U.S. patent number 3,625,281 [Application Number 04/818,726] was granted by the patent office on 1971-12-07 for well completion method and apparatus.
This patent grant is currently assigned to Rockwell Manufacturing Company. Invention is credited to James V. Bonds, Valoris L. Forsyth, David P. Herd.
United States Patent |
3,625,281 |
Herd , et al. |
December 7, 1971 |
WELL COMPLETION METHOD AND APPARATUS
Abstract
A method and apparatus for completing an underwater well
comprising the steps of: lowering hanger means and at least one
tubing string on a handling string into the well casing to a
position where said hanger means will be supported substantially
below the mudline; cementing the tubing string within the well
casing by passing cement through the handling string and the tubing
string; disconnecting and removing the handling string; lowering
connector means, a tubing riser and valve in the casing; and
remotely connecting the connector means to the hanger means,
placing the tubing string and tubing riser in fluidtight flow
communication, the valve being installed in the tubing riser at a
point substantially below the mudline, the tubing riser extending
to the well platform. One hanger embodiment comprises remotely
operable hydraulic slip suspension means which may be activated by
a remote pressure source in communication with the suspension means
through a handling string and setting tool. The setting tool is
provided with latches disengageable from the hanger on rotation of
the handling string. One connector means embodiment comprises
remotely operable hydraulic latch means which may be activated
through a tubing riser to engage the hanger means. An orientation
sleeve may be provided on the connector means for aligning the
tubing riser and tubing string before engagement. A conduit
arrangement is shown which may be used to subsequently disconnect
the connector means and riser from the hanger means for
removal.
Inventors: |
Herd; David P. (Houston,
TX), Forsyth; Valoris L. (Houston, TX), Bonds; James
V. (Houston, TX) |
Assignee: |
Rockwell Manufacturing Company
(Houston, TX)
|
Family
ID: |
25226260 |
Appl.
No.: |
04/818,726 |
Filed: |
April 23, 1969 |
Current U.S.
Class: |
166/344; 166/189;
166/212; 166/348; 166/367 |
Current CPC
Class: |
E21B
34/04 (20130101); E21B 33/047 (20130101) |
Current International
Class: |
E21B
34/04 (20060101); E21B 33/03 (20060101); E21B
33/047 (20060101); E21B 34/00 (20060101); E21b
043/01 () |
Field of
Search: |
;166/5.6,120,123,125,212 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Novosad; Stephen J.
Assistant Examiner: Favreau; Richard E.
Claims
We claim:
1. A method of completing an underwater well having a platform
supported from the floor of a body of water and casing means
penetrating said floor and projecting upwardly through said body of
water to said platform, comprising the steps of: lowering hanger
means and at least one-tubing string on a handling string into said
casing means to a position where said hanger means will be
supported substantially below said floor; cementing said tubing
string within said casing means by passing cement through said
handling string and said tubing string; disconnecting and removing
said handling string; lowering connector means, at least one-tubing
riser and valve means into said casing means; and remotely
connecting said connector means to said hanger means, placing said
tubing string and said tubing riser in fluidtight flow
communication, said valve means being installed in said tubing
riser at a point substantially below said floor, said tubing riser
extending upwardly to said platform.
2. A method of completing an underwater well as set forth in claim
1, characterized in that said platform is submerged in said body of
water substantially below the surface thereof; said method of
completion being conducted from a floating vessel.
3. A method of completing an underwater well as set forth in claim
1, characterized in that said hanger means comprises hydraulically
operable slip means in fluid communication with said handling
string, the supporting of said hanger means within said casing
means being accomplished by applying pressure to said slip means
through said handling string forcing said slip means into
engagement with said casing means.
4. A method of completing an underwater well as set forth in claim
1, characterized in that said hanger means is attached to said
handling string by tool means, said tool means having latch means
thereon engaging said hanger means, said disconnecting of said
handling string being accomplished by rotation of said handling
string to release said latch means allowing the removal of said
tool means along with said handling string.
5. A method of completing an underwater well as set forth in claim
1, characterized by the further steps of: remotely disconnecting
said connector means from said hanger means; and removing said
connector means, said tubing riser and said valve means from said
casing means.
6. A method of completing an underwater well as set forth in claim
1, characterized in that said connector means is provided with
hydraulically operable latch means in fluid communication with said
tubing riser, said remotely connecting said connector means to said
hanger means being accomplished by applying pressure to said latch
means through said tubing riser causing said latch means to engage
a portion of said hanger means.
7. A method of completing an underwater well as set forth in claim
6, characterized by the further step of: removing said connector
means, said tubing riser and said valve means by applying pressure
to said latch means through said tubing riser, causing said latch
means to disengage said hanger means portion.
8. A method of completing an underwater well as set forth in claim
6, characterized in that said latch means comprises piston means
within a cylinder, the rod end of said piston means being connected
to wedge means, said pressure being applied to both the head end
and rod end of said piston means, resulting in an effective force
in the direction of said wedge means forcing latch elements into
engagement with said hanger means portion.
9. A method of completing an underwater well as set forth in claim
8, characterized by the further step of: removing said connector
means by applying pressure through said tubing riser to the rod end
of said piston means while blocking pressure to said head end of
said piston means, resulting in an effective force directed away
from said wedge means to release said latch elements from said
engagement with said hanger means portion.
10. An underwater well comprising:
a fixed platform rigidly supported at the floor of a body of
water,
casing means penetrating the floor of said body of water and
extending upwardly through said body of water to said platform,
hanger means supported in said casing means at a point
substantially below said floor;
at least one-tubing string connected to said hanger means and
extending downwardly through said casing means;
at least one-tubing riser and remotely actuatable engageable and
disengageable connector means connected to said tubing riser and
remotely operable valve means installed in said tubing riser,
said riser and connector means and valve means being lowerable as a
unit separate from said tubing string through said casing for
remote engagement with said hanger means,
said remotely actuatable engageable and disengageable connector
means being disposed at the lower end of said riser in engagement
with said hanger means placing said tubing string and said tubing
riser in fluidtight flow communication through flow bores in said
hanger means and said connector means,
said remotely operable valve being installed in said riser in such
position that when said connector means is in said engagement with
said hanger means said valve is located at a point substantially
below the floor of said body of water.
11. Apparatus for completing an underwater well having a platform
supported at the floor of a body of water and casing means
penetrating the floor of said body of water and extending upwardly
through said body of water to said platform, said apparatus
comprising: hanger means supported in said casing means at a point
substantially below said floor; at least one-tubing string
connected to said hanger means and extending downwardly through
said casing means; at least one-tubing riser connected above said
hanger means by remotely engageable and disengageable connector
means, said tubing riser extending upwardly through said casing
means to said platform; and valve means installed in said tubing
riser at a point substantially below the floor of said body of
water,
said hanger means being provided with suspension means around its
exterior and connection means whereby a disengageable setting tool
may be connected to said hanger and lowered therewith on a handling
string to said point of support, said suspension means being in
fluid communication with said handling string for hydraulic
activation of said suspension means for engaging said casing means
to support said hanger means therein.
12. Apparatus as set forth in claim 11, characterized in that said
suspension means comprises slip means, mandrel means fixed relative
to said hanger means and setting cone means longitudinally movable
on said hanger means, said mandrel means having a frustoconical
surface, said setting cone means having a frustoconical surface
converging in a direction opposite to said mandrel frustoconical
surface, said slip means having oppositely converging frustoconical
surfaces on its inner faces and tooth engagement means on its outer
faces, said slip means frustoconical surfaces being in contact with
said mandrel and setting cone frustoconical surfaces and
cooperating therewith on longitudinal movement of said setting cone
in response to fluid pressure in said handling string, to wedgingly
force said tooth engagement means into engagement with said casing
means.
13. Apparatus as set forth in claim 11, characterized in that said
fluid communication is established through internal ports in said
setting tool and said hanger means sealingly connected at the
interface of said setting tool and said hanger means.
14. Apparatus as set forth in claim 11, characterized in that said
connection means comprises shoulder means, said setting tool being
provided with latch means and wedge means, said wedge means being
longitudinally movable on said setting tool to force said latch
means into engagement with said shoulder means providing fluidtight
flow communication between said handling string and said tubing
string through flow bores in said setting tool and hanger
means.
15. Apparatus as set forth in claim 14, characterized in that said
wedge means comprises sleeve means around said setting tool
longitudinally fixed to said handling string by retainer means,
said handling string being threadingly coupled to said setting tool
so that upon make up of said coupling said sleeve is longitudinally
displaced to force said latch means into said engagement with said
shoulder means.
16. Apparatus for completing an underwater well having a platform
supported at the floor of a body of water and casing means
penetrating the floor of said body of water and extending upwardly
through said body of water to said platform, said apparatus
comprising: hanger means supported in said casing means at a point
substantially below said floor; at least one-tubing string
connected to said hanger means and extending downwardly through
said casing means; at least one-tubing riser connected above said
hanger means by remotely engageable and disengageable connector
means, said tubing riser extending upwardly through said casing
means to said platform; and valve means installed in said tubing
riser at a point substantially below the floor of said body of
water,
said tubing riser being connected to said hanger means by connector
means, said connector means being provided with latch means
engageable with shoulder means on said hanger means to provide
fluidtight flow communication between said tubing riser and said
tubing string through flow bores in said connector means and said
hanger means.
17. Apparatus as set forth in claim 16, characterized in that said
connector means, said tubing riser and said valve means are
lowerable through said casing means from said platform to said
hanger means, said latch means being remotely operable to engage
said shoulder means to provide said fluidtight communication.
18. Apparatus as set forth in claim 17, characterized in that said
connector means and said hanger means are provided with orientation
means cooperating to automatically align said tubing riser and
connector means flow bore with said tubing string and hanger means
flow bore as said connector means and said tubing riser are lowered
to said hanger means.
19. Apparatus as set forth in claim 18, characterized in that said
orientation means comprises dog means on one of said hanger means
and said connector means and sleeve means around the other of said
hanger means and said connector means, said sleeve means having a
double-helix surface facing toward said dog means as said connector
means is lowered to said hanger means, said double-helix surface
converging in slot means whereby said double-helix surface first
contacts said dog means causing said connector means to rotate
until said dog means engages said slot means.
20. Apparatus as set forth in claim 17, characterized in that said
connector means comprises wedge means connected to at least one
piston means movable in a cylinder within said connector means,
said cylinder being in fluid communication with a remote pressure
source whereby fluid pressure may be applied to said piston means
causing said wedge means to force said latch means into said
engagement with said hanger shoulder means.
21. Apparatus as set forth in claim 20, characterized in that plug
means are installed in said tubing riser above said valve means,
said fluid communication between said remote pressure source and
said cylinder being established through first conduit means,
between said cylinder and first port means in said tubing riser,
said first port means being isolated from said valve by said plug
means.
22. Apparatus as set forth in claim 21, characterized by second
port means in said tubing riser below said plug means and second
conduit means establishing fluid communication between said tubing
riser and the rod end of said cylinder means, said first conduit
means being connected to the head end of said cylinder means.
23. Apparatus as set forth in claim 22, characterized in that said
remote pressure source is connected to said first port means
through tubing means connected to said plug means and
concentrically disposed in said tubing riser leaving an annular
space therebetween, said second conduit means being in fluid
communication with said annular space through third port means in
said plug means.
24. Apparatus for completing an underwater well, comprising hanger
means for supporting at least one-tubing string in a casing, said
hanger means having a generally cylindrical body through which
passes a flow bore in fluidtight communication with said tubing
string, remotely operable suspension means being mounted around
said hanger body comprising mandrel means, setting cone means and
slip means mounted therebetween so that movement of one of said
mandrel means and said setting cone means toward the other forces
said slip means into supporting engagement with said casing, in
combination with a setting tool
and a least one-handling string for lowering said hanger means and
tubing string into said casing, said suspension means being in
fluid communication with a remote pressure source through said
handling string and conduit means in said hanger means for remotely
operating said suspension means for said supporting engagement with
said casing.
25. Apparatus as set forth in claim 24, characterized in that said
setting tool and said hanger means are connected by disengageable
latch means comprising a plurality of laterally movable latches
carried by said setting tool in engagement with shoulder means on
said hanger means.
26. Apparatus as set forth in claim 25, characterized in that said
latch means comprises wedge means carried by said setting tool
operable on the rotation of said handling string to disengage said
latches from said hanger shoulder means.
27. Apparatus as set forth in claim 26, characterized in that said
handling string is threadingly connected to the body of said
setting tool, said wedge means comprising a sleeve member
surrounding said setting tool body and attached to said handling
string by retainer means adapted for longitudinal movement relative
to said setting tool body on the said rotation of said handling
string to disengage said latches.
28. Apparatus for completing an underwater well, comprising hanger
means for supporting at least one-tubing string in a casing, said
hanger means having a generally cylindrical body through which
passes a flow bore in fluidtight communication with said tubing
string, remotely operable suspension means being mounted around
said hanger body comprising mandrel means, setting cone means and
slip means mounted therebetween so that movement of one of said
mandrel means and said setting cone means toward the other forces
said slip means into supporting engagement with said casing,
in combination with connector means, at least one-tubing riser and
valve means lowerable together into said casing for connection to
said hanger means, said connector means having remotely operable
latch means for engagement with shoulder means on said hanger means
to place said tubing riser and said tubing string in fluidtight
communication through said hanger flow bore and a flow bore in said
connector means.
29. Apparatus as set forth in claim 28, characterized in that said
latch means comprises a hydraulically movable sleeve and a
plurality of laterally acting latches activated on the longitudinal
movement of said sleeve to engage said hanger shoulder means, said
sleeve being provided with first orientation means cooperable with
second orientation means on said hanger means to align said tubing
riser with said tubing string as said connector means and said
tubing riser are lowered toward said hanger means.
30. Apparatus as set forth in claim 29, characterized by piston
means within cylinder means carried by said connector, said piston
means being connected to said sleeve and movable therewith on
introduction of fluid pressure into said cylinder from said remote
pressure source to activate said latches.
31. Apparatus for completing a well drilled in the floor of a body
of water, comprising hanger means for supporting at least
one-tubing string within a casing at a point substantially below
said water body floor and connector means and at least one-tubing
riser lowerable as a unit through said casing for remote engagement
with said hanger means, placing said tubing string and said tubing
riser in fluidtight flow communication through flow bores in said
hanger means and said connector means, said riser projecting
upwardly from said connector means to a wellhead at the upper end
of said casing for connection to a Christmas tree,
said connector means being provided with a plurality of latches
remotely and laterally movable into engagement with shoulder means
on said hanger means to effect said fluidtight flow
communication.
32. Apparatus as set forth in claim 31, characterized in that said
connector means is provided with sleeve means in contact with said
latches and longitudinally movable by hydraulic means to effect
said lateral movement of said latches.
33. Apparatus as set forth in claim 32, characterized in that said
hydraulic means comprises piston means connected to said sleeve
means, said piston means being movable in a cylinder within said
connector means, said cylinder being connected through said riser
to a remote pressure source for moving said piston means and said
sleeve means.
34. Apparatus as set forth in claim 32, characterized in that said
sleeve means and said hanger means are provided with alignment
means cooperating as said connector means is lowered into contact
with said hanger means to automatically align said tubing string
and said riser.
35. Apparatus as set forth in claim 33, characterized by first port
means in said riser connected to one end of said cylinder through
first conduit means and second port means in said riser connected
through second conduit means to the other end of said cylinder and
plug means installable in said riser between said first and second
port means sealingly isolating one end of said cylinder from the
other end.
36. Apparatus as set forth in claim 35, characterized in that a
remotely operable valve is installed in said riser below said first
and second ports at a point substantially below said water body
floor.
Description
BACKGROUND OF THE INVENTION
1. Field of the Invention
This invention pertains to drilling and completion of oil and gas
wells. In particular it concerns methods and apparatus for
completing a well in relatively deep water.
2. Description of the Prior Art
As more and more offshore drilling occurs, oil companies are
investigating methods of producing at ever increasing water depths.
At the present, a great deal of interest is directed toward depths
of 1,200 feet. This exceeds present bottom supported above the
water platform technology. Divers are also limited with present day
equipment to around 600 feet. Therefore, an ocean floor wellhead
and Christmas tree at a depth of 1,200 feet could not be reached
for repairs or preventative maintenance.
It has been suggested that a bottom supported subsea platform be
installed with its platform submerged at a depth of around 600
feet. The platform would be equipped to receive a multiple number
of remote wellheads and Christmas trees and the necessary
manifolds, controls etc. for producing the wells. Drilling
operations would be conducted from a floating drilling vessel. Such
a platform would not be subject to the wind and wave stress of an
above the water platform. Present technology, would allow such an
installation.
With such a submerged platform it would be desirable to place a
hydraulically controlled safety valve in the tubing strings below
the mudline. The valve would shut-in and control the well in the
event of damage to the platform or casing and tubing strings above
the mudline. If conventional equipment and techniques were used,
the tubing strings with the safety valves and control lines would
be run in the well and suspended in place. This method has at least
three disadvantages:
a. the safety valves might be made inoperative by cement pumped
through the tubing string;
b. the tubing string might become stuck before reaching total
depth, causing the safety valve to be located above the mudline and
preventing the hanger mechanism from reaching the remote wellhead;
and
c. should the safety valve malfunction it could not be removed
during the producing life of the well.
SUMMARY OF THE PRESENT INVENTION
The present invention eliminates these and other problems by
providing a method of completion comprising the steps of: lowering
hanger means and at least one-tubing string on a handling string
into the well casing to a position where said hanger means will be
supported substantially below the mudline; cementing the tubing
string within the well casing by passing cement through the
handling string and the tubing string; disconnecting and removing
the handling string; lowering connector means, a tubing riser and
valve in the casing; and remotely connecting the connector means to
the hanger means, placing the tubing string and tubing riser in
fluidtight flow communication, the valve being installed in the
tubing riser at a point substantially below the mudline, the tubing
riser extending upwardly to the well platform. Apparatus for
performing this method is also disclosed herein including a unique
tubing hanger, handling tool and riser connector.
Using the method and apparatus of the invention, a safety valve may
be installed below the mudline and in the event of damage to the
well platform, the well may be shut-in below the mudline,
preventing costly production losses. The valve is not subject to
malfunction from cement since cementing is performed before the
valve is installed. Should the tubing string become stuck before
reaching total depth the hanger apparatus permits the hanger to be
installed at several levels and still assures that the valve is
below the mudline. In addition, the connector apparatus allows
removal of the riser and valve subsequent to installation
permitting a malfunctioning valve to be repaired or replaced.
BRIEF DESCRIPTION OF THE DRAWINGS
Other objects and advantages of the invention will become apparent
from the description which follows taken in conjunction with the
attached drawings in which:
FIG. 1 is a schematic representation of a submerged platform
installation in which a preferred embodiment of the invention might
be used;
FIG. 2 is a horizontal cross section of a tubing hanger assembly
according to a preferred embodiment of the invention taken on line
2--2 of FIG. 3A, primarily for showing where other sectional
elevation views are taken;
FIG. 3A and 3B are sectional elevation views of tubing hanger and
setting tool apparatus, according to a preferred embodiment of the
invention, taken on lines 3A, 3B-3A, 3B of FIG. 2. FIG. 3A being
the upper portion, FIG. 3B being the continuing lower portion
thereof;
FIGS. 4A and 4B are elevation views partially in section of the
tubing hanger assembly of FIGS. 3A and 3B and a tubing riser
connector, according to a preferred embodiment of the invention,
taken on lines 4A, 4B-4A, 4B of FIG. 2, FIG. 4A being the upper
portion, FIG. 4B the continuing lower portion thereof.
FIGS. 5A and 5B are sectional elevation views similar to FIGS. 4A
and 4B but taken on lines 5A, 5B-5A, 5B of FIG. 2 with a portion of
the hanger assembly broken away; and
FIGS. 6 through 11 are schematic drawings showing the step by step
installation of the apparatus shown in FIGS. 2 through 5B with the
exception of FIG. 7 which shows a slight variation of the tubing
hanger assembly of the embodiment shown in FIGS. 2 through 5B.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
Referring first to FIG. 1, a submerged platform 2 is shown
supported at the floor 4 of a body of water 6. The floor 4 may be
at a depth of 1,200 feet while the platform level is at a depth of
600 feet. A floating drilling vessel 8 is anchored above platform 2
from which drilling and completion operations take place. The
platform 2 is equipped to receive a multiple number of wellheads
10, drilling control equipment 12 and eventually Christmas trees,
manifolds, controls etc. (not shown). The drilling control
equipment 12 could be installed on the drilling vessel. Guidelines
14 may be attached to the platform 2 for guiding equipment into
place. A conductor casing 15 connects the wellhead 10 to the subsea
floor 4. Drilling, installation and cementing of surface casing and
any intermediate casing strings take place through conductor 15 as
in other submerged wells.
In the preferred embodiment of the invention the well would be
completed by the tubingless method. For example, using a 30 inch
.times. 16 inch .times. 10-3/4 inch casing program and dual-tubing
strings, a 16 inch surface casing (not shown) would be installed in
30 inch conductor casing 15. Then the 10-3/4 inch innermost casing
string (not shown) would be installed within this 16 inch surface
casing. Next the dual-tubing strings (not shown) would be run
through the control equipment 12 and suspended on a hanger as much
as several hundred feet below the level of floor 4 within the
10-3/4 inch innermost casing.
Referring now to FIGS. 2 through 5A and 5B, the equipment for
installing tubing strings and safety valves will be described. FIG.
2 is a horizontal section of a portion of a tubing hanger assembly
50 taken on line 2--2 of FIG. 3A and is primarily for the purpose
of showing where other sectional views are taken. Shown in this
view are dual-tubing run bores 53 and 54, internal port 52, and an
alignment dog 51, the construction and purposes of which will be
better understood subsequently.
Referring specifically now to FIGS. 3A and 3B, a preferred
embodiment of the apparatus for suspending dual tubing strings 21
and 22 in the innermost casing string of an underwater well at a
point below the mudline will be described. The apparatus shown
comprises a running tool 80 and tubing hanger 50 the upper portion
of which is shown in FIG. 3A, the lower portion in FIG. 3B. The
tubing strings 21 and 22 are attached to the bottom of hanger 50 by
threaded connections 25.
Tubing hanger 50 comprises a generally cylindrical body portion 55
through which pass vertical tubing run bores 54, internal port 52,
and cement return bore 76. A half-moonlike slot 77 is cut in the
side of hanger body 55 into the upper end of cement return bore
76.
Mounted around the lower end of hanger body 55 are slip suspension
means comprising mandrel 56, a plurality of slip segments 57, and
setting cone 58. The lower end of body 55 has a larger diameter
portion 59 and a lower shoulder 60. Shoulder 60 limits the downward
movement of setting cone 58 and the larger diameter portion 59
cooperates with a skirt portion of setting cone 58 to provide an
annular piston arrangement whereby hydraulic pressure may be
applied to the annular space 61 to force setting cone 58 upwardly.
Annular cells 62 and 63 on portion 59 and setting cone 58,
respectively, seal the annular space 61. Slip segments 57 may be
assembled along with setting cone 58 by sliding them down around
body 55 before mandrel 56 is installed. Slip segments 57 may be
held together by a spring ring (not shown) or the like. After slips
57 are mounted, mandrel 56 may be placed around body 55 and
fastened in the mounting position shown by setscrews 64. To prevent
premature setting of the slips 57, setting cone 58 may be attached
to body 55 by shearpins 65. To set clips 57, a pressure would be
introduced into annular space 61 sufficient to shearpin 65 and move
setting cone 58 upwardly behind slips 57. The frustoconical
surfaces 66 and 67 on setting cone 58 and mandrel 56 respectively,
would cooperate with the opposing frustoconical surfaces 68, 69 on
the back of slips 57 causing them to be wedged outwardly into
engagement with the walls of a surrounding casing (not shown). The
weight of the tubing strings 21 and 22 would maintain support
engagement even if pressure were relieved from annular space 61.
However, with pressure maintained, hold-down of the string against
down-the-hole pressure would be assured.
A receptacle slot is cut near the upper portion of hanger body 55
for the mounting of alignment dog 51. The dog 51 is fastened to
hanger body 55 by capscrews 70. The upper edge of dog 51 is an
inverted "V"-shape and can best be seen in FIG. 4A. The purpose of
alignment dog 51 is to orient apparatus which may be subsequently
attached to hanger 50. The upper end of hanger body 55 is provided
with pockets 72 and hub shoulder 73 for attachment to tool 80 or
any other equipment designed for that purpose.
The running tool 80 comprises two latch segments 82 which clamp the
running tool 80 to hanger 50. Latch segments 82 comprise a lip
portion 83 which engages hub shoulder 73 within pocket 72, a foot
portion 84, retained in recess 85 of tool 80 and heel portion 89
for disengagement as will be more fully understood hereafter.
Latches 82 are set by sleeve 90 and attached wedge block 91 which
are driven down to the position shown by left-hand rotation of
couplings 103 and 104 attached to handling strings (not shown).
Couplings 103 and 104 are threaded into tool body 86 such as at 92
and communicate with hanger bores 54 through tool body bores 94. A
retainer plate 96 is attached to sleeve 90 by capscrews 97,
providing annular pockets 99 in which are located bearing shoulders
105 of couplings 103 and 104. One of the bores 94 through tool body
86 is connected to hanger port 52 by internal tool ports 87, nipple
88 and internal hanger port 78. An alignment pin (not shown)
projecting out of tool body 86 similar to nipple 88 and a socket
(not shown) in hanger body 55 may be provided to aid in alignment
of tool 80 with hanger assembly 50. The flow bores 54, 94 are
sealed by ring gaskets 107 which are held to tool body 86 by a
spring retainer and groove arrangement 108. The complete operation
of hanger assembly 50 and tool 80 will be described in detail
subsequently hereto. For the present, it is sufficient to say that
hanger assembly 50 may be lowered into an underwater well casing,
attached to tool 80, then suspended therein by setting the slips
57. Then tool 80 may be removed, withdrawing nipple 88 and seal
rings 107, for further operations.
Referring now to FIGS. 4A, 4B, 5A and 5B a tubing riser connector
unit 150 for attachment to hanger assembly 50 will be described.
FIG. 4A is a vertical section view of the upper portion of
connector unit 150 connected to hanger assembly 50. FIG. 4B is a
continuation of FIG. 4A showing the lower portion of connector
sleeve 160 and hanger assembly 50 from which tubing strings 21 and
22 are suspended. FIGS. 5A and 5B are views similar to FIGS. 4A and
4B, except rotated 90.degree..
In FIGS. 4A and 4B the hanger assembly 50; including lower shoulder
60, setting cone 58, slips 57, mandrel 56, slot 77, the upper end
of cement bore 76, alignment dog 51 and tubing run bores 53, 54;
can easily be seen. The tubing riser connector body 155 has dual
tubing run bores 156, 158 communicating with hanger bores 53, 54.
This connection is sealed by ring seals 153 and 154 affixed to
connector body 155 by spring ring and groove arrangements 163, 164.
Threadingly connected at the top of connector bore 156, 158 are
nipples 166, 168 which extend upwardly to a safety valve package
(not shown) above which tubing risers project upwardly for
extension to a submerged platform such as 2 in FIG. 1. Connector
sleeve 160 surrounds the lower end of connector body 155 and the
upper end of hanger assembly 50. The lower portion of connector
sleeve 160 is a double-helix alignment surface 170 which converges
in a vertical slot 171. The purpose of the double helix 170 and
slot 171 is to automatically align the connector 150. If connector
150 is lowered toward hanger 50, the double-helix surface 170 will
first contact one side of the inverted "V"-shaped upper edge
51.sub. a, 51.sub. b of alignment dog 51, causing the entire unit
to rotate until a slot 171 and alignment dog 51 are fully engaged.
Final alignment of bores 54, 156 and 53, 158 are assured by
alignment pins and holes (see 188 in FIG. 5A).
Referring now to the 90.degree. rotated views of FIGS. 5A and 5B
the details of the latching apparatus of connector 150 will be
described. The pockets 72 and hub shoulder 73 of hanger body 55
previously described are used for attaching to connector 150 in a
similar manner as to the running tool 80 in FIG. 3A. Oppositely
opposed latches 182 are retained in connector body recesses 185 by
latch foot portions 184. Wedge pieces 191 hold the lips 183 of
latches 182 in engagement with hub shoulder 73. The cooperating
surfaces 193 between latches 182 and wedge pieces 191 are
self-locking tapers.
Mounted in connector body 155 for longitudinal movement by pressure
are two pistons 200 which have rod portions 202 and heads 204. The
rods 202 are connected to wedge pieces 191 by threaded connections
199 and move simultaneously with them and sleeve 160 which is tied
to wedge pieces 191 by keys 198. The piston heads 204 are mounted
in piston cylinders 206 for movement from a disengaged position at
the upper end of the cylinders 206 to the engaged position shown.
The upper ends of the cylinders 206 are closed by cylinder plugs
208, 209. Connected to the upper end of each cylinder plug 208, 209
are external conduits 218, 219 the purpose of which will be better
understood subsequently hereto. Internal ports 210, 211 and 212
connect the rod side of pistons 204 with conduit 218. Internal
ports 214, 215, 216 and 217 connect the head side of pistons 204
with conduit 219. Each cylinder plug 208, 209 is provided with
annular seals 228, 229 which seal and isolate the various ports and
areas of pressure. Piston heads 204 and piston rods 202 are also
provided with annular seals 224 and 222, respectively. A full
description of the operation of pistons 204 and latches 193 will
follow. For the present, it is sufficient to note that the downward
movement of pistons 204 causes latches 182 to engage hanger hub
shoulders 73 and the upward movement of pistons 204 causes them to
be disengaged.
Referring now to the remaining schematic drawings, FIGS. 6-11, a
step by step explanation of the operation and procedure for
utilizing the previously described apparatus will be given. The
same reference numbers used in FIGS. 2-5B will be given to
corresponding parts in FIGS. 6-11.
As previously explained with reference to FIG. 1, drilling and
setting of casing is performed from a floating drilling vessel and
the wellhead equipment is to be located at a submerged platform 2.
In the 30 inch .times. 16 inch .times. 10-3/4 inch representative
casing program given, the 16 inch surface casing would be installed
inside of the 30 inch conductor casing 15. Then, the 10-3/4 inch
innermost casing would be installed and suspended in the 16 inch
casing.
At this point tubing would be run in the innermost casing
represented in FIG. 6 by the reference number 18. The dual-tubing
strings 21, 22 are lowered into casing 18 attached to the tubing
hanger assembly 50 which is in turn attached to the running tool 80
as previously described with reference to FIG. 3A. The hanger 50
and running tool 80 are lowered on running or handling strings 123
and 124 with slips 57 in the retracted position, until the tubing
strings 21, 22 reach their total depth. The strings 21, 22 are of
such a length that hanger 50 will then be at a point in casing 18
approximately 100 feet or more below the floor of the body of water
in which the well platform is submerged. At this point the slips 57
are set by applying pressure to setting cone 58 through handling
string 123, internal port 87, nipple 88 and internal port 52.
First, shear pins 65 are sheared releasing the setting cone for
upward movement. Then coaction of stationary mandrel 56 and the
moving setting cone 58 causes slips 57 to move outwardly into
engagement with the walls of casing 18 as shown in FIG. 7.
FIG. 7 also shows an alternative suspension arrangement whereby
casing 18 is provided with a support head 130 and the lower end of
hanger assembly 50 is provided with a spring-loaded latch assembly
132 which automatically engages latch grooves in the head 130 for
primary support of hanger 50 and the tubing strings 21, 22. In this
case the slip means could be used as secondary suspension in the
event the tubing strings 21, 22 become stuck before the latch
assembly 132 reaches head 130.
After the hanger assembly 50 is set tubing strings 21, 22 would be
cemented in place by pumping cement down through the handling
strings 123, 124, tubing strings 21, 22 and back up through the
space 133 surrounding tubing strings 21, 22 in casing 18. FIG. 3B
shows the cement return bore 76 and slot 77 for allowing cement
returns through the hanger assembly 50. At the operator's option
the cementing step could be performed before the setting of hanger
assembly 50. This would allow reciprocation of the tubing strings
during cementing, as some operators prefer.
Next, running tool 80 would be disconnected from hanger assembly 50
and removed from the well. This is accomplished by rotating
couplings 123 and 124 to the right causing retainer plate 96 and
sleeve 90 to move upwardly. The wedge blocks 91 attached to sleeve
90 catch the heel of latch foot portion 84 causing latch lip 83 to
pivot out of engagement with hub shoulder 73. As tool 80 is
removed, nipple 88, guide pin 135 and ring seals 107 are withdrawn
also.
Referring now to FIGS. 8 and 9, the next step is to install tubing
riser connector 150, safety valve package 250 and tubing risers
300, 301. The safety valve package 250 is installed in the riser
strings above nipples 166, 168 which are shown in FIG. 4A. Control
lines (not shown) would be run in with the risers 300, 301 for
remotely operating the valves 251 and 252. Connected in riser
string 300 are ported nipples 303, 305 and a landing nipple 304
such as Otis type "S". External conduit 218 is connected to ported
nipple 305 and external conduit 219 is connected to ported nipple
303. External conduits 218, 219 communicate with piston cylinders
206 through the internal porting 210, 211, 212, 214, 215, 216 and
217 as more fully described heretofore with reference to FIG.
5A.
As the connector 150 is lowered into place the alignment surface
170 of connector sleeve 160 contacts alignment dog 51 causing the
sleeve 160 along with the entire connector assembly 150 to rotate
until slot 171 engages the alignment dog 51 preventing further
rotation. Final alignment is accomplished by pins 188 engaging
corresponding holes in the upper face of hanger assembly 50. Thus,
the tubing run bores 53, 158 and 54, 156 are properly aligned and
sealed by ring seals 153, 154.
During the lowering operations pistons 200 and sleeve 160 are held
in their upper positions so that latches 182 are pivoted away from
hanger shoulder 73. After connector 150 and hanger 50 are abutting
each other connector 150 is latched to hanger 50 by applying
pressure through riser 300 with valve 251 closed. Thus, pressure is
applied below piston heads 204 through conduit 218 and above piston
heads 204 through conduit 219. Since the effective pressure area is
the area of piston rods 202, pistons 200 and sleeve 160 are forced
downward wedging latches 182 into engagement with hanger shoulder
73 as previously described.
The tubing risers 300, 310 pass upwardly through casing 18 to the
submerged platform (2 in FIG. 1) where they are connected to a
production manifold or "Christmas tree" as it is sometimes called.
The control lines (not shown) which run from safety valve package
250 to a remote operating station control the opening and closing
of valves 251, 252. If for any reason the submerged platform should
become damaged to the extent that there is danger of losing well
fluid, valves 251, 252 could be closed, shutting the well in at a
point well below the mudline. Then, even if the platform turned
completely over, the well would be protected.
Referring also now to FIG. 10 a method for releasing connector 150
from the well hanger 50 will be described. If valve 251 is
operative, a locator mandrel with tubing plug 280 is run on a wire
line through riser 300 and latched in landing nipple 304. Pressure
is applied through riser 300. Check valve 281 and seals 282 connect
pressure to external conduit 218 routing the pressure below piston
heads 204 causing the pistons 200 to move up, releasing the
connector latches (182 in FIG. 8). The area of the piston heads 204
less the area of rods 202 is greater than the area of rods 202.
Therefore, using the same pressure as was used in setting the
latches a greater upward releasing force is applied. The latches
should be easily released. Fluid above the piston heads 204 is
displaced through external conduit 219 through open valve 251.
Referring also to FIG. 11, an alternate method for releasing the
connector 150, when valve 251 is inoperative and in the closed
position, will be described. A releasing adapter or plug 290 is
attached to a locating mandrel 291 and run in place on small
diameter tubing 292. Pressure is applied through tubing 292. Seals
293 on adapter 290 seal above and below the port in nipple 305,
routing the pressure through external conduit 218 below piston
heads 204 for releasing the connector 150. Fluid above pistons
heads 204 is displaced through external conduit 219, a port 294 in
mandrel 291 and adapter internal ports 295 to the annulus between
small tubing 292 and riser 300.
The foregoing description has shown how the tubing strings of an
underwater well with a submerged platform may be suspended from a
hanger set at a point below the mudline and how risers may be
attached above the hanger with a safety valve package located also
below the mudline to close in the well in the event the platform or
risers thereto are damaged. Both the installation and removal of
such equipment has been described. Such methods and apparatus for
the performance thereof permit safe and easily maintainable
underwater well installation at depths previously prohibited.
Although the primary intended use for such a method and apparatus
is with a submerged platform, it could also be used with an above
the water platform as a safety feature in the event the platform
were damaged or turned over by hurricanes, sea action or collision
with a sea going vessel.
* * * * *