U.S. patent application number 16/038453 was filed with the patent office on 2019-01-24 for open water coiled tubing sealing device.
This patent application is currently assigned to Oceaneering International, Inc.. The applicant listed for this patent is Oceaneering International, Inc.. Invention is credited to Sam Almerico, John R. Cook, Neil Crawford, Caleb Fulks.
Application Number | 20190024471 16/038453 |
Document ID | / |
Family ID | 65015328 |
Filed Date | 2019-01-24 |
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United States Patent
Application |
20190024471 |
Kind Code |
A1 |
Crawford; Neil ; et
al. |
January 24, 2019 |
Open Water Coiled Tubing Sealing Device
Abstract
Dynamic/static sealing of coiled tubing subsea for pipeline and
well access with hydrostatic conditions up to 10,000 feet water
depth while maintaining wellbore or pipeline pressures up to 10,000
psi may be achieved using a system comprising a subsea fluid source
which utilizes a riserless open water coiled tubing system and an
open water coiled tubing sealer to control hydrostatic pressure and
wellbore/pipeline pressures. This comprises an upper well control
assembly having a first geometric orientation and a lower well
control assembly in fluid communication with the upper well control
assembly aligned in a second geometric orientation substantially
inverted to the first orientation; a quick disconnect connector in
fluid communication with the upper well control assembly; one or
more electrically powered subsea assist jacks operatively connected
to the quick disconnect connector; a controller operatively in
communication with the electrically powered subsea assist jacks;
and a power connector operatively in communication with the source
of electrical power, the controller, and the electrically powered
subsea assist jack.
Inventors: |
Crawford; Neil; (The
Woodlands, TX) ; Almerico; Sam; (The Woodlands,
TX) ; Cook; John R.; (Kingwood, TX) ; Fulks;
Caleb; (McKinney, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Oceaneering International, Inc. |
Houston |
TX |
US |
|
|
Assignee: |
Oceaneering International,
Inc.
Houston
TX
|
Family ID: |
65015328 |
Appl. No.: |
16/038453 |
Filed: |
July 18, 2018 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
62534333 |
Jul 19, 2017 |
|
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 33/0355 20130101;
E21B 43/013 20130101; E21B 19/22 20130101; E21B 33/038 20130101;
E21B 33/076 20130101 |
International
Class: |
E21B 33/035 20060101
E21B033/035; E21B 33/038 20060101 E21B033/038; E21B 33/076 20060101
E21B033/076 |
Claims
1. An open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures, comprising: a. an upper
well control assembly having a first geometric orientation; b. a
lower well control assembly in fluid communication with the upper
well control assembly, the lower well control assembly comprising a
second geometric orientation substantially inverted to the first
orientation; c. a quick disconnect connector in fluid communication
with the upper well control assembly; d. an electrically powered
subsea assist jack operatively connected to the quick disconnect
connector, the electrically powered subsea assist jack comprising:
i. an electric motor; ii. a power connector operatively in
communication with the electric motor; and iii. a power convertor
operatively in communication with the electric motor; e. a
controller operatively in communication with the electrically
powered subsea assist jack; and f. a power connector operatively in
communication with the source of electrical power, the controller,
and the electrically powered subsea assist jack.
2. The open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures of claim 1, wherein the
controller further comprises: a. a feedback loop adapted to provide
data communication over the power connector; b. an electronic
sensor; and c. a position sensor operatively in communication with
the electrically powered subsea assist jack and operative to
provide feedback on a position of an internal element of the
electrically powered subsea assist jack.
3. The open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures of claim 1, wherein the
source of electrical power comprises a skid based source of
electrical power.
4. The open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures of claim 1, further
comprising a coiled tubing packer disposed intermediate the
electrically powered subsea assist jack and the quick disconnect
connector.
5. The open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures of claim 1, wherein the
upper well control assembly comprises a plurality of control
assemblies.
6. The open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures of claim 1, wherein: a.
the upper well control assembly comprises a plurality of control
assist assemblies arranged into pairs; and b. the lower well
control assembly comprises a plurality of control assist assemblies
arranged into pairs.
7. The open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures of claim 1, wherein the
upper well control assembly comprises an inverted stripper.
8. The open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures of claim 1, wherein the
upper well control assembly comprises a packer element.
9. The open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures of claim 1, wherein the
lower well control assembly comprises a stripper.
10. The open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures of claim 1, wherein the
lower well control assembly comprises a packer element.
11. The open water coiled tubing sealer to control hydrostatic
pressure and wellbore/pipeline pressures of claim 13, wherein the
packer element comprises a subsea replaceable packer.
12. A method for controlling hydrostatic pressure and
wellbore/pipeline pressures in a system that comprises a subsea
fluid source which utilizes a riserless open water coiled tubing
system, the method comprising: a. operatively connecting an open
water coiled tubing sealer to the subsea fluid source which
utilizes the riserless open water coiled tubing system and to a
source of electrical power, the open water coiled tubing sealer
comprising: i. an upper well control assembly having a first
geometric orientation; ii. a lower well control assembly in fluid
communication with the upper well control assembly, the lower well
control assembly comprising a second geometric orientation
substantially inverted to the first orientation; and iii. a quick
disconnect connector in fluid communication with the upper well
control assembly; iv. an electrically powered subsea assist jack
operatively connected to the quick disconnect connector, the
electrically powered subsea assist jack comprising: 1. an electric
motor; 2. a power connector operatively in communication with the
electric motor; and 3. a power convertor operatively in
communication with the electric motor; v. a controller operatively
in communication with the electrically powered sub sea assist jack;
and vi. a power connector operatively in communication with the
source of electrical power, the controller, and the electrically
powered subsea assist jack; b. using the upper well control
assembly and the lower well control assembly packer assembly to
pressurize a predetermined set of annular cavities existing between
the upper well control assembly and the lower well control assembly
packer assembly; c. enabling hydrostatic pressure to assist sealing
the upper well control assembly; d. using fluid pressure from the
subsea fluid source which utilizes the riserless open water coiled
tubing system to assist sealing the lower well control assembly;
and e. maintaining a predetermined amount of hydrostatic pressure
with very low well/pipeline pressure and handling the subsequent
differential pressure.
13. The method for controlling hydrostatic pressure and
wellbore/pipeline pressures in a system that comprises a subsea
fluid source which utilizes a riserless open water coiled tubing
system of claim 12, further comprising creating bi-directional
sealing elements set up in pairs.
14. The method for controlling hydrostatic pressure and
wellbore/pipeline pressures in a system that comprises a subsea
fluid source which utilizes a riserless open water coiled tubing
system of claim 12, wherein the upper well control assembly
comprises a plurality of packer assemblies with hydrostatic control
assist and the lower well assembly comprises a plurality of packer
units adapted for well control assist, the method further
comprising using hydro-cushions to pressurize the annular cavities
between the dual sets of packers.
15. The method for controlling hydrostatic pressure and
wellbore/pipeline pressures in a system that comprises a subsea
fluid source which utilizes a riserless open water coiled tubing
system of claim 12, wherein the system further comprises a subsea
fluid source, the method further comprising controlling the
pressure using pairs of sealing elements with full backup for each
system to enable the hydrostatic pressure to assist sealing the
upper pair of packers and the wellbore pressure to assist sealing
the lower pair of packers.
16. The method for controlling hydrostatic pressure and
wellbore/pipeline pressures in a system that comprises a subsea
fluid source which utilizes a riserless open water coiled tubing
system of claim 15, wherein the sealing elements comprise a
packer.
17. The method for controlling hydrostatic pressure and
wellbore/pipeline pressures in a system that comprises a subsea
fluid source which utilizes a riserless open water coiled tubing
system of claim 15, wherein the full backup comprises a duplicate
set of sealing elements, each set of sealing elements further
comprising a packer.
18. The method for controlling hydrostatic pressure and
wellbore/pipeline pressures in a system that comprises a subsea
fluid source which utilizes a riserless open water coiled tubing
system of claim 12, further comprising: a. using hydrostatic
pressure of up to a first pressure of around 4500 psi; and b. using
source fluid pressures from zero to around 10000 psi.
19. The method for controlling hydrostatic pressure and
wellbore/pipeline pressures in a system that comprises a subsea
fluid source which utilizes a riserless open water coiled tubing
system of claim 12, further comprising: a. using the electronic
sensor to provide feedback to the controller on an electrically
related parameter; and b. using the position sensor to provide
feedback to the controller on a position of an element of the
electrically powered subsea assist jack.
Description
[0001] This application claims priority through U.S. Provisional
Application 62/534,333, filed Jul. 19, 2017.
BACKGROUND
[0002] This invention relates to coiled tubing being utilized to
intervene in a pipeline or well subsea while maintaining pressure
integrity from the hydrostatic and dynamic conditions.
[0003] In a subsea environment, performing an intervention with
coiled tubing to a pipeline, or oil/gas well historically used a
semi-submersible rig or DP Monohull vessel with a riser conduit
from surface to the subsea tree or pipeline.
[0004] When utilizing a riser or flexible conduit the pressure
control equipment (BOP's and stripper assembly) are mounted at
surface to control any release of fluids or gases from the
well/pipeline during the intervention program.
[0005] However, when operating riserless utilizing Open Water
Coiled Tubing (OWCT), the well control package including the
strippers for dynamic control have to be modified to operate subsea
and control both hydrostatic and wellbore conditions
simultaneously.
[0006] Normally this equipment is hydraulically controlled to
function subsea. Method of dynamic/static sealing of coiled tubing
subsea for pipeline and well access with hydrostatic conditions up
to 10,000 ft water depth while maintaining wellbore or pipeline
pressures up to 10,000 psi. Current systems exist for surface
application only and seal coiled tubing from wellbore or pipeline
pressure with only ambient pressure at surface.
DRAWINGS
[0007] Various figures are included herein which illustrate aspects
of embodiments of the disclosed inventions.
[0008] FIG. 1 is a view in partial perspective of a first exemplary
system;
[0009] FIG. 2 is a second in partial perspective of a second
exemplary system; and
[0010] FIG. 3 is a view in partial perspective of an exemplary
system showing a fluid source.
BRIEF DESCRIPTION OF EXEMPLARY EMBODIMENTS
[0011] Referring now to FIG. 1, open water coiled tubing sealer 1,
useful to control hydrostatic pressure and wellbore/pipeline
pressures, comprises upper well control assembly 10, comprising a
first geometric orientation; lower well control assembly 20 in
fluid communication with upper well control assembly 10, where
lower well control assembly 20 comprises a second geometric
orientation substantially inverted to the first orientation; and
quick disconnect connector 30 in fluid communication with upper
well control assembly 10.
[0012] In typical embodiments, open water coiled tubing sealer 1
further comprises one or more electrically powered subsea assist
jacks 40 which are operatively connected to quick disconnect
connector 30 and a controller operatively in communication with the
electrically powered subsea assist jack. Previously this equipment
was to be hydraulically controlled (which is the industry norm).
Typically, electrically powered subsea assist jacks 40 are
controlled using three phase electric power and electric motors
with a feedback loop of electronic communication over a power
connector which may comprise or otherwise interface with umbilical
110 or the like. Thus, instead of hydraulic motors driving the jack
cylinders, these would be replaced with electric motors utilizing a
power convertor operatively in communication with the power
connector to handle the speed and direction through a main
umbilical, such as umbilical 110, to subsea fluid source 100 which
may be part of a subsea control skid.
[0013] The same thing could be done with one or more slip bowls,
i.e. electric motors could replace hydraulic motors to activate and
de-activate the slips. One or more electronic sensors, which can
comprise proximity switches or similar equipment, can be utilized
to provide feedback for control such as for closing and opening the
slip bowls along with one or more position sensors to provide
feedback on the position of the cylinders/roller bearing screw
jacks, e.g. electrically powered subsea assist jacks 40, which are
operatively connected to the electric motors.
[0014] Power and communication may be achieved through umbilical
120 to intervention system 200.
[0015] In certain embodiments open water coiled tubing sealer 1
further comprises one or more coiled tubing packers 50 disposed
intermediate electrically powered subsea assist jacks 40 and quick
disconnect connector 30.
[0016] Typically, upper well control assembly 10 comprises a
plurality of control assemblies 12. Similarly, lower well control
assembly 20 may also comprise a plurality of control assemblies 22
which may be the same as or similar to control assemblies 12. Where
upper well control assembly 10 comprises the plurality of control
assist assemblies 12, these may be arranged into pairs, which may
be arranged redundantly and/or cooperatively or the like.
Similarly, where lower well control assembly 20 comprises the
plurality of control assist assemblies 22, these may also be
arranged into pairs, which may be arranged redundantly and/or
cooperatively or the like.
[0017] Upper well control assembly 10 may further comprise one or
more inverted strippers 14. Upper well control assembly 10 may also
further comprise one or more packer elements 16. Such packer
elements 16 may be other otherwise comprise a subsea replaceable
packer.
[0018] As illustrated in FIGS. 1 and 2, quick disconnect connector
30 may be located intermediate strippers 14 and upper well control
assembly 10 and a second quick disconnect connector, quick
disconnect connector 31 (FIG. 2) may be optionally present and
located intermediate electrically powered subsea assist jacks 40
and strippers 14.
[0019] Similarly, lower well control assembly 20 may comprise one
or more strippers 24. As with upper well control assembly 10, lower
well control assembly 20 may also further comprise one or more
packer elements 26 which may be other otherwise comprise a subsea
replaceable packer.
[0020] In the operation of exemplary embodiments, hydrostatic
pressure and wellbore/pipeline pressures may be controlled in a
system that comprises subsea fluid source 100 which utilizes
riserless open water coiled tubing system 1. In general, the method
comprises operatively connecting open water coiled tubing sealer 1,
as described above, to subsea fluid source 100 and an electrical
power source and using upper well control assembly 10 and lower
well control assembly 20 to pressurize a predetermined set of
annular cavities existing between upper well control assembly 10
and lower well control assembly packer assembly 20. Hydrostatic
pressure is then enabled to assist sealing upper well control
assembly 10. Fluid pressure from subsea fluid source 100 may be
used to assist sealing lower well control assembly 10. A
predetermined amount of hydrostatic pressure may then be maintained
with very low well/pipeline pressure and handling the subsequent
differential pressure.
[0021] Hydrostatic pressure of up to a first pressure of around
4500 psi may be used. Further, source fluid pressures from zero to
around 10000 psi may be used.
[0022] One or more pairs of bi-directional sealing elements may be
set up in pairs as described above.
[0023] Where upper well control assembly 10 comprises a plurality
of packer assemblies 16 with hydrostatic control assist and lower
well assembly 20 comprises a plurality of packer units 25 which are
adapted for assisting well control, the method further comprising
using hydro-cushions to pressurize the annular cavities between the
dual sets of packers.
[0024] Where the system further comprises subsea fluid source 100
such as a monoethylene glycol (MEG) fluid source or the like, the
method may further comprise controlling the pressure using pairs of
sealing elements with full backup for each system to enable the
hydrostatic pressure to assist sealing the upper pair of packers
and the wellbore pressure to assist sealing the lower pair of
packers. In embodiments, full backup comprises using a duplicate
set of sealing elements, each set of sealing elements further
comprising one or more packers 16,26.
[0025] In embodiments, packers 16,26 may be replaced subsea,
thereby allowing continuous operations without pulling open water
coiled tubing sealer 1 back to surface to replace the packers.
[0026] It is noted that although various arrangements can be used,
the basic arrangement is a first stripper/packer arranged in a
first position relative to fluid flow and a second stripper/packer,
essentially the same or similar to the first stripper/packer,
fluidly coupled to the first stripper/packer but inverted with
respect the first stripper/packer alignment. This can entail a
plurality of each such stripper/packer units, e.g. two first
stripper/packer assemblies with hydrostatic control assist and one
or more second stripper/packer units for well control assist with
hydro-cushions to pressurize the annular cavities between the dual
sets of packers. By doing this, hydrostatic pressure is enabled to
assist sealing the upper stripper/packers and the wellbore pressure
to assist sealing the lower stripper/packers. It has been found
that adding additional stages as described herein, splitting them
into pairs, and then inverting one pair from the other so using
ambient and well pressure to energize and seal.
[0027] As opposed to current systems for only surface application
and seal coiled tubing from wellbore or pipeline pressure with only
ambient pressure at surface, using the methods described above,
dynamic/static sealing of coiled tubing subsea, such as for
pipeline and well access, may be accomplished with hydrostatic
conditions of up to around 10,000 ft water depth while maintaining
wellbore or pipeline pressures up to around 10,000 psi.
[0028] The foregoing disclosure and description of the inventions
are illustrative and explanatory. Various changes in the size,
shape, and materials, as well as in the details of the illustrative
construction and/or an illustrative method may be made without
departing from the spirit of the invention.
* * * * *