U.S. patent application number 14/026170 was filed with the patent office on 2015-03-19 for system and method for separating gaseous material from formation fluids.
This patent application is currently assigned to TriAxon Oil Corp.. The applicant listed for this patent is TriAxon Oil Corp.. Invention is credited to Robbie Singh Hari, Jeffrey Charles Saponja.
Application Number | 20150075772 14/026170 |
Document ID | / |
Family ID | 52666905 |
Filed Date | 2015-03-19 |
United States Patent
Application |
20150075772 |
Kind Code |
A1 |
Saponja; Jeffrey Charles ;
et al. |
March 19, 2015 |
System and Method for Separating Gaseous Material From Formation
Fluids
Abstract
There is provided a system for effecting production of formation
fluids from a subterranean formation. The system includes a gas
anchor for mitigating gas lock. Sealing engagement of the gas
anchor against the wellbore tubular is effected without use of a
conventional packer, which would otherwise be susceptible to
receiving debris deposited from the formation fluid, which thereby
results in the packer, as well as the gas anchor, becoming
vulnerable to becoming stuck within the wellbore tubular.
Inventors: |
Saponja; Jeffrey Charles;
(Calgary, CA) ; Hari; Robbie Singh; (Calgary,
CA) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
TriAxon Oil Corp. |
Calgary |
|
CA |
|
|
Assignee: |
TriAxon Oil Corp.
Calgary
CA
|
Family ID: |
52666905 |
Appl. No.: |
14/026170 |
Filed: |
September 13, 2013 |
Current U.S.
Class: |
166/115 |
Current CPC
Class: |
E21B 43/121 20130101;
E21B 23/00 20130101; E21B 33/10 20130101; E21B 43/38 20130101; E21B
43/10 20130101 |
Class at
Publication: |
166/115 |
International
Class: |
E21B 43/12 20060101
E21B043/12; E21B 33/00 20060101 E21B033/00; E21B 17/00 20060101
E21B017/00 |
Claims
1. A system for effecting production of formation fluid from a
subterranean formation, comprising: a wellbore tubular disposed
within a wellbore, wherein the wellbore tubular includes a
receptacle portion, wherein the receptacle portion includes a
receptacle sealing surface; a production tubular, disposed within
the wellbore tubular, including: a formation fluid-receiving
conduit portion, defining a formation fluid-receiving fluid passage
portion for receiving the formation fluid, and including a sealing
member-engaging surface portion; a gas separator portion configured
to co-operate with at least the wellbore tubular for effecting
separation of at least a fraction of gaseous material, that is
entrained within the received formation fluid, from the received
formation fluid to generate a gaseous material-depleted formation
fluid; a gaseous material-depleted fluid formation conduit defining
a gaseous material-depleted formation fluid conducting-fluid
passage portion for conducting a flow of the gaseous
material-depleted formation fluid to the surface; and a prime mover
disposed for inducing flow of the formation fluid from a
subterranean formation and into the formation fluid-receiving fluid
passage portion, and for receiving and energizing the gaseous
material-depleted formation fluid to flow through the gaseous
material-depleted formation fluid conducting-fluid passage portion
to the surface; and a sealing member disposed between the sealing
member-engaging surface portion and the receptacle sealing surface
for effecting a seal between at least the sealing member-engaging
surface portion and the receptacle sealing surface, for preventing,
or substantially preventing, flow of the formation fluid between at
least the sealing member-engaging external surface portion and the
receptacle sealing surface; wherein the co-operation between the
gas separator portion and at least the wellbore tubular is with
effect that, while the flow of the formation fluid is being induced
by the prime mover and received through the formation
fluid-receiving fluid passage portion, flowing of the received
formation fluid is directed through a gas separator annulus
disposed between the gas separator portion and the wellbore
tubular, in a direction opposite to that which the formation fluid
is flowing while being received by the formation fluid-receiving
fluid passage portion of the formation fluid-receiving conduit
portion of the production tubular, prior to being received by the
prime mover, and the formation fluid flowing through the gas
separator annulus is prevented, or substantially prevented, from
returning to the formation fluid-receiving fluid passage portion of
the formation fluid-receiving conduit portion of the production
tubular by the effected seal between at least the sealing
member-engaging surface portion of the formation fluid-receiving
conduit portion of the production tubular and the receptacle
sealing surface of the receptacle portion of the wellbore tubular,
wherein, while the flowing of the received formation fluid is being
directed through the gas separator annulus, the at least a fraction
of the entrained gaseous material becomes separated, in response to
buoyancy forces, from the received formation fluid that is being
directed through the gas separator annulus; and wherein the
receptacle sealing surface is disposed less than a distance "D" of
2.5 millimetres from the sealing member-engaging surface
portion.
2. The system as claimed in claim 1; wherein the wellbore tubular
includes a casing, and the receptacle portion is defined by an
inwardly extending protrusion of the casing.
3. The system as claimed in claim 1; wherein the wellbore tubular
includes: a casing string; a liner string, coupled to the casing
string, the liner string including: a polished bore receptacle that
includes the receptacle portion; and a sealing surface, sealingly
engaged to the casing string for preventing, or substantially
preventing, flow of formation fluid between the sealing surface and
the casing string; and wherein the production tubular is disposed
within the polished bore receptacle.
4. The system as claimed in claim 3; wherein the coupling of the
liner string to the casing string is by way of hanging of the liner
string to the casing string.
5. The system as claimed in claim 3; wherein the sealing member is
disposed in sealing engagement with both of the sealing
member-engaging surface portion and the receptacle sealing surface,
and urging of the sealing engagement is effected with a seal latch
assembly.
6. The process as claimed in claim 3; wherein the casing string
includes a packer for effecting the sealing engagement between the
sealing surface of the liner string and the casing string.
7. The system as claimed in claim 1; further comprising: a
conducting annulus disposed between the production tubular and the
wellbore tubular and configured to receive and conduct the
separated gaseous material to the surface; wherein the gas
separator annulus is disposed in vertical alignment with the
conducting annulus.
8. The system as claimed in claim 1; wherein the gas separator
further co-operates with the wellbore tubular with effect that the
received formation fluid flow being flowed through the gas
separator annulus is flowing in a downwardly direction.
9. The system as claimed in claim 1; wherein the disposition of the
wellbore tubular relative to the wellbore is with effect that the
effected fluid communication between the formation fluid-receiving
fluid passage portion of the production tubular and the
subterranean formation treatment zone is isolated, or substantially
isolated, from at least one other zone of the subterranean
formation.
10. The system as claimed in claim 1; wherein the prime mover is
disposed within a horizontal wellbore portion of the wellbore.
11. The system as claimed in claim 1; wherein the production
tubular is releasably secured to the wellbore tubular.
12. The system as claimed in claim 1; wherein the production
tubular is disposed in an interference fit relationship with the
wellbore tubular.
13. The system as claimed in claim 1; wherein the sealing member is
coupled to the production tubular.
14. The system as claimed in claim 1; wherein the sealing member is
carried by the production tubular.
15. A system for effecting production of formation fluids from a
subterranean formation, comprising: a wellbore tubular disposed
within a wellbore, wherein the wellbore tubular includes: a casing
string; a liner string, coupled to the casing string, the liner
string including: a polished bore receptacle that includes a
receptacle portion, wherein the receptacle portion includes a
receptacle sealing surface; and a sealing surface, sealingly
engaged to the casing string for preventing, or substantially
preventing, flow of formation fluid between the sealing surface and
the casing string; and a production tubular, disposed within the
wellbore tubular, including: a formation fluid-receiving conduit
portion, defining a formation fluid-receiving fluid passage portion
for receiving the formation fluid, and including a sealing surface
disposed in sealing engagement with the receptacle sealing surface
for preventing, or substantially preventing, flow of the formation
fluids between the sealing surface and the receptacle sealing
surface; a gas separator portion configured to co-operate with at
least the wellbore tubular for effecting separation of at least a
fraction of gaseous material, that is entrained within the received
formation fluid, from the received formation fluid to generate a
gaseous material-depleted formation fluid; a gaseous
material-depleted fluid formation conduit defining a gaseous
material-depleted formation fluid conducting-fluid passage portion
for conducting a flow of the gaseous material-depleted formation
fluid to the surface; and a prime mover disposed for inducing flow
of the formation fluid from a subterranean formation and into the
formation fluid-receiving fluid passage portion, and for receiving
and energizing the gaseous material-depleted formation fluid to
flow through the gaseous material-depleted formation fluid
conducting-fluid passage portion to the surface; wherein the
co-operation between the gas separator portion and at least the
wellbore tubular is with effect that, while the flow of the
formation fluid is being induced by the prime mover and received
through the formation fluid-receiving fluid passage portion,
flowing of the received formation fluid is directed through a gas
separator annulus disposed between the gas separator portion and
the wellbore tubular, in a direction opposite to that which the
formation fluid is flowing while being received by the formation
fluid-receiving fluid passage portion of the formation
fluid-receiving conduit portion of the production tubular, prior to
being received by the prime mover, and the formation fluid flowing
through the gas separator annulus is prevented, or substantially
prevented, from returning to the formation fluid-receiving fluid
passage portion of the formation fluid-receiving conduit portion of
the production tubular by at least the sealing engagement between
the sealing surface of the formation fluid-receiving conduit
portion of the production tubular and the receptacle sealing
surface of the receptacle portion of the wellbore tubular, wherein,
while the flowing of the received formation fluid is being directed
through the gas separator annulus, the at least a fraction of the
entrained gaseous material becomes separated, in response to
buoyancy forces, from the received formation fluid that is being
directed through the gas separator annulus.
16. The system as claimed in claim 15; wherein the production
tubular is disposed within the polished bore receptacle, and urging
of the sealing engagement between the sealing surface of the
formation fluid-receiving conduit portion of the production tubular
and the receptacle sealing surface of the receptacle portion of the
polished bore receptacle is effected with a seal latch
assembly.
17. The system as claimed in claim 15; wherein the coupling of the
liner string to the casing string is by way of hanging of the liner
string to the casing string.
18. The system as claimed in claim 15; wherein the production
tubular is releasably secured to the wellbore tubular.
19. The system as claimed in claim 15; wherein the production
tubular is disposed in an interference fit relationship with the
wellbore tubular.
20. The system as claimed in claim 19; wherein the interference fit
relationship is effected between the sealing surface of the
formation fluid-receiving conduit portion of the production tubular
and the receptacle sealing surface of the receptacle portion of the
wellbore tubular.
21. A system for effecting production of formation fluids from a
subterranean formation, comprising: a wellbore tubular disposed
within a wellbore, wherein the wellbore tubular includes a casing,
wherein the casing includes a receptacle portion, wherein the
receptacle portion is defined by an inwardly extending protrusion
of the casing and includes a receptacle sealing surface; and a
production tubular, disposed within the wellbore tubular,
including: a formation fluid-receiving conduit portion, defining a
formation fluid-receiving fluid passage portion for receiving the
formation fluid, and including a sealing surface disposed in
sealing engagement with the receptacle sealing surface for
preventing, or substantially preventing, flow of the formation
fluids between the sealing surface and the receptacle sealing
surface; a gas separator portion configured to co-operate with at
least the wellbore tubular for effecting separation of at least a
fraction of gaseous material, that is entrained within the received
formation fluid, from the received formation fluid to generate a
gaseous material-depleted formation fluid; a gaseous
material-depleted fluid formation conduit defining a gaseous
material-depleted formation fluid conducting-fluid passage portion
for conducting a flow of the gaseous material-depleted formation
fluid to the surface; and a prime mover disposed for inducing flow
of the formation fluid from a subterranean formation and into the
formation fluid-receiving fluid passage portion, and for receiving
and energizing the gaseous material-depleted formation fluid to
flow through the gaseous material-depleted formation fluid
conducting-fluid passage portion to the surface; wherein the
co-operation between the gas separator portion and at least the
wellbore tubular is with effect that, while the flow of the
formation fluid is being induced by the prime mover and received
through the formation fluid-receiving fluid passage portion,
flowing of the received formation fluid is directed through a gas
separator annulus disposed between the gas separator portion and
the wellbore tubular, in a direction opposite to that which the
formation fluid is flowing while being received by the formation
fluid-receiving fluid passage portion of the formation
fluid-receiving conduit portion of the production tubular, prior to
being received by the prime mover, and the formation fluid flowing
through the gas separator annulus is prevented, or substantially
prevented, from returning to the formation fluid-receiving fluid
passage portion of the formation fluid-receiving conduit portion of
the production tubular by at least the sealing engagement between
the sealing surface of the formation fluid-receiving conduit
portion of the production tubular and the receptacle sealing
surface of the receptacle portion of the wellbore tubular, wherein,
while the flowing of the received formation fluid is being directed
through the gas separator annulus, the at least a fraction of the
entrained gaseous material becomes separated, in response to
buoyancy forces, from the received formation fluid that is being
directed through the gas separator annulus.
22. The system as claimed in claim 21; wherein the receptacle
portion defines a constricted passage within the casing.
23. The system as claimed in claim 21; wherein the production
tubular is releasably secured to the wellbore tubular.
24. The system as claimed in claim 21; wherein the production
tubular is disposed in an interference fit relationship with the
wellbore tubular.
25. The system as claimed in claim 24; wherein the interference fit
relationship is effected between the sealing surface of the
formation fluid-receiving conduit portion of the production tubular
and the receptacle sealing surface of the receptacle portion of the
wellbore tubular.
26-68. (canceled)
Description
FIELD
[0001] The present disclosure relates to production of formation
fluids, and, in particular, separating gaseous material that is
entrained within the formation fluids.
BACKGROUND
[0002] Gas lock is a problem encountered while producing wells,
especially wells with horizontal portions. Packer-type gas anchors
are provided to remedy gas lock. However, packer-type gas anchors
are relatively expensive. Further, the packers on packer-type gas
anchors are susceptible to having debris accumulate thereon and, as
a result, becoming stuck within the wellbore tubular against which
it forms a seal. This makes it difficult to remove production
tubing from the wellbore, such as during a workover. Such attempt
at removal may also damage the packer, thereby rendering the
packer-type gas anchor unusable for future production.
SUMMARY
[0003] In one aspect there is provided a system for effecting
production of formation fluid from a subterranean formation,
comprising:
a wellbore tubular disposed within a wellbore, wherein the wellbore
tubular includes a receptacle portion, wherein the receptacle
portion includes a receptacle sealing surface; a production
tubular, disposed within the wellbore tubular, including:
[0004] a formation fluid-receiving conduit portion, defining a
formation fluid-receiving fluid passage portion for receiving the
formation fluid, and including a sealing member-engaging surface
portion;
[0005] a gas separator portion configured to co-operate with at
least the wellbore tubular for effecting separation of at least a
fraction of gaseous material, that is entrained within the received
formation fluid, from the received formation fluid to generate a
gaseous material-depleted formation fluid;
[0006] a gaseous material-depleted fluid formation conduit defining
a gaseous material-depleted formation fluid conducting-fluid
passage portion for conducting a flow of the gaseous
material-depleted formation fluid to the surface; and
[0007] a prime mover disposed for inducing flow of the formation
fluid from a subterranean formation and into the formation
fluid-receiving fluid passage portion, and for receiving and
energizing the gaseous material-depleted formation fluid to flow
through the gaseous material-depleted formation fluid
conducting-fluid passage portion to the surface;
and a sealing member disposed between the sealing member-engaging
surface portion and the receptacle sealing surface for effecting a
seal between at least the sealing member-engaging surface portion
and the receptacle sealing surface, for preventing, or
substantially preventing, flow of the formation fluid between at
least the sealing member-engaging external surface portion and the
receptacle sealing surface; wherein the co-operation between the
gas separator portion and at least the wellbore tubular is with
effect that, while the flow of the formation fluid is being induced
by the prime mover and received through the formation
fluid-receiving fluid passage portion, flowing of the received
formation fluid is directed through a gas separator annulus
disposed between the gas separator portion and the wellbore
tubular, in a direction opposite to that which the formation fluid
is flowing while being received by the formation fluid-receiving
fluid passage portion of the formation fluid-receiving conduit
portion of the production tubular, prior to being received by the
prime mover, and the formation fluid flowing through the gas
separator annulus is prevented, or substantially prevented, from
returning to the formation fluid-receiving fluid passage portion of
the formation fluid-receiving conduit portion of the production
tubular by the effected seal between at least the sealing
member-engaging surface portion of the formation fluid-receiving
conduit portion of the production tubular and the receptacle
sealing surface of the receptacle portion of the wellbore tubular,
wherein, while the flowing of the received formation fluid is being
directed through the gas separator annulus, the at least a fraction
of the entrained gaseous material becomes separated, in response to
buoyancy forces, from the received formation fluid that is being
directed through the gas separator annulus; and wherein the
receptacle sealing surface is disposed less than a distance "D" of
2.5 millimetres from the sealing member-engaging surface
portion.
[0008] In another aspect there is provided a system for effecting
production of formation fluids from a subterranean formation,
comprising:
a wellbore tubular disposed within a wellbore, wherein the wellbore
tubular includes:
[0009] a casing string;
[0010] a liner string, coupled to the casing string, the liner
string including: [0011] a polished bore receptacle that includes a
receptacle portion, wherein the receptacle portion includes a
receptacle sealing surface; and [0012] a sealing surface, sealingly
engaged to the casing string for preventing, or substantially
preventing, flow of formation fluid between the sealing surface and
the casing string; and a production tubular, disposed within the
wellbore tubular, including:
[0013] a formation fluid-receiving conduit portion, defining a
formation fluid-receiving fluid passage portion for receiving the
formation fluid, and including a sealing surface disposed in
sealing engagement with the receptacle sealing surface for
preventing, or substantially preventing, flow of the formation
fluids between the sealing surface and the receptacle sealing
surface;
[0014] a gas separator portion configured to co-operate with at
least the wellbore tubular for effecting separation of at least a
fraction of gaseous material, that is entrained within the received
formation fluid, from the received formation fluid to generate a
gaseous material-depleted formation fluid;
[0015] a gaseous material-depleted fluid formation conduit defining
a gaseous material-depleted formation fluid conducting-fluid
passage portion for conducting a flow of the gaseous
material-depleted formation fluid to the surface; and
[0016] a prime mover disposed for inducing flow of the formation
fluid from a subterranean formation and into the formation
fluid-receiving fluid passage portion, and for receiving and
energizing the gaseous material-depleted formation fluid to flow
through the gaseous material-depleted formation fluid
conducting-fluid passage portion to the surface;
wherein the co-operation between the gas separator portion and at
least the wellbore tubular is with effect that, while the flow of
the formation fluid is being induced by the prime mover and
received through the formation fluid-receiving fluid passage
portion, flowing of the received formation fluid is directed
through a gas separator annulus disposed between the gas separator
portion and the wellbore tubular, in a direction opposite to that
which the formation fluid is flowing while being received by the
formation fluid-receiving fluid passage portion of the formation
fluid-receiving conduit portion of the production tubular, prior to
being received by the prime mover, and the formation fluid flowing
through the gas separator annulus is prevented, or substantially
prevented, from returning to the formation fluid-receiving fluid
passage portion of the formation fluid-receiving conduit portion of
the production tubular by at least the sealing engagement between
the sealing surface of the formation fluid-receiving conduit
portion of the production tubular and the receptacle sealing
surface of the receptacle portion of the wellbore tubular, wherein,
while the flowing of the received formation fluid is being directed
through the gas separator annulus, the at least a fraction of the
entrained gaseous material becomes separated, in response to
buoyancy forces, from the received formation fluid that is being
directed through the gas separator annulus.
[0017] In another aspect there is provided a system for effecting
production of formation fluids from a subterranean formation,
comprising:
a wellbore tubular disposed within a wellbore, wherein the wellbore
tubular includes a casing, wherein the casing includes a receptacle
portion, wherein the receptacle portion is defined by an inwardly
extending protrusion of the casing and includes a receptacle
sealing surface; and a production tubular, disposed within the
wellbore tubular, including:
[0018] a formation fluid-receiving conduit portion, defining a
formation fluid-receiving fluid passage portion for receiving the
formation fluid, and including a sealing surface disposed in
sealing engagement with the receptacle sealing surface for
preventing, or substantially preventing, flow of the formation
fluids between the sealing surface and the receptacle sealing
surface;
[0019] a gas separator portion configured to co-operate with at
least the wellbore tubular for effecting separation of at least a
fraction of gaseous material, that is entrained within the received
formation fluid, from the received formation fluid to generate a
gaseous material-depleted formation fluid;
[0020] a gaseous material-depleted fluid formation conduit defining
a gaseous material-depleted formation fluid conducting-fluid
passage portion for conducting a flow of the gaseous
material-depleted formation fluid to the surface; and a prime mover
disposed for inducing flow of the formation fluid from a
subterranean formation and into the formation fluid-receiving fluid
passage portion, and for receiving and energizing the gaseous
material-depleted formation fluid to flow through the gaseous
material-depleted formation fluid conducting-fluid passage portion
to the surface;
wherein the co-operation between the gas separator portion and at
least the wellbore tubular is with effect that, while the flow of
the formation fluid is being induced by the prime mover and
received through the formation fluid-receiving fluid passage
portion, flowing of the received formation fluid is directed
through a gas separator annulus disposed between the gas separator
portion and the wellbore tubular, in a direction opposite to that
which the formation fluid is flowing while being received by the
formation fluid-receiving fluid passage portion of the formation
fluid-receiving conduit portion of the production tubular, prior to
being received by the prime mover, and the formation fluid flowing
through the gas separator annulus is prevented, or substantially
prevented, from returning to the formation fluid-receiving fluid
passage portion of the formation fluid-receiving conduit portion of
the production tubular by at least the sealing engagement between
the sealing surface of the formation fluid-receiving conduit
portion of the production tubular and the receptacle sealing
surface of the receptacle portion of the wellbore tubular, wherein,
while the flowing of the received formation fluid is being directed
through the gas separator annulus, the at least a fraction of the
entrained gaseous material becomes separated, in response to
buoyancy forces, from the received formation fluid that is being
directed through the gas separator annulus.
[0021] In another aspect there is provided a process for effecting
production of formation fluids from a subterranean formation,
comprising:
positioning a wellbore tubular within a wellbore, wherein the
wellbore tubular includes a receptacle portion, wherein the
receptacle portion includes a receptacle sealing surface; providing
a production tubular, wherein the production tubular includes:
[0022] a formation fluid-receiving conduit portion, defining a
formation fluid-receiving fluid passage portion for receiving the
formation fluid, and including a sealing member-engaging surface
portion;
[0023] a gas separator portion;
[0024] a gaseous material-depleted fluid formation conduit defining
a gaseous material-depleted formation fluid conducting-fluid
passage portion for conducting a flow of the gaseous
material-depleted formation fluid to the surface; and
[0025] a prime mover disposed for inducing flow of the formation
fluid from a subterranean formation and into the formation
fluid-receiving fluid passage portion, and for receiving and
energizing the gaseous material-depleted formation fluid to flow
through the gaseous material-depleted formation fluid
conducting-fluid passage portion to the surface;
and a sealing member disposable between the sealing member-engaging
surface portion and the receptacle sealing surface for effecting a
seal between at least the sealing member-engaging surface portion
and the receptacle sealing surface, for preventing, or
substantially preventing, flow of the formation fluid between at
least the sealing member-engaging surface portion and the
receptacle sealing surface; wherein, while the production tubular
is positioned within the wellbore tubular such that the seal
between at least the sealing member-engaging surface portion and
the receptacle sealing surface is being effected, the gas separator
portion is configured to co-operate with at least the wellbore
tubular for effecting separation of at least a fraction of gaseous
material, that is entrained within the received formation fluid,
from the received formation fluid to generate a gaseous
material-depleted formation fluid; and wherein the co-operation
between the gas separator portion and at least the wellbore tubular
is with effect that, while the flow of the formation fluid is being
induced by the prime mover and received through the formation
fluid-receiving fluid passage portion, flowing of the received
formation fluid is directed through a gas separator annulus
disposed between the gas separator portion and the wellbore
tubular, in a direction opposite to that which the formation fluid
is flowing while being received by the formation fluid-receiving
fluid passage portion of the formation fluid-receiving conduit
portion of the production tubular, prior to being received by the
prime mover, and the formation fluid flowing through the gas
separator annulus is prevented, or substantially prevented, from
returning to the formation fluid-receiving fluid passage portion of
the formation fluid-receiving conduit portion of the production
tubular by the effected seal between at least the sealing
member-engaging surface portion of the formation fluid-receiving
conduit portion of the production tubular and the receptacle
sealing surface of the receptacle portion of the wellbore tubular,
wherein, while the flowing of the received formation fluid is being
directed through the gas separator annulus, the at least a fraction
of the entrained gaseous material becomes separated, in response to
buoyancy forces, from the received formation fluid that is being
directed through the gas separator annulus, and the receptacle
sealing surface is disposed less than a distance "D" of 2.5
millimetres from the sealing member-engaging surface portion.
positioning the production tubular within the wellbore tubular such
that the seal between at least the sealing member-engaging surface
portion and the receptacle sealing surface is being effected;
inducing flow of the formation fluid, from a treated subterranean
formation to the formation fluid-receiving fluid passage portion of
the formation fluid-receiving conduit portion of the production
tubular, by the prime mover; directing flow of the received
formation fluid through the gas separator annulus, in a direction
opposite to that which the formation fluid is flowing while being
received by the formation fluid-receiving fluid passage portion of
the formation fluid-receiving conduit portion of the production
tubular, by the co-operating of the gas separator with the wellbore
tubular; preventing, or substantially preventing, the received
formation fluid, that is flowing through the gas separator annulus,
from returning to the formation fluid-receiving fluid passage
portion of the formation fluid-receiving conduit portion of the
production tubular by the seal effected between at least the seal
member-engaging sealing surface portion of the formation
fluid-receiving conduit portion of the production tubular and the
receptacle sealing surface of the receptacle portion of the
wellbore tubular; while the flow of the received formation fluid is
being directed through the gas separator annulus, effecting
separation, in response to buoyancy forces, of at least a fraction
of gaseous material entrained within the formation fluid flow being
flowed through the gas separator annulus to generate a gaseous
material-depleted formation fluid flow; energizing the gaseous
material-depleted formation fluid flow with the prime mover for
flow to the surface through the gaseous material-depleted fluid
formation conduit of the production tubular; and conducting the
energized gaseous material-depleted formation fluid flow to the
surface through the gaseous material-depleted fluid formation
conduit of the production tubular.
[0026] In another aspect there is provided a process for effecting
production of formation fluids from a subterranean formation,
comprising:
positioning a wellbore tubular within a wellbore, wherein the
wellbore tubular includes:
[0027] a casing string;
[0028] a liner string, coupled to the casing string, the liner
string including: [0029] a polished bore receptacle that includes a
receptacle portion, wherein the receptacle portion includes a
receptacle sealing surface; and [0030] a sealing surface, sealingly
engaged to the casing string for preventing, or substantially
preventing, flow of formation fluid between the sealing surface and
the casing string; providing a production tubular, wherein the
production tubular includes:
[0031] a formation fluid-receiving conduit portion, defining a
formation fluid-receiving fluid passage portion for receiving the
formation fluid, and including a sealing surface disposable for
sealing engagement with the receptacle sealing surface for
preventing, or substantially preventing, flow of the formation
fluids between the sealing surface and the receptacle sealing
surface;
[0032] a gas separator portion;
[0033] a gaseous material-depleted fluid formation conduit defining
a gaseous material-depleted formation fluid conducting-fluid
passage portion for conducting a flow of the gaseous
material-depleted formation fluid to the surface; and
[0034] a prime mover disposed for inducing flow of the formation
fluid from a subterranean formation and into the formation
fluid-receiving fluid passage portion, and for receiving and
energizing the gaseous material-depleted formation fluid to flow
through the gaseous material-depleted formation fluid
conducting-fluid passage portion to the surface;
wherein, while the production tubular is positioned within the
wellbore tubular such that the sealing engagement between at least
the sealing surface of the formation fluid-receiving conduit
portion and the receptacle sealing surface of the receptacle
portion is being effected, the gas separator portion is configured
to co-operate with at least the wellbore tubular for effecting
separation of at least a fraction of gaseous material, that is
entrained within the received formation fluid, from the received
formation fluid to generate a gaseous material-depleted formation
fluid; and wherein the co-operation between the gas separator
portion and at least the wellbore tubular is with effect that,
while the flow of the formation fluid is being induced by the prime
mover and received through the formation fluid-receiving fluid
passage portion, flowing of the received formation fluid is
directed through a gas separator annulus disposed between the gas
separator portion and the wellbore tubular, in a direction opposite
to that which the formation fluid is flowing while being received
by the formation fluid-receiving fluid passage portion of the
formation fluid-receiving conduit portion of the production
tubular, prior to being received by the prime mover, and the
formation fluid flowing through the gas separator annulus is
prevented, or substantially prevented, from returning to the
formation fluid-receiving fluid passage portion of the formation
fluid-receiving conduit portion of the production tubular by the
sealing engagement between at least the sealing surface of the
formation fluid-receiving conduit portion of the production tubular
and the receptacle sealing surface of the receptacle portion of the
wellbore tubular, wherein, while the flowing of the received
formation fluid is being directed through the gas separator
annulus, the at least a fraction of the entrained gaseous material
becomes separated, in response to buoyancy forces, from the
received formation fluid that is being directed through the gas
separator annulus; positioning the production tubular within the
wellbore tubular such that the sealing engagement between at least
the sealing surface of the formation fluid-receiving conduit
portion of the production tubular and the receptacle sealing
surface of the receptacle portion of the wellbore tubular is being
effected; inducing flow of the formation fluid, from a treated
subterranean formation to the formation fluid-receiving fluid
passage portion of the formation fluid-receiving conduit portion of
the production tubular, by the prime mover; directing flow of the
received formation fluid through the gas separator annulus, in a
direction opposite to that which the formation fluid is flowing
while being received by the formation fluid-receiving fluid passage
portion of the formation fluid-receiving conduit portion of the
production tubular, by the co-operating of the gas separator with
the wellbore tubular; preventing, or substantially preventing, the
received formation fluid, that is flowing through the gas separator
annulus, from returning to the formation fluid-receiving fluid
passage portion of the formation fluid-receiving conduit portion of
the production tubular by the sealing engagement between at least
the sealing surface of the formation fluid-receiving conduit
portion of the production tubular and the receptacle portion of the
wellbore tubular; while the flow of the received formation fluid is
being directed through the gas separator annulus, effecting
separation, in response to buoyancy forces, of at least a fraction
of gaseous material entrained within the formation fluid flow being
flowed through the gas separator annulus to generate a gaseous
material-depleted formation fluid flow; energizing the gaseous
material-depleted formation fluid flow with the prime mover for
flow to the surface through the gaseous material-depleted fluid
formation conduit of the production tubular; and conducting the
energized gaseous material-depleted formation fluid flow to the
surface through the gaseous material-depleted fluid formation
conduit of the production tubular.
[0035] In another aspect there is provided a process for effecting
production of formation fluids from a subterranean formation,
comprising:
positioning a wellbore tubular within a wellbore, wherein the
wellbore tubular includes a casing, wherein the casing includes a
receptacle portion, wherein the receptacle portion is defined by an
inwardly extending protrusion of the casing and includes a
receptacle sealing surface; providing a production tubular, wherein
the production tubular includes:
[0036] a formation fluid-receiving conduit portion, defining a
formation fluid-receiving fluid passage portion for receiving the
formation fluid, and including a sealing surface disposable for
sealing engagement with the receptacle sealing surface for
preventing, or substantially preventing, flow of the formation
fluids between the sealing surface and the receptacle sealing
surface;
[0037] a gas separator portion;
[0038] a gaseous material-depleted fluid formation conduit defining
a gaseous material-depleted formation fluid conducting-fluid
passage portion for conducting a flow of the gaseous
material-depleted formation fluid to the surface; and
[0039] a prime mover disposed for inducing flow of the formation
fluid from a subterranean formation and into the formation
fluid-receiving fluid passage portion, and for receiving and
energizing the gaseous material-depleted formation fluid to flow
through the gaseous material-depleted formation fluid
conducting-fluid passage portion to the surface;
wherein, while the production tubular is positioned within the
wellbore tubular such that the sealing engagement between at least
the sealing surface of the formation fluid-receiving conduit
portion and the receptacle sealing surface of the receptacle
portion is being effected, the gas separator portion is configured
to co-operate with at least the wellbore tubular for effecting
separation of at least a fraction of gaseous material, that is
entrained within the received formation fluid, from the received
formation fluid to generate a gaseous material-depleted formation
fluid; and wherein the co-operation between the gas separator
portion and at least the wellbore tubular is with effect that,
while the flow of the formation fluid is being induced by the prime
mover and received through the formation fluid-receiving fluid
passage portion, flowing of the received formation fluid is
directed through a gas separator annulus disposed between the gas
separator portion and the wellbore tubular, in a direction opposite
to that which the formation fluid is flowing while being received
by the formation fluid-receiving fluid passage portion of the
formation fluid-receiving conduit portion of the production
tubular, prior to being received by the prime mover, and the
formation fluid flowing through the gas separator annulus is
prevented, or substantially prevented, from returning to the
formation fluid-receiving fluid passage portion of the formation
fluid-receiving conduit portion of the production tubular by the
sealing engagement between at least the sealing surface of the
formation fluid-receiving conduit portion of the production tubular
and the receptacle sealing surface of the receptacle portion of the
wellbore tubular, wherein, while the flowing of the received
formation fluid is being directed through the gas separator
annulus, the at least a fraction of the entrained gaseous material
becomes separated, in response to buoyancy forces, from the
received formation fluid that is being directed through the gas
separator annulus; positioning the production tubular within the
wellbore tubular such that the sealing engagement between at least
the sealing surface of the formation fluid-receiving conduit
portion of the production tubular and the receptacle sealing
surface of the receptacle portion of the wellbore tubular is being
effected; inducing flow of the formation fluid, from a treated
subterranean formation to the formation fluid-receiving fluid
passage portion of the formation fluid-receiving conduit portion of
the production tubular, by the prime mover; directing flow of the
received formation fluid through the gas separator annulus, in a
direction opposite to that which the formation fluid is flowing
while being received by the formation fluid-receiving fluid passage
portion of the formation fluid-receiving conduit portion of the
production tubular, by the co-operating of the gas separator with
the wellbore tubular; preventing, or substantially preventing, the
received formation fluid, that is flowing through the gas separator
annulus, from returning to the formation fluid-receiving fluid
passage portion of the formation fluid-receiving conduit portion of
the production tubular by the sealing engagement between at least
the sealing surface of the formation fluid-receiving conduit
portion of the production tubular and the receptacle portion of the
wellbore tubular; while the flow of the received formation fluid is
being directed through the gas separator annulus, effecting
separation, in response to buoyancy forces, of at least a fraction
of gaseous material entrained within the formation fluid flow being
flowed through the gas separator annulus to generate a gaseous
material-depleted formation fluid flow; energizing the gaseous
material-depleted formation fluid flow with the prime mover for
flow to the surface through the gaseous material-depleted fluid
formation conduit of the production tubular; and conducting the
energized gaseous material-depleted formation fluid flow to the
surface through the gaseous material-depleted fluid formation
conduit of the production tubular.
BRIEF DESCRIPTION OF DRAWINGS
[0040] The preferred embodiments will now be described with the
following accompanying drawings, in which:
[0041] FIG. 1 is a schematic illustration of an embodiment of the
present disclosure, illustrating fluid flowpath through the gas
separator;
[0042] FIG. 2 is a schematic illustration of an enlarged portion of
the embodiment illustrated in FIG. 1, in the region of the gas
separator;
[0043] FIG. 2A is a schematic illustration of a further enlarged
portion of the embodiment illustrated in FIG. 1, in the region of
the gas separator, and specifically illustrating the relative
spatial disposition between a receptacle sealing surface of the
wellbore tubular and the sealing member-engaging surface portion of
the production tubular;
[0044] FIG. 3 is a schematic illustration of another embodiment of
the present disclosure, also illustrating fluid flowpath through
the gas separator; and
[0045] FIG. 4 is a schematic illustration of an enlarged portion of
the embodiment illustrated in FIG. 1, in the region of the gas
separator.
DETAILED DESCRIPTION
[0046] The term "upwardly" means, in a spatial context, from a
lower position to an upper position. The lower and upper positions
do not necessarily need to be in perfect vertical alignment, but
this possibility is not excluded.
[0047] The term "downardly" means, in a spatial context, from an
upper position to a lower position. The upper and lower position do
not necessarily need to be in perfect vertical alignment, but this
possibility is not excluded.
[0048] The term "tubular" refers to any generally tubular conduit
(not necessarily cylindrical in cross-section) for transporting
fluid, into or from a subterranean formation. A "tubular", as
deployed in a wellbore, may be formed from individual, discrete
lengths of generally tubular conduit that are joined together to
form, for example a tubing string, drill string, casing string, or
liner. In this respect, a tubular may be a tubing string, drill
string, casing string, or liner. Any of these structures are
positioned within a wellbore and utilized, at least in part, to
transport fluids. The tubular may have a bore of a generally
uniform diameter throughout the length thereof or may have two or
more sections having bores of different diameters. In some
embodiments, for example, one or more downhole tools may be secured
to the tubular.
[0049] "Formation fluid" is fluid that is contained within a
subterranean formation. Formation fluid may be liquid material,
gaseous material, or a mixture of liquid material and gaseous
material. In some embodiments, for example, the formation fluid
includes hydrocarbonaceous material, such as oil, natural gas, or
combinations thereof.
[0050] Referring to FIGS. 1 to 4, there is provided a system 10 for
effecting production of formation fluids from a subterranean
formation 50. The system includes a wellbore tubular 20 and a
production tubular 30. The wellbore tubular 20 and the production
tubular 30 extend from a wellhead 15 that is supported on the
ground surface 16.
[0051] The wellbore tubular 20 is disposed or positioned within a
wellbore 40. The wellbore tubular 20 includes a receptacle portion
22. The receptacle portion 22 includes a receptacle sealing surface
21.
[0052] The wellbore 40 can be straight, curved, or branched. The
wellbore can have various wellbore portions. A wellbore portion is
an axial length of a wellbore. A wellbore portion can be
characterized as "vertical" or "horizontal" even though the actual
axial orientation can vary from true vertical or true horizontal,
and even though the axial path can tend to "corkscrew" or otherwise
vary. The term "horizontal", when used to describe a wellbore
portion, refers to a horizontal or highly deviated wellbore portion
as understood in the art, such as, for example, a wellbore portion
having a longitudinal axis that is between 70 and 110 degrees from
vertical.
[0053] In some embodiments, for example, the wellbore tubular 20
includes a casing. The casing isolates certain zones of the
subterranean formation 50 from the formation fluid being produced
from another zone of the subterranean formation. In some
embodiments, for example, the casing stabilizes the subterranean
formation during drilling of the wellbore, as well as after the
wellbore has been completed, by preventing the collapse of the
subterranean formation that is defining the wellbore.
[0054] In some embodiments, for example, the casing 20 includes one
or more casing strings, each of which is positioned within the well
bore, having one end extending from the well head, either surface
or subsea. The casing strings may be cemented to the wellbore. The
combination of cement and casing strengthens the wellbore and
facilitates the isolation of certain areas of the subterranean
formation behind the casing for the production of formation fluids.
In some embodiments, for example and referring to FIG. 1, the
casing, including one or more casing strings, is connected at its
other end to a liner string 26. The liner string extends only a
short distance above the lower end of the previously installed
casing string and is suspended within the wellbore by a liner
hanger connected to the previously installed casing string. The
liner string can be made from the same material as the casing
string, but, unlike the casing string, the liner string does not
extend back to the wellhead. The liner string may be cemented to
the wellbore, or remain uncemented.
[0055] In some embodiments, for example and referring to FIGS. 3
and 4, the casing may include one or more expandable liner strings.
During assembly of the casing, and after being disposed in the
wellbore, the expandable liner string is expanded diametrically
into frictional engagement with the previous string of casing or
liner (which could also have been expanded diametrically into
frictional engagement with a further previous string of casing or
liner). The expanded string may be cemented to the wellbore, or
remain uncemented. The assembly of the casing, using such
expandable liner strings, effects production of at least a casing
section generally described as a "monobore" casing or casing
section.
[0056] In some embodiments, for example, the production tubular may
be a tubular string that includes several "joints" (a "joint" is a
length of pipe) or other tubular members assembled to create the
string.
[0057] The production tubular 30 is disposed within the wellbore
tubular 20. The production tubular includes a formation
fluid-receiving conduit portion 32, a gas separator portion 38, a
gaseous material-depleted fluid formation conduit portion 34, and a
prime mover 36.
[0058] The formation fluid-receiving conduit portion 32 includes a
formation fluid-receiving fluid passage-defining surface 323 that
defines a formation fluid-receiving fluid passage portion 3231 for
receiving the formation fluid.
[0059] In one aspect, the formation fluid-receiving conduit portion
includes a sealing surface 321 disposed in sealing engagement with
the receptacle sealing surface 21 for preventing, or substantially
preventing, flow of the formation fluids between the sealing
surface 321 and the receptacle sealing surface 21. The sealing
engagement effects a seal between the sealing surface 321 and the
receptacle sealing surface 21. In some embodiments, for example,
one of the sealing surfaces 21 or 321 is defined by a sealing
member 400 that is disposed between the formation fluid-receiving
conduit portion 32 and the receptacle portion 22 for effecting the
seal between the formation fluid-receiving conduit portion 32 and
the receptacle portion 22.
[0060] In some embodiments, for example, the sealing member 400
includes resilient material, such as elastomeric material. In some
embodiments, for example, the sealing member 400 includes
deformable metallic materials.
[0061] The gas separator portion 38 is configured to co-operate
with at least the wellbore tubular 20 for effecting separation of
at least a fraction of gaseous material, that is entrained within
the received formation fluid, from the received formation fluid to
generate a gaseous material-depleted formation fluid.
[0062] The gaseous material-depleted fluid formation conduit
portion 34 defines a gaseous material-depleted formation fluid
conducting-fluid passage portion 341 for conducting a flow of the
gaseous material-depleted formation fluid to the surface.
[0063] The prime mover 36 is disposed for inducing flow of the
formation fluid from a subterranean formation and into the
formation fluid-receiving fluid passage portion 3231, and for
receiving and energizing the gaseous material-depleted formation
fluid to flow through the gaseous material-depleted formation fluid
conducting-fluid passage portion 341 to the surface. In some
embodiments, for example, the prime mover 36 is a fluid propeller.
In some of these embodiments, for example, the prime mover is a
pump, such as a downhole pump. In some embodiments, for example,
the pump is a rod pump, such as a sucker rod pump.
[0064] The co-operation between the gas separator portion 38 and at
least the wellbore tubular 20 is with effect that, while the flow
of the formation fluid is being induced by the prime mover 36 and
received through the formation fluid-receiving fluid passage
portion 3231, flowing of the received formation fluid is directed
through a gas separator annulus 381 disposed between the gas
separator portion 38 and the wellbore tubular 20, in a direction
opposite to that which the formation fluid is flowing while being
received by the formation fluid-receiving fluid passage portion
3231 of the formation fluid-receiving conduit portion 32 of the
production tubular 30, prior to being received by the prime mover
36, and the formation fluid flowing through the gas separator
annulus 381 is prevented, or substantially prevented, from
returning to the formation fluid-receiving fluid passage portion
3231 of the formation fluid-receiving conduit portion 32 of the
production tubular 30 by at least the seal formed (as
above-described) between the formation fluid-receiving conduit
portion 32 of the production tubular 30 and the receptacle portion
22 of the wellbore tubular 20, wherein, while the flowing of the
received formation fluid is being directed through the gas
separator annulus 381, the at least a fraction of the entrained
gaseous material becomes separated, in response to buoyancy forces,
from the received formation fluid that is being directed through
the gas separator annulus 381.
[0065] Referring to FIG. 2A, in another aspect, the formation
fluid-receiving conduit portion 32 includes a sealing
member-engaging surface portion 325, and a sealing member 400 is
disposed between a sealing member-engaging surface portion 325 of
the formation fluid-receiving conduit portion 32 and the receptacle
sealing surface 21 for effecting the seal between at least the
sealing member-engaging surface portion 325 and the receptacle
sealing surface 21, for preventing, or substantially preventing,
flow of the formation fluid between at least the sealing
member-engaging surface portion 325 and the receptacle sealing
surface 21. In some of these embodiments, for example, the sealing
member 400 is coupled to, or carried, by the formation
fluid-receiving conduit portion 32. The receptacle sealing surface
21 is disposed less than a distance "D" of 2.5 millimetres from the
sealing member-engaging surface portion 325. In some embodiments,
for example, the distance "D" is one (1) millimetre, such that the
receptacle sealing surface 21 is disposed less than one (1)
millimetre from the sealing member-engaging surface portion 325.
This distance "D" is selected so as to minimize debris accumulation
but still permit the in installation of the sealing member 400.
[0066] By effecting separation of at least a fraction of gaseous
material, that is entrained within the received flow of formation
fluid, from the received formation fluid, the gas lock phenomena is
at least partially mitigated by the co-operation of the gas
separator 38 and the wellbore tubular 20. Unlike existing
packer-type gas anchors, by co-operatively configuring the wellbore
tubular 20 and the production tubular 30 such that the provided
spacing between the receptacle sealing surface 21, of the wellbore
tubular 20, and the sealing member-engaging surface portion 325, of
the production tubular 30, is below a predetermined distance (as
defined above), the amount of space to be dedicated for effecting
the sealing engagement between the receptacle sealing surface 21
and the sealing member-engaging surface portion 325 can be
minimized such that conventional packers are not required to be
used associated with the gas separator portion 38 to effect the
necessary sealing for preventing, or substantially preventing flow
between the tubulars 20, 30 in order for the removal of the
entrained gases to be effected. Because this is the case, the
problem of debris accumulation on the packer, which would otherwise
make it more difficult to remove the production tubular 30, from
the wellbore tubular 20, owing to the fact that such accumulated
debris may cause the packer associated with a gas separator,
disposed on the production tubular 30, to be stuck against the
wellbore tubular 20, is eliminated or mitigated, at least as it
relates to its relevance to removability of the production tubular
30 from the wellbore, such as during workovers.
[0067] In some embodiments, for example, the production tubular 30
is releasably secured to the wellbore tubular 20. In some of these
embodiments, for example, the production tubular is disposed in an
interference fit relationship (such as a press-fit relationship)
with the wellbore tubular 20. In some of these embodiments, for
example, the interference fit relationship is effected between the
sealing surface 321 of the formation fluid-receiving conduit
portion 32 of the production tubular 30 and the receptacle sealing
surface 21 of the receptacle portion 22 of the wellbore tubular
20.
[0068] Referring to FIGS. 1 and 2, in some embodiments, for
example, the wellbore tubular 20 includes a casing 2, and the
casing includes a casing string 201 and a liner string 26. In some
embodiments, for example, the liner string 26 is hung from the
casing string 201. The liner string 26 includes a polished bore
receptacle 261 and an external sealing surface 262. The polished
bore receptacle 261 includes the receptacle portion 22. The
external sealing surface 262 is sealingly engaged to the casing
string 201 for preventing, or substantially preventing, flow of
formation fluid between the external sealing surface 262 and the
casing string 201. In some embodiments, for example, the sealing
engagement between the surface 262 and the casing string 201 is
effected by a packer 24 mounted to the casing string 201. The
production tubular 30 is disposed within the polished bore
receptacle 261, and urging of the sealing engagement between the
sealing surface 321 of the production tubular 30 and the receptacle
sealing surface 21 of the receptacle portion 22 of the polished
bore receptacle 261 is effected with a seal latch assembly that
releasably secures the production tubular 30 to the polished bore
receptacle 261. In some embodiments, for example, the production
tubular 30 is releasably coupled or releasably secured to the
polished bore receptacle 261. In some of these embodiments, for
example, the releasable coupling (or the releasable securement) is
effected by way of an interference fit engagement (such as a
press-fit engagement) between the production tubular 30 and the
receptacle portion 22 of the polished bore receptacle 261.
[0069] Referring to FIGS. 3 and 4, in some embodiments, for
example, the wellbore tubular 20 includes a casing 2, and the
receptacle portion 22 extends inwardly from the casing 2. In some
embodiments, for example, the receptacle portion 22 defines a
constricted portion 221 of the casing 2. In some embodiments, for
example, the production tubular 30 is releasably coupled or
releasably secured to the receptacle portion 22. In some of these
embodiments, for example, the releasable coupling (or the
releasable securement) is effected by way of an interference fit
engagement (such as a press-fit engagement) between the production
tubular 30 and the receptacle portion 22. In this respect, the
extending inward receptacle portion 22 is permanently affixed to
the casing 2, thus any accumulation of debris will not prevent
removal of the production tubular 30 and the sealing
member-engaging surface portion 325.
[0070] In some embodiments, for example, the system further
includes a conducting annulus 382 disposed between the production
tubular 30 and the wellbore tubular 20. The conducting annulus 382
is configured to receive and conduct the separated gaseous material
to the surface. The gas separator annulus 381 is disposed in
vertical alignment with the conducting annulus 382.
[0071] In some embodiments, for example, the gas separator 38
further co-operates with the wellbore tubular 20 with effect that
the received formation fluid flow being flowed through the gas
separator annulus 381 is flowing in a downwardly direction.
[0072] In some embodiments, for example, the disposition of the
wellbore tubular 20 relative to the wellbore is with effect that
the effected fluid communication between the formation
fluid-receiving fluid passage portion 3231 of the production
tubular 30 and the subterranean formation treatment zone is
isolated, or substantially isolated, from at least one other zone
of the subterranean formation (such as, in FIG. 1, by another
packer 501).
[0073] In some embodiments, for example, the prime mover 36 is
disposed within a horizontal wellbore portion of the wellbore
40.
[0074] In some embodiments, for example, a mechanical filter 327
(such as a sand screen) is disposed within the production tubular
30, upstream of the gas separator 38 for filtering solids from the
formation fluid whose flow has been induced into the formation
fluid-receiving conduit portion 32. Intermittently, the solids,
retained by the mechanical filter 327 can be purged by pumping a
fluid downhole through the annulus 382.
[0075] In some of these embodiments, for example, a check valve may
be disposed within the production tubular, upstream of the inlet,
for enabling fluid circulation of a purging fluid that may be used
for cleaning out debris within the production tubular, while
preventing fluid communication with the production zone.
[0076] There is also provided a process for effecting production of
formation fluids from a subterranean formation.
[0077] The process includes positioning the wellbore tubular 20
within the wellbore, and then positioning the production tubular 30
within the wellbore tubular 20.
[0078] Flow of the formation fluid, from a treated subterranean
formation 50 to the formation fluid-receiving conduit portion 32 of
the production tubular 30, is then induced by the prime mover 36.
The flow of the received formation fluid is directed through the
gas separator annulus 381, in a direction opposite to that which
the formation fluid is flowing while being received by the
formation fluid-receiving fluid passage portion 3231 of the
production tubular 30, by the co-operating of the gas separator 38
with the wellbore tubular 20. The received formation fluid, that is
flowing through the gas separator annulus 381, is prevented, or
substantially prevented, from returning to the formation
fluid-receiving fluid passage portion 3231 of the production
tubular 30 by at least the sealing engagement between the formation
fluid-receiving fluid passage portion 3231 of the formation
fluid-receiving conduit portion 32 of the production tubular 30 and
the receptacle sealing surface 21 of the receptacle portion 22 of
the wellbore tubular 20. While the flow of the received formation
fluid is being directed through the gas separator annulus 381,
separation, of at least a fraction of gaseous material entrained
within the formation fluid flow being flowed through the gas
separator annulus 381, in response to buoyancy forces, is effected
to generate a gaseous material-depleted formation fluid flow. The
gaseous material-depleted formation fluid flow is energized with
the prime mover 36 for flow to the surface through the gaseous
material-depleted formation fluid conducting-fluid passage portion
341 of the production tubular 30. The energized gaseous
material-depleted formation fluid flow is conducted to the surface
through the gaseous material-depleted formation fluid
conducting-fluid passage portion 341.
[0079] In some embodiments, for example, the received formation
fluid flow, being flowed through the gas separator annulus 381, is
flowing, in a downwardly direction.
[0080] In some embodiments, for example, while the flow of the
formation fluid, for receiving by the formation fluid-receiving
fluid passage portion 3231 of the production tubular 30, is being
induced, the formation fluid is flowing in an upwardly
direction.
[0081] In some embodiments, for example, the inducing flow of
formation fluid includes effecting the development of a sufficient
pressure differential, between the suction of the prime mover 36
and the subterranean formation 50, by the prime mover 36.
[0082] In some embodiments, for example, the positioning of the
production tubular 30 includes positioning the prime mover 36
within a horizontal wellbore portion of the wellbore 40.
[0083] In some embodiments, for example, the process further
includes flowing the separated gaseous material to the surface
through a conducting annulus 382 disposed between the production
tubular 30 and the wellbore tubular 20. In some of these
embodiments, for example, the gas separator annulus 381 is disposed
in vertical alignment with the conducting annulus 382. In some of
these embodiments, for example, the flowing of the separated
gaseous material is in a direction opposite to that of the flow of
the received formation fluid through the gas separator annulus
381.
[0084] In some embodiments, for example, the process further
includes, prior to the positioning of a production tubular 30
within the wellbore tubular 20, the steps of: delivering a wellbore
treatment fluid to a treatment zone of the subterranean formation
50 to effect treatment of the subterranean formation treatment
zone, and then suspending the delivering of the wellbore treatment
fluid. The formation fluid is derived from the subterranean
formation treatment zone. In some of these embodiments, the process
further includes, prior to the delivering of the wellbore treatment
fluid to the subterranean formation treatment zone, the step of
positioning the wellbore treatment tubular into fluid communication
with the subterranean formation treatment zone with effect that the
wellbore treatment tubular is disposed for conducting wellbore
treatment fluid to the subterranean formation treatment zone, and
also further includes, after the delivering of the wellbore
treatment fluid, repositioning the wellbore treatment tubular with
effect that fluid communication between the wellbore treatment
tubular and the receptacle portion becomes suspended. After the
repositioning, the production tubular 30 is positioned within the
wellbore tubular 20.
[0085] "Wellbore treatment fluid" refers to fluid used in treatment
(such as stimulation) of a subterranean formation. Stimulation is a
type of treatment performed on a subterranean formation to restore
or enhance the productivity of oil or gas or other fluid within the
subterranean formation. Stimulation includes hydraulic fracturing.
Nonlimiting examples of a suitable wellbore servicing fluid include
but are not limited to a fracturing fluid, a perforating or
hydrajetting fluid, an acidizing fluid, or combinations
thereof.
[0086] In some embodiments, for example, while the delivering of
the wellbore treatment fluid is being effected, the receptacle 22
is sealingly engaging the wellbore treatment tubular.
[0087] The wellbore treatment tubular includes a fluid passage for
conducting wellbore treatment fluid from a wellbore treatment fluid
supply source disposed on the surface to the subterranean formation
50. In some embodiments, for example, The wellbore treatment
tubular may be a tubular string that includes several "joints" (a
"joint" is a length of pipe) or other tubular members assembled to
create the string. In some embodiments, for example, the wellbore
treatment tubular includes one or more downhole tools for effecting
fracturing of the subterranean formation with which the one or more
downhole tools is disposed in fracture-effecting communication with
when disposed within the wellbore.
[0088] One or more flow control devices may be provided for
selectively effecting fluid communication between the receptacle
portion and a subterranean formation. In some modes of operation,
the effecting of fluid communication between the wellbore treatment
tubular and a treatment zone of a subterranean formation 50, by the
one or more flow control valves, provides a flowpath for the
delivery of wellbore treatment fluid. In other modes of operation,
the effecting of fluid communication between the formation
fluid-receiving fluid passage portion 3231 of the production
tubular 30 and a subterranean formation, by the one or more flow
control valves, provides a flowpath for conducting of formation
fluid from the subterranean formation to the production tubular
30.
[0089] In some embodiments, for example, the one or more flow
control devices are integrated within the wellbore tubular 20. For
those embodiments where the one or more flow control devices are
provided by the wellbore tubular, in some of these embodiments, for
example, the wellbore treatment tubular includes a tool for
selectively effecting opening and closing of the one or more flow
control devices integrated within the wellbore tubular for
effecting fluid communication between a selected zone of the
subterranean formation 50 and the wellbore treatment tubular, and
thereby facilitating the delivery of the wellbore treatment fluid
to the selected zone of the subterranean formation 50 to effect
treatment of the selected zone of the subterranean formation,
independently of other zones of the subterranean formation. Also
for those embodiments where the one or more flow control devices
are provided by the wellbore tubular, in some of these embodiments,
for example, the production tubular 30 includes a tool for
selectively effecting opening and closing of the one or more flow
control devices integrated within the wellbore tubular for
effecting fluid communication between a selected zone of the
treated subterranean formation 50 and the formation fluid-receiving
fluid passage portion 3231 of the production tubular 30, while
isolating other ones of the zones of the treated subterranean
formation, and thereby facilitating flow of the formation fluid
from the selected zone of the treated subterranean formation, to
the formation fluid-receiving fluid passage portion 3231, while
isolating other ones of the zones of the treated subterranean
formation from the formation fluid being flowed from the selected
zone.
[0090] The flow control devices may comprise sliding sleeves,
valves, and other types of flow control devices which may be
actuated by a member dropped down through the associated
tubular.
[0091] In the above description, for purposes of explanation,
numerous details are set forth in order to provide a thorough
understanding of the present disclosure. However, it will be
apparent to one skilled in the art that these specific details are
not required in order to practice the present disclosure. Although
certain dimensions and materials are described for implementing the
disclosed example embodiments, other suitable dimensions and/or
materials may be used within the scope of this disclosure. All such
modifications and variations, including all suitable current and
future changes in technology, are believed to be within the sphere
and scope of the present disclosure. All references mentioned are
hereby incorporated by reference in their entirety.
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