U.S. patent application number 12/134442 was filed with the patent office on 2009-12-10 for constricting flow diverter.
Invention is credited to Scott Dahlgren, David R. Hall, Jonathan Marshall.
Application Number | 20090301784 12/134442 |
Document ID | / |
Family ID | 41350804 |
Filed Date | 2009-12-10 |
United States Patent
Application |
20090301784 |
Kind Code |
A1 |
Hall; David R. ; et
al. |
December 10, 2009 |
Constricting Flow Diverter
Abstract
In one aspect of the present invention, a downhole assembly has
a downhole tool string component with a bore adapted to accommodate
drilling mud having a central passage and at least one periphery
passage. At least two movable segments are peripherally positioned
around a bore wall adapted to constrict a diameter of the central
passage and are adapted to divert drilling mud into the at least
one periphery passage. At least one opening mechanism is adapted to
move a portion of the at least two movable segments toward the bore
wall.
Inventors: |
Hall; David R.; (Provo,
UT) ; Dahlgren; Scott; (Alpine, UT) ;
Marshall; Jonathan; (Provo, UT) |
Correspondence
Address: |
TYSON J. WILDE;NOVATEK INTERNATIONAL, INC.
2185 SOUTH LARSEN PARKWAY
PROVO
UT
84606
US
|
Family ID: |
41350804 |
Appl. No.: |
12/134442 |
Filed: |
June 6, 2008 |
Current U.S.
Class: |
175/269 |
Current CPC
Class: |
E21B 21/12 20130101;
E21B 21/103 20130101; E21B 41/0085 20130101; E21B 21/08
20130101 |
Class at
Publication: |
175/269 |
International
Class: |
E21B 10/18 20060101
E21B010/18 |
Claims
1. A downhole assembly, comprising: a downhole tool string
component comprising a bore adapted to accommodate drilling mud
comprising a central passage and at least one periphery passage; at
least two movable segments peripherally positioned around a bore
wall adapted to constrict a diameter of the central passage adapted
to divert drilling mud into the at least one periphery passage; and
at least one opening mechanism adapted to move a portion of the at
least two movable segments toward the bore wall; wherein a turbine
body disposed within the bore and the at least two movable segments
form a barrier separating the central passage and the at least one
periphery passage.
2. The downhole assembly of claim 1, wherein the at least one
periphery passage directs drilling mud to a turbine.
3. The downhole assembly of claim 2, wherein the turbine is in
communication with an electrical generator.
4. The downhole assembly of claim 1, wherein the at least one
periphery passage directs drilling mud to a downhole hammer, a
downhole steering tool, sensors, or combinations thereof.
5. The downhole assembly of claim 1, wherein the at least one
opening mechanism comprises a motor, a spring, a pin, a hydraulic
actuator, or combinations thereof.
6. The downhole assembly of claim 1, wherein the at least two
movable segments are interlocked.
7. The downhole assembly of claim 1, wherein springs connect the at
least two movable segments together.
8. (canceled)
9. The downhole assembly of claim 7, wherein the springs are
adapted to move the at least two movable segments closer to each
other.
10. The downhole assembly of claim 1, wherein the downhole assembly
is in communication with a telemetry system.
11. The downhole assembly of claim 1, wherein the at least two
movable segments are foils.
12. The downhole assembly of claim 1, wherein the at least two
movable segments comprise a forward tapered face.
13. The downhole assembly of claim 1, wherein the at least two
movable segments comprise a rearward tapered face.
14. The downhole assembly of claim 1, wherein an edge of the at
least two movable segments tapers from a bottom end of the at least
two movable segments to a top end of the at least two movable
segments.
15. The downhole assembly of claim 1, wherein the bore comprises an
expanded diameter region.
16. The downhole assembly of claim 1, wherein the at least two
movable segments are adapted to pivot on the opening mechanism.
17. The downhole assembly of claim 1, wherein the at least two
movable segments are adapted to pivot on a stator disposed within
the bore
18. The downhole assembly of claim 1, wherein the at least two
movable segments are adapted to pivot on a wall of the at least one
periphery passage.
19. (canceled)
20. The downhole assembly of claim 1, wherein the at least two
movable segments close the at least one periphery passage.
Description
BACKGROUND OF THE INVENTION
[0001] This invention relates to downhole drilling assemblies,
specifically downhole drilling assemblies for use in oil, gas,
geothermal, and horizontal drilling. The ability to efficiently
provide a power source downhole is desirable to electronically and
mechanically power downhole instrumentation.
[0002] U.S. Pat. No. 5,626,200 to Gilbert et al., which is herein
incorporated by reference for all that it contains discloses a
logging-while-drilling tool for use in a wellbore in which a well
fluid is circulated into the wellbore through the hollow drill
string. In addition to measurement electronics, the tool includes
an alternator for providing power to the electronics, and a turbine
for driving the alternator. The turbine blades are driven by the
well fluid introduced into the hollow drill string. The tool also
includes a deflector to deflect a portion of the well fluid away
from the turbine blades.
[0003] U.S. Pat. No. 5,839,508 to Tubel et al., which is herein
incorporated by reference for all that it contains, discloses an
electrical generating apparatus which connects to the production
tubing. In a preferred embodiment, this apparatus includes a
housing having a primary flow passageway in communication with the
production tubing. The housing also includes a laterally displaced
side passageway communicating with the primary flow passageway such
that production fluid passes upwardly towards the surface through
the primary and side passageways. A flow diverter may be positioned
in the housing to divert a variable amount of the production fluid
from the production tubing and into the side passageway. In
accordance with an important feature of this invention, an
electrical generator is located at least partially in or along the
side passageway. The electrical generator generates electricity
through the interaction of the flowing production fluid.
[0004] U.S. Pat. No. 4,211,291 to Kellner, which is herein
incorporated by reference for all it contains, discloses a drill
fluid powered hydraulic system used for driving a shaft connected
to a drill bit is disclosed. The apparatus includes a hydraulic
fluid powered motor actuated and controlled by hydraulic fluid. The
hydraulic fluid is supplied to the hydraulic fluid powered motor
through an intermediate drive system actuated by drill fluid. The
intermediate drive system is provided with two rotary valves and
two double sided accumulators. One of the rotary valves routes the
hydraulic fluid to and from the accumulators from the drill fluid
supply and from the accumulators to the drill bit. The rotary
valves are indexed by a gear system and Geneva drive connected to
the motor or drill shaft. A heat exchanger is provided to cool the
hydraulic fluid. The heat exchanger has one side of the exchange
piped between the drill fluid inlet and the drill fluid rotary
valve and the other side of the exchange piped between the
hydraulic fluid side of the accumulators and the hydraulic fluid
rotary valve.
[0005] U.S. Pat. No. 4,462,469 to Brown, which is herein
incorporated by reference for all that it contains, discloses a
motor for driving a rotary drilling bit within a well through which
mud is circulated during a drilling operation, with the motor being
driven by a secondary fluid which is isolated from the circulating
mud but derives energy therefrom to power the motor. A pressure
drop in the circulating mud across a choke in the drill string is
utilized to cause motion of the secondary fluid through the motor.
An instrument which is within the well and develops data to be
transmitted to the surface of the earth controls the actuation of
the motor between different operation conditions in correspondence
with data signals produced by the instrument, and the resulting
variations in torque in the drill string and/or the variations in
torque in the drill string and/or the variations in circulating
fluid pressure are sensed at the surface of the earth to control
and produce a readout representative of the down hole data.
[0006] U.S. Pat. No. 5,098,258 to Barnetche-Gonzalez, which is
herein incorporated by reference for all that it contains,
discloses a multistage drag turbine assembly is provided for use in
a downhole motor, the drag turbine assembly comprising an outer
sleeve and a central shaft positioned within the outer sleeve, the
central shaft having a hollow center and a divider means extending
longitudinally in the hollow center for forming first and second
longitudinal channels therein. A stator is mounted on the shaft.
The stator has a hub surrounding the shaft and a seal member fixed
to the hub wherein the hub and the shaft each have first and second
slot openings therein. A rotor comprising a rotor rim and a
plurality of turbine blades mounted on the rotor rim is positioned
within the outer sleeve for rotation therewith respect to the
stator such that a flow channel is formed in the outer sleeve
between the turbine blades and the stator. A flow path is formed in
the turbine assembly such that fluid flows though the turbine
assembly flows through the first longitudinal channel in the
central shaft, through the first slot openings in the shaft and the
stator hub, through the flow channel wherein the fluid contacts the
edges of the turbine blades for causing a drag force thereon, and
then through the second slot openings in the stator hub and the
shaft into the second channel.
BRIEF SUMMARY OF THE INVENTION
[0007] In one aspect of the present invention, a downhole assembly
has a downhole tool string component with a bore adapted to
accommodate drilling mud having a central passage and at least one
periphery passage. At least two movable segments are peripherally
positioned around a bore wall adapted to constrict a diameter of
the central passage and are adapted to divert drilling mud into the
at least one periphery passage. At least one opening mechanism is
adapted to move a portion of the at least two movable segments
toward the bore wall.
[0008] The at least one periphery passage may direct drilling mud
to a turbine. The turbine may be in communication with an
electrical generator. The at least one periphery passage may direct
drilling mud to a downhole hammer, a downhole steering tool,
sensors, or combinations thereof.
[0009] The at least one opening mechanism may comprises a motor, a
spring, a pin, a hydraulic actuator, or combinations thereof. The
at least two movable segments may be interlocked. Springs may
connect the at least two movable segments together. The at least
two movable segments may be foils. The at least two movable
segments may have a forward tapered face. The at least two movable
segments may have a rearward tapered face. An edge of the at least
two movable segments may taper from a bottom end of the at least
two movable segments to a top end of the at least two movable
segments.
[0010] The at least two movable segments may be adapted to pivot on
the opening mechanism. The at least two movable segments may be
adapted to pivot on a stator disposed within the bore. The at least
two movable segments may be adapted to pivot on a wall of the at
least one periphery passage. A turbine body disposed within the
bore and the at least two movable segments may form a barrier
separating the central passage and the at least one periphery
passage. The bore may have an expanded diameter region. The
downhole assembly may be in communication with a telemetry
system.
BRIEF DESCRIPTION OF THE DRAWINGS
[0011] FIG. 1 is a cross-sectional diagram of an embodiment of a
drill string suspended in a bore hole.
[0012] FIG. 2 is a cross-sectional diagram of an embodiment of a
downhole tool string component.
[0013] FIG. 3a is a cross-sectional diagram of another embodiment
of the downhole tool string component in the opened position.
[0014] FIG. 3b is a cross-sectional diagram of another embodiment
of the downhole tool string component in the closed position.
[0015] FIG. 4a is a cross-sectional diagram of another embodiment
of the downhole tool string component in the opened position.
[0016] FIG. 4b is a cross-sectional diagram of another embodiment
of the downhole tool string component in the closed position.
[0017] FIG. 5a is a cross-sectional diagram of another embodiment
of the downhole tool string component in the opened position.
[0018] FIG. 5b is a cross-sectional diagram of another embodiment
of the downhole tool string component in the closed position.
[0019] FIG. 6a is a cross-sectional diagram of another embodiment
of the downhole tool string component in the opened position.
[0020] FIG. 6b is a cross-sectional diagram of another embodiment
of the downhole tool string component in the closed position.
[0021] FIG. 7a is a cross-sectional diagram of another embodiment
of the downhole tool string component in the opened position.
[0022] FIG. 7b is a cross-sectional diagram of another embodiment
of the downhole tool string component in the closed position.
[0023] FIG. 8 is a sectional diagram of an embodiment of a portion
of the downhole assembly.
DETAILED DESCRIPTION OF THE INVENTION AND THE PREFERRED
EMBODIMENT
[0024] FIG. 1 is an embodiment of a drill string 100 suspended by a
derrick 101. A downhole assembly 102 is located at the bottom of a
bore hole 103 and comprises a drill bit 104. As the drill bit 104
rotates downhole the drill string 100 advances farther into the
earth. The drill string 100 may penetrate soft or hard subterranean
formations 105. The downhole assembly 102 and/or downhole
components may comprise data acquisition devices which may gather
data. The data may be sent to the surface via a transmission system
to a data swivel 106. The data swivel 106 may send the data to the
surface equipment. Further, the surface equipment may send data
and/or power to downhole tools and/or the downhole assembly
102.
[0025] Referring now to FIGS. 2 through 3b, the downhole assembly
102 comprises a downhole tool string component 200 comprising a
bore 201 adapted to accommodate drilling mud 202. The bore 201
comprises a central passage 203 and at least one periphery passage
204. The at least one periphery passage 204 may direct drilling mud
202 to a turbine 210. At least two movable segments 205 are
disposed within the bore 201 and are peripherally positioned around
a bore wall 206. The at least two movable segments 205 are adapted
to constrict a diameter 207 of the central passage 203 and are
adapted to divert drilling mud 202 into the at least one periphery
passage 204. In the embodiment of FIGS. 3a through 3b the at least
two movable segments 205 may be adapted to pivot on a wall 208 of
the at least one periphery passage 204. An edge 250 of the at least
two movable segments 205 may taper from a bottom end 251 of the at
least two movable segments 205 to a top end 252 of the at least two
movable segments 205. The at least two movable segments 205 may be
foils 205. It is believed that as drilling mud 202 flows through
the bore a pressure drop may develop and the top ends 252 of the at
least two movable segments 205 will move towards the center of the
bore 201. It is anticipated that as the top ends 252 of the at
least two movable segments 205 move towards the center of the bore
201, the tapered edges 250 of the at least two movable segments 205
may abut one with another preventing the top ends 252 of the at
least two movable segments 205 from advancing further towards the
center of the bore 201. The downhole tool string component 200 is
considered to be in a closed position when the top ends 252 of the
at least two movable segments 205 can no longer advance further
towards the center of the bore 201. When the downhole tool string
component 200 is in the closed position the at least two movable
segments 205 constrict the diameter 207 of the central passage 203
and divert drilling mud 202 into the at least one periphery passage
204.
[0026] The downhole tool string component 200 comprises at least
one opening mechanism 260 adapted to move a portion of the at least
two movable segments 205 toward the bore wall 206. In the
embodiment of FIGS. 3a through 3b, the at least one opening
mechanism 260 may comprise at least one pin 261 with a first end
262 and a second end 263. The first end 262 may be connected to the
bore wall 206 and adapted to pivot. A spring 264 may be used to
apply a force on the pin 261 pushing the pin towards the bore wall
206. As the spring 264 pushes the pin 261 in the direction of the
bore wall 206 the second end 263 of the pin 261 may contact one of
the at least two movable segments 205 and move the top end 252 of
the contacted movable segment 205 toward the bore wall 206. The
downhole tool string component 200 is considered to be in an opened
position when the top ends 252 of the at least two movable segments
205 are positioned proximate the bore wall 206 the diameter 207 of
the central passage 203 is not constricted. The spring 264 may
exert a force strong enough to keep the at least two movable
segments 205 in the opened position when drilling mud 202 is not
flowing through the bore 201 and weak enough to allow the at least
two movable segments 205 to move to the closed position when
drilling mud 202 is flowing through the bore 201. The embodiment of
FIGS. 3a through 3b may comprise as many pins 261 and springs 264
as there are movable segments 205 and may comprise as few as one
pin 261 and one spring 264. The at least two movable segments 205
may be interlocked such that if one of the at least movable
segments 205 is moved towards the bore wall 206 the rest of the at
least two segments 205 are also moved towards the bore wall 206. It
is believed that the interlocked movable segments 205 may be
beneficial when instruments from the surface are passed down the
center of the drill string 100 and as the instruments approach the
at least two movable segments 205 the instruments will contact at
least one of the pins 261 forcing all of the at least two movable
segments 205 to the opened position if they are not already in the
opened position. The at least two movable segments 205 may close
the at least one periphery passage 204 when in the opened position
preventing drilling mud 202 from entering the at least one
periphery passage 204.
[0027] In the embodiment of FIGS. 3a and 3b, a turbine body 211 and
the at least two movable segments 205 may form a barrier 209
separating the central passage 203 and the at least one periphery
passage 204. Turbine blades 212 may be connected to the turbine
body 211 and disposed within the at least one periphery passage
204. The turbine 210 may be in communication with an electrical
generator 220. The turbine 210 may transfer mechanical energy to
the electrical generator 220 via a connecting rod 221 disposed
intermediate the turbine 210 and the electrical generator 220. The
bore 201 may comprise an expanded diameter region 270 adapted to
accommodate the turbine 210, the electrical generator 220, the at
least two movable segments 205, and the at least one periphery
passage 204.
[0028] FIGS. 4a through 4b disclose an embodiment wherein the at
least one opening mechanism 260 may comprise an actuator 301. In
some embodiments, the actuator may be a hydraulic actuator. The
actuator 301 may comprise a piston 302 disposed in a piston housing
303 located within the bore wall 206. A distal end 306 of the
piston 302 is in communication with the at least two movable
segments 205. A pump 304 may be in communication with the piston
housing 303 and may direct hydraulic fluid 307 from a fluid
reservoir 305 to the piston housing 303 and the pump 304 may direct
hydraulic fluid 307 from the piston housing 303 to the fluid
reservoir 305. As hydraulic fluid 307 is directed to the piston
housing 303 the piston 302 may move the at least two movable
segments 205 into the closed position. As hydraulic fluid 307 is
directed from the piston housing 303 to the fluid reservoir 305 the
piston 302 may move the at least two movable segments 205 into the
opened position. A telemetry system 308 may be in communication
with the downhole assembly 102 and may be used to control the
opening mechanism 260. In the embodiment of FIGS. 4a through 4b,
the telemetry system 308 may be used to control the pump 304.
[0029] Referring now to FIGS. 5a through 5b, the at least two
movable segments 205 are adapted to pivot on the opening mechanism
260. The distal end 306 of the piston 302 may comprise a spherical
geometry 401 adapted to fit within a recess 402 formed in the at
least two movable segments 205. The spherical geometry 401 of the
distal end 306 and the recess 402 in the at least two movable
segments 205 may form a ball-and-socket joint 403 wherein the at
least two movable segments 205 may pivot on the distal end 306 of
the piston 302.
[0030] Referring now to the embodiment of FIGS. 6a through 6b,
springs 501 may connect the at least two movable segments 205
together. The springs 501 may be used to move the at least two
movable segments 205 apart from each other into the opened
position. The springs 501 may exert a force strong enough to keep
the at least two movable segments 205 in the opened position when
drilling mud 202 is not flowing through the bore 201 and weak
enough to allow the at least two movable segments 205 to move to
the closed position when drilling mud 202 is flowing through the
bore 201. The springs 501 may be used to move the at least two
movable segments 205 together into the closed position. The at
least two movable segments 205 may comprise a forward tapered face
502. It is believed that the forward tapered face 502 may be
beneficial when instruments from the surface are passed down the
center of the drill string 100 and as the instruments approach the
at least two movable segments 205 the instruments will contact the
forward tapered face 502 of the at least two movable segments 205
which will direct the instruments towards the central passage 203.
The at least two movable segments 205 may comprise a rearward
tapered face 503. It is believed that the rearward tapered face 502
may be beneficial when instruments from the surface that have been
passed down the center of the drill string 100 and the downhole
component 200 are being raised back up to the surface and as the
instruments approach the at least two movable segments 205 the
instruments will contact the reward tapered face 503 of the at
least two movable segments 205 which will direct the instruments
towards the central passage 203 and may assist the instruments in
moving the at least two movable segments 205 to the opened position
if the at least two movable segments 205 are in the closed
position.
[0031] Referring now to FIGS. 7a through 7b, a stator 601, the
turbine body 211 and the at least two movable segments 205 may form
the barrier 209 separating the central passage 203 and the at least
one periphery passage 204. The stator 601 may be disposed
intermediate the turbine body 211 and the at least two movable
segments 205 and at least two movable segments 205 may be adapted
to pivot on the stator 601. Bearings 602 may be disposed
intermediate the turbine body 211 and the stator 601. Bearings 602
may also be disposed intermediate the turbine body 211 and the bore
wall 206.
[0032] The at least one periphery passage 204 may direct drilling
mud to a downhole hammer, a downhole steering tool, sensors, or
combinations thereof. Referring now to FIG. 8, the at least one
periphery passage 204 may direct drilling mud to a downhole hammer
701. The downhole hammer 701 may comprise a loading spring 702,
fluid chamber 703, entry valves 704, exit valves 705, and a hammer
head 706. The at least one periphery passage 204 may direct
drilling mud 202 to the entry valves 704 and into the fluid chamber
703. As the fluid chamber 703 fills, pressure in the fluid chamber
703 compresses the loading spring 702. After the loading spring 702
is compressed, the exit valves 705 are opened allowing the drilling
mud 202 to exit the fluid chamber 703 and the loading spring 702
pushes the hammer head 706 against the formation 105. The central
passage 203 may direct drilling mud 202 to a nozzle 707.
[0033] Whereas the present invention has been described in
particular relation to the drawings attached hereto, it should be
understood that other and further modifications apart from those
shown or suggested herein, may be made within the scope and spirit
of the present invention.
* * * * *