U.S. patent application number 13/973686 was filed with the patent office on 2015-02-26 for wellbore annular safety valve and method.
This patent application is currently assigned to Schlumberger Technology Corporation. The applicant listed for this patent is Schlumberger Technology Corporation. Invention is credited to Niek Dijkstra, Geir Meling, Bjoern Staale Varnes, Graham M. Watson, Eirik Windegaard.
Application Number | 20150053415 13/973686 |
Document ID | / |
Family ID | 51389918 |
Filed Date | 2015-02-26 |
United States Patent
Application |
20150053415 |
Kind Code |
A1 |
Windegaard; Eirik ; et
al. |
February 26, 2015 |
WELLBORE ANNULAR SAFETY VALVE AND METHOD
Abstract
A well system includes an annular barrier separating the
tubing-casing annulus into an upper annulus and a lower annulus and
a barrier valve coupled with the annular barrier, the barrier valve
permitting one-way fluid communication from the upper annulus to
the lower annulus. The annular barrier may include a female
polished bore receptacle integrated in the casing and a male seal
assembly integrated in the tubing. The tubing bore and an annular
fluid conduit extend through the male seal assembly substantially
parallel to one another and the barrier valve is connected in the
annular fluid conduit.
Inventors: |
Windegaard; Eirik; (Dusavik,
NO) ; Varnes; Bjoern Staale; (Tau, NO) ;
Dijkstra; Niek; (Madrid, ES) ; Meling; Geir;
(Hafrsfjord, NO) ; Watson; Graham M.; (Sugar Land,
TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Schlumberger Technology Corporation |
Sugar Land |
TX |
US |
|
|
Assignee: |
Schlumberger Technology
Corporation
Sugar Land
TX
|
Family ID: |
51389918 |
Appl. No.: |
13/973686 |
Filed: |
August 22, 2013 |
Current U.S.
Class: |
166/373 ;
166/184 |
Current CPC
Class: |
E21B 43/123 20130101;
E21B 33/1294 20130101; E21B 34/10 20130101; E21B 34/06 20130101;
E21B 43/12 20130101; E21B 34/105 20130101 |
Class at
Publication: |
166/373 ;
166/184 |
International
Class: |
E21B 43/12 20060101
E21B043/12; E21B 34/06 20060101 E21B034/06 |
Claims
1. A well system, comprising: a wellbore extending downward from a
surface, the wellbore comprising a tubing deployed in a casing; an
annular barrier disposed in a tubing-casing annulus of a wellbore
separating the tubing-casing annulus into an upper annulus and a
lower annulus; and a barrier valve coupled with the annular
barrier, the barrier valve permitting one-way fluid communication
from the upper annulus to the lower annulus.
2. The well system of claim 1, wherein the annular barrier is a
polished bore receptacle.
3. The well system of claim 1, wherein the annular barrier
comprises: a female polished bore receptacle integrated in the
casing; and a male seal assembly integrated in the tubing.
4. The well system of claim 1, further comprising a control line
passing through the annular barrier.
5. The well system of claim 1, wherein the barrier valve is
disposed in a side pocket mandrel integrated in the tubing.
6. The well system of claim 1, wherein the barrier valve is located
above the annular barrier.
7. The well system of claim 1, wherein the barrier valve is
operated to an open position in response to pressure in the upper
annulus being greater than pressure in the lower annulus.
8. The well system of claim 1, wherein the barrier valve is located
in a side pocket mandrel integrated in the tubing; and the polished
bore receptacle comprises: a female polished bore receptacle
integrated in the casing; and a male seal assembly integrated in
the tubing.
9. The well system of claim 8, further comprising gas lift valves
located in the tubing below the annular barrier.
10. The well system of claim 9, further comprising a control line
extending from above the annular barrier through the annular
barrier to a device located below the annular barrier.
11. An annular safety valve, comprising: a male seal assembly
integrated in a tubing, wherein a tubing bore extends through the
male seal assembly; a fluid conduit extending through a body of the
male seal assembly substantially parallel to the tubing bore; a
female polished bore receptacle integrated in a casing to receive
the male seal assembly and form an annular barrier between the
tubing and the casing; and a barrier valve in connection with the
fluid conduit to permit one-way fluid flow through the fluid
conduit.
12. The annular safety valve of claim 11, wherein the barrier valve
is disposed in a side pocket mandrel integrated in the tubing.
13. The annular safety valve of claim 11, wherein the seal assembly
comprises a port formed longitudinally through the body to pass a
control line across the male seal assembly.
14. The annular safety valve of claim 11, wherein the barrier valve
is normally closed.
15. A method, comprising: setting a casing in a wellbore, the
casing comprising a female polished bore receptacle; deploying a
tubing in the casing, the tubing comprising a male seal assembly
landed in the female polished bore receptacle forming an annular
barrier across a tubing-casing annulus separating the tubing-casing
annulus into an upper annulus and a lower annulus, wherein the male
seal assembly comprises a fluid conduit extending substantially
parallel to a tubing bore, and a barrier valve coupled with the
fluid conduit to permit fluid flow from the upper annulus to the
lower annulus; communicating a fluid from the upper annulus through
the barrier valve to the lower annulus; and closing the barrier
valve in response to pressure in the upper annulus being less than
pressure in the lower annulus.
16. The method of claim 15, wherein the fluid is a pressurized gas
and further comprising injecting the pressurized gas from the lower
annulus through a gas lift valve into the tubing.
17. The method of claim 15, further comprising a control line
extending from the upper annulus through a body of the male seal
assembly to a device located below the annular barrier.
18. The method of claim 15, wherein the barrier valve is located in
a side pocket mandrel integrated in the tubing.
19. The method of claim 15, wherein the barrier valve is normally
closed and the barrier valve is opened in response to pressure in
the upper annulus being greater than pressure in the lower
annulus.
20. The method of claim 17, wherein: the barrier valve is located
in a side pocket mandrel integrated in the tubing; the fluid is a
pressurized gas; and further comprising injecting the pressurized
gas from the lower annulus through a gas lift valve into the
tubing.
Description
BACKGROUND
[0001] This section provides background information to facilitate a
better understanding of the various aspects of the disclosure. It
should be understood that the statements in this section of this
document are to be read in this light, and not as admissions of
prior art.
[0002] Hydrocarbon fluids such as oil and natural gas are obtained
from a subterranean geological formation, referred to as a
reservoir, by drilling a well that penetrates the
hydrocarbon-bearing formation. Forms of well completion components
may be installed in the wellbore to control and enhance efficiency
of producing fluids from the reservoir.
SUMMARY
[0003] A well system in accordance to one or more embodiments
includes an annular barrier disposed in a tubing-casing annulus of
a wellbore separating the tubing-casing annulus into an upper
annulus and a lower annulus and a barrier valve coupled with the
annular barrier, the barrier valve permitting one-way fluid
communication from the upper annulus to the lower annulus. An
annular safety valve in accordance with an embodiment includes a
male seal assembly integrated in a tubing, a tubing bore and a
fluid conduit extending through the body substantially parallel to
one another, a female polished bore receptacle integrated in a
casing to receive the male seal assembly and form an annular
barrier between the tubing and the casing, and a barrier valve in
connection with the fluid conduit to permit one-way fluid flow
through the fluid conduit. A method includes setting casing having
a female polished bore receptacle in a wellbore, deploying tubing
having a male seal assembly landed in the female polished bore
receptacle forming an annular barrier separating the tubing-casing
annulus into an upper annulus and a lower annulus, communicating
fluid from the upper annulus through a barrier valve in connection
with a fluid conduit through the male seal assembly and closing the
barrier valve in response to pressure in the upper annulus being
lower than the pressure in the lower annulus.
[0004] The foregoing has outlined some of the features and
technical advantages in order that the detailed description of the
annular safety valves, systems, and methods that follow may be
better understood. Additional features and advantages of the
annular safety valve system and method will be described
hereinafter which form the subject of the claims of the invention.
This summary is not intended to identify key or essential features
of the claimed subject matter, nor is it intended to be used as an
aid in limiting the scope of claimed subject matter.
BRIEF DESCRIPTION OF THE DRAWINGS
[0005] Embodiments of annular safety valves and methods are
described with reference to the following figures. The same numbers
are used throughout the figures to reference like features and
components. It is emphasized that, in accordance with standard
practice in the industry, various features are not necessarily
drawn to scale. In fact, the dimensions of various features may be
arbitrarily increased or reduced for clarity of discussion.
[0006] FIG. 1 illustrates a well system in which an annular safety
valve in accordance to one or more embodiments is incorporated.
[0007] FIG. 2 illustrates an annular safety valve in accordance to
one or more embodiments.
[0008] FIG. 3 illustrates a male polished bore receptacle seal
assembly in accordance to one or more embodiments.
[0009] FIG. 4 is a top view illustration of a male polished bore
receptacle seal assembly in accordance to one or more
embodiments.
[0010] FIG. 5 illustrates a side pocket mandrel in accordance to
one or more embodiments.
[0011] FIG. 6 illustrates a side pocket mandrel along the line I-I
of FIG. 5.
[0012] FIG. 7 illustrates a barrier valve in accordance to one or
more embodiments.
DETAILED DESCRIPTION
[0013] It is to be understood that the following disclosure
provides many different embodiments, or examples, for implementing
different features of various embodiments. Specific examples of
components and arrangements are described below to simplify the
disclosure. These are, of course, merely examples and are not
intended to be limiting. In addition, the disclosure may repeat
reference numerals and/or letters in the various examples. This
repetition is for the purpose of simplicity and clarity and does
not in itself dictate a relationship between the various
embodiments and/or configurations discussed.
[0014] As used herein, the terms "connect," "connection,"
"connected," "in connection with," and "connecting" are used to
mean "in direct connection with" or "in connection with via one or
more elements"; and the term "set" is used to mean "one element" or
"more than one element." Further, the terms "couple," "coupling,"
"coupled," "coupled together," and "coupled with" are used to mean
"directly coupled together" or "coupled together via one or more
elements." As used herein, the terms "up" and "down," "upper" and
"lower," "top" and "bottom," and other like terms indicating
relative positions to a given point or element are utilized to more
clearly describe some elements. Commonly, these terms relate to a
reference point as the surface from which drilling operations are
initiated as being the top point and the total depth being the
lowest point, wherein the well (e.g., wellbore, borehole) is
vertical, horizontal or slanted relative to the surface.
[0015] Generally, a well consists of a wellbore drilled through one
or more reservoir production zones. Conductor casing serves as
support during drilling operations and provides support for a
wellhead and Christmas tree. In offshore wells, a riser may extend
the wellbore from the sea floor to the surface platform. One or
more strings of casing with diminishing inside diameters will be
run inside of the conductor. The well may then be completed with a
tubing string extending to the one or more reservoir production
zones. The annulus between the tubing and the smallest diameter
casing, i.e., the A-annulus, extends from the producing zones to
the surface. The surface barrier seals the tubing-casing annulus
from the environment. The tubing may be landed for example in a
production packer located above the upper most production zone to
isolate the annulus from the producing zones. The tubing-casing
annulus may extend thousands of feet from the surface to the
production packer. The tubing-casing annulus may be utilized for
example for gas-injection into the tubing to reduce the density of
the fluid in the tubing to facilitate production to the surface.
The tubing-casing annulus may be exposed to the surrounding
formations via perforations or loss of casing integrity. In the
case of failure of the surface annular barrier, for example located
at the wellhead, wellbore fluid in the tubing-casing annulus will
be in communication with the environment.
[0016] In accordance to one or more embodiments, an annular safety
valve is integrated in the completion to provide an annular safety
barrier in the upper completion. In accordance with embodiments,
the annular safety valve provides one-way fluid flow from the upper
annulus to the lower annulus. In accordance to one or more
embodiments, the annular safety valve provides one or more control
line bypasses to operationally connect devices in the lower
completion below the annular safety valve to surface control
systems at the surface or in the upper completion above the annular
safety valve. In accordance to one or more embodiments, the annular
safety valve is not surface controlled.
[0017] FIG. 1 illustrates a well system 5 in which a polished bore
receptacle ("PBR") based subsurface annular safety valve ("ASV"),
generally denoted by the numeral 10, may be incorporated and
utilized. Annular safety valve 10 includes a one-way barrier valve
12 coupled with an annular barrier 14. In accordance with
embodiments, annular barrier 14 is referred to as a polished bore
receptacle ("PBR") barrier 14. PBR 14 provides a sealed annular
barrier between the tubing and casing. Barrier valve 12 is
illustrated as being located above PBR 14 in FIG. 1, however, as
will be understood by those skilled in the art with benefit of this
disclosure, barrier valve 12 may be locate below PBR 14. Barrier
valve 12 provides one-way fluid flow in the direction from the
upper completion or upper annulus across PBR 14 to the lower
completion or lower annulus. In accordance to one or more
embodiments, barrier valve 12 is normally closed and actuated to
the open position in response to pressure in the upper annulus
being greater than pressure in the lower annulus. Similarly,
barrier valve 12 is actuated to the closed position in response to
pressure in the lower annulus exceeding pressure in the upper
annulus.
[0018] Well system 5 is illustrated as a gas lift completion that
includes tubing 16 that extends from an upper or surface barrier 18
into a wellbore 20. A portion of wellbore 20 is completed with
casing 22. The tubing-casing annulus, generally denoted by the
numeral 24, between tubing 16 and casing 22 may be referred to as
the A-annulus. Surface barrier 18, for example a tubing hanger, is
depicted in FIG. 1 located at a water surface 26, for example at a
platform, e.g., tension leg platform, or ship, positioned above a
sea floor 28. Surface barrier 18 may be located in the wellhead
area. Reference to the surface of the well is not limited to the
sea surface or sea floor. Annular safety valve 10 is set in the
upper completion and separates tubing-casing annulus 24 into an
upper annulus 23 and a lower annulus 25. Lower annulus 25 may be
isolated from a production zone 7, i.e., reservoir formation, by a
production packer 9.
[0019] Tubing 16 incorporates one or more gas lift valves 30 which
are located in the lower tubing section 17 below annular safety
valve 10 in wellbore 20. For purposes of gas injection, well system
5 includes a gas compressor 32 located at the surface to pressurize
gas that is communicated to tubing-casing annulus 24. The
pressurized gas 34 is communicated from upper annulus 23 through
annular safety valve 10 to lower annulus 25. The pressurized gas 34
is communicated from lower annulus 25 into tubing bore 36 through
gas lift valves 30.
[0020] One or more control lines 38 may extend from a surface
system 40, for example an electronic controller and or pressurized
fluid source, to downhole devices, generally denoted by the numeral
42, located below annular safety valve 10. Downhole devices 42 may
include devices such as, and without limitation to, pressure,
temperature, and flow rate sensors 43, chemical injection valves
45, and flow control valves 47. In accordance to one or more
embodiments, annular safety valve 10 provides control line bypasses
from the upper completion or surface to the lower completion while
maintaining an annular barrier. Control lines 38 may include,
without limitation, electrical and optic cables as well as
hydraulic and chemical conduits.
[0021] Together, annular safety valve 10 and tubing 16 can serve as
a primary barrier to maintain well integrity. In the depicted
embodiment, a downhole safety valve 44 is located in the upper
section 15 of tubing 16 to provide a vertical barrier through
tubing bore 36. In this example, downhole safety valve 44 is a
surface controlled subsurface safety valve ("SCSSV") connected to
the surface via a control line 38. Annular safety valve 10 serves
as a safety barrier in A-annulus 24 in the event that surface
barrier 18 is lost. Lower annulus 25 although located above
production packer 9 in FIG. 1, may be in communication with
formation fluids and pressure. For example, perforations or loss
integrity of casing 22 may expose annulus 25 to the surrounding
formation 46. In FIG. 1, gas lift injection through lower annulus
25 may temporarily supercharge formation 46.
[0022] With additional reference to FIGS. 2 to 4, polished bore
receptacle 14 includes a female PBR 48 integrated in casing 22 and
a male PBR 50 integrated in tubing 16. Female PBR 48 includes a
smooth or honed bore formed on the inner surface of casing 22 and
has a predetermined diameter for sealing or mating with male PBR
50. Female PBR 48 is depicted disposed above casing cross-over 27.
Female PBR 48 may be constructed as portion of casing cross-over
27. Tubing 16 may be anchored to casing 22 for example proximate to
female PBR 48.
[0023] Depicted male PBR 50 (e.g., seal assembly) is an eccentric
member having one or more seal elements 52. Male seal assembly 50
is integrated with tubing 16 so that the tubing bore 36 extends
through male seal assembly 50. Bypass ports, generally denoted by
the reference number 60, are formed longitudinally through male PBR
50, for example substantially parallel to tubing bore 36, to pass
or form a portion of annular fluid conduit 54 and control lines 38
in the depicted embodiment. Barrier valve 12 is coupled with fluid
conduit 54 to provide one-way fluid communication across PBR 14,
i.e., upper annulus to lower annulus fluid flow. For example, ports
60 are formed through the thicker body portion 58 of male PBR 50
between tubing bore 36 and seal elements 52. As will be understood
by those skilled in the art with benefit of this disclosure,
annular safety valve 10 may be utilized in well systems 5 that do
not have gas injection.
[0024] With reference in particular to FIGS. 1-2 and 5-6, barrier
valve 12 is a one-way valve providing fluid connection across
polished bore receptacle 14 from upper annulus 23 to lower annulus
25 through passage or conduit 54. Although barrier valve 12 is
illustrated located above PBR 14 in FIGS. 1 and 2, it will be
understood by those skilled in the art with benefit of this
disclosure that barrier valve 12 can be located below PBR 14 to
provide fluid communication in the direction from upper annulus 23
to lower annulus 25.
[0025] In accordance to one or more embodiments, barrier valve 12
is located in a side pocket mandrel 56 integrated, i.e., connected,
with tubing 16. Barrier valve 12 is disposed in pocket 62 (FIG. 6)
to provide annulus to annulus fluid communication. Fluid, such as
gas 34, flows from upper annulus 23 through port(s) 64 into pocket
62 and through barrier valve 12 into conduit 54 and lower annulus
25. Side pocket mandrel 56 may not include a port between
tubing-casing annulus 24 and tubing bore 36 or the tubing bore may
not be in communication with tubing-casing annulus 24 through
barrier valve 12. Side pocket mandrel 56 may be a single or a dual
pocket mandrel.
[0026] FIG. 7 illustrates a gas lift type barrier valve 12 in
accordance to one or more embodiments. Barrier valve 12 includes a
reverse flow check valve 66 suited for barrier applications. For
example, barrier valve 12 is a barrier-qualified, reverse flow
check valve that provides positive seal between the lower annulus
side and the upper annulus side. In accordance to one or more
embodiments, barrier valve 12 has metal-to-meal seal surfaces
without elastomers. Some embodiments may have elastomer seal
surfaces. A non-limiting example of barrier valve 12 is a NOVA 15-B
type of gas lift valve available from Schlumberger.
[0027] In accordance to one or more embodiments, a surface control
system is not required for operation of annular safety valve 10.
Barrier valve 12 may be retrieved, for example via wireline or
slickline, eliminating the need to retrieve the completion to
maintain the well integrity. If the pressure in lower annulus 25
exceeds the pressure in upper annulus 23, barrier valve 12 closes.
Accordingly, barrier valve 12 fails safe closed if the surface
barrier is lost. Annular safety valve 10 is insensitive to setting
depth. In accordance with one or more embodiments, barrier valve 12
may be eliminated for example by eliminating or plugging conduit
54. For example, a dummy valve may be landed in pocket 62 to plug
conduit 54.
[0028] A method in accordance to one or more embodiments is now
described with reference to FIGS. 1-7. Casing 22 having a female
polished bore receptacle 48 is set in wellbore 20. Tubing 16 is
deployed landing integrated male seal assembly 50 in the female
polished bore receptacle forming an annular barrier 14 across a
tubing-casing annulus 24, the annular barrier separating the
tubing-casing annulus into an upper annulus 23 and a lower annulus
25. Male seal assembly 50 includes a fluid conduit 54 extending
substantially parallel to tubing bore 36. Barrier valve 12 is
coupled with the fluid conduit to permit fluid, for example gas 34,
to flow from the upper annulus to the lower annulus. Fluid 34 is
communicated from the upper annulus through the barrier valve and
across the annular barrier in response to pressure in the upper
annulus being greater than pressure in the lower annulus. The
barrier valve is closed in response to the pressure in the upper
annulus being less than the pressure in the lower annulus.
[0029] The foregoing outlines features of several embodiments of
annular safety valves, systems, and methods so that those skilled
in the art may better understand the aspects of the disclosure.
Those skilled in the art should appreciate that they may readily
use the disclosure as a basis for designing or modifying other
processes and structures for carrying out the same purposes and/or
achieving the same advantages of the embodiments introduced herein.
Those skilled in the art should also realize that such equivalent
constructions do not depart from the spirit and scope of the
disclosure, and that they may make various changes, substitutions
and alterations herein without departing from the spirit and scope
of the disclosure. The scope of the invention should be determined
only by the language of the claims that follow. The term
"comprising" within the claims is intended to mean "including at
least" such that the recited listing of elements in a claim are an
open group. The terms "a," "an" and other singular terms are
intended to include the plural forms thereof unless specifically
excluded.
* * * * *