U.S. patent application number 15/097502 was filed with the patent office on 2016-10-13 for drilling system with top drive entry port.
The applicant listed for this patent is Schlumberger Technology Corporation. Invention is credited to Jacques Orban.
Application Number | 20160298399 15/097502 |
Document ID | / |
Family ID | 57112512 |
Filed Date | 2016-10-13 |
United States Patent
Application |
20160298399 |
Kind Code |
A1 |
Orban; Jacques |
October 13, 2016 |
DRILLING SYSTEM WITH TOP DRIVE ENTRY PORT
Abstract
Apparatus and methods for drilling a wellbore. The apparatus
includes a housing defining an entry port, and a shaft coupled to
the housing and configured to connect to a drill string deployed
into the wellbore. The entry port communicates with the drill
string via an interior of the shaft, when the shaft is connected to
the drill string. The apparatus further includes a sealing device
coupled to the housing. The sealing device has a first
configuration in which the sealing device is configured to seal
with an instrument line received through the entry port, and a
second configuration in which the sealing device is configured to
seal the entry port.
Inventors: |
Orban; Jacques; (Katy,
TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Schlumberger Technology Corporation |
Sugar Land |
TX |
US |
|
|
Family ID: |
57112512 |
Appl. No.: |
15/097502 |
Filed: |
April 13, 2016 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
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62146731 |
Apr 13, 2015 |
|
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 23/08 20130101;
E21B 47/12 20130101; E21B 33/072 20130101; E21B 47/01 20130101;
E21B 17/023 20130101 |
International
Class: |
E21B 19/084 20060101
E21B019/084; E21B 47/12 20060101 E21B047/12; E21B 47/00 20060101
E21B047/00 |
Claims
1. An apparatus for drilling a wellbore, comprising: a housing
defining an entry port; a shaft coupled to the housing and
configured to connect to a drill string deployed into the wellbore,
wherein the entry port communicates with the drill string via an
interior of the shaft, when the shaft is connected to the drill
string; and a sealing device coupled to the housing, wherein the
sealing device has a first configuration in which the sealing
device is configured to seal with an instrument line received
through the entry port, and a second configuration in which the
sealing device is configured to seal the entry port.
2. The apparatus of claim 1, further comprising a first sheave and
a second sheave, the first and second sheaves being coupled to the
housing such that the apparatus is liftable via a drill line
received through the first and second sheaves, the entry port being
positioned between the first and second sheaves.
3. The apparatus of claim 1, further comprising: a spool configured
to receive the instrument line; and a sheave to support the
instrumented line.
4. The apparatus of claim 1, further comprising a line-pusher
coupled to the housing and configured to push the instrument line
through the sealing device, the entry port, the interior of the
shaft, and into the drill string.
5. The apparatus of claim 4, wherein the sealing device is
positioned between the housing and the line-pusher.
6. The apparatus of claim 3, wherein the line-pusher comprises one
or more tracks that are movable to engage and push the instrument
line.
7. The apparatus of claim 1, further comprising: a line sheave; and
a pivotable guide configured to receive the instrument line from
the line sheave, wherein the pivotable guide has a first guide
position in which the pivotable guide directs the instrument line
toward the entry port, and a second guide position in which the
pivotable guide directs the instrument line away from the entry
port.
8. The apparatus of claim 7, wherein the pivotable guide extends at
least partially between sheaves of a crown block.
9. The apparatus of claim 1, further comprising a mud conduit in
the housing, the mud conduit receiving a flow of mud therein, the
mud conduit being in communication with the entry port and the
shaft.
10. A method for deploying an instrument into a drill string in a
wellbore, the method comprising: receiving the instrument and an
instrument line coupled thereto into a drilling device through an
entry port of the drilling device; sealing the entry port, with the
instrument line received therethrough, using a sealing device
coupled to the drilling device; drilling at least a portion of the
wellbore using the drilling device, the drilling device being
lowered and connected the drill string; and lowering the instrument
through the drill string while drilling the wellbore and while
sealing the entry port.
11. The method of claim 10, further comprising receiving a flow of
mud past the instrument in the drill string.
12. The method of claim 11, wherein the mud flow is received into a
conduit of the drilling device, the conduit being in communication
with the entry port, and wherein the sealing device prevents the
mud flow from exiting the drilling device via the entry port.
13. The method of claim 10, wherein moving the instrument through
the drill string comprises pushing an instrument line attached to
the instrument through the entry port.
14. The method of claim 13, wherein a line-pusher coupled to the
drilling device pushes the line downwards or upwards through the
entry port.
15. The method of claim 10, further comprising: acquiring data in
the wellbore using the instrument; and transmitting the data to a
processor located at or near a top surface of the well via an
instrument line attached to the instrument.
16. The method of claim 10, further comprising transmitting data
between a processor located at or near a top surface of the well
and the instrument in the drill string via the instrument line.
17. The method of claim 10, wherein sealing the entry port
comprises actuating an annular seal, one or more pipe rams, one or
more blind rams, or a combination thereof, and wherein actuating
comprises transmitting a signal by remote control.
18. The system of claim 17, wherein sealing the entry port further
comprises actuating one or more shear rams of the sealing device,
to shear the instrument line.
19. A method for deploying an instrument into a drill string in a
wellbore, the method comprising: receiving the instrument and an
instrument line attached thereto into a drilling device through an
entry port of the drilling device; sealing the entry port with the
instrument line extending therethrough, using a sealing device
coupled to the drilling device; and applying torque or tension onto
the drill string using the drilling device.
20. The method of claim 19, further comprising lowering the
instrument through the drill string by pushing the instrument line
therethrough using a line-pusher.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This application claims priority to U.S. Provisional
Application Ser. No. 62/146,731, which was filed on Apr. 13, 2015
and is incorporated herein by reference in its entirety.
BACKGROUND
[0002] During drilling, information is sometimes transmitted to the
surface from instruments within the wellbore, and/or from the
surface to downhole instruments. For example, signals may be
transmitted to or from measuring-while-drilling (MWD) equipment,
logging-while-drilling (LWD) equipment, steering equipment, or
other equipment. Such information may assist operators in the task
of efficiently drilling a wellbore by providing information related
to tool-face orientation and/or formation composition, and allowing
commands and configuration of the downhole instruments, among other
possible uses.
[0003] The drill string may extend thousands of feet, and
transmitting data over this distance, below the surface, may
present challenges. One way such transmission has been effected is
through the use of mud-pulse telemetry. In mud-pulse telemetry, a
pressure spike or modulated sine wave representing a bit of data is
generated in the drilling mud from a mud-pulse generator in the
drill string. The pressure spike or modulated sine wave is detected
by a pressure sensor at or near the surface, allowing bits of data
to be related through the mud. While this communication technique
has proven effective, the transmission rate may be relatively slow,
on the order of single digit bits-per-minute. Moreover, the
signal-to-noise ratio can be low, because the pressure spike or
modulated sine wave may be attenuated once it reaches the surface.
Furthermore, the noise may high due to the proximity of machinery,
such as mud pumps.
[0004] Electromagnetic ("e-mag") signal transmission has also been
employed. In such communication, an electromagnetic signal is
generated in the downhole equipment, which travels through the
formation and is detected by sensors (e.g., voltmeters) at the
surface, and then returns through the drill pipe to the source,
completing the circuit. However, the effectiveness of this type of
signal transmission depends partially on the formation properties.
If, for example, the wellbore penetrates a salt layer, the
electromagnetic transmissions may be unable to reach the
surface.
[0005] Various other types of downhole communication have also been
proposed and/or implemented. Wired drill pipe, for example, has
been proposed, and has the potential to obviate the challenges
experienced with wireless signal transmission. However, because
each pipe includes a wire connector that is prone to failure, if
one connector in one pipe among the potentially thousands of pipes
fails, the entire assembly can be rendered inoperative.
SUMMARY
[0006] Embodiments of the disclosure may provide an apparatus for
drilling a wellbore. The apparatus includes a housing defining an
entry port, and a shaft coupled to the housing and configured to
connect to a drill string deployed into the wellbore. The entry
port communicates with the drill string via an interior of the
shaft, when the shaft is connected to the drill string. The
apparatus also includes a sealing device coupled to the housing.
The sealing device has a first configuration in which the sealing
device is configured to seal with an instrument line received
through the entry port, and a second configuration in which the
sealing device is configured to seal the entry port.
[0007] Embodiments of the disclosure may also include a method for
deploying an instrument into a drill string in a wellbore. The
method includes receiving the instrument and an instrument line
coupled thereto into a drilling device through an entry port of the
drilling device, sealing the entry port, with the instrument line
received therethrough, using a sealing device coupled to the
drilling device, drilling at least a portion of the wellbore using
the drilling device, the drilling device being lowered and
connected the drill string, and lowering the instrument through the
drill string while drilling the wellbore and while sealing the
entry port.
[0008] Embodiments of the disclosure may also provide a method for
deploying an instrument into a drill string in a wellbore. The
method includes receiving the instrument and an instrument line
attached thereto into a drilling device through an entry port of
the drilling device, sealing the entry port with the instrument
line extending therethrough, using a sealing device coupled to the
drilling device, and applying torque or tension onto the drill
string using the drilling device.
BRIEF DESCRIPTION OF THE DRAWINGS
[0009] The accompanying drawings, which are incorporated in and
constitute a part of this specification, illustrate embodiments of
the present teachings and together with the description, serve to
explain the principles of the present teachings. In the
figures:
[0010] FIG. 1 illustrates a simplified, schematic view of a
drilling rig system, according to an embodiment.
[0011] FIG. 2 illustrates a side, schematic view of a tool
deployment assembly, according to an embodiment.
[0012] FIG. 3A illustrates a first side view of a top drive of the
drilling rig system, according to an embodiment.
[0013] FIG. 3B illustrates a second side view of the top drive of
the drilling rig system, according to an embodiment.
[0014] FIG. 4 illustrates a flowchart of a method for deploying a
tool within a drill string, according to an embodiment.
[0015] FIG. 5 illustrates a schematic view of a computing system,
according to an embodiment.
DETAILED DESCRIPTION
[0016] Reference will now be made in detail to specific embodiments
illustrated in the accompanying drawings and figures. In the
following detailed description, numerous specific details are set
forth in order to provide a thorough understanding of the
invention. However, it will be apparent to one of ordinary skill in
the art that the invention may be practiced without these specific
details. In other instances, well-known methods, procedures,
components, circuits, and networks have not been described in
detail so as not to unnecessarily obscure aspects of the
embodiments.
[0017] It will also be understood that, although the terms first,
second, etc. may be used herein to describe various elements, these
elements should not be limited by these terms. These terms are only
used to distinguish one element from another. For example, a first
object could be termed a second object or step, and, similarly, a
second object could be termed a first object or step, without
departing from the scope of the present disclosure.
[0018] The terminology used in the description of the invention
herein is for the purpose of describing particular embodiments only
and is not intended to be limiting. As used in the description of
the invention and the appended claims, the singular forms "a," "an"
and "the" are intended to include the plural forms as well, unless
the context clearly indicates otherwise. It will also be understood
that the term "and/or" as used herein refers to and encompasses any
and all possible combinations of one or more of the associated
listed items. It will be further understood that the terms
"includes," "including," "comprises" and/or "comprising," when used
in this specification, specify the presence of stated features,
integers, steps, operations, elements, and/or components, but do
not preclude the presence or addition of one or more other
features, integers, steps, operations, elements, components, and/or
groups thereof. Further, as used herein, the term "if" may be
construed to mean "when" or "upon" or "in response to determining"
or "in response to detecting," depending on the context.
[0019] FIG. 1 illustrates a schematic view of a drilling rig 100,
according to an embodiment. The drilling rig 100 includes a
drilling apparatus 102 and a drill string 104 coupled thereto. The
drilling apparatus 102 may include any type of drilling device,
such as a top drive to support and rotate the drill string 104 or
any other device configured to support, lower, and rotate the drill
string 104, which may be deployed into a wellbore 106. In the
illustrated embodiment, the drilling apparatus 102 may also include
a travelling block 105, which may include of one or more rotating
sheaves.
[0020] The drilling rig 100 may also include a rig floor 108, from
which a support structure (e.g., including a mast) 110 may extend.
A slips assembly 109 may be disposed at the rig floor 108, and may
be configured to engage the drill string 104 so as to enable a new
stand of tubulars to be added to the drill string 104 via the
drilling apparatus 102.
[0021] A crown block 112 may be coupled to the support structure
110. Further, a drawworks 114 may be coupled to the rig floor 108.
A drill line 116 may extend between the drawworks 114 and the crown
block 112, and may be received through the sheaves of the
travelling block 105. Accordingly, the position of the drilling
apparatus 102 may be changed (e.g., raised or lowered) by spooling
or unspooling the drilling line 116 from the drawworks 114, e.g.,
by rotation of the drawworks 114.
[0022] The drilling rig 100 may also include an instrument line
120, which may be received through the drilling apparatus 102 and
into the drill string 104. The instrument line 120 may be spooled
on an instrument line spool 122, and may be received at least
partially around a line sheave 124 between the instrument line
spool 122 and the drilling apparatus 102. In an embodiment, the
instrument line spool 122 may be coupled to the rig floor 108 as
shown, but in other embodiments, may be positioned anywhere on the
rig 100 or in proximity thereto. Furthermore, in some embodiments,
the line sheave 124 may be installed below the crown block 112. It
may also be installed on the side of the crown-block 112. In such
an embodiment, a guide may be installed above the entry port 220 to
align the instrument line 120 from the sheave 124 with the bore of
the shaft 204 and the drill-sting 104. In another embodiment, the
sheave 124 can be attached directly onto the drilling apparatus
102. In such an embodiment, the spooling of the line spool 122 may
be synchronize with the rotation of the drawworks 114.
[0023] The instrument line 120 may be connected to a downhole
instrument 126, which may be deployed into the interior of the
drill string 104, as will be described in greater detail below. The
drill string 104 may be rotated while the instrument line 120 is
deployed in the drill string 104. The rotation may induce twisting
of the instrument line 120. Accordingly, the instrument 126 and/or
a lower portion of the instrument line 120 may, in some
embodiments, include a swivel, allowing for relative rotation
between the instrument 126 and the instrument line 120. In such an
embodiment, the instrument 126 may also be connected to the
rotating drill string 104.
[0024] In an embodiment, the position of the downhole instrument
126 may be changed (e.g., raised or lowered) by spooling or
unspooling the instrument line 120 from the instrument line spool
122. The downhole instrument 126 may be any type of instrument,
such as a logging device, which may include one or more geophones,
hydrophones or accelerometers, acoustic receivers, torque sensors,
strain gauges, accelerometers, gyroscope, current probe,
voltmeters, and/or the like. Further, the instrument line 120 may
provide for wired communication with a controller 128, e.g.,
without calling for wires to be formed as a part of the drill pipe
making up the drill string 104.
[0025] FIG. 2 illustrates an enlarged, partial, schematic view of
the drilling rig 100, according to an embodiment. As shown, the
drilling apparatus 102 may be suspended from the rig floor 108 via
interaction with the travelling block 105, the crown block 112, and
the drilling line 116 that is spooled on the drawworks 114.
[0026] In addition, the drilling apparatus 102 may include a
drilling device 200, e.g., a top drive. The drilling device 200 may
include a housing 202 and a shaft 204, which may be coupled to and
extend out of the housing 202. In particular, the shaft 204 may be
rotatably coupled to the housing 202 via a thrust bearing 206. The
shaft 204 may be drive to rotate by a motor 207, which may be
coupled to and/or disposed within the housing 202. Further, the
shaft 204 may be connected to the drill string 104, such that
rotation of the shaft 204 may cause the drill string 104 to rotate.
Such rotation may be employed for drilling the well in rotary mode,
as well as controlling orientation of the drill string 104 while
drilling the well in sliding mode with a down-hole motor or
turbine, allowing potential deviation of the wellbore 106 to the
correct azimuth. By such connection between the shaft 204 and the
drill string 104, at least a portion of the weight of the drill
string 104 may be supported by the housing 202, which transmits the
weight to the rig floor 108 via the crown block 112 and the support
structure 110, as well as the drawworks 114. The drilling device
200 may also include one or more rollers 208 (four are shown) or
sliding guides, which may transmit reactionary torque loads to the
support structure 110. The housing 202 may further include an entry
port 210, through which the instrument line 120 and the instrument
126 may be received.
[0027] Further, the drilling apparatus 102 may include a sealing
device 220, through which the instrument line 120 and the
instrument 126 may be received into the entry port 210. The sealing
device 220 may be coupled to the housing 202 of the drilling device
200, and may be movable therewith. The sealing device 220 may have
(e.g., be able to be operated in) at least three configurations. In
an open configuration, the sealing device 220 may be configured to
receive the instrument 126 therethrough. In a first, sealed
configuration (illustrated in FIG. 2), the sealing device 220 may
be configured to receive and seal with the instrument line 120. The
instrument line 120 may be able to slide relative to the sealing
device 220 when the sealing device 220 is in the first
configuration, but fluid may be prevented from proceeding through
the entry port 210 by the sealing device 220. In a second, sealed
configuration, the sealing device 220 may completely seal the entry
port 210, e.g., when the instrument line 120 is not received
therethrough. Thus, the sealing device 220 may function similarly
to a blowout preventer does for the drill string 104, serving to
control access into the entry port 210. The different
configurations may be reached based on a position of an annular
"preventer" or seal of the sealing device 220, as will be described
in greater detail below.
[0028] The entry port 210 may communicate with an interior 250 of
the shaft 204, e.g., via a conduit 253 within the housing 202. The
shaft 204 may be rotatably coupled to the conduit 253 via swivel
254, as shown. Accordingly, the instrument line 120, when received
through the entry port 210, may proceed through the conduit 253 and
into the shaft 204, and then into the drill string 104.
[0029] The drilling device 200 may also receive a flow of drilling
mud via a mud conduit 260. The mud conduit 260 may communicate with
the conduit 253 within the housing 202, and thus the mud conduit
260 may be in fluid communication with the entry port 210, as well
as the interior 250 of the shaft 204 and the drill string 104. The
sealing device 220 may serve to prevent mud flow up through the
entry port 210 in either or both of the first and second
configurations thereof.
[0030] The drilling apparatus 200 may further include a line-pusher
265. The line-pusher 265 may be configured to apply a
downwardly-directed force on the instrument line 120, which may
cause the instrument line 120 to be directed downward, through the
sealing device 220, the entry port 210, the conduit 253, the
interior 250 of the shaft 204, and through at least a portion of
the drill string 104, so as to deploy the instrument 126 (FIG. 1)
therein. Further, the line-pusher 265 may be coupled to the housing
202 of the drilling device 200 and may be movable therewith. In an
embodiment, the line-pusher 265 may be directly attached to the
sealing device 220, e.g., such that the sealing device 220 is
positioned between the housing 202 and the line-pusher 265. As
such, the line-pusher 265 may be configured to push the instrument
line 120 through the entry port 210 via the sealing device 220.
[0031] The line-pusher 265 may be employed to overcome initial
fluid resistance provided by the drilling mud coursing through the
mud conduit 260. Further, the line-pusher 265 may provide for rapid
deployment of the instrument line 120 through the drill string 104,
e.g., at a similar rate, or even faster than, the velocity of the
drilling mud therein, and thus the line-pusher 265 may overcome
drag forces of the instrument 126 and the drilling line 116 in
contact with the mud and with the bore of the drill string 104.
[0032] The line-pusher 265 may also be used to retract the
instrument line 120 and the instrument 126 out of the drill string
104, e.g., by reversing direction and pushing the instrument line
120 upwards, away from the entry port 210. The retracted instrument
line 120 may thus be spooled on the instrument line spool 122,
e.g., with minimum pull force by the instrument line spool 122.
[0033] The drilling apparatus 102 may also include a pivotable
guide 270, through which the instrument line 120 may be received.
The pivotable guide 270 may be positioned, as proceeding along the
line 120, between the line sheave 124 and the line-pusher 265. The
pivotable guide 270 may be movable across a range of positions, for
example, between a first position, shown with solid lines, and a
second position, shown with dashed lines. In the first position,
the pivotable guide 270 may direct the instrument line 120 between
the sheaves of the crown block 112 and between the sheaves of the
travelling block 105 and toward the entry port 210. In the second
position, the pivotable guide 270 may direct the instrument line
120 away from the entry port 210. For example, the second position
may be employed when raising the drilling device 200 so as to
accept a new stand of tubulars on the drill string 104 and/or when
initially running the instrument 126 and the instrument line 120
into the entry port 210, as will be described in greater detail
below, and/or retrieving the instrument 126 from the drill string
104.
[0034] FIGS. 3A and 3B illustrates two partial side views of the
drilling apparatus 102, specifically showing additional details of
the sealing device 220 and the line-pusher 265, among other things,
according to an embodiment. As illustrated, the sealing device 220
and the line-pusher 265 may be positioned between two sets of
sheaves 306, 308 of the travelling block 105, and thus may be
positioned to receive the instrument line 120 and feed the
instrument line 120 to the entry port 210.
[0035] Further, the sealing device 220 may include an annular seal
(e.g., an annular "preventer") 300 and one or more rams (two shown:
302, 304). The annular seal 300 may be movable in response to a
command, e.g., radially inwards and outwards. Accordingly, the
annular seal 300 may be moved outwards to receive the instrument
line 120 and inwards to seal the entry port 210.
[0036] The ram 302 may be a pipe ram or a shear ram, and the ram
304 may be a blind ram. In an embodiment, the ram 304 being a blind
ram may allow the sealing device 220 to close the entry port 210
when the instrumented line 120 is not present in the sealing device
220. Such situation may occur during drilling operations when usage
of the instrument line 120 and/or the instrument 126 is not
desired. The change of sealing configuration may occur in response
to a remote control with a minimum time delay. Such configuration
control may be implemented using a hydraulics system, which apply
oil pressure on actuators via manually or computer-controlled
valves. In the embodiment in which the ram 302 is a pipe ram, the
pipe ram 302 may be used to seal accurately against the
instrumented line 120, for example, in situations in which the
inside of the drill string 104 is at high pressure. The pipe rams
also may support the instrument 120 line within the drill string
104, and thus may serve as a back-up if the line-pusher 265 is
temporarily incapable of supporting the instrumented line within
the drill sting 104. The ram 302 acting as a shear ram or the ram
304 acting as a shear/blind rams may sever the instrument line 120
when pressure inside the drill string 104 reaches a high value.
[0037] Further, the line-pusher 265 may include two or more tracks
or "caterpillars" 307, 309, which may engage and move the
instrument line 120 into and/or out of the entry port 210. The
tracks 307, 309 may include links, rollers, or any other structure
capable of engaging the instrument line 120 and, e.g., through the
friction created by such an engagement, force the instrument line
120 downwards into the entry port 210, or to pull the instrument
line 120 upwards, out of the entry port 210, as the tracks 307, 309
are moved. The tracks 307, 309 may have shapes to match the
circular pattern of the instrument line 120, allowing distributed
contact between the tracks 307, 309 with the instrument lien 120
for high friction while keeping the local contact pressure to an
acceptable level for the instrument line 120. The high friction
allows to the "caterpillars" to apply fair push or pull force onto
the instrument line 120.
[0038] In the illustrated embodiment, the shaft 204 is connected to
a gear 318, which meshes with a gear 320 that is connected to a
motor shaft 322. The motor shaft 322 is rotated by the motor 207,
and such rotate is transmitted to the shaft 204 via the meshing
gears 318, 320. In this embodiment, the motor 207 is coupled to the
housing 202, while mounts 324, 326 support the shaft of pinion gear
320.
[0039] The drilling apparatus 102 may also include a controller
310, which may be coupled to the housing 202 and movable therewith,
or otherwise in communication with the drilling device 200. The
controller 310 may receive commands, e.g., from the controller 128
(FIG. 1) via a control line 312, but in some embodiments, may be
autonomous. Further, the controller 310 may control the operation
of the line-pusher 265, e.g., to control when the line-pusher 265
operates to feed the instrument line 120 through the entry port
210. The controller 310 may also operate to control the sealing
device 220, e.g., to control when the annular seal 300 moves
radially and to control the operation of one or both rams 302, 304.
The controller 310 may further control or monitor the power to the
motor 207 via a power line 314, so as to control when, and at what
speed, the motor 207 rotates the shaft 204.
[0040] FIG. 4 illustrates a flowchart of a method 400 for deploying
the instrument 126 into the drill string 104 deployed into the
wellbore 106, according to an embodiment. Although the present
method 400 is described with reference to the drilling rig 100
discussed above, it will be appreciated that this is merely an
example, and embodiments of the method 400 may be applied using
other structures.
[0041] The method 400 may begin with receiving the instrument 126
in the drilling device 200, as at 402. This may include, for
example, receiving the instrument 126 and the instrument line 120
down between or near the sheaves of the crown block 112, between
the sheaves of the travelling block 105, through the line-pusher
265, through the sealing device 220, and into the entry port 210 of
the housing 202. In a specific embodiment, the instrument 126 may
be positioned in the interior 250 of the shaft 204, or in the
conduit 253.
[0042] The method 400 may also include sealing the entry port 210
using the sealing device 220, as at 404. For example, the annular
seal 300 of the sealing device 220 may extend radially inward from
an open position, which allows the instrument 126 to pass through,
to a first, sealed configuration, in which the annular seal 300
engages and seals with the instrument line 120.
[0043] The method 400 may include receiving a flow of mud past the
instrument 126, as at 406. The method 400 may then proceed to
lowering the instrument 126 into the drill string 104, as at 408.
At least a part of this lowering may be accomplished by pushing the
instrument line 120 using the line-pusher 265, although at least a
part of this pushing may also or instead rely on mud flow dragging
the instrument 126 downwards. Further, the instrument 126 may be
lowered (e.g., pushed) to a predetermined depth within the drill
string 104. In addition, while the instrument 126 is being lowered,
the instrument line spool 122 may unspool the instrument line 120
therefrom, so as to allow the line 116 to be extended down into the
drill string 104. The unspooling of the instrument line 120 may be
coordinated, e.g., synchronized, with the pushing by the
line-pusher 265. Such lowering may occur rapidly, e.g., to minimize
"blind" time during deployment during which the instrument 126 is
not in position to transmit data. For example, such lowering may
occur at about 5, about 10, about 15, or about 20 meters per
second. The retrieval of the instrument 126 is obtained by
reversing the movement in the pushing devise 265 which pulls the
instrument line 120. The spool 122 may re-spool the instrument line
120 in accordance with the movement of the line-pusher 265.
[0044] In an embodiment, the method 400 may include lowering the
drilling device 200, e.g., by unspooling drilling line 116 from the
drawworks 114, as at 410. In some embodiments, lowering the
drilling device 200 may occur at the same time as the instrument
126 is being pushed into the drill string 104, and thus the pushing
of the drill string 104 may take into account the change in
position of the drilling device 200. The drilling device 200 may
operate to apply a torque to and rotate the drill string 104 while
being lowered at 410, e.g., as a process of drilling
operations.
[0045] Prior to, during, or after lowering the drilling device 200,
the instrument 126 may be moved into one or more predetermined
positions and employed to collect data (e.g., formation, seismic,
drill-pipe stress, torque, stick-slip, vibration, gyroscopic,
inclination, or any other type of data), as at 412, which may be
sent to the one or more surface controllers 128, e.g., via the
instrument line 120. Further, data may be collected by the
instrument 126 as transmitted to the surface via the instrument
line 120. In other situations, data can be transmitted to the
instrument 126 via the instrument line 120 for purposes of
configuration of sensors of the instrument 126 or for relay to
other equipment of the drill string 104, such as the steering
components of the bottom-hole assembly (not shown).
[0046] The method 400 may also include raising the instrument 126
to a position within the drilling device 200, e.g., within the
shaft 204 or within the conduit 253, as at 414. This may occur
rapidly, for example, at least about 5, about 10, or about 15
meters per second, or more. For example, this may be conducted in
response to the drilling device 200 reaching a predetermined
elevation with respect to the rig floor 108, e.g., when the
drilling device 200 is at or near to its lower end range of
movement.
[0047] Once the instrument 126 is above the drill string 104, the
shaft 204 may be disconnected from the drill string 104, as at 416.
Thereafter, a new stand of one or more tubulars may be added to the
drill string 104 and attached to the new stand, as at 418. The
method 400 may return to lowering the instrument 126 at 408, and
the sequence may repeat.
[0048] The instrument line 120 is constructed to include electrical
wires to ensure electrical connection between the instrument 126
and the surface electronics including the controller 128. The
instrument line 120 may also be designed to support the contact
stress at the line pusher 265, as well as the tension force created
by the weight of the instrument line and instrument 126. The
instrument line 120 may also support the instrument 126 and the
line 120 itself against pressure effects and friction. Friction
induces axial force onto the instrument line when the line is
moving axially in the drill string 104. Also, friction generates
torque onto the instrument line when the drill string 104 is
rotated. The instrument 126 and/or the instrument line 120 may be
mechanically reinforced to survive these effects.
[0049] In some embodiments, the methods of the present disclosure
may be executed by a computing system. FIG. 5 illustrates an
example of such a computing system 500, in accordance with some
embodiments. The computing system 500 may include a computer or
computer system 501A, which may be an individual computer system
501A or an arrangement of distributed computer systems. The
computer system 501A includes one or more analysis modules 502 that
are configured to perform various tasks according to some
embodiments, such as one or more methods disclosed herein. To
perform these various tasks, the analysis module 502 executes
independently, or in coordination with, one or more processors 504,
which is (or are) connected to one or more storage media 506. The
processor(s) 504 is (or are) also connected to a network interface
507 to allow the computer system 501A to communicate over a data
network 509 with one or more additional computer systems and/or
computing systems, such as 501B, 501C, and/or 501D (note that
computer systems 501B, 501C and/or 501D may or may not share the
same architecture as computer system 501A, and may be located in
different physical locations, e.g., computer systems 501A and 501B
may be located in a processing facility, while in communication
with one or more computer systems such as 501C and/or 501D that are
located in one or more data centers, and/or located in varying
countries on different continents).
[0050] A processor may include a microprocessor, microcontroller,
processor module or subsystem, programmable integrated circuit,
programmable gate array, or another control or computing
device.
[0051] The storage media 506 may be implemented as one or more
computer-readable or machine-readable storage media. Note that
while in the example embodiment of FIG. 5 storage media 506 is
depicted as within computer system 501A, in some embodiments,
storage media 506 may be distributed within and/or across multiple
internal and/or external enclosures of computing system 501A and/or
additional computing systems. Storage media 506 may include one or
more different forms of memory including semiconductor memory
devices such as dynamic or static random access memories (DRAMs or
SRAMs), erasable and programmable read-only memories (EPROMs),
electrically erasable and programmable read-only memories (EEPROMs)
and flash memories, magnetic disks such as fixed, floppy and
removable disks, other magnetic media including tape, optical media
such as compact disks (CDs) or digital video disks (DVDs),
BLU-RAY.RTM. disks, or other types of optical storage, or other
types of storage devices. Note that the instructions discussed
above may be provided on one computer-readable or machine-readable
storage medium, or alternatively, may be provided on multiple
computer-readable or machine-readable storage media distributed in
a large system having possibly plural nodes. Such computer-readable
or machine-readable storage medium or media is (are) considered to
be part of an article (or article of manufacture). An article or
article of manufacture may refer to any manufactured single
component or multiple components. The storage medium or media may
be located either in the machine running the machine-readable
instructions, or located at a remote site from which
machine-readable instructions may be downloaded over a network for
execution.
[0052] In some embodiments, the computing system 500 contains one
or more rig control module(s) 508. In the example of computing
system 500, computer system 501A includes the rig control module
508. In some embodiments, a single rig control module may be used
to perform some or all aspects of one or more embodiments of the
methods disclosed herein. In alternate embodiments, a plurality of
rig control modules may be used to perform some or all aspects of
methods herein.
[0053] The computing system 500 is one example of a computing
system; in other examples, the computing system 500 may have more
or fewer components than shown, may combine additional components
not depicted in the example embodiment of FIG. 5, and/or the
computing system 500 may have a different configuration or
arrangement of the components depicted in FIG. 5. The various
components shown in FIG. 5 may be implemented in hardware,
software, or a combination of both hardware and software, including
one or more signal processing and/or application specific
integrated circuits.
[0054] Further, the steps in the processing methods described
herein may be implemented by running one or more functional modules
in information processing apparatus such as general purpose
processors or application specific chips, such as ASICs, FPGAs,
PLDs, or other appropriate devices. These modules, combinations of
these modules, and/or their combination with general hardware are
all included within the scope of protection of the invention.
[0055] The foregoing description, for purpose of explanation, has
been described with reference to specific embodiments. However, the
illustrative discussions above are not intended to be exhaustive or
to limit the invention to the precise forms disclosed. Many
modifications and variations are possible in view of the above
teachings. Moreover, the order in which the elements of the methods
described herein are illustrate and described may be re-arranged,
and/or two or more elements may occur simultaneously. The
embodiments were chosen and described in order to best explain the
principals of the invention and its practical applications, to
thereby enable others skilled in the art to best utilize the
invention and various embodiments with various modifications as are
suited to the particular use contemplated.
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