U.S. patent application number 11/186314 was filed with the patent office on 2007-01-25 for tubular running apparatus.
Invention is credited to Egill Abrahamsen, Christopher Hopkins.
Application Number | 20070017682 11/186314 |
Document ID | / |
Family ID | 36998376 |
Filed Date | 2007-01-25 |
United States Patent
Application |
20070017682 |
Kind Code |
A1 |
Abrahamsen; Egill ; et
al. |
January 25, 2007 |
Tubular running apparatus
Abstract
Methods and apparatus are provided to prevent collisions between
one drilling tool and another drilling tool during drilling
operations. If the drilling tools reach a certain proximity to one
another, a controller takes action to prevent a collision.
Inventors: |
Abrahamsen; Egill;
(Stavanger, NO) ; Hopkins; Christopher;
(Stoneville, AU) |
Correspondence
Address: |
PATTERSON & SHERIDAN, L.L.P.
3040 POST OAK BOULEVARD, SUITE 1500
HOUSTON
TX
77056
US
|
Family ID: |
36998376 |
Appl. No.: |
11/186314 |
Filed: |
July 21, 2005 |
Current U.S.
Class: |
166/379 ;
166/77.51 |
Current CPC
Class: |
E21B 19/00 20130101;
E21B 44/00 20130101 |
Class at
Publication: |
166/379 ;
166/077.51 |
International
Class: |
E21B 19/18 20060101
E21B019/18 |
Claims
1. An apparatus for preventing well component collisions,
comprising: a first component moveable along a first predetermined
path; a second component moveable along a second predetermined
path, wherein the first and second predetermined paths intersect in
at least one location; and a sensing member for monitoring the
location of the first component relative to the second
component.
2. The apparatus of claim 1, wherein in the first path comprises a
substantially vertical path toward and away from a rig floor.
3. The apparatus of claim 1, wherein the second path comprises a
substantially horizontal path toward and away from the well
center.
4. The apparatus of claim 1, wherein the first component lowers a
tubular towards the wellbore surface and the second component
aligns the tubular over the wellbore surface in a horizontal
plane.
5. The apparatus of claim 1, wherein the apparatus includes a
second sensing member for monitoring the location of the second
component.
6. The apparatus of claim 5, wherein the second sensing member is a
linear potentiometer attachable to the second component.
7. The apparatus of claim 5, wherein the second sensing member is a
position sensor attachable to the second component incorporated in
a triangulating positioning system.
8. The apparatus of claim 1, wherein the sensing member is a strain
gauge attachable to a railing system for guiding a top drive.
9. The apparatus of claim 1, wherein a controller is operable to
receive data from the sensing member and transmit data for
controlling functions of the first component and the second
component.
10. The apparatus of claim 9, wherein a controller is operable. to
receive data from the sensing member and the second sensing member
and transmit data for controlling functions of the first component
and the second component.
11. The apparatus of claim 1, wherein the sensing member is a wheel
counter attachable to a cable from a draw-works which operates the
first component.
12. The apparatus of claim 1, wherein the sensing member is a
position sensor incorporated in a triangulating positioning system
attachable to the second component.
13. A method for preventing a collision between a first and a
second component at a well, comprising: moving the first component
substantially along a first path; moving the second component
substantially along a second path, wherein the first and second
paths intersect in at least one location; sensing the location of
the first component; transmitting the location of the first
component to a controller; and preventing the collision between the
first component and the second component.
14. The method of claim 13, wherein the first component is for
raising and lowering a tubular over a well center and the second
component for aligning the tubular over a well center.
15. The method of claim 13, further comprising the controller
moving the second component to a safe location upon the first
component reaching an elevation A.
16. The method of claim 13, further comprising sensing the location
of the second component.
17. The method of claim 16, further comprising transmitting the
location of the second component to the controller.
18. The method of claim 17, further comprising transmitting the
unsafe location of the second component to the controller and
moving the second component to a safe location upon the first
component reaching an elevation A.
19. The method of claim 17, further comprising stopping the first
component upon reaching an elevation B if the second component is
in an unsafe location.
20. The method of claim 13, further comprising controlling
functions of the first and second component with the
controller.
21. The method of claim 20, further comprising sensing the location
of the second component and transmitting the location of the second
component to the controller.
22. The method of claim 21, further comprising the controller
preventing a collision between the first component and second
component.
22. An anti-collision system comprising: a first sensor for
monitoring the location of a first component; a second sensor for
monitoring the location of a second component; and a controller for
receiving data from the first and the second sensor and controlling
functions of the first and second component in order to prevent a
collision.
23. An anti-collision system, comprising: a calculator comprising:
a first algorithm for calculating the location of a first
component; and a second algorithm for calculating the location of a
second component; and a controller communicatively connected with
the calculator and at least one of the first and second components
in order to prevent a collision.
24. A method for preventing a collision between a first and a
second component at a well, comprising: sensing the location of the
first component relative to the second component; transmitting the
location to a controller; utilizing the information transmitted to
the controller to move the first component to a predetermined
location while avoiding a collision between the components.
Description
BACKGROUND OF THE INVENTION
[0001] 1. Field of the Invention
[0002] Embodiments of the present invention generally relate to an
apparatus and method for facilitating the connection of tubulars.
More particularly, the invention relates to a safety device for
preventing well components from colliding. More particularly still,
the invention relates to a monitoring system which prevents and/or
alerts an operator when a collision between well components is
imminent.
[0003] 2. Description of the Related Art
[0004] In the construction and completion of oil and gas wells, a
drilling rig is constructed on the earth's surface to facilitate
the insertion and removal of tubular strings into a wellbore. The
drilling rig includes a platform and power tools such as a hoisting
system, an aligning/stabbing tool and a spider to engage, assemble,
and lower the tubulars into the wellbore. The hoisting system
suspends above the platform from a pulley that is operated by a
draw works that can raise or lower the hoisting system in relation
to the floor of the rig. The hoisting system includes an elevator,
a traveling block, bails, top drive, etc. The aligning/stabbing
tool for aligning tubulars comprises a positioning head which is
mounted on a telescopic arm which can be hydraulically extended and
retracted and pivoted in a horizontal plane to position the
tubular. The spider mounts to the platform floor. The elevator and
spider both have slips that are capable of engaging and releasing a
tubular, and are designed to work in tandem.
[0005] One or more operators perform the construction process on a
platform of the drilling rig. The operators monitor the drilling
instrumentation, the rig floor and the derrick while assembling
tubular strings with the remote control power tools. The distance
between an operator and the aligning/stabbing makes it difficult
for the operator to judge the location of drilling tools in
relation to other drilling tools. The operator's view of the
drilling tools is further obstructed by the drilling tools relative
to each other or impaired by adverse weather and poor lighting.
These factors sometimes cause an operator to make a mistake thereby
causing a collision between the power tools.
[0006] If the hoisting system is raised and lowered with the path
of the hoisting system obstructed by a power tool, severe damage to
the hoisting system or the power tool can occur. Falling objects
from the derrick can cause damage to other equipment, personal
injury, or death. Thus, a collision may cause loss of rig time,
repair costs, and replacement costs.
[0007] There exists a need for an improved method and apparatus for
monitoring the distance between drill rig power tools. Further,
there exists a need for a monitoring system that prevents and/or
alerts the operator when collisions between drilling tools is
imminent.
SUMMARY OF THE INVENTION
[0008] Embodiments of the present invention generally relate to
methods and apparatus to prevent inadvertent collisions between one
drilling tool and another drilling tool during drilling operations.
One or more sensors, and/or a controller are used to detect the
location of drilling tools. If the drilling tools reach a certain
proximity to one another the controller takes action to prevent a
collision.
[0009] In one embodiment, the apparatus for preventing well
component collisions includes a first component moveable in a
substantially vertical plane toward and away from a drill rig
floor, a second component moveable toward and away from the well
center, and a sensing member for monitoring the location of the
first component and a controller.
[0010] In another embodiment, an apparatus for preventing well
component collisions comprises a first component moveable along a
first predetermined path; a second component moveable along a
second predetermined path, wherein the first and second
predetermined paths intersect in at least one location; and a
sensing member for monitoring the location of the first component
relative to the second component.
[0011] In another embodiment, a method for preventing a collision
between a first and a second component at a well comprises moving
the first component substantially along a first path; moving the
second component substantially along a second path, wherein the
first and second paths intersect in at least one location; sensing
the location of the first component; transmitting the location of
the first component to a controller; and preventing the collision
between the first component and the second component.
[0012] In another embodiment, an anti-collision system comprises a
first sensor for monitoring the location of a first component; a
second sensor for monitoring the location of a second component;
and a controller for receiving data from the first and the second
sensor and controlling functions of the first and second component
in order to prevent a collision.
[0013] In another embodiment, an anti-collision system comprises a
calculator having a first algorithm for calculating the location of
a first component and a second algorithm for calculating the
location of a second component. The system also includes a
controller communicatively connected with the calculator and at
least one of the first and second components in order to prevent a
collision.
[0014] In another embodiment, a method for preventing a collision
between a first and a second component at a well comprises sensing
the location of the first component relative to the second
component; transmitting the location to a controller; and utilizing
the information transmitted to the controller to move the first
component to a predetermined location while avoiding a collision
between the components.
BRIEF DESCRIPTION OF THE DRAWINGS
[0015] So that the manner in which the above recited features of
the present invention can be understood in detail, a more
particular description of the invention, briefly summarized above,
may be had by reference to embodiments, some of which are
illustrated in the appended drawings. It is to be noted, however,
that the appended drawings illustrate only typical embodiments of
this invention and are therefore not to be considered limiting of
its scope, for the invention may admit to other equally effective
embodiments.
[0016] FIG. 1 is a schematic view of a drilling rig having an
anti-collision system.
[0017] FIG. 2 illustrates a schematic diagram of an anti-collision
system.
[0018] FIG. 3 is a flow chart of a typical operation of tubular
string or casing assembly with use of the safety system
disclosed.
DETAILED DESCRIPTION
[0019] In one embodiment, a monitor system is provided for use with
a drilling rig during assembly and disassembly of tubulars in the
ground or subsea surface. The system may by utilized to prevent
collisions of drilling rig power tools during tubular assembly and
disassembly.
[0020] FIG. 1 illustrates a side view of a drilling rig 100 on a
surface 170 above a wellbore 180. The drilling rig 100 includes a
draw-works 102 with a cable 150 attached to a pulley system 105,
for raising and lowering a hoisting system 115. The hoisting system
115 is shown schematically and could include any type of hoisting
system, such that disclosed in U.S. Pat. No. 6,742,596 and U.S.
Patent Serial Number 2004/0003490 assigned to Weatherford/Lamb,
Inc., and herein incorporated by reference in their entirety. The
drilling rig 100 further includes a platform 300 with an operator
310 and a control panel 320 to operate one or more tools 350. The
platform 300 and operator 310 are located anywhere on the drilling
rig 100, or offsite if desired. Typically, another operator (not
shown) operates the draw-works 102 and the hoisting system 115,
however one operator could do operate both the hoisting system 115
and the tool 350. In one embodiment there is no operator and the
system is completely automated. The draw-works 102 consists of a
wheel or spool for winding and unwinding the cable 150. The cable
150 attaches to a pulley system 105, at the top of the drill rig
100, for raising and lowering the hoisting system 115. If the
hoisting system 115 includes a top drive (not shown) a railing
system 140 is necessary to prevent rotation of the hoisting system
115. The center of the drill rig floor 330 includes an opening with
a spider 400. The spider 400 holds a tubular string 210. A stack of
unassembled tubulars 130 is shown on the drilling rig 100. It
should be understood that the unassembled tubulars 130 can be
stacked anywhere, and in any configurations so long as the hoisting
system 115 is able to lift the tubulars 130.
[0021] The drilling rig 100 assembles or disassembles tubular
strings 210 for use in the wellbore 180. For exemplary purposes the
assembly of a tubular string 210 is described. The spider 400 holds
the assembled tubular string 210 so that the top end is above the
drill rig floor 330. The hoisting system 115 grips one of the
unassembled tubulars 130 from the stack and positions the tubular
over the spider 400. A tool 350 aligns the tubular 130 with the
tubular string 210. The tool 350 includes a gripping end 353, for
aligning the tubular 130. An example of an aligning tool can be
found in U.S. Pat. No. 6,591,471, assigned to Weatherford/Lamb,
Inc., and herein incorporated by reference in its entirety. The
tubular 130 connects to the tubular string 210. With the tubulars
130 and 210 connected the spider 400 disengages the tubular string
210. With the spider 400 disengaged, the hoisting system 115
supports the tubular string 210 and prevents it from falling into
the wellbore 180. The operator 310 retracts the tool 350 and the
other operator lowers the hoisting system 115 until only the end is
above the drill rig floor 330. The spider 400 reengages the tubular
string 210. The hoisting system 115 disengages the tubular string
210 and is brought back to the top of the drilling rig 100. This
process is repeated until the tubular string 210 is complete.
Further, the drill rig 100 may include other tools 103 (shown
schematically) such as a power tong and or a tailing in and
stabbing device. An example of a power tong is disclosed in U.S.
Patent Publication Number 2002/0189804 assigned to
Weatherford/Lamb, Inc. and herein incorporated by reference in its
entirety. Examples of a tailing in and stabbing device are
disclosed in U.S. patent application Ser. No. 11/119,958, titled
"Tailing In and Stabbing Device," filed on May 2, 2005, and U.S.
Patent Application Publication No. 2004/0131449, which applications
are herein incorporated by reference in their entirety.
[0022] The hoisting system 115 is larger than the diameter of the
tubular 130. Therefore, the hoisting system 115 will collide with
the tool 350, if the tool 350 is not retracted to a safe location
before the hoisting system 115 passes the tool 350. In FIG. 1,
elevation A represents an arbitrary elevation, set by the user, at
which the tool 350 may be retracted without damage while the
hoisting system 115 is traveling down. Elevation B represents an
arbitrary elevation, set by the user, at which a collision is
imminent if the hoisting system 115 is not stopped and it is unsafe
to retract the tool 350. One or more sensors 500, 502, 503, 504 and
505 are located on the drilling rig 100 to monitor the location of
the hoisting system 115 and the tool 350. Data collected by these
sensors 500, 502, 503, 504 and 505 are relayed to a controller 900.
The controller 900 is adapted to prevent collision between the
hoisting system 115 and the tool 350. Further, the system for
preventing collision may be adapted to prevent a collision between
any tools on the drill rig 100, including the power tong and/or the
tailing in and stabbing device 103.
[0023] The controller 900 includes a programmable central
processing unit that is operable with a memory, a mass storage
device, an input control unit, and an optional display unit.
Additionally, the controller 900 includes well-known support
circuits such as power supplies, clocks, cache, input/output
circuits and the like. The controller 900 is capable of receiving
data from the sensors 500, 502, 503, 504 and 505 and other devices
and capable of controlling devices connected to it. One of the
functions of the controller 900 is to prevent collisions between
the hoisting system 115 and the tool 350 as described below.
[0024] A sensor 500 is placed near the cable 150 of the draw-works
102. The sensor 500 monitors the amount of hoisting cable 150 being
let out or pulled in by the draw-works drum 102. The sensor 500 may
comprise a wheel counter in engagement with the cable 150, a sensor
for detecting revolutions of the draw-works 102 drum, a sensor for
detecting the revolutions of the drive shaft (not shown) or drive
mechanism (not shown) of the draw works drum or any other type of
device for measuring the amount of cable 150 extending from the
draw works 102 drum. The wheel counter measures the amount of
revolutions the wheel in engagement with the cable 150 makes during
operation. As shown in FIG. 2, the sensor 500 sends data to the
controller 900. The sensor 900 is programmed with information
regarding the pulley ratio and start location of the hoisting
system 115. The pulley ratio determines the distance of travel
toward the rig floor for a particular cable extension from the
draw-works drum 102. For example, if the pulley ratio is 10 to 1,
then for every 10 feet of cable extended from the draw-works drum
102 the hoisting system 115 will travel 1 foot toward the drill rig
floor 330. Thus, the controller 900 is configured to calculate the
location of the hoisting system 115 as the cable 150 is wound and
unwound from the draw-works drum 102. The sensor 500 may be used
alone or in conjunction with one or more sensors described below in
order to prevent a collision on the platform as discussed
below.
[0025] A sensor 502 attaches to the tool 350. The sensor 502
detects the position of the tool 350 and relays the data to the
controller 900. In one embodiment, the sensor 502 is a mechanical
sensor attached to the tool 350, as is known in the art, such as a
linear potentiometer, a position transducer, a piston, etc. (FIG.
2). The sensor 502 detects when the tool 350 is extended to an
unsafe location and when the tool is in a safe location and relays
this data to the controller 900.
[0026] In another embodiment, the sensor 502 is a position sensor
as part of a wireless positioning system. As is known in the art,
wireless position sensors use signals, such as radio waves to
triangulate the location of the sensor 502. The sensor 502 is used
in conjunction with location tracking components. In one
embodiment, three location tags 550, 551 and 552 attach to the
drilling rig 100 at three separate locations. The location tags
550, 551 and 552 can be placed anywhere on the drilling rig 100
although it is preferred to have them spaced apart both
horizontally and vertically. The three location tags 550, 551 and
552 can then triangulate the location of the sensor 502 thus
determining the location of the tool 350 and relay the data to the
controller 900. Further, the sensor 502 can be used in conjunction
with previously existing location tracking components, such as the
GPS satellites, or Wi-Fi networks.
[0027] Another position sensor 503 attaches to the hoisting system
115 and is incorporated as a part of the wireless positioning
system. The location tags 550, 551 and 552 locate the sensor 503 as
the hoisting system 115 moves up and down and relay this data to
the controller 900.
[0028] In another embodiment, if the hoisting system 115 has a top
drive dolly (not shown), a sensor 504 placed on the rail 140
detects when the dolly moves below elevation A and/or elevation B.
The sensor 504 can be any type of sensor known in the art, such as
a strain gauge, a switch activated by the dolly, etc. The sensor
504 relays this data to the controller 900.
[0029] In another embodiment, a sensor 505 is placed on the drill
rig 100. The sensor 505 consists of a camera which sends data to
the controller 900. The camera views the location of both the tool
350 and the hoisting system 115. The controller 900 is equipped
with corresponding detection software which determines the location
of the hoisting system 115 and/or the tool 350.
[0030] Regardless of the type of sensor, or if no sensor is used,
the controller 900 performs the function of preventing the hoisting
system 115 from colliding with the tool 350. The sensors 500, 503,
504 or 505 locate the hoisting system 115, and at least one method
of locating the hoisting system 115 is used. In one embodiment,
upon the hoisting system 115 reaching elevation A, the controller
900 sends a signal through hydraulic, pneumatic, or electric
transmission to the tool 350. The signal will override the tool
controller 320 and retract the tool 350. Further, the controller
900 can be designed to send a signal directly to a piston 351 which
retracts tool 350. This embodiment does not require the use of a
second sensor 502 on the tool 350, because regardless of the
location of the tool 350 the controller 900 will retract the tool
350. Additionally, if the gripping end 353 is activated and
gripping a tubular, the controller 900 can be programmed to not
automatically retract the tool 350 until the tubular is safely
supported.
[0031] In yet another embodiment, the hoisting system 115 sensor
500, 503, 504 or 505 operate in conjunction with the sensor 502 on
the tool. The sensors 500, 503, 504 or 505 relay data to the
controller 900 indicating the location of the hoisting system 115.
If the sensors 500, 503, 504 or 505 indicate to the controller 900
that the hoisting system 115 reached the elevation B and sensor 502
indicates to the controller 900 that the tool 350 is in an unsafe
position, the controller 900 will override the control to the
draw-works drum 102 and stop the hoisting system 115 before a
collision occurs. In this embodiment the controller 900 can also
raise the hoisting system 115 to a safe location and retract the
tool 350.
[0032] In yet another embodiment, the hoisting system sensors 500,
503, 504 or 505 operate in conjunction with the sensor 502 on the
tool 350. The sensors 500, 503, 504 or 505 relay data to the
controller 900 indicating the location of the hoisting system 115.
If the sensor 500, 503, 504, or 505 indicate to the controller 900
that the hoisting system 115 has reached the elevation A and sensor
502 indicates to the controller 900 that the tool 350 is in an
unsafe position, the controller 900 retracts the tool 350. If the
tool 350 fails to retract and the hoisting system 115 reaches
elevation B, the controller 900 will stop the hoisting system 115,
as described above.
[0033] In yet another embodiment, the controller 900 prevents the
extension of the tool 350 when the hoisting system 115 is in an
unsafe position. When the controller 900 detects, through use of
sensors 500, 503, 504, or 505, the hoisting system 115 is below
elevation A, the controller 900 will override the tool controls
320. The controller 900 prevents extension of the tool 350 until
the hoisting system 115 moves above elevation A.
[0034] The sensors 500, 501, 502, 503 504 and 505 are
incorporatable into the drilling rig 100 at any time, making it
easy to place the system on a working drilling rig 100. Further,
the anti-collision system can be incorporated to prevent moveable
components from colliding with immovable components. To further
communicate the unsafe position of the tool 350 to the operator
310, the sensors 500, 501, 502, 503, 504, and 505 may set off an
alarm (not shown), consisting of an audible and/or visual
signal.
[0035] In yet another embodiment, rather than using a sensor to
determine the position of the hoisting system 115 and/or the tool
350, the controller 900 may track or calculate the position without
a sensor. For example, the position of the components may be
determined by keeping track of expected linear movement from a
known starting/stopping point as the controller 900 manipulates the
hoisting system 115 and/or the tool 350. Thus, the controller 900
knows the locations of the components at anytime during operation.
The controller 900 is programmed so that the components of the
drill rig 100 such as the hoisting system 115, the tool 350 and the
other tools 103 will not collide with one another. Further, the
anti-collision system may work the same as the embodiments
described above but the controller 900 does not need sensors.
[0036] FIG. 3 is a flow chart illustrating a typical operation of a
string or casing assembly with the anti-collision system in place.
At a first step 600, the closed spider 400 holds the tubular string
210 and is thereby prevented from moving in a downward direction.
At step 610, the hoisting system 115 engages the tubular 130 from a
stack of tubulars. At step 620, the hoisting system 115 moves the
tubular 130 into position above the tubular string 210. At step
630, tool 350 extends to engage the tubular 130, and thereafter,
aligns the tubular 130 with the tubular string 210. At step 640,
the tubular 130 connects to the tubular string 210 by any known
method, such as threading or welding the tubulars 130 and 210
together. At step 650, the operator 310 retracts the tool 350 into
a safe position. At step 660, the spider 400 disengages the tubular
string 210, thus the weight of the string is supported by the
hoisting system 115. At step 670, the hoisting system 115 lowers
the tubular string 210 into the wellbore 180 until only a small
portion of the tubular string 210 extends above the spider 400. At
step 680, the spider 400 reengages the tubular string 210. At step
690, the hoisting system 115 disengages the tubular string 210 and
raises up to the top of the drilling rig 100. At step 695, if the
well is complete the method is complete, however if more tubulars
130 need to be assembled the process starts over again at step
600.
[0037] Step 700 follows step 640 as an alternative method based on
the operators 310 action. At step 700, the spider 400 disengages
the tubular string 210. At step 705, the operator 310 retracts tool
350 to a safe position. After step 705 the flow charts next step is
step 670 described above. The alternative choice after step 700 is
step 710. At step 710, the operator 310 lowers the hoisting system
115 and the tubular string 210 without retracting the tool 350. At
step 715, the hoisting system 115 reaches the elevation A as
detected by sensor 500, 503 or 504 and relayed to controller 900.
One alternative after step 715 is step 720, the controller 900
automatically retracts the tool 350 as described above. After step
720, with the tool 350 retracted the next step is back to step 670,
lowering the hoisting system 115. An alternative route after step
715 is step 725, the sensor 502 detects the tool 350 is in an
unsafe position and relays this data to controller 900. In the next
step 730 the controller 900 retracts the tool 350. After step 730,
with the tool 350 retracted the next steps back to step 670,
lowering the hoisting system 115. In yet another alternative after
step 715, in step 735 the hoisting system 115 reaches the elevation
B as detected by sensor 500, 503 or 504 and relayed to controller
900. At step 740 the controller 900 stops the hoisting system 115
from moving down. At step 745 the controller 900 or the operator
raises the hoisting system 115 to the elevation A. At step 750 the
controller 900 or operator retract the tool 350. After step 750,
with the tool 350 retracted the next step is back to step 670,
lowering the hoisting system 115. The above-described steps may be
utilized in running any drill string in a drilling operation, in
running casing to reinforce the wellbore, or for assembling strings
to place wellbore components in the wellbore. The steps may also be
reversed in order to disassemble the tubular string.
[0038] While the foregoing is directed to embodiments of the
present invention, other and further embodiments of the invention
may be devised without departing from the basic scope thereof, and
the scope thereof is determined by the claims that follow.
* * * * *