U.S. patent application number 13/458192 was filed with the patent office on 2012-11-01 for collapse sensing check valve.
Invention is credited to BRENT J. LIRETTE, MICHAEL LOGIUDICE, LEV RING, THAD JOSEPH SCOTT, JOSHUA VERNON SYMMS.
Application Number | 20120273225 13/458192 |
Document ID | / |
Family ID | 46052897 |
Filed Date | 2012-11-01 |
United States Patent
Application |
20120273225 |
Kind Code |
A1 |
LOGIUDICE; MICHAEL ; et
al. |
November 1, 2012 |
COLLAPSE SENSING CHECK VALVE
Abstract
A method and apparatus for a pressure relief valve assembly. The
valve assembly may be coupled to one or more casings and/or tubular
members to control fluid communication therebetween. The valve
assembly is a one-way valve assembly that relieves pressure within
an annulus formed between adjacent casings and/or tubular members
to prevent burst or collapse of the casings and/or tubular members.
The valve assembly is resettable downhole.
Inventors: |
LOGIUDICE; MICHAEL;
(Cypress, TX) ; SYMMS; JOSHUA VERNON; (Cypress,
TX) ; LIRETTE; BRENT J.; (Cypress, TX) ;
SCOTT; THAD JOSEPH; (Houston, TX) ; RING; LEV;
(Houston, TX) |
Family ID: |
46052897 |
Appl. No.: |
13/458192 |
Filed: |
April 27, 2012 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61481088 |
Apr 29, 2011 |
|
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Current U.S.
Class: |
166/373 ;
166/321; 166/332.1 |
Current CPC
Class: |
E21B 34/101 20130101;
E21B 2200/06 20200501; E21B 34/103 20130101; E21B 34/08 20130101;
E21B 21/103 20130101 |
Class at
Publication: |
166/373 ;
166/332.1; 166/321 |
International
Class: |
E21B 34/08 20060101
E21B034/08 |
Claims
1. A valve assembly, comprising: a tubular mandrel; a sleeve member
disposed within the tubular mandrel; and a biasing member disposed
within the tubular mandrel and operable to bias the sleeve member
against a shoulder of the tubular mandrel, wherein the sleeve
member is movable between a closed position where fluid
communication is closed between a bore of the valve assembly and a
port disposed through the tubular mandrel and an open position
where fluid communication is open between the bore of the valve
assembly and the port disposed through the tubular mandrel.
2. The valve assembly of claim 1, further comprising a seal member
for sealing the port from communication with the bore when the
sleeve member is in the closed position.
3. The valve assembly of claim 2, wherein the seal member is
coupled to the sleeve member and is movable across the port to open
fluid communication.
4. The valve assembly of claim 1, further comprising an internal
piston area and an external piston area, wherein the biasing member
contacts the internal piston area, and wherein the external piston
area is in fluid communication with an annulus surrounding the
valve assembly.
5. The valve assembly of claim 4, wherein the internal piston area
is formed by an end of the sleeve member, and wherein the external
piston area is formed by a shoulder of the sleeve member.
6. The valve assembly of claim 5, wherein the external piston area
is in fluid communication with the annulus via a second port
disposed through the tubular mandrel.
7. The valve assembly of claim 6, further comprising a seal member
for sealing communication between the second port and the bore.
8. A method of controlling fluid communication between an exterior
of a wellbore tubular and an interior of the wellbore tubular,
comprising: providing a valve assembly for coupling to the wellbore
tubular, wherein the valve assembly includes a tubular mandrel, a
sleeve member movably disposed in the tubular mandrel, and a
biasing member for biasing the sleeve member into a closed
position; and moving the sleeve member to an open position to open
fluid communication between the exterior of the wellbore tubular
and the interior of the wellbore in response to a pressure
differential exceeding a first predetermined value.
9. The method of claim 8, further comprising moving the sleeve
member to the closed position using the biasing member to close
fluid communication between the exterior of the wellbore tubular
and the interior of the wellbore tubular.
10. The method of claim 9, further comprising controlling fluid
flow through a port in the tubular mandrel using the sleeve member.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This application claims benefit of U.S. Provisional Patent
Application Ser. No. 61/481,088, filed Apr. 29, 2011, which is
herein incorporated in its entirety.
BACKGROUND OF THE INVENTION
[0002] 1. Field of the Invention
[0003] Embodiments of the invention generally relate to a pressure
relief valve assembly.
[0004] 2. Description of the Related Art
[0005] Traditional well construction, such as the drilling of an
oil or gas well, includes a wellbore or borehole being drilled
through a series of formations. Each formation, through which the
well passes, must be sealed so as to avoid an undesirable passage
of formation fluids, gases or materials out of the formation and
into the borehole. Conventional well architecture includes
cementing casings in the borehole to isolate or seal each
formation. The casings prevent the collapse of the borehole wall
and prevent the undesired inflow of fluids from the formation into
the borehole.
[0006] In standard practice, each succeeding casing placed in the
wellbore has an outside diameter significantly reduced in size when
compared to the casing previously installed. The borehole is
drilled in intervals whereby a casing, which is to be installed in
a lower borehole interval, is lowered through a previously
installed casing of an upper borehole interval and then cemented in
the borehole. The purpose of the cement around the casing is to fix
the casing in the well and to seal the borehole around the casing
in order to prevent vertical flow of fluid alongside the casing
towards other formation layers or even to the earth's surface.
[0007] If the cement seal is breached, due to high pressure in the
formations and/or poor bonding in the cement for example, fluids
(liquids or gases) may begin to migrate up the borehole. The fluids
may flow into the annuli between previously installed casings and
cause undesirable pressure differentials across the casings. The
fluids may also flow into the annuli between the casings and other
drilling or production tubular members that are disposed in the
borehole. Some of the casings and other tubulars, such as the
larger diameter casings, may not be rated to handle the unexpected
pressure increases, which can result in the collapse or burst of a
casing or tubular.
[0008] Therefore, there is a need for apparatus and methods to
prevent wellbore casing and tubular failure due to unexpected
downhole pressure changes.
SUMMARY OF THE INVENTION
[0009] In one embodiment, a valve assembly comprises a tubular
mandrel; a sleeve member disposed within the tubular mandrel; and a
biasing member disposed within the tubular mandrel and operable to
bias the sleeve member against a shoulder of the tubular mandrel.
The sleeve member is movable between a closed position where fluid
communication is closed between a bore of the valve assembly and a
port disposed through the tubular mandrel, and an open position
where fluid communication is open between the bore of the valve
assembly and the port disposed through the tubular mandrel.
[0010] In one embodiment, a method of controlling fluid
communication between an exterior of a wellbore tubular and an
interior of the wellbore tubular comprises providing a valve
assembly for coupling to the wellbore tubular, wherein the valve
assembly includes a tubular mandrel, a sleeve member movably
disposed in the tubular mandrel, and a biasing member for biasing
the sleeve member into a closed position; and moving the sleeve
member to an open position to open fluid communication between the
exterior of the wellbore tubular and the interior of the wellbore
in response to a pressure differential exceeding a first
predetermined value.
BRIEF DESCRIPTION OF THE DRAWINGS
[0011] So that the manner in which the above recited features of
the invention can be understood in detail, a more particular
description of the invention, briefly summarized above, may be had
by reference to embodiments, some of which are illustrated in the
appended drawings. It is to be noted, however, that the appended
drawings illustrate only typical embodiments of this invention and
are therefore not to be considered limiting of its scope, for the
invention may admit to other equally effective embodiments.
[0012] FIG. 1 is a schematic view of a wellbore.
[0013] FIG. 2 is a cross sectional view of a valve assembly in a
closed position.
[0014] FIG. 3 is a cross sectional view of the valve assembly in an
open position.
DETAILED DESCRIPTION
[0015] FIG. 1 illustrates a wellbore 5 formed within an earthen
formation 80. The walls of the wellbore 5 are reinforced with a
plurality of casings 10, 20, 30 of varying diameters that are
structurally supported within the formation 80. The casings 10, 20,
30 are fixed within the formation 80 using a sealing material 15,
25, 35, such as cement, which prevents the migration of fluids from
the formation 80 into the annuli between the casings 10, 20, 30.
One or more tubular members 40, 45, such as drilling or production
tubular members, may also be disposed in the wellbore 5 for
conducting wellbore operations. An annulus "A" is formed between
the casing 10 and the casing 20, and an annulus "B" is formed
between the casing 20 and the tubular member 40. It is important to
note that the embodiments described herein may be used with other
wellbore arrangements and are not limited to use with the wellbore
configuration illustrated in FIG. 1.
[0016] The wellbore 5 may intersect a high pressure zone 50 within
the formation 80. Fluids within the high pressure zone 50 are
sealed from the annulus A and B by the sealing material 25 that is
disposed between the casing 20 and the wellbore 5 wall. In the
event that the sealing material 25 is breached or otherwise
compromised, pressurized fluids may migrate upward into the annulus
A and cause an unexpected pressure increase. The pressure rise may
form a pressure differential across the casings 10, 20 that (if
unchecked) may result leakage through or burst of casing 10, and/or
leakage through or collapse of the casing 20. A valve assembly 100
is provided to relieve the pressure in the annulus A prior to
failure of one or both of the casings 10, 20.
[0017] FIG. 2 illustrates the valve assembly 100 in a closed
position. The valve assembly 100 is shown coupled to the casing 20
in FIG. 1, but each of the casings 10, 20, 30 and/or the tubular
members 40, 45 may similarly include one or more of the valve
assembly 100 as described herein. The valve assembly 100 may be
coupled to the casings 10, 20, 30 and/or the tubular members 40, 45
using a threaded connection, a welded connection, and/or other
similar connection arrangements.
[0018] The valve assembly 100 may comprise a top sub 110, a bottom
sub 120, a sleeve member 130, and a biasing member 140. The bottom
sub 120 is coupled to the top sub 110, such as by a threaded
connection. In one embodiment, the top sub 110 and the bottom sub
120 may be integrally formed as a single tubular mandrel. The
sleeve member 130 is movably disposed within the top sub 110, and
may be biased against a shoulder 125 or upper end of the bottom sub
120 by the biasing member 140. The biasing member 140 may be a
spring or other similar biasing mechanism. The biasing member 140
is also disposed within the top sub 110, and may be positioned
between the sleeve member 130 and a shoulder 113 of the top sub
110. A cover member 145 optionally may be provided to secure the
biasing member 140 within the top sub 110 and to protect the
biasing member 140 from interference with any component(s) that
pass through the bore 105 of the valve assembly 100. The inner
diameters of the top sub 110, the bottom sub 120, the sleeve member
130, and/or the cover member 145 may be equal to provide a
substantially uniform inner diameter surface throughout the length
of the valve assembly 100. In one embodiment, the inner diameter of
the bore 105 of the valve assembly 100 (including the top sub 110,
the bottom sub 120, and/or the sleeve member 130) may be
substantially equal to or greater than the inner diameter of the
casings 10, 20, 30 and/or the tubular members 40, 45 to which it is
attached when assembled.
[0019] As illustrated in FIG. 2, the sleeve member 130 is biased
into the closed position. When in the closed position, sealing
members 131, 132, 133, such as o-rings, close fluid communication
between the bore 105 of the valve assembly 100 and the annulus
surrounding the valve assembly 100. In particular, the sealing
members 131, 132, 133 seal fluid communication to a first port 115
and a second port 117 that are disposed through the body of the top
sub 110. The first port 115 is sealed on opposite sides by sealing
members 131 and 132. The second port 117 is sealed on opposite
sides by sealing members 132 and 133.
[0020] An external piston area 139, such as a shoulder portion, is
provided on the sleeve member 130 between sealing members 132 and
133 and is in fluid communication with the second port 117. An
internal piston area 135 is formed by an end of the sleeve member
130, which is in contact with the biasing member 140 and is in
fluid communication with the bore 105 of the valve assembly 100.
When the force on the internal piston area 135 is greater than the
force on the external piston area 139, the valve assembly 100 is
moved to the closed position as shown in FIG. 2. When the force on
the external piston area 139 is greater than the force on the
internal piston area 135, the valve assembly 100 is moved to the
open position as shown in FIG. 3.
[0021] In an optional embodiment, the sleeve member 130 may be
initially coupled to the top sub 110 and/or the bottom sub 120 by
one or more shearable members, such as shear pins 137 illustrated
in FIG. 2. The shear pins 137 may retain the sleeve member 130 in a
closed position to prevent inadvertent actuation of the sleeve
member 130 by a component(s), such as a drilling or production
string, that is moved through the bore 105 of the valve assembly
100 during a wellbore operation. The shear pins 137 may be sheared
by pressurizing the annulus surrounding the valve assembly 100 to
force the sleeve member 130 into the open position as described
herein. The force required to shear the shear pins 137 may be
greater than the force required to subsequently move the sleeve
member 130 to the open position. In one embodiment, a tool or other
downhole device may be lowered into the bore 105 of the valve
assembly 100 and into engagement with the sleeve member 130 to
apply a force sufficient to shear the shear pins 137.
[0022] FIG. 3 illustrates the valve assembly 100 in the open
position, where the bore 105 of the valve assembly 100 is in fluid
communication with the annulus surrounding the valve assembly 100
via the first port 115. The pressure in the annulus surrounding the
valve assembly 100 may generate a force on the external piston area
139 sufficient to overcome the force on the internal piston area
135. The force on the internal piston area 135 may include the
force from the biasing member 140, such as a spring force, plus the
force generated by any pressure within the bore 105 acting on the
internal piston area 135. The force on the external piston area 139
may move the sleeve member 130 to a position such that the first
port 115 is open to fluid communication with the bore 105 of the
valve assembly 100. In particular, the sealing member 131 is moved
across the first port 115 to open fluid communication.
[0023] Referring back to FIG. 1, the valve assembly 100 may be
operable to control fluid communication between the annulus A and
the annulus B. The annulus A surrounds the valve assembly 100, and
the annulus B is in fluid communication with the bore 105 of the
valve assembly 100. Pressure in the annulus A may act on the
external piston area 139 via the second port 117 to move the sleeve
member 130 against the force of the biasing member 140 and any
pressure force in the annulus B acting on the internal piston area
135. When the valve assembly 100 is open, pressurized fluid may
flow from the annulus A to the annulus B through the first port 115
of the valve assembly 100. The valve assembly 100 is thus operable
to relieve a pressure that may cause burst of a casing exterior to
the casing to which the valve assembly 100 is attached, and/or
collapse of a casing to which the valve assembly 100 is
attached.
[0024] When the pressure in the annulus A and the force acting on
the external piston area 139 decreases to a predetermined amount,
the biasing member 140 may move the sleeve member 130 back to the
closed position where the sealing members 131, 132 close fluid
communication to the first port 115. In this manner, the valve
assembly 100 is operable as a one-way valve in that it will permit
fluid flow into the bore 105 of the valve assembly 100 but will
prevent fluid flow out of the bore 105 via the first port 115. The
valve assembly 100 is automatically resettable downhole and may be
operated multiple times in response to any pressure fluctuations
within the wellbore 5. As stated above, any of the casings 10, 20,
30 and/or the tubular members 40, 45 may each be provided with one
or more valve assemblies 100 to allow fluid flow from a surrounding
casing or tubular member to an inner casing or tubular member,
while preventing fluid flow in the opposite direction. The valve
assembly 100 vents off collapse pressure from the outside of the
casings 10, 20, 30 and/or tubular members 40, 45 but allows
internal pressurization of the casings 10, 20, 30 and/or tubular
members 40, 45. The internal pressure holding integrity of the
casings 10, 20, 30 and/or tubular members 40, 45 is provided by the
seal formed between the top sub 110 and the sleeve member 130 with
the sealing members 131, 133.
[0025] In one embodiment, a casing 10, 20, 30 and/or tubular member
40, 45 may be provided with multiple valve assemblies 100 that are
spaced apart along the length of the casing or tubular member. The
valve assemblies 100 may be operable to open and/or close at
different pre-determined pressure setting. One or more of the valve
assemblies 100 may be operable to open when a first predetermined
pressure acts on the external piston area 139, while one or more of
the other valve assemblies 100 may be operable to open when a
second predetermined pressure acts on the external piston area 139.
The first predetermined pressure may be greater than, less than, or
equal to the second predetermined pressure.
[0026] In one embodiment, the valve assembly 100 may be operable to
open when a pressure differential across the valve assembly 100
exceeds a first predetermined value. The valve assembly 100 may be
operable to close when the pressure differential across the valve
assembly 100 decreases below a second predetermined value. The
first predetermined value may be greater than or equal to the
second predetermined value. For example, the valve assembly 100 may
include a detent mechanism and/or a collet assembly configured to
retain the valve assembly 100 in the open position until the
pressure differential across the valve assembly 100 decreases below
the second predetermined value. In one embodiment, the detent
mechanism may include a c-ring coupled to the sleeve member 130
that engages a shoulder of the top sub 110. When moved to the open
position, the sleeve member 130 may move the c-ring across the
shoulder with minimal resistance, but when moved to the closed
position, the sleeve member 130 may encounter a greater resistance
to move the c-ring across the shoulder. Other detent arrangements
may be use with the embodiments described herein.
[0027] While the foregoing is directed to embodiments of the
invention, other and further embodiments of the invention may be
devised without departing from the basic scope thereof, and the
scope thereof is determined by the claims that follow.
* * * * *