SEPARABLE COMPLETION ARCHITECTURE
A technique facilitates performance of a work over on a completion used in a wellbore. The completion comprises an upper completion coupled with a lower completion by a mandrel and a latch. When a work over is to be performed, the upper completion is separated by moving a cutter device down along the mandrel and operating the cutting device to sever the mandrel. Once the mandrel has been severed, the latch may be activated to release the upper completion for removal.
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CROSS-REFERENCE TO RELATED APPLICATION
The present document is based on and claims priority to U.S. Provisional Application Ser. No.: 61/649,610, filed May 21, 2012, incorporated herein by reference.
Hydrocarbon fluids such as oil and natural gas are obtained from a subterranean geologic formation, referred to as reservoir, by drilling a well that penetrates the hydrocarbon-bearing formation. In a variety of downhole applications, completions are deployed downhole to facilitate many types of well related operations. In some applications, a lower completion and an upper completion are both deployed downhole into a wellbore. When the upper completion is in need of service or updating, a work over is sometimes performed by pulling the entire completion or by separately pulling the upper completion. If the upper completion is separately pulled, the upper and lower completions are connected by, for example, a latch having a shear pin. The shear pin may be sheared via tubing or annulus pressure by utilizing a seal between the tubing and the annulus. However, the shear pin style latch is susceptible to inadvertent activation under high loading and/or seal failure in certain environments, e.g. subsea well environments.
In general, a system and methodology are provided for performing a work over on a completion. The completion comprises an upper completion coupled with a lower completion by a mandrel and a latch. When a work over is to be performed, the upper completion is separated by moving a cutting device down along the mandrel and operating the cutting device to sever the mandrel. Once the mandrel has been severed, the latch may be activated to release the upper completion for removal.
However, many modifications are possible without materially departing from the teachings of this disclosure. Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.
BRIEF DESCRIPTION OF THE DRAWINGS
Certain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements. It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and:
In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure. However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.
The disclosure herein generally involves a system and methodology related to utilizing a downhole completion system. By way of example, the system and methodology may be used to facilitate servicing, e.g. a work over, of a downhole completion system. The completion system comprises an upper completion and a lower completion in which the upper completion is coupled to the lower completion by a latch and a mandrel. Additionally, communication line segments, e.g. hydraulic control line segments and electric control line segments of the upper and lower completions, may be releasably engaged by at least one wet connect, e.g. an electro-hydraulic wet connect. By employing the mandrel, the completion structure is able to withstand high axial loading. Release of the upper completion can be achieved by cutting the mandrel transversely with a cutting device to enable release of the latch.
The latch and the mandrel enable the upper and lower completions to be deployed downhole into a wellbore in a single trip. According to an embodiment of the disclosure, the latch may comprise male and female portions which are joined and behave as one piece until the latch is activated. Activation of the latch enables the upper completion to be disconnected from the lower completion and pulled out of the wellbore for a work over.
To release the latch, the mandrel is transversely cut, e.g. circumferentially cut, with a suitable cutter run into the well. Examples of a suitable cutting device comprise an explosive cutter, a chemical cutter, or a mechanical cutter. The cutting device is run downhole into the wellbore via a conveyance, such as wireline, coiled tubing, slick line, pipe, or another suitable conveyance. In some embodiments, the cutting device is run downhole along an interior of the mandrel. For example, the mandrel may comprise a pipe with a hollow interior having sufficient size to enable conveyance of the cutting device down to a desired cut-through region.
Referring generally to
Depending on the specific application, completion system 30 may comprise a variety of components designed to facilitate different types of well operations, including well production operations, well treatment operations, and other well related operations. In the example illustrated in
The completion system 30 also may comprise a casing 56 and various upper completion components, such as a surface controlled subsurface safety valve 58 and a gas lift mandrel 60. Additionally, the lower completion 34 may comprise a plurality of packers 62 position to isolate well zones 38 along wellbore 36. In some applications, the lower completion 34 also may comprise at least one flow control valve 64 and a variety of sensors and/or gauges 66. By way of further example, the lower completion 34 may comprise a chemical injection mandrel 68 supplied by chemical injection lines 70. Flow control valve 64 may be actuated by hydraulic fluid supplied through corresponding hydraulic control lines 48. Additionally, the lower completion may comprise a mechanical sliding sleeve 72 or other valve system used for stimulation. Many of these components may be deployed in each well zone between sequential packers 62 to control flow with respect to the associated well zone 38.
Referring generally to
As illustrated in
In the embodiment illustrated, latch 44 is a collet-style latch and comprises a latch collet 90 having collet fingers 92 which are placed in compression and received in a latch profile 94. A latch collet support 96 securely holds collet fingers 92 in latch profile 94 until the latch 44 is actuated for release of the upper completion 32. A stop housing 98 and associated stop 100 may be employed to facilitate movement when activating latch 44 and to provide support for withdrawal of the upper completion 32.
The mandrel 42 and latch 44 securely combine the upper completion 32 and lower completion 34 for conveyance downhole into wellbore 36 with packers 62 in the contracted position illustrated in
Once packers 62 are set, a desired well operation may be initiated. For example, a well injection operation, such as a well treatment, may be initiated by pumping fluid into the desired well zones 38. The well operation also may comprise producing fluids from the well zones 38. As illustrated in
If a work over of upper completion 32 is desired due to development of a downhole problem or for another suitable reason, separation of the upper completion 32 from the lower completion 34 is initiated. As illustrated in
After forming transverse cut 110, the mandrel 42 is separated into pieces which allows the upper completion 32 to be lifted or picked up by, for example, the upper portion of production tubing forming mandrel 42 (as illustrated in
When the work over is completed and/or when a different upper completion 32 is prepared, the upper completion 32 is again lowered down into wellbore 36 for engagement with lower completion 34, as illustrated in
Referring generally to
The simplified contraction joint 54 also may comprise a seal stack 124 which seals against an internal, slidable tube/mandrel 126 having a stop 128 which is movably captured within stroke region 114. Other features of contraction joint 54 may comprise a slot (or slots) for receiving the cable/flat pack 86. A clamp 132 may be used to secure the cable 86 in slot 130. In the example illustrated, a segment of production tubing 112 also extends below the contraction joint 54 and into latch 44.
Referring generally to
Similar to the previously described embodiment, release of the upper completion 32 and separation of latch 44 initially involves movement of cutting device 104 downhole, as illustrated in
After forming transverse cut 110, the pieces of mandrel 42 are separated, when the upper completion 32 is lifted or picked up by, for example, production tubing 112, as illustrated in
When the work over is completed and/or when a different upper completion 32 is prepared, the reworked or new upper completion 32 is again lowered down into wellbore 36 for engagement with lower completion 34, as illustrated in
As described herein, the completion system may be used in a variety of applications, including numerous well production and treatment applications. Depending on the specifics of a given tool system, well application, and environment, the design of the overall completion system 30, upper completion 32, lower completion 34, mandrel 42, latch 44, wet connect 52, contraction joint 54, and other components may vary. Additionally, the completion system may be designed for use in many types of wells, including vertical wells and deviated, e.g. horizontal, wells. The wells may be drilled in many types of formations with single or multiple production zones. Additionally, a variety of cutting devices may be used to sever the mandrel from an internal position and/or an external position. The specific cutting mechanism also may be designed in a variety of forms or combinations of forms.
Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure. Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.
1. A method for utilizing a downhole completion system, comprising:
- coupling an upper completion with a lower completion via a latch and a mandrel;
- deploying the upper completion and the lower completion downhole into a wellbore in a single trip; and
- separating the upper completion from the lower completion by cutting transversely through the mandrel and releasing the latch.
2. The method as recited in claim 1, wherein separating comprises cutting through the mandrel with an explosive.
3. The method as recited in claim 1, wherein separating comprises cutting through the mandrel with a chemical cutter.
4. The method as recited in claim 1, wherein separating comprises cutting through the mandrel with a mechanical cutter.
5. The method as recited in claim 1, wherein coupling comprises coupling with the latch via a collet having collet fingers held radially outward into engagement with a latch profile.
6. The method as recited in claim 1, wherein coupling comprises coupling with the latch via a collet having collet fingers held radially inward into engagement with a latch profile.
7. The method as recited in claim 1, wherein separating comprises lifting the upper completion to release the latch after cutting transversely through the mandrel.
8. The method as recited in claim 1, wherein coupling comprises coupling via the mandrel in the form of a tubing.
9. The method as recited in claim 1, further comprising coupling a plurality of control lines with a hydro-electric wet connect.
10. The method as recited in claim 9, wherein separating comprises separating the hydro-electric wet connect and the plurality of control lines.
11. A method for performing a work over on a completion, comprising:
- moving a cutter device down along an interior of a tubing coupling an upper completion with a lower completion in a wellbore;
- operating the cutter device within the tubing to sever the tubing; and
- removing the upper completion from the wellbore.
12. The method as recited in claim 11, further comprising lifting the upper completion after severing the tubing to release a latch.
13. The method as recited in claim 11, further comprising lifting the upper completion after severing the tubing to release a collet of a latch.
14. The method as recited in claim 12, further comprising separating communication lines at a wet connect.
15. The method as recited in claim 12, further comprising separating electric and hydraulic communication lines at a hydro-electric wet connect.
16. The method as recited in claim 11, wherein moving comprises moving an explosive cutter device.
17. The method as recited in claim 11, wherein moving comprises moving a mechanical cutter device.
18. A system, comprising:
- a lower completion;
- an upper completion; and
- a coupling system coupling the upper completion to the lower completion, the coupling system having a latch and a mandrel with a cut-through region, the latch and the mandrel cooperating such that cutting the mandrel at the cut-through region severs the mandrel into a plurality of pieces and enables release of the latch.
19. The system as recited in claim 18, further comprising a hydro-electric wet connect releasably coupling a plurality of control lines extending from the upper completion to the lower completion.
20. The system as recited in claim 18, further comprising a cutter device deployed along an interior of the mandrel.
International Classification: E21B 17/02 (20060101);