U.S. patent application number 11/115439 was filed with the patent office on 2006-11-02 for conductor pipe string deflector and method of using same.
Invention is credited to Jeremy R. Angelle.
Application Number | 20060243436 11/115439 |
Document ID | / |
Family ID | 37215525 |
Filed Date | 2006-11-02 |
United States Patent
Application |
20060243436 |
Kind Code |
A1 |
Angelle; Jeremy R. |
November 2, 2006 |
Conductor pipe string deflector and method of using same
Abstract
An apparatus for deflecting a tubular string preferably
comprising at least one side nozzle near the lower end of a first
tubular string. The nozzle permits passage of a fluid therethrough
from the first tubular string bore and deflects the first tubular
string in a substantially horizontal direction. A second tubular
string may be lowered over the deflected first tubular string. The
second tubular string and the first tubular string are preferably
lowered into the sea floor for maintaining their deflection. A
method for deflecting a first tubular string and securing the first
tubular string in the deflected state preferably comprises lowering
the first tubular string axially so that the lower end of the first
tubular string is near the sea floor. Preferably, a fluid, such as
seawater, is propelled down through the bore of the first tubular
string and through at least one side nozzle near the lower end of
the first tubular, wherein the fluid moving through the side nozzle
deflects the first tubular string. The first tubular string end is
preferably lowered into the sea floor for maintaining the
deflection of the first tubular string. A second tubular string may
then be slidably lowered over the first tubular string for
deflecting the second tubular string.
Inventors: |
Angelle; Jeremy R.;
(Lafayette, LA) |
Correspondence
Address: |
THE MATTHEWS FIRM
2000 BERING DRIVE
SUITE 700
HOUSTON
TX
77057
US
|
Family ID: |
37215525 |
Appl. No.: |
11/115439 |
Filed: |
April 27, 2005 |
Current U.S.
Class: |
166/242.8 |
Current CPC
Class: |
E21B 7/043 20130101;
E02B 2017/0095 20130101; E21B 41/08 20130101 |
Class at
Publication: |
166/242.8 |
International
Class: |
E21B 17/14 20060101
E21B017/14 |
Claims
1. A drive shoe configured for fixedly attaching to an end of a
tubular comprising: a first end configured for fixedly attaching to
a first tubular; a second end, wherein the second end defines a
first aperture through which a second tubular may pass while the
first tubular is slidably inserted over the second tubular, wherein
the drive shoe may guide the first tubular as it is slidably
inserted over the second tubular, said drive shoe having an outer
wall.
2. The drive shoe of claim 1, wherein the second end is configured
having an angular shape.
3. The drive shoe of claim 2, wherein the angled second end allows
the drive shoe to be lowered past obstructions without substantial
hindrance.
4. The drive shoe of claim 1, further comprising a solid material
disposed about the second end, wherein said solid material defines
the first aperture.
5. The drive shoe of claim 1, wherein the solid material is a
composite material.
6. The drive shoe of claim 1, further comprising a reinforcement
disposed about the second end, wherein the reinforcement
substantially prevents deformation to the second end.
7. The drive shoe of claim 1, defining at least a second aperture
in said outer wall of said drive shoe.
8. The drive shoe of claim 7, wherein at least one nozzle is
mounted within said at least one aperture, respectively.
9. An apparatus for deflecting a tubular having a tubular wall and
a bore therethrough, comprising: At least one nozzle mounted within
at least one aperture, respectively, in the tubular wall wherein
fluid moving through the tubular bore is directed through said at
least one nozzle, and wherein said fluid moving through said at
least one nozzle creates one or more jet flows which deflect the
tubular in a direction substantially opposite from the vector sum
of the thrusts generated by the fluid flow through said at least
one nozzle.
10. An apparatus for deflecting a tubular conductor pipe having a
tubular wall and a bore therethrough, comprising: a nozzle mounted
within an aperture in the tubular wall of said conductor pipe,
wherein fluid moving through the tubular bore is directed through
said nozzle, and fluid moving through said nozzle creates a jet
flow which deflects the tubular conductor pipe in a direction
substantially opposite the direction of fluid flow through said
nozzle.
Description
RELATED APPLICATION
[0001] This application relates to U.S. patent application Ser. No.
______, filed ______, for Conductor Pipe String Deflector and
Method.
FIELD OF THE INVENTION
[0002] This invention pertains to apparatus and method for the
deflection of a tubular string which may be suspended from a
drilling or service rig or platform.
BRIEF DESCRIPTION OF THE DRAWINGS
[0003] FIG. 1 illustrates a side elevated view of the lower portion
of an offshore installation utilizing the deflector apparatus
according to the present invention;
[0004] FIG. 2 illustrates a side elevated, diagrammatic view of a
prior art system involving a selected portion of the installation
of the embodiment illustrated in FIG. 1 with a diver and winch line
in use intending to be used to be used to laterally shift the upper
portion of a separated tubular string;
[0005] FIG. 3 illustrates a side elevated view of an alternative
prior art system involving a whipstock that has been speared into
an abandoned well pipe;
[0006] FIG. 4 illustrates a cross-sectional elevated side view of a
deflector sub according to the present invention;
[0007] FIG. 5 illustrates an exploded, elevated perspective view of
an alternative embodiment of a deflector sub according to the
present invention;
[0008] FIG. 6 illustrates a longitudinal, cross-sectional view of
the embodiment illustrated in FIG. 5 according to the present
invention;
[0009] FIG. 6A illustrates an end plan view of the embodiment
illustrated in FIG. 6 according to the present invention;
[0010] FIG. 6B illustrates an enlarged, detail view, partly in
cross section of the nozzle-receiving portion of the deflector sub
body illustrated in FIG. 6A according to the present invention;
[0011] FIG. 7 illustrates a side view, partially cut away, of an
alternative embodiment of the deflector sub according to the
present invention;
[0012] FIG. 8 illustrates a side elevated, diagrammatic view of a
tubular string deflected by a fluid jet according to the present
invention;
[0013] FIG. 9 illustrates a side elevated, diagrammatic view of the
embodiment illustrated in FIG. 8 further illustrating a second
tubular being lowered over a deflected tubular string according to
the present invention;
[0014] FIG. 10 illustrates a side elevated, diagrammatic view of a
pair of concentric tubulars being pushed into the seabed according
to the present invention;
[0015] FIG. 11 illustrates a side elevated view of the internal
tubular string illustrated in FIG. 10 having been removed according
to the present invention;
[0016] FIG. 12 illustrates a side elevated view of an alternative
embodiment with the exterior tubular illustrated in FIG. 10 being
in place during the deflection process according to the present
invention;
[0017] FIG. 13 illustrates a side cut away, elevated view of a jet
nozzle switching apparatus, with a piston in a first position,
according to the present invention;
[0018] FIG. 14 illustrates a side cut away, elevated view of an
alternative embodiment with a drop ball in place, with a piston in
a first position, according to the present invention;
[0019] FIG. 15 illustrates a side cut away, elevated view of the
embodiment illustrated in FIG. 13 with the piston in a second
position according to the present invention;
[0020] FIG. 16 illustrates a side cut away, elevated view of the
embodiment illustrated in FIG. 15 with the drop ball expelled
according to the present invention;
[0021] FIG. 17 illustrates a side cut away, elevated view of the
embodiment illustrated in FIG. 16 further illustrating a removal
tool according to the present invention;
[0022] FIG. 18 illustrates a side cut away, elevated view of the
embodiment illustrated in FIG. 17 with the nozzle switching
apparatus removed according to the present invention;
[0023] FIG. 19 illustrates an elevated, pictorial view of a drive
shoe according to the present invention;
[0024] FIG. 20 is a partial, elevated view of an alternative
embodiment of the invention in which a nozzle is used in the side
wall of a conductor pipe, thereby allowing the conductor pipe to be
directly deflected; and
[0025] FIG. 21 is a graphic illustration showing the resulting
deflection of a tubular which is opposite from the vector sum of
the thrusts generated in accordance with the invention.
DETAILED DESCRIPTION OF EMBODIMENTS
[0026] It should be understood that the description herein below
may use the terms drill string, pipe string, or the more general
term tubular or tubular string interchangeably without intention of
limitation. It should be further understood that the device and
method described herein can be applied to tubulars other than drill
string, casing, or tubing.
[0027] FIG. 1 illustrates the lower portion of a typical fixed
offshore platform 1. It is well known in the art that the platform
structure stands in the seabed B, is preferably anchored in a
conventional manner, and preferably has vertically distributed
braces such as illustrated by braces 1a-1d. It is further well
known that the platform comprises a plurality of "slots" through
which one or more wells can be drilled. Typically, guide sleeves 15
are mounted to the braces 1a-1d and are substantially vertically
aligned with the "slots". Typically, tubulars, used for drilling
and production operations are lowered through the "slots" and the
corresponding vertically aligned guide sleeves 15. Such slots and
guide sleeves are conventional and well known in this art.
[0028] It is well known that due to size constraints of the
platform 1, the number of "slots" is limited. It is further known
that if a wellbore, which corresponds to a particular "slot" and
its vertically aligned guide sleeves 15 becomes unuseable, that
"slot" also becomes unuseable unless the tubular string, which is
to be lowered through the unuseable "slot" can be deflected, from a
substantially vertical position, in order to position a new
wellbore proximate the unuseable wellbore. It is still further well
known, in the art, that a wellbore becomes unuseable for a variety
of reasons, including but not limited to, stuck tubulars or tools,
adverse borehole conditions, and the like. Typically, in an
unuseable wellbore, the tubulars are cut off below the mudline and
are abandoned for the purposes of the drilling and/or production
operations. Typically, after the unuseable wellbore is abandoned,
all tubulars are removed from the corresponding "slot" and its
vertically aligned guide sleeves 15. Therefore, the "slot" is only
unuseable from the point of view of utilizing a substantially
vertical tubular string.
[0029] Still referring to FIG. 1, when a "slot" is to be recovered,
a new tubular string 2 is lowered through the particular "slot" and
must be deflected, in a substantially horizontal direction, to
bypass the unuseable wellbore. According to the present apparatus,
this deflection is preferably accomplished by utilizing a jet sub
3b as further described herein below.
[0030] FIGS. 2 and 3 illustrate a pair of prior art systems for
attempting the tubular string deflection necessary for the "slot"
recovery. FIG. 2 illustrates the use of a diver 4B to secure a
winch line or cable 4a to the platform 1 in an attempt to deflect a
pipe 5 in a substantially horizontal direction. A pulley 4 is
secured to the platform 1. Line 4a hooks around the pipe 5 and
pulley 4 and leads to the surface and a winch on the platform.
However, this method for deflecting a pipe string presents several
problems including the fact that underwater diving operations are
inherently risky and weather conditions must be acceptable for
divers to operate. Therefore, the procedure is often suspended
during inclement weather conditions causing unpredictable delays to
the offshore operations.
[0031] FIG. 3 illustrates using a whipstock 6 which is typically
speared into the top of an existing pipe EP that has been cut off
below the mud line. The whipstock wedge surface or trough 6b serves
to guide and deflect the descending pipe string 5 horizontally.
However, this method for deflecting a pipe string also presents
several problems including difficulty in stabbing the whipstock
into the existing pipe and the probability that the whipstock will
become stuck in the mud and prematurely be set and separate from
the tubular string.
[0032] FIGS. 4-7 illustrate embodiments of the deflector sub 3b,
according to the present invention. FIG. 4 illustrates the basic
structure and operation of the deflector sub 3b. Preferably, the
deflector sub 3b has a closed end 19. However, it should be
appreciated that the deflector sub 3b does not have to be
positioned at the lowermost end of the tubular string 3,
illustrated in FIG. 1. The deflector sub 3b may be positioned
uphole or behind additional subs or devices (FIG. 7). It should be
further appreciated that the deflector sub 3 may comprise various
top and bottom connections, such as, but not limited to, box and
pin connections respectively, and as such, the closed end 19 may be
a separate structure attached to the deflector sub 3b by threaded
attachment, welding, or any other means of conventional attachment
or may be located downhole of the deflector sub 3b.
[0033] Preferably, pumps, or other fluid driving devices, such as
the rig pumps may push or propel seawater or other fluid into the
tubular string 3 in the general direction indicated by the arrow
17. The selection of the fluid, being pumped into the tubular
string 3 may be dependent on the environment, particularly the
environment into which the fluid will be discharged. Preferably,
the seawater, or other fluid, is pumped through the tubular string
3 and into the deflector sub 3b.
[0034] Preferably a jet nozzle 3b2 is positioned in the sidewall of
the deflector sub 3b and becomes the outlet for the seawater or
other fluid being pumped through the deflector sub 3b. As the fluid
exits through the nozzle 3b2 it will produce a fluid jet 3b1. The
fluid jet 3b1, in turn, preferably produces a thrust 3b3, in a
substantially opposite direction from the fluid jet 3b1 and thus
moves the deflector sub in the direction of the thrust 3b3. It
should be appreciated that the amount of pressure in the bore of
the tubular string 3 and the nozzle 3b2 size influences the amount
of the thrust force 3b3, which in turn substantially determines the
amount of deflection of the tubular string 3. It should be
appreciated, by those skilled in the art, that nozzle 3b2 is
typically a commercially available item and can be found in a
variety of sizes. However, the utilization of non-commercial or
non-conventional nozzle sizes should not be viewed as a limitation
of the present apparatus or method.
[0035] FIG. 5 illustrates further detail of the deflector sub 3b
which preferably comprises a deflector sub body 16, nozzle 3b2,
O-ring 18, and retaining ring 20. It should be appreciated that
nozzle 3b2, O-ring 18, and retaining ring 20, whether commercially
available or specifically manufactured for a particular
application, are well known in the art and will not be described in
detail herein. FIGS. 6 and 6A illustrate cross-sectional,
longitudinal and end views, respectively, of deflector sub body 16.
Orifice 22 is preferably machined in the wall of the deflector sub
body 16 for receiving the nozzle 3b2. FIG. 6B is an enlarged view
of orifice 22 in the wall of the deflector sub body 16.
[0036] FIG. 7 illustrates an alternative embodiment of the
invention in which deflector sub 3b is installed behind or uphole
from a bit sub 13 located at the end of tubular string 3. Bit sub
13 is preferably plugged at its lower end 14 in order to allow
fluid and pressure, in the drill string or tubular string 3, to
discharge through nozzle 3b2. The guide tubular 3 is illustrated as
passing beside a bay brace 7 which resides on the exterior of the
guide sleeve 15 through which the unusable wellbore is associated.
The guide sleeve 15 is located on the lowermost horizontal rig
brace 1d illustrated in FIG. 1.
[0037] In recovering a "slot", a drill string or tubular string 3
is preferably lowered, through the "slot" to be recovered and at
least some of its corresponding vertically aligned guide sleeves
15, to a point about three to four feet above the sea floor. It
should be understood that the target depth can vary depending on
several factors including, but not limited to, the overall ocean
depth, speed of currents, amount of desired deflection, and the
size/weight of the guide string. Thus, it should be appreciated
that in more adverse conditions, the deflection of the tubular
string 3 may need to be initiated earlier or later (i.e. further
from or closer to the sea floor) in order to accomplish the desired
deflection or to avoid other objects such as, but not limited to,
other drill strings, or other drilling related operations. The
position of tubular string 3 may then be verified with a
measurement device such as a gyroscope. The tubular string 3 is
then preferably deflected by energizing a deflector sub 3b which is
preferably attached to the end of the tubular string 3.
[0038] FIG. 8 illustrates tubular string 3 being deflected by the
side thrust 3b3 being produced by the fluid jet 3b1. FIG. 8 further
illustrates an unuseable well bore 21 (the wellbore 21 being
unuseable as described herein above). The deflection, of the
tubular string 3, preferably causes the tubular string 3 to bypass
at least the lower most guide sleeve 15 and an unusable wellbore 21
thus recovering the previously unuseable "slot" associated with its
vertically aligned guide sleeve 15 and unuseable wellbore 21. After
tubular string 3 is deflected as illustrated, it is then preferably
inserted or speared into the mud or sea floor B along line 3c. It
should be understood that line 3c is preferably deflected, at some
desired angle, from a vertical axis passing through the recovered
"slot" and its vertically aligned guide sleeves 15 and the
unuseable wellbore 21.
[0039] After the tubular string 3 has been inserted or speared into
the sea floor B mud line (FIG. 9), the pumping of seawater is
preferably stopped and measurements are taken to verify the
position of the deflected drill string or tubular string 3. The
tubular string 3 may then be further lowered until it preferably
supports its own weight axially. It should be appreciated that the
tubular string 3 will substantially sink through the mud or
sediment bottom due to its own weight. It should be appreciated
that as the drill pipe or tubular string 3 is lowered further into
the seabed B, it will preferably retain its deflected position and
not shift in a horizontal direction to its pre-deflected vertically
aligned position. The tubular string 3 may then be disconnected at
the rotary table (not illustrated) on the platform, leaving a stub
protruding through the rotary floor (not illustrated). Another pipe
or tubular string 2 (FIG. 9) may then be lowered over the deflected
tubular string 3.
[0040] FIG. 9 illustrates the drive pipe or tubular string 2
installed to preferably slide over the deflected tubular string 3.
FIGS. 9, 10, 12, and 13 illustrate the tubular string 2 and the
deflected tubular string 3 being in a substantially concentric
relationship. However, this is optional since in order to maintain
such a substantially concentric relationship some type of
centralization device (not illustrated), such as a conventional
tubular centralizer, would have to be used. The deflected tubular
string 3 preferably acts as a guide string to deviate the pipe
string or tubular string 2 as it is lowered, over the deflected
tubular or tubular string 3, to the sea floor B. The pipe string or
tubular string 2 will preferably be thrust into the mud below mud
line as illustrated in FIG. 10. The tubular string 3 may then be
withdrawn from inside the pipe or tubular string 2, as shown in
FIG. 11. It should be appreciated that the conductor bay brace 7
may also aid in the offset alignment of the drive pipe or tubular
string 2. The conductor bay brace 7 will preferably aid in
preventing the drive pipe or tubular string 2 from moving in a
substantially horizontal direction toward the unuseable well bore
21.
[0041] FIG. 12 illustrates an alternative embodiment similar to
that illustrated in FIG. 8 except that both the tubular string 3,
with the deflector sub 3b, and pipe string 2 are installed/lowered
together to a desired position above the seabed B. It should be
understood that the tubular string 3 is installed/lowered while
positioned in the throughbore of the pipe string 2. As described
herein above, pumps may be activated to cause flow through the
fluid jet 3b1 thus producing a side load 3b3 and deflecting both
the tubular string 3 and tubular string 2. When deflected, both the
tubular string 3 and tubular string 2 may be dropped/inserted into
the mud to secure the deflected position. Further, as illustrated
in FIG. 1, the inner tubular string 3 can be retrieved from the
inner bore of the drive pipe or tubular string 2.
[0042] FIGS. 13-18 show another embodiment of a deflector sub 3b.
This embodiment will preferably allow the deflector sub to deflect
the tubular string, as described herein above, and then redirect
the jet flow from a side nozzle to a bottom nozzle or aperture to
aid in the insertion of the drill pipe or tubular string 3 into the
seabed B or "glance" off other obstructions. FIG. 13 illustrates
the nozzle switching apparatus 23 which may be housed in a tubular
section 8. It should be appreciated that the tubular section 8 may
be attached to the end of tubular string 3, a pipe, or other tool
or tubular as necessary in a manner similar to that of the
deflector sub 3b described herein above. Preferably, the nozzle
switching apparatus 23 comprises a drillable material such that the
nozzle switching apparatus 23 will not restrict further drilling
operations. It should be appreciated that the nozzle switching
apparatus 23 may be used as part of a guide string, wherein a
larger tubular string is installed over it, or the apparatus 23 may
be utilized to guide and deflect the larger tubular. Still
referring to FIG. 13, the nozzle switching apparatus further
comprises a guide 8b which is preferably configured to guide the
piston 9. In its first position, the piston 9 isolates the bore 8a,
of the tubular section 8 from a lower cavity 12. The piston 9
preferably comprises a plurality of grooves 9c, disposed about the
piston 9, which may engage corresponding ridges 8d, disposed about
the inner circumference of the lower portion of the tubular section
8. The engagement of the ridges 8d with the grooves 9c will
preferably prevent rotation of the piston 9 when it is necessary to
drill out the nozzle switching apparatus 23 (See FIGS. 16-18). The
lower most portion of the tubular section 8 preferably comprises an
end 8c preferably having an opening 8f, which may be circular or
non-circular, as desired.
[0043] The piston 9 is preferably configured with a central channel
9a bored in a substantially longitudinal direction to intersect
with a cross bore 9b which passes through the piston 9 in a
substantially radial direction. In the first position, the piston 9
is releasably secured such that the cross bore 9b is in fluid
communication with a nozzle 8e. It should be understood that the
piston 9 may be held in the first position by a variety of
attachment means including, but not limited to shear screws, set
screws, ridges, frangible supports, pins, rivets, screws, bolts,
specific tolerance fits or a variety of other conventional
retention means.
[0044] As with the deflector sub 3b, preferably a fluid, such as
seawater, is pumped into the nozzle switching apparatus 23 to
activate the jet flow J1 by pumping or propelling the fluid through
the nozzle 8e. It should be understood that the fluid is pumped
through the pipe or tubular string which extends from the tubular
section 8 to the drilling rig or other drilling structure. As the
fluid is pumped through the bore 8a of the tubular section 8, it
will preferably enter the central channel 9a, move into the cross
bore 9b, and be exhausted through the nozzle 8e to produce the jet
J1. The jet J1 will preferably produce a thrust force in a similar
manner to the jet 3b1 thus causing the tubular 8 and any attached
tubular string to deflect in a direction substantially opposite the
nozzle 8e.
[0045] When the desired deflection is achieved and/or it is desired
to switch operation from the side nozzle 8e to the bottom nozzle or
aperture 8f, a ball 10 or other stopper is preferably dropped down
the bore of the tubular, attached to the tubular section 8, to
close channel 9a as illustrated in FIG. 14. With the seawater still
being pumped into the bore 8a, the pressure builds up against the
top of piston 9 and preferably forces the piston 9 downward to a
second position as illustrated in FIG. 15. It should be appreciated
that the pressure increase, which preferably occurs due to the ball
or stopper 10 blocking channel 9a, will shear or break any support
maintaining the piston 9 in its initial position and thus allowing
for its downward travel. After the piston 9 moves from the first
position, cross bore 9b will no longer communicate with the nozzle
8e. In the second position, cross bore 9b will preferably open to
the cavity 12.
[0046] After the piston 9 has moved to the second position, the
pressure in bore 8a is further raised to pump the ball 10 through
the central channel 9a and the cross bore 9b to permit flow through
the bottom hole 8f. It should be understood that ball 10 may be
comprised of a variety of materials 4 ncluding, but not limited to,
elastomeric, plastic, or frangible materials such as to allow the
ball 10 to deform or break in order to pass through the central
channel 9a, the cross bore 9b, and into the lower cavity 12. After
the ball 10 is pushed out of the piston 9, as illustrated in FIG.
16, any flow though the bore 8a is preferably directed through the
bottom hole 8f to aid in reducing interference from mud and
sediment which is preferably loosened or removed by the flow
through the bottom hole 8f. It should be appreciated that the
bottom hole 8f can also be configured to accept a nozzle, such as
8e or 3b1 to produce a more forceful jet flow for reducing the
interference.
[0047] FIG. 17 illustrates an embodiment wherein the interior
components of the tubular section 8 and the attached tubular string
are ready to be drilled out for subsequent activity. A milling or
drilling assembly 11, which may be commonly run on a drill string,
includes at least one cutter insert 11a. It should be understood,
by those in the art, that a conventional milling or drilling
assembly 11 will preferably drill or mill out substantially all
material attached to the inside diameter of tubular 8. FIG. 18
illustrates the pipe string or tubular 8 after the drilling
operation has been carried out. Typically, the side nozzle 8e can
remain unplugged.
[0048] Referring now to FIGS. 19 and 20, the lowermost end of the
drive pipe or tubular string 2 will preferably, comprise a drive
shoe 26 which may be integral to the lowermost section of the drive
pipe or tubular string 2 or may be a separate drive shoe attached
to the lowermost section of the drive pipe or tubular string 2. It
should be appreciated that the attachment of the drive shoe 26 is
well know in the art and will not be described in detail herein. It
should be understood, that although the embodiments illustrated
herein show the lower most end of the tubular string 2 as having an
angular shaped end, the shape should not be viewed as limiting. A
variety of other end configurations should be included within the
scope of this invention as the end serves to allow easier entry
into the seabed B and aid in guiding the tubular string 2 past
obstructions as it is lowered from the rig to the seabed B.
[0049] As illustrated in FIG. 19, an embodiment of the drive-shoe
26 may comprise a miter cut 28, a solid bottom end 35, and a hole
34 offset from the longitudinal centerline of the shoe 26. The
solid bottom 35 may be a plug, a cap, a molded cap, a welded end,
or other desirable closure member. Preferably, solid bottom 35 will
be of an easy drillable, frangible, or otherwise removable
material, for example, high density polyethylene. The hole 34
allows the deflector sub 3b, and any attached tubulars to pass
through as the larger diameter tubular 2 is lowered over the drill
string or tubular string 3. The miter cut 28 preferably permits the
conductor pipe 2 to "glance" off and not become hung up on the
conductor bay brace 7 (see for example FIGS. 8 and 9), other
tubular strings, or other drilling and production equipment should
it come in contact with them. It should be appreciated that when
the drive shoe 26 initially contacts the conductor bay brace 7,
other tubular strings, or other drilling and production equipment
there will be a point force exerted on the drive shoe 26 from the
contact. The hole 34 is preferably provided so that the position of
the conductor or tubular string 2 with respect to the drill pipe or
tubular string 3 can be controlled. Preferably, the drive-shoe 26
on the conductor pipe or tubular string 2 will effectively "ramp"
off the conductor bay brace 7 with little resistance and allow the
tubular string 2 to enter the seabed B.
[0050] As further illustrated in FIG. 19, an embodiment of the
drive shoe joint 26 preferably comprises a miter cut 28 with
reinforcing material 30 on the long end to prevent curling of the
tip 32. The remainder of the drive shoe is preferably manufactured
from steel or another non-drillable material. The miter cut 28 may
comprise various angles depending on factors such as, but not
limited to, spacing of other guide sleeves 15 (FIG. 1), other
drilling strings, casing, tubing, tool joints, tubulars, and other
drilling related operations.
[0051] It should be understood that the drive shoe 26, with the
miter cut 28, may also be utilized to avoid collisions with other
tubular strings in a manner similar to the "glancing" effect
described herein above. Further, the combination of the drive shoe
26, with the miter cut 28, and the guide string 3, similar to the
embodiment illustrated in FIG. 12, may be utilized to avoid
collisions by activating the fluid jet 3b1 in conjunction with the
miter cut 28 "glancing" operation. It should also be appreciated,
that when desired, fluid may also be moved through the bore of the
shoe 26 such that the fluid, when exiting through the hole 34 may
aid in moving the drive shoe through the softer sediment and
mud.
[0052] Referring now to FIG. 20, there is illustrated the lower end
of a conductor pipe 200 having an end 202 having at least one
nozzle 204 located in the side wall 206 of the conductor pipe 200.
In the operation of the conductor pipe 200, fluid flowing through
the nozzle 204 will cause conductor pipe 200 to be thrust in the
direction of the arrow 208. With this embodiment, by putting the
nozzle in the conductor pipe directly, there is no requirement of
using a drill string and then lowering the conductor pipe over the
drill string. In this embodiment, the conductor pipe is directly
deflected.
[0053] As an option, the lower end of the conductor pipe 200 can be
filled with an easy drillable material 210, for example, hard
plastic.
[0054] Referring now to FIG. 21, an alternative embodiment of the
invention, which illustrates the use of a plurality of nozzles in
the side wall of a tubular, for example, nozzles 220 and 230 which
generate a resulting thrust along the dotted line 240 indicative of
the vector sum of the multiple thrusts which result in a deflection
of the tubular along the arrow 215.
Operation
[0055] In practicing the present invention, in order to recover the
use of an existing slot which has formerly been used in an
abandoned wellbore, the existing string or strings of pipe have to
first be removed.
[0056] All uncemented strings of pipe, if not stuck within the
wellbore, are pulled from the abandoned wellbore, and usually also
any pipes remaining between the seabed and the slot to be
recovered.
[0057] Any remaining strings of pipe are cut approximately eighty
feet below the mudline by conventional apparatus and methods which
are well known in the art of cutting tubulars such as casing
cutters, production tubing cutters, drill pipe cutters, and the
like. Such well-known tubular cutting technology includes the use
of mechanical cutters, explosive cutters, chemical cutters, and
combinations thereof.
[0058] After the existing strings of pipe have been removed, new
strings of pipe are run through the recovered slot and then through
the vertically spaced braces such as the guide sleeves 15 used with
the braces 1a-1d discussed herein with respect to FIG. 1. The new
string or strings are then run down to or into the mudline and the
string or strings can then be moved laterally by the various fluid
jetting processes herein described.
[0059] From the foregoing, it will be seen that this invention is
one well adapted to attain all of the ends and objects hereinabove
set forth, together with other advantages which are obvious and
which are inherent to the tubular string deflector and method of
the present invention.
[0060] The tubular string deflector and method of the present
invention and many of its intended advantages will be understood
from the foregoing description. It will be apparent that, although
the invention and its advantages have been described in detail,
various changes, substitutions, and alterations may be made in the
manner, procedure and details thereof without departing from the
spirit and scope of the invention. It should be understood that
certain features and sub-combinations are of utility and may be
employed without reference to other features and sub-combinations.
This is contemplated by and is within the scope of the claims.
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