This disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, in an example described below, more particularly provides for retrieval of a multi-component plunger in a plunger lift system for a well.
A plunger lift system is typically used to remove an accumulation of liquid (such as, water, gas condensate, oil, mixtures thereof, etc.) from a well. In many cases where the well is for production of hydrocarbon gas, the accumulation of liquid in the well may be undesirable, in that the liquid can impede flow of the gas to surface.
Therefore, it will be appreciated that improvements are continually needed in the arts of constructing and operating plunger lift systems. Such improvements may be useful in a variety of different applications, including but not limited to displacement of liquids from production wells.
Representatively illustrated in
In the
Although the wellbore 12 is depicted in the drawings as being generally vertically oriented, in other examples the wellbore 12 could be inclined or deviated relative to vertical. In addition, it is not necessary for any particular section of the wellbore 12 to be lined with casing or cement.
Although, for clarity of illustration, only one string of the casing 18 is depicted in the drawings, it will be appreciated by those skilled in the art that multiple strings of casing are typically used. Thus, the scope of this disclosure is not limited to any numbers, combinations or configurations of various elements of the well system 10 as depicted in the drawings or described herein.
A tubular string 22 is positioned in the casing 18 for producing the gas 16 to surface via a flow passage 24 extending longitudinally through the tubular string 22. The tubular string 22 could comprise, for example, a production tubing string. The tubular string 22 could be continuous or made up of individual sections connected together. Any type of tubular string may be used in keeping with the scope of this disclosure.
The casing 18 and tubular string 22 extend to a wellhead 26 at the surface. The “surface” may be at a land-based or a water-based wellsite (e.g., the wellhead 26 could be positioned on land, on a sea floor or otherwise below water, etc.).
Connected above the wellhead 26 is a lubricator 28 having an internal flow passage 30 in communication with the flow passage 24 of the tubular string 22. Such communication between the lubricator flow passage 30 and the tubular string flow passage 24 can be permitted or prevented by selective operation of a master valve 32 connected between the lubricator 28 and the wellhead 26.
The lubricator 28, in this example, is part of a plunger lift system 34 that displaces liquid 36 from the tubular string 22. By reducing accumulation of the liquid 36 in the tubular string 22, the gas 16 can be much more readily produced from the formation 14. However, it should be clearly understood that the scope of this disclosure is not limited to any particular function, purpose, application or benefit for, or derived from, use of the plunger lift system 34.
In the
The plunger lift system 34, in this example, further includes a plunger catcher 42, and a controller 44 for controlling operation of the plunger catcher 42. When the sleeve 38 is appropriately received in the flow passage 30 of the lubricator 28, the plunger catcher 42 can be actuated to engage and secure the sleeve 38 in the lubricator 28.
For example, the plunger catcher 42 may include a key, lug, dog or other engagement member 46 extendable into engagement with the sleeve 38 in the lubricator 28. The plunger catcher 42 could include a piston, motor, solenoid, diaphragm or other type of actuator for displacing the member 46 in response to a signal received from the controller 44.
The controller 44 may be programmed to selectively release and secure the sleeve 38 for a variety of different purposes. For example, the controller 44 may be programmed to release the sleeve 38 into the tubular string 22 a certain amount of time after the closure 40 has been released into the tubular string 22, so that the sleeve 38 engages the closure 40 soon after the closure 40 has contacted a bumper spring 48 near a lower end of the flow passage 24. The amount of time may be determined based, for example, on drag characteristics of the sleeve 38 and closure 40, flow rate of the gas 16, length and inclination of the flow passage 24, etc.).
Inputs to the controller 44 could be provided manually (such as, via a keyboard, mouse, touch screen, voice recognition, data storage media, etc.), or automatically (such as, via wired or wireless transmission from various instruments or sensors 50). The controller 44 could be programmed to automatically initiate a plunger lift operation in response to certain conditions (such as, a certain reduction in pressure or flow rate as detected by one or more of the sensors 50).
Note that the sleeve 38, closure 40, plunger catcher 42 and controller 44 may be similar to those described in US publication no. 2016/0090827, which is incorporated herein in its entirety for all purposes by this reference. However, the scope of this disclosure is not limited to use of any particular configuration of the sleeve 38, closure 40, plunger catcher 42 or controller 44.
As viewed in
In one example, the sleeve 38 and closure 40 could be installed in the flow passage 30 of the lubricator 28, with the master valve 32 closed, by removing an upper portion of the lubricator 28 (such as, an upper cap or flanged connection).
The sleeve 38 could be secured in the lubricator 28 using the plunger catcher 42, and then the upper portion of the lubricator 28 could be reconnected to the lubricator.
To release the closure 40 into the flow passage 24 of the tubular string 22, the master valve 32 is opened. To release the sleeve 38 into the flow passage 24 of the tubular string 22, the plunger catcher 42 is actuated to disengage from the sleeve 38. The controller 44 can actuate the plunger catcher 42 to release the sleeve 38 a predetermined amount of time after the closure 40 is released.
As viewed in
The sleeve 38 has also descended through the flow passage 24 to the closure 40, so that the closure 40 is received in a central longitudinal flow path 52 formed through the sleeve 38 (not visible in
In various examples described in the US publication no. 2016/0090827 mentioned above, the plunger closure is in the form of an elongated spear having an external sealing surface formed thereon which sealingly engages an internal sealing surface formed in the plunger sleeve. The plunger closure (spear) is shaped to reduce drag as it descends through a tubing string.
As used herein, the term “closure” is used in the sense of a structure that closes off, blocks or prevents flow. In the present example, the plunger closure 40 substantially blocks or completely prevents flow through the plunger 54. A closure can have various shapes and forms, including but not limited to, a plug, spear, sleeve, dart, etc.
In some examples incorporating the principles of this disclosure, the plunger closure 40 could be in the form of a sleeve that is configured to cooperatively engage the plunger sleeve 38 to block flow through the flow path 52. In one example, the plunger closure 40 in the shape of a sleeve could receive the plunger sleeve 38 at least partially therein, to thereby close off the flow path 52, which extends through a side wall of the plunger sleeve 38. Thus, it should be clearly understood that the scope of this disclosure is not limited to any particular configuration or other details of the plunger sleeve 38 or plunger closure 40 as depicted in the drawings or described herein.
As viewed in
The plunger 54 and the liquid 36 are displaced upward through the tubular string 22 to the surface by the pressure differential across the plunger 54. The pressure differential can be maintained across the plunger 54 as it ascends through the tubular string 22, due to the closure 40 blocking fluid flow through the flow path 52 of the sleeve 38, and due to the restriction to flow between the sleeve 38 and the interior of the tubular string 22.
As viewed in
The plunger 54 continues to displace upward in the lubricator 28, until an upper end of the closure 40 contacts a strike pad 58 disposed near an upper end of the flow passage 30. This contact disengages the closure 40 from the sleeve 38, so that the pressure differential can no longer be maintained across the plunger 54, and the closure 40 is then permitted to displace downwardly away from the sleeve 38.
The sleeve 38 is secured in the lubricator 28 by the plunger catcher 42 when the plunger 54 is appropriately received in the lubricator flow passage 30. In this manner, the closure 40 can again descend through the tubular string 22, separate from the sleeve 38, after the closure 40 contacts the strike pad 58 and is thereby disengaged from the sleeve 38.
As viewed in
Thus, the steps depicted in
When it is desired to retrieve the plunger 54 from the well (for example, due to the liquid 36 having been sufficiently removed from the well, or for maintenance or replacement of the plunger 54), a plunger retrieval device 60 (see
As viewed in
The plunger sleeve 62 may be substantially the same as the plunger sleeve 38, other than the addition of the plunger retrieval device 60. In some examples, the plunger sleeve 62 could be longer than the plunger sleeve 38, so that, when the closure 40 is received in the plunger sleeve 62, the closure 40 does not extend upwardly from the plunger sleeve 62 and thus cannot contact the strike pad 58 in the lubricator 28.
As viewed in
However, in the retrieval operation of
The plunger catcher 42 is actuated to secure the sleeve 62 in the lubricator 28, as viewed in
Referring additionally now to
The plunger lift system 34 example of
When the plunger 54 is next received in the lubricator 28 (as viewed in
The plunger 54 can now be removed by closing the master valve 32 and disconnecting the upper portion of the lubricator 28 from the lubricator. The upper portion of the lubricator 28 can be reconnected to the lubricator after removing the plunger 54 from the lubricator 28, and the master valve 32 can then be opened to resume production.
Referring additionally now to
In the
When the closure 40 is received sufficiently into the flow path 52, the latch member 66 is initially urged radially outward by the closure 40, and then the latch member 66 is resiliently biased radially inward by the spring 68. The latch member 66, thus, is received in a radially reduced profile 70 formed near an upper end of the closure 40 (for example, of the type known to those skilled in the art as a “fishing neck” profile). A shoulder 72 formed at an upper end of the profile 70 will engage the latch member 66 to prevent separation of the closure 40 from the sleeve 62.
Note that the sleeve 62 extends upwardly further than the closure 40. This can, in some examples, prevent the closure 40 from contacting the strike pad 58 in the lubricator 28 (see
Referring additionally now to
In the
Referring additionally now to
In the
When the plunger 54 is received sufficiently far into the lubricator flow passage 30, the collets 74 will be initially urged radially outward by the closure 40, and then the collets 74 will be resiliently biased radially inward and received in the profile 70. The shoulder 72 will engage the collets 74 to prevent separation of the closure 40 from the plunger retrieval device 60, and thereby secure the plunger 54 in the lubricator 28.
It may now be fully appreciated that the above disclosure provides significant advancements to the arts of constructing and operating plunger lift systems. In examples described above, the plunger 54 can be conveniently and reliably retrieved from a well, either as a unit (e.g., the combined sleeve 38 and closure 40) or by separate components (e.g., the sleeve 38 first, and then the combined closure 40 and sleeve 62).
The above disclosure provides to the art a method of operating a plunger lift system 34 for a subterranean well. In one example, the method comprises: introducing a plunger sleeve 38 or 62 and a plunger closure 40 into the well; engaging the plunger sleeve 38/62 with the plunger closure 40; securing the plunger sleeve 38/62 and the plunger closure 40 to each other in a flow passage 24 or 30 of the well; and then retrieving the plunger sleeve 38/62 and the plunger closure 40 from the well.
The securing step may include a plunger retrieval device 60 preventing displacement of the plunger sleeve 38/62 and the plunger closure 40 away from each other.
The introducing step may include introducing the plunger retrieval device 60 with the plunger sleeve 62 into the well.
The securing step may include the plunger retrieval device 60 confining the plunger closure 40 to displace with the plunger sleeve 62 in the well. The securing step may be performed in response to the engaging step.
The securing step may comprise disposing a plunger retrieval device 60 in a lubricator 28. The securing step may also comprise the plunger retrieval device 60 engaging the plunger closure 40 in the lubricator 28 and preventing displacement of the plunger closure 40 and the plunger sleeve 38 out of the lubricator 28.
The retrieving step may comprise retrieving the plunger sleeve 38/62 and plunger closure 40 while the plunger sleeve 38/62 and the plunger closure 40 are secured to each other.
Also provided to the art by the above disclosure is a plunger lift system 34 for use with a subterranean well. In one example, the plunger lift system 34 can include a plunger sleeve 62 configured for reciprocal displacement in a flow passage 24 of the well, a plunger closure 40 configured to block flow through a flow path 52 of the plunger sleeve 62, the plunger closure 40 being displaceable in the flow passage 24 separate from the plunger sleeve 62, and a plunger retrieval device 60 that displaces with the plunger sleeve 62 in the flow passage 24 and secures the plunger closure 40 against displacement away from the plunger sleeve 62.
The plunger retrieval device 60 may secure the plunger closure 40 against displacement away from the plunger sleeve 62 in response to engagement between the plunger closure 40 and the plunger sleeve 62 in the flow passage 24, or in response to the plunger closure 40 being received in the flow path 52 of the plunger sleeve 62.
The plunger retrieval device 60 may comprise a latch 64 connected with the plunger sleeve 62. The latch 64 may engage the plunger closure 40 in response to the plunger closure 40 being received in the flow path 52 of the plunger sleeve 62.
The plunger retrieval device 60 may comprise resilient collets 74 connected with the plunger sleeve 62. The collets 74 may engage the plunger closure 40 in response to the plunger closure 40 being received in the flow path 52 of the plunger sleeve 62.
Another plunger lift system 34 for use with a subterranean well is described above. In this example, the plunger lift system 34 includes a plunger sleeve 38 configured for reciprocal displacement in a flow passage 24 of the well, a plunger closure 40 configured to block flow through a flow path 52 of the plunger sleeve 38, the plunger closure 40 being displaceable in the flow passage 24 separate from the plunger sleeve 38, and a plunger retrieval device 60 positioned in a lubricator 28. The plunger retrieval device 60 engages the plunger closure 40 and secures the plunger closure 40 against displacement away from the plunger sleeve 38 in the lubricator 28.
The plunger retrieval device 60 may secure the plunger closure 40 against displacement away from the plunger sleeve 38 in response to engagement between the plunger closure 40 and the plunger retrieval device 60 in the lubricator 28, or in response to the plunger closure 40 and the plunger sleeve 38 being received in the lubricator 28.
The plunger retrieval device 60 may comprise resilient collets 74 disposed in a flow passage 30 of the lubricator 28. The collets 74 may engage the plunger closure 40 in response to the plunger closure 40 and the plunger sleeve 38 being received in the lubricator 28.
Although various examples have been described above, with each example having certain features, it should be understood that it is not necessary for a particular feature of one example to be used exclusively with that example. Instead, any of the features described above and/or depicted in the drawings can be combined with any of the examples, in addition to or in substitution for any of the other features of those examples. One example's features are not mutually exclusive to another example's features. Instead, the scope of this disclosure encompasses any combination of any of the features.
Although each example described above includes a certain combination of features, it should be understood that it is not necessary for all features of an example to be used. Instead, any of the features described above can be used, without any other particular feature or features also being used.
It should be understood that the various embodiments described herein may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of this disclosure. The embodiments are described merely as examples of useful applications of the principles of the disclosure, which is not limited to any specific details of these embodiments.
In the above description of the representative examples, directional terms (such as “above,” “below,” “upper,” “lower,” etc.) are used for convenience in referring to the accompanying drawings. However, it should be clearly understood that the scope of this disclosure is not limited to any particular directions described herein.
The terms “including,” “includes,” “comprising,” “comprises,” and similar terms are used in a non-limiting sense in this specification. For example, if a system, method, apparatus, device, etc., is described as “including” a certain feature or element, the system, method, apparatus, device, etc., can include that feature or element, and can also include other features or elements. Similarly, the term “comprises” is considered to mean “comprises, but is not limited to.”
Of course, a person skilled in the art would, upon a careful consideration of the above description of representative embodiments of the disclosure, readily appreciate that many modifications, additions, substitutions, deletions, and other changes may be made to the specific embodiments, and such changes are contemplated by the principles of this disclosure. For example, structures disclosed as being separately formed can, in other examples, be integrally formed and vice versa. 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 invention being limited solely by the appended claims and their equivalents.
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Number | Date | Country |
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2013131165 | Sep 2013 | WO |
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Number | Date | Country | |
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20180100381 A1 | Apr 2018 | US |