U.S. patent application number 15/026756 was filed with the patent office on 2016-10-06 for smart fluid completions, isolations, and safety systems.
The applicant listed for this patent is HALLIBURTON ENERGY SERVICES, INC.. Invention is credited to Russell Stephen HAAKE, Christopher Michael MCMILLON, Robert Mitchell NEELY.
Application Number | 20160290089 15/026756 |
Document ID | / |
Family ID | 53479378 |
Filed Date | 2016-10-06 |
United States Patent
Application |
20160290089 |
Kind Code |
A1 |
MCMILLON; Christopher Michael ;
et al. |
October 6, 2016 |
SMART FLUID COMPLETIONS, ISOLATIONS, AND SAFETY SYSTEMS
Abstract
Systems and related methods are disclosed for applying
electrorheological fluids in hydro-carbon-producing environments.
The systems include a fluid-retaining member having a conductive
inner surface and a conductive outer surface. The fluid-retaining
member retains a smart fluid. The systems also include a controller
that is electrically coupled to a power source and at least one of
the conductive inner surface and conductive outer surface of the
fluid-retaining member to actuate an electric field or magnetic
field across fluid-retaining member. Actuation of the electric
field or magnetic field results in a near instantaneous increase in
the viscosity of the fluid, causing the fluid to solidify, nearly
solidify, gel or otherwise increase in viscosity. The actuated
fluid retaining member may be used as a well casing, an isolator, a
blowout inhibitor, or in a well insulation system to absorb energy
in the event of an explosion.
Inventors: |
MCMILLON; Christopher Michael;
(Wylie, TX) ; NEELY; Robert Mitchell; (Carrollton,
TX) ; HAAKE; Russell Stephen; (Dallas, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
HALLIBURTON ENERGY SERVICES, INC. |
Houston |
TX |
US |
|
|
Family ID: |
53479378 |
Appl. No.: |
15/026756 |
Filed: |
December 24, 2013 |
PCT Filed: |
December 24, 2013 |
PCT NO: |
PCT/US13/77695 |
371 Date: |
April 1, 2016 |
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 33/03 20130101;
E21B 33/12 20130101; E21B 47/06 20130101; E21B 33/10 20130101; E21B
41/0021 20130101; E21B 33/1208 20130101 |
International
Class: |
E21B 33/10 20060101
E21B033/10; E21B 33/03 20060101 E21B033/03; E21B 47/06 20060101
E21B047/06 |
Claims
1. A system for use in a wellbore, the system comprising: a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain a
smart fluid; a controller, the controller being electrically
coupled to at least one of the inner surface and outer surface of
the fluid-retaining member and operable to actuate a field between
the inner surface and outer surface of the fluid-retaining member;
a surface control subsystem communicatively coupled to the
controller and operable actuate the controller.
2. The system of claim 1, wherein the field is an electric
field.
3. The system of claim 1, wherein the field is a magnetic
field.
4. The system of claim 1, wherein the fluid-retaining member is
selected from the group consisting of a sponge, a lattice, and a
hollow cylindrical structure.
5. The system of claim 1, wherein the fluid-retaining member is
prefilled with the smart fluid.
6. The system of claim 1, further comprising a fluid delivery
system for the smart fluid to the fluid-retaining member.
7. The system of claim 1, further comprising: a smart fluid
disposed within the fluid-retaining member, the smart fluid being
operable to solidify in response to the actuation of the field; and
a pressure sensor coupled to at least one of the controller and the
surface control, the pressure sensor being operable to monitor a
pressure within the wellbore downhole from the fluid-retaining
member, wherein the fluid-retaining member forms a blowout
inhibitor in response to the actuation of the field.
8. A method for forming a temporary fluid-restraining member in a
wellbore, the method comprising: providing a fluid-retaining member
having an inner surface and an outer surface within a wellbore, the
fluid-retaining member being operable to retain a smart fluid;
providing a controller, the controller being electrically coupled
to at least one of the inner surface and outer surface of the
fluid-retaining member; and actuating a field between the inner
surface and outer surface of the fluid-retaining member.
9. The method of claim 7, wherein the smart fluid comprises a
magnetorheological fluid and the field comprises a magnetic
field.
10. The method of claim 7, wherein the smart fluid comprises an
electrorheological fluid and the field comprises an electric
field.
11. The method of claim 7, wherein the fluid-retaining member is
selected from the group consisting of a sponge, a lattice, and a
hollow cylindrical structure.
12. The method of claim 7, further comprising prefilling the
fluid-retaining structure with a smart fluid.
13. The method of claim 7, further comprising delivering a smart
fluid to the fluid-retaining member in response to receiving a
control signal at the controller.
14. The method of claim 7, further comprising causing a smart fluid
disposed within the fluid-retaining member to solidify in response
to the actuation of the field.
15. A wellhead insulation system comprising: at least one
fluid-retaining member having an inner surface and an outer
surface; a power source operable to actuate a field between the
inner surface and outer surface of the fluid-retaining member; and
a smart fluid disposed within the fluid-retaining member, the smart
fluid being operable to solidify in response to the field.
16. The system of claim 15, wherein the smart fluid comprises a
magnetorheological fluid and wherein the field comprises a magnetic
field.
17. The system of claim 15, wherein the smart fluid comprises an
electrorheological fluid and wherein the field comprises an
electric field.
18. The system of claim 15, wherein the at least one
fluid-retaining member comprises a cylindrical member that forms a
circumferential barrier around the wellhead.
19. The system of claim 15, wherein the at least one
fluid-retaining member comprises a series of structures arranged in
segments to form a barrier around a wellhead.
20. The system of claim 15, further comprising: a controller, the
controller being electrically coupled to the power source and at
least one of the inner surface and outer surface of the
fluid-retaining member and operable to actuate an electric field
between the inner surface and outer surface of the fluid-retaining
member; and a pressure sensor coupled to the controller, the
pressure sensor being operable to monitor a pressure within a well
downhole from the wellhead, wherein the controller is operable to
generate a control signal that results in actuation of the electric
field in response to determining that the pressure within the well
is greater than a pre-determined threshold rate.
Description
1. FIELD OF THE INVENTION
[0001] The disclosure relates to oil and gas exploration and
production, and more particularly, but not by way of limitation to
systems that employ variable-viscosity fluids to generate well
completions, isolations, and safety systems.
2. DESCRIPTION OF RELATED ART
[0002] Crude oil and natural gas occur naturally in subterranean
deposits and their extraction includes drilling a well. The well
provides access to a production fluid that often contains crude oil
and natural gas. Generally, drilling of the well involves deploying
a drill string into a formation. The drill string includes a drill
bit that removes material from the formation as the drill string is
lowered to remove material from the formation and form a wellbore.
After drilling and prior to production, a casing may be deployed in
the wellbore to isolate portions of the wellbore wall and prevent
the ingress of fluids from parts of the formation that are not
likely to produce desirable fluids. After completion, a production
string may be deployed into the well to facilitate the flow of
desirable fluids from producing areas of the formation to the
surface for collection and processing.
[0003] A number of mechanisms may be included in drill strings and
production strings to protect equipment within the wellbore and
ensure consistent operation such equipment. For example, valves and
blow-out preventers may be installed to prevent rapid, excessive
increases in pressure and to prevent backflow. In addition, safety
equipment may be installed at a wellhead to protect equipment and
people in the vicinity of the wellhead in the event of a blowout at
the wellhead.
BRIEF DESCRIPTION OF THE DRAWINGS
[0004] FIG. 1 illustrates a schematic view of a producing well in
which a temporary casing system and isolators are deployed;
[0005] FIG. 2A illustrates a schematic view of a subterranean well
in which an electrorheological safety system and a smart fluid
blowout inhibitor is deployed;
[0006] FIG. 2B illustrates a schematic view of a subsea well in
which the electrorheological safety system and a smart fluid
blowout inhibitor of FIG. 2A are deployed;
[0007] FIG. 3 is a schematic, side cross-section view of a
temporary casing that includes a smart fluid;
[0008] FIG. 4 is a schematic, side cross-section view of a blowout
inhibitor that includes a smart fluid;
[0009] FIG. 5 is a schematic, side cross-section view of a wellhead
insulation system that includes a smart fluid; and
[0010] FIG. 5A is a schematic, cross-section view of the system of
FIG. 5 taken along the line 5A-5A.
DETAILED DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS
[0011] In the following detailed description of the illustrative
embodiments, reference is made to the accompanying drawings that
form a part hereof. These embodiments are described in sufficient
detail to enable those skilled in the art to practice the
invention, and it is understood that other embodiments may be
utilized and that logical structural, mechanical, electrical, and
chemical changes may be made without departing from the scope of
the invention. To avoid detail not necessary to enable those
skilled in the art to practice the embodiments described herein,
the description may omit certain information known to those skilled
in the art. The following detailed description is, therefore, not
to be taken in a limiting sense, and the scope of the illustrative
embodiments is defined only by the appended claims.
[0012] In the drawings and description that follow, like parts are
typically marked throughout the specification and drawings with the
same reference numerals, respectively. The drawing figures are not
necessarily to scale. Certain features of the invention may be
shown exaggerated in scale or in somewhat schematic form and some
details of conventional elements may not be shown in the interest
of clarity and conciseness.
[0013] The embodiments described herein relate to systems, tools,
and methods for establishing temporary structures in a drilling or
production system. In an illustrative embodiment, a temporary
wellbore structure, which may be a segment of casing or an
isolator, includes a fluid-retaining member having an inner surface
and an outer surface. The fluid-retaining member is operable to
retain a smart fluid, which may be an electrorheological fluid or a
magnetorheological fluid. The temporary structure includes a
controller that is electrically coupled to at least one of the
inner surface and outer surface of the fluid-retaining member,
which form a field generator that is operable to actuate an
electric field or a magnetic field between the inner surface and
outer surface of the fluid-retaining member. A surface control
subsystem may be communicatively coupled to the controller and to
enable a surface-based well operator to actuate the controller.
[0014] A smart fluid is disposed within the fluid-retaining member
and operable to solidify, gel, or otherwise increase in viscosity
upon actuation of the field to increase the rigidity of the
fluid-retaining member. The fluid-retaining member may be a sponge,
lattice, hollow cylindrical structure, or another suitable
structure. The fluid-retaining member is prefilled with a smart
fluid in an embodiment. In another embodiment, the system includes
a fluid delivery system for delivering a smart fluid to the
fluid-retaining member.
[0015] The fluid-retaining member may be disposed adjacent a
wellbore wall, and therefore operable to form a temporary casing.
In another embodiment, the fluid-retaining member may be disposed
in an annulus between a production string and a wellbore wall or
casing, and operable to isolate a well zone that is downhole from
the fluid-retaining member from a well zone that is up-hole from
the fluid-retaining member. In another embodiment, the
fluid-retaining member is disposed within a production string or a
similar segment of tubing, and operable to act as a blowout
inhibitor in response to the actuation of the field.
[0016] Unless otherwise specified, any use of any form of the terms
"connect," "engage," "couple," "attach," or any other term
describing an interaction between elements is not meant to limit
the interaction to direct interaction between the elements and may
also include indirect interaction between the elements described.
In the following discussion and in the claims, the terms
"including" and "comprising" are used in an open-ended fashion, and
thus should be interpreted to mean "including, but not limited to".
Unless otherwise indicated, as used throughout this document, "or"
does not require mutual exclusivity.
[0017] The various characteristics mentioned above, as well as
other features and characteristics described in more detail below,
will be readily apparent to those skilled in the art with the aid
of this disclosure upon reading the following detailed description
of the embodiments, and by referring to the accompanying drawings.
Other means may be used as well.
[0018] Referring now to the figures, FIG. 1 shows an example of a
production system 100 that includes an isolator 105 and temporary
casing segment 104, as described in more detail below. The
production system 100 includes a rig 116 atop the surface 132 of a
well 101. Beneath the rig 116, the wellbore 108 is formed within
the geological formation 106, which is expected to produce
hydrocarbons. The wellbore 108 may be formed in the geological
formation 106 using a drill string that includes a drill bit to
remove material from the geological formation 106. The wellbore 108
in FIG. 1 is shown as being near-vertical, but may be formed at any
suitable angle to reach a hydrocarbon-rich portion of the
geological formation 106. As such, in an embodiment, the wellbore
108 may follow a vertical, partially vertical, angled, or even a
partially horizontal path through the geological formation 106.
[0019] Following or during formation of the wellbore 108, a
production tool string 112 may be deployed that includes tools for
use in the wellbore 108 to operate and maintain the well 101. For
example, the production tool string 112 optionally includes an
artificial lift system to assist fluids from the geological
formation to reach the surface 132 of the well 101. Such an
artificial lift system may include an electric submersible pump
102, sucker rods, a gas lift system, or any other suitable system
for generating a pressure differential. The pump 102 receives power
from the surface 132 from a power transmission cable 110, which may
also be referred to as an "umbilical cable."
[0020] In a production environment, as shown in FIG. 1, production
fluids 146 are extracted from the formation 106 and delivered to
the surface 132 via the wellbore 108. As fluid 146 is transported
to the surface 132, the fluid passes through the blowout preventer
142 and a fluid diverter 144 that diverts fluid 146 to a collection
tank 140 for subsequent processing and refinement.
[0021] In such systems, a well operator may monitor the condition
of the well 101 and components of the production tool string 112 to
ensure that the well operates efficiently and to determine whether
the production fluid 146 has desired properties. For example, an
operator may want to determine that the production fluid 146 has a
high hydrocarbon content and a low water content. In some cases, a
well operator may determine that a portion of the formation 106
produces desirable fluids while another portion of the foundation
produces undesirable fluids, each such portion of the formation may
be referred to as a zone. An operator may similarly determine that
different zones within a formation produce fluid at different
rates, or that different zones have higher or lower hydrostatic
pressure relative to one another. For example, the formation 106
may have a first zone 156 that interacts with the wellbore 108
downhole from a second zone 158. To account for such differing
characteristics, an operator may include an isolator 105 for
separating the first zone 156 from the second zone to allow for
different rates of production or to allow, for example, production
of fluid from the first zone 156 without allowing production from
the second zone 158. Similarly, to prevent the ingress of fluids
from a zone in the formation 106, the system 100 may include a
casing 114 or temporary casing 104 that restricts the communication
of fluids between the formation 106 and wellbore 108.
[0022] In addition, the well operator may take steps to ensure that
the pressure in the well does not increase beyond a predetermined
threshold, and that pressure within the well or production string
112 does not increase at a rate that is faster than a predetermined
rate. Rapid increases in pressure, which may be referred to herein
as "pressure spikes" may damage equipment in the production string
112 that is subject to the pressure spike or stress other sealing
elements that are designed to contain the well. To account for such
pressure spikes and prevent damage to wellbore equipment, the
production system 100 may include a blowout inhibitor 124 that
prevents such pressure spikes from being transmitted to parts of
the production string that are up-hole from the blowout inhibitor
124.
[0023] In an embodiment, a surface controller 120 may be
communicatively coupled to the temporary casing segment 104,
isolator 105, or blowout inhibitor 124 (any of which may be
referred to as a "downhole component") by the cable 110 or by a
wireless communication protocol, such as mud-pulse telemetry or a
similar communications protocol. The cable 110 may supply power to
the downhole component and facilitate the transmission of data
between the surface controller 120 and downhole component. In some
embodiments, one or more of the downhole components may be
permanently or semi-permanently deployed in the wellbore 108, and
may include an on-board controller that functions autonomously or
that communicates with the surface controller 120 via a wired or
wireless communications protocol.
[0024] The production system 100 of FIG. 1 is deployed from the rig
116, which may be a drilling rig, a completion rig, a workover rig,
or another type of rig. The rig 116 includes a derrick 109 and a
rig floor 111. The production tool string 112 extends downward
through the rig floor, through a fluid diverter 144 and up-hole
blowout preventer 142 that provide a fluidly sealed interface
between the wellbore 108 and external environment. The rig 116 may
also include a motorized winch 130 and other equipment for
extending the tool string 112 into the wellbore 108, retrieving the
tool string 112 from the wellbore 108, and positioning the tool
string 112 at a selected depth within the wellbore 108.
[0025] While the operating environment shown in FIG. 1 relates to a
stationary, land-based rig 116 for raising, lowering and setting
the tool string 112, in alternative embodiments, mobile rigs,
wellbore servicing units (such as coiled tubing units, slickline
units, or wireline units), and the like may be used to lower the
tool string 112. Further, while the operating environment is
generally discussed as relating to a land-based well, the systems
and methods described herein may instead be operated in subsea well
configurations accessed by a fixed or floating platform. Further,
while the downhole components are shown as being deployed in a
production environment, the downhole components may be similarly
deployed in a drilling environment during the formation of the
wellbore 108.
[0026] For example, FIGS. 2A and 2B show a system 200 that includes
a drill string 212 deployed a well. The well is formed by a
wellbore 208 that extends from a surface 232 of the well to or
through a subterranean geological formation 206. The well is
illustrated onshore in FIG. 2A with the system 200 being deployed
in land-based well. In another embodiment, the system 200 may be
deployed in a sub-sea well accessed by a fixed or floating platform
221. In the embodiment illustrated in FIG. 2A, the well is formed
by a drilling process in which a drill bit 216 is turned by a drill
string 212 that extends the drill bit 216 from the surface 232 to
the bottom of the well. The drill string 212 may be made up of one
or more connected tubes or pipes, of varying or similar
cross-section. The drill string may refer to the collection of
pipes or tubes as a single component, or alternatively to the
individual pipes or tubes that comprise the string. The term drill
string is not meant to be limiting in nature and may refer to any
component or components that are capable of transferring kinetic,
electrical, or hydraulic energy from the surface of the well to the
drill bit to remove material from the wellbore. In several
embodiments, the drill string 212 may include a central passage
disposed longitudinally in the drill string and capable of allowing
fluid communication between the surface of the well and downhole
locations.
[0027] At or near the surface 232 of the well, the drill string 212
may include or be coupled to a kelly 228. The kelly 228 may have a
square, hexagonal or octagonal cross-section. The kelly 228 is
connected at one end to the remainder of the drill string and at an
opposite end to a rotary swivel 233. The kelly passes through a
rotary table 236 that is capable of rotating the kelly 228 and thus
the remainder of the drill string 212 and drill bit 216. The rotary
swivel 233 allows the kelly 228 to rotate without rotational motion
being imparted to the rotary swivel 233. A hook 238, cable 242,
traveling block (not shown), and hoist (not shown) are provided to
lift or lower the drill bit 216, drill string 20, kelly 228 and
rotary swivel 233. The kelly 128 and swivel 233 may be raised or
lowered as needed to add additional sections of tubing to the drill
string 212 as the drill bit 216 advances, or to remove sections of
tubing from the drill string 212 if removal of the drill string 212
and drill bit 216 from the well is desired.
[0028] A reservoir 244 is positioned at the surface 208 and holds
drilling mud 248 for delivery to the well 202 during drilling
operations. A supply line 252 is fluidly coupled between the
reservoir 244 and the inner passage of the drill string 212. A pump
256 drives fluid through the supply line 252 and downhole to
lubricate the drill bit 216 during drilling and to carry cuttings
from the drilling process back to the surface 232. After traveling
downhole, the drilling mud 248 returns to the surface 232 by way of
an annulus 260 formed between the drill string 212 and the wellbore
208. At the surface 232, the drilling mud 248 is returned to the
reservoir 244 through a return line 264. The drilling mud 248 may
be filtered or otherwise processed prior to recirculation through
the well 202.
[0029] A wellhead insulation system 204 may be positioned at or
near the top of the well to protect equipment and people working in
the vicinity in the event of an explosion or other rapid ejection
of matter from the well. The wellhead insulation system 204 may
include one or more similarly formed wellhead insulation system
components that absorb energy and prevent the full force of an
explosion from being felt outside of the wellhead insulation system
204.
[0030] Referring now primarily to FIG. 3, an embodiment of a
downhole component 300 is shown. The downhole component may be a
temporary casing, isolator, or other similar component. The
downhole component includes a fluid-retaining member, which may be
an approximately cylindrical member 302 having an outer surface 304
and an inner surface 306. Each of the outer surface 304 and inner
surface 306 includes a conductive layer that is formed from an
electrically polarizable material and coupled to either a ground or
an electric potential. For example, in the embodiment of FIG. 3,
the outer surface 304 is coupled to a ground 308 and the inner
surface is coupled to a potential 310. Each of the ground 308 and
potential 310 may be provided by a control line 312 that is coupled
to, for example, a surface controller, as described above with
regard to FIG. 1.
[0031] The control line 312 is operable to actuate the potential
310, which generates a charge at the inner surface 306 and a
corresponding electric field between the inner surface and the
outer surface 304. In an alternative embodiment, the potential 310
may be coupled to an electromagnet that generates a magnetic field
between the inner surface 306 and the outer surface 304.
[0032] The fluid-retaining member may be a hollow structure, a
lattice, a sponge, or any other suitable structure that is capable
of holding a fluid, gel, or solidified fluid or gel. The
fluid-retaining member may be prefilled with a smart fluid or
filled with a smart fluid upon the occurrence of an actuation
event, which may be the receipt of a control signal and
corresponding potential from the control line 312 or the receipt of
an actuation signal from another source, such as an onboard
controller or sensor. To fill the fluid-retaining member upon the
occurrence of an actuation event, a control signal may be generated
to a valved reservoir that forces an adequate amount of smart fluid
into the fluid-retaining member to fill all or a portion of the
fluid-retaining member upon actuation. The valved reservoir may be
analogous to the fluid chamber described below with regard to FIG.
4, and may include a piston that forces fluid from the reservoir
into the fluid-retention member upon the occurrence of an actuation
event.
[0033] As referenced herein, a smart fluid is a fluid having a
viscosity that varies in accordance with a stimulus, such as an
electric field or magnetic field applied across the fluid.
Generally, an electrorheological fluid is a suspension of
conductive particles in an electrically insulating fluid. The
apparent viscosity of the electrorheological fluid may change
reversibly in response to the electric field. For example, a
typical electrorheological fluid can go from the consistency of
liquid water to a gel, a solid state, or a nearly solid state, and
back, with a response times on the order of milliseconds. In an
embodiment, the electrorheological fluid comprises urea-coated
particles of barium titanium oxalate suspended in silicone oil.
Similarly, a magnetorheological fluid is a suspension of magnetic
particles in a fluid. The apparent viscosity of the
magnetorheological fluid may also change reversibly in response to
a magnetic field. Like an electrorheological fluid, a typical
magnetorheological fluid can go from the consistency of liquid
water to a gel, a solid state, or a nearly solid state, and back,
with a response time on the order of milliseconds. In the
illustrative embodiments described below, the smart fluid is
generally described as an electrorheological fluid. However, the
electrorheological fluid and corresponding actuation mechanisms may
be substituted for a magnetorheological fluid and actuation
structure without departing from the scope of this disclosure.
[0034] In the case of the downhole component 300 shown in FIG. 3
actuation of the potential 310 and corresponding electric field may
cause an amount of electrorheological fluid stored within the
fluid-retaining member to gel or solidify, thereby restricting the
ability of other fluids to flow through the area occupied by the
actuated electrorheological fluid. This may enable the
fluid-retaining structure to function as a temporary casing or as
an isolator to restrict flow between zones in a wellbore or to
restrict the ingress of fluid from a wellbore at the site of the
temporary casing.
[0035] FIG. 4 shows an alternative embodiment of a downhole
component, as described above with regard to FIG. 1, wherein the
downhole component is a blowout inhibitor 400. The blowout
inhibitor 400 may be deployed as an element in a production string
and may therefore include couplings 432 at either end for joining
with tubing segments 430 of a production string. In an embodiment,
the blowout inhibitor 400 includes a fluid-retaining member, which
may be a hollow tubing segment or similar cylindrical member 402.
The cylindrical member may include a fluid chamber 404 that
functions as a reservoir to store, for example, an
electrorheological fluid 406. The fluid chamber 404 may be enclosed
by a valve 411 that separates the fluid chamber 404 from a conduit
that passes through the blowout inhibitor 400 and other tubing
segments 430 in the production string. The fluid chamber 404 may
also include a piston 408 that may be actuated to urge the
electrorheological fluid 406 through the valve 411 and into the
conduit. An actuator, such as a solenoid 410, may be included to
actuate the piston 408.
[0036] The solenoid 410 or another type of actuator may be coupled
to a controller 412 by a first control line 414. A pressure sensor
416 may be included at the base of the blowout inhibitor 400 or
downhole from the blowout inhibitor 400 to detect pressure spikes.
The pressure sensor 416 may be coupled to the controller 412 by
sensor coupling 418 to generate a signal to the controller 412 that
indicates when a pressure spike is detected. Detection of the
pressure spike may result in actuation of a field, such as an
electric field or magnetic field, by the controller 412.
[0037] To generate an electric field, the controller 412 may
include or be coupled to a power source, such as a battery or a
remote power source. In addition, in an embodiment, the controller
412 is coupled to a conductive inner surface 428 of the cylindrical
member 402 or a conductive member 422 having a conductive outer
surface 424 to provide an actuation signal, or a potential. In an
embodiment, either one of the inner surface 428 of the cylindrical
member 402 and the outer surface 424 of the conductive member 422
is coupled to the controller and the other of the inner surface 428
of the cylindrical member 402 and the outer surface 424 of the
conductive member 422 is coupled to a ground. A second control line
420 may be provided to couple the conductive member 422 to the
controller 412 or to couple the conductive member 422 to a ground.
In another embodiment, on or more of the controller 412 and the
sensor 416 may be coupled to one another indirectly via a surface
controller.
[0038] In an embodiment, the electric field of the blowout
inhibitor 400 of FIG. 4 may be initiated by the receipt of a
control signal from a surface controller or upon determination of a
pressure spike by the pressure sensor 416, either of which may be
referred to as an initiation signal. In response to an initiation
signal, the solenoid 410 may actuate the piston 408 to cause it to
force the electrorheological fluid 406 from the fluid chamber 404
to the conduit. The initiation signal may also result in the
actuation of the electric field so that, as the electrorheological
fluid flows into the conduit, the electrorheological fluid may
solidify to restrict the ability of the pressure spike to propagate
up the production string to affect other components.
[0039] In the event that a pressure spike does reach the surface,
resulting in an emission of fluid or another type of explosion,
similar systems may be employed to protect people and equipment
near the wellhead. An example of such a system is shown in FIG. 5.
More particularly, FIG. 5 shows a wellhead insulation system 500
deployed at a wellhead 504. In an embodiment, the wellhead
insulation system 500 includes one or more fluid-retaining members
502, which may be a hollow tubing segment or similar cylindrical
member, or a segment 522 thereof that is arranged next to an
adjacent segment to form an enclosure around the wellhead 504.
While the perimeter is shown as being round, the perimeter may
alternatively be square, oval, or any other suitable shape. Each
fluid-retaining member 502 includes a conductive inner plate 506, a
conductive outer plate 508, and functions as reservoir to store,
for example, an electrorheological fluid 510.
[0040] One of the inner plate 506 and outer plate 508 may be
coupled to a controller 512 by a control line 512 and the other of
the inner plate 506 and outer plate 508 may be coupled to a ground
520. A pressure sensor 514 may be included in the wellhead 504 to
detect a blowout or similar event by, for example, detecting
pressure spikes. The pressure sensor 514 may be coupled to the
controller 512 by sensor coupling 516 to generate a signal to the
controller 512 that indicates when a pressure spike is detected. As
described above with regard to the blowout inhibitor of FIG. 4,
detection of the pressure spike may result in actuation of an
electric field by the controller 412.
[0041] To generate a field, the controller 512 may include or be
coupled to a power source, such as a battery or a remote power
source. In an embodiment, an electric field of the wellhead
insulation system 500 of FIG. 5 may be initiated by the receipt of
a control signal from a surface controller or upon determination of
a pressure spike by the pressure sensor 514, either of which may be
referred to as an initiation signal. In an embodiment, the
initiation signal results in the actuation of an electric field by
causing the controller to apply a potential to one of the inner
plate 506 and outer plate 508 so that the electrorheological fluid
solidifies gels. Since significant kinetic energy is absorbed when
wellbore material collides with the energized electrorheological
fluid in the wellhead insulation system 500, the wellhead
insulation system 500 will restrict the ability of an explosion to
injure nearby equipment or workers.
[0042] FIG. 5A shows a top view of the wellhead insulation system
500 of FIG. 5 and illustrates that the wellhead insulation system
500 may be formed in segments 522. Each segment may form a portion
of the perimeter that surrounds the wellhead 504. The inner plate
506 and outer plate 508 may be coupled to a common controller in
parallel or in series, or may each be constructed with an onboard
controller that is coupled to one or more sensors 514 to detect a
blowout or similar event.
[0043] In another embodiment, empty segments 522 or an empty
fluid-retaining structure 502 may be constructed to be a hollow,
lightweight component that can easily be transported to a wellhead
504 and filled onsite with an electrorheological fluid, greatly
reducing transportation and assembly costs, and providing for
easier installation. In an embodiment, the controller 512 may be
omitted and the inner plates 506 or outer plates 508 may be coupled
to stable potential to maintain the electrorheological fluid in an
energizes state, thereby negating the need to detect a blowout in
order to protect nearby equipment or personnel.
[0044] As an alternative to each of the foregoing embodiments, a
corresponding embodiment may be implemented that uses a
magnetorheological fluid in place of the electrorheological fluid.
In the case of each such alternative embodiment, the structures
disclosed may be nearly identical with the exception of the
alternative fluid, and the replacement of the structure used to
generate an electric field with a corresponding structure that
generates a magnetic field. For example, a wound coil that
generates an electromagnetic field may be used to apply a magnetic
field affect a magnetorheological fluid. In an embodiment in which
the fluid retaining structure that houses the magnetorheological
fluid comprises parallel surfaces, each surface may include a
shielded magnetic plate, or an electromagnet coupled to a
magnetizable plate to generate a magnetic field adjacent the plate.
In addition, a permanent magnet may be deployed into the
magnetorheological fluid to actuate the fluid and increase its
viscosity to effect a temporary completion, a blowout inhibitor, or
a safety system.
[0045] In an embodiment in which a magnetorheological fluid is
used, any suitable magnetorheological fluid may be used. The
magnetorheological fluid may be, for example, a first composition
including 20 wt. % carbonyl iron (CI) and fumed silica stabilizer
("Aerosil 200") in silicone oil (OKS 1050); a second composition
including 40 wt. % carbonyl iron (CI) and fumed silica stabilizer
("Aerosil 200") in silicone oil (OKS 1050); a third composition
including 20 wt. % carbonyl iron (CI) in silicone oil (OKS 1050);
and a fourth composition including 40 wt. % carbonyl iron (CI) in
silicone oil (OKS 1050); or any other suitable composition. In each
of the representative examples, the viscosity of the
magneto-rheological fluid varies as a function of magnetic field
strength generated by a field generator, such as an electromagnet
or a permanent magnet.
[0046] In view of the above disclosure, a number of systems and
methods relating to the use of electrorheological completions,
isolations, and safety systems are provided. For example, in an
illustrative embodiment, a system for use in a wellbore comprises a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain an
electrorheological fluid. The system also includes a controller
that is electrically coupled to at least one of the inner surface
and outer surface of the fluid-retaining member and operable to
actuate an electric field between the inner surface and outer
surface of the fluid-retaining member. In addition, the system
includes a surface control subsystem communicatively that is
coupled to the controller and operable actuate the controller. The
fluid-retaining member may be a sponge, a lattice or honeycomb, or
a porous foam. In an embodiment, the fluid-retaining member is a
hollow cylindrical structure.
[0047] The fluid-retaining member may be prefilled with an
electrorheological fluid, or configured to receive
electrorheological fluid from a fluid delivery system that delivers
electrorheological fluid to the fluid-retaining member and forms a
portion of the system. Electrorheological fluid disposed within the
fluid-retaining member may be operable to solidify, gel, thicken,
or otherwise vary in viscosity in response to the actuation of the
electric field.
[0048] In an embodiment, the fluid-retaining member forms a segment
of a wellbore casing upon being subjected to the electric field. In
another embodiment, the fluid-retaining member forms a blowout
inhibitor upon being subjected to the electric field. The blowout
inhibitor may be operable to obstruct the flow of fluid in the
wellbore beyond the blowout inhibitor, effectively stopping upward
flow. In an embodiment, the system further includes a pressure
sensor coupled to at least one of the controller and the surface
control. The pressure sensor may be operable to monitor a pressure
within the wellbore downhole from the fluid-retaining member.
[0049] At least one of the controller and the surface control may
be operable to generate a control signal that results in actuation
of the electric field in response to the pressure sensor
determining that the pressure within the wellbore downhole from the
fluid-retaining member is greater than a pre-determined threshold,
or in response to determining that the pressure within the wellbore
downhole from the fluid-retaining member is increasing at a rate
that exceeds a predetermined threshold rate. In an embodiment, the
system includes a fluid delivery subsystem to deliver an
electrorheological fluid to the fluid-retaining member in response
to the control signal.
[0050] In accordance with another illustrative embodiment, a method
for forming a temporary fluid-restraining member in a wellbore
includes providing a fluid-retaining member having an inner surface
and an outer surface within a wellbore. The fluid-retaining member
being operable to retain an electrorheological fluid. The method
further includes providing a controller that is electrically
coupled to at least one of the inner surface and outer surface of
the fluid-retaining member. In addition the method includes
actuating an electric field between the inner surface and outer
surface of the fluid-retaining member to energize an
electrorheological fluid.
[0051] The fluid-retaining member may include a sponge, lattice, or
similar structure, and may also include a hollow cylindrical
structure resembling, for example, a segment of tubing. The method
may further include prefilling the fluid-retaining structure with
an electrorheological fluid or delivering the electrorheological
fluid to the fluid-retaining member in response to receiving a
control signal at the controller. The method may also include
causing an electrorheological fluid disposed within the
fluid-retaining member to solidify in response to the actuation of
the electric field.
[0052] In an embodiment, the method includes forming a segment of a
wellbore casing with the fluid-retaining member in response to the
actuation of the electric field. In another embodiment, the method
includes forming a blow-out preventer with the fluid-retaining
member in response to the actuation of the electric field. The
method may further comprise coupling a pressure sensor to the
controller and monitoring a pressure within the wellbore downhole
from the fluid-retaining member. In addition, the method may
comprise generating a control signal that results in actuation of
the electric field in response to determining that the pressure
within the wellbore downhole from the fluid-retaining member is
greater than a pre-determined threshold, or generating a control
signal that results in actuation of the electric field in response
to determining that the pressure within the wellbore downhole from
the fluid-retaining member is increasing at a rate that is greater
than a pre-determined threshold rate. In such an embodiment, the
method may further include delivering an electrorheological fluid
to the fluid-retaining member in response to the control
signal.
[0053] According to another illustrative embodiment, a wellhead
insulation system includes at least one fluid-retaining member
having an inner surface and an outer surface and a controller that
is electrically coupled to at least one of the inner surface and
outer surface of the fluid-retaining member and operable to actuate
an electric field between the inner surface and outer surface of
the fluid-retaining member. The wellhead insulation system also
includes an electrorheological fluid disposed within the
fluid-retaining member. The electrorheological fluid is operable to
solidify, gel, or otherwise increase in viscosity in response to
the actuation of the electric field. Further, the wellhead
insulation system includes an electrorheological fluid disposed
within the fluid-retaining member and may include a pressure sensor
coupled to the controller. The he pressure sensor being operable to
monitor a pressure within a well downhole from the wellhead.
[0054] In an embodiment, the fluid-retaining structure is a
cylindrical member that forms a circumferential barrier around the
wellhead. In another embodiment, the fluid-retaining structure is a
series of structures arranged in segments to form a barrier around
a wellhead. The series of structures may be a series of hollow
plates having conductive layers on each side of the hollow
plates.
[0055] In an embodiment, the controller is operable to generate a
control signal that results in actuation of the electric field in
response to determining that the pressure within the well is
greater than a pre-determined threshold. In another embodiment, the
controller is operable to generate a control signal that results in
actuation of the electric field in response to determining that the
pressure within the well is increasing at a rate that is greater
than a predetermined threshold rate.
[0056] In addition to the illustrative embodiments described above,
many examples of specific combinations are within the scope of the
disclosure, some of which are presented below.
Example One
[0057] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain a
smart fluid. The system also includes a controller, which is
electrically coupled to at least one of the inner surface and outer
surface of the fluid-retaining member and operable to actuate a
field between the inner surface and outer surface of the
fluid-retaining member. The system also includes a surface control
subsystem communicatively coupled to the controller and operable
actuate the controller.
Example Two
[0058] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain an
electrorheological fluid. The system also includes a controller,
which is electrically coupled to at least one of the inner surface
and outer surface of the fluid-retaining member and operable to
actuate an electric field between the inner surface and outer
surface of the fluid-retaining member. The system also includes a
surface control subsystem communicatively coupled to the controller
and operable actuate the controller.
Example Three
[0059] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain an
electrorheological fluid. The system also includes a controller,
which is magnetically coupled to at least one of the inner surface
and outer surface of the fluid-retaining member and operable to
actuate an electric field between the inner surface and outer
surface of the fluid-retaining member. The system also includes a
surface control subsystem communicatively coupled to the controller
and operable actuate the controller.
Example Four
[0060] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain a
smart fluid. The system also includes a controller, which is
electrically coupled to at least one of the inner surface and outer
surface of the fluid-retaining member and operable to actuate a
field between the inner surface and outer surface of the
fluid-retaining member. The system also includes a surface control
subsystem communicatively coupled to the controller and operable
actuate the controller. The fluid-retaining member is selected from
the group consisting of a sponge, a lattice, and a hollow
cylindrical structure.
Example Five
[0061] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being prefilled with and
operable to retain a smart fluid. The system also includes a
controller, which is electrically coupled to at least one of the
inner surface and outer surface of the fluid-retaining member and
operable to actuate a field between the inner surface and outer
surface of the fluid-retaining member. The system also includes a
surface control subsystem communicatively coupled to the controller
and operable actuate the controller.
Example Six
[0062] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being prefilled with and
operable to retain a smart fluid. The system also includes a
controller, which is electrically coupled to at least one of the
inner surface and outer surface of the fluid-retaining member and
operable to actuate a field between the inner surface and outer
surface of the fluid-retaining member. The system includes a
surface control subsystem communicatively coupled to the controller
and operable actuate the controller and also includes a fluid
delivery system for the smart fluid to the fluid-retaining
member.
Example Seven
[0063] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain a
smart fluid. The system also includes a controller, which is
electrically coupled to at least one of the inner surface and outer
surface of the fluid-retaining member and operable to actuate a
field between the inner surface and outer surface of the
fluid-retaining member. The system also includes a surface control
subsystem communicatively coupled to the controller and operable
actuate the controller. The smart fluid is disposed within the
fluid-retaining member yet is operable to solidify in response to
the actuation of the field.
Example Eight
[0064] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain a
smart fluid. The system also includes a controller, which is
electrically coupled to at least one of the inner surface and outer
surface of the fluid-retaining member and operable to actuate a
field between the inner surface and outer surface of the
fluid-retaining member. The system also includes a surface control
subsystem communicatively coupled to the controller and operable
actuate the controller. The smart fluid is disposed within the
fluid-retaining member yet is operable to solidify in response to
the actuation of the field. The fluid-retaining member may be a
segment of a wellbore casing to be formed in response to the
actuation of the field or a blowout inhibitor in response to the
actuation of the field.
Example Nine
[0065] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain a
smart fluid. The system also includes a controller, which is
electrically coupled to at least one of the inner surface and outer
surface of the fluid-retaining member and operable to actuate a
field between the inner surface and outer surface of the
fluid-retaining member. The system also includes a surface control
subsystem communicatively coupled to the controller and operable
actuate the controller. In addition, the system includes a pressure
sensor coupled to at least one of the controller and the surface
control, the pressure sensor being operable to monitor a pressure
within the wellbore downhole from the fluid-retaining member.
Example Ten
[0066] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain a
smart fluid. The system also includes a controller, which is
electrically coupled to at least one of the inner surface and outer
surface of the fluid-retaining member and operable to actuate a
field between the inner surface and outer surface of the
fluid-retaining member. The system also includes a surface control
subsystem communicatively coupled to the controller and operable
actuate the controller. In addition, the system includes a pressure
sensor coupled to at least one of the controller and the surface
control, the pressure sensor being operable to monitor a pressure
within the wellbore downhole from the fluid-retaining member. In
accordance with the system, at least one of the controller and the
surface control is operable to generate a control signal that
results in actuation of the field in response to the pressure
sensor determining that the pressure within the wellbore downhole
from the fluid-retaining member is greater than a pre-determined
threshold. The system may also include a fluid delivery subsystem
to deliver a smart fluid to the fluid-retaining member in response
to the control signal.
Example Eleven
[0067] A system for use in a wellbore, the system having a
fluid-retaining member having an inner surface and an outer
surface, the fluid-retaining member being operable to retain a
smart fluid. The system also includes a controller, which is
electrically coupled to at least one of the inner surface and outer
surface of the fluid-retaining member and operable to actuate a
field between the inner surface and outer surface of the
fluid-retaining member. The system also includes a surface control
subsystem communicatively coupled to the controller and operable
actuate the controller. In addition, the system includes a pressure
sensor coupled to at least one of the controller and the surface
control, the pressure sensor being operable to monitor a pressure
within the wellbore downhole from the fluid-retaining member. In
accordance with the system, at least one of the controller and the
surface control is operable to generate a control signal that
results in actuation of the field in response to the pressure
sensor determining that the pressure within the wellbore downhole
from the fluid-retaining member is increasing at a rate that is
greater than a pre-determined threshold rate. The system may also
include a fluid delivery subsystem to deliver a smart fluid to the
fluid-retaining member in response to the control signal.
Example Twelve
[0068] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member.
Example Thirteen
[0069] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. In this example, the smart
fluid is a magnetorheological fluid and the field is a magnetic
field.
Example Fourteen
[0070] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. In this example, the smart
fluid is an electrorheological fluid and the field is an electric
field.
Example Fifteen
[0071] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. The fluid-retaining member
is selected from the group consisting of a sponge, a lattice, and a
hollow cylindrical structure.
Example Sixteen
[0072] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. The method further includes
prefilling the fluid-retaining structure with a smart fluid.
Example Seventeen
[0073] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. The method further includes
delivering a smart fluid to the fluid-retaining member in response
to receiving a control signal at the controller.
Example Eighteen
[0074] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. The method further includes
causing a smart fluid disposed within the fluid-retaining member to
solidify in response to the actuation of the field.
Example Nineteen
[0075] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. The method further includes
forming a segment of a wellbore casing with the fluid-retaining
member in response to the actuation of the field.
Example Twenty
[0076] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. The method further includes
forming a blow-out preventer with the fluid-retaining member in
response to the actuation of the field.
Example Twenty-One
[0077] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. The method further includes
forming a blow-out preventer with the fluid-retaining member in
response to the actuation of the field. In addition, the method
includes coupling a pressure sensor to the controller and
monitoring a pressure within the wellbore downhole from the
fluid-retaining member.
Example Twenty-Two
[0078] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. The method further includes
forming a blow-out preventer with the fluid-retaining member in
response to the actuation of the field. In addition, the method
includes generating a control signal that results in actuation of
the field in response to determining that the pressure within the
wellbore downhole from the fluid-retaining member is greater than a
pre-determined threshold.
Example Twenty-Three
[0079] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. The method further includes
forming a blow-out preventer with the fluid-retaining member in
response to the actuation of the field. In addition, the method
includes generating a control signal that results in actuation of
the field in response to determining that the pressure within the
wellbore downhole from the fluid-retaining member is increasing at
a rate that is greater than a pre-determined threshold rate.
Example Twenty-Four
[0080] A method for forming a temporary fluid-restraining member in
a wellbore includes providing a fluid-retaining member having an
inner surface and an outer surface. The fluid-retaining member is
operable to retain a smart fluid. The method further includes
providing a controller that is electrically coupled to at least one
of the inner surface and outer surface of the fluid-retaining
member, and actuating a field between the inner surface and outer
surface of the fluid-retaining member. The method further includes
forming a blow-out preventer with the fluid-retaining member in
response to the actuation of the field. In addition, the method
includes generating a control signal that results in actuation of
the field in response to determining that the pressure within the
wellbore downhole from the fluid-retaining member is increasing at
a rate that is greater than a pre-determined threshold rate, or in
response to determining that the pressure is greater than a
pre-determined threshold. The method also includes delivering a
smart fluid to the fluid-retaining member in response to the
control signal.
Example Twenty-Five
[0081] A wellhead insulation system having at least one
fluid-retaining member that includes an inner surface and an outer
surface. The system has a power source operable to actuate a field
between the inner surface and outer surface of the fluid-retaining
member, and a smart fluid is disposed within the fluid-retaining
member. The smart fluid is operable to solidify in response to the
field.
Example Twenty-Six
[0082] A wellhead insulation system having at least one
fluid-retaining member that includes an inner surface and an outer
surface. The system has a power source operable to actuate a field
between the inner surface and outer surface of the fluid-retaining
member, and a smart fluid is disposed within the fluid-retaining
member. The smart fluid is operable to solidify in response to the
field. The smart fluid is a magnetorheological fluid and the field
is a magnetic field.
Example Twenty-Six
[0083] A wellhead insulation system having at least one
fluid-retaining member that includes an inner surface and an outer
surface. The system has a power source operable to actuate a field
between the inner surface and outer surface of the fluid-retaining
member, and a smart fluid is disposed within the fluid-retaining
member. The smart fluid is operable to solidify in response to the
field. The smart fluid is an electrorheological fluid and the field
is an electric field.
Example Twenty-Seven
[0084] A wellhead insulation system having at least one
fluid-retaining member that includes an inner surface and an outer
surface. The system has a power source operable to actuate a field
between the inner surface and outer surface of the fluid-retaining
member, and a smart fluid is disposed within the fluid-retaining
member. The smart fluid is operable to solidify in response to the
field. The at least one fluid-retaining member includes a
cylindrical member that forms a circumferential barrier around the
wellhead.
Example Twenty-Eight
[0085] A wellhead insulation system having at least one
fluid-retaining member that includes an inner surface and an outer
surface. The system has a power source operable to actuate a field
between the inner surface and outer surface of the fluid-retaining
member, and a smart fluid is disposed within the fluid-retaining
member. The smart fluid is operable to solidify in response to the
field. The at least one fluid-retaining member includes a series of
structures arranged in segments to form a barrier around a
wellhead.
Example Twenty-Eight
[0086] A wellhead insulation system having at least one
fluid-retaining member that includes an inner surface and an outer
surface. The system has a power source operable to actuate a field
between the inner surface and outer surface of the fluid-retaining
member, and a smart fluid is disposed within the fluid-retaining
member. The smart fluid is operable to solidify in response to the
field. The at least one fluid-retaining member includes a series of
structures arranged in segments to form a barrier around a
wellhead, and the series of structures includes a series of hollow
plates having conductive layers on each side of the hollow
plates.
Example Twenty-Nine
[0087] A wellhead insulation system having at least one
fluid-retaining member that includes an inner surface and an outer
surface. The system has a power source operable to actuate a field
between the inner surface and outer surface of the fluid-retaining
member, and a smart fluid is disposed within the fluid-retaining
member. The smart fluid is operable to solidify in response to the
field. The fluid-retaining member includes a sponge or a
lattice.
Example Thirty
[0088] A wellhead insulation system having at least one
fluid-retaining member that includes an inner surface and an outer
surface. The system has a power source operable to actuate a field
between the inner surface and outer surface of the fluid-retaining
member, and a smart fluid is disposed within the fluid-retaining
member. The smart fluid is operable to solidify in response to the
field. The system further includes a controller that is
electrically coupled to the power source and at least one of the
inner surface and outer surface of the fluid-retaining member and
operable to actuate an electric or a magnetic field between the
inner surface and outer surface of the fluid-retaining member. In
addition, the system includes a pressure sensor coupled to the
controller. The pressure sensor is operable to monitor a pressure
within a well downhole from the wellhead.
Example Thirty-One
[0089] A wellhead insulation system having at least one
fluid-retaining member that includes an inner surface and an outer
surface. The system has a power source operable to actuate a field
between the inner surface and outer surface of the fluid-retaining
member, and a smart fluid is disposed within the fluid-retaining
member. The smart fluid is operable to solidify in response to the
field. The system further includes a controller that is
electrically coupled to the power source and at least one of the
inner surface and outer surface of the fluid-retaining member and
operable to actuate an electric or a magnetic field between the
inner surface and outer surface of the fluid-retaining member. In
addition, the system includes a pressure sensor coupled to the
controller. The pressure sensor is operable to monitor a pressure
within a well downhole from the wellhead. The controller is
operable to generate a control signal that results in actuation of
the electric field or magnetic field in response to determining
that the pressure within the well is greater than a pre-determined
threshold.
Example Thirty-Two
[0090] A wellhead insulation system having at least one
fluid-retaining member that includes an inner surface and an outer
surface. The system has a power source operable to actuate a field
between the inner surface and outer surface of the fluid-retaining
member, and a smart fluid is disposed within the fluid-retaining
member. The smart fluid is operable to solidify in response to the
field. The system further includes a controller that is
electrically coupled to the power source and at least one of the
inner surface and outer surface of the fluid-retaining member and
operable to actuate an electric or a magnetic field between the
inner surface and outer surface of the fluid-retaining member. In
addition, the system includes a pressure sensor coupled to the
controller. The pressure sensor is operable to monitor a pressure
within a well downhole from the wellhead. The controller is
operable to generate a control signal that results in actuation of
the electric field or magnetic field in response to determining
that the pressure within the well is greater than a pre-determined
threshold rate.
[0091] It will be understood that the above description of
preferred embodiments is given by way of example only and that
various modifications may be made by those skilled in the art. The
above specification, examples, and data provide a complete
description of the structure and use of exemplary embodiments of
the invention. Although various embodiments of the invention have
been described above with a certain degree of particularity, or
with reference to one or more individual embodiments, those skilled
in the art could make numerous alterations to the disclosed
embodiments without departing from the scope of the claims.
* * * * *