U.S. patent application number 16/573193 was filed with the patent office on 2021-01-14 for hybrid coiled tubing system.
This patent application is currently assigned to Halliburton Energy Services, Inc.. The applicant listed for this patent is Halliburton Energy Services, Inc.. Invention is credited to Scott Robert Greig, Anna Savenkova, Iain James Shepherd.
Application Number | 20210010346 16/573193 |
Document ID | / |
Family ID | 1000004360252 |
Filed Date | 2021-01-14 |
United States Patent
Application |
20210010346 |
Kind Code |
A1 |
Greig; Scott Robert ; et
al. |
January 14, 2021 |
Hybrid Coiled Tubing System
Abstract
A hybrid coiled tubing system. The hybrid coiled tubing system
may include composite coiled tubing, metallic coiled tubing, and a
composite coiled tubing connector coupled to and joining the
composite coiled tubing and the metallic coiled tubing.
Inventors: |
Greig; Scott Robert;
(Aberdeen, SC) ; Shepherd; Iain James; (Aberdeen,
SC) ; Savenkova; Anna; (Aberdeen, SC) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Halliburton Energy Services, Inc. |
Houston |
TX |
US |
|
|
Assignee: |
Halliburton Energy Services,
Inc.
Houston
TX
|
Family ID: |
1000004360252 |
Appl. No.: |
16/573193 |
Filed: |
September 17, 2019 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
62873254 |
Jul 12, 2019 |
|
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|
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 37/00 20130101;
E21B 17/00 20130101; E21B 2200/05 20200501; E21B 2200/06 20200501;
E21B 19/22 20130101; E21B 34/06 20130101; E21B 2200/04
20200501 |
International
Class: |
E21B 34/06 20060101
E21B034/06; E21B 19/22 20060101 E21B019/22; E21B 37/00 20060101
E21B037/00 |
Claims
1. A hybrid coiled tubing system comprising: composite coiled
tubing; metallic coiled tubing; and a composite coiled tubing
connector coupled to and joining the composite coiled tubing and
the metallic coiled tubing.
2. The hybrid coiled tubing system of claim 1, wherein a valve is
coupled to and positioned between the composite coiled tubing
connector and the metallic coiled tubing to control flow between
the composite coiled tubing and the metallic coiled tubing.
3. The hybrid coiled tubing system of claim 1, wherein a valve is
coupled to and positioned between the composite coiled tubing
connector and the composite coiled tubing to control flow between
the composite coiled tubing and the metallic coiled tubing.
4. The hybrid coiled tubing system of claim 1, further comprising
at least one of piping, composite coiled tubing, or metallic coiled
tubing that is joined to the composite coiled tubing via a second
connector.
5. The hybrid coiled tubing system of claim 1, further comprising
at least one of piping, composite coiled tubing, or metallic coiled
tubing that is joined to the metallic coiled tubing via a second
connector.
6. The hybrid coiled tubing system of claim 5, wherein the piping
is composite piping.
7. The hybrid coiled tubing system of claim 5, wherein the piping
is steel piping.
8. A hybrid coiled tubing system comprising: composite coiled
tubing; piping; and a composite coiled tubing connector coupled to
and joining the composite coiled tubing and the piping.
9. The hybrid coiled tubing system of claim 8, wherein a valve is
coupled to and positioned between the connector and the composite
coiled tubing to control flow between the composite coiled tubing
and the piping.
10. The hybrid coiled tubing system of claim 8, wherein a valve is
coupled to and positioned between the connector and the piping to
control flow between the composite coiled tubing and the
piping.
11. The hybrid coiled tubing system of claim 8, wherein the piping
comprises composite piping.
12. The hybrid coiled tubing system of claim 8, wherein the piping
comprises steel piping.
13. The hybrid coiled tubing system of claim 8, further comprising
at least one of piping, composite coiled tubing, or metallic coiled
tubing that is joined to the composite coiled tubing via a second
connector.
14. The hybrid coiled tubing system of claim 8, further comprising
at least one of piping, composite coiled tubing, or metallic coiled
tubing that is joined to the piping via a second connector.
15. A method of performing borehole servicing operations at a job
site, the method comprising: running a tool string comprising a
hybrid coiled tubing system into a borehole, the hybrid coiled
tubing system comprising composite coiled tubing, either piping or
metallic coiled tubing, and a composite coiled tubing connector
coupled to and joining the composite piping and the at least one of
the piping and the metallic coiled tubing; and performing servicing
operations within the borehole.
16. The method of claim 15, wherein a valve is coupled to and
positioned between the connector and the composite coiled tubing to
control flow between the composite coiled tubing and the at least
one of the piping and the metallic coiled tubing.
17. The method of claim 15, wherein a valve is coupled to and
positioned between the connector and the piping or the metallic
coiled tubing to control flow between the composite coiled tubing
and the at least one of the piping and the metallic coiled
tubing.
18. The method of claim 15, wherein running the tool string
comprising the hybrid coiled tubing system into the borehole
comprises unspooling the hybrid coiled tubing system from a
reel.
19. The method of claim 15, wherein running the tool string
comprising the hybrid coiled tubing system into the borehole
comprises connecting the composite coiled tubing to the piping or
the metallic coiled tubing via a connector to make up the hybrid
coiled tubing system at the job site.
20. The method of claim 15, wherein performing the servicing
operations within the borehole comprises removing blockages and
restrictions from within the borehole.
Description
BACKGROUND
[0001] Coiled tubing generally refers to continuous, small-diameter
cylindrical tubing that is sufficiently flexible to be coiled onto
a reel, for use in oil and gas service operations. Coiled tubing
can be mounted on a truck or other support structure, such as a
reel, for transporting to a work site. Coiled tubing may be used in
a variety of oil and gas service operations, such as well or
pipeline servicing operations, including drilling, completion,
stimulation, cleaning, workover, well intervention, and other
operations.
[0002] Coiled tubing may be used, for example, to inject or
circulate gas or other fluids into the borehole or pipeline, to
transport tools downhole (such as logging tools), to perform
remedial cementing, clean-out, or circulation operations in the
bore, to deliver and operate drilling and milling tools downhole,
for electric wireline logging and perforating, fishing, setting and
retrieving tools, for displacing fluids, and for transmitting
hydraulic power into the borehole. The flexible, lightweight nature
of coiled tubing makes it particularly useful in deviated
boreholes, flowlines, pipelines and risers.
BRIEF DESCRIPTION OF THE DRAWINGS
[0003] Embodiments of the hybrid coiled tubing system are described
with reference to the following figures. The same numbers are used
throughout the figures to reference like features and components.
The features depicted in the figures are not necessarily shown to
scale. Certain features of the embodiments may be shown exaggerated
in scale or in somewhat schematic form, and some details of
elements may not be shown in the interest of clarity and
conciseness.
[0004] FIG. 1 is a well system, according to one or more
embodiments;
[0005] FIG. 2 is a cross-sectional view of a hybrid coiled tubing
system, according to one or more embodiments; and
[0006] FIG. 3 is a cross-sectional view of a hybrid coiled tubing
system, according to one or more embodiments.
DETAILED DESCRIPTION
[0007] The present disclosure provides a hybrid coiled tubing
system. The hybrid coiled tubing system includes composite coiled
tubing and at least one of metallic coiled tubing or piping. The
hybrid coiled tubing system is used when performing servicing
operations on wells, flowlines, pipelines, or risers. The
combination of composite coiled tubing and either metallic coiled
tubing or piping allows for increased flexibility when compared to
fully a metallic coiled tubing system and an increased load and
torque rating when compared to a fully composite coiled tubing
system.
[0008] A subterranean formation containing oil or gas hydrocarbons
may be referred to as a reservoir, in which a reservoir may be
located on-shore or off-shore. Reservoirs are typically located in
the range of a few hundred feet (shallow reservoirs) to tens of
thousands of feet (ultra-deep reservoirs). To produce oil, gas, or
other fluids from the reservoir, a well is drilled into a reservoir
or adjacent to a reservoir.
[0009] A well can include, without limitation, an oil, gas, or
water production well, or an injection well. As used herein, a
"well" includes at least one borehole having a borehole wall. A
borehole can include vertical, inclined, and horizontal portions,
and it can be straight, curved, or branched. As used herein, the
term "borehole" includes any cased, and any uncased, open-hole
portion of the borehole. Further, the term "uphole" refers a
direction that is towards the surface of the well, while the term
"downhole" refers a direction that is away from the surface of the
well.
[0010] As used herein, the term piping refers to tubular conduct
that is supplied in short lengths (typically 40 feet or less). The
term tubing, as used herein, refers to tubular conduit that is
supplied in long lengths (typically more than 100 feet) and that is
stored and deployed from a reel.
[0011] FIG. 1 is a well system 100, according to one or more
embodiments. The exemplary well system 100 is utilized to produce
hydrocarbons from borehole 102 extending through various earth
strata in an oil and gas formation 104 located below the earth's
surface 106. The borehole 102 may be formed of a single or multiple
bores extending into the formation 104, and disposed in any
orientation.
[0012] The well system 100 utilizes a hybrid coiled tubing system
108, as described in more detail below, to conduct various
drilling, production, and well intervention operations. The hybrid
coiled tubing system includes composite coiled tubing and at least
one of metallic coiled tubing or piping. The hybrid coiled tubing
system 108 is stored on one or more reels 110 positioned near a
wellhead 112. A tube guide 114 guides the coiled tubing of the
hybrid coiled tubing system 108 into an injector 116 supported on a
frame assembly 118 and positioned above the wellhead 112. The tube
guide 114 is used to feed and direct the coiled tubing of the
hybrid coiled tubing system 108 into and out of the borehole 102.
The injector 116 and the frame assembly 118 may be suspended by a
conventional derrick (not shown), a support frame (not shown), or a
crane 120.
[0013] The coiled tubing of the hybrid coiled tubing system 108
extends through a blowout preventer (BOP) stack 122 connected to
the wellhead 112 for pressure control of the borehole 102. The BOP
stack 112 may include one or more BOPs. Positioned atop the BOP
stack 122 is a lubricator mechanism or one or more stuffing boxes
124, which provides the primary operational seal about the outer
diameter of the coiled tubing of the hybrid coiled tubing system
108 for the retention of any pressure that may be present at or
near the surface of the borehole 102. Although a land-based well
system 100 is depicted in FIG. 1, the hybrid coiled tubing system
108 can be deployed from floating rigs, jackups, platforms, subsea
wellheads, or any other well location. Additionally, the hybrid
coiled tubing system 108 can be deployed for use on a pipeline.
[0014] A working or service fluid source 126, such as a storage
tank or vessel, may supply a working fluid to the hybrid coiled
tubing system 108. In particular, the fluid source 126 is in fluid
communication with a fluid swivel 128 secured to reel 110 and in
fluid communication with the interior of hybrid coiled tubing
system 108. The fluid source 126 may supply any fluid utilized in
well operations including, without limitation, drilling fluid,
cement slurry, acidizing fluid, liquid water, steam, nitrogen, or
some other type of fluid.
[0015] Various examples of fluids that may be provided by fluid
source 126 and employed in the drilling, production, and well
intervention operation described herein include air, water, oil,
lubricant, friction reducer, natural gas, mist, foam, surfactant,
nitrogen, various gases, drilling mud, acid, etc., or any
combination thereof, which are flowed through the hybrid coiled
tubing system 108 during a downhole operation. Moreover, the fluid
source 126 may be in fluid communication with a pump (not shown)
that pressurizes the working fluid at a select pressure, such as
during high pressure pumping operation. The fluid source 126 may
likewise be in communication with other surface equipment, such as
mixers, blenders and the like, utilized to prepare fluids for
pumping downhole via the fluid source 126. In at least one
embodiment, the fluid source 126 and/or surface equipment may be
adjustable in real time responsive to communications during various
well operations.
[0016] The well system 100 may also include a power supply 130 and
a communications hub 132 for sending signals and/or power and
otherwise controlling the well operations via electric and/or optic
cable deployed within the hybrid coiled tubing system 108.
[0017] The well system 100 may include one or more casing strings
134 that may be cemented in borehole 102, such as the surface,
intermediate and production casings 134 shown in FIG. 1. An annulus
136 is formed between the walls of sets of adjacent tubular
components, such as concentric casing strings 134 or the exterior
of the hybrid coiled tubing system 108 and the inside wall 138 of
borehole 102 or the casing string 134, as the case may be.
[0018] A bottom hole assembly (BHA) 140 may be suspended from the
hybrid coiled tubing system 108. The well system 100 passes a fluid
down the flowbore of the hybrid coiled tubing system 108 to the BHA
140. The return fluid will then pass up the annulus 136 formed
between the hybrid coiled tubing system 108 and the casing string
134, completion string, or the borehole wall 138 if uncased. Fluids
may also be pumped down the annulus 136 and return through the flow
bore of the hybrid coiled tubing system 108. Fluids, cuttings and
other debris returning to surface 106 from borehole 102 are
directed by a flow line 142 to storage tanks 144 (or the fluid
source 126) and/or processing systems 146, such as shakers,
centrifuges and the like.
[0019] FIG. 2 is a cross-sectional view of a hybrid coiled tubing
system 200, according to one or more embodiments. The hybrid coiled
tubing system 200 includes composite coiled tubing 202, a connector
204, a safety valve 206, and piping 208. In some embodiments, the
piping 208 may be metallic piping, such as steel piping. In other
embodiments, the piping 208 may be a composite, plastic, or other
material suitable for use in a pipeline or borehole. The composite
coiled tubing 202 may be made of glass fiber, carbon fiber, or
other composite materials known to one skilled in the art.
[0020] As shown in FIG. 2, the safety valve 206 may be positioned
between the connector 204 and the piping 208. In other embodiments,
the safety valve 206 may be positioned between the composite coiled
tubing 202 and the connector 204, or safety valves 206 may be
positioned on both sides of the connector 204. Additionally, the
connector 204 may be made up of one or more components as necessary
to transition between the composite coiled tubing 202 and the
safety valve 206.
[0021] In at least one embodiment, the connection between the
connector 204 and the composite coiled tubing 202 is a swaged
connection, where the composite coiled tubing 202 is inserted into
the connector 204. In other embodiments, the connection between the
connector 204 and the composite coiled tubing may be a threaded
connection. When using a threaded connection, the male thread may
be cut into either the composite coiled tubing 202 or the connector
204. Additionally, the connection between the connector 204 and the
safety valve 206 may be a threaded connection, a welded connection,
or a flanged connection. Similarly the connection between the
safety valve 206 and the piping 208 may be a threaded connection, a
welded connection, or a flanged connection.
[0022] The safety valve 206 may be a sleeve valve, flapper valve,
ball valve, or any other type of valve known to one skilled in the
art that is actuated remotely from the surface via hydraulics,
pneumatics, or an electromechanical actuator to control flow
between the composite coiled tubing 202 and the piping 208. In
other embodiments, the safety valve 206 may be actuated
automatically once a preset pressure value is reached or if a
specific fluid passes through the safety valve 206.
[0023] The composite coiled tubing system 200 may also include
additional valves (not shown) positioned along composite coiled
tubing 202 opposite the connector 204 and/or positioned along the
piping 208. In other embodiments, the safety valve 206 may be
omitted and the connector 204 is directly coupled to both the
composite coiled tubing 202 and the piping 208. In such
embodiments, the connector 204 and the piping 208 are connected via
welding, a threaded connection, or a flanged connection.
Additionally, some embodiments may include additional connectors
(not shown) that connect the composite coiled tubing 202 to an
additional section of tubing or piping (not shown), or that connect
the piping 208 to an additional section of tubing or piping (not
shown).
[0024] As discussed above, the composite coiled tubing system 200
may be spoolable on a reel, as shown in FIG. 1. Such a
configuration allows the composite coiled tubing system 200 to be
made up offsite and transported to a job site for use. In other
embodiments, the piping, safety valve, and/or connector are not
spoolable and the composite coiled tubing system 200 must be made
up at a job site.
[0025] FIG. 3 is a cross-sectional view of a hybrid coiled tubing
system 300, according to one or more embodiments. The hybrid coiled
tubing system 300 includes composite coiled tubing 302, a connector
304, a safety valve 306, and metallic coiled tubing 308. Similar to
the composite coiled tubing system 200 discussed above, the
composite coiled tubing 302 may be made of glass fiber, carbon
fiber, or other composite materials known to one skilled in the
art. The metallic coiled tubing 308 may be made of steel or another
metal suitable for use in a pipeline or borehole.
[0026] As shown in FIG. 3, the safety valve 306 may be positioned
between the connector 304 and the metallic coiled tubing 308. In
other embodiments, the safety valve 306 may be positioned between
the composite coiled tubing 302 and the connector 304, or safety
valves 306 may be positioned on both sides of the connector 304.
Additionally, the connector 304 may be made up of one or more
components as necessary to transition between the composite coiled
tubing 302 and the safety valve 306. The connections between the
composite coiled tubing 302, connector 304, and safety valve 306
are similar to those described above with reference to FIG. 2.
However, the connection between the safety valve 308 and the
metallic coiled tubing may be a swaged, threaded, welded, or
flanged connection.
[0027] As discussed above, the safety valve 306 may be a sleeve
valve, flapper valve, ball valve, or any other type of valve known
to one skilled in the art that is actuated remotely from the
surface to control flow between the composite coiled tubing 302 and
the piping 308. In other embodiments, the safety valve 306 may be
actuated automatically once a preset pressure value is reached or
if a specific fluid passes through the safety valve 306.
[0028] The composite coiled tubing system 300 may also include
additional valves (not shown) positioned along composite coiled
tubing 302 opposite the connector 304 and/or positioned along the
metallic coiled tubing 308. In other embodiments, the safety valve
306 may be omitted and the connector is directly coupled to both
the composite coiled tubing 302 and the metallic coiled tubing 308.
In such embodiments, the connector 304 and the piping 208 metallic
coiled tubing are connected via welding, a swaged connection, a
threaded connection, or a flanged connection. Additionally, some
embodiments may include additional connectors (not shown) that
connect the composite coiled tubing 302 to an additional section of
tubing or piping (not shown), or that connect the metallic coiled
tubing 308 to an additional section of tubing or piping (not
shown).
[0029] Similar to the composite coiled tubing system 200 described
above, the composite coiled tubing system 300 may be spoolable on a
reel. In other embodiments, the piping, safety valve, and/or
connector are not spoolable and the composite coiled tubing system
300 must be made up at the job site.
[0030] Further examples include:
[0031] Example 1 is a hybrid coiled tubing system that includes
composite coiled tubing, metallic coiled tubing, and a composite
coiled tubing connector coupled to and joining the composite coiled
tubing and the metallic coiled tubing.
[0032] In Example 2, the embodiments of any preceding paragraph or
combination thereof further include wherein a valve is coupled to
and positioned between the composite coiled tubing connector and
the metallic coiled tubing to control flow between the composite
coiled tubing and the metallic coiled tubing.
[0033] In Example 3, the embodiments of any preceding paragraph or
combination thereof further include wherein a valve is coupled to
and positioned between the composite coiled tubing connector and
the composite coiled tubing to control flow between the composite
coiled tubing and the metallic coiled tubing.
[0034] In Example 4, the embodiments of any preceding paragraph or
combination thereof further include at least one of piping,
composite coiled tubing, or metallic coiled tubing that is joined
to the composite coiled tubing via a second connector.
[0035] In Example 5, the embodiments of any preceding paragraph or
combination thereof further include at least one of piping,
composite coiled tubing, or metallic coiled tubing that is joined
to the metallic coiled tubing via a second connector.
[0036] In Example 6, the embodiments of any preceding paragraph or
combination thereof further include wherein the piping is composite
piping.
[0037] In Example 7, the embodiments of any preceding paragraph or
combination thereof further include wherein the piping is steel
piping.
[0038] Example 8 is a hybrid coiled tubing system that includes
composite coiled tubing, piping, and a composite coiled tubing
connector coupled to and joining the composite coiled tubing and
the piping.
[0039] In Example 9, the embodiments of any preceding paragraph or
combination thereof further include wherein a valve is coupled to
and positioned between the connector and the composite coiled
tubing to control flow between the composite coiled tubing and the
piping.
[0040] In Example 10, the embodiments of any preceding paragraph or
combination thereof further include wherein a valve is coupled to
and positioned between the connector and the piping to control flow
between the composite coiled tubing and the piping.
[0041] In Example 11, the embodiments of any preceding paragraph or
combination thereof further include wherein the piping includes
composite piping.
[0042] In Example 12, the embodiments of any preceding paragraph or
combination thereof further include wherein the piping includes
steel piping.
[0043] In Example 13, the embodiments of any preceding paragraph or
combination thereof further include at least one of piping,
composite coiled tubing, or metallic coiled tubing that is joined
to the composite coiled tubing via a second connector.
[0044] In Example 14, the embodiments of any preceding paragraph or
combination thereof further include at least one of piping,
composite coiled tubing, or metallic coiled tubing that is joined
to the piping via a second connector.
[0045] Example 15 is a method of performing borehole servicing
operations at a job site. The method includes running a tool string
including a hybrid coiled tubing system into a borehole, the hybrid
coiled tubing system including composite coiled tubing, either
piping or metallic coiled tubing, and a coiled tubing connector
coupled to and joining the composite piping and the at least one of
the piping and the metallic coiled tubing. The method also includes
performing servicing operations within the borehole.
[0046] In Example 16, the embodiments of any preceding paragraph or
combination thereof further include a valve is coupled to and
positioned between the connector and the composite coiled tubing to
control flow between the composite coiled tubing and the at least
one of the piping and the metallic coiled tubing.
[0047] In Example 17, the embodiments of any preceding paragraph or
combination thereof further include wherein a valve is coupled to
and positioned between the connector and the piping or the metallic
coiled tubing to control flow between the composite coiled tubing
and the at least one of the piping and the metallic coiled
tubing.
[0048] In Example 18, the embodiments of any preceding paragraph or
combination thereof further include wherein running the tool string
comprising the hybrid coiled tubing system into the borehole
comprises unspooling the hybrid coiled tubing system from a
reel.
[0049] In Example 19, the embodiments of any preceding paragraph or
combination thereof further include wherein running the tool string
comprising the hybrid coiled tubing system into the borehole
comprises connecting the composite coiled tubing to the piping or
the metallic coiled tubing via a connector to make up the hybrid
coiled tubing system at the job site.
[0050] In Example 20, the embodiments of any preceding paragraph or
combination thereof further include wherein performing the
servicing operations within the borehole comprises removing
blockages and restrictions from within the borehole.
[0051] Certain terms are used throughout the description and claims
to refer to particular features or components. As one skilled in
the art will appreciate, different persons may refer to the same
feature or component by different names. This document does not
intend to distinguish between components or features that differ in
name but not function.
[0052] Reference throughout this specification to "one embodiment,"
"an embodiment," "embodiments," "some embodiments," "certain
embodiments," or similar language means that a particular feature,
structure, or characteristic described in connector with the
embodiment may be included in at least one embodiment of the
present disclosure. Thus, these phrases or similar language
throughout this specification may, but do not necessarily, all
refer to the same embodiment.
[0053] The embodiments disclosed should not be interpreted, or
otherwise used, as limiting the scope of the disclosure, including
the claims. It is to be fully recognized that the different
teachings of the embodiments discussed may be employed separately
or in any suitable combination to produce desired results. In
addition, one skilled in the art will understand that the
description has broad application, and the discussion of any
embodiment is meant only to be exemplary of that embodiment, and
not intended to suggest that the scope of the disclosure, including
the claims, is limited to that embodiment.
* * * * *