Patent Grant
10605011
Not Applicable.
Not Applicable
This disclosure relates to the field of wellbore pumps, such as electric submersible pumps (ESPs). More particularly, the present disclosure relates to methods and apparatus for deploying ESPs on coiled tubing having an electrical cable associated therewith, wherein the coiled tubing is used as a conduit to move fluid out of a wellbore.
Background
Wellbore fluid pumps, such as ESPs may be deployed into wellbores at the end of a conveyance such as coiled tubing. Coiled tubing pump deployment known in the art typically only uses the coiled tubing to support the weight of the ESP as it is lowered to a selected depth in the wellbore through the production tubing.
Such deployment methods may require first, that the ESP includes some form of anchor or locking and sealing mechanism to hold the ESP within the production tubing string and to isolate the intake from the discharge of the pump. Finally, specialized seal elements may be required in order to enable the electrical cable to pass through a wellhead (one or more valves disposed at the surface end of the tubing string and surface well casing) while enabling the wellhead to be closed to stop fluid flow from the wellbore if and as needed.
One aspect of the present disclosure relates to a method for deploying a pump in a wellbore, comprising:
When installed, the lower coiled tubing portion retained within the wellbore may provide a fluid conduit or passage to facilitate communication of pumped fluids to surface.
The releasable tubing connector may function to provide engagement with the suspending arrangement, for example mechanical engagement, such that the lower coiled tubing portion and pump are suspended in the wellbore via the releasable tubing connector. The method may comprise mechanically engaging the releasable tubing connector with the suspending arrangement.
The releasable tubing connector may function to provide sealing engagement with the suspending arrangement. The method may comprise sealingly engaging the releasable tubing connector with the suspending arrangement.
The suspending arrangement may comprise one or more rams provided in a wellhead assembly. For example, the suspending arrangement may comprise one or more rams of a blowout preventer (BOP), such as a rod lock BOP, coiled tubing BOP or the like.
The suspending arrangement may comprise a tubing hanger profile provided within a wellhead assembly. The method may comprise providing a tubing hanger profile on the releasable tubing connector to facilitate engagement with the tubing hanger profile provided within the wellhead assembly. The tubing hanger profile may provide one or both of mechanical and sealing engagement.
A wellhead assembly incorporating a tubing hanger profile may comprise a wellhead tree, for example.
The method may comprise deploying the coiled tubing from a reel. The releasable tubing connector may provide a connection between the upper and lower coiled tubing portions with minimal disruption to the ability to coil or spool the coiled tubing on the reel. The releasable tubing connector may also be defined as a spoolable connector.
An electrical cable may extend through the coiled tubing. The method may comprise providing the coiled tubing with the electrical cable preinstalled therein. The electrical cable may extend through both the upper and lower coiled tubing sections, and also through the releasable tubing connector.
The method may comprise coupling the pump to the electrical cable, for example prior to inserting the pump into the wellbore. The electrical cable may provide power and/or control to the pump, for example from a surface location. The electrical cable may be releasable from the pump when the pump is deployed, for example to permit the cable to be removed from the wellbore independently from the pump and the coiled tubing.
The electrical cable may comprise a tubing encapsulated electrical cable.
The method may comprise securing the electrical cable within the releasable tubing connector. The electrical cable may be secured within the releasable tubing connector prior to deployment into the wellbore. The method may comprise suspending the electrical cable within the releasable tubing connector. In this way the lower coiled tubing portion (and the connected pump) and the electrical cable may be suspended from the releasable tubing connector, wherein the releasable tubing connector is suspended from the suspending arrangement.
The method may comprise suspending the electrical cable from a cable hanger portion located within the releasable tubing connector. The cable hanger portion may form part of the releasable tubing connector. In one example the cable hanger portion may be secured to the electrical cable. The cable hanger portion may be mechanically secured to the cable hanger portion, for example via a clamping arrangement, friction arrangement or the like. The cable hanger portion may be sealingly secured to the electrical cable.
The cable hanger portion may be mechanically engaged within the releasable tubing connector, for example via an inter-engaging profile, such as a no-go profile. The cable hanger portion may include a load support feature to transfer axial load from the cable to the releasable tubing connector.
The cable hanger portion may be sealingly engaged within the releasable tubing connector. The cable hanger portion may be moveable within the releasable tubing connector. Such movement may selectively provide and remove a seal between the cable hanger portion and the releasable tubing connector, as described in more detail below. In one example the cable hanger portion may function as a seal shuttle.
The releasable tubing connector may comprise one or more flow ports providing fluid communication between an interior of the coiled tubing and an exterior thereof. The method may comprise operating a sealing shuttle inside the releasable tubing connector to selectively open and close the flow ports. In one example the sealing shuttle may be provided by a cable hanger portion within the releasable tubing connector.
The method may comprise providing a wellhead telescoping arrangement, and operating the sealing shuttle by extending and retracting a telescoping section of the telescoping arrangement.
The method may comprise locking the sealing shuttle in the releasable tubing connector. The locking may be performed by a latch arrangement, such as by a collet, split ring or the like.
The method may comprise cutting the upper coiled tubing portion and the electrical cable therein at a selected distance above the releasable tubing and retaining an upper coiled tubing stub portion coupled to the releasable tubing connector. The step of uncoupling the upper coiled tubing portion from the releasable connector may comprise uncoupling the upper coiled tubing stub portion from the releasable tubing connector, and exposing a selected length of the electrical cable.
The method may comprise coupling the cable to a source of electric current to operate the pump.
A wellhead or wellhead equipment provided at the surface of the wellbore may comprise a first fluid outlet in fluid communication with the flow ports in the releasable tubing connector and a second fluid outlet hydraulically separated from the flow ports and in fluid communication with an annular space between the coiled tubing and a surface casing extending from the wellhead and into the wellbore.
The method may comprise affixing a coiled tubing pressure control apparatus at the surface end of the well, for example on top of the wellhead. The method may comprise closing the coiled tubing pressure control apparatus to flow. The method may comprise lifting the pump into a lubricator and affixing the lubricator to the top of the coiled tubing pressure control apparatus. The method may comprise opening the coiled tubing pressure control apparatus (and optionally the suspending arrangement, if required to allow passage of the pump and coiled tubing) prior to extending the coiled tubing.
The wellhead adapter may comprise a segment of conduit sealingly engageable with an interior of an opening in the top of the wellhead and a cable adapter sealingly engageable with an interior of the segment of conduit and with an exterior of the cable.
One aspect of the present disclosure relates to a method for retrieving a pump from a wellbore, comprising:
The method may comprise completely withdrawing the releasable tubing connector, lower coiled tubing portion and pump from the wellbore on the interface component, for example by coiling onto a reel.
The method may comprise providing initial withdrawal of the releasable tubing connector, lower coiled tubing portion and pump on the interface component, and subsequently disconnecting the interface component from the releasable tubing connector. The method may comprise subsequently connecting an upper portion of coiled tubing to the releasable tubing connecting and then completing withdrawal of the releasable tubing connector, lower coiled tubing portion and pump from the wellbore.
One aspect of the present disclosure relates to a releasable tubing connector for providing a releasable connection between first and second tubing portions, comprising:
The releasable connector may be provided or used in the method according to any other aspect.
The releasable connector may be utilised to permit an electrical cable to be suspended from the releasable connector, such as an electrical cable, while also facilitating a releasable connection between first and second tubing portions. Such an arrangement may advantageously provide benefits in relation to the deployment of a pump within a wellbore, for example in accordance with any other aspect.
The releasable tubing connector may be a releasable coiled tubing connector for providing a releasable connection between first and second coiled tubing portions. The releasable tubing connector may be a spoolable releasable tubing connector.
The releasable tubing connector may be deployable into a wellbore. In one example, when deployed within a wellbore the first tubing connector may be defined as an upper tubing connector which is connectable to an upper tubing portion. Similarly, the second tubing connector may be defined as a lower tubing connector which is connectable to a lower tubing portion.
The releasable tubing connector may be disposable in a suspending arrangement within a wellbore. In such an arrangement the releasable tubing connector may be functional in suspending one of the first and second tubing portions (for example the second tubing portion) within the wellbore. The releasable tubing connector may be disposable within a suspending arrangement proximate a surface of the wellbore. The suspending arrangement may be provided within a wellhead assembly. The suspending arrangement may comprise one or more rams, for example which form part of a BOP. The suspending arrangement may be provided within a wellhead tree. The suspending arrangement may comprise a tubing hanger.
The first tubing connector may be releasable from the intermediate portion when the releasable tubing connector is deployed (for example in place within a wellbore or wellhead assembly.
The releasable tubing connector may comprise a tubing hanger profile provided on an outer surface thereof for engaging a tubing hanger. The tubing hanger profile may be releasably mountable on the releasable tubing connector. The tubing hanger profile may be provided on multiple segments assembled on the releasable tubing connector.
The first tubing connector may be coupled to the intermediate portion via any suitable releasable connection, such as via a threaded connection.
The second tubing connector may be releasably coupled to the intermediate portion, for example via a threaded connection. In an alternative example the second tubing connector may be permanently coupled to the intermediate portion. In one example the second tubing connector may be integrally formed with or as part of the intermediate portion.
The intermediate portion may be tubular.
The intermediate portion may comprise at least one port in a wall thereof for providing fluid communication between internal and external locations of the releasable connector. In one example the at least one port may facilitate outflow of a fluid driven by a pump connected to an opposing end of the second tubing portion.
The cable hanger portion may be moveable, for example axially moveable within the intermediate portion. The cable hanger portion may be moveable within the intermediate portion while connected to an electrical cable extending therein. Such movement may be permitted by virtue of compliance within the cable.
The cable hanger portion may be moveable within the intermediate portion to selectively open and close the at least one port. Selectively closing may comprise completely closing, for example to prevent flow. Selectively closing may comprise partially closing, for example to choke flow.
The cable hanger portion may function as a sealing shuttle.
The cable hanger portion may be moveable under control of an external actuator. In one example the cable hanger portion may be moveable under control of a wellhead penetrator, such as a telescoping wellhead penetrator.
In some examples the releasable tubing connector may comprise an actuator for providing movement of the cable hanger portion.
The cable hanger portion may comprise a seal extension which is configured to be inserted and removed from a sealing bore within the releasable tubing connector during movement of the cable hanger portion. The sealing bore may be provided within the intermediate portion. The sealing bore may be provided within the second tubing connector. The sealing bore may be located below the at least one port.
The cable hanger portion may be initially secured to the intermediate portion, for example via one or more shear elements, such as shear screws. The cable hanger portion may be releasable from the intermediate portion, for example upon application of a predetermined force.
The cable hanger portion may be configured to be connected, for example latched, relative to the intermediate portion to prevent or limit further relative movement between the cable hanger portion and the intermediate portion.
An aspect of the present disclosure relates to a wellbore pump assembly, comprising:
The wellbore pump system may further comprise an electrical cable extending from the pump and through the first and second coiled tubing portions and the releasable connector. The releasable connector may comprise a cable hanger portion to interconnect the electrical cable relative to the releasable connector.
One aspect of the present disclosure relates to a method for deploying a pump in a wellbore, comprising:
The connector may comprise flow ports in fluid communication between an interior of the coiled tubing and an exterior thereof.
The method may further comprise operating a sealing shuttle inside the wellhead adapter to selectively open and close the flow ports. The sealing shuttle may be operable by extending and retracting a telescoping section of the wellhead adapter operable to raise and lower a cable hanger having a sealing body and seal affixed thereto.
The method may further comprise locking the sealing shuttle in the connector.
The locking may be performed by collets latched into a latching feature in the connector.
The method may further comprise cutting the coiled tubing and the cable therein at a selected distance above the connector prior to uncoupling the connector to expose a selected length of the cable.
The method may further comprise coupling the cable to a source of electric current to operate the pump.
The wellhead may comprise a first fluid outlet in fluid communication with the flow ports in the connector and a second fluid outlet hydraulically separated from the flow ports and in fluid communication with an annular space between the coiled tubing and the surface casing.
The cable may comprise a tubing encapsulated electrical cable.
The method may further comprise affixing a coiled tubing pressure control apparatus on top of the wellhead, closing the coiled tubing pressure control apparatus to flow, lifting the pump into a lubricator, affixing the lubricator to the top of the coiled tubing pressure control apparatus, and opening the coiled tubing pressure control apparatus and the means for suspending prior to extending the coiled tubing.
The wellhead adapter may comprise a segment of conduit sealingly engageable with an interior of an opening in the top of the wellhead and a cable adapter sealingly engageable with an interior of the segment of conduit and with an exterior of the cable.
The cable adapter may comprise a load support feature to transfer axial load from the cable to the segment of conduit.
The means for suspending may comprise a rod lock blowout preventer.
The connector may comprise a roll on or dimple fitting disposed inside the coiled tubing and wherein the rod lock blowout preventer is closed on a portion of the coiled tubing having the roll on fitting therein.
Aspects of the present disclosure relate to methods and apparatus for deploying and/or retrieving a pump. However, the principles of the present invention may also relate to the deployment and/or retrieval of any wellbore equipment.
One aspect of the present disclosure relates to a method for deploying a wellbore apparatus in a wellbore, comprising:
One aspect of the present disclosure relates to a method for retrieving a wellbore apparatus from a wellbore, comprising:
One aspect of the present disclosure relates to a valve to be interconnected between first and second tubing portions, comprising:
The valve may function to provide a connection between the first and second tubing portions. The valve may thus function as a tubing connector.
The first tubing connector may be releasably coupled to the housing. Alternatively, the first tubing connector may be permanently coupled to the housing, for example integrally formed with the housing. The second tubing connector may be releasably coupled to the housing. Alternatively, the second tubing connector may be permanently coupled to the housing, for example integrally formed with the housing.
The at least one flow port may be provided within a wall of the housing.
The cable hanger portion may function as a valve member. The cable hanger portion may function as a seal shuttle.
The valve may be provided in accordance with a releasable tubing connector according to any other aspect.
The coiled tubing 18 disposed on the reel 20 of the coiled tubing deployment apparatus 10 may include an electrical cable (not visible in
The coiled tubing 18 may comprise a connector and cable hanger apparatus 22, which is not shown in
The connector and cable hanger apparatus 22 may be used to interconnect separate portions of the coiled tubing 18, in this case upper and lower portions of the coiled tubing 18, while allowing the different portions to be separated during deployment operations (and reconnected during retrieval operations if necessary). In the present example the connector and cable hanger apparatus 22 provides a connection between the different portions (upper and lower portions) of the coiled tubing 18 while still permitting the coiled tubing 18 to be spooled on the reel 20. As such, the connector 22 may also be defined as a spoolable coiled tubing connector. The connector 22 may function to provide a mechanical connection between the coiled tubing portions. The connector 22 may also function to accommodate or mechanically support the electrical cable which is disposed within the coiled tubing 18. Further, the connector 22 may facilitate opening/closing of flow from the coiled tubing 18.
The upper end of the ESP system 26 may also comprise a mechanical connector 36, such as a “roll on” connector, threaded connector or any other type of connector to couple the ESP system 26 to the end of the coiled tubing 18 such that the full weight of the ESP system 26 may be safely supported from the end of the coiled tubing 18, and that the outlet of the pump 32 in the ESP system 26 may be discharged into the interior of the coiled tubing 18 without any significant leakage of fluid from the connector 36.
In
In
In
In
In
The connector and cable hanger apparatus 22 may comprise fluid discharge ports 60 above the position of the rams 25 in the rod lock BOP 24. The discharge ports 60 are aligned with one or more outlet ports 61 provided on the rod lock BOP 24. Suitable pipework (not shown) may be connected to the outlet ports 61 to receive flow from the wellbore and deliver this to appropriate production equipment. The rod lock BOP 24 may also include a separate fluid outlet 62 in fluid communication with the wellbore below the rams 25 in the rod lock BOP 24. Thus, the wellbore has two fluid outlets that are hydraulically isolated from each other; a first outlet 62 being in communication with the wellbore casing (below the rod lock BOP rams 25) and a second outlet 61 being in fluid communication through the fluid discharge ports 60 in the connector and cable hanger apparatus 22 with the interior of the coiled tubing 18.
In
In
In the present example embodiment, the electrical cable 64 may be a tubing encapsulated cable (TEC). TEC may be obtained, for example from Draka division of Prysmian Group (Prysmian, S.p.A.) Viale Sarca, 222 20126 Milan, Italy. Possible advantages of using TEC are resistance to damage of the electrical cable 64 by reason of fluid flowing through the coiled tubing when the ESP system 26 is operating.
The connector 22 may further include an intermediate ported tubular portion 84 which includes the discharge ports 60 to enable flow of fluid from inside the coiled tubing 18 to enter the rod lock BOP 24 (
The upper coiled tubing connector portion 66 may be coupled to the upper portion 18a of the coiled tubing 18 using any suitable connection, such as a roll on connection or similar device; the connection need not be fluid tight. The upper coiled tubing connector portion 66 may be connected to the intermediate ported tubular portion 84 by any device that enables disconnection of the upper coiled tubing connector portion 66 at the well site while the coiled tubing 18 is suspended in the wellbore. A threaded connection may be provided, for example.
As noted above, the upper coiled tubing connector portion 66 and the upper coiled tubing portion 18a will have already been removed when the components of
In the present example the connector 22 may comprise a tapered seat 86 that is configured to engage a suspension slip cone or cable hanger portion 88 mechanically affixed to the exterior of the electrical cable 64. The cable hanger portion 88 may be a two-part tapered cone assembly that frictionally engages the exterior tube of the TEC 64. As configured, the upper coiled tubing connector portion 66 may be disengaged from the intermediate ported tubular portion 84, leaving said intermediate portion 84 suspended in the wellbore by the rod lock BOP 24 and the cable 64 suspended in the intermediate ported tubular portion 84 by the cable hanger portion 88.
The cable hanger portion 88 may include on its lower end collets 90 that may engage a corresponding engagement surface 92 inside the lower coiled tubing connector portion 82. The collets 90 may hold the cable hanger portion 88 in position inside the connector 22.
A seal, such as a lip seal or O-ring 94 may be disposed about a cylindrical body of the cable hanger portion 88. When the cable hanger portion 88 is fully lowered into the connector 22, the seal 94 is seated inside a seal bore 96 to isolate the lower interior of the coiled tubing 18, such that the flow ports 60 may be closed to fluid flow. The seal bore 96 may be provided within the intermediate ported tubing portion 84, or alternatively within the lower coiled tubing connector 82
In the present example the cable hanger portion 88 functions as an internal shuttle component which is axially moveable within the intermediate ported tubular portion 84, under the control of the telescoping wellhead penetrator 68 and sealing shuttle load tube 72 (
In some examples the connector and cable hanger apparatus 22 may be initially configured such that the discharge ports 60 are closed during the installation procedure. When in such an initially closed configuration the collet 90 of the cable hanger portion 88 may not yet be fully engaged within the engagement surface 92, thus permitting subsequent movement of the cable hanger portion 88. Once installation is complete the cable hanger portion 88 may be shifted upwardly by action of the telescopic wellhead penetrator 68 to open the ports 60 and allow suitable flow from the wellbore. Whenever necessary the cable hanger portion 88 may be shifted downwardly to close the discharge ports 60, for example during a retrieval operation to retrieve the coiled tubing 18 and ESP 26 form the wellbore. In some examples such re-closure of the ports 60 may involve downward movement of the cable hanger portion 88 by a sufficient distance to allow the collet 90 to fully engage within the engagement surface 92, thus providing a more permanent closure of the ports 60. Such an arrangement may require retrieval and redressing of the connector 22. In some examples, however, the collet 90 may be releasable from the engagement surface 92 upon exceeding a threshold separation or release pulling force.
It should be noted that axial movement of the cable hanger portion 88 (which functions as the internal shuttle) to open and close the discharge ports 60 is performed while mechanically connected to the cable 64. The present inventors have discovered that such an arrangement is permitted and acceptable by virtue of compliance of the cable 64. Such compliance may be provided in view of a degree of “slack” in the cable 64, for example either intentionally provided or as a function of the difference between the effective cord length of the cable 64 and that of the coiled tubing 18 when spooled on the coiled tubing reel 20 (
An alternative example connector and cable hanger apparatus 122 is illustrated in
In the same manner as described above, the coiled tubing 18 may be deployed into a wellbore to locate an ESP (not shown in
In a similar manner to that of the previously described connector 22, the upper coiled tubing connector portion 166 is secured to the intermediate ported tubular portion 184 via a releasable connection, which in the present example is a threaded connection 200. This releasable threaded connection 200 permits the upper coiled tubing connector portion 166 and associated upper coiled tubing portion 18a to be removed, in the same manner as illustrated in
The connector 122 further includes an internal cable hanger portion 188 which is mechanically and sealably secured to the electrical cable 64. As will be described in more detail below, the cable hanger portion 188 is axially moveable relative to the intermediate ported tubular portion 184 to open or close the discharge ports 160. As such, the cable hanger portion 188 may function as a sealing shuttle.
An upper end of the mandrel 202 includes a load tube connector 216 which facilitates connection with the sealing shuttle load tube 72, shown in broken outline (and first illustrated in
When the connector 122 is appropriately deployed, with all necessary wellhead equipment installed, the sealing shuttle load tube 72 may apply an upward force on the mandrel 202, shearing screws 204 and moving the mandrel 202 upwardly, as illustrated in
If the discharge ports 160 must be closed once again the mandrel 202 may be moved downwardly by the sealing shuttle load tube 72 to re-engage the sealing extension 212 within the lower coiled tubing connector portion 182. The mandrel 202 may be returned to the same position illustrated in
As outlined above, in some examples a connector and cable hanger apparatus (22, 122) may be located and engaged with a rod lock BOP, with rams of the rod lock BOP supporting the connector. However, in other examples the connector may be suspended in other wellhead equipment or infrastructure. In one particular example, which will now be described with reference to
When the hanger segments 402, 404 are mounted together on the connector 322 as illustrated in
Examples provided above relate to methods and corresponding apparatus to facilitate deployment of an ESP into a wellbore. The present disclosure also extends to possible retrieval methods for use in retrieving an ESP from a wellbore. In this respect an appropriate reversal of some or all deployment steps may be performed, as described below.
When retrieval is required the discharge ports in a connector and cable hanger apparatus may be closed. Subsequent to this the various equipment and infrastructure may be disassembled, such as in the reverse sequence of
A method and connector system as described herein may enable rapid, economical deployment of an ESP system without the need to anchor the ESP system in the wellbore and without the need to deploy a workover rig or similar device to install a production tubing.
While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.
Continuation of International Application No. PCT/GB2017/050086 filed on Jan. 14, 2017. Priority is claimed from U.S. Provisional Application No. 62/278,150 filed on Jan. 14, 2016. The foregoing applications are incorporated herein by reference in their entireties.
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| International Preliminary Report on Patentability and Written Opinion of the International Searching Authority International Application No. PCT/GB2017/050086, International filing date of Jan. 13, 2017. |
| International Search Report and Written Opinion, International Application No. PCT/GB2017/050086, dated May 16, 2017. |
| Number | Date | Country | |
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| 20180320454 A1 | Nov 2018 | US |
| Number | Date | Country | |
|---|---|---|---|
| 62278150 | Jan 2016 | US |
| Number | Date | Country | |
|---|---|---|---|
| Parent | PCT/GB2017/050086 | Jan 2017 | US |
| Child | 16032806 | US |
