The present invention relates generally to operations performed and equipment utilized in conjunction with subterranean wells and, in an embodiment described herein, more particularly provides multilateral well completion systems and methods.
A typical multilateral well includes multiple lateral or branch wellbores. The multiple branch wellbores could be used for variously injecting, transferring, storing and producing fluids in these wells. However, at present no satisfactory systems and methods are commercially available for accomplishing these functions conveniently, cost effectively and reliably in multilateral wells.
Furthermore, it is difficult if not impossible to change a typical multilateral completion system without pulling the system from the well. Thus, if well conditions change, for example, if it is desired to inject or store fluids in a zone which was formerly produced, typical multilateral completion systems must be pulled from the well and be reconfigured or replaced to conform to the new well conditions.
Therefore, it is well known by those skilled in the art that improved systems and methods are needed for multilateral well completions. Preferably, such improved multilateral well completion systems and methods should be adaptable to changing well conditions and configurable to suit a variety of situations.
In carrying out the principles of the present invention, in accordance with an embodiment thereof, a well completion system is provided which includes the capability of performing a variety of functions with convenience and economy. Associated methods are also provided.
In one aspect of the invention, a system for completing a well having a first wellbore intersecting each of second, third and fourth wellbores is provided. The system includes a casing string positioned in the first wellbore. A first fluid is injected into the second wellbore. A second fluid is received into the third wellbore. The second fluid may be flowed into the third wellbore in response to the first fluid flowing into the second wellbore.
The second fluid is transferred from the third wellbore to the fourth wellbore for storage therein and later production. The transfer of the second fluid is accomplished by way of a passage in the first wellbore isolated from the casing string.
In another aspect of the invention, a method of completing a well having a first wellbore intersecting each of second, third and fourth wellbores is provided. The method includes the steps of: injecting a first fluid into a first zone intersected by the second wellbore; receiving a second fluid into the third wellbore in response to the first fluid injecting step; flowing the second fluid from the third wellbore to the fourth wellbore; storing the second fluid in a second zone intersected by the fourth wellbore; and then producing the second fluid from the second zone to a remote location.
In yet another aspect of the invention, another method of completing a well having a first wellbore intersecting each of second, third and fourth wellbores is provided. The method includes the steps of: interconnecting first, second and third apparatuses in a casing string, each of the apparatuses having a first passage forming a part of a longitudinal flow passage of the casing string, and a second passage intersecting the first passage; positioning the casing string in the first wellbore; injecting a first fluid through the first apparatus second passage into the second wellbore; receiving a second fluid from the third wellbore into the second apparatus second passage; flowing the second fluid from the second apparatus to the third apparatus; and storing the second fluid in a zone intersected by the fourth wellbore.
These and other features, advantages, benefits and objects of the present invention will become apparent to one of ordinary skill in the art upon careful consideration of the detailed description of representative embodiments of the invention hereinbelow and the accompanying drawings.
Representatively illustrated in
The incorporated copending applications describe how an apparatus, such as the apparatus 12 depicted in
The incorporated copending applications also describe how fluid communication may be provided between apparatuses interconnected in a casing string using passages formed in the apparatuses and selectively isolated from an internal flow passage of the casing string. In the system 10, the upper two apparatuses 12, 18 are in fluid communication via a passage 26 formed in each of the apparatuses. The passage 26 is visible in
Each of the apparatuses 12, 18, 20 has a passage 28 formed longitudinally therethrough which is a part of an internal longitudinal flow passage 30 of the casing string 14. Each of the apparatuses 12, 18, 20 also has a passage 32 which intersects and extends laterally relative to the passage 28. The branch wellbores 16, 22, 24 are drilled by deflecting cutting tools from the passage 28 through the passage 32 of the corresponding one of the apparatuses 12, 18, 20.
The upper apparatus 12 includes a flow control device 34 which controls flow between the passage 32 and the passage 26, and which also controls flow between the passages 32, 28 of the apparatus 12. The flow control device 34 is depicted in
The middle apparatus 18 also includes a flow control device 40 which is similar to the flow control device 34 described above. The flow control device 40 also controls flow between the passages 26, 32 and between the passages 28, 32 in the apparatus 18.
The lower apparatus 20 also includes a flow control device 42 which is similar in many respects to the flow control devices 34, 40. However, the lower apparatus 20 does not have the passage 26 formed therein, so the flow control device 42 only controls flow between the passages 28, 32 in the lower apparatus.
In each of the apparatuses 12, 18, 20, a plug 44 is installed after the corresponding one of the branch wellbores 16, 22, 24 is drilled. The plug 44 prevents direct flow between the passages 28, 32 in each of the apparatuses 12, 18, 20.
As depicted in
Fluid (indicated by arrows 46), such as water or steam, is flowed down through the casing string 14 into the passage 28 of the lower apparatus 20. The fluid 46 flows through the flow control device 42 and through the passage 32 into the branch wellbore 24. The fluid 46 then flows outward into a formation or zone 48 intersected by the branch wellbore 24.
This flow of the fluid 46 into the zone 48 causes or at least enhances the flow of another fluid (indicated by arrows 50), such as oil or gas, into the branch wellbore 22. Preferably, the branch wellbore 22 intersects the same zone 48 as intersected by the branch wellbore 24. It will be readily appreciated by one skilled in the art how flowing a relatively dense fluid, such as water, into a zone will force a relatively less dense fluid, such as oil or gas to rise in a zone. In this situation, the fluid 46 is injected into a lower portion of the zone 48, and the hydrocarbon bearing fluid 50 is flowed out of an upper portion of the zone 48.
However, it should be understood that these fluids and relative positions are not necessary in keeping with the principles of the invention. For example, a relatively less dense fluid, such as gas, could be injected into an upper portion of a zone, while a relatively more dense fluid, such as oil is flowed from a lower portion of a zone.
In this situation, the apparatuses 18, 20 could be in reversed positions as compared to the configuration shown in FIG. 1. If the apparatus 20 is interconnected in the casing string 14 between the apparatuses 12, 18, then the apparatus 20 could have a cross-section as depicted in FIG. 6. This alternative cross-section provides the passage 26 through the apparatus 20 for fluid communication between the flow control devices 34, 40 of the apparatuses 12, 18.
As another alternative, the apparatus 20 could be configured similar to the other apparatuses 12, 18, wherein the flow control device 42 is also capable of controlling flow between the passages 26, 32. Thus, it will be appreciated that many different configurations are possible, and the apparatuses 12, 18, 20 may have different relative positions, without departing from the principles of the invention.
The fluid 50 received into the branch wellbore 22 is flowed through the flow control device 40 and into the passage 26 in the middle apparatus 18. The fluid 50 then flows from the passage 26, through the flow control device 34 and into the passage 32 in the upper apparatus 12. The fluid 50 then flows into the branch wellbore 16 and outward into a formation or zone 52 intersected by the branch wellbore 16. The zone 52 may or may not be the same as the zone 48 into which the fluid 46 is injected.
If the fluid 50 is gas, or at least less dense than the fluid 46, then the zone 52 could be an upper portion of the zone 48. For gas or oil storage, the zone 52 could also be completely isolated from the zone 48. Note that the injected fluid 46 could be gas, in which case the fluid 50 could be stored in the zone 52 which could be a lower portion of the zone 48, in which case the apparatus 12 would be switched with the apparatus 20 in the casing string 14.
Thus, as depicted in
Referring additionally now to
The fluid 50 flows out of the zone 52 and into the branch wellbore 16. The fluid 50 then flows into the passage 32, through the flow control device 34 and into the passage 28. The fluid 50 may then flow through the casing string passage 30 to a remote location, such as the earth's surface.
Referring additionally now to
In this configuration, the flow control device 40 permits flow between the passages 28, 32, but prevents flow between the passages 26, 32, in the middle apparatus 18. The flow control device 34 prevents flow between the passages 26, 32 and between the passages 28, 32 in the upper apparatus 12. The flow control device 42 prevents flow between the passages 28, 32 in the lower apparatus 20.
Referring additionally now to
This configuration may be used, for example, when an emergency situation occurs. Each of the flow control devices 34, 40, 42 may perform the function of a safety valve to shut in the corresponding one of the branch wellbores 16, 22, 24. The flow control devices 34, 40, 42 may respond to a signal transmitted from a remote location (e.g., via telemetry or via the lines 38), or they may respond to conditions sensed downhole, to close off flow therethrough.
It may now be fully appreciated how the system 10 provides enhanced functionality, convenience and versatility in multilateral completions. Although only three apparatuses 12, 18, 20 are illustrated in
Note that it is not necessary for the system 10 to be configured as depicted in
Referring additionally now to
The system 60 uses three apparatuses 62, 64, 66 interconnected in a casing string 14 and cemented within a parent wellbore 67, as in the system 10. The branch wellbores 16, 22, 24 are drilled through the passages 32 of the corresponding one of the apparatuses 62, 64, 66. A plug 44 is installed after drilling to prevent direct flow between the passages 28, 32 in each of the apparatuses 62, 64, 66.
However, in the system 60 the apparatuses 62, 64, 66 are identical to each other. Each of the apparatuses 62, 64, 66 has two passages 68, 70 formed therethrough and a flow control device 72 for controlling flow between the passage 32 and each of the passages 28, 68, 70. That is, the flow control device 72 selectively permits and prevents flow between the passage 32 and each of the passages 28, 68, 70 in each of the apparatuses 62, 64, 66.
A cross-sectional view of the apparatus 62 is depicted in
To control flow between the passages 28, 32, 68, 70, the flow control device 72 is preferably of the type known to those skilled in the art as a “four way” valve. However, it should be understood that other numbers of flow control devices and other types of flow control devices could be used in keeping with the principles of the invention. For example, a separate valve could be used for controlling flow between the passage 32 and each one of the other passages 28, 68,70.
The passages 68, 70 are provided in the apparatuses 62, 64, 66 in order to isolate injection and transfer flows from the casing string flow passage 30. This configuration may be desired in situations in which fluid (indicated by arrows 74) is to be produced through the casing string flow passage 30 while fluid is being injected into one branch wellbore and fluid is being transferred between branch wellbores through the other passages 68, 70.
A fluid (indicated by arrows 76), such as gas, may be injected from the passage 68, through the flow control device 72 and into the passage 32 in the upper apparatus 62. The fluid 76 would then flow into the branch wellbore 16 and outward into a formation or zone 78 intersected by the branch wellbore. The flow control device 72 in the upper apparatus 62 would permit flow between the passages 32, 68, but prevent flow between the passages 32, 70 and between the passages 28, 32.
Flow of the fluid 76 into the zone 78 would cause, or at least enhance, flow of another fluid (indicated by arrows 80), such as oil, into the branch wellbore 22. The fluid 80 would then flow into the passage 32, through the flow control device 72 and into the passage 70 in the middle apparatus 64. The flow control device 72 would permit flow between the passages 32, 70, but would prevent flow between the passages 28, 32 and between the passages 32, 68. The fluid 80 would flow from the middle apparatus 64 to the lower apparatus 66 through the passage 70.
In the lower apparatus 66, the fluid 80 would flow from the passage 70, through the flow control device 72 and into the passage 32. The fluid 80 would then flow into the branch wellbore 24 and outward into a formation or zone 82 intersected by the branch wellbore. The flow control device 72 in the lower apparatus 66 could permit flow between the passages 32, 70, but would prevent flow between the passages 28, 32 and between the passages 32, 68.
The fluid 80 would be stored in the zone 82. The zone 82 could be a lower portion of the zone 78, or it could be completely isolated from the zone 78. The fluid 80 could be produced from the zone 82 by actuating the flow control device 72 in the lower apparatus 66 to permit flow between the passages 28, 32, but prevent flow between the passages 32, 68 and between the passages 32, 70.
It will be readily appreciated that any number of the apparatuses 62, 64, 66 could be interconnected in the casing string 14 to inject fluid into, transfer fluid between, or produce fluid from any number of branch wellbores. For example, the fluid 74 could be produced through another apparatus interconnected below the lower apparatus 66. Furthermore, the apparatuses 62, 64, 66 may have any relative position with respect to the other apparatuses, and the apparatuses may be similarly or differently configured.
Instead of injecting the fluid 76 through the casing string flow passage 30, in the system 60 the fluid is received into the upper apparatus 62 from a tubular string 84 extending to a remote location. The passage 68 extends through the tubular string 84.
The tubular string 84 is external to the casing string 14 in the parent wellbore 67 and is isolated from the casing string flow passage 30. This permits injection of the fluid 76 while the fluid 74 is produced through the casing string flow passage 30.
Another tubular string 86 could be connected to the upper apparatus 62, if desired, to convey the fluid 80 to a remote location. In that case, the passage 70 would extend through the tubular string 86, permitting the fluid 80 to flow through the tubular string 86 to the remote location, for example, for testing or for production separate from the fluid 74 produced through the casing string 14 in situations where commingling of the fluids 74, 80 is not desired, or is not permitted.
The system 60 demonstrates the wide range of multilateral well completions which may be accomplished using the principles of the invention. Fluid may be injected into any branch wellbore 16, 22, 24 by merely permitting flow between the passages 32, 68 in the associated one of the apparatuses 62, 64, 66. Fluid may be transferred between any of the apparatuses 62, 64, 66 by merely permitting flow between the passages 32, 70 in each of the apparatuses. Fluid may be produced from any of the branch wellbores 16, 22, 24 by merely permitting flow between the passages 28, 32 in the associated one of the apparatuses 62, 64, 66.
Fluid may be injected into multiple branch wellbores, transferred between more than two branch wellbores, stored in multiple branch wellbores, and produced from multiple branch wellbores simultaneously. Additional apparatuses may be interconnected in the casing string 14 to permit these operations to be performed in additional branch wellbores.
Since each apparatus has injection, fluid transfer and production capabilities (due to the passages 28, 68, 70 being formed in each apparatus), any of these operations may be performed in any of the apparatuses at any time. For example, the upper branch wellbore 16 could have produced oil when the well was initially completed. Later, after much of the oil is depleted from the upper portion of the zone 78, the branch wellbore 16 may be used to inject gas into the zone to enhance oil recovery from the lower portion of the zone via the branch wellbore 22. The gas injected into the zone 78 could be separated from the fluid 80 produced from the zone 78, or from another zone.
Of course, a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the invention, readily appreciate that many modifications, additions, substitutions, deletions, and other changes may be made to these specific embodiments, and such changes are contemplated by the principles of the present invention. For example, in either of the systems 10, 60, any of the branch wellbores 16, 22, 24 could be an extension or another portion of the parent wellbore 67, the plug 44 could be replaced by packers straddling the passage 32 in the passage 28, it is not necessary for the branch wellbores 16, 22, 24 to be drilled through the apparatuses, etc. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example only, the spirit and scope of the present invention being limited solely by the appended claims and their equivalents.
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