US20150330158A1

US20150330158A1 - Apparatuses, systems, and methods for injecting fluids into a subterranean formation

Info

Publication number: US20150330158A1
Application number: US14/281,307
Authority: US
Inventors: Mohammed Rashad Abdo QAID; James Robert Hunter; Ryan Thomas McDowell
Original assignee: Crescent Point Energy Corp
Current assignee: Crescent Point Energy Corp
Priority date: 2014-05-19
Filing date: 2014-05-19
Publication date: 2015-11-19
Also published as: WO2015176159A1

Abstract

There is provided apparatuses, systems, and methods for effecting injection of injection fluids into a subterranean formation, including: a bundled plurality of fluid-conducting conduits.

Description

FIELD

The present disclosure relates to apparatuses, systems and methods for injecting fluids into a subterranean formation.

BACKGROUND

Fluids are injected into subterranean formations, such as oil reservoirs, for various treatment purposes. In some cases, fluids are injected from one or more injections wells to increase reservoir pressure so as to enhance oil recovery through a production well. Unfortunately, subterranean formations are relatively heterogeneous, and injected fluids may bypass the formation fluid and flow (or channel) to the production well without having influenced the displacement of at least a meaningful quantity of formation fluid into the production well. It is, therefore, desirable to improve the efficiency and economics of enhanced oil recovery through fluid injection.

SUMMARY

In one aspect, there is provided an apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising: a plurality of fluid-conducting conduits, each one of the fluid-conducting conduits, independently, including a respective conduit fluid passage and a respective at least one first fluid communication feature, such that a plurality of first fluid communication features is provided, wherein each one of the first fluid communication features, independently, includes one of: (a) a first fluid conducting port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the first fluid conducting port is respective, externally of the respective fluid-conducting conduit; and (b) a first frangible portion adapted to fracture to define a first fluid conducting port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the first frangible portion is respective, externally of the respective fluid-conducting conduit; a carrier conduit including, respective to each one of the fluid-conducting conduits, at least one second fluid communication feature, such that a plurality of second fluid communication features is provided, wherein each one of the second fluid communication features, independently, includes one of: (a) a second fluid conducting port for conducting fluid, received from at least one first fluid conducting port of the fluid-conducting conduit to which the second fluid conducting port, of the carrier conduit, is respective, to a subterranean zone of the subterranean formation; and (b) a second frangible portion adapted to fracture to define a second fluid conducting port for conducting fluid, received from at least one first fluid conducting port of the fluid-conducting conduit to which the second frangible portion, of the carrier conduit, is respective, to a subterranean zone of the subterranean formation; wherein the plurality of fluid-conducting conduits is disposed within the carrier conduit; and wherein the carrier conduit is disposed in sealing engagement, or substantially sealing engagement, with the plurality of fluid-conducting conduits such that sealing, or substantial sealing, of fluid communication, within the carrier conduit, between (i) the at least one first fluid communication feature of one of the fluid-conducting conduits and, at least, (ii) the at least one first fluid communication feature of another one of the fluid-conducting conduits, is effected.
In another aspect, there is provided an apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising: a plurality of fluid-conducting conduits, each one of the fluid-conducting conduits, independently, including a conduit fluid passage; and respective to each one of the fluid-conducting conduits, at least one fluid communication feature, such that a plurality of fluid communication features is provided, wherein each one of the fluid communication features, independently, includes one of: (a) an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the apparatus port is respective, to a subterranean zone of the subterranean formation; and (b) a frangible portion adapted to fracture to define an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible portion is respective, to a subterranean zone of the subterranean formation; wherein, the at least one fluid communication feature, respective to a one of the fluid-conducting conduits, is spaced apart from the at least one fluid communication feature respective to another one of the fluid-conducting conduits.
In another aspect, there is provided an apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising: a plurality of fluid-conducting conduits, each one of the fluid-conducting conduits, independently, including a conduit fluid passage; and respective to each one of the fluid-conducting conduits, at least one fluid communication feature, such that a plurality of fluid communication features is provided, wherein each one of the fluid communication features, independently, includes one of: (a) an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the apparatus port is respective, to a subterranean zone of the subterranean formation; and (b) a frangible portion adapted to fracture to define an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible portion is respective, to a subterranean zone of the subterranean formation; respective to at least one of the fluid-conducting conduits, a pair of sealing members extending from the fluid-conducting conduit, wherein the at least one fluid communication feature, of the fluid-conducting conduit to which the pair of sealing members is respective, is disposed between the pair of sealing members; and wherein the pair of sealing members is configured such that, when the apparatus is deployed within the wellbore, the sealing members are disposed, or deployable into a disposition, to prevent, or substantially prevent, fluid communication, through a wellbore annulus, between: (i) the at least one fluid communication feature, disposed between the pair of sealing members, and (ii) a fluid communication feature of another one of the fluid-conducting conduits.
In another aspect, there is provided an apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising: a plurality of fluid-conducting conduits, each one of the fluid-conducting conduits, independently, including a conduit fluid passage; and respective to each one of the fluid-conducting conduits, at least one fluid communication feature, such that a plurality of fluid communication features is provided, wherein each one of the fluid communication features, independently, includes one of (a) an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the apparatus port is respective, to a subterranean zone of the subterranean formation; and (b) a frangible portion adapted to fracture to define an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible portion is respective, to a subterranean zone of the subterranean formation; respective to at least one of the fluid-conducting conduits, a pair of sealing members extending from the fluid-conducting conduit, wherein the at least one fluid communication feature, of the fluid-conducting conduit to which the pair of sealing members is respective, is disposed between the pair of sealing members; wherein, the pair of sealing members is configured such that, when the apparatus is deployed within the wellbore, and the pair of sealing members are disposed in sealing engagement with the formation, and injection fluid is being injected, from at least one apparatus port of the fluid-conducting conduit to which the pair of sealing members is respective, into a subterranean zone, the pair of sealing members effect isolation, or substantial isolation, of the injected injection fluid from the remainder of the subterranean formation.
In another aspect, there is provided an apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising: a plurality of fluid-conducting conduits, each one of the fluid-conducting conduits, independently, including a conduit fluid passage; and respective to each one of the fluid-conducting conduits, at least one fluid communication feature, such that a plurality of fluid communication features is provided, wherein each one of the fluid communication features, independently, includes one of: (a) an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the apparatus port is respective, to a subterranean zone of the subterranean formation; and (b) a frangible portion adapted to fracture to define an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible portion is respective, to a subterranean zone of the subterranean formation; respective to at least one of the fluid-conducting conduits, a pair of sealing members extending from the fluid-conducting conduit, wherein the at least one fluid communication feature, of the fluid-conducting conduit to which the pair of sealing members is respective, is disposed between the pair of sealing members; wherein the pair of sealing members is configured such that, when the apparatus is deployed within the wellbore, the sealing members are disposed in, or deployable into a disposition of, sealing engagement or substantially sealing engagement with a surface that, in co-operation with at least the apparatus, defines a wellbore annulus.
In another aspect, there is provided an apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising: a plurality of fluid-conducting conduits, each one of the fluid-conducting conduits, independently, including a conduit fluid passage; and respective to each one of the fluid-conducting conduits, at least one fluid communication feature, such that a plurality of fluid communication features is provided, wherein each one of the fluid communication features, independently, includes one of: (a) an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the apparatus port is respective, to a subterranean zone of the subterranean formation; and (b) a frangible portion adapted to fracture to define an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible portion is respective, to a subterranean zone of the subterranean formation; wherein each one of the fluid-conducting conduits, independently, includes a valve member configured for at least interfering with fluid communication, through the fluid passage, between a fluid source upstream of the valve and the at least one apparatus port.
In another aspect, there is provided a system including any one of the apparatuses described above disposed within a wellbore.
In another aspect, there is provided a method of supplying fluid into a subterranean formation, comprising: deploying a bundled plurality of fluid-conducting conduits into a wellbore; and supplying fluid, from a fluid supply source disposed above the surface, through the fluid-conducting conduits and into the subterranean formation.

BRIEF DESCRIPTION OF DRAWINGS

The preferred embodiments will now be described with the following accompanying drawings, in which:

FIG. 1 is a schematic illustration of an embodiment of a system of the present disclosure;

FIG. 2 is a schematic illustration of a waterflooding system;

FIG. 3 is a cross-sectional view of an embodiment of an apparatus of the present disclosure, disposed within an injection well;

FIG. 4 is a front perspective view of a portion of the apparatus illustrated in FIG. 3, with the carrier conduit removed for clarity;

FIG. 4A is a front perspective view of a portion of the apparatus illustrated in FIG. 3;

FIG. 5 is a cross-sectional view of another embodiment of an apparatus of the present disclosure; and

FIG. 6 is a front perspective view of a portion of the apparatus illustrated in FIG. 3.

DETAILED DESCRIPTION

1. Apparatus

As used herein, the terms “up”, “upward”, “upper”, or “uphole”, mean, relativistically, in closer proximity to the surface and further away from the bottom of the wellbore, when measured along the longitudinal axis of the wellbore. The terms “down”, “downward”, “lower”, or “downhole” mean, relativistically, further away from the surface and in closer proximity to the bottom of the wellbore, when measured along the longitudinal axis of the wellbore.
Referring to FIGS. 3 to 6, there is provided an apparatus 10 for effecting injection of injection fluids into a subterranean formation 18, such as an oil reservoir. The apparatus 10 includes bundled conduits.
Referring to the embodiment illustrated in FIGS. 3 and 4, in one aspect, the bundled conduit includes a plurality of fluid-conducting conduits 12 a, 12 b, 12 c, 12 d (four are illustrated). Each one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, independently, includes a respective conduit fluid passage 14 a, 14 b, 14 c, 14 d. The apparatus also includes, respective to each one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, at least one fluid communication feature 17. In this respect, the apparatus includes a plurality of fluid communication features 17. Each one of the fluid communication features 17, independently, includes one of: (a) an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the apparatus port is respective, to a subterranean zone of the subterranean formation (see FIG. 1); and (b) a frangible portion adapted to fracture to define an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible portion is respective, to a subterranean zone of the subterranean formation In the illustrated embodiment of FIGS. 3 and 4, the fluid communication feature 17 includes an apparatus port.
In another aspect, the bundled conduits include a plurality of fluid-conducting conduits 12 a, 12 b, 12 c, 12 d that are constrained from moving apart from one another. In some embodiments, for example, the constraining is such that the conduits 12 a, 12 b, 12 c and 12 d are constrained from moving apart from one another while the apparatus is being deployed downhole into a wellbore 20. Each one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, independently, includes a respective conduit fluid passage 14 a. 14 b, 14 c, 14 d. The apparatus also includes, respective to each one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, at least one fluid communication feature 17. In this respect, a plurality of fluid communication features 17 is provided. Each one of the fluid communication features 17, independently, includes one of: (a) an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the apparatus port is respective, to a subterranean zone of the subterranean formation (see FIG. 1); and (b) a frangible portion adapted to fracture to define an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible portion is respective, to a subterranean zone of the subterranean formation. In the illustrated embodiment of FIGS. 3 and 4, the fluid communication feature 17 includes an apparatus port.
Reference herein to a “frangible portion” refers to a relatively weaker portion of the structure which may be punctured or otherwise fractured to create a throughbore or port, or which may be fractured in response to a predetermined fluid pressure to define a throughbore or port. The puncturing or fracturing may be effected as the apparatus is being deployed downhole. The puncturing or fracturing may also be effected after the apparatus has been deployed downhole (such as by fluid pressure), and prior to the conducting of fluid to the subterranean formation via the apparatus. In some embodiments, for example, the “frangible portion” may be a “burst port”.
In some embodiments, for example, the apparatus 10 is configured for deployment within a wellbore 20.
The wellbore 20 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.
The wellbore 20 may be completed either as a cased-hole completion or an open-hole completion.
Referring to FIG. 2, in some embodiments, for example, the apparatus is configured for deployment within an injection well 22, for effecting the injection of injection fluids into the subterranean formation 18 such that pressure of formation fluids within the subterranean formation is increased, thereby initiating (or inducing) production, or increasing the rate of production, of formation fluids from the subterranean formation through a production well 24. In this respect, there is also provided a production well 24 for receiving the formation fluid being flowed in response to the pressure differential between the subterranean formation 18 and the production well 24, wherein at least a fraction of the pressure differential is attributable to the injection of the injection fluid by the apparatus within the injection well 22. In some embodiments, for example, there is provided a plurality of injection wells 22, 22 a, and the wells 22, 22 a are provided to enable injection of injection fluid through these wells into the subterranean formation 18, and each one of the injection wells contributes to effecting an increase in pressure of the formation fluids within the formation well such that production is initiated or induced through the production well 24, or the rate of production of the formation fluids through the production well 24 is increased. In some embodiments, for example, when the injection fluid includes water or an aqueous solution, the process is referred to as “waterflooding”.
It is understood that the apparatus could be deployed for applications relating to treatment of subterranean formations other than waterflooding.
In some embodiments, for example, each one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, independently, includes tubing. In some of these embodiments, for example, the tubing is made of any suitable material. Exemplary materials include carbon steel, stainless steel, fiberglass, plastics, or composite materials. The tubing may be constructed from individual sections or may be a single continuous piece.
The bundling or constraining is effected by a retainer.
Referring to FIGS. 3, 4 and 4A, in some embodiments, for example, the “bundling” or “constraining” is effected by press-fit engagement of the conduits 12 a, 12 b, 12 c, 12 d within a carrier conduit 26. In this respect, the retainer includes the carrier conduit 26. In some of these embodiments, for example, the carrier conduit 26 may be made of any suitable materials. Exemplary materials include carbon steel, stainless steel, fiberglass, plastics, or composite materials. In some embodiments, for example, the material of the carrier conduit 26 is different than the material of the conduits 12 a, 12 b, 12 c, 12 d.
Respective to each one of the conduits 12 a, 12 b, 12 c, 12 d, there is provided at least one first fluid communication feature 171A. In this respect, the bundled conduits include a plurality of first fluid communication features 171A. Each one of the first fluid communication features, independently, includes one of: (a) a first fluid conducting port 171A for conducting fluid, when fluid is flowing through the conduit fluid passage to which the first fluid conducting port is respective, externally of the respective fluid-conducting conduit; and (b) a first frangible portion adapted to fracture to define a first fluid conducting port 171A for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible portion is respective, externally of the respective fluid-conducting conduit. In the illustrated embodiment, the first fluid communication feature includes a port 171A.
The carrier conduit 26, includes, respective to each one of the conduits 12 a, 12 b, 12 c, 12 d, at least one second fluid communication feature 171B. In this respect, the carrier conduit 26 includes a plurality of second fluid communication features 171B. Each one of the second fluid communication features 171B, independently, includes one of: (a) a second fluid conducting port 171B for conducting fluid, received from at least one first fluid conducting port 171A (including ports that have been defined by the fracturing of a corresponding frangible portion) of the fluid-conducting conduit to which the second fluid conducting port (of the carrier conduit 26) is respective, to a subterranean zone of the subterranean formation; and (b) a second frangible portion adapted to fracture to define a second fluid conducting port 171B for conducting fluid, received from at least one first fluid conducting port 171A (including ports that have been defined by the fracturing of a corresponding frangible portion) of the fluid-conducting conduit to which the second frangible portion (of the carrier conduit 26) is respective, to a subterranean zone of the subterranean formation. In the embodiment illustrated in FIG. 4A, the second fluid communication feature 171B includes a port.
In this respect, in the embodiment illustrated in FIGS. 3, 4 and 4A, the fluid communication feature 17 is defined by the combination of the features 171A and 171B.
The carrier conduit 26 is disposed in sealing engagement or substantially sealing engagement with the plurality of fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, such that sealing, or substantial sealing, of fluid communication, within the carrier conduit, between (i) the at least one first fluid communication feature 171A (such as at least one first fluid-conducting conduit port 171A) of one of the fluid-conducting conduits and, at least, (ii) the at least one first fluid communication feature 171A (such as at least one first fluid-conducting conduit port 171A) of another one of the fluid-conducting conduits is effected.
Referring to FIGS. 5 and 6, in other embodiments, for example, the “bundling” or “constraining” is effected by extending conduits 112 a, 112 b, 112 c, and 112 d through, and in press-fit engagement with, sealing members 128 a, 128 b, and 128 c. Each one of the conduits 112 a, 112 b, 112 c, and 112 d, independently, include a respective fluid passage 114 a, 114 b, 114 c, 114 d. In such embodiment, the retainer includes the sealing members 128 a, 128 b, and 128 c.
In some embodiments, for example, the at least one fluid communication feature 17, respective to a one of the fluid-conducting conduits 12 a, 12 b, 12 c 12 d, is spaced apart from the at least one fluid communication feature 17, respective to another one of the fluid-conducting conduits 12 a, 12 b, 12 c 12 d. In some of these embodiments, for example, the spacing apart is by a minimum distance of at least 15 metres. In some embodiments, for example, the minimum distance is between 15 metres and 800 metres.
In some embodiments, for example, the at least one fluid communication feature 17, respective to a one of the fluid-conducting conduits 12 a, 12 b, 12 c 12 d, is spaced apart from every other fluid communication feature 17 that is respective to another one of the fluid-conducting conduits 12 a, 12 b, 12 c 12 d. In some embodiments, for example, the spacing apart is by a minimum distance of at least 15 metres. In some embodiments, for example, the minimum distance is between 15 metres and 800 metres.
In some embodiments, for example, when the apparatus 10 is deployed within a wellbore, a portion of the subterranean formation 18, disposed opposite to a fluid communication feature 17 of one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, is spaced apart from a portion of the subterranean formation 18 disposed opposite to a fluid communication feature 17 of another one of the fluid-conducting conduits 12 a, 12 b, 12 c 12 d. In some embodiments, for example, the spacing apart is by a minimum distance of at least 15 metres. In some embodiments, for example, the minimum distance is between 15 metres and 800 metres.
In some embodiments, for example, when the apparatus 10 is deployed within a wellbore, a portion of the subterranean formation 18, disposed opposite to a fluid communication feature 17 respective to a one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, is spaced apart from every one of the other portions of the subterranean zone 18 that is disposed opposite to a fluid communication feature 17 respective to another one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d. In some embodiments, for example, the spacing apart is by a minimum distance of at least 15 metres. In some embodiments, for example, the minimum distance is between 15 metres and 800 metres.
Referring to FIGS. 3 and 4, or FIGS. 5 and 6, in some embodiments, for example, in the case of the embodiment illustrated in FIGS. 3 and 4, respective to each one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, or in the case of the embodiment illustrated in FIGS. 5 and 6, respective to each one of the conduits 112 a, 112 b, and 112 c, a pair of sealing members (in the case of the embodiment illustrated in FIGS. 3 and 4, any pair of successive ones of sealing members 28 a, 28 b, and 28 c, or in the case of the embodiment illustrated in FIGS. 5 and 6, any pair of successive ones of sealing members 128 a, 128 b, and 128 c) extends from the respective conduit and straddles the at least one fluid communication feature 17 (in the case of the embodiment illustrated in the FIGS. 3 and 4, the fluid communication feature 17 is defined by a combination of features 171A and 171B, and in the case of the embodiment illustrated in FIGS. 5 and 6, the fluid communication feature 17 is an apparatus port). The pair of sealing members is configured such that, when the apparatus 10 is deployed within the wellbore, the sealing members are disposed, or deployable into a disposition, to prevent, or substantially prevent, fluid communication, through a wellbore annulus 30, between: (i) the at least one fluid communication feature 17, disposed between the pair of sealing members, and (ii) a fluid communication feature 17 of another one of the fluid-conducting conduits. In some embodiments, for example, each one of the sealing members includes a packer.
In some embodiments, for example, when the apparatus 10 is deployed within the wellbore, and the pair of sealing members is disposed in sealing engagement with the formation 18, and while injection fluid is being injected from the at least one apparatus port 17 (including apparatus ports that have been defined by the fracturing of a corresponding frangible portion), the pair of sealing members effects isolation, or substantial isolation, of the injected injection fluid from the remainder of the subterranean formation 18.
In some embodiments, for example, the pair of sealing members is configured such that, when the apparatus 10 is deployed within the wellbore, the sealing members are disposed in, or deployable into a disposition of, sealing engagement, or substantially sealing engagement, with a surface that, in co-operation with at least the apparatus 10, defines the wellbore annulus 30. In some embodiments, for example, the surface is a portion of the subterranean formation 18 (such as in the case of an open hole completion). In some embodiments, for example, the surface is that of a portion of a casing that is lining the wellbore 20, or a portion of a liner that is hanging from the casing (such as in the case of a cased hole completion).
In some embodiments, for example, each one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, independently, includes a valve member 42 a 42 b, 42 c, 42 d configured for at least interfering with fluid communication, through the fluid passage 14, between a fluid source upstream of the valve member 42 a 42 b, 42 c, 42 d and the at least one apparatus port 17 (including apparatus ports that have been defined by the fracturing of a corresponding frangible portion). In some embodiments, for example, the valve member 42 a 42 b, 42 c, 42 d is configured for disposition between an open condition and a closed condition. In the open condition, fluid communication, through the fluid passage 14, is being effected between a fluid source upstream of the valve member 42 a 42 b, 42 c, 42 d and the at least one apparatus port 17. In the closed condition, sealing, or substantial sealing of fluid communication, through the fluid passage, between a fluid source upstream of the valve member 42 a 42 b, 42 c, 42 d and the at least one apparatus port 17, is being effected.
The valve member 42 a 42 b, 42 c, 42 d is configured for manual actuation, in response to detecting water production from a producing well 24, while monitoring water production from the producing well. If water production is observed, the valve member, disposed in the conduit which is conducting the injected water, may be closed to seal, or substantially seal, fluid communication between a fluid source upstream of the valve member and the at least one apparatus port 17, and thereby mitigate unnecessary water usage.
In some embodiments, for example, the valve member 42 a 42 b, 42 c, 42 d is configured for disposition above the wellhead 38 when the apparatus 10 is disposed within the wellbore 20.
In some embodiments, for example, the valve member 42 a 42 b, 42 c, 42 d is configured for disposition above the surface 40 when the apparatus 10 is disposed within the wellbore 20.

2. System

In another aspect, there is provided a system 100 including the apparatus 10, of any one of the embodiments described above, disposed within a wellbore 20.
The apparatus 10 is delivered to the wellsite, either in a single piece, or in a number of sections.
The apparatus 10 is deployed into the wellbore 20 with either an endless tubing (coiled tubing) unit, or service rig.
Sealing members 28 a, 28 b, 28 c (or 128 a, 128 b, 128 c) are installed at the time of deployment and are removed when retrieving the apparatus from the wellbore 20. Well control is maintained throughout.

3. Operation

Operation of an embodiment of the system 100, described above, will now be described. The system includes an injection well 22 and a production well 24, with an embodiment of the apparatus 10, described above, being disposed within the injection well 22. Each one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, of the deployed apparatus 10, includes at least one apparatus port, and either the conduits included such apparatus ports 17 prior to deployment downhole, or such apparatus ports 17 became defined within the conduits upon fracturing of the corresponding frangible portions.
Injection fluid is supplied to the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d of the apparatus 10 from a fluid source. The received injection fluid is injected through the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d into the subterranean formation 18. The injected fluid effects an increase to the pressure of the formation fluid within the subterranean formation 18. As a result, formation fluid may be produced from the production well 24. Alternatively, the rate of production of the formation fluid, through the production well 24, is increased.
In this respect, a method of supplying fluid into a subterranean formation 18 includes: deploying the apparatus including the bundled plurality of fluid-conducting conduits 12 a, 12 b, 12 c, 12 d into a wellbore 20, and supplying fluid, from a fluid supply source disposed above the surface 40, through the fluid-conducting conduits and into the subterranean formation 18. Where the fluid communication features 17 include frangible portions, prior to the supplying of fluid (and, in some cases, for example, as the apparatus is being deployed), fracturing of the frangible portions is effected to define respective apparatus ports 17.
In some embodiments, for example, the supplying includes: supplying a first zone 18A of the subterranean formation through a port 17 of a first one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, and supplying a second zone 18B of the subterranean formation through a port 17 of a second one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d. The port of the first one of the fluid-conducting conduits is spaced-apart from the port of the second one of the fluid-conducting conduits by a distance of at least 15 metres.
In some embodiments, for example, sealing, or substantial sealing, of fluid communication, through the wellbore, between the port 17 of the first one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d and the port 17 of the second one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d, is effected.
In some embodiments, for example, the method further includes controlling the flow of fluid through the first one of the fluid-conducting conduits 12 a, 12 b, 12 c, 12 d with a first valve (e.g. valve member 42 a), and controlling the flow of fluid through the second one of the fluid-conducting conduits with a second valve (e.g. valve member 42 b) that is different that the first valve (e.g. valve member 42 a). Both of the first and second valves are disposed above the surface 40.
In some embodiments, for example, the method further includes injecting of injection fluids, through the bundled fluid-conducting conduits, into the subterranean formation 17, such that pressure of formation fluids within the subterranean formation is increased, thereby inducing production, or increasing the rate of production, of formation fluids from the subterranean formation through a production well 24.
During operation, the production well 24 is monitored for water production. When water production from the production well 24 is detected, the valve member (e.g. valve member 42 a), disposed in the conduit which is conducting the injected water, may be manually closed to seal, or substantially seal, fluid communication between a fluid source upstream of the valve member (e.g. valve member 42 a) and the at least one apparatus port 17, thereby terminating, or at least suspending, injection of the injection fluid, and thereby mitigate unnecessary water usage. In combination, a valve member (e.g. valve member 42 b), disposed in another conduit, may be opened to thereby stimulate production from another zone within the subterranean formation.
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.

Claims

1. An apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising:

a plurality of fluid-conducting conduits, each one of the fluid-conducting conduits, independently, including a respective conduit fluid passage and a respective at least one first fluid communication feature, such that a plurality of first fluid communication features is provided, wherein each one of the first fluid communication features, independently, includes one of:

(a) a first fluid conducting port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the first fluid conducting port is respective, externally of the respective fluid-conducting conduit; and

(b) a first frangible portion adapted to fracture to define a first fluid conducting port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the first frangible portion is respective, externally of the respective fluid-conducting conduit;

a carrier conduit including, respective to each one of the fluid-conducting conduits, at least one second fluid communication feature, such that a plurality of second fluid communication features is provided, wherein each one of the second fluid communication features, independently, includes one of:

(a) a second fluid conducting port for conducting fluid, received from at least one first fluid conducting port of the fluid-conducting conduit to which the second fluid conducting port, of the carrier conduit, is respective, to a subterranean zone of the subterranean formation; and

(b) a second frangible portion adapted to fracture to define a second fluid conducting port for conducting fluid, received from at least one first fluid conducting port of the fluid-conducting conduit to which the second frangible portion, of the carrier conduit, is respective, to a subterranean zone of the subterranean formation;

wherein the plurality of fluid-conducting conduits is disposed within the carrier conduit; and wherein the carrier conduit is disposed in sealing engagement, or substantially sealing engagement, with the plurality of fluid-conducting conduits such that sealing, or substantial sealing, of fluid communication, within the carrier conduit, between (i) the at least one first fluid communication feature of one of the fluid-conducting conduits and, at least, (ii) the at least one first fluid communication feature of another one of the fluid-conducting conduits, is effected.

2. The apparatus as claimed in claim 1, wherein each one of the fluid-conducting conduits includes tubing.

3. The apparatus as claimed in claim 1;

wherein each one of the first fluid communication features, independently, includes a first fluid conducting port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the first fluid conducting port is respective, externally of the fluid-conducting conduit;

and wherein each one of the second fluid communication features, independently, includes a second fluid conducting port for conducting fluid, received from at least one first fluid conducting port of the fluid-conducting conduit to which the second fluid conducting port is respective, to a subterranean zone of the subterranean formation.

4. The apparatus as claimed in claim 1;

wherein each one of the first fluid communication features, independently, includes a first frangible portion adapted to fracture to define a first fluid conducting port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the first frangible portion is respective, externally of the respective fluid-conducting conduit;

and wherein each one of the second fluid communication features, independently, includes a second frangible portion adapted to fracture to define a second fluid conducting port for conducting fluid, received from at least one first fluid conducting port of the fluid-conducting conduit to which the second frangible portion is respective, to a subterranean zone of the subterranean formation.

5. A system including the apparatus, as claimed in claim 1, disposed within a wellbore.

6. An apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising:

a plurality of fluid-conducting conduits, each one of the fluid-conducting conduits, independently, including a conduit fluid passage; and

respective to each one of the fluid-conducting conduits, at least one fluid communication feature, such that a plurality of fluid communication features is provided, wherein each one of the fluid communication features, independently, includes one of:

(a) an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the apparatus port is respective, to a subterranean zone of the subterranean formation; and

(b) a frangible portion adapted to fracture to define an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible portion is respective, to a subterranean zone of the subterranean formation;

wherein, the at least one fluid communication feature, respective to a one of the fluid-conducting conduits, is spaced apart from the at least one fluid communication feature respective to another one of the fluid-conducting conduits.

7. The apparatus as claimed in claim 6, wherein the spacing apart is by a minimum distance of at least 15 metres.

8. The apparatus as claimed in claim 7, wherein the at least one fluid communication feature, respective to a one of the fluid-conducting conduits, is spaced apart from every other fluid communication feature that is respective to another one of the fluid-conducting conduits.

9. The apparatus as claimed in claim 8, wherein the spacing apart is by a minimum distance of at least 15 metres.

10. The apparatus as claimed in claim 6;

wherein each one of the fluid communication features, independently, includes an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the apparatus port is respective, to a subterranean zone of the subterranean formation.

11. The apparatus as claimed in claim 6;

wherein each one of the fluid communication features, independently, includes a frangible portion adapted to fracture to define an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible portion is respective, to a subterranean zone of the subterranean formation;

12. A system comprising the apparatus, as claimed in claim 6, disposed within a wellbore.

13. An apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising:

a plurality of fluid-conducting conduits, each one of the fluid-conducting conduits, independently, including a conduit fluid passage; and respective to each one of the fluid-conducting conduits, at least one fluid communication feature, such that a plurality of fluid communication features is provided, wherein each one of the fluid communication features, independently, includes one of:

respective to at least one of the fluid-conducting conduits, a pair of sealing members extending from the fluid-conducting conduit, wherein the at least one fluid communication feature, of the fluid-conducting conduit to which the pair of sealing members is respective, is disposed between the pair of sealing members;

and wherein the pair of sealing members is configured such that, when the apparatus is deployed within the wellbore, the sealing members are disposed, or deployable into a disposition, to prevent, or substantially prevent, fluid communication, through a wellbore annulus, between: (i) the at least one fluid communication feature, disposed between the pair of sealing members, and (ii) a fluid communication feature of another one of the fluid-conducting conduits.

14. The apparatus as claimed in claim 13, wherein the pair of sealing members is configured such that, when the apparatus is deployed within the wellbore, the sealing members are disposed in, or deployable into a disposition of, sealing, or substantially sealing, engagement with a surface that, in co-operation with at least the apparatus, defines a wellbore annulus.

15. The apparatus as claimed in claim 14, wherein the surface is a portion of the subterranean formation.

16. The apparatus as claimed in claim 14, wherein the surface is that of a portion of a casing that is lining the wellbore, or a portion of a liner that is hanging from the casing.

17. The apparatus as claimed in claim 13, wherein each one of the sealing member includes a packer.

18. The apparatus as claimed in claim 13, wherein, the pair of scaling members is configured such that, when the apparatus is deployed within the wellbore, and injection fluid is being injected from the at least one apparatus port into a subterranean zone, the pair of sealing members effects isolation, or substantial isolation, of the injected injection fluid from the remainder of the subterranean formation.

19. The apparatus as claimed in claim 13;

20. The apparatus as claimed in claim 13;

wherein each one of the fluid communication features, independently, includes a frangible portion adapted to fracture to deline an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible port is respective, to a subterranean zone of the subterranean formation.

21. A system comprising the apparatus, as claimed in claim 13, disposed within a wellbore.

22. An apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising:

wherein, the pair of sealing members is configured such that, when the apparatus is deployed within the wellbore, and the pair of sealing members are disposed in sealing engagement with the formation, and injection fluid is being injected, from at least one apparatus port of the fluid-conducting conduit to which the pair of sealing members is respective, into a subterranean zone, the pair of sealing members effect isolation, or substantial isolation, of the injected injection fluid from the remainder of the subterranean formation.

23. The apparatus as claimed in claim 22;

wherein each one of the sealing members includes a packer.

24. The apparatus as claimed in claim 22;

25. The apparatus as claimed in claim 22;

wherein each one of the fluid communication features, independently, includes a frangible portion adapted to fracture to define an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the frangible port is respective, to a subterranean zone of the subterranean formation.

26. A system comprising the apparatus, as claimed in claim 22, disposed within a wellbore.

27. An apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising:

wherein the pair of sealing members is configured such that, when the apparatus is deployed within the wellbore, the sealing members are disposed in, or deployable into a disposition of, sealing engagement or substantially sealing engagement with a surface that, in co-operation with at least the apparatus, defines a wellbore annulus.

28. The apparatus as claimed in claim 27, wherein the surface is a portion of the subterranean formation.

29. The apparatus as claimed in claim 27, wherein the surface is that of a portion of a casing that is lining the wellbore, or a portion of a liner that is hanging from the casing.

30. The apparatus as claimed in claim 27, wherein each one of the sealing members includes a packer.

31. The apparatus as claimed in claim 27; wherein each one of the fluid communication features, independently, includes an apparatus port for conducting fluid, when fluid is flowing through the conduit fluid passage to which the apparatus port is respective, to a subterranean zone of the subterranean formation.

32. The apparatus as claimed in claim 27;

33. A system comprising the apparatus, as claimed in claim 27, disposed within a wellbore.

34. An apparatus for effecting injection of injection fluids into a subterranean formation, including bundled conduits comprising:

wherein each one of the fluid-conducting conduits, independently, includes a valve member configured for at least interfering with fluid communication, through the fluid passage, between a fluid source upstream of the valve and the at least one apparatus port.

35. The apparatus as claimed in claim 34, wherein the valve member is configured for disposition between an open condition and a closed condition, wherein, in the open condition, fluid communication, through the fluid passage, is effected between a fluid source upstream of the valve member and the at least one apparatus port, and wherein, in the closed condition, sealing, or substantial sealing of fluid communication, through the fluid passage, between a fluid source upstream of the valve member and the at least one apparatus port, is effected.

36. The apparatus as claimed in claim 34, wherein the valve member, of each one of the fluid-conducting conduits, is configured for disposition above the wellhead when the apparatus is disposed within the wellbore.

37. The apparatus as claimed in claim 34, wherein the valve member, of each one of the fluid-conducting conduits, is configured for disposition above the surface when the apparatus is disposed within the wellbore.

38. The apparatus as claimed in claim 34;

39. The apparatus as claimed in;

40. A system comprising the apparatus, as claimed in claim 34, disposed within a wellbore.

41. A method of supplying fluid into a subterranean formation, comprising:

deploying bundled conduits, including a plurality of fluid-conducting conduits, into a wellbore: and

supplying fluid, from a fluid supply source disposed above the surface, through the fluid-conducting conduits and into the subterranean formation.

42. The method as claimed in claim 41;

wherein the supplying includes:

supplying a first zone of the subterranean formation through a port of a first one of the fluid-conducting conduits; and

supplying a second zone of the subterranean formation through a port of a second one of the fluid-conducting conduits;

wherein the port of the first one of the fluid-conducting conduits is spaced-apart from the port of the second one of the fluid-conducting conduits by a distance of at least 15 metres.

43. The method as claimed in claim 42;

wherein sealing, or substantial sealing, of fluid communication, through the wellbore, between the port of the first one of the fluid-conducting conduits and the port of the second one of the fluid-conducting conduits, is effected.

44. The method as claimed in claim 41, further comprising:

controlling the flow of fluid through the first one of the fluid-conducting conduits with a first valve; and

controlling the flow of fluid through the second one of the fluid-conducting conduits with a second valve that is different than the first valve;

wherein both of the first and second valves are disposed above the surface.

45. The method as claimed in claim 41, further comprising:

injecting injection fluids, through the fluid-conducting conduits, into the subterranean formation, such that pressure of formation fluids within the subterranean formation is increased, thereby inducing production, or increasing the rate of production, of formation fluids from the subterranean formation through a production well.

46. The method as claimed in claim 45, further comprising:

producing the pressurized formation fluids from the production well.