U.S. patent application number 14/543420 was filed with the patent office on 2015-05-21 for apparatus and method for deploying equipment into a wellbore.
The applicant listed for this patent is Rodgers Technology, LLC. Invention is credited to Troy A. Rodgers.
Application Number | 20150136422 14/543420 |
Document ID | / |
Family ID | 53172126 |
Filed Date | 2015-05-21 |
United States Patent
Application |
20150136422 |
Kind Code |
A1 |
Rodgers; Troy A. |
May 21, 2015 |
APPARATUS AND METHOD FOR DEPLOYING EQUIPMENT INTO A WELLBORE
Abstract
A method for lubricating a downhole tool into a wellbore with a
lubricator assembly comprising a hydraulic cylinder with a cylinder
and a rod and a pressure isolation assembly connected to the bottom
of the cylinder of the hydraulic cylinder. The pressure isolation
assembly has a base, a top, a plurality of posts supporting the top
in a spaced apart relationship to the base, and a seal assembly
supported by the base and configured to seal around the rod. The
seal assembly includes a packing flange body having a flange
portion and a tubular portion formed as a one piece unit. The
flange portion extends across a portion of a lower side of the base
and the tubular portion extends through base. The rod extends
through the seal assembly of the pressure isolation assembly.
Inventors: |
Rodgers; Troy A.;
(Chickasha, OK) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Rodgers Technology, LLC |
Chickasha |
OK |
US |
|
|
Family ID: |
53172126 |
Appl. No.: |
14/543420 |
Filed: |
November 17, 2014 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61905339 |
Nov 18, 2013 |
|
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|
Current U.S.
Class: |
166/379 |
Current CPC
Class: |
E21B 33/068 20130101;
E21B 19/22 20130101 |
Class at
Publication: |
166/379 |
International
Class: |
E21B 19/08 20060101
E21B019/08; E21B 19/02 20060101 E21B019/02; E21B 15/00 20060101
E21B015/00; E21B 33/06 20060101 E21B033/06 |
Claims
1. A method for lubricating a downhole tool into a wellbore, the
method comprising: installing a blowout preventer to the top of a
wellhead, the blowout preventer includes internal rams; suspending
a lubricator assembly over the wellhead, the lubricator assembly
including a hydraulic cylinder with a cylinder and a rod and a
pressure isolation assembly connected to the bottom of the cylinder
of the hydraulic cylinder, wherein the pressure isolation assembly
has a base, a top, a plurality of posts supporting the top in a
spaced apart relationship to the base, and a seal assembly
supported by the base and configured to seal around the rod, the
seal assembly includes a packing flange body having a flange
portion and a tubular portion formed as a one piece unit, the
flange portion extending across a portion of a lower side of the
base and the tubular portion extending at least partially through
base, the rod extending through the seal assembly of the pressure
isolation assembly; assembling the downhole tool; connecting the
assembled downhole tool to the rod; securing at least one spacer
spool to the flange portion of the seal assembly of the pressure
isolation assembly to encase the assembled downhole tool;
connecting the spacer spool to the top of the blowout preventer;
equalizing the pressure in the at least one spacer spool and the
pressure in the wellbore; holding the pressure in the spacer spool
with the seal assembly; activating the hydraulic cylinder to extend
the rod and downhole tool through the blowout preventer; and
suspending the downhole tool in the blowout preventer with the
internal rams of the blowout preventer.
2. The method of claim 1, further comprising: supporting the
lubricator assembly on a trailer prior to suspending the lubricator
assembly over the wellhead; and pressure testing the assembled
downhole tool with a make-up and testing assembly supported by the
trailer.
3. The method of claim 2, further comprising assembling the
downhole tool with the make-up and testing assembly prior to
pressure testing the assembled downhole tool, wherein the make-up
and testing assembly includes a tong boom supported by the trailer
and supporting a tong trolley assembly configured to connect and
disconnect portions of the tool assembly.
4. A method for lubricating a downhole tool into a wellbore, the
method comprising: assembling a downhole tool with a make-up and
testing assembly supported by a trailer, the make-up and testing
assembly including a tong boom supported by the trailer and
supporting a tong trolley assembly configured to connect and
disconnect portions of the tool assembly. installing a blowout
preventer to the top of a wellhead, wherein the blowout preventer
includes internal rams; supporting a lubricator assembly on the
trailer in a horizontal orientation, the lubricator assembly
including a hydraulic cylinder with a cylinder and a rod and a
pressure isolation assembly connected to the bottom of the cylinder
of the hydraulic cylinder, the pressure isolation assembly has a
base, a top, a plurality of posts supporting the top in a spaced
apart relationship to the base, and a seal assembly supported by
the base and configured to seal around the rod; moving the
lubricator assembly from the horizontal orientation to a vertical
orientation with a crane supported by the trailer; suspending the
lubricator assembly over the wellhead; connecting the assembled
downhole tool to the rod; securing at least one spacer spool to the
flange portion of the seal assembly of the pressure isolation
assembly to encase the assembled downhole tool; connecting the
spacer spool to the top of the blowout preventer; equalizing the
pressure in the at least one spacer spool and the pressure in the
wellbore; holding the pressure in the spacer spool with the seal
assembly; activating the hydraulic cylinder to extend the rod and
downhole tool through the blowout preventer; and suspending the
downhole tool in the blowout preventer with the internal rams of
the blowout preventer.
5. The method of claim 4, further comprising: supporting the
lubricator assembly on a trailer prior to suspending the lubricator
assembly over the wellhead; and pressure testing the assembled
downhole tool with the make-up and testing assembly supported by
the trailer prior to connecting the assembled downhole tool to the
rod.
6. A method for lubricating a downhole tool into a wellbore, the
method comprising: assembling a downhole tool with a make-up and
testing assembly supported by a trailer, the make-up and testing
assembly including a tong boom supported by the trailer and
supporting a tong trolley assembly configured to connect and
disconnect portions of the tool assembly. installing a blowout
preventer to the top of a wellhead, wherein the blowout preventer
includes internal rams; supporting a lubricator assembly on the
trailer in a horizontal orientation, the lubricator assembly
including a hydraulic cylinder with a cylinder and a rod and a
pressure isolation assembly connected to the bottom of the cylinder
of the hydraulic cylinder, wherein the pressure isolation assembly
has a base, a top, a plurality of posts supporting the top in a
spaced apart relationship to the base, and a seal assembly
supported by the base and configured to seal around the rod, the
seal assembly includes a packing flange body having a flange
portion and a tubular portion formed as a one piece unit, the
flange portion connected to and extending across a portion of a
lower side of the base and the tubular portion extending at least
partially through base, the rod extending through the seal assembly
of the pressure isolation assembly; moving the lubricator assembly
from the horizontal orientation to a vertical orientation with a
crane supported by the trailer; suspending the lubricator assembly
over the wellhead; connecting the assembled downhole tool to the
rod; securing at least one spacer spool to the flange portion of
the seal assembly of the pressure isolation assembly to encase the
assembled downhole tool; connecting the spacer spool to the top of
the blowout preventer; equalizing the pressure in the at least one
spacer spool and the pressure in the wellbore; holding the pressure
in the spacer spool with the seal assembly; activating the
hydraulic cylinder to extend the rod and downhole tool through the
blowout preventer; and suspending the downhole tool in the blowout
preventer with the internal rams of the blowout preventer.
7. The method of claim 6, further comprising: supporting the
lubricator assembly on a trailer prior to suspending the lubricator
assembly over the wellhead; and pressure testing the assembled
downhole tool with the make-up and testing assembly supported by
the trailer prior to connecting the assembled downhole tool to the
rod.
Description
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This application claims the benefit of U.S. Provisional
Application No. 61/905,339 filed Nov. 18, 2013, which is expressly
incorporated herein by reference in its entirety.
BACKGROUND
[0002] Coiled tubing is often used to deploy downhole assembly.
Coiled tubing can be defined as any continuously-milled tubular
product manufactured in lengths that require spooling onto a
take-up reel. Although initially used primarily for well cleanout
and acid stimulation applications, coiled tubing is now used in
other applications, including well unloading, fishing, tool
conveyance, setting plus and retrieving plugs. The term "downhole
tool" or "downhole assembly" refers generally to the downhole
assembly that is deployed and used in a subterranean well.
Electrical submersible pumps, jars, motors, fishing tools, and
monitoring devices are common examples of downhole assembly.
[0003] Coiled tubing units typically include an injector head that
is suspended above the wellhead by a crane or derrick. The injector
head provides the surface drive force to run and retrieve the
coiled tubing from the well. The injector head is often used in
conjunction with a stripper and a blowout preventer. The stripper
is typically located between the injector head and the blowout
preventer and provides the primary operational seal between
pressurized wellbore fluids and the surface environment. The
blowout preventer may include one or more rams that perform various
functions, including supporting the hanging coiled tubing, sealing
around the coiled tubing and shearing the coiled tubing.
[0004] One of the drawbacks of using coiled tubing in conjunction
with downhole assembly is the process used to connect the downhole
assembly to the coiled tubing before lowering the downhole assembly
into the well. In the past, a conventional lubricator was used to
load tools before running the tools into the live well. The
lubricator is a long, high-pressure pipe that is fitted between the
top of a wellhead and the bottom of the injector head. The tools
are assembled inside the lubricator and connected to the coiled
tubing. The lubricator is then pressurized to wellbore pressure and
the assembled tools are deployed through the wellhead in the
well.
[0005] While generally effective, the prior art method of
lubricating tools into the well suffers significant drawbacks. Most
significantly, the use of a lubricator raises the injector head
high above the wellbore for the duration of the coiled tubing
operation. This requires the use of large cranes or derricks that
decrease the cost effectiveness and efficiency of the coiled tubing
deployment. Many well sites are too remote or too small to support
the use of large cranes or derricks. Furthermore, elevated injector
heads are unstable in high winds and pose an increased risk to
operators and equipment.
[0006] In light of the shortcomings of the existing art, a need
exists for an improved apparatus and method for lubricating and
injecting downhole assembly into a wellbore. The inventive concepts
disclosed herein are directed to these and other deficiencies in
the prior art.
BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS
[0007] FIG. 1 is a perspective view of a deployment assembly
constructed in accordance with the inventive concepts disclosed
herein.
[0008] FIG. 2 is a side elevational view of the deployment assembly
of FIG. 1
[0009] FIG. 3 is a top plan view of the deployment assembly of FIG.
1.
[0010] FIG. 4 is a perspective view of a portion of a lubricator
assembly.
[0011] FIG. 5 is an exploded, elevational view the portion of the
lubricator assembly illustrated in FIG. 5.
[0012] FIG. 6 is an enlarged view of FIG. 5.
[0013] FIG. 7A is a side elevational view of the lubricator
assembly.
[0014] FIG. 7B is a cross-sectional view of a pressure isolation
assembly taken along line 7B-7B of FIG. 7A.
[0015] FIG. 8 is an elevational view of the lubricator assembly
shown mounted on a wellhead.
[0016] FIG. 9 is a cross sectional view taken along line 9-9 of
FIG. 8.
DETAILED DESCRIPTION OF EXEMPLARY EMBODIMENTS
[0017] Before explaining at least one embodiment of the inventive
concepts disclosed herein in detail, it is to be understood that
the inventive concepts are not limited in their application to the
details of construction and the arrangement of the components or
steps or methodologies set forth in the following description or
illustrated in the drawings. The inventive concepts disclosed
herein are capable of other embodiments, or of being practiced or
carried out in various ways. Also, it is to be understood that the
phraseology and terminology employed herein is for the purpose of
description and should not be regarded as limiting the inventive
concepts disclosed and claimed herein in any way.
[0018] In the following detailed description of embodiments of the
inventive concepts, numerous specific details are set forth in
order to provide a more thorough understanding of the inventive
concepts. However, it will be apparent to one of ordinary skill in
the art that the inventive concepts within the instant disclosure
may be practiced without these specific details. In other
instances, well-known features have not been described in detail to
avoid unnecessarily complicating the instant disclosure.
[0019] As used herein, the terms "comprises," "comprising,"
"includes," "including," "has," "having," and any variations
thereof, are intended to cover a non-exclusive inclusion. For
example, a process, method, article, or apparatus that comprises a
list of elements is not necessarily limited to only those elements,
and may include other elements not expressly listed or inherently
present therein.
[0020] Unless expressly stated to the contrary, "or" refers to an
inclusive or and not to an exclusive or. For example, a condition A
or B is satisfied by anyone of the following: A is true (or
present) and B is false (or not present), A is false (or not
present) and B is true (or present), and both A and B is true (or
present).
[0021] In addition, use of the "a" or "an" are employed to describe
elements and components of the embodiments disclosed herein. This
is done merely for convenience and to give a general sense of the
inventive concepts. This description should be read to include one
or at least one and the singular also includes the plural unless it
is obvious that it is meant otherwise.
[0022] As used herein, qualifiers like "substantially," "about,"
"approximately," and combinations and variations thereof, are
intended to include not only the exact amount or value that they
qualify, but also some slight deviations therefrom, which may be
due to manufacturing tolerances, measurement error, wear and tear,
stresses exerted on various parts, and combinations thereof, for
example.
[0023] Finally, as used herein any reference to "one embodiment" or
"an embodiment" means that a particular element, feature,
structure, or characteristic described in connection with the
embodiment is included in at least one embodiment. The appearances
of the phrase "in one embodiment" in various places in the
specification are not necessarily all referring to the same
embodiment.
[0024] Referring now to the drawings, FIGS. 1-3 illustrate a
lubricator assembly 100 shown incorporated in a deployment assembly
10. The lubricator assembly 100 serves to lubricate and inject
downhole assemblies into a wellbore under pressure. "Downhole
assembly" refers herein generally to downhole assembly that is
deployed and used in a subterranean well. Electrical submersible
pumps, jars, motors, fishing tools, and monitoring devices are
common examples of downhole assemblies. As best illustrated in
FIGS. 8 and 9, the lubricator assembly 100 may include a hydraulic
cylinder 102, a pressure isolation assembly 104, a spool 106, and a
blowout preventer 108. The blowout preventer 108 is to be connected
to the top of a wellhead 110 (FIGS. 8 and 9).
[0025] Returning now to FIGS. 1-3, in one embodiment, the
deployment assembly 10 may include a portable trailer 12 configured
to support the lubricator assembly 100. The lubricator assembly 100
may be supported on the trailer 12 in such a way that the
lubricator assembly 100 may be positioned in a horizontal
orientation (FIGS. 2 and 3) for transport and in a vertical
position (FIG. 1) wherein the lubricator assembly 100 may be
supported by a derrick or crane (not shown) sufficient to lift and
support the lubricator assembly 100 from the trailer and position
the lubricator 100 over the wellhead 110 (shown in FIG. 8) in a
manner to be discussed in further detail below. It will be
understood, however, that the lubricator assembly 100 can
alternatively be used in offshore applications and mounted on a
boat or barge.
[0026] To assist in the assembly of the downhole assemblies, the
deployment assembly 10 may further include a make-up and testing
assembly 14 (referred to as "assembly 14" hereafter). The assembly
14 may include a tong boom 16 supported on the trailer 12 and
moveable between a horizontal transport position (FIGS. 2 and 3)
and a vertical position (FIG. 1). The tong boom 16 supports a tong
trolley assembly 18 which is configured for connecting and
disconnecting (threading and unthreading) tubular members, such as
pipe joints. The tong trolley assembly 18 is slidably supported on
the tong boom 16 so that the tong trolley assembly 18 is
selectively moveable along the tong boom 16 to a desired height.
Any suitable mechanism may be used to move the tong trolley
assembly 18 along the tong boom 16. For example, the tong boom 16
may include a cable and pulley system (not shown).
[0027] The tong trolley assembly 18 may include a power tong 20 and
at least one backup assembly 22. Any suitable power tong and back
up tong may be utilized. However, in one embodiment, the power tong
20 and backup assembly 22 may be configured as described in U.S.
61/730,266, which is hereby expressly incorporated herein by
reference.
[0028] The deployment assembly 10 may further include a dynamometer
or "dyno" 24 for measuring force, moment of force (torque), or
power of a motor (not shown) which is part of a downhole assembly
prior to inserting the downhole assembly into the wellbore. The
dyno 24 may be supported at the lower end of the tong boom 16.
[0029] The deployment assembly 10 may further include a crane 26
positioned in a way that the crane 26 may be utilized to lift and
move the various parts of a downhole assembly into a position
adjacent the tong boom 16, as needed. The deployment assembly 10
may also include at least on liquid storage tank 28 for storing a
volume of liquid. In one embodiment, the volume of liquid stored in
the liquid storage tank 28 may be used to pressure test varies
pieces of equipment, such as blowout preventer 108. The deployment
assembly 10 may also include a suitable power pack 30 which may
include a hydraulic pump 32 and a diesel engine 34 and suitable
electronics for recording data obtained from components of the
deployment assembly 10.
[0030] While the deployment assembly 10 is shown as being mounted
on a flatbed trailer 12, it is to be understood that the assembly
14 and the lubricator assembly 100 may be mounted on separate
trailers (not shown). Further, the various components may be
disassembled for transport or storage, and may be transported and
assembled at any desired location, as will be understood by persons
of ordinary skill in the art having the benefit of the instant
disclosure.
[0031] Referring now to FIG. 8, the blowout preventer 108 may be a
standard blowout preventer used in coiled tubing operations and
should be selected based on the particular requirements of specific
applications. The blowout preventer 108 may include a pair of
internal rams. The blowout preventer 108 may also include one or
more pairs of shear rams or blind rams. The blowout preventer may
also be attached to other blowout preventers.
[0032] The lubricator assembly 100 is used to insert a downhole
assembly, such as downhole assembly 138 (FIG. 9), into the
wellbore. The downhole assembly 138 may be a single component, or
alternatively made up of multiple components 138a, 138b, and 138c
that connect together to form the downhole assembly 138. It will be
understood that the downhole assembly 138 may be made up of fewer
components or more components than are shown in FIG. 9.
[0033] The spool 106 may include one or more spool segments 106a
and 106b. In the embodiment illustrated herein, the spool segment
106a may be function has an adapter between spool segment 106b and
the pressure isolation assembly 104. The spool 106 is designed to
contain the downhole assembly 138 prior to the insertion of the
downhole assembly 138 into the wellbore. The number of spool
segments depends on the length of the downhole assembly 138. Each
spool segment 106a and 106b may be a high-pressure spacer spool. In
one embodiment, the spool 106 may be 30 feet in length, and the
spool segments are installed in series.
[0034] The hydraulic cylinder 102 includes a cylinder 114 having a
bore 116, a rod 118 and a seal assembly (not shown). The hydraulic
cylinder 102 is connected to the hydraulic power pack 30 or
hydraulic pump (not shown) and, unless otherwise specified, is
structurally and functionally similar to conventional hydraulic
rams.
[0035] The rod 118 may be constructed in modular rod segments such
that additional lengths can be added or removed as needed as spool
segments are added and removed, as discussed below.
[0036] As illustrated, the hydraulic cylinder 102 may be supported
by a cage 121 to protect the hydraulic cylinder 102 and its various
components during transport, as well as the rigging up and rigging
down process.
[0037] The lubricator assembly 100 may also include a connector sub
136 (FIG. 9) that serves as a joint between the distal end of the
rod 118 and the connected downhole assembly 138. In one embodiment,
the connector sub 136 is configured as a "pup-joint" with opposing
ends capable of being secured to the pressure isolation assembly
104 and the upper end of the spool 106. The functionality of the
connector sub 136 is discussed below.
[0038] As shown in greater detail in FIGS. 5-7, the pressure
isolation assembly 104 includes a base 122, a top 124, and a series
of support posts 126. The top 124 of the pressure isolation
assembly 104 may be connected to the cylinder 114 of the hydraulic
cylinder 102. In one embodiment, the pressure isolation assembly
104 is rigidly fixed to the hydraulic cylinder 102 to facilitate
transport.
[0039] The pressure isolation assembly 104 further includes a seal
assembly 127. The seal assembly 127 is configured to seal around
the rod 118 to retain pressure inside the spool 106. The seal
assembly 127 may include a packing flange body 128, a packing
spring 129, a lower bushing 130, a series of packings 131 separated
by spacers 132, an upper bushing 133, and packing gland nut
134.
[0040] The packing flange body 128 includes a flange portion 135
and a tubular portion 136 machined as a one-piece unit. The packing
spring 129, lower bushing 130, the packings 131, and upper bushing
133 are housed in the tubular portion 136, and the packing gland
nut 134 engages the tubular portion 136 of the packing flange body
128 to affect the seal about rod 118.
[0041] The flange portion 136 is configured to extend across a
portion of a lower side of the base 122 and includes a plurality of
holes 137 for securing the packing flange body 128 between the base
122 and the top spool segment 106a with fasteners of sufficient
strength to withstand the stresses encountered when the lubricator
100 is in a horizontal position for transport. Examples of suitable
fasteners are 13/8 inch bolts (not shown). The flange portion 136
may be secured to the base 122 in any suitable fashion, such as
with fasteners or by welding. The flange portion 130 may include an
annular groove 139 for receiving a ring seal (not shown) adapted to
provide a suitable seal between the packing flange body 128 and the
top spool segment 106a. In one embodiment, the lubricator assembly
100 is used to assemble and load the downhole assembly 138 before
the downhole assembly 138 is connected to coiled tubing and
deployed in the well. The use of the lubricator assembly 100
obviates the need for a conventional lubricator under the coiled
tubing injector head. The injector head can thereby be operated
much closer to the ground with smaller equipment and with reduced
risk to person and property.
[0042] In an exemplary rig-up procedure, the blowout preventer 108
is secured to the wellhead 110. Next, the downhole assembly 138 is
assembled and placed inside the spacer spool 106. The downhole
assembly 138 may be assembled and tested using the assembly 14 and
positioned in the spool using the crane 26 or other device. Once
the downhole equipment 138 is completely assembled, the connector
sub 136 is attached to the top of the downhole equipment 138 and
the bottom of the hydraulic rod 118.
[0043] In an alternate embodiment, the hydraulic rod 118 is first
connected to the connector sub 136, which in turn, is connected to
the top component 138a within the downhole equipment 138. The next
component 138b of the downhole equipment 138 is then connected to
the top component 138a. Once the length of the downhole equipment
138 is greater than the length of the first spool segment 106a, the
downhole equipment 138 is placed in the first spool segment 106a,
and the spool segment 106a is secured to the pressure isolation
assembly 104. In this fashion, additional spacer spool segments are
added to the top spacer spool segment 106a as the length of the
downhole equipment 138 increases. To facilitate assembly, the rod
118 can be extended and retracted to provide easier access to the
downhole equipment 138.
[0044] Once the downhole assembly 138 is assembled, tested and
positioned in the spacer spool 106, the spacer spool 106 can be
secured between the blowout preventer 108 and the pressure
isolation assembly 104. Next, the spacer spool 106 is pressurized
to wellbore pressure. In one embodiment, the spacer spool 106 is
pressurized using a suitable compressed gas or fluid (e.g.,
methanol) stored on the trailer 12. Alternatively, the spacer spool
106 can be pressurized with a bypass line connected directly to the
wellbore.
[0045] When the pressure inside the spacer spool 106 is balanced
with the wellbore pressure, the operator moves a master valve on
the wellhead to full open. The hydraulic assembly 102 is then
activated to push the downhole assembly 138 through the blowout
preventer 108 and the wellhead 110 into the well. Once the
connector sub 136 reaches the blowout preventer 108, the internal
rams 112 are closed to lock the downhole assembly 138 in place. The
travel of the hydraulic rod 118 required to move the connector sub
136 through the blowout preventer 108 is measured, preferably with
a counter wheel 140 or digital encoder, and recorded.
[0046] Next, the pressure in the spacer spool 106 is released and
the spacer spool segments 106a-106b are disconnected from the
blowout preventer 108. The rod 118 is then disconnected from the
connector sub 136, and the depressurized spacer spool segments
106a-106b, pressure isolation assembly 104 and hydraulic assembly
102 are moved out of the way or rigged-down. At this point in the
operation, the wellbore pressure is retained by the blowout
preventer 108, and the downhole assembly 138 is suspended from the
connector sub 136. The connector sub 136 is captured by the
internal rams of the blowout preventer 108 with the top portion of
the connector sub 136 extending above the top of the blowout
preventer 108.
[0047] Coiled tubing (not shown) is then attached to the exposed
end of the connector sub 136 and to a coiled tubing injector head
(not shown). Any intervening components, such as additional blowout
preventers (not shown), are attached to the top of the blowout
preventer 108. Once the intervening components are brought to
wellbore pressure, the internal rams 112 are opened and the coiled
tubing injector head deploys the downhole assembly 138 into the
well. At the end of the coiled tubing operation, the coiled tubing
is retracted until the connector sub 136 is properly positioned
adjacent the internal rams 112 of the blowout preventer 108. The
internal rams 112 are closed around the connector sub 136, and the
injector head and any intervening components can be removed from
the well site. The spacer spool 106, hydraulic assembly 102 and
pressure isolation assembly 104 are then installed and pressurized
so that the downhole assembly 138 can be retracted into the spacer
spool 106 for disassembly.
[0048] Thus, the lubricator 100 provides for a hydraulically
powered lubricator that can be advantageously used to load downhole
assembly in a well in a separate operation before connecting coiled
tubing and a coiled tubing injector head. The apparatus and method
provide an efficient and safe alternative to conventional
lubricators used in combination with coiled tubing systems.
[0049] It is clear that the present invention is well adapted to
carry out is objectives and attain the ends and advantages
mentioned above as well as those inherent therein. While presently
preferred embodiments of the invention have been described in
varying detail for purposes of disclosure, it will be understood
that numerous changes may be made which will readily suggest
themselves to those skilled in the art and which are encompassed
within the spirit of the invention disclosed herein and in the
associated drawings. For example, the hydraulic assembly 102,
pressure isolation assembly 104 and blowout preventer 108 can be
cooperatively used for fishing operations that require substantial
"push-and-pull" forces.
* * * * *