Patent Grant
11105184
As is well known, a production string of tubulars having a completion on its lower end can be inserted into a cased or uncased wellbore. The production string may be required for a number of reasons, including carrying produced fluid from production zones up to the surface of the wellbore.
Conventionally, the production string includes one or more completion tools, such as: a barrier in the form of a flapper valve or the like; a packer to seal the annulus between the completion string and the casing; and a circulation valve to selectively circulate fluid from out of the throughbore of the production tubing and into the annulus to flush fluids up the annulus and out of the wellbore. The production string may also include other completion tools, such as sand screen assemblies, gravel packing equipment, sliding sleeves, and the like.
The various completion tools downhole can be selectively activated in a number of ways. In one method, operators can use intervention equipment, such as tools run with an intervention rig into the production tubing on slickline to actuate the tools. In an alternative method, the completion and production string can be run into the cased wellbore with electrical cables that run from the various tools up the outside of the production string to the surface. In this way, power and control signals can be sent down the cables to the various tools.
Despite these methods, a completion apparatus is desirable that can reduce the requirements for either cables run from the downhole completion up to the surface and/or reduce the need for intervention to be able to actuate the various completion tools.
According to the present disclosure, a completion apparatus for a wellbore comprises one or more completion or flow tools. In one particular arrangement, the apparatus includes plurality of flow tools and includes an actuation mechanism disposed downhole for operating the flow tools.
The flow tool comprises a housing, a piston, and a sleeve. The housing defines a throughbore and has a first (circulation) port and a second (production) port communicating the throughbore with the wellbore. The piston defines first and second chambers with the housing. The chambers communicate with hydraulics, and the piston is movable in response to the communicated hydraulics.
The sleeve is disposed in the throughbore and is movable with the piston between first, second, and third positions. The sleeve in the first (closed) position closes off communication through the circulation and production ports, whereas the sleeve in the second (circulation) position permits communication through the circulation port and closes off communication through the production port so circulation, treatment, or fracture operations can be performed. The sleeve in the third (production) position closes off communication through the circulation port and permits communication through the production port so production can be performed.
The apparatus can include a screen disposed on the apparatus adjacent the flow tool to screen fluid communication of produced fluids from the wellbore to the production port when the tool is configured for production. A flow control in the form of a nozzle, valve, or the like can be disposed on the apparatus in fluid communication between the screened fluid and the production port to control the flow of the screen fluid (i.e., change velocity, pressure, or flow rate of the produced fluid).
During operations to circulate treatment, the sleeve can be sequenced at least one time from the first (closed) position to the second (circulation) position and from the second (circulation) position back to the first (closed) position. To produce fluid, the sleeve can be sequenced at least one time from the first (closed) position to the third (production) position.
The flow tool can further include a seat disposed in the throughbore and movable with the sleeve between first (pass) and second (engage) conditions. For example, the seat in the pass condition is expanded to pass a given plug traveling through the throughbore of the flow tool, while the seat in the engage condition is contracted or restricted to engage a given plug traveling through the throughbore. Being movable with the sleeve, the seat has its different conditions based on the position of the sleeve. For example, the seat has the pass condition with the sleeve in the closed position. Thus, the seat having the pass condition with the sleeve in the closed position can pass any number of the given plug travelling through the throughbore. Alternatively, the seat has the engage condition with the sleeve in the circulation position so the seat can engage the given plug traveling through the throughbore and divert circulated fluid in the throughbore out the circulation port. Finally, the seat can have the pass condition with the sleeve in the production position to pass any number of plugs travelling through the throughbore.
In one configuration, the seat comprises a plurality of segments disposed about the throughbore and carried by the sleeve. The segments have the pass condition expanded into a first recess in the throughbore when the sleeve is in the closed and the production position, while the segments have the engage condition retracted in the throughbore when the sleeve is in the circulation position. As an alternative, the seat can include a split ring, dogs, or other components available in the art.
In one arrangement, the apparatus further comprises an actuation mechanism disposed on the apparatus and operable to communicate the hydraulics respectively with the first and second chambers of one or more of the flow tools. For example, the actuation mechanism can include at least one hydraulic source communicating the hydraulics, at least one detector receiving one or more communicated signals, and an electronic control in operable communication with the at least one detector. The electronic control can operate the at least one hydraulic source in response to the one or more received signals.
The at least one detector can be a wireless antenna and/or a pressure transducer. Meanwhile, the at least one hydraulic source can include at least one electric motor operating at least one hydraulic pump in fluid communication with at least one hydraulic fluid reservoir. At least one selector can be provided to selectively communicate the hydraulics of the at least one hydraulic source with a plurality of transmission lines for various flow tools of the completion apparatus.
According to the present disclosure, completing zones of a wellbore with a completion apparatus involves selecting any one of the zones. Each of the zones is associated with a flow tool of the completion apparatus. To select any one of the zones and open/close the tool's ports, signals can be received downhole at the completion apparatus, or a timer of the completion apparatus can be timed out.
For the selected zone, a circulation port is opened in the associated flow tool by actuating hydraulics of the completion apparatus. Fluid is then circulated from the circulation port to the wellbore for treatment, circulation, fracturing, or the like. After treatment, the circulation port is then closed in the associated flow tool by actuating the hydraulics of the completion apparatus.
At least one other completion operation can then be performed in the wellbore. For example, another zone can be selected for treatment in a comparable manner. Eventually, the flow tool can be configured for production by actuating the hydraulics of the completion apparatus to open a production port in the associated flow tool associated with the selected zone. During production, wellbore fluid can be screened into the production port through a screen associated with the associated flow tool.
To circulate the fluid from the circulation port to the wellbore, a deployed plug can be engaged at a seat of the associated flow tool to at least partially divert the circulated fluid from the circulation port. Then, closing the circulation port in the associated flow tool further can involve releasing the engaged plug from the seat.
Actuating the hydraulics of the completion apparatus can involve supplying the hydraulics to chambers of a piston of the associated flow tool to shift a sleeve opened/closed relative to the circulation port with the piston. Similarly, actuating the hydraulics of the completion apparatus to open the production port can involve supplying the hydraulics to one of the chambers of the piston to shift the sleeve open relative to the production port with the piston.
The foregoing summary is not intended to summarize each potential embodiment or every aspect of the present disclosure.
In completion systems, it can be advantageous to treat, circulate fluids, fracture, etc. various zones downhole in any desired sequence. Additionally, it can be advantageous to produce from various zones downhole in any desired sequence. As shown in
The completion assembly 10 includes an actuation mechanism 20 and includes a number of completion or flow tools 100A-E located along the production string 14 at various zones. Packers 16 may be located in the annulus of the wellbore 12 to isolate the zones from one another, and the completion assembly 10 may include a circulation valve 17, which may be in the form of a ball valve, a flapper valve, or a remotely actuated valve according to the present disclosure.
Each of the completion tools 100A-E includes a first (outlet or circulation) port 102, which may be used for circulation, facture, or other treatment of the surrounding zone. Each of the completion tools 100A-E also include a second (inlet or production) port 104, which may be used for production from the surrounding zone. As preferred, the inlet port 104 for the tools 100A-E may communicate with screens 106 for screening the produced fluid from the zone.
Internally and as discussed in more detail below, each of the completion tools 100A-E further includes a valve 108 selectively operable to open and close the outlet and inlet ports 102, 104 according to operations to be performed in the various zones. According to one arrangement detailed later with respect to
During deployment, the completion assembly 10 is run in the wellbore 12 on the production string 14, which is made up of a number (which could be hundreds) of production tubulars having threaded connections. The completion assembly 10 is run into the wellbore 12 with the circulation valve 17 in the open configuration so fluid can flow in production string 14. The packers 16, if present, are run into the wellbore 12 in an unset configuration so they do not seal in the annulus. Additionally, the completion tools 100A-E are run in a closed configuration in which the ports 102, 104 are closed by the respective valves 108.
Once deployed in the wellbore 12, the production string 14 may be pressure tested, and the packers 16 may then be set. These steps may involve opening/closing the circulation valve 17, pressuring up the production string 14, and/or actuating the packers 16. These steps can be achieved in a number of ways. For example, a ball may be dropped down the production string 14 to close off the valve 17 so built-up tubing pressure can set the packers 16. Alternatively, tags 18 can be inserted into fluid at the surface of the wellbore 12 and can be pumped down through the production string 14 to the completion assembly 10. The tags 18 can be coded at the surface with instructions to tell the actuation mechanism 20 to actuate the circulation valve 17, set the packers 16, etc. Also, if fluid flow is not available through the production string 14 during various stages, pressure signals instead of tags 18 can be sent downhole from the surface to the actuation mechanism 20 to sense the pressure signals in the fluid within the string 14 and to then actuate the circulation valve 17, set the packers 16, etc.
Once the completion assembly 10 is properly set, various treatment and production operations can be selectively performed. In the assembly 10 of
The actuation mechanism 20 can be controlled from the surface using a number of techniques, including, but not limited to, pressure pulse telemetry, electrical communication through wired lines, wirelessly using RFID tags, etc. In one particular embodiment, the actuation mechanism 20 is a wireless remote control central power unit similar to what is disclosed in U.S. Pat. No. 8,833,469 and its related co-pending application U.S. Pub. 2015/0285063, which are incorporated herein by reference in their entirety.
A control transmission 40 is shown schematically in
In one arrangement, signals in the form of one or more tags 18, pressure pulses, etc. coded at surface with predetermined instructions can be introduced into the fluid flow for the actuation mechanism 20 to actuate various ones of the flow tools 100A-E (and the circulation tool 17 and packers 16 if applicable). Features of the actuation mechanism 20 in the form of a wireless remote control central power unit are schematically shown in FIG. 2. The mechanism 20 includes an RFID tag detector 22 having an antenna to detect signals sent from the surface. The signals are coded onto RFID tags 18 at the surface by operators and then deployed through the tubing string (14) to the mechanism 20. In addition or in the alternative, a pressure signature detector 24 with a pressure transducer or the like can be used to detect peaks in fluid pressure in the tubing string (14) applied at the surface by the operators to provide a second way for the operators to send signals downhole to the mechanism 20.
A battery pack 26 is provided if direct electrical communication with the surface is not provided. The battery package 26 may thereby provide all the power requirements to the mechanism 20. An electronics package 28 with an electronic control and memory has stored information coded at the surface by the operators with the instructions for selection of which completion tools 100A-E to operate depending upon what signals are received by one of the two receivers 22, 24. The electronics package 26 may also include one or more timers for initiating operations after a period of time.
In response to signals, timers or the like, the actuation mechanism 20 uses hydraulic power to selectively operate the selected completion tools 100A-E. Accordingly, one or more hydraulic sources 30 having electrical motor and hydraulic pump combinations can be operated to control the opening and closing of one or more of the flow tools 100A-E.
As shown in
As noted, other tools of the completion assembly 10 besides the flow tools 100A-E can be actuated by the actuation mechanism 20. For example,
As depicted in
To operate a given one of the completion tools 100A-E with circulation being possible, one or more pre-programmed RFID tags 18 dropped or flushed into the completion string (14) eventually reach the actuation mechanism 20. The tag 18 then transmits certain radio frequency signals, enabling it to communicate with the mechanism's antenna 22. This data is then processed by the electronics package 28. As an example, the RFID tag 18 may have been programmed at the surface by the operators to transmit information instructing the mechanism 20 to open the outlet port (102) on one of the given flow tools (100A-E) to commence treatment of the associated zone. (As noted, a pressure signal can be used to communicate with the mechanism's pressure detector 24.)
The electronics package 28 processes the data and instructs the motor/pump combination 30 powered by battery pack 26 to drive a hydraulic piston pump (not shown). Hydraulic fluid is then pumped through one of the hydraulic conduits 42, 44 to the piston 108 of the selected tool (100A-E) to shift the tool's sleeve (110). Fluid exits the piston 108 through the other hydraulic conduit 44, 42 for return to a hydraulic fluid reservoir (not shown) of the motor/pump combination 30. This action results in the shifting of the sleeve (110) to open fluid communication through the circulation port (102). Continued operation of opening/closing ports (102, 104) on this and other of the flow tools (100A-E) can follow comparable steps.
With an understanding of the overall completion assembly 10, discussion now turns to
The tool 100 includes a housing 101, which may comprise several components to facilitate assembly. As noted above, the tool 100 has a valve 108 that can selectively control fluid communication through outlet ports 102 and inlet ports 104. The outlet ports 102 defined in the housing 101 can be circulation ports for communicating fracture fluid or other treatment out of the tool 100. The inlet ports 104 defined in the housing 101 can be production ports that communicate fluid passing from the wellbore through a screen 106 and nozzle 107 into the tool 100.
As noted above, the valve 108 includes a sleeve 110 movable in the bore of the housing 101 by operation of a piston 130. Fluid communicated via conduits 142, 144 in the housing 101 communicate with opposing sides of the piston 130, which moves the sleeve 110 in opposing directions in the housing 101. These conduits 142, 144 communicate with the actuation mechanism (20:
The sleeve 110 includes openings 112 for aligning or misaligning with the circulation ports 102 on the housing 101. The sleeve 110 further includes openings 114 for aligning or misaligning with the production ports 104 on the housing 101. The sleeve 110 is movable with the piston 130 between first, second, and third positions. For example, the sleeve 110 in the first position (
Finally, a seat 120 is disposed on the sleeve 110 and is movable therewith between a pass (retracted) condition and an engage (contracted) condition depending on the position of the sleeve 110 in the housing 101. As shown in the current arrangement, the seat 120 can be segmented having dogs or segments 122 that contract and retract relative to one another depending and on the location of the dogs or segments 122 relative to recesses 105A-B in the housing's bore. The tool 100 can use other types of seats, such as a split C-ring seat that expands and contracts, segments having interstitial elastomer to prevent a buildup of material, etc. Accordingly, the seat 120 can have any other suitable structure.
The seat 120 in the pass condition is expanded to pass a plug P traveling through the tool 100, whereas the seat 120 in the engage condition is restricted to engage a traveling plug P. As shown, the seat 120 has the pass condition with the sleeve 110 in the first, closed position (
Operation of the completion tool 100 in
After run in, the flow tool 100 is in a first, closed condition as shown in
When circulation or fracturing is set to occur at a selected zone (Decision 202), a first signal is sent from the surface (Block 204), first hydraulics are actuated (Block 206), and the sleeve 110 of the selected tool 100 is sequenced or shifted from the closed position to the second, circulation position (
For example, the actuation mechanism (20) discussed previously is initiated by a signal, trigger, timer, RFID tag (18), pressure pulse, or the like being deployed down the tubing string (14). The hydraulic pressure unit of the actuation mechanism (20) pressures up the first hydraulic line 142 for the selected tool 100 to a first pressure level. (The second hydraulic line 144 may be vented to the reservoir of the mechanism (20) or elsewhere.) The build-up pressure in the piston 130 of the tool 100 then shifts the sleeve 110 to a first opened condition, as shown in
As shown, the sleeve 110 aligns its set of circulation openings 112 with the circulation ports 102 so that fluid communication is permitted between the tool's bore and the wellbore. In this shift of the sleeve 110, the seat 120 is moved from the pass condition to the engage condition suited for catching a plug, such as a later deployed plug P2. As shown, the seat 120 can have a number of segments 122 that reside in a recess 105A of the tool's bore when in the pass condition (
As shown in
The selected zone can now been treated (fractured) by pumping the treatment fluid T down the tubing string (14) and diverting the treatment to the zone through the opened tool 100 (Block 212). After the treatment (fracture) operation, a second signal is sent from the surface (Block 214), second hydraulics are actuated (Block 216), and the sleeve 110 of the selected tool 100 is sequenced or shifted from the circulation position back to the initial closed position, as shown in
To sequence the sleeve 110, for example, the actuation mechanism (20) discussed previously is initiated by a second signal, trigger, or the like. For this and any other signaling disclosed herein, a telemetry pressure pulse, a second RFID tag (18), timer, or other form of transmission may be used. Depending on whether circulation is available, an RFID tag (18) can be deployed down the tubing string (14) to provide the second signal. Otherwise, if circulation is not available, then the pressure pulse telemetry or timer can be used.
In response to the second signal, the hydraulic pressure unit of the actuation mechanism (20) pressures up the second hydraulic line 144 for the selected tool 100 to a first pressure level. (The first hydraulic line 142 can be vented.) The built-up pressure on the opposing side of the piston 130 of the tool 100 then shifts the sleeve 110 from the second position back to its initial closed condition closing the circulation ports 102 on the tool 100.
The actuation mechanism (20) can control the shifting so that the sleeve 110 does not shift past the closed position. Also, a feature on the tool 100 can prevent further shifting of the sleeve 110 beyond the initial position. For example, a dog, catch, or temporary lock can engage when the sleeve 110 shifts back to the initial closed position so that the built-up pressure does not shift the sleeve 110 past this initial position. As noted below, a shearable device, such as shear ring, shear pins, etc., on the piston 130 can engage a shoulder in the chamber 109 to prevent further movement of the sleeve 110.
As shown in
At any point, this completion tool 100 can be again shifted from this closed position (
At some point during operations, the given zone along with any other zones may be set for production (Decision 222). A third signal is sent from the surface (Block 224), the second hydraulics are actuated (Block 226), and the sleeve 110 of the selected tool 100 is sequenced or shifted to the third, production position (
For example, the actuation mechanism (20) discussed previously is initiated by a third signal, trigger, or the like, such as a third RFID tag (18) being deployed down the tubing string (14). The hydraulic pressure unit of the actuation mechanism (20) pressures up the second hydraulic line 144 for the selected tool 100 to a second pressure level. (The first hydraulic line 142 can be vented.) The built-up pressure on the opposing side of the piston 130 of the tool 100 then shifts the sleeve 110 to the third opened condition, as shown in
As shown, the sleeve 110 aligns its set of production openings 114 with the production ports 104 so that fluid communication is permitted between the tool's bore and the screen 106, which can have inflow controls, such as a nozzle 107, check valve, etc. In this shift of the sleeve 110, the seat 120 is moved from its initial pass condition to a subsequent pass condition in another recess 105B for releasing and passing deployed plug(s). At this point, other stages can be actuated, and any deployed plugs can be allowed to pass through the tool 100.
Although the completion tool 100 is described here as being particularly sequenced from the first (closed) position to the second (circulation) position, back to the first (closed) position, and then to the third (production) position, such a sequence is not strictly necessary, especially if treatment or circulation is not required for the zone. Accordingly, it is possible for the tool 100 to be operated from the outset from the first (closed) position (
Although the recess 105B can be provided for the seat 120 to retract, an alternative arrangement of the tool 100 may instead lack such a recess 105B. Instead, the seat 120 can have the engage condition while the sleeve 110 is in the production position. This arrangement may allow a plug (not shown) to be deployed to the tool 100 to engage the seat 120, which may have a number of purposes, such as closing off fluid flow further downhole, shifting the sleeve 110, or the like.
To shift the sleeve 110 from the closed position to the production position (
The second pressure level on the piston 130, however, used to move the sleeve 110 into the production position that uncovers the production ports (104) is set to shear the device 150. For example,
The foregoing description of preferred and other embodiments is not intended to limit or restrict the scope or applicability of the inventive concepts conceived of by the Applicants. It will be appreciated with the benefit of the present disclosure that features described above in accordance with any embodiment or aspect of the disclosed subject matter can be utilized, either alone or in combination, with any other described feature, in any other embodiment or aspect of the disclosed subject matter.
In exchange for disclosing the inventive concepts contained herein, the Applicants desire all patent rights afforded by the disclosed subject matter. Therefore, it is intended that the disclosed subject matter include all modifications and alterations to the full extent that they come within the scope of the disclosed embodiments, combinations, and the equivalents thereof.
This is a continuation of U.S. application Ser. No. 15/437,492, filed Feb. 21, 2017, which claims the benefit of U.S. Provisional Appl. 62/299,525, filed Feb. 24, 2016, both of which are incorporated herein by reference.
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| Number | Date | Country | |
|---|---|---|---|
| 20190218888 A1 | Jul 2019 | US |
| Number | Date | Country | |
|---|---|---|---|
| 62299525 | Feb 2016 | US |
| Number | Date | Country | |
|---|---|---|---|
| Parent | 15437492 | Feb 2017 | US |
| Child | 16361754 | US |
