Note: Descriptions are shown in the official language in which they were submitted.
CA 02222194 1997-12-09
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SPOOLABLE COILED TUBING COMPLETION SYSTEM
Background of the Invention
This application is a divisional of Canadian Application Serial No.
2,134,273, filed on October 25, 1994.
The present invention is directed to a method and apparatus for
completion or recompletion of oil and/or gas wells with spoolable, flexible
coiled tubing and retrieving the same.
In place of conventional drilling rigs or workover rigs, completions
or recompletions of conventional oil and gas wells by coiled tubing have
been disclosed in United States Patent 4,844,1fi6. However, the various
completion equipment utilized, such as safety valves, gas lift mandrels and
packers are rigid tools placed in the coiled tubing while the coiled tubing
is being inserted into the well. In addition, the various completion
equipment components are of a larger diameter than the coiled tubing
(called upset). Since the completion equipment is rigid and has a larger
outside diameter than the coiled tubing, these characteristics prevent the
completion equipment from being run through a coiled tubing injector
head. Therefore, equipment including windows must be provided to
couple and splice this type of completion equipment in the coiled tubing
string under the injector head. Furthermore, various specialized well
control equipment, such as pack-offs and BOP stacks, were required
because of the external upsets in the installation. Such installations were
much more complicated to operate and required additional equipment
when used with live wells which need to be pressure balanced.
The present invention is directed to a coiled tubing completion
system which utilizes a continuous flush outside diameter length of coiled
CA 02222194 2000-08-23
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tubing and various completion components. The coiled tubing and the
components are flexible and may be spooled onto a reel into lengths as
long as 25,000 feet. The spool of coiled tubing and components is
transported to the well site by a motorized vehicle and may be
continuously injected into the well bore. As injection is occurring, a seal
of well bore pressure may be more easily maintained around the
circumference of the coiled tubing and components allowing the entire
length to be placed in the well bore without a killing operation,
eliminating the need for expensive kill fluids or damaging the formation.
Included in the coiled tubing are various completion equipment, such as
safety valves, annular control valves, concentric gas lift valves, packers,
landing nipples, and sliding sleeves which are provided with an outside
diameter flush with the coiled tubing outside diameter and which are
flexible, spoolable, and with through bores large enough to pass wireline
tools for various well completion operations. In addition, some of this
equipment, such as safety valves and annular control valves are
hydraulically operated through a hydraulic control conduit which must not
be upset to the outside diameter of the coiled tubing or interfere with the
through bore of the coiled tubing. The coiled tubing completion .system
is simplified and cost is reduced since well control equipment that is
normally required for handling external upsets in a production tubing is
not required.
Summary
The present invention is directed to a spoolable, flexible coiled
tubing completion system whicr includes a flexible coiled tubing having an
outer wall and a fore therethrough in which the outer wall has a
substantially constant outer diameter and the bore is adapted to pass wireline
tools. By
"substantially constant" is meant that the outside diameter is free of upsets.
The system
may include one or more of the following completion components: a
longitudinally
flexible safety valve, a longitudinally flexible annular control valve
positioned in the
coiled
CA 02222194 1998-03-09
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tubing, one or more longitudinally flexible gas lift valves positioned in the
coiled tubing, a longitudinally fle~le isolation packer positioned in the
coiled tubing, a longitudinally flexible landing nipple- positioned in the
coiled tubing, a longitudinally flenble sliding sleeve positioned in the
coiled tubing, a production packer and a pump out plug. All of the above
include a bore therein for passage of wireline tools and have an outside
diameter flushed with the outside diameter of the coiled tubing. .The
safety valve and annular contml valve each have a hydraulic control line
extending upwardly within the outer wall of the coiled tubing but adjacent
the outer.wall for avoiding interference with the passage of wireline tools
through the coiled tubing bore.
'The present invention provides a
coiled tubing hanger supporting the coiled tubing, a control line housing
positioned above the coiled tubing hanger for receiving the upper end of
the coiled tubing and for connection to the hydraulic control li-nes,-and an
internal connector gripping means having an outside diameter no greater
than the coiled tubing for longitudinal movement into the interior of the
top of the coiled tubing. In one embodiment, a hydraulic control li-ne
cutting means is positioned in the control line housing for cutting any
_ hydraulic control li-ne. In addition, holding means may be ~3rovided- iu the
control line hanger for holding the hydraulic control line in -tension
whereby any cut lines will retract in the coiled tubing and out of the way
of the internal connector. -
Further, the present invention provides
movable centralizing means in the control line housing for engaging and
aligning the top of the coiled tubing for engagement by the internal
connector.
Still further, the present invention provides a
coiled tubing safety valve having a housing secured to the coiled tubing,
a valve closure means in the passageway moving between open and closed
position for controlling the fluid flow through the passageway, a flow tube
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telescopically moving in the housing for controlling the movement of the
valve closure member, hydraulic piston and cylinder fluid actuating means
positioned above and connected to the flow tubb with a biasing spring
means positioned about the flow tube and connected thereto for moving
the valve to a closed position. The spring means and the flow tube are
longitudinally flexl'ble for allowing bending about the longitudinal axis of
the valve for allowing the valve to be spooled on a coiled tubing reel
Preferably, the hydraulic actuating mean is connected to the flow tube by
a flexible connection. Preferably, a downstop is connected to the inside of
the coiled tubing for limiting the movement of the flow tube. In one
embodiment, the coiled tubing includes a wall and a hydraulic control line
is connected to the hydraulic piston and cylinder actuating means and is
positioned in the wall of the coiled tubing. The longitudinally flexible
valve is provided longitudinal tle~bility by having a housing which
includes first and second separated parts secured to the inside of the
coiled tubing, and includes a plurality of separated longitudinally
extending ribs.
Yet further, the present invention provides a
hydraulically controlled annular control valve having a housing With an
- expandable flexible cup seal having a sealing lip and positioned around the
housing for sealing between the housing and a well conduit, byfiraulic
piston and cylinder means for retracting the cup seal, expandable slip
means positioned around the housing for gripping the interior of the well
conduit and a second hydraulic piston and cylinder means for expanding
the slip means. The flexible cup and the slip means are initially retracted
to an outer dimension substantially equal to the outside diameter of the
coiled tubing and the control valve for passing through an injector and
wellhead. The control valve is longitudinally flexible for allowing bending
about its longitudinal axis for allowing the valve to be spooled on a coiled
tubing reel. Preferably, the annular control valve includes a longitudinally
movable protector sleeve initially covering and protecting the seal lip,
CA 02222194 2000-08-23
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spring means biasing the cup seal into a fail safe expanded sealing
relationship, movable wedge means for expanding the cup seal, a second
spring means for biasing the cup seal toward a retracted position, and a
breakable protective covering initially positioned about the cup seal and
the slips.
Still further, the present invention provides a
spoolable, flexible hydraulically set, straight pull release well packer
positioned in the coiled tubing and including a mandrel having a bore
therethrough for the passage of wireline tools, an expandable packer seal
positioned about the mandrel, expandable slip means positioned about the
mandrel in which the packer seal and slip means are initially retracted to
an outer dimension substantially equal to the outside diameter of the
coiled tubing. Hydraulic piston and cylinder actuating means are
positioned outside the mandrel and between the packer seal and the slip
means for setting the slip means in the packer seal. The well packer is
longitudinally flexible for allowing bending about its longitudinal axis for
allowing the packer to be spooled on a coiled tubing reel. Preferably, the
piston and cylinder actuating means is longitudinally flexible and a
breakable protective coating is initially positioned around the packer and
- the slip means. - ~ - - -
- Still further, the present invention provides a
spoolable, flexible landing nipple positioned in a coiled tubing for receiving
well tools which includes first and second separate spaced tubular
members in which the members each have a bore extending therethrough
for the passage of wireline tools. Each of the members is secured to the
inside of the coiled tubing and a flexible boot is positioned between each
of the members and the inside of the coiled tubing. Preferably, one of the
members include a no-go shoulder and a locking recess and the other of
the members includes a polished bore.
Yet further, the present invention provides
a spoolable, flexible sliding sleeve positioned in a coiled tubing for
~
CA 02222194 1998-03-09
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controlling communication between the inside and the outside of the coiled
tubing. The sleeve includes a tubular housing having a bore therein for
the passage of wireline tools and has first and second ends connected in
. a coiled tubing. The housing includes at least one port for communicating
between the outside and inside of the housing. A sliding tubular member
telescopically moves in the housing for opening and closing the poxfis. An
upper and lower guide is positioned on opposite sides of the member_and
secured to the inside of the coiled tubing, and a flexible boot is positioned
between each of the guides and the inside of the coiled tubing wherein the
sliding sleeve is longitudinally flexible for allowing the sliding sleeve to
be
spooled on a coiled tubing reel.
Still further, the present invention provides a
retrievable system for retrieving a coiled tubing system having a
continuous sized outside diameter which includes a coiled tubing hanger
supporting and sealing the outside of the upper end of the coiled tubing
with a wellhead, a blowout preventer and an injector head successively
positioned above the coiled tubing hanger, and a second coiled tubing
positioned on a reel and having a first end with a longitudinally actuated
internal gripping connector attached thereto for insertion through the
- injector, blowout preventer and wellhead -and into the upper end o~ the
first coiled tubing for gripping and removal the tubing from the w~11.
Yet further, the present invention provides a control line housing
positioned above the coiled tubing hanger for receiving the upper end of
the first coiled tubing and for connection to any hydraulic lines in the first
coiled tubing. Preferably, a hydraulic control line cutting means is
positioned in the control line housing for cutting any control lines for
preventing the control lines from interfering with the internal gripping
connector. Preferably holding means are provided in the control line
hanger for holding the hydraulic control lines in tension whereby a cut
line will retract in the first coiled tubing housing and out of the Way of the
internal connector. Preferably centralizing means are provided in the
~
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control line housing for engaging and aligning the top of the first coiled
tubing for engagement by the internal connector. Preferably the
centralizing means is transversely movable in relation to the longitudinal
axis of the control line housing. Preferably the centralizing means
includes a guide for guiding the internal connector into the top of the first
coiled tubing.
Other and further features and advantages wilt be apparent
from the following description of presently preferred embodiments of the
invention; given for the purpose of disclosure, and taken in conjunction
with the accompanying drawings.
Brief Description of the Drawings
Figs. lA, iB, 1C, 1D, lE, 1F, 1G, 1H, 1I, 1J, 1K, 1L, 1M, 1N, 10,
1P, 1Q, 1R, IS, 1T, and lU are fragmentary elevational views, partly in
cross section, and together form a spoolable coiled tubing completion
system of the present invention,
Fig. 2 is a cross-sectional view taken along the line 2-2 of Fig. 1D,
Fig. 3~is a cross-sectional view taken along the line 3-3 of Fig. 1F,
Fig. 4 is a cross-sectional view taken along the line 4-4 of Fig. lA,
Fig. 5 is a schematic elevational _view, partly m cross section, of
another embodiment of a control line hanger,
Figs. fiA and 6B are elevational views, in cross section, illustrating
the flexible hydraulically controlled safety valve of the present invention
in a spooled and closed position,
Figs. 7A, 7B and 7C is an elevational view, in quarter section. of the
hydraulic control annular control valve of the present invention in the
retracted and spooled position,
Figs. 8A, SB, 8C, 8D and 8E are continuations of each other and
form an elevational view, in cross section, of the annular control valve of
the present invention in position in a well conduit in a closed position,
CA 02222194 1997-12-09
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Figs. 9A, 9B, 9C and 9D are continuations of each other and form
an elevational view in quarter section of the isolation packer of the
present invention in a retracted and spooled position,
Figs. 10A, lOB and lOC are continuations of each other and form
and elevational view, in cross section of the production packer of the
present invention in the retracted position,
Fig. 11 is an elevational view, in cross section, of the landing nipple
of the present invention shown in the spooled position,
Fig. 12 is an elevational view, in cross section, of the sliding sleeve
of the present invention shown in the spooled position,
Fig. 13 is a cross-sectional view taken along the line 13-13 of Fig.
8A,
Fig. 14 is a cross-sectional view taken along the line 14-14 of Fig.
8B,
Fig. 15 is an elevational view of a retrieval system connected to the
spoolable coiled tubing completion system of the present invention, and
Figs. 16A and 16B are continuations of each other and illustrate a
suitable internal connector for retrieving the coiled tubing completion
system of the present invention.
Description of the Preferred Embodiment
While the spoolable coiled tubing completion system of the present
invention will be described, for purposes of illustration only as including
a tubing retrievable safety valve, an annular safety valve, one or more
concentric gas lift valves, an isolation packer, a landing nipple, a sliding
sleeve, a production packer and a pump out plug, many completion
systems may utilize only some of this equipment depending upon the
particular application.
Referring now to Figs. lA-lU, the spoolable coiled tubing
completion system of the present invention is best seen and is referred to
by the reference numeral 10 and is installed and retrieved though a
CA 02222194 2000-08-23
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retrieval system generally indicated by the reference numeral 12 (Fig. 15).
The completion system 10 is installed and retrieved by the retrieval
system 12 which generally includes a mobile truck and power unit 14
having a conventional coiled tubing reel 16 which inserts and removes the
completion system 10 through a guide arch 18, an injector head 20, a
blowout preventer 22, a wellhead or valve 24, a control line housing 2~~
a coiled tubing hanger 28, a tubing hanger 30, and a casing hanger 32.
As will be more fully discussed hereinafter, a completion system 10
is longitudinally flexible and can be spooled on the reel 16. All of the
components have a flush diameter substantially equal to the outside
diameter of the coiled tubing, but yet have a bore with a passageway
therethrough for passage of wireline tools. Thus, the completion system
10 is highly advantageous as it may be~ inserted into and retrieved with
the retrieval system 12 without requiring a window to insert or splice
equipment into the coiled tubing and allows the use of standard well
control equipment such as the injector head 20, the BOP 22 and any
packoffs therein to control annular pressure because of the externally
flushed design of the system 10. Thus, the installation of the present
invention is simplified and cost reduced since well control equipment for
external upsets is not required.
Referring now to Figs. lA, 1B and 4, a flexible coiled tubing 34 has
an outer wall and a bore 36 therethrough in which the outer wall has a
continuous outer diameter without upsets and the bore is adapted to pass
wireline tools. The coiled tubing 34 is supported in the coiled tubing
hanger 28 (Fig. 1B) and the top 37 of the coiled tubing 34 extends up into
the control line hanger 26 for providing one or more hydraulic control line
exits for any hydraulic control lines which are utilized in the completion
system 10 such as a safety valve and annular control valve, which will be
more fully discussed hereinafter. The preferred embodiment is to provide
two hydraulic control lines 38 and 40 within and inside the wall of the
coiled tubing 34,.
CA 02222194 2000-08-23
~ v
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The control line hanger 26 is positioned in a control line
housing 27 which may include a conventional pressure test plug 29.
Additionally, movable centralizing means, such as guides 42, are provided
in the control line housing 27 for being transversely movable to the axis
of the coiled tubing 34 for supporting the upper end 37 of the coiled
tubing 34 during the retrieval process as will be more fully discussed
hereinafter. Preferably, the guides 42 include inclined surfaces 44.
Referring now to Figs. 1C, 1D and 2, a surface control subsurface
spoolable hydraulic control longitudinally flexible safety valve is generally
indicated by the reference numeral 46 having a housing which includes
first 48 and second 50 separated parts each of which is secured to the
inside of the coiled tubing 34 and which forms part of the housing of the
safety valve 46 and thus presents a flush exterior with the remainder of
the coiled tubing 34 without requiring any upsets. The valve 46 generally
includes a bore 52 therethrough for the passage of wireline tools, an
annular valve seat 54, a valve closure element or flapper valve 56
connected to the housing by pivot pin 58, a flow tube 60 is telesco$ically
movable in the housing through the valve seat 54 to move the flapper 56
to the open position as best seen in Fig. 1D. When the flow tube 60 is
moved upwardly, the flapper 56 is allowed to move upwardly onto the seat
54. Hydraulic piston and cylinder actuating means such as one or more
pistons 62 and cylinders 64 in communication with hydraulic conduit 38
are positioned above and connected to the flow tube 60 by a flexible
connection 66, such as a loose tongue and groove connection, for moving
the flow tube 60 downwardly and opening the valve 46. A biasing spring
67 is positioned about the flow tube 60 and connected thereto for moving
the flow tube 60 upwardly and into a fail safe closed position. The spring
67 and the flow tube 60 are longitudinally flexible for allowing bending
about the longitudinal axis of the valve for allowing the valve to be
CA 02222194 1997-12-09
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spooled onto a coiled tubing reel. Preferably, the flow tube 60 includes a
plurality of separated longitudinally extending ribs 68 for providing
longitudinal flexibility. In addition, the valve 46 includes a down stop 70
positioned to engage a stop on the flow tube 60 for preventing excessive
column loading in the safety valve 46. Referring now to Figs. 6A and 6B,
the safety valve 46 is shown in the closed and spooled condition.
Referring now to Figs. lE, 1F, 1G, 1H and lI, a surface control
subsurface annular control safety valve which is longitudinally flexible,
spoolable and hydraulically controlled is positioned in the coiled tubing 34
and has a bore 74 therein for passage of wireline tools. The valve 72
includes a housing 76 having an outside diameter substantially equal to
the outside diameter of the coiled tubing 34. The valve 72 includes an
expandable, flexible cup seal 78 having a sealing lip 80 and is positioned
around the housing 76 for sealing between the housing 76 and a well
conduit 79 which may be production tubing or well casing. The valve 72
also includes slips 82 outside of the housing 76.
As best seen in Figs. 7A, 7B and 7C, the annular control valve 72
is longitudinally flexible and the expandable cup seal 78 and the slips 82
are initially in a retracted position whereby the outside diameter~ef the
valve 72 is substantially the same as the outside diameter of the coiled
tubing 34 whereby the valve 72 may be inserted through the retrieval
system 12. Preferably, the outside of the cup seal 78 is sealed with a thin
breakable protective cover such as a heat shrinkable plastic 77, such as
sold under the trademark "Teflon" and the slips 82 are initially sealed with
a thin breakable protective covering such as room temperature vulcanized
rubber 83. The protective covers on the seal 78 and the slips 82 are for
protecting these elements from components in the system 12 and also
protecting any seals in the system 12 from the valve 72. However, after
installation in the well, the protective covers, which are breakable, are
broken on expansion of the seal 78 and slips 82. Additionally, a
longitudinally movable protective sleeve 81 initially covers and protects
CA 02222194 1997-12-09
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the sealing lip 80 as it is passed downwardly through the system 12 and
into the well.
Referring again to Figs. 1E and 1F, hydraulic piston and cylinder
means, such as one or more pistons 84, are movable in cylinders 86 and
in communication with hydraulic control conduit 40. The hydraulic
control means are connected by a sleeve 88 to a plurality of wedges 90
(Figs. 1F .and 3). Spring biasing means 92 normally biases the piston and
cylinder assembly upwardly moving the sleeve 88 and the wedges 90
upwardly to expand the lip seal 80 against the interior of the well conduit
94, as best seen in Figs. 8A-8E (after setting the slips). Actuation of the
hydraulic piston and cylinder assemblies 84 and 86 moves the wedges 90
downwardly and allows the flexible cup seal, which may be rubber, to
retract by the action of springs 93 embedded in the flexible cup seal 78.
As best seen in Fig. 1F, with the cup seal 78 in the retracted position, lift
gas may be injected down the annulus between the annular control valve
72 and the inside of the well conduit 79 to downhole gas lift valves which
will be more fully discussed hereinafter. And the annulus provides a much
greater gas flow area than conventional annular control valves. However,
actuation of the flexible cup 78 to the expanded. position (Fig. 8B~ packs
off and seals the annulus between the valve 72 and the inside of the well
conduit 79. And the lip 80 is pressed into an increasing sealing
relationship with the inside of the well conduit 79 as the annulus pressure
therebelow increases.
Prior to expanding the cup seal 78, the slips 82 are expanded and
set. Referring now to Figs. 1F, 1G and 1H, hydraulic pressure is exerted
through the bore 74 of the control valve 72 (as will be more fully
explained hereinafter through a pump out plug) and hydraulic fluid is
exerted through ports 94 (Fig. 1G) between seals 96 (1G) and 98 (1F) to
move element 100 downwardly which (1) moves the protective sleeve 81
downwardly away from the lip 80 of the cup seal 78 and wedges the slips
82 outwardly against the inside wall of the well conduit 79. This sets the
CA 02222194 2000-08-23
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slips 82 which are then held in a set position by ratchet 102 on the
member 100 acting against ratchet teeth 104 on the housing 76.
The annular control valve 72 includes mechanically actuated
releasing means for releasing the control valve 72 from the inside of the
well conduit ?4. Referring to Figs. 1H and lI, the interior housing 76 of
the valve 72 is connected through dogs 106 to the coiled tubing 34. A
sleeve 108 which holds the dogs 106 in place is connected to the coiled
tubing 34 by shear pins 110. The sleeve 108 includes an upwardly facing
shoulder 112 which, when jarred by a suitable tool, shears the pins 110,
moves the sleeve 108 downwardly, and releases the dogs for allowing the
control valve 78 to be lifted and the slips 82 retracted.
Referring now to Figs. 1J, a longitudinally flexible gas lift valve 120
is shown connected in the coiled tubing 34. In the completion system 10,
normally a plurality of such gas lift valves may be provided.
The gas lift valve 120 has an outside diameter equal to the
outside diameter of the coiled tubing 34, and includes a bore 1~2 for
passage of wireline tools and is longitudinally flexible. Generally, the gas
lift valve 120 includes a housing 124 which includes one or more ports 126
for the admission of gas in the annulus outside of the 'housing 12 which
is injected into the bore 122 for lifting fluids therein. The valve 120 is
normally biased to a closed position by a gas charged compartment 128
acting on one or more bellows 130 and 132. The gas compartment 128 is
charged through a dill valve 1R4. A movable ball 136 and a seat 138 are
provided in the housing 124 in communication with the port 126. The gas
charged compartment 128 acts to seat the ball 136 on the seat 138 by
being connected to a valve element extension 140. For opening the valve
120, lifting gas is injected into the port 126, lifts the ball element 136 and
allows the gas to pass into the bore 122.
CA 02222194 1997-12-09
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Referring now to Figs. 1K, 1L, 1M, 1N and 10, a zone or isolation
packer 150 is shown. The packer 150 is shown in the set position in Figs.
1K-10. The packer 150 is shown in its spooled and retracted position in
Figs. 9A-9D. The packer 150 includes a housing 152 connected to the
inside of the coiled tubing 34 in which the coiled tubing forms part of the
housing for the packer 150. As best seen in Figs. 9A-9D, the packer 150
in its retracted position has an outside diameter equal to the outside
diameter of the coiled tubing 34 and thus does not create any upsets. The
packer 150 also includes a bore 154 where passage of wireline tools. The
packer 150 includes conventional seal means 156 which may be a
conventional wire mesh and resilient seal and also includes slip means
158. The seal means 156 and slip means 158 are adapted to expand and
engage against the inside of the well conduit 79. Preferably, the seal
means 156 includes a thin brekable protective coating 157 such as a heat
shrinkable plastic such as one sold under the trademark "Teflon". And
the slips 158 include a thin breakable protective coating 159 such as room
temperature vulcanized rubber. The coatings 157 and 159 are to protect
the seal 156 and the slips 158 as they are moved into the well and also
protect any seals in the system 12. Thereafter, the protective coat~gs 157
and 159 will be broken when the seal means 156 and the slip means 158
are expanded into a set position.
The packer 150 is a hydraulic set straight pull release packer. The
packer 150 is set by pressuring up hydraulic fluid in the bore 154 and
applying this pressurizing fluid through ports 160 in Fig. 1N which act
between piston seals 162 (Fig. 10) and seal 164 (Fig. 1M). This causes
movement of the wedges 166 for extending the slips 158 into engagement
with the well conduit 79 and thereafter compressing the seal means 156
into the set position of Fig. 1L. The seal means 156 and the slip means
158 are held in the set position by a ratchet 166 coacting with ratchet
teeth 168. As shown in Figs. 9A-9D, the packer 150 is longitudinally
flexible for allowing bending about the longitudinal axis of the well packer
CA 02222194 1997-12-09
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150 for allowing the packer 150 to be spooled on a coiled tubing reel. The
piston seals 162 and 164 form pistons movable in their respective
cylinders between the seal means 156 and the slip means 158 and are
longitudinally flexible for assisting in bending of the packer 150. The
packer 150 includes shear pins 170 (Fig. 1K) for releasing the seal means
156 and the slip means 158 on an upward pull of the coiled tubing 34
when it is desired to pull the completion system 10 from the well conduit
79.
Referring now to Fig. 1P, the reference numeral 180 refers to a
longitudinally flexible landing nipple positioned in the coiled tubing 34
and having a bore 182 therein for the passage of wireline tools. The
landing nipple 180 is shown in a spoolable position in Fig. 11 for storage
on a coiled tubing reel. The landing nipple 180 includes first 184 and
second 186 separate and spaced tubular members each having a bore
extending therethrough for the passage of the wireline tools. The
members 184 and 186 are secured to the inside of the coiled tubing 34,
such as by welding, and therefore the members 184 and 186 along with a
section of the coiled tubing 34 form a housing for the nipple 180.
Therefore, the exterior of the landing nipple 180 is flush with the_-Boiled
tubing 34. The part 184 may include a no-go shoulder 187 and a locking
recess 188 and the second part 186 may include a polished bore 190.
Thus, the interior of the landing nipple 180 is similar to that of a
conventional D nipple of Camco International Inc. However, by providing
separate members 184 and 186 the landing nipple 180 may be made
longitudinally flexible and in addition the members 184 and 186 may be
separated from each other by variable lengths to accommodate various
types of other well tools. In addition, a flexible boot 192 is positioned
between each of the members 184 and 186 and the inside of the coiled
tubing 34 for providing flexibility and provide barriers at each end of the
members 184 and 186 for preventing wireline tool hangups.
CA 02222194 1997-12-09
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Referring now to Fig. 1Q, a spoolable longitudinally flexible sliding
sleeve 200 is best seen positioned in the coiled tubing 34 and having a
bore 202 therein for the passage of wireline tools. The sliding sleeve 200
has a housing including a portion of the coiled tubing 34, a first end 204,
and a second end 206 connected to the coiled tubing 34. The housing
includes one or more ports 208 for communicating fluid between the
outside and the inside of the housing. The sliding sleeve 200 is shown in
the spooled and flexed position in Fig. 12.
A sliding tubular member 210 is telescopically movable in the
housing for opening and closing the ports 208. The ends 204 and 206 are
positioned on opposite ends of the tubular member 210. A flexible boot
212 and 214 is positioned between each of the ends 204 and 206,
respectively, and the inside of the coiled tubing 34 whereby the sliding
sleeve 200 is longitudinally flexible for allowing the sliding sleeve 200 to
be spooled on a coiled tubing reel.
Referring now to Figs. 1R, 1S and 1T, a production packer 220 is
illustrated in the set position and is shown in the set position in Figs. 10A,
lOB and lOC. The production packer 220 includes a bore 222
therethrough for the passage of wireline tools and the packer,-In the
retracted position, as best seen in Figs. 10A, lOC includes an outside
diameter flush with the outside diameter of the coiled tubing 34. While
the packer 220 is positioned in the coiled tubing 34, it is connected
adjacent the lower end of the completion system 10 and therefore is not
required to be longitudinally flexible when the completion system 10 is
rolled upon a coiled tubing reel. However, it is important that the packer
220 have a flush OD for passing through the injector head, packoff and
blowout preventer and yet have a bore size for passage of other wireline
tools. The packer 220 is similar in structure and operation to the isolation
packer 150 previously described and is hydraulically set and mechanically
released with a straight pull. Thus, the packer 220 includes packing
sealing means 224 and slips 226. The packer 220 is set by pressuring up
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fluid in the bore 222 and applying it through a port 228 to act across seals
230 and 232 to actuate the slip means 226 and the seal means 224. The
packer 220 is then held in the set position by the action of a ratchet 234
acting against teeth 236. A thin breakable protective coating 238, such as
a heat shrinkable plastic, such as sold under the trademark "Teflon", is
applied around the seal 224. And a thin breakable protective coating 240,
such as a room temperature vulcanized rubber, is applied around the slip
means 226.
Referring now to Fig. lU, a pump out plug 250 is connected to the
lower end of the coiled tubing 34 and includes a bore 252 therethrough for
the passage of wireline tools. The pump out plug 250 includes an outside
diameter substantially equal to the outside diameter of the coiled tubing
34, but the pump out plug 250 is used to pressurize the bore of the tubing
completion system 10 by dropping a ball 254 onto a removable seat 256.
In addition, the pump out plug 250 may include a no-go shoulder 258 and
a locking recess 260 for landing additional well tools therein.
Referring now to Fig. 5, another embodiment of a control line
hanger and control line housing is shown as a variation of the
embodiment illustrated in Fig. lA. Like parts to that shown in Fig. lA
are similarly numbered with the addition of the suffix "a". In Fig. lA, the
hydraulic control conduits 38 and 40 were illustrated as being within the
walls of the coiled tubing 34. However, in some installations the control
conduit or conduits may be positioned on the outside of the coiled tubing;
34a. Such an internal type hydraulic control conduit would interfere with
the operation of the retrieval system 12 which will be more fully discussed
hereinafter which grips the inside of the top 37a of the coiled tubing 34a.
Thus, a control line hanger 26a is positioned in a control line hanger
housing 27a in which one or more hydraulic control conduits, here shown
as a single hydraulic conduit 38a extends down the interior of the coiled
tubing 34a. The control line hanger 26a holds the control line 38a in
tension, such as an inverted U configuration, and the control conduit 38a
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is shown exiting the housing 27a. The hanger 26a includes a cutting
means 39 which, when actuated, such as hydraulically cuts the control
conduit 38a which is under tension, and thus conduit 38a springs back
into the interior of the coiled tubing 34a and below the top 37a. This
clears the inside of the top of the coiled tubing 34a for retrieval
operations. Additionally, the control line housing 27a includes movable
centralizing guides 42a having guide surfaces 44a for moving inwardly
against the outside of the top 37a of the coiled tubing 34a for centralizing
the coiled tubing 34a for insertion of the retrieval system 12.
Referring now to Figs. 15,16A and 16B, a system for retrieving the
spoolable completion system 10 of the present invention is best seen.
Because the tubing completion system 10 has a flush and constant outside
diameter without any upsets and is flexible and spoolable, the retrieval
system 12 is able to retrieve the tubing system 10 through the injector 20,
the blowout preventer 22 and the wellhead 24 and any other packoffs even
if the well is live without needing to pressure balance the well as the
completion system 10 is removed. The retrieval system 12 includes the
reel lfi, and a second coiled tubing 34b positioned on the reel 16 having
at its end a longitudinally actuated internal gripping connector 300 which
is longitudinally flexible and has an outside diameter equal to the outside
diameter of the coiled tubing so that it may be inserted through the
injector 20, the blowout preventer 22 and the wellhead 24 and into the
upper end 37 or 37a of the coiled tubing 34 or 34a for gripping and
removing the completion system 10 from the well. The internal connector
300 may be of the type disclosed in United States Patent No. 5,306,050, issued
April 26, 1994, entitled "Method And Apparatus For Internally Connecting To
Coiled Tubing". Generally, the connector 300, as shown in Figs. 16A and 16B,
is initially positioned, but unset, in the inside of one end of the coiled
tubing 34b
and 34, shown in dotted outline. The connector 300 includes a metal body 316
having a first end 318 and a second end 320 and a bore
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322 therethrough for the passage of fluids. The body 316 has an outside
diameter 324 of a size no greater than the outside diameter of the coiled
tubing 34b and 34. Therefore, the body 316 does not upset or protrude
past the outside diameter of the coiled tubing 34b and 34 and thus passes
freely through coiled tubing injector chains, round goosenecks, and on to
the coiled tubing reel 16. The first end 318 of the body 316 and the
second end 320 of the body 316 have an outside diameter substantially
equal to the inside diameter of the first and second coiled tubing 34b and
34, respectively.
Seal means, such as O-ring seals 326 and 328 are provided on the
first end 318 of the body 316 and also on the second end 320 of the body
316, respectively, for sealing between the first end 318 and the inside of
the first coiled tubing 34b and for sealing between the second end 320 of
the body 316 and the inside of the second coiled tubing 34, respectively.
In the preferred embodiment, the outside diameter of the metal part
of the body 316 is substantially equal to the inside diameter of the coiled
tubing 34b and 34 which allows the body 316 to be thin and flexible and
spoolable. A plastic coating 324, such as sold under the trademark "Halar
200" is bonded to the exterior of the body 316. The coating 324 -has an
outside diameter substantially equal to the outside diameter of the coiled
tubing 34b and 34.
A first mandrel 330 has a first end 332 and a second end 334 and
is provided with a bore 336 therethrough in communication with the bore
322. The first end 332 of the first mandrel 330 includes a plurality of
collet fingers 333 and coacting ratchet means on the fingers and the inside
of the first end 318 of the body 316. Thus, the collet fingers 333 include
a plurality of ratchet teeth 335 which coact with ratchet teeth 337 on the
inside of the body 316. Thus, the mandrel 330 may ratchet into the bore
322 of the body 316 but cannot longitudinally move out of the body 316.
A second mandrel 340 includes a first end 342 and a second end 344 with
a bore 346 therebetween in communication with the bore 322. The first
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end 342 of the mandrel 340 includes a plurality of collet fingers 342a.
Coacting ratchet means are provided on the outside of the fingers 342a and
on the inside of the second end 320 of the body 316. Thus, ratchet teeth
345 are provided on the exterior of the collet fingers 342a and teeth 347 on
the inside of the body 316. Preferably, the teeth 345 and 34? are coacting
threads. Therefore, the mandrels 330 and 340 may longitudinally move
towards the body 316, but are prevented from moving away from the body
316 by the coacting ratchet teeth.
First slip means 350 abuts the first end 318 of the body 316 and is
engagable with the outside of the first mandrel 330. The slip means 350
includes a plurality of outwardly directed teeth 352 which are preferably
directed towards the first end 318 of the body 312 and towards the end of
the first coiled tubing 312. A second slip means 360 is provided abutting
the second end 320 of the body 316 and is engagable with the outside of
the second mandrel 340. The slip means 360 includes a plurality of
outwardly directed teeth 362 directed towards the end 320 of the body 316
and towards the end of the coiled tubing 314. Thus, it is noted that when
the slips 350 and 352 are inserted into the coiled tubings 312 and 314,
respectively, the slip means 350 and 352 travels into the ends of t~ coiled
tubings 312 and 314, but not out of the ends of the coiled tubing 312 and
314.
Coacting wedge surfaces are provided on the inside of the first slip
means 350 and on the outside of the first mandrel 330 such as wedge
surface 354 on the slip means 350 and wedge surface 356 on the outside
of the mandrel 330. The wedge surfaces 354 and 356 wedge the first slip
means 350 into the inside of the first coiled tubing 312 when the body 316
is longitudinally pulled out of the end of the coiled tubing 312 thereby
pulling the mandrel 330 by the coacting engaging ratchet teeth 335 and
337. Similarly, second coacting wedge surfaces are provided on the inside
of the second slip means 360 and the outside of the second mandrel 340
such as wedge surface 364 on the inside of slip means 360 and wedge
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surface 366 on the outside of mandrel 340 for wedging the second slip
means 360 into the inside of the second coiled tubing 314 when the body
is longitudinally pulled out of the second coiled tubing 314.
In use, the connector 300 is made up as best seen in Figs. 16A and
16B. A longitudinal pull is exerted on the coiled tubing 34b in a direction
to withdraw the body 300 from the ends of the coiled tubing 34b and 34.
The longitudinal force is alternated to provide a compressive force to allow
the connector 300 to longitudinally ratchet together to securely grip the
insides of the coiled tubings 34b and 34. After securing the connector 300
to the coiled tubings, the spoolable completion system 10 may be removed
(after the packers 150 and 220 are unseated) and withdrawn from the
well.
The present invention, therefore, is well adapted to carry out the
objects and attain the ends and advantages mentioned as well as others
inherent therein. While a presently preferred embodiment of the
invention has been given for the purpose of disclosure, numerous changes
in the details of construction, will be readily apparent to those skilled in
the art and which are encompassed within the spirit of the invention and
the scope of the appended claims.
