while drilling
(MWD) or logging while drilling (LWD) techniques. Often while drilling, operators would like
to know the direction and inclination of the drill bit, temperature and pressure of the wellbore,
etc. To accomplish this, sensors or detectors are used downhole. Yet, one challenge is to get
the information—or at least a portion of it—to the surface during operations.
[0003] To this end, a number of techniques have been developed. For example, in pulse
telemetry, acoustic pressure signals are created and sent through the drilling fluid. Still, issues
and shortcoming exist with this and similar techniques.
BRIEF DESCRIPTION OF THE DRAWINGS
[0004] FIGURE 1 is a schematic, elevational view with a portion of a formation shown
in cross-section showing a pulse telemetry system for communicating digital data from a
wellbore to a surface unit;
[0005] FIGURE 2 is a elevational, schematic diagram of an illustrative embodiment of a
pulse telemetry system;
[0006] FIGURE 3 is a schematic diagram of an illustrative, non-limiting embodiment of
a voice coil actuator;
[0007] FIGURE 4 is a schematic plot for two curves under ideal conditions (resistance
not included);
[0008] FIGURE 5 is a schematic diagram of a processing unit;
[0009] FIGURE 6 is a schematic circuit diagram of an illustrative embodiment of a
control unit 600; and
[0010] FIGURE 7 is a schematic flow diagram of an illustrative embodiment of one
method for transmitting data developed in a wellbore to a surface unit.
DETAILED DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS
[0011] In the following detailed description of the illustrative embodiments, reference is
made to the accompanying drawings that form a part hereof. These embodiments are described
in sufficient detail to enable those skilled in the art to practice the invention, and it is understood
that other embodiments may be utilized and that logical structural, mechanical, electrical, and
chemical changes may be made without departing from the spirit or scope of the invention. To
avoid detail not necessary to enable those skilled in the art to practice the embodiments
described herein, the description may omit certain information known to those skilled in the art.
The following detailed description is not to be taken in a limiting sense, and the scope of the
illustrative embodiments is defined only by the appended claims.
[0012] In the drawings and description that follow, like parts are typically marked
throughout the specification and drawings with the same reference numerals, respectively. The
drawing figures are not necessarily to scale. Certain features of the invention may be shown
exaggerated in scale or in somewhat schematic form and some details of conventional elements
may not be shown in the interest of clarity and conciseness.
[0013] Unless otherwise specified, any use of any form of the terms "connect,"
"engage," "couple," "attach," or any other term describing an interaction between elements is
not meant to limit the interaction to direct interaction between the elements and may also
include indirect interaction between the elements described. In the following 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 . . . ". Unless otherwise indicated,
as used throughout this document, "or" does not require mutual exclusivity.
[0014] As used herein, the terms "seal", "sealing", "sealing engagement" or "hydraulic
seal" are intended to include a "perfect seal", and an "imperfect seal. A "perfect seal" may refer
to a flow restriction (seal) that prevents all fluid flow across or through the flow restriction and
forces all fluid to be redirected or stopped. An "imperfect seal" may refer to a flow restriction
(seal) that substantially prevents fluid flow across or through the flow restriction and forces a
substantial portion of the fluid to be redirected or stopped.
[0015] Referring now to the drawings, FIGURE 1 is a schematic, elevational view with
a portion of a formation shown in cross-section showing a pulse telemetry system 100 for
communicating digital data from a wellbore 102 to a surface unit 104. A derrick 106 is
positioned over the well 108 with its wellbore 102. A drillpipe 110 is disposed within the
wellbore 102. The drillpipe 110 has a downstream portion 11 1 and an upstream portion 113.
"Upstream" means a further upstream or further against the basic direction of fluid flow from
wellbore toward the surface in the pipe under normal circumstances, and "downstream" means
further in the same direction as the fluid flow under normal circumstances. The space between
the wellbore 102 and an exterior of the drillpipe 110 defines an annulus 112.
[0016] The drillpipe 110 includes a central passageway 114 that defines an interior
portion of the drillpipe 110. A subassembly 116, which includes a drill collar 118, is coupled to
a drill bit 120 and is coupled to or includes the drillpipe 110. The subassembly 116 includes
one or more logging tools, detectors, or sensors 122 for developing information about the
formation 124 or the drilling process. The one or more sensors 122 includes one or more of the
following: gamma ray sensor, azimuthal sensor, borehole pressure sensor, temperature sensor,
vibration sensor, shock sensor, torque sensor, porosity sensor, density sensor, resistivity sensor,
etc.
[0017] Also disposed downhole and associated with the drillpipe 110 is the pulse
telemetry system 100. The pulse telemetry system 100 may formed as part of or couple to the
subassembly 116. The pulse telemetry system 100 uses one or more valves that include voice
coil actuators to modulate the flow of drilling fluid, or mud, in a portion of the drillpipe 110 to
generate pulses that travel through or are carried on the drilling fluid to the surface unit 104
where they are further processed. The pulse telemetry system 100 may be a negative pressure
telemetry system or could be a positive pressure system. In the negative pressure telemetry
system, the valves are momentarily opened outside of the drillpipe 110 to create a quick
pressure drop, or negative pressure, pulse that propagates through the drilling fluid to the
surface unit 104. In a positive system, the valve or valves restrict the flow of drilling fluid for a
brief moment to build a pressure pulse that again propagates through the drilling fluid to the
surface unit 104.
[0018] As will be explained further below, the pulse telemetry system 100 uses a voice
coil actuator to move one or more valve components, e.g., a plunger, to either restrict flow or
vent flow to cause pressure pulses for telemetry. The voice coil actuator is believed to be an
improvement over designs that use solenoids. As contemplated here, the voice coil actuators
may provide a strong electrical-to-mechanical energy conversion efficiency, strong force-to size
ratio, quick response times—potentially allowing larger data transmission rates, lighter
components, longer service life, minimal maintenance, and avoiding of off-centering effects.
The voice coil actuators are named from use of the technology in sound speakers. The voice
coil actuator will be further described elsewhere.
[0019] The drillpipe 110 may extend downwardly from an elevator assembly 126, which
is suspended from the derrick 106, through a rotary table 128. The rotary table 128 causes the
drillpipe 110 to rotate and the drill collar and ultimately the drill bit 120 to rotate. Drilling fluid
is circulated to the drill bit 120 to assist with the drilling. For example, the drilling fluid may
cool the drill bit 120 and remove cuttings.
[0020] A tank 130 stores the drilling fluid at the surface 132. A pipe 134 may be used to
move the drilling fluid from the tank 130 through a drilling- fluid pump 136 into a pipe 138 that
leads to standpipe 140. The standpipe 140 is coupled to the drillpipe 110 by a flexible conduit
142. The drilling-fluid pump 136 pulls drilling fluid from the tank 130 and moves the drilling
fluid along the pipes/conduits 138, 140, 142 and into the central passageway 114 of the drillpipe
110 to the subassembly 116. The drilling fluid passing through the subassembly 116 exits
proximate to the drill bit 120 and returns to the surface through the annulus 112 and is delivered
through pipe 143 to the tank 130. The drilling fluid in tank 130 may be reconditioned (cuttings
removed and degassed etc.) and reused. It should be noted that tank 130 may comprise two
tanks—one with ready-to-use drilling fluid coupled to pipe 134 and one for receiving used
drilling fluid from pipe 143.
[0021] The surface unit 104 may, amongst other things, decode pressure pulses, or
transitions, sent over the drilling fluid in the central passageway 114. The surface unit 104 may
include one or more surface sensors or transducers 144. For example, an array of sensors 144
might be spaced for noise cancellation. The transducer 144 is shown on pipe 138 for sensing
the pressure transitions, or pulses, from the pulse telemetry system 100. Other components such
as sensors to assist with noise cancellation or a desurger 146 (to minimize surges from pump
136) or other devices may be included. A valve 148 may be included on pipe 138 to induce
pulses via the drilling fluid in central passageway 114 to deliver data or instructions from the
surface 132 to subassembly 116. The valve 148 may include a voice coil actuator and may
function analogous to the valve in the subassembly 116 described further below. In such an
embodiment, a decoder may be included in the subassembly for receiving data or commands
through pulses initiated by the valve 148. The pulses traveling downward may be used to
control aspects of the subassembly 116.
[0022] The surface unit 104 may include one or more processors, e.g., microprocessors,
associated with one or more memories, drive and control circuitry for downlink communication
and detection circuit for uplink communications. The one or more processors and one or more
memories are operable to carry out steps including receiving the pressure transitions or pulses,
which have been acquired by detection circuit, and decoding them into data in formats desired
in an uplink mode. In the downlink mode, the one or more processors and one or more
memories are able to encode the data and transmit the encoded data to a downhole device via
the drive and control circuit.
[0023] Referring now primarily to FIGURE 2, a schematic diagram of an illustrative
embodiment of a pulse telemetry system 100 is presented. The pulse telemetry system 100
includes a valve 202 that includes a voice coil actuator 204. The valve 202 may be any type
that restricts or opens the flow of the drilling fluid as result of movement of one or more
components by the voice coil actuator 204. For example, the valve 202 may include a plunger
or piston (not explicitly shown) that is moved by a portion of the voice coil actuator 204.
[0024] The central passageway 114 of the drillpipe 110 continues into the subassembly
116 and splits into at least two passageways: a bypass passageway 206 and an input passageway
208. An outlet passageway 210 delivers drilling fluid from the valve 202 toward the drill bit
120 (FIG. 1). The drilling fluid in the outlet passageway 210 is united with the drilling fluid
from bypass passageway 206. In other embodiments, the bypass passageway 206 may be
omitted. For example, in a completely restricted positive valve, the bypass passageway 206
may be omitted. In a negative valve arrangement, the outlet passageway may penetrate the
collar of the subassembly 116 into the annulus to divert a portion of the drilling fluid.
[0025] A processing unit 2 12 is associated with the voice coil actuator 204. The
processing unit 212 is coupled to the one or more sensors 122 for receiving data therefrom. The
processing unit 212 may include one or more processors and one or more memories associated
with the one or more processors. The one or more processors and one or more memories are
shown generally by numeral 214. A control unit 216 is associated with the one or more
processors and one or more memories 214 and the voice coil actuator 204. The control unit 216
will be described more in connection with FIGURES 5 and 6 below.
[0026] A power unit 218 may be included to provide power to the one or more
processors and one or more memories 214, control unit 216, or voice coil actuator 204. The
power unit 218 may be a generator, battery, or other device. A differential pressure transducer
220 may be included to measure pressure of the drilling fluid across the valve 202. Thus, the
differential pressure transducer 220 may measure pressure at the inlet passageway 208 and the
outlet passageway 210. The resultant pressure differential may be delivered to the one or more
processors and one or more memories 214 or the control unit 216.
[0027] While one illustrative valve arrangement is shown in FIGURE 3, it should be
understood that numerous valve designs might be used. Yet, all the valve designs include a
voice coil actuator.
[0028] Referring now primarily to FIGURE 3, a schematic diagram of an illustrative,
non-limiting embodiment of a voice coil actuator 300 suitable for use as the voice coil actuator
204 in FIGURE 2 to manipulate the valve 202 is presented. FIGURE 3 is a simplified diagram
to present the main concepts, and those skilled in the art will understand that other arrangements
are possible. More particularly, FIGURE 3 is a sectional view of one cylindrical voice coil
actuator 300 along its axis and with a portion removed. The voice coil actuator 300 includes a
shell 302, which may be formed from a soft-magnetic material, and which is an E-type
cylindrical member. The shell 302 forms an "E" or "EP" shape with members: an outer
member 308, which is typically cylindrical in shape, and a center-post member 309. The voice
coil actuator 300 also includes a permanent magnet 312 that is coupled to at least a portion of an
interior portion or surface 310 of the outer member 308. The center-post member 309 may be
coupled with a permanent magnet paired to the magnet 312. A coil 326 is cylindrically wrapped
around a coil holder 320 to carry the current. The coil 326 and coil holder 320 form the
armature of the actuator in a one embodiment, although permanent magnet 312 and shell 302
may also form the armature. Either way, a small air gap 323 is formed between permanent
magnet and coil holder 320. The air gap 323 may be filled with oil or other lubricant for cooling
and lubrication purpose.
[0029] The coil holder 320 may be made of numerous materials including, without
limitation, aluminum alloy, titanium, steel, ceramic, composite materials, etc. A plungerconnect
linkage or other linkage 332 may be used to couple the coil holder 320 to one or more
components of the valve 202 (FIG. 2) to manipulate flow or pressure through the valve 202.
The magnetic field is shown by lines 334. The direction of flow of current in the coils 326, i.e.,
coil current, influences the direction of the force on linkage 332.
[0030] The voice coil actuator 300 develops an electromagnetic force delivered to
linkage 332. The force in the present system is used to move one or more components of the
valve 202 to create negative or positive pressure transitions, or pulses. While not being limited
by theory, the voice coil actuator 300 uses a macroscopic form of Lorentz Force, namely, a
magnetic force acting on a current-carrying conductor. The voice coil actuator 300 typically
includes the one or more permanent magnets 312 that generate the magnetic field, the magnetic
shell 302, e.g., soft magnetic shell, for producing a magnetic field with low reluctance, one or
more coils 326 for current flow that interacts with the magnetic field, and the coil holder 320,
which not only provides physical support to the coil 326 but also functions as an armature to
transfer mechanical force to linkage 332.
[0031] The force developed by the voice coil actuator 300 may be approximated with
the following equation:
[0032] F = N * B* * (1)
[0033] Where:
[0034] i is an average circular length of the coil(s);
[0035] B is a magnetic flux density;
[0036] I is a current of the coil(s);
[0037] N is the number of turns of the coil(s); and
[0038] F is the mechanical force applied to the linkage 332.
[0039] The permanent magnet arrangement 312 can generate a substantially uniform
magnetic field in the air gap 323 where the coil 326 and coil holder 320 move in an axial
direction. According to the Lorentz Force law, the force acting on the coil is shown by equation
(1) above.
[0040] The voice coil actuator force, F, has a relatively simple relation as shown in
equation (1). If one ignores the effect of coil current on the permanent magnet 312, the voice
coil actuator force is a linear function of coil current. Moreover, the direction of the force also
depends on the direction of the current. These characteristics may make the voice coil actuator
300 a highly controllable device.
[0041] The voice coil actuator 300 has good power conversion efficiency compared to
many other devices. There is only a little change in the magnetic flux density due to coil current
effect, which may weaken or strengthen the magnetic field depending on the direction of coil
current. This means insignificant magnetic hysteresis loss. Since the flux density change is very
little, the induced eddy current loss is also much less compared to other approaches.
Additionally, there is no magnetic stored energy loss. In addition, higher power efficiency leads
to lower system temperature rise, which in turn helps the magnets minimize parametric drift.
[0042] The voice coil actuator 300 has a good force-to-size ratio. When the coil 326
moves in the air gap, the air gap does not change, and accordingly a minimal air gap is
achievable. For a given magnet, a stronger magnetic field can be generated than with solenoids
or other techniques. By sophisticated flux-focus design, the flux density in the air gap can be
even higher than the residual value for the magnets 326. Producing a stronger magnetic field
produces a better force-to-current ratio. The voice coil actuator's mechanical force has little
relation to the position of coil. During one stroke of the coil, the mechanical force will remain
substantially constant if the coil current does not change.
[0043] The voice coil actuator 300 also has a quick response time. This allows for
enhanced data transmission rates. Indeed, the response time can be less than one millisecond. In
contrast to other devices that generate the mechanical force by storing the magnetic energy in
the air gap which is normally slow due to the high inductor-resistor (LR) time constant of coil,
the voice coil actuator 300 is considerable quicker. The voice coil actuator 300 generates its
mechanical force without energy storage but rather relies on the coil current interacting with
permanent magnetic field. Again, the pulse telemetry systems herein carry more data than other
systems, e.g., solenoid actuated systems, because the pulse rate can be considerably quicker.
The voice coil actuator 300 can cycle at 10 Hz or more.
[0044] The voice coil actuator 300 may have a light moving armature, which is formed
by the coil 326 and the coil holder 320. Since there is not any magnetic field passing through
the armature, a wide variety of light materials are available for use. Lighter armature material
results in lower system inertia, and consequentially, a lower force requirement. The voice coil
actuator 300 may also avoid off-centering effects that some other devices can encounter.
[0045] Referring now primarily to FIGURE 4, a schematic plot is presented for two
curves under ideal conditions (resistance not included). One curve 400 shows the force
developed by the voice coil actuator. In this instance, the ordinate qualitatively presents force
and the abscissa presents percentage actuation of a valve actuated by the voice coil actuator.
The second curve 402 presents the speed of the linkage or moving component in the valve. The
speed is shown qualitatively on the ordinate axis. The plot shows the ideal shaft speed in
relation to the shaft position (actuation) as well as the required net force acting on the shaft in
one illustrative valve.
[0046] In the embodiment of FIGURE 4, there is no mechanical impact on the shaft
since the speed reduces to zero proximate point 404 when fully actuated. So the valve will be
free from wear-out or damage of the type encountered on solenoid valves. The force is initially
positive and fairly constant on segment 406, and then is decreased at 408 and goes negative
starting proximate to 410. The force becomes a fairly constant negative at segment 412. The coil
actuator can achieve this change in force direction easily since the direction of the mechanical
force depends on the direction of magnetic field and also the coil current.
[0047] Referring now primarily to FIGURE 5, a schematic diagram of a processing unit
500 is presented. The processing unit 500 includes one or more processors 502 associated with
one or more memories 504 to form a processing member 506. The processing unit 500 also
includes a control unit 508. The processing member 506 is coupled to one or more downhole
sensors and may receive data from the one or more downhole sensors through an input 510 bus.
The one or more processors 502 and the one or more memories 504 are configured to perform
numerous processes. For example, the one or more processors 502 and more memories 504
may be configured or programmed to carry out functions such as converting some or all the data
from the sensors received through input 510 into binary data that is desirable for use on the
surface. The binary data may be delivered to the control unit 508 and the control unit may
control the voice coil actuator by signals delivered from output 512. The control unit 508
develops the necessary movements of the voice coil actuator to actuate the valve, e.g., valve 202
in FIG. 2, to transmit pressure transitions to or at least toward the surface carrying the data.
[0048] Referring now primarily to FIGURE 6, a schematic circuit diagram of an
illustrative embodiment of a control unit 600 is shown. A power unit 602 provides power to the
control unit 600. The power unit 602 may be a downhole generator, a battery, or other device.
The power is delivered to a digital current source or controller 604. The digital current source
604 typically changes the current from high to low and controls the amount of current that is
ultimately delivered to the voice coil actuator 606. The force developed by the voice coil
actuator 606 is proportional to the current and so by controlling the amount of current, the
developed force may be controlled. Any type of controller for the current may be used.
[0049] The voice coil actuator 606 may apply a force in two directions depending on
which way the current is applied. An aspect of the control unit 600 is able to change the
direction of the current flow. In this illustrative, non-limiting embodiment, a side drive 608 and
main controller 622 control the direction of current flowing through the voice coil actuator 606.
The side drive 608 is used with a plurality of unidirectional switches 610, 612, 614, and 616.
The switches 610, 612, 614, and 616 may comprise one or more the following: transistors,
MOSFET, IGBT, or other switching devices. By controlling the switches, the flow of current
through the voice coil actuator 606 may assume either of two directions. For example, there is
one current flow generated by closing the switches 610, 616 and opening the switches 612,614;
the opposite current is generated by closing the switches 612, 614 and opening the switches
610,616.
[0050] The voice coil actuator 606 uses a force direction change to minimize the final
mechanical impact in the valves and the control unit 600 is used to assist with this purpose. The
force developed by the voice coil actuator 606 depends on the magnetic field and coil current.
The direction change of a force can rise from the field direction change or current direction
change. Considering the rather short shaft stroke e.g., about 0.156 inches in one illustrative
embodiment, it is difficult to change the direction of the magnetic field quickly enough. Even if
it were achieved, the magnetic hysteresis loss and eddy current loss would increase dramatically
due to a large flux change. For this reason, the main illustrative embodiment presented changes
the direction of the current, which in turn can be implemented by either the current source or
circuit switch structure. The latter is presented in FIGURE 6.
[0051] As previously referenced, FIGURE 6 presents a full bridge drive that can change
the current direction quickly. A question is when to change the direction of the current. To
answer this question, one may consider information about the shaft movement, position and
speed. Accordingly, a proper proportional-integral-derivative (PID) controller can be
implemented to accurately control the actuation. However, such accuracy may not be necessary
since the small speed of the shaft or linkage at the end of stroke will not cause serious impact. In
some embodiments, including FIGURE 5, to simplify the system design, only a speed sensor
618 may be used for control. The position of the shaft or linkage can later be deduced by either
an external integrator 620 or internal digital processing in a main controller 622.
[0052] The main controller 622 may provide control to the digital current source 604 to
set the amount of current used and to control the side drive 608 to control the direction. The
main controller 622 receives speed information from speed sensor 618 to calculate an estimate
of the actuator position or may receive displacement information from the integrator 620. In
addition, the current proximate the voice coil actuator 606 may be measured by a current sensor
624.
[0053] The current measure may form a part of a control loop of a digital current source.
In such a case, the main controller 622, digital current source 604 and current measure or sensor
624 are integrated into one complete control loop. The current sensor 624 serves as the
feedback of control loop. In another case, the current sensor 624 may ensure the functionality of
the digital current source 604 and transistors 610, 612,614 and 616 to achieve better system
reliability. The current sensor 624 can be implemented by shunt current resistor, hall current
sensor, magnet or esistive sensor or current transformer.
[0054] It may be beneficial to include in the control unit 600 a device for determining or
approximating the location of the armature or linkage within the voice coil actuator 606. As
noted, this may be done directly measuring displacement or alternatively speed may be used to
calculate the approximate position. In the present illustrative embodiment, the speed approach
is used and the control unit 600 includes the speed sensor 618 for detecting the speed of the
voice coil actuator 606 and in particular the armature. The speed information from the speed
sensor 618 is provided to the main controller 622 or optionally to the integrator 620. The
integration of the speed information to calculate displacement may be done digitally by the
main controller 622, or an analog signal may be integrated by the integrator 620. The speed
sensor 618 may be contact or contactless. The former may be the resistive potential measure and
the latter may be digital encoder, magnetic resolver or even a miniature of VCA or other device.
[0055] The displacement is used to determine when to reverse the current and thereby to
determine the force direction in the voice coil actuator 606. By controlling the change, the
armature or moving components within the valve associated with the voice coil actuator 606
may avoid impact with other surfaces and thereby avoid fatigue or wear. Those skilled in the
art will understand that other embodiments of the control unit may be used.
[0056] Referring now primarily to FIGURE 7, the figure is a schematic flow diagram of
an illustrative embodiment of one method 700 for transmitting data developed in a wellbore to a
surface unit. The method 700 includes the step 702 of disposing a drillpipe in a wellbore. At
least a portion of the drillpipe includes a drilling fluid that extends in a column to the surface
unit. The method 700 also includes the step 704 of disposing one or more downhole sensors in
the wellbore and the step 706 of using the one or more downhole sensors to develop data
representative of some characteristic of the wellbore or drilling process. The method 700 also
involves the step 708 of placing the data in a digital format to arrive at a digital data set and the
step 710 of moving a portion of a valve with a voice coil actuator in response to a control signal
to develop pressure transitions in the drilling fluid that carry the digital data set over the drilling
fluid to the surface unit. Other methods will be apparent from the description herein.
[0057] 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.
[0058] Example 1. A pulse telemetry system for communicating digital data from a
wellbore to a surface unit that includes: a drillpipe positioned downhole having an upstream end
and containing, at least in portion, a drilling fluid; one or more downhole sensors; a processing
unit coupled to the one or more downhole sensors; a valve fluidly coupled to the drilling fluid
for adjusting pressure in the drillpipe proximate the upstream end to cause pressure transitions
within the drilling fluid within the drillpipe to transmit data over the drilling fluid; and wherein
the valve includes a voice coil actuator for developing the pressure transitions within the drilling
fluid.
[0059] Example 2. The pulse telemetry system of example 1 above, wherein the
processing unit includes at least one processor and at least one memory associated with the
processor, whereby the at least one processor and at least one memory are operable to perform
the following steps: receiving data from the one or more sensors; developing a digital
representation of at least some of the data; and sending a control signal to the voice coil actuator
that modulates pressure transitions in the drilling fluid in accord with the digital data.
[0060] Example 3. The pulse telemetry system of example 1 above or example 2,
wherein the voice coil actuator includes a coil holder coupled to a valve plunger for creating a
seal within the valve. The coil holder may be made of aluminum, titanium, or other material.
[0061] Example 4. The pulse telemetry system of example 1 above or examples 2 or 3,
wherein the valve is operable to receive a closing force from the voice coil actuator and an
opening force from the voice coil actuator within less than one second.
[0062] Example 5. The system of example 1 or any of examples 2 or 3, wherein the
valve is operable to receive a closing force from the voice coil actuator and an opening force
from the voice coil actuator within less than 5 to 10 milliseconds.
[0063] Example 6. The system of example 1 or any of the examples 2-5, wherein the
voice coil actuator includes: one or more permanent magnets; a shell; a coil holder; a coil
associated with at least a portion of the coil holder; and wherein the one or more permanent
magnets are stationary and wherein the coil holder is configured to move relative to the one or
more permanent magnets and the coil holder is coupled to a portion of the valve for moving a
component within the valve.
[0064] Example 7. The system of example 1 or any of examples 2-5, wherein the voice
coil actuator includes: one or more permanent magnets; a shell; a coil holder; a coil associated
with at least a portion of the coil holder; and wherein the coil holder is stationary and the one or
more permanent magnets are coupled to a portion of the valve for moving a component within
the valve, and the one or more permanent magnets are configured to move relative to the coil
holder.
[0065] Example 8. The system of example 1 or any of examples 3-7, wherein the
processing unit includes a control unit, and wherein the control unit includes: a digital current
source for controlling an amount of current delivered to the voice coil actuator; and a main
controller and side drive for controlling a direction of current flowing through the voice coil
actuator.
[0066] Example 9. The system of example 1 or any of the preceding examples, wherein
the one or more downhole sensors includes one or more of the following: gamma ray sensor,
compass sensor, tool face sensor, borehole pressure sensor, temperature sensor, vibration
sensor, shock sensor, torque sensor, porosity sensor, density sensor and resistivity sensor.
[0067] Example 10. A method for transmitting data developed in a wellbore to a surface
unit including: disposing a drillpipe in a wellbore, wherein at least a portion of the drillpipe
includes a drilling fluid that extends in a column to the surface unit; disposing one or more
downhole sensors in the wellbore; using the one or more downhole sensors to develop data
representative of some characteristic of the wellbore or drilling process; placing at least a
portion of the data in a digital format to arrive at a digital data set; and moving a portion of a
valve with a voice coil actuator in response to a control signal to develop pressure transitions in
the drilling fluid that carry the digital data set over the drilling fluid to the surface unit.
[0068] Example 11. The method of example 10, wherein the voice coil actuator
includes a coil holder coupled to a valve plunger for creating a seal within a valve.
[0069] Example 12. The method of example 10, wherein the valve is operable to
receive a closing force from the voice coil actuator and an opening force from the voice coil
actuator within less than one second.
[0070] Example 13. The method of example 10, wherein the valve is operable to
receive a closing force from the voice coil actuator and an opening force from the voice coil
actuator within less than 5 to 10 milliseconds.
[0071] Example 14. The method of example 10, wherein the voice coil actuator
includes: one or more permanent magnets; a shell; a coil holder; a coil associated with at least a
portion of the coil holder; wherein the one or more permanent magnets are stationary and
wherein the coil holder is configured to move relative to the one or more permanent magnets
and is coupled to a portion of the valve for moving a component within the valve; and wherein
the step of moving a portion of a valve with a voice coil actuator includes moving the coil
holder to move the portion of the valve.
[0072] Example 15. The system of example 10, wherein the voice coil actuator
includes: one or more permanent magnets; a shell; a coil holder; a coil associated with at least a
portion of the coil holder; wherein the coil holder is stationary and the one or more permanent
magnets are coupled to a portion of the valve for moving a component within the valve, and the
one or more permanent magnets are configured to move relative to the coil holder; and wherein
the step of moving a portion of a valve with a voice coil actuator includes moving the one or
more permanent magnets to move the portion of the valve.
[0073] Example 16. The method of example 10 or any of examples 11-15, wherein the
processing unit includes a control unit, and wherein the control unit includes: a digital current
source for controlling an amount of current delivered to the voice coil actuator; and a main
controller and side drive for controlling a direction of current flowing through the voice coil
actuator.
[0074] Example 17. The method of example 10 or any of examples 11-16, wherein the
step of disposing one or more downhole sensors in the wellbore includes disposing one or more
of the following: gamma ray sensor, compass sensor, tool face sensor, borehole pressure
sensor, temperature sensor, vibration sensor, shock sensor, torque sensor, porosity sensor,
density sensor, and resistivity sensor.
[0075] Example 18. A method of manufacturing a downhole pulse telemetry unit,
wherein the method includes: forming a valve to be associated with a drillpipe for creating
pressure transitions with a drilling fluid; and coupling a voice coil actuator to the valve for
moving at least a portion of the valve.
[0076] Example 19. The method of example 18, further including electrically coupling
a processing unit to the voice coil actuator.
[0077] Example 20. The method of example 18, wherein the voice coil actuator
includes a coil holder coupled to a valve plunger for creating a seal within the valve.
[0078] Although the present invention and its advantages have been disclosed in the
context of certain illustrative, non-limiting embodiments, it should be understood that various
changes, substitutions, permutations, and alterations can be made without departing from the
scope of the invention as defined by the appended claims. It will be appreciated that any feature
that is described in connection to any one embodiment may also be applicable to any other
embodiment.
[0079] It will be understood that the benefits and advantages described above may relate
to one embodiment or may relate to several embodiments. It will further be understood that
reference to "an" item refers to one or more of those items.
[0080] The steps of the methods described herein may be carried out in any suitable
order, or simultaneously where appropriate.
[0081] Where appropriate, aspects of any of the examples described above may be
combined with aspects of any of the other examples described to form further examples having
comparable or different properties and addressing the same or different problems.
[0082] It will be understood that the above description of preferred embodiments is
given by way of example only and that various modifications may be made by those skilled in
the art. The above specification, examples and data provide a complete description of the
structure and use of exemplary embodiments of the invention. Although various embodiments
of the invention have been described above with a certain degree of particularity, or with
reference to one or more individual embodiments, those skilled in the art could make numerous
alterations to the disclosed embodiments without departing from the scope of the claims.

CLAIMS
A pulse telemetry system for communicating digital data from a wellbore to a
surface unit, the system comprising:
a drillpipe positioned downhole having an upstream end and containing, at
least in portion, a drilling fluid;
one or more downhole sensors;
a processing unit coupled to the one or more downhole sensors;
a valve fluidly coupled to the drilling fluid to adjust pressure in the
drillpipe proximate the upstream end to cause pressure transitions
within the drilling fluid to transmit data via the drilling fluid; and
wherein the valve includes a voice coil actuator for developing the pressure
transitions within the drilling fluid.
The system of claim 1, wherein the processing unit includes at least one
processor and at least one memory associated with the processor, whereby the at
least one processor and at least one memory are operable to perform the
following steps:
receiving data from the one or more sensors;
developing a digital representation of at least some of the data; and
sending a control signal to the voice coil actuator that modulates pressure
transitions in the drilling fluid in accord with the digital data.
The system of claim 1, wherein the voice coil actuator comprises a coil holder
coupled to a valve plunger to create a seal within the valve.
The system of claim 1, wherein the voice coil actuator is configured to deliver a
closing force to a portion of the valve and an opening force to a portion of the
valve within less than one second.
The system of claim 1, wherein the voice coil actuator is configured to deliver a
closing force to a portion of the valve and an opening force to a portion of the
valve within less than 0.3 seconds.
Claim 6. The system of claim 1, wherein the voice coil actuator comprises:
one or more permanent magnets;
a shell;
a coil holder;
a coil associated with at least a portion of the coil holder; and
wherein the one or more permanent magnets are stationary and wherein the
coil holder is configured to move relative to the one or more
permanent magnets and the coil holder is coupled to a portion of the
valve to move a component within the valve.
Claim 7. The system of claim 1, wherein the voice coil actuator comprises:
one or more permanent magnet;
a shell;
a coil holder;
a coil associated with at least a portion of the coil holder; and
wherein the coil holder is stationary and the one or more permanent
magnets are coupled to a portion of the valve to move a component
within the valve, and the one or more permanent magnets are
configured to move relative to the coil holder.
Claim 8. The system of claim 1, wherein the processing unit comprises a control unit, and
wherein the control unit comprises:
a digital current source configured to control an amount of current
delivered to the voice coil actuator; and
a main controller and a side drive to control a direction of current flowing
through the voice coil actuator.
Claim 9. The system of claim 1, wherein the one or more downhole sensors comprises one
or more of the following: gamma ray sensor, compass sensor, tool face sensor,
borehole pressure sensor, temperature sensor, vibration sensor, shock sensor, and
torque sensor, porosity sensor, density sensor, and resistivity sensor.
A method for transmitting data developed in a wellbore to a surface unit, the
method comprising:
disposing a drillpipe in a wellbore, wherein at least a portion of the
drillpipe includes a drilling fluid that extends in a column to the
surface unit,
disposing one or more downhole sensors in the wellbore,
using the one or more downhole sensor to develop data representative of
some characteristic of the wellbore or drilling process;
placing at least a portion of the data in a digital format to arrive at a digital
data set; and
moving a portion of a valve with a voice coil actuator in response to a
control signal to develop pressure transitions in the drilling fluid
that carry the at least a portion of digital data set over the drilling
fluid to the surface unit.
Claim 11. The method of claim 10, wherein the voice coil actuator comprises a coil holder
coupled to a valve plunger to create a seal within a valve.
The method of claim 10, wherein the valve receives a closing force from the
voice coil actuator and an opening force from the voice coil actuator within less
than one second.
Claim 13. The method of claim 10, wherein the valve receives a closing force from the
voice coil actuator and an opening force from the voice coil actuator within less
than 0.3 seconds.
Claim 14. The method of claim 10, wherein the voice coil actuator comprises:
one or more permanent magnets;
a shell;
a coil holder;
a coil associated with at least a portion of the coil holder;
wherein the one or more permanent magnets are stationary and wherein the
coil holder moves relative to the one or more permanent magnets
when the voice coil is actuated;
wherein the coil holder is coupled to a portion of the valve to move a
component within the valve; and
wherein moving a portion of a valve with a voice coil actuator comprises
moving the coil holder to move the portion of the valve.
Claim 15. The system of claim 10, wherein the voice coil actuator comprises:
one or more permanent magnets;
a shell;
a coil holder;
a coil associated with at least a portion of the coil holder;
wherein the coil holder is stationary and the one or more permanent
magnets are coupled to a portion of the valve to move a component
within the valve, and the one or more permanent magnets are
configured to move relative to the coil holder; and
wherein moving a portion of a valve with a voice coil actuator comprises
moving the one or more permanent magnets to move the portion of
the valve.
Claim 16. The method of claim 10, wherein the processing unit comprises a control unit,
and wherein the control unit comprises:
a digital current source to control an amount of current delivered to the
voice coil actuator; and
a main controller and side drive to control a direction of current flowing
through the voice coil actuator.
Claim 17. The method of claim 10, wherein the step of disposing one or more downhole
sensors in the wellbore comprises disposing one or more of the following:
gamma ray sensor, compass sensor, tool face sensor, borehole pressure sensor,
temperature sensor, vibration sensor, shock sensor, and torque sensor, porosity
sensor, density sensor, and resistivity sensor.
Claim 18. A method of manufacturing a downhole pulse telemetry unit, wherein the
method comprises:
forming a valve to be associated with a drillpipe to create pressure
transitions with a drilling fluid; and
coupling a voice coil actuator to the valve to move at least a portion of the
valve.
Claim 19. The method of claim 18, further comprising electrically coupling a processing
unit to the voice coil actuator.
Claim 20. The method of claim 18, wherein the voice coil actuator comprises a coil holder
coupled to a valve plunger to create a seal within the valve.